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Home My WebLink About201-168Nolan 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: 1/21/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260121 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 16RD 50133205540100 207125 12/3/2025 AK E-LINE PPROF T41253 BRU 211-35 50283201890000 223050 11/7/2025 AK E-LINE Perf T41254 BRU 213-26 50283201920000 223069 11/23/2025 AK E-LINE Perf T41255 BRU 213-26T 50283202040000 225038 11/4/2025 AK E-LINE Perf T41256 BRU 241-34S 50283201980000 224077 11/9/2025 AK E-LINE Perf T41257 BRU 241-34T 50283201810000 220052 11/6/2025 AK E-LINE Perf T41258 BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf T41259 BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun T41259 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf T41260 IRU 241-01 50283201840000 221076 12/21/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/30/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/16/2025 AK E-LINE Plug T41261 IRU 241-01 50283201840000 221076 11/26/2025 AK E-LINE Plug/Perf T41261 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf T41262 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF T41263 KU 12-17 50133205770000 208089 11/14/2025 AK E-LINE StimGun T41264 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf T41265 MPI 2-32 50029220840000 190119 12/10/2025 AK E-LINE LDL T41266 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL T41267 MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL T41268 MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut T41268 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL T41269 NCIU A-06A 50883200260100 225071 11/28/2025 AK E-LINE Perf/Plug T41270 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT T41271 NCIU A-19 50883201940000 224026 12/16/2025 AK E-LINE GPT T41272 NCIU A-19 50883201940000 224026 12/12/2025 AK E-LINE GPT/Perf/Plug T41272 NCIU A-19 50883201940000 224026 12/17/2025 AK E-LINE Perf T41272 NCIU A-21A 50883201990100 225075 12/30/2025 AK E-LINE PPROF T41273 OP19-T1N 50029234910000 213068 11/19/2025 AK E-LINE TubingPunch T41274 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:35 -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: PCU D-10 50283202080000 225082 12/9/2025 AK E-LINE Perf T41275 SCU 322C-04 50133101040100 215217 12/4/2025 AK E-LINE TubingPunch T41276 SRU 222-33 50133207150000 223100 12/7/2025 AK E-LINE Plug T41277 SU 43-10 50133207390000 225107 11/26/2025 AK E-LINE CBL T41278 TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf T41279 TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch T41280 TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch T41280 TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf T41281 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:51 -09'00' From:McLellan, Bryan J (OGC) To:Scott Warner Cc:Starns, Ted C (OGC); Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL] FW: LRU C-01RD AOGCC 10-403 325-686 PTD 201-168 Approved 11-20-25 Date:Tuesday, November 25, 2025 2:00:00 PM Scott, Hilcorp has approval to cut tubing at approximately 3916’ MD as requested. 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, November 25, 2025 12:48 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Starns, Ted C (OGC) <ted.starns@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] FW: LRU C-01RD AOGCC 10-403 325-686 PTD 201-168 Approved 11-20-25 Bryan, Yes, the plan is to recover the tubing from the cut point and then attempt to retrieve additional tubing below the current tag depth of approximately 3,916’. This would provide access to at least the H-I perforations and if cleanout and tubing recovery are successful below the cut, potentially the 46-8 and 47-5 intervals as well. Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Sent: Tuesday, November 25, 2025 12:14 PM To: Scott Warner <scott.warner@hilcorp.com> Cc: Starns, Ted C (OGC) <ted.starns@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] FW: LRU C-01RD AOGCC 10-403 325-686 PTD 201-168 Approved 11-20-25 The plan for the rig is to recover some of the tubing and CT below the tubing cut depth of 3916’ 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, November 25, 2025 12:09 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Starns, Ted C (OGC) <ted.starns@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] FW: LRU C-01RD AOGCC 10-403 325-686 PTD 201-168 Approved 11-20-25 Bryan, If the proposed perforations do not restore flow, we are proceeding with the tubing cut now to maximize our ability to pull the tubing as deep as possible should sand continue to enter the well. From the cut point, the tubing would be pulled, and the rig would then attempt to reach greater depth and recomplete the well using a monobore/cement completion if possible. Hilcorp believes this approach gives us the best opportunity to secure the reserves if the perforations fail to recover the well. Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 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. Cell: (907) 830-8863 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, November 25, 2025 10:42 AM To: Scott Warner <scott.warner@hilcorp.com> Cc: Starns, Ted C (OGC) <ted.starns@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] FW: LRU C-01RD AOGCC 10-403 325-686 PTD 201-168 Approved 11-20-25 Scott, What would be the scope of the future RWO mentioned in the Sundry? 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, November 25, 2025 9:02 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: FW: LRU C-01RD AOGCC 10-403 325-686 PTD 201-168 Approved 11-20-25 Bryan, The sundry has an estimated tubing cut at 4070’ since that was where coil cleaned out to recently. We just tagged the fill at ~3916’ with slickline and plan to cut the tubing at that depth followed by perforations as per sundry. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Thursday, November 20, 2025 2:48 PM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: LRU C-01RD AOGCC 10-403 325-686 PTD 201-168 Approved 11-20-25 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 the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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 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 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, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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): 6,469' 4,070' (fill) Casing Collapse Structural Conductor 1,130psi Surface 3,880psi Intermediate Production 4,320psi Liner 7,250psi 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: Chad Helgeson, Operations Engineer Contact Email:chelgeson@hilcorp.com Contact Phone: 907-777-8405 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 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: 1-1/4" PRESENT WELL CONDITION SUMMARY 75' AOGCC USE ONLY 8,290psi Tubing Grade: 2.3# / L-80 Noel Nocas, Operations Manager 907-564-5278 Tubing MD (ft): 2,339'Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0058798 201-168 50-283-20061-01-00 Hilcorp Alaska, LLC Proposed Pools: 75' 6.4# / N-80 TVD Burst 5,490' 4,980psi 2,408' Size 368' 2,409' MD 5" See Attached Schematic 2,730psi 4,720psi 368'368' 2,409' November 24, 2025 6,461'4,007' 2-7/8" 6,437' 75' 20" 2,650' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Lewis River Unit (LRU) C-01RDStatewide Spaing Same 2,649'7" ~1622psi 2,650' 6,043' Length Baker FH Pkr; N/A 2,386' MD/2,365'TVD; N/A, N/A 6,384' 6,043' 5,980' Lewis River Undefined Gas 13-3/8" 9-5/8" See Attached Schematic 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 8:11 am, Nov 12, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.11.10 17:31:21 - 09'00' Noel Nocas (4361) 325-686 DSR-11/13/25BJM 11/19/25 10-404 A.Dewhurst 20NOV25 11/20/25 Well Prognosis Well Name: LRU C-1RD API Number: 50-283-20061-01-00 Current Status: Gas Producer Permit to Drill Number: 201-168 First Call Engineer: Chad Helgeson (907) 229-4824 Second Call Engineer: Ryan Lemay (661) 487-0871 Maximum Expected BHP: 1825 psi @ 4056 TVD (Based on 0.45 psi/ft gradient) Max. Potential Surface Pressure: 1622 psi (Based on 0.05 psi/ft gas gradient to surface) Applicable Frac Gradient: 0.754 psi/ft using 14.5 ppg EMW FIT at the 7 surface casing shoe Shallowest Potential Perf TVD: MPSP/(0.754-0.05) = 1622 psi / 0.704 = 2303 TVD Well Status: Online Gas Producer making 40 mcf/day at 260 psi Brief Well Summary Lewis River C-01RD was drilled and completed in 2001 as a twin to replace C-01 which was offline as a result of sanding up. In July 2002, perforations were added to the 58-0 sands, rates IPd greater than 10.0 MMCFD, but quickly dropped below 3.0 MMCFD. In January 2006, the well sanded up, necessitating a coil cleanout to 6009. Following the coil cleanout perfs were reshot in August 2006 in the 58-0 & 60-2 sands and a thru tubing gravel pack was placed over them. The well remained shut-in until May 2008 when the 46-8 & 47-5 sands were perforated. The well enjoyed a good run of on-time, until September 2019 when the Beluga F5 sands were added. After perforations in April 2024, the well has flowed a steady 1+ mmscfd until it sanded up in October 2025. Coil tubing cleaned out the well to 4070. The well is equipped with 2-7/8 tubing and requires a minimum of 810 MCFD to maintain unloading rates. The purpose of this work/sundry is to increase productivity by perforating additional Beluga sands. History: SI Buildup pressure 804 psi on 11/5/25 Procedure: 1. Review approved COAs 2. MIRU Eline, PT lubricator to 250/2500 psi. 3. MU & RIH with tubing cutter (1.689 jet cut or RCT) and cut tubing at ~4070 Note: Cutting the tubing is to prepare the well for a future workover if well continues to sand up or unable to flow this winter. There are enough reserves that a workover will be completed next summer if the following perf adds do not recover this gas. 4. Perforate the following sands within the below interval bottom up with N2 pressure on well: Zone Top MD Btm MD Top TVD BtmTVD Ft E5 ±2,805' ±2,817' ±2,804' ±2,816' ±12' F5 ±2,890' ±2,894' ±2,889' ±2,893' ±4' 56 ±2,906' ±2,912' ±2,904' ±2,910' ±6' G2 ±3,172' ±3,184' ±3,170' ±3,182' ±12' G5 ±3,447' ±3,458' ±3,444' ±3,455' ±11' G6 ±3,479' ±3,491' ±3,476' ±3,488' ±12' Top of Beluga Sands (geologic formation) 2571 MD 2570 TVD Assume 13.9 ppg EMW LOT based on offset C-02 LOT @ 2837' TVD. This gives Shallowest allowable perf at approximately 2400' TVD. See attached email from Chad Helgeson 11/19/25. -bjm Well Prognosis 5. Return to production Attachments: 1. Actual Schematic 2. Proposed Schematic ___________________________________________________________________________________ Updated by CAH 11-10-25 SCHEMATIC Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01-00 PBTD =6,043 MD/ 5,980 TVD TD = 6,469 MD/ 6,384 TVD Max Deviation 19.2° @ 6,000 Max Dogleg 2.8°/100 @ 2,700 Ground Elev: 100.0 Above MSL KB-THF: 16.50 / KB-GL: 15.0 CASING DETAIL Size Type Wt Grade Conn.ID Top Btm Cmt 20Conductor 94 H-40 --Surf 75Driven 13-3/8Surf. Csg 54.5 K-55 BTC 12.615Surf 368425 sx 9-5/8"Int. Csg 47 N-80/S-95 LTC 8.681Surf 2,409950 sx 7Prod. Csg 26/29 L-80 BTC 6.184Surf 2,650750 sx 5"Prod Liner 15 L-80 BTC 4.408"2,4546,461500 sx TUBING DETAIL 2-7/8"Prod Tubing 6.4 L-80 IBT (SCC)2.441Surf 5,490- 1-1/4Heater String 2.3 L-80 CS Hydril 1.380Surf 2,339- 1 13-3/8 9-5/8 3 7 5 JEWELRY DETAIL No.Depth ID OD Item 1 16.5--Dual Tubing Hanger, 2-7/8x2-3/8 DCB 9 5M 2 2,3402.3134.250CMU Sliding Sleeve 3 2,3771.8752.250TTS/Owens Tbg Patch (18 Long) 4 2,3862.8755.983Baker FH Packer (Size 47B2) 5 2,4282.3132.875X-Profile 6 2,4461.8752.250TTS/Owens Tbg Patch (20 Long) Tbg punch 2,450-2,451 7 PERFORATION DETAIL Zone Top MD Btm MD Top TVD BtmTVD SPF Ft Phase Date Comments F5 2,944 2,954 2,942 2,9524 10 0 9/23/2019 1.68 Owen Shogun Strip Gun F5 2,944 2,954 2,942 2,9524 10 4/27/2024 Open H6 3,573 3,580 3,570 3,5774 7 4/27/2024 Open H6 3,599 3,609 3,596 3,6064 10 4/27/2024 Open H7 3,673 3,687 3,557 3,5714 14 4/27/2024 Open H10 3,782 3,792 3,665 3,7884 10 4/27/2024 Open I 4,047 4,061 4,043 4,0564 14 4/26/2024 Open 46-8 4,679 4,689 4,668 4,6788 10 60 5/14/2008 1.68 Enerjet 47-5 4,747 4,759 4,735 4,7478 12 60 5/14/2008 1.68 Enerjet 58-0 5,800 5,818 5,750 5,76712 18 60 7/15/2002 2.0 PJ 8/11/2006 2.0 PJ Omega 58-0 5,872 5,880 5,818 5,82612 8 60 7/15/2002 2.0 PJ 8/11/2006 2.0 PJ Omega 60-2 6,021 6,026 5,959 5,96412 5 60 8/11/2006 2.0 PJ Omega 60-2 6,022 6,042 5,960 5,9796 20 60 12/9/2001 2.0 HC 60-8 6,080 6,118 6,015 6,0516 38 60 10/22/2001 2.0 PJ Liner Hanger ZXP Packer @ 2,454 6x7 hole Window @ 2,650 Shoe @ 6,461 EST TOC @ 2,400 58-0 E D 20 60-8 60-2 58-0 46-8 47-5 GRAVEL PACK DETAIL No.Depth ID OD Item A 5,440 1.382.25TTS 2-7/8 Anchor Latch / 2-3/8 PBR Assy. 1.752.28TTS Gravel Pack Packer 1-1/2 NU Pin; 2-1/2 Fish Neck 1.752.20MOE w/ 1-1/2 NU 10RD BxB B 5,4571.611.9010 jts Blank Tbg w/ 1-1/2 NU 10RD Pin x Box w/ XOs C 5,790 5,8331.375 2.06 4 jts BJ CoilFlow DB Screen w/ 2 Bow Spring Centralizers Spaced 20 Apart w/ 1-1/4 NU 10RD 5,8501.3802.062 jts BJ Pro Weld Screen .008 Gauge 1-1/4 NU 10RD 5,868 5,8811.375 2.06 1 jt BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4 NU 10RD 5,883 6,0031.380 2.06 8 jts BJ Pro Weld Screen .008 Gauge 1-1/4 NU 10RD w/ 3 bow spring centralizers, spaced every 30 6,005 6,0181.375 2.06 1 jt BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4 NU 10RD D 6,021-2.05 Combination Bull Plug w/ 1-1/2 NU 10RD 6,021-2.28RBP Pulling Tool 6,022 6,026- 2.28 TTS Retrievable Bridge Plug E 6,054- -Posi-Set Plug (capped with 11 of cement) Notes: TTS GP Packer takes a TTS 2-7/8 Pulling Tool Pinned for 4,800# Release. SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg. Sand Out @ 1,750# above injection rate @ ½ bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels & covered 16 of Blank Tubing C A B 2 4 5 6 Temp Log TOC @ 2,750F5 H-IStrip gun Debris @ 4070 11/9/25 Sand tag @ 4110 3/5/24 Updated by CAH 11-10-25 PROPOSED Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01-00 PBTD =6,043 MD/ 5,980 TVD TD = 6,469 MD/ 6,384 TVD Max Deviation 19.2° @ 6,000 Max Dogleg 2.8°/100 @ 2,700 Ground Elev: 100.0 Above MSL KB-THF: 16.50 / KB-GL: 15.0 ___________________________________________________________________________________ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm Cmt 20Conductor 94 H-40 --Surf 75Driven 13-3/8Surf. Csg 54.5 K-55 BTC 12.615Surf 368425 sx 9-5/8"Int. Csg 47 N-80/S-95 LTC 8.681Surf 2,409950 sx 7Prod. Csg 26/29 L-80 BTC 6.184Surf 2,650750 sx 5"Prod Liner 15 L-80 BTC 4.408"2,4546,461500 sx TUBING DETAIL 2-7/8"Prod Tubing 6.4 L-80 IBT (SCC)2.441Surf 5,490- 1-1/4Heater String 2.3 L-80 CS Hydril 1.380Surf 2,339- 1 13-3/8 9-5/8 3 7 5 JEWELRY DETAIL No.Depth ID OD Item 1 16.5--Dual Tubing Hanger, 2-7/8x2-3/8 DCB 9 5M 2 2,3402.3134.250CMU Sliding Sleeve 3 2,3771.8752.250TTS/Owens Tbg Patch (18 Long) 4 2,3862.8755.983Baker FH Packer (Size 47B2) 5 2,4282.3132.875X-Profile 6 2,4461.8752.250TTS/Owens Tbg Patch (20 Long) Tbg punch 2,450-2,451 7 2,4674.2505.250HMC/ZXP Liner Hanger and Tieback Sleeve & Seals 7 PERFORATION DETAIL Zone Top MD Btm MD Top TVD BtmTVD SPF Ft Phase Date Comments E5 ±2,805' ±2,817' ±2,804' ±2,816' 4 ±12' 22.5 Proposed TBD F5 ±2,890' ±2,894' ±2,889' ±2,893' 4 ±4' 22.5 Proposed TBD F5 ±2,906' ±2,912' ±2,904' ±2,910' 4 ±6' 22.5 Proposed TBD F5 2,944 2,954 2,942 2,9524 10' 0 9/23/2019 1.68 Owen Shogun Strip Gun F5 2,944 2,954 2,942 2,9524 10' 22.5 4/27/2024 Open G2 ±3,172' ±3,184' ±3,170' ±3,182' 4 ±12' 22.5 Proposed TBD G5 ±3,447' ±3,458' ±3,444' ±3,455' 4 ±11' 22.5 Proposed TBD G6 ±3,479' ±3,491' ±3,476' ±3,488' 4 ±12' 22.5 Proposed TBD H6 3,573 3,580 3,570 3,5774' 7' 22.5 4/27/2024 Open H6 3,599 3,609 3,596 3,6064' 10' 22.5 4/27/2024 Open (PERFORATION DETAIL continued on following page) Liner Hanger ZXP Packer @ 2,454 6x7 hole Window @ 2,650 Shoe @ 6,461 TOC @ 2,454 58-0 E D 20 60-8 60-2 58-0 46-8 47-5 GRAVEL PACK DETAIL No.Depth ID OD Item A 5,440 1.382.25TTS 2-7/8 Anchor Latch / 2-3/8 PBR Assy. 1.752.28TTS Gravel Pack Packer 1-1/2 NU Pin; 2-1/2 Fish Neck 1.752.20MOE w/ 1-1/2 NU 10RD BxB B 5,4571.611.9010 jts Blank Tbg w/ 1-1/2 NU 10RD Pin x Box w/ XOs C 5,790 5,8331.375 2.06 4 jts BJ CoilFlow DB Screen w/ 2 Bow Spring Centralizers Spaced 20 Apart w/ 1-1/4 NU 10RD 5,850 1.380 2.06 2 jts BJ Pro Weld Screen .008 Gauge 1-1/4 NU 10RD 5,868 5,8811.375 2.06 1 jt BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4 NU 10RD 5,883 6,0031.380 2.06 8 jts BJ Pro Weld Screen .008 Gauge 1-1/4 NU 10RD w/ 3 bow spring centralizers, spaced every 30 6,005 6,0181.375 2.06 1 jt BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4 NU 10RD D 6,021-2.05 Combination Bull Plug w/ 1-1/2 NU 10RD 6,021-2.28RBP Pulling Tool 6,022 6,026- 2.28 TTS Retrievable Bridge Plug E 6,054- -Posi-Set Plug (capped with 11 of cement) Notes: TTS GP Packer takes a TTS 2-7/8 Pulling Tool Pinned for 4,800# Release. SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg. Sand Out @ 1,750# above injection rate @ ½ bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels & covered 16 of Blank Tubing C A B 2 4 5 6 Temp Log TOC @ 2,750 F H-I G E Tubing cut at 4069 Strip gun Debris @ 4070 11/9/25 Sand tag @ 4110 3/5/24 Updated by CAH 11-10-25 PROPOSED Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01-00 ___________________________________________________________________________________ PERFORATION DETAIL continued from previous page Zone Top MD Btm MD Top TVD BtmTVD SPF Ft Phase Date Comments H7 3,673 3,687 3,557 3,571 4' 14' 22.5 4/27/2024 Open H10 3,782 3,792 3,665 3,788 4' 10' 22.5 4/27/2024 Open I 4,047 4,061 4,043 4,056 4' 14' 22.5 4/26/2024 Open 46-8 4,679 4,689 4,668 4,678 8' 10' 60' 5/14/2008 1.68 Enerjet 47-5 4,747 4,759 4,735 4,747 8' 12' 60' 5/14/2008 1.68 Enerjet 58-0 5,800 5,818 5,750 5,767 12' 18' 60' 7/15/2002 2.0 PJ 58-0 5,800 5,818 5,750 5,767 12' 18' 60' 8/11/2006 2.0 PJ Omega 58-0 5,872 5,880 5,818 5,826 12' 8' 60' 7/15/2002 2.0 PJ 58-0 5,872 5,880 5,818 5,826 12' 8' 60' 8/11/2006 2.0 PJ Omega 60-2 6,021 6,026 5,959 5,964 12' 5' 60' 8/11/2006 2.0 PJ Omega 60-2 6,022 6,042 5,960 5,979 6' 20' 60' 12/9/2001 2.0 HC 60-8 6,080 6,118 6,015 6,051 6' 38' 60' 10/22/2001 2.0 PJ 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: 5/10/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240510-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 242-04 50283201640000 212041 3/11/2024 AK E-LINE Perf LRU C-01RD 50283200610100 201168 4/26/2024 AK E-LINE Perf LRU C-02 50283201900000 223057 4/28/2024 AK E-LINE Perf MPU F-65 50029227526000 223121 5/3/2024 AK E-LINE HoistCut MPU L-07 50029220280000 190037 4/26/2024 AK E-LINE Perf NCIU A-17 50883201880000 223031 4/28/2024 AK E-LINE GPT/Perf NCIU B-02 50883200900100 197210 4/29/2024 AK E-LINE PPROF NCIU B-02 50883200900100 197210 5/4/2024 AK E-LINE PPROF PAXTON 6 50133207070000 222054 4/13/2024 AK E-LINE GPT/CIBP/Perf PAXTON 6 50133207070000 222054 4/16/2024 AK E-LINE GPT/CIBP/Perf SRU 14B-27 50133206040000 212089 4/23/2024 AK E-LINE Caliper SRU 32C-15 50133206130000 213070 4/24/2024 AK E-LINE Caliper TBU M-15 50733204220000 190109 4/18/2024 AK E-LINE GPT/Puncher TBU M-23 50733207190000 224018 5/1/2024 AK E-LINE CBL Please include current contact information if different from above. T38780 T38781 T38782 T38783 T38784 T38785 T38786 T38786 T38787 T38787 T38788 T38789 T38790 T38791 LRU C-01RD 50283200610100 201168 4/26/2024 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.13 15:31:19 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory 3. Address: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 6,469 feet 6,043 feet true vertical 6,384 feet 5,438 (fill) feet Effective Depth measured 6,043 feet 2,386 feet true vertical 5,980 feet 2,365 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 1-1/4" 2.3# / L-80 2,339' MD 2,338' TVD Tubing (size, grade, measured and true vertical depth)2-7/8" 6.4# / N-80 5,490' MD 5,455' TVD Packers and SSSV (type, measured and true vertical depth)Baker PH Pkr; N/A 2,386' MD 2,365' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Jake Flora, Operations Engineer 324-194 Sr Pet Eng: 7,250psi Sr Pet Geo:Sr Res Eng: WINJ WAG 129 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A jake.flora@hilcorp.com 907-777-8442 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 75' 4 Size 75' 368' 0 4554 0 1060 228 measured TVD 8,290psi 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-168 50-283-20061-01-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0058798 Lewis River / Undefined Gas Lewis River Unit (LRU) C-01RD Plugs Junk measured Length 75' Production Liner 2,650' 4,007' Casing Structural 2,649' 5" 2,650' 6,461'6,437' 368'Conductor Surface Intermediate 20" 13-3/8" 9-5/87" 366' 2,409' 4,320psi 2,730psi 4,720psi 4j980 2,409'2,408' Burst Collapse 1,130psi 3,880psi p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 4:00 pm, May 09, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.05.08 15:11:19 - 08'00' Noel Nocas (4361) DSR-5/13/24 RBDMS JSB 051524 Page 1/1 Well Name: LRU C-001RD Report Printed: 5/1/2024www.peloton.com Well Operations Summary Jobs Actual Start Date:4/26/2024 End Date:4/27/2024 Report Number 1 Report Start Date 4/26/2024 Report End Date 4/26/2024 Operation AK E-line attend morning ops meeting, obtain PTW and hold PJSM. Mobilize equipment to LRU pad. Spot and R/U. Rehead line, stranded line in top sheave picking up wire, rehead again, M/U GPT and lubricator, move to well and PT. Blew out tapped plug in lubricator. Replace plug and retest lubricator. 250 psi / 2500 psi. Pass. FTP 111 psi / 200-250 mcfd. Open swab and run flowing GPT survey. Locate fluid level at 2960' (F5 perfs 2944'-2954'). RIH and tag PBTD at 4104'. P/U and run baseline GR/CCL from PBTD to 2200'. Send log to RE/OE/Geo and confirmed on depth to perforate BEL_I & H sands. POOH. M/U 7' snake strip gun (4 spf / 0-22.5 deg. phased). M/U tool string with wt. bar, e-line jars, CCL and strip gun (6' CCL-T.S.). RIH with well flowing. Log through F5 perfs (as correlation confirmation) and log collars on depth at shot depth. Position gun and perforate BEL_I interval (4054'-4061'). POOH. Initial: 108 psi 5 min: 104 psi 10 min: 110 psi 15 min: 106 psi Some overpull through tubing patches. M/U second 7' snake strip gun to tool string and RIH. Log through F5 perfs for confirmation and GIH to perf depth and log 3 collars on depth. Position and shoot BEL_I interval 4047'-4054'. POOH. Inital: 100 psi 5 min: 104 psi 10 min: 104 psi 15 min: 104 psi Experienced 300-400# overpulls pulling through tubing patches. LD lube and tools, secured well and SDFN. Well SI automatically due to compressor failure. Report Number 2 Report Start Date 4/27/2024 Report End Date 4/27/2024 Operation AK E-line PTW, PJSM, travel to location. Warm up equipment and M/U tool string (wt.bar,e-line jars, CCL and 10' (4spf/0-22.5 deg.) snake strip gun. (3.5' CCL-T.S.) SITP - 622 psi. RIH, correlate CCL to F5 perfs (2944'-54'), GIH and log collars at perf depth. Positon and shoot BEL_H10 (3782'-3792'). POOH. Initial: 581 psi 5 min: 607 psi 10 min: 614 psi 15 min: 617 psi OOH. M/U 7' perf gun (6' CCL-T.S.). RIH, confirm on depth and shoot BEL_H7 (lwr) (3680'-3687'). POOH. Initial: 589 psi 5 min: 720 psi 10 min: 711 psi 15 min: 651 psi OOH. M/U second 7' perf gun (6' CCL -T.S.). RIH, confirm on depth and shoot BEL_H7 (upr) (3673'-3680'). POOH. Initial: 680 psi 5 min: 670 psi 10 min: 650 psi 15 min: 648 psi OOH. M/U 10' strip gun (3.5' CCl-T.S.). Correlate and shoot BEL_H6 (3599'-3609'). POOH. Initial: 675 psi 5 min: 671 psi 10 min: 663 psi 15 min: 655 psi OOH. M/U 7' strip gun (6' CCL-T.S.). RIH, correlate, confirm on depth and shoot BEL_H6 interval (3573'-3580'). POOH. Initial: 632 psi 5 min: 633 psi 10 min: 634 psi 15 min: 628 psi. OOH. Secure well. Job complete. LD tool string, lubricator and move over to LRU C-02. E-line crane returned to base for changeout. Production to continue flow line cleanout and compressor repair and flow test well. API: 50-283-20061-01-00 Field: Lewis River Sundry #: 324-194 State: Alaska Rig/Service:Permit to Drill (PTD) #:201-168 ___________________________________________________________________________________ Updated by DMA 05-08-24 SCHEMATIC Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01-00 PBTD =6,043 MD/ 5,980’ TVD TD = 6,469’ MD/ 6,384’ TVD Max Deviation 19.2° @ 6,000’ Max Dogleg 2.8°/100’ @ 2,700’ Ground Elev: 100.0’ Above MSL KB-THF: 16.50’ / KB-GL: 15.0’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm Cmt 20”Conductor 94 H-40 --Surf 75’Driven 13-3/8”Surf. Csg 54.5 K-55 BTC 12.615”Surf 368’425 sx 9-5/8"Int. Csg 47 N-80/S-95 LTC 8.681”Surf 2,409’950 sx 7”Prod. Csg 26/29 L-80 BTC 6.184”Surf 2,650’750 sx 5"Prod Liner 15 L-80 BTC 4.408"2,454’6,461’500 sx TUBING DETAIL 2-7/8"Prod Tubing 6.4 L-80 IBT (SCC)2.441”Surf 5,490’- 1-1/4”Heater String 2.3 L-80 CS Hydril 1.380”Surf 2,339’- 1 13-3/8” 9-5/8” 3 7 5” JEWELRY DETAIL No.Depth ID OD Item 1 16.5’--Dual Tubing Hanger, 2-7/8”x2-3/8” DCB 9” 5M 2 2,340’2.313”4.250”CMU Sliding Sleeve 3 2,377’1.875”2.250”TTS/Owens Tbg Patch (18’ Long) 4 2,386’2.875”5.983”Baker FH Packer (Size 47B2) 5 2,428’2.313”2.875”X-Profile 6 2,446’1.875”2.250”TTS/Owens Tbg Patch (20’ Long) Tbg punch 2,450’-2,451’ 7” PERFORATION DETAIL Zone Top MD Btm MD Top TVD BtmTVD SPF Ft Phase Date Comments F5 2,944’2,954’2,942’2,952’4 10 0 9/23/2019 1.68” Owen Shogun Strip Gun F5 2,944’2,954’2,942’2,952’4 10 4/27/2024 Open H6 3,573’3,580’3,570’3,577’4 7 4/27/2024 Open H6 3,599’3,609’3,596’3,606’4 10 4/27/2024 Open H7 3,673’3,687’3,557’3,571’4 14 4/27/2024 Open H10 3,782’3,792’3,665’3,788’4 10 4/27/2024 Open I 4,047’4,061’4,043’4,056’4 14 4/26/2024 Open 46-8 4,679’4,689’4,668’4,678’8 10 60 5/14/2008 1.68” Enerjet 47-5 4,747’4,759’4,735’4,747’8 12 60 5/14/2008 1.68” Enerjet 58-0 5,800’5,818’5,750’5,767’12 18 60 7/15/2002 2.0” PJ 8/11/2006 2.0” PJ Omega 58-0 5,872’5,880’5,818’5,826’12 8607/15/2002 2.0” PJ 8/11/2006 2.0” PJ Omega 60-2 6,021’6,026’5,959’5,964’12 5 60 8/11/2006 2.0” PJ Omega 60-2 6,022’6,042’5,960’5,979’6 20 60 12/9/2001 2.0” HC 60-8 6,080’6,118’6,015’6,051’6 38 60 10/22/2001 2.0” PJ Liner Hanger ZXP Packer @ 2,454’ 6”x7”hole Window @ 2,650’ Shoe @ 6,461’ EST TOC @ 2,400’ 58-0 E D 20” 60-8 60-2 58-0 46-8 47-5 GRAVEL PACK DETAIL No.Depth ID OD Item A 5,440’ 1.38”2.25”TTS 2-7/8” Anchor Latch / 2-3/8” PBR Assy. 1.75”2.28”TTS Gravel Pack Packer 1-1/2’ NU Pin; 2-1/2” Fish Neck 1.75”2.20”MOE w/ 1-1/2” NU 10RD BxB B 5,457’1.61”1.90”10 jts – Blank Tbg w/ 1-1/2” NU 10RD Pin x Box w/ XOs C 5,790’ 5,833’1.375” 2.06” 4 jts – BJ CoilFlow DB Screen w/ 2 Bow Spring Centralizers Spaced 20’ Apart w/ 1-1/4” NU 10RD 5,850’1.380”2.06”2 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD 5,868’ 5,881’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD 5,883’ 6,003’1.380” 2.06” 8 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD w/ 3 bow spring centralizers, spaced every 30’ 6,005’ 6,018’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD D 6,021’-2.05”Combination Bull Plug w/ 1-1/2” NU 10RD 6,021’-2.28”RBP Pulling Tool 6,022’ 6,026’-2.28”TTS Retrievable Bridge Plug E 6,054’--Posi-Set Plug (capped with 11’ of cement) Notes: TTS GP Packer takes a TTS 2-7/8” Pulling Tool Pinned for 4,800# Release. SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg. Sand Out @ 1,750# above injection rate @ ½ bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels & covered 16’ of Blank Tubing C A B 2 4 5 6 Temp Log TOC @ 2,750’ F5 H-I 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: N2 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6,469'5,438' (fill) Casing Collapse Structural Conductor 1,130psi Surface 3,880psi Intermediate Production 4,320psi Liner 7,250psi 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 jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: 1-1/4" PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY 8,290psi Tubing Grade: 2.3# / L-80 Tubing MD (ft): 2,339'Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0058798 201-168 50-283-20061-01-00 Hilcorp Alaska, LLC Proposed Pools: 75'75' 6.4# / N-80 TVD Burst 5,490' 4,980psi 2,408' Size 368' 2,409' MD 5" See Attached Schematic 2,730psi 4,720psi 368'368' 2,409' April 15, 2024 6,461'4,007' 2-7/8" 6,437' 75'20" 2,650' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Lewis River Unit (LRU) C-01RDStatewide Spaing Same 2,649'7" ~2105psi 2,650' 6,043' Length Baker FH Pkr; N/A 2,386' MD/2,365'TVD; N/A, N/A 6,384'6,043'5,980' Lewis River Undefined Gas 13-3/8" 9-5/8" See Attached Schematic m n P s 66 t 2 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 8:46 am, Apr 02, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.04.01 18:01:09 -08'00' 324-194 SFD 4/3/2024BJM 4/11/24 Perforate 10-404 DSR-4/12/24JLC 4/12/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.12 14:18:32 -08'00' RBDMS JSB 042624 Well Prognosis Well Name: LRU C-1RD API Number: 50-283-20061-01-00 Current Status: Gas Producer Permit to Drill Number: 201-168 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) Maximum Expected BHP: 2706 psi 0.45 psi/ft gradient (6015’ TVD) Max. Potential Surface Pressure: 2105 psi BHP minus 0.1 psi/ft gradient Well Status: Online Gas Producer Last well test: 274 mcfd @ 101 psi, 0 bw Brief Well Summary Lewis River C-01RD was drilled and completed in 2001 as a twin to replace C-01 which was offline as a result of sanding up. Perforations were shot in the 60-8 sands, when the well was BOL, it infilled with sand up to 6066’. The perforations were isolated and then added in the 60-2, the well was swabbed online at a rate of 3.0 MMCFD. In July 2002, perforations were added to the 58-0 sands, rates IP’d greater than 10.0 MMCFD, but quickly dropped below 3.0 MMCFD. In January 2006, the well sanded up, necessitating a coil cleanout to 6009’. Following the coil cleanout perfs were reshot in August 2006 in the 58-0 & 60-2 sands and a gravel pack was placed over them. The well remained shut-in until May 2008 when the 46-8 & 47-5 sands were perforated. The well enjoyed a good run of on-time, until September 2019 when the Beluga F5 sands were added. F5 sands propped rate up to 1.0 MMCFD and has been able to maintain rate while continuing to open the choke and drop WHP. Initially, WHP was 1150 psi and current WHP is at 200. The well is equipped with 2-7/8” tubing and requires a minimum of 810 MCFD to maintain unloading rates at current pressure. The purpose of this work/sundry is to increase productivity by perforating additional Beluga sands. All proposed sands are within the current gross perforation interval. History: 3-05-2024 1.85” GR to 4060’, 1.25” DDB to 4105’, ½ cup sand Procedure: 1. Review approved COAs 2. MIRU Eline, PT lubricator to 2500 psi. 3. Perforate sands within the below interval bottom up: Top Beluga Pool 2571’ MD 2570’ TVD Proposed Interval 3573’ – 4061’ MD 3570’ – 4056’ TVD (Beluga H-I sands) a. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. b. If necessary use nitrogen to pressure up well during perforating 4. Return to production Well Prognosis Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Nitrogen SOP ___________________________________________________________________________________ Updated by DMA 0 4-01-24 SCHEMATIC Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01-00 PBTD =6,043 MD/ 5,980’ TVD TD = 6,469’ MD/ 6,384’ TVD Max Deviation 19.2° @ 6,000’ Max Dogleg 2.8°/100’ @ 2,700’ Ground Elev: 100.0’ Above MSL KB-THF: 16.50’ / KB-GL: 15.0’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm Cmt 20”Conductor 94 H-40 --Surf 75’Driven 13-3/8”Surf. Csg 54.5 K-55 BTC 12.615”Surf 368’425 sx 9-5/8"Int. Csg 47 N-80/S-95 LTC 8.681”Surf 2,409’950 sx 7”Prod. Csg 26/29 L-80 BTC 6.184”Surf 2,650’750 sx 5"Prod Liner 15 L-80 BTC 4.408"2,454’6,461’500 sx TUBING DETAIL 2-7/8"Prod Tubing 6.4 L-80 IBT (SCC)2.441”Surf 5,490’- 1-1/4”Heater String 2.3 L-80 CS Hydril 1.380”Surf 2,339’- 1 13-3/8” 9-5/8” 3 7 5” JEWELRY DETAIL No.Depth ID OD Item 1 16.5’--Dual Tubing Hanger, 2-7/8”x2-3/8” DCB 9” 5M 2 2,340’2.313”4.250”CMU Sliding Sleeve 3 2,377’1.875”2.250”TTS/Owens Tbg Patch (18’ Long) 4 2,386’2.875”5.983”Baker FH Packer (Size 47B2) 5 2,428’2.313”2.875”X-Profile 6 2,446’1.875”2.250”TTS/Owens Tbg Patch (20’ Long) Tbg punch 2,450’-2,451’ 7 2,467’4.250”5.250”HMC/ZXP Liner Hanger and Tieback Sleeve & Seals 7” PERFORATION DETAIL Zone Top MD Btm MD Top TVD BtmTVD SPF Ft Phase Date Comments F5 2,944’2,954’2,942’2,952’4 10 0 9/23/2019 1.68” Owen Shogun Strip Gun 46-8 4,679’4,689’4,668’4,678’8 10 60 5/14/2008 1.68” Enerjet 47-5 4,747’4,759’4,735’4,747’8 12 60 5/14/2008 1.68” Enerjet 58-0 5,800’5,818’5,750’5,767’12 18 60 7/15/2002 2.0” PJ 8/11/2006 2.0” PJ Omega 58-0 5,872’5,880’5,818’5,826’12 8 60 7/15/2002 2.0” PJ 8/11/2006 2.0” PJ Omega 60-2 6,021’6,026’5,959’5,964’12 5 60 8/11/2006 2.0” PJ Omega 60-2 6,022’6,042’5,960’5,979’6 20 60 12/9/2001 2.0” HC 60-8 6,080’6,118’6,015’6,051’6 38 60 10/22/2001 2.0” PJ Liner Hanger ZXP Packer @ 2,454’ 6”x7”hole Window @ 2,650’ Shoe @ 6,461’ EST TOC @ 2,400’ 58-0 E D 20” 60-8 60-2 58-0 46-8 47-5 GRAVEL PACK DETAIL No.Depth ID OD Item A 5,440’ 1.38”2.25”TTS 2-7/8” Anchor Latch / 2-3/8” PBR Assy. 1.75”2.28”TTS Gravel Pack Packer 1-1/2’ NU Pin; 2-1/2” Fish Neck 1.75”2.20”MOE w/ 1-1/2” NU 10RD BxB B 5,457’1.61”1.90”10 jts – Blank Tbg w/ 1-1/2” NU 10RD Pin x Box w/ XOs C 5,790’ 5,833’1.375” 2.06” 4 jts – BJ CoilFlow DB Screen w/ 2 Bow Spring Centralizers Spaced 20’ Apart w/ 1-1/4” NU 10RD 5,850’1.380”2.06”2 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD 5,868’ 5,881’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD 5,883’ 6,003’1.380” 2.06” 8 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD w/ 3 bow spring centralizers, spaced every 30’ 6,005’ 6,018’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD D 6,021’-2.05”Combination Bull Plug w/ 1-1/2” NU 10RD 6,021’-2.28”RBP Pulling Tool 6,022’ 6,026’-2.28”TTS Retrievable Bridge Plug E 6,054’--Posi-Set Plug (capped with 11’ of cement) Notes: TTS GP Packer takes a TTS 2-7/8” Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand Out @ 1,750# above injection rate @ ½ bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels & covered 16’ of Blank Tubing C A B 2 4 5 6 Temp Log TOC @ 2,750’ F5 ___________________________________________________________________________________ Updated by DMA 0 4-01-24 PROPOSED Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01-00 PBTD =6,043 MD/ 5,980’ TVD TD = 6,469’ MD/ 6,384’ TVD Max Deviation 19.2° @ 6,000’ Max Dogleg 2.8°/100’ @ 2,700’ Ground Elev: 100.0’ Above MSL KB-THF: 16.50’ / KB-GL: 15.0’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm Cmt 20”Conductor 94 H-40 --Surf 75’Driven 13-3/8”Surf. Csg 54.5 K-55 BTC 12.615”Surf 368’425 sx 9-5/8"Int. Csg 47 N-80/S-95 LTC 8.681”Surf 2,409’950 sx 7”Prod. Csg 26/29 L-80 BTC 6.184”Surf 2,650’750 sx 5"Prod Liner 15 L-80 BTC 4.408"2,454’6,461’500 sx TUBING DETAIL 2-7/8"Prod Tubing 6.4 L-80 IBT (SCC)2.441”Surf 5,490’- 1-1/4”Heater String 2.3 L-80 CS Hydril 1.380”Surf 2,339’- 1 13-3/8” 9-5/8” 3 7 5” JEWELRY DETAIL No.Depth ID OD Item 1 16.5’--Dual Tubing Hanger, 2-7/8”x2-3/8” DCB 9” 5M 2 2,340’2.313”4.250”CMU Sliding Sleeve 3 2,377’1.875”2.250”TTS/Owens Tbg Patch (18’ Long) 4 2,386’2.875”5.983”Baker FH Packer (Size 47B2) 5 2,428’2.313”2.875”X-Profile 6 2,446’1.875”2.250”TTS/Owens Tbg Patch (20’ Long) Tbg punch 2,450’-2,451’ 7 2,467’4.250”5.250”HMC/ZXP Liner Hanger and Tieback Sleeve & Seals 7” PERFORATION DETAIL Zone Top MD Btm MD Top TVD BtmTVD SPF Ft Phase Date Comments F5 2,944’2,954’2,942’2,952’4 10 0 9/23/2019 1.68” Owen Shogun Strip Gun H-I ±3,573’±4,061’±3,570’±4,056’488 Proposed TBD 46-8 4,679’4,689’4,668’4,678’8 10 60 5/14/2008 1.68” Enerjet 47-5 4,747’4,759’4,735’4,747’8 12 60 5/14/2008 1.68” Enerjet 58-0 5,800’5,818’5,750’5,767’12 18 60 7/15/2002 2.0” PJ 8/11/2006 2.0” PJ Omega 58-0 5,872’5,880’5,818’5,826’12 8607/15/2002 2.0” PJ 8/11/2006 2.0” PJ Omega 60-2 6,021’6,026’5,959’5,964’12 5 60 8/11/2006 2.0” PJ Omega 60-2 6,022’6,042’5,960’5,979’6 20 60 12/9/2001 2.0” HC 60-8 6,080’6,118’6,015’6,051’6 38 60 10/22/2001 2.0” PJ Liner Hanger ZXP Packer @ 2,454’ 6”x7”hole Window @ 2,650’ Shoe @ 6,461’ EST TOC @ 2,400’ 58-0 E D 20” 60-8 60-2 58-0 46-8 47-5 GRAVEL PACK DETAIL No.Depth ID OD Item A 5,440’ 1.38”2.25”TTS 2-7/8” Anchor Latch / 2-3/8” PBR Assy. 1.75”2.28”TTS Gravel Pack Packer 1-1/2’ NU Pin; 2-1/2” Fish Neck 1.75”2.20”MOE w/ 1-1/2” NU 10RD BxB B 5,457’1.61”1.90”10 jts – Blank Tbg w/ 1-1/2” NU 10RD Pin x Box w/ XOs C 5,790’ 5,833’1.375” 2.06” 4 jts – BJ CoilFlow DB Screen w/ 2 Bow Spring Centralizers Spaced 20’ Apart w/ 1-1/4” NU 10RD 5,850’1.380”2.06”2 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD 5,868’ 5,881’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD 5,883’ 6,003’1.380” 2.06” 8 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD w/ 3 bow spring centralizers, spaced every 30’ 6,005’ 6,018’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD D 6,021’-2.05”Combination Bull Plug w/ 1-1/2” NU 10RD 6,021’-2.28”RBP Pulling Tool 6,022’ 6,026’-2.28”TTS Retrievable Bridge Plug E 6,054’--Posi-Set Plug (capped with 11’ of cement) Notes: TTS GP Packer takes a TTS 2-7/8” Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand Out @ 1,750# above injection rate @ ½ bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels & covered 16’ of Blank Tubing C A B 2 4 5 6 Temp Log TOC @ 2,750’ F5 Beluga H-I sands STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. 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: N2 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6,469'5,438' (fill) Casing Collapse Structural Conductor 1,130psi Surface 3,880psi Intermediate Production 4,320psi Liner 7,250psi 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 jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: 1-1/4" PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY 8,290psi Tubing Grade: 2.3# / L-80 Tubing MD (ft): 2,339'Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0058798 201-168 50-283-20061-01-00 Hilcorp Alaska, LLC Proposed Pools: 75'75' 6.4# / N-80 TVD Burst 5,490' 4,980psi 2,408' Size 368' 2,409' MD 5" See Attached Schematic 2,730psi 4,720psi 368'368' 2,409' April 15, 2024 6,461'4,007' 2-7/8" 6,437' 75'20" 2,650' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Lewis River Unit (LRU) C-01RDStatewide Spaing Same 2,649'7" ~2105psi 2,650' 6,043' Length Baker FH Pkr; N/A 2,386' MD/2,365'TVD; N/A, N/A 6,384'6,043'5,980' Lewis River Undefined Gas 13-3/8" 9-5/8" See Attached Schematic m n P s 66 t 2 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 8:46 am, Apr 02, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.04.01 18:01:09 -08'00' 324-194 SFD 4/3/2024BJM 4/11/24 Perforate 10-404 DSR-4/12/24JLC 4/12/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.12 14:18:32 -08'00' RBDMS JSB 041624 Well Prognosis Well Name: LRU C-1RD API Number: 50-283-20061-01-00 Current Status: Gas Producer Permit to Drill Number: 201-168 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) Maximum Expected BHP: 2706 psi 0.45 psi/ft gradient (6015’ TVD) Max. Potential Surface Pressure: 2105 psi BHP minus 0.1 psi/ft gradient Well Status: Online Gas Producer Last well test: 274 mcfd @ 101 psi, 0 bw Brief Well Summary Lewis River C-01RD was drilled and completed in 2001 as a twin to replace C-01 which was offline as a result of sanding up. Perforations were shot in the 60-8 sands, when the well was BOL, it infilled with sand up to 6066’. The perforations were isolated and then added in the 60-2, the well was swabbed online at a rate of 3.0 MMCFD. In July 2002, perforations were added to the 58-0 sands, rates IP’d greater than 10.0 MMCFD, but quickly dropped below 3.0 MMCFD. In January 2006, the well sanded up, necessitating a coil cleanout to 6009’. Following the coil cleanout perfs were reshot in August 2006 in the 58-0 & 60-2 sands and a gravel pack was placed over them. The well remained shut-in until May 2008 when the 46-8 & 47-5 sands were perforated. The well enjoyed a good run of on-time, until September 2019 when the Beluga F5 sands were added. F5 sands propped rate up to 1.0 MMCFD and has been able to maintain rate while continuing to open the choke and drop WHP. Initially, WHP was 1150 psi and current WHP is at 200. The well is equipped with 2-7/8” tubing and requires a minimum of 810 MCFD to maintain unloading rates at current pressure. The purpose of this work/sundry is to increase productivity by perforating additional Beluga sands. All proposed sands are within the current gross perforation interval. History: 3-05-2024 1.85” GR to 4060’, 1.25” DDB to 4105’, ½ cup sand Procedure: 1. Review approved COAs 2. MIRU Eline, PT lubricator to 2500 psi. 3. Perforate sands within the below interval bottom up: Top Beluga Pool 2571’ MD 2570’ TVD Proposed Interval 3573’ – 4061’ MD 3570’ – 4056’ TVD (Beluga H-I sands) a. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. b. If necessary use nitrogen to pressure up well during perforating 4. Return to production Well Prognosis Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Nitrogen SOP ___________________________________________________________________________________ Updated by DMA 0 4-01-24 SCHEMATIC Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01-00 PBTD =6,043 MD/ 5,980’ TVD TD = 6,469’ MD/ 6,384’ TVD Max Deviation 19.2° @ 6,000’ Max Dogleg 2.8°/100’ @ 2,700’ Ground Elev: 100.0’ Above MSL KB-THF: 16.50’ / KB-GL: 15.0’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm Cmt 20”Conductor 94 H-40 --Surf 75’Driven 13-3/8”Surf. Csg 54.5 K-55 BTC 12.615”Surf 368’425 sx 9-5/8"Int. Csg 47 N-80/S-95 LTC 8.681”Surf 2,409’950 sx 7”Prod. Csg 26/29 L-80 BTC 6.184”Surf 2,650’750 sx 5"Prod Liner 15 L-80 BTC 4.408"2,454’6,461’500 sx TUBING DETAIL 2-7/8"Prod Tubing 6.4 L-80 IBT (SCC)2.441”Surf 5,490’- 1-1/4”Heater String 2.3 L-80 CS Hydril 1.380”Surf 2,339’- 1 13-3/8” 9-5/8” 3 7 5” JEWELRY DETAIL No.Depth ID OD Item 1 16.5’--Dual Tubing Hanger, 2-7/8”x2-3/8” DCB 9” 5M 2 2,340’2.313”4.250”CMU Sliding Sleeve 3 2,377’1.875”2.250”TTS/Owens Tbg Patch (18’ Long) 4 2,386’2.875”5.983”Baker FH Packer (Size 47B2) 5 2,428’2.313”2.875”X-Profile 6 2,446’1.875”2.250”TTS/Owens Tbg Patch (20’ Long) Tbg punch 2,450’-2,451’ 7 2,467’4.250”5.250”HMC/ZXP Liner Hanger and Tieback Sleeve & Seals 7” PERFORATION DETAIL Zone Top MD Btm MD Top TVD BtmTVD SPF Ft Phase Date Comments F5 2,944’2,954’2,942’2,952’4 10 0 9/23/2019 1.68” Owen Shogun Strip Gun 46-8 4,679’4,689’4,668’4,678’8 10 60 5/14/2008 1.68” Enerjet 47-5 4,747’4,759’4,735’4,747’8 12 60 5/14/2008 1.68” Enerjet 58-0 5,800’5,818’5,750’5,767’12 18 60 7/15/2002 2.0” PJ 8/11/2006 2.0” PJ Omega 58-0 5,872’5,880’5,818’5,826’12 8 60 7/15/2002 2.0” PJ 8/11/2006 2.0” PJ Omega 60-2 6,021’6,026’5,959’5,964’12 5 60 8/11/2006 2.0” PJ Omega 60-2 6,022’6,042’5,960’5,979’6 20 60 12/9/2001 2.0” HC 60-8 6,080’6,118’6,015’6,051’6 38 60 10/22/2001 2.0” PJ Liner Hanger ZXP Packer @ 2,454’ 6”x7”hole Window @ 2,650’ Shoe @ 6,461’ EST TOC @ 2,400’ 58-0 E D 20” 60-8 60-2 58-0 46-8 47-5 GRAVEL PACK DETAIL No.Depth ID OD Item A 5,440’ 1.38”2.25”TTS 2-7/8” Anchor Latch / 2-3/8” PBR Assy. 1.75”2.28”TTS Gravel Pack Packer 1-1/2’ NU Pin; 2-1/2” Fish Neck 1.75”2.20”MOE w/ 1-1/2” NU 10RD BxB B 5,457’1.61”1.90”10 jts – Blank Tbg w/ 1-1/2” NU 10RD Pin x Box w/ XOs C 5,790’ 5,833’1.375” 2.06” 4 jts – BJ CoilFlow DB Screen w/ 2 Bow Spring Centralizers Spaced 20’ Apart w/ 1-1/4” NU 10RD 5,850’1.380”2.06”2 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD 5,868’ 5,881’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD 5,883’ 6,003’1.380” 2.06” 8 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD w/ 3 bow spring centralizers, spaced every 30’ 6,005’ 6,018’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD D 6,021’-2.05”Combination Bull Plug w/ 1-1/2” NU 10RD 6,021’-2.28”RBP Pulling Tool 6,022’ 6,026’-2.28”TTS Retrievable Bridge Plug E 6,054’--Posi-Set Plug (capped with 11’ of cement) Notes: TTS GP Packer takes a TTS 2-7/8” Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand Out @ 1,750# above injection rate @ ½ bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels & covered 16’ of Blank Tubing C A B 2 4 5 6 Temp Log TOC @ 2,750’ F5 ___________________________________________________________________________________ Updated by DMA 0 4-01-24 PROPOSED Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01-00 PBTD =6,043 MD/ 5,980’ TVD TD = 6,469’ MD/ 6,384’ TVD Max Deviation 19.2° @ 6,000’ Max Dogleg 2.8°/100’ @ 2,700’ Ground Elev: 100.0’ Above MSL KB-THF: 16.50’ / KB-GL: 15.0’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm Cmt 20”Conductor 94 H-40 --Surf 75’Driven 13-3/8”Surf. Csg 54.5 K-55 BTC 12.615”Surf 368’425 sx 9-5/8"Int. Csg 47 N-80/S-95 LTC 8.681”Surf 2,409’950 sx 7”Prod. Csg 26/29 L-80 BTC 6.184”Surf 2,650’750 sx 5"Prod Liner 15 L-80 BTC 4.408"2,454’6,461’500 sx TUBING DETAIL 2-7/8"Prod Tubing 6.4 L-80 IBT (SCC)2.441”Surf 5,490’- 1-1/4”Heater String 2.3 L-80 CS Hydril 1.380”Surf 2,339’- 1 13-3/8” 9-5/8” 3 7 5” JEWELRY DETAIL No.Depth ID OD Item 1 16.5’--Dual Tubing Hanger, 2-7/8”x2-3/8” DCB 9” 5M 2 2,340’2.313”4.250”CMU Sliding Sleeve 3 2,377’1.875”2.250”TTS/Owens Tbg Patch (18’ Long) 4 2,386’2.875”5.983”Baker FH Packer (Size 47B2) 5 2,428’2.313”2.875”X-Profile 6 2,446’1.875”2.250”TTS/Owens Tbg Patch (20’ Long) Tbg punch 2,450’-2,451’ 7 2,467’4.250”5.250”HMC/ZXP Liner Hanger and Tieback Sleeve & Seals 7” PERFORATION DETAIL Zone Top MD Btm MD Top TVD BtmTVD SPF Ft Phase Date Comments F5 2,944’2,954’2,942’2,952’4 10 0 9/23/2019 1.68” Owen Shogun Strip Gun H-I ±3,573’±4,061’±3,570’±4,056’488 Proposed TBD 46-8 4,679’4,689’4,668’4,678’8 10 60 5/14/2008 1.68” Enerjet 47-5 4,747’4,759’4,735’4,747’8 12 60 5/14/2008 1.68” Enerjet 58-0 5,800’5,818’5,750’5,767’12 18 60 7/15/2002 2.0” PJ 8/11/2006 2.0” PJ Omega 58-0 5,872’5,880’5,818’5,826’12 8607/15/2002 2.0” PJ 8/11/2006 2.0” PJ Omega 60-2 6,021’6,026’5,959’5,964’12 5 60 8/11/2006 2.0” PJ Omega 60-2 6,022’6,042’5,960’5,979’6 20 60 12/9/2001 2.0” HC 60-8 6,080’6,118’6,015’6,051’6 38 60 10/22/2001 2.0” PJ Liner Hanger ZXP Packer @ 2,454’ 6”x7”hole Window @ 2,650’ Shoe @ 6,461’ EST TOC @ 2,400’ 58-0 E D 20” 60-8 60-2 58-0 46-8 47-5 GRAVEL PACK DETAIL No.Depth ID OD Item A 5,440’ 1.38”2.25”TTS 2-7/8” Anchor Latch / 2-3/8” PBR Assy. 1.75”2.28”TTS Gravel Pack Packer 1-1/2’ NU Pin; 2-1/2” Fish Neck 1.75”2.20”MOE w/ 1-1/2” NU 10RD BxB B 5,457’1.61”1.90”10 jts – Blank Tbg w/ 1-1/2” NU 10RD Pin x Box w/ XOs C 5,790’ 5,833’1.375” 2.06” 4 jts – BJ CoilFlow DB Screen w/ 2 Bow Spring Centralizers Spaced 20’ Apart w/ 1-1/4” NU 10RD 5,850’1.380”2.06”2 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD 5,868’ 5,881’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD 5,883’ 6,003’1.380” 2.06” 8 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD w/ 3 bow spring centralizers, spaced every 30’ 6,005’ 6,018’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD D 6,021’-2.05”Combination Bull Plug w/ 1-1/2” NU 10RD 6,021’-2.28”RBP Pulling Tool 6,022’ 6,026’-2.28”TTS Retrievable Bridge Plug E 6,054’--Posi-Set Plug (capped with 11’ of cement) Notes: TTS GP Packer takes a TTS 2-7/8” Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand Out @ 1,750# above injection rate @ ½ bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels & covered 16’ of Blank Tubing C A B 2 4 5 6 Temp Log TOC @ 2,750’ F5 Beluga H-I sands STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,469'5,438' (fill) Casing Collapse Structural Conductor 1,130psi Surface 3,880psi Intermediate Production 4,320psi Liner 7,250psi 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 4,980psi2,649'2,650' 8,290psi6,461'6,437' 368' 2,409' Perforation Depth MD (ft): 2,650' 5"4,007' 7" 13-3/8" 9-5/8" 368' 2,409' 2,730psi 4,720psi 368' 2,408' Length Size Proposed Pools: 75'75' TVD Burst PRESENT WELL CONDITION SUMMARY 6,384'6,043'5,980'~1,567psi 6,043' 75'20" MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0058798 201-168 50-283-20061-01-00 Lewis River Undefined Gas Same Statewide Spacing Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Lewis River Unit (LRU) C-01RD Tubing Grade: 2.3# / L-80 Tubing MD (ft): 2,339'Perforation Depth TVD (ft):Tubing Size: 1-1/4" 6.4# / N-80 5,490' January 26, 2023 Baker FH Pkr; N/A 2,386' MD/2,365'TVD; N/A, N/A See Schematic See Schematic 2-7/8" 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: AOGCC USE ONLY Jake Flora, Operations Engineer jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 m n P s t _ 66 p Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 9:24 am, Jan 13, 2023 323-017 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.01.12 19:42:09 -09'00' Noel Nocas (4361) BJM 1/18/23 DSR-1/17/23SFD 1/13/2023 10-404 GCW 01/18/23 JLC 1/18/2023 1/19/23 Brett W. Huber. Sr.Digitally signed by Brett W. Huber. Sr. Date: 2023.01.19 08:27:45 -09'00' RBDMS JSB 011923 Well Prognosis Well Name: LRU C-1RD API Number: 50-283-20061-01-00 Current Status: Gas Producer Permit to Drill Number: 201-168 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) Maximum Expected BHP: 2014 psi 0.45 psi/ft gradient (4476’ TVD) Max. Potential Surface Pressure: 1567 psi BHP minus 0.1 psi/ft gradient Current Status: Online Producer making 300 mcfd at 200 psi FTP Brief Well Summary Lewis River C-01RD was drilled and completed in 2001 as a twin to replace C-01 which was offline as a result of sanding up. Perforations were shot in the 60-8 sands, when the well was BOL, it infilled with sand up to 6066’. The perforations were isolated and then added in the 60-2, the well was swabbed online at a rate of 3.0 MMCFD. In July 2002, perforations were added to the 58-0 sands, rates IP’d greater than 10.0 MMCFD, but quickly dropped below 3.0 MMCFD. In January 2006, the well sanded up, necessitating a coil cleanout to 6009’. Following the coil cleanout perfs were reshot in August 2006 in the 58-0 & 60-2 sands and a gravel pack was placed over them. The well remained shut-in until May 2008 when the 46-8 & 47-5 sands were perforated. The well enjoyed a good run of ontime, until September 2019 when the Beluga F5 sands were added. The F5 sands propped rate up to 1.0 MMCFD and has been able to maintain rate while continuing to open the choke and drop WHP. Initially, WHP was 1150 psi and current WHP is at 200. The well is equipped with 2-7/8” tubing and requires a minimum of 810 MCFD to maintain unloading rates at current pressure. The purpose of this work/sundry is to increase productivity by perforating additional sands. Wellbore Condition Last Tag Depth Date Operation Obstruction Tool OD 4,681’ 10/12/21 Drift N/A 1.75” Procedure 1. RU E-line, PT lubricator to 2500 psi 2. Perforate the below Beluga sands: 3. Formation Sand Top MD Bottom MD Total Top TVD Bottom TVD Beluga H3 3599 3610 11 3596 3607 Beluga I3 4280 4286 6 4274 4280 Beluga I4 4307 4331 24 4298 4322 Beluga I7 4387 4396 9 4381 4390 Beluga I8 4450 4485 35 4441 4476 a) All sands lie in the LEWIS RIVER, UNDEFINED GAS POOL b) If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. Well Prognosis Attachments: 1. Current Well Schematic 2. Proposed Well Schematic ___________________________________________________________________________________ Updated by CMT 10-4-2019 SCHEMATIC Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01 PBTD =6,043 MD/ 5,980’ TVD TD = 6,469’ MD/ 6,384’ TVD Max Deviation 19.2° @ 6,000’ Max Dogleg 2.8°/100’ @ 2,700’ Ground Elev: 100.0’ Above MSL KB-THF: 16.50’ / KB-GL: 15.0’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm Cmt 20”Conductor 94 H-40 --Surf 75’Driven 13-3/8”Surf. Csg 54.5 K-55 BTC 12.615”Surf 368’425 sx 9-5/8"Int. Csg 47 N-80/S-95 LTC 8.681”Surf 2,409’950 sx 7”Prod. Csg 26/29 L-80 BTC 6.184”Surf 2,650’750 sx 5"Prod Liner 15 L-80 BTC 4.408"2,454’6,461’500 sx TUBING DETAIL 2-7/8"Prod Tubing 6.4 L-80 IBT (SCC)2.441”Surf 5,490’- 1-1/4”Heater String 2.3 L-80 CS Hydril 1.380”Surf 2,339’- 1 13-3/8” 9-5/8” 3 7 5” JEWELRY DETAIL No.Depth ID OD Item 1 16.5’--Dual Tubing Hanger, 2-7/8”x2-3/8” DCB 9” 5M 2 2,340’2.313”4.250”CMU Sliding Sleeve 3 2,377’1.875”2.250”TTS/Owens Tbg Patch (18’ Long) 4 2,386’2.875”5.983”Baker FH Packer (Size 47B2) 5 2,428’2.313”2.875”X-Profile 6 2,446’ 1.875” 2.250” TTS/Owens Tbg Patch (20’ Long) Tbg punch 2,450’-2,451’ 7 2,467’4.250”5.250”HMC/ZXP Liner Hanger and Tieback Sleeve & Seals 7” PERFORATION DETAIL Date Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)SPF Ft Phase Comments 9/23/19 F5 2,944’ 2,954’ 2,942’ 2,952’ 4 10 0 1.68” Owen Shogun Strip Gun 5/14/08 46-8 4,679’4,689’4,668’4,678’8 10 60 1.68” Enerjet 5/14/08 47-5 4,747’4,759’4,735’4,747’8 12 60 1.68” Enerjet 7/15/02 8/11/06 58-0 5,800’ 5,818’ 5,750’ 5,767’12 18 60 2.0” PJ 2.0” PJ Omega 7/15/02 8/11/06 58-0 5,872’ 5,880’ 5,818’ 5,826’12 860 2.0” PJ 2.0” PJ Omega 8/11/06 60-2 6,021’6,026’5,959’5,964’12 5 60 2.0” PJ Omega 12/09/01 60-2 6,022’6,042’5,960’5,979’6 20 60 2.0” HC 10/22/01 60-8 6,080’6,118’6,015’6,051’6 38 60 2.0” PJ Liner Hanger ZXP Packer @ 2,454’ 6”x7”hole X Window @ 2,650’ Shoe @ 6,461’ EST TOC @ 2,400’ 58-0 E D 20” 60-8 60-2 58-0 46-8 47-5 GRAVEL PACK DETAIL No.Depth ID OD Item A 5,440’ 1.38”2.25”TTS 2-7/8” Anchor Latch / 2-3/8” PBR Assy. 1.75”2.28”TTS Gravel Pack Packer 1-1/2’ NU Pin; 2-1/2” Fish Neck 1.75”2.20”MOE w/ 1-1/2” NU 10RD BxB B 5,457’1.61”1.90”10 jts – Blank Tbg w/ 1-1/2” NU 10RD Pin x Box w/ XOs C 5,790’ 5,833’1.375” 2.06” 4 jts – BJ CoilFlow DB Screen w/ 2 Bow Spring Centralizers Spaced 20’ Apart w/ 1-1/4” NU 10RD 5,850’1.380”2.06”2 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD 5,868’ 5,881’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD 5,883’ 6,003’1.380” 2.06” 8 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD w/ 3 bow spring centralizers, spaced every 30’ 6,005’ 6,018’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD D 6,021’-2.05”Combination Bull Plug w/ 1-1/2” NU 10RD 6,021’-2.28”RBP Pulling Tool 6,022’ 6,026’-2.28”TTS Retrievable Bridge Plug E 6,054’--Posi-Set Plug (capped with 11’ of cement) Notes: TTS GP Packer takes a TTS 2-7/8” Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand Out @ 1,750# above injection rate @ ½ bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels & covered 16’ of Blank Tubing C A B 2 4 5 6 Temp Log TOC @ 2,750’F5 ___________________________________________________________________________________ Updated by JMF 01-12-23 PROPOSED Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01-00 PBTD =6,043 MD/ 5,980’ TVD TD = 6,469’ MD/ 6,384’ TVD Max Deviation 19.2° @ 6,000’ Max Dogleg 2.8°/100’ @ 2,700’ Ground Elev: 100.0’ Above MSL KB-THF: 16.50’ / KB-GL: 15.0’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm Cmt 20”Conductor 94 H-40 --Surf 75’Driven 13-3/8”Surf. Csg 54.5 K-55 BTC 12.615”Surf 368’425 sx 9-5/8"Int. Csg 47 N-80/S-95 LTC 8.681”Surf 2,409’950 sx 7”Prod. Csg 26/29 L-80 BTC 6.184”Surf 2,650’750 sx 5"Prod Liner 15 L-80 BTC 4.408"2,454’6,461’500 sx TUBING DETAIL 2-7/8"Prod Tubing 6.4 L-80 IBT (SCC)2.441”Surf 5,490’- 1-1/4”Heater String 2.3 L-80 CS Hydril 1.380”Surf 2,339’- 1 13-3/8” 9-5/8” 3 7 5” JEWELRY DETAIL No.Depth ID OD Item 1 16.5’--Dual Tubing Hanger, 2-7/8”x2-3/8” DCB 9” 5M 2 2,340’2.313”4.250”CMU Sliding Sleeve 3 2,377’1.875”2.250”TTS/Owens Tbg Patch (18’ Long) 4 2,386’2.875”5.983”Baker FH Packer (Size 47B2) 5 2,428’2.313”2.875”X-Profile 6 2,446’ 1.875” 2.250” TTS/Owens Tbg Patch (20’ Long) Tbg punch 2,450’-2,451’ 7 2,467’4.250”5.250”HMC/ZXP Liner Hanger and Tieback Sleeve & Seals 7” PERFORATION DETAIL Date Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)SPF Ft Phase Comments 9/23/19 F5 2,944’ 2,954’ 2,942’ 2,952’ 4 10 0 1.68” Owen Shogun Strip Gun TBD H-I ±3,599’±4,485’±3,596’±4,476’PLANNED 5/14/08 46-8 4,679’4,689’4,668’4,678’8 10 60 1.68” Enerjet 5/14/08 47-5 4,747’4,759’4,735’4,747’8 12 60 1.68” Enerjet 7/15/02 8/11/06 58-0 5,800’ 5,818’ 5,750’ 5,767’12 18 60 2.0” PJ 2.0” PJ Omega 7/15/02 8/11/06 58-0 5,872’ 5,880’ 5,818’ 5,826’12 860 2.0” PJ 2.0” PJ Omega 8/11/06 60-2 6,021’6,026’5,959’5,964’12 5 60 2.0” PJ Omega 12/09/01 60-2 6,022’6,042’5,960’5,979’6 20 60 2.0” HC 10/22/01 60 8 6 080’6 118’6 015’6 051’6 38 60 20”PJ Liner Hanger ZXP Packer @ 2,454’ 6”x7”hole X Window @ 2,650’ Shoe @ 6,461’ EST TOC @ 2,400’ 58-0 E D 20” 60-8 60-2 58-0 46-8 47-5 GRAVEL PACK DETAIL No.Depth ID OD Item A 5,440’ 1.38”2.25”TTS 2-7/8” Anchor Latch / 2-3/8” PBR Assy. 1.75”2.28”TTS Gravel Pack Packer 1-1/2’ NU Pin; 2-1/2” Fish Neck 1.75”2.20”MOE w/ 1-1/2” NU 10RD BxB B 5,457’1.61”1.90”10 jts – Blank Tbg w/ 1-1/2” NU 10RD Pin x Box w/ XOs C 5,790’ 5,833’1.375” 2.06” 4 jts – BJ CoilFlow DB Screen w/ 2 Bow Spring Centralizers Spaced 20’ Apart w/ 1-1/4” NU 10RD 5,850’1.380”2.06”2 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD 5,868’ 5,881’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD 5,883’ 6,003’1.380” 2.06” 8 jts – BJ Pro Weld Screen .008” Gauge 1-1/4” NU 10RD w/ 3 bow spring centralizers, spaced every 30’ 6,005’ 6,018’1.375” 2.06” 1 jt – BJ CoilFlow DB Screen w/ 1 Bow Spring Centralizer w/ 1-1/4” NU 10RD D 6,021’-2.05”Combination Bull Plug w/ 1-1/2” NU 10RD 6,021’-2.28”RBP Pulling Tool 6,022’ 6,026’-2.28”TTS Retrievable Bridge Plug E 6,054’--Posi-Set Plug (capped with 11’ of cement) Notes: TTS GP Packer takes a TTS 2-7/8” Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand Out @ 1,750# above injection rate @ ½ bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels & covered 16’ of Blank Tubing C A B 2 4 5 6 Temp Log TOC @ 2,750’ F5 Beluga H-I sands STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate U Pull Tubing Ll Operations shutdown Li Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 201-168 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-283-20061-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0058798 Lewis River Unit (LRU) C-01 RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/P001(s): N/A Lewis River/ Undefined Gas 11. Present Well Condition Summary: Total Depth measured 6,469 feet Plugs measured 6,043 feet true vertical 6,384 feet Junk measured 5,438 (fill) feet Effective Depth measured 6,043 feet Packer measured 2,386 feet true vertical 5,980 feet true vertical 2,365 feet Casing Length Size MD TVD Burst Collapse Structural 75' 20" 75' 75' Conductor 368' 13-3/8" 368' 368' 2,730psi 1,130psi Surface 2,409' 9-5/8" 2,409' 2,408' 4,720psi 3,880psi Intermediate Production 2,650' 7" 2,650' 2,649' 4,980psi 4,320psi Liner 4,007' 5" 6,461' 6,437' 8,290psi 7,250psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 1-1/4" 2.3# / L-80 2,339' MD 2,338' TVD Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.4# / N-80 5,490' MD 5,455' TVD Packers and SSSV (type, measured and true vertical depth) Baker PH Pkr; N/A 2,386' MD 2,365' 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 CasingPressure Tubing Pressure Prior to well operation: 0 237 0 0 590 Subsequent to operation: 0 2047 10 0 1220 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-418 Authorized Name: Be York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerPhilcoro.com % Authorized Signature: / - L�-- Date: Ll(] 2.0 Contact Phone: 777-8420 Form 10-404 Revised 4/2017// Submit Original Only /� e I MSL�"'OCT 9 9 2019 j1- NJ Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date LRU C-01RD E -Line 50-283-20061-00-00 201-168 9/23/19 9/23/19 Daily Operations: 09/23/2019 - Monday Pollard E -line arrive in Beluga River. PTW, JSA. Travel to west side. Re head a -line rope socket. Spot and RU skid unit. Rig up crane. Make up 1-11/16" GPT assembly. Well was flowing 209K at 570 psi. Shut in well at 11:00 hrs to allow fluid level to stabilize. RIH with GPT. tagged top of perfs at 4,672' CCL. Bottom of tool at 4,678'. Pull correlation pass. GPT did not indicate any fluid level from surface to tag depth. Log OOH . Clean pick up . Make up 10' strip gun. Stab on well. RIH. Send GPT log to town. Log is on depth. Tagging with strip guns at tubing patch at 2,377'. Attempt to work guns through patch. No luck. POOH to surface. End of guns are bent. Straighten tip of strip guns. RIH. 5.5' CCL to top shot. Pull correlation pass. On depth. bark CCL at 2,938.5'. Top shot 2,944' SITP 850 psi. Attempt to fire guns. No indication of fire. POOH to surface to inspect. Guns are gassed up. Tools hand a leaky connection keeping us from firing. make up new Gamma Ray. Ru perf guns. Stab on well. RIH CCL to top shot 6'. Log correlation pass. Park CCL at 2,938' puts top shot at 2,944'. SITP 850 psi. Shoot guns from 2,944'-2,954'. Guns fired. Lost weight. Pressure climbed from 850 psi to 1,310 psi. POOH to surface. Close master and swab. Rig down Pollard (AK-Eline). Turn well over to production. ff He npp Alaska. 11,C Ground Elev: 100.0' Above MSL KB -THF: 16.50'/ KB -GL: 15.0' 1 20^ 13-3/8" 2 3 46-8 47-5 A B 58-0 C 58-0 60-2 E fi0-8 6"x7" hale S" -+•, Shoe@6,461' PBTD =6,043 M D/ 5,980' ND TD = 6,469' MD/ 6,384' ND Max Deviation 19.2` @.6,000' Max Dogleg 2.8°/100' @ 2,700' SCHEMATIC rACIhIG r1FTAll Lewis River Unit Well: LRU C-SRD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01 Size Type Wt 5 Conn. EST TOC @ 2,400' X Btm 6( 20" . Liner Hanger 94 ZXP Packer - - Surf @ 2,454' 7" Temp Log TOC t @ 2,750' 13-3/8" Window @ 2,6.5/0/' FS 0 ' 54.5 46-8 47-5 A B 58-0 C 58-0 60-2 E fi0-8 6"x7" hale S" -+•, Shoe@6,461' PBTD =6,043 M D/ 5,980' ND TD = 6,469' MD/ 6,384' ND Max Deviation 19.2` @.6,000' Max Dogleg 2.8°/100' @ 2,700' SCHEMATIC rACIhIG r1FTAll Lewis River Unit Well: LRU C-SRD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01 Size Type Wt Grade Conn. ID Top Btm Cmt 20" Conductor 94 11-40 - - Surf 75' Driven 13-3/8" Surf. Csg 54.5 K-55 BTC 12.615" Surf 368' 425 sx 9-5/8" Int. Csg 47 N -80/S-95 LTC 8.681" Surf 2,409' 950 sx 7" Prod. Csg 26/29 L-80 BTC 6.184" Surf 2,650' 750 sx 5" Prod Liner 15 L-80 BTC 4.408" 2,454' 6,461' 800 sx IF1A/FI RV r)PTAll No. Depth ID OD Item 1 16.5' - - Dual Tubing Hanger, 2-7/8"x2-3/8" DCB 9" 5M 2 2,340' 2.313" 4.250" CMUSlidmg Sleeve 3 2,377' 1.875" 2.250" TTS/Owens Tbg Patch (18' Long) 4 2,386' 2.875" 5.983" Baker FH Packer (Size 47B2) 5 2,428' 2.313" 2.875" X -Profile 6 2,446' 1.875" 2.250" TTS/Owens Tbg Patch (20' Long) Tbg punch 2,450'-2,451' 7 2,467' 4.250" 5.250" HMC/ZXP Liner Hanger and Tieback Sleeve & Seals (]RAIU DAry ncTAu No. Depth ID OD Item 1.38" 2.25" TTS 2-7/8" Anchor Latch / 2-3/8" PBR Assy. A 5,440' 1.75" 2.28" TTS Gravel Pack Packer 1-1/2' NU Pin; 2-1/2" Fish Neck 1.75" 2.20" MOE w/ 1-1/2- NU LORD BxB Comments 9/23/19 B 5,457' 1.61" 1.90" 30its—Blank Tbg w/1-1/2" NO 30RD Pin x Box w/X05 4 5,790' 1,375" 2.06" 4jts— BJ CoilFlow DB Screen w/2 Bow Spring 46-8 5,833' 4,689' 4,668' Centralizers Spaced 20' Apa rt w/ 1-1/4" NU LORD 8 5,850' 1.380" 2.06" 2 its— BJ Pro Weld Screen .008" Gauge 1-1/4" NU 10RD 47-5 5,868' 1.375" 2.06" 1 jt — BJ CoilFlow D8 Screen w/ 1 Bow Spring C 5,881' 60 1.68" Enerjet Centralizer w/1-1/4"NU LORD 58-0 5,883' 1.380" 2.06" 8 jts — B1 Pro Weld Screen .008" Gauge 1-1/4" NU 10R6 12 6,003' 60 2.0" P1 w/ 3 bow spring centralizers, spaced every 30' 6,005' 1.375" 2.06" 1 it— BJ CoilFlow DB Screen w/ 1 Bow Spring 6,018' 2.0" PJ Omega Centralizer w/ 1-1/4" NO lORD 58-0 6,021' - 2.05" Combination Bull Plug w/ 1-1/2" NO 30RD D 6,021' - 2.28" REP Pulling Tool 6.022'TTS - 2.28" Retrievable Bridge Plug 6,026' 2.0" PJ Omega 8/11/06 E 6,054' - - Posi-Set Plug (capped with 11' of cement) Notes: TTS GP Packer takes a TTS 2-7/8" Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand Out @ 1,750# above injection rate @ Y. bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Pert Tunnels & covered 36' of Blank Tubing Updated by CMT 10-4-2019 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 9/23/19 F5 2,944' 2,954' 2,942' 2,952' 4 10 0 1.68" Owen Shogun 5/14/08 46-8 41679' 4,689' 4,668' --4,- 678' 8 10 60 Strip Gun 1.68" Enerjet 5/14/08 47-5 4,747' 4,759' 4,735' 4,47' 8 12 60 1.68" Enerjet 7/15/02 8/11/06 58-0 51800' 5,818' 5,750' 5,767' 12 18 60 2.0" P1 2.0" PJ Omega 7/15/02 8/11/06 58-0 5,872' 5,880' 5,818' 5,826' 12 8 60 2.0 2.0" PJ Omega 8/11/06 60-2 6,021' 6,026' 5,959' 5,964' 12 5 60 2.0" Ell Omega 12/09/01 60-2 6,022' 6,042' 5,960' 5,979' 6 20 60 2.0" HC 10/22/01 1 60-8 1 6,uov I6,118' 0,ul5I 6,051 I 6 1 38 1 60 1 2.0" PJ Notes: TTS GP Packer takes a TTS 2-7/8" Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand Out @ 1,750# above injection rate @ Y. bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Pert Tunnels & covered 36' of Blank Tubing Updated by CMT 10-4-2019 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Lewis River Field, Undefined Gas Pool, LRU C-OIRD Permit to Drill Number: 201-168 Sundry Number: 319-418 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, �v )essie L�Clunielowski Commissioner DATED this / 7- day of September, 2019. 3BDMS ��SEP 2 0 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 SE? 13 26'119 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate 1] Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q . Stratigraphic❑ Service ❑ 201-168 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-283-20061-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Statewide Spacing Will planned perforations require a spacing exception? Yes ❑ No ❑� Lewis River Unit (LRU) C-01 RD ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0058798 Lewis River/ Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,469' 6,384' 6,043' 5,980' -995 psi 6,043' 5,438' (fill) Casing Length Size MD TVD Burst Collapse Structural 75' 20" 75' 75' Conductor 368' 13-3/8" 368' 368' 2,730psi 1,130psi Surface 2,409' 9-5/8" 2,409' 2,408' 4,720psi 3,880psi Intermediate Production 2,650' 7" 2,650' 2,649' 4,980psi 4,320psi Liner 6,461' 5" 6,461' 6,437' 8,290psi 7,250psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 1-1/4" Tubing Grade: 2.3# / L-80 Tubing MD (ft): 2,339' See Attached Schematic See Attached Schematic 2-7/8" 6.4# / N-80 5,490' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FH Pkr; N/A 2,386' MD/2,365'TVD; N/A, N/A 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: September 23, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager Contact Email: otwo ood hilcor .Com 1 Contact Phone: 777-8443 ,3 ,2 Ztt �j Authorized Signature: Date: 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: jr A� .Q "'I C 0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: MMS.IL/t^'SEP 2 0 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes El No Subsequent Form Required: - APPROVED BY Lf ((( Approved by: COMMISSIONER THE COMMISSION Date: V � i-1(0-11 U K I U I N A L S`,_%" � i`Y�SubmilForm and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval..��nttachments in Duplicate �Yvkolle .-4S-%,14-/�, K llilcara Alaaka, Lb Well Prognosis Well: LRU C-01RD Date:9/13/2019 Well Name: LRU C-01RD API Number: 50-283-20061-01-00 Current Status: Producing Gas Well Leg: NA Estimated Start Date: September 23rd, 2019 Rig: E -Line Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 201-168 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: Current BHP: Max. Expected BHP: Max. Possible Surface Pressure: Brief Well Summary —872 psi at 4,786' TVD —1,290 psi at 2,952' TVD —995 psi at 2,952' TVD (Based on 3/18/16 static pressure survey) (Based on normal gradient) (Based on expected BHP and gas gradient to surface (0.1 psi/ft)) LCU C-01RD was a redrill of the original C-01 that was completed in 2001 to target the deeper Tyonek. The 60-8 sand was perforated in October 2001. The 60-2 sand was perforated in December 2001 and again in August 2006. The 58-0 Sand was perforated in July 2002 and again in August 2006. The 47-5 and 46-8 sands were perforated - in May 2008 and are currently the only two open intervals. The purpose of this work/sundry is to perforate the Beluga F5 sand. Notes Regarding Wellbore Condition • Last tag at 4,718' RKB on 9/12/2019 • Minimum ID is 1.875" at 2,377' MD and 2,446' MD. Both TTS/Owen Tbg Patches, 18'& 20' respectively Safety Concerns Discuss Nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job). • Ensure all crews are aware of stop job authority. E -Line Procedure 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 2,000 psi High. 2. RIH with GPT tool and find fluid level. If fluid is over the depth of the new perfs, discuss using methane or Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen Truck, pressure up on well and push water back into formation. Use GPT tool to confirm water level is below interval to perf. 4. RU perfguns. U llilm" Alaska, IAA 5. RIH and perforate the below interval: Well Prognosis Well: LRU C-01RD Date:9/13/2019 Zone Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Beluga F5 ±2,944' ±2,954' ±2,942' ±2,952' 10' a. Well may be shot flowing. If well is not shot flowing, pressure up well to 800 psi before perforating. b. Proposed perfs also shown on the proposed schematic in red font. c. Final perfs tie-in sheet will be provided in the field for exact pert intervals. d. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. e. Use Gamma/CCL to correlate. f. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. g. Record 5, 10 and 15 minutes pressures after firing guns. 6. POOH. 7. RD E -Line. 8. Turn well over to production. E -Line Procedure (Contingency) 1. If these zones produce sand and/or water and need to be isolated. 2. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 3,000 psi High. 3. RIH and set 2-7/8" Casing Patch or set 2-7/8" CIBP above the zone and dump 25' of cement on top of the plug. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure — N2 Operations 20^ — 13-3/a" Ground Elev: 100.0' Above MSL KB -THF: 16.50'/ KB -GL: 15.0' 2 3 EST TOC @ 2,400' 6 Liner Hanger ZXP Packer 7 @ 2,454' ' Window Temp Log TUC @ 2,650' @ 2,750' SCHEMATIC CASING DETAIL Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01 Size Type Wt 46-8 Conn. ID Top 47-5 Cmt 20" Conductor 94 13 - 68-0 Surf 75' 4�1 r\ Surf. Csg SCHEMATIC CASING DETAIL Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01 Size Type Wt Grade Conn. ID Top N Cmt 20" Conductor 94 H-40 - 68-0 Surf 75' Driven 13-3/8" Surf. Csg 54.5 K-55 BTC 12.615" Surf 368' 425 sx 9-5/8" Int. Csg 47 N -80/S-95 LTC 8.681" Surf 2,409' 950 sx 7" Prod. Csg 26/29 L-80 BTC 6.184" Surf 2,650' 60.2 5" Prod Liner 15 i� BTC P 2,454' 6,461' 500 sx its - BJ Pro Weld Screen .008" Gauge 1-1/4" NU 10RD SCHEMATIC CASING DETAIL Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01 Size Type Wt Grade Conn. ID Top Bim Cmt 20" Conductor 94 H-40 - - Surf 75' Driven 13-3/8" Surf. Csg 54.5 K-55 BTC 12.615" Surf 368' 425 sx 9-5/8" Int. Csg 47 N -80/S-95 LTC 8.681" Surf 2,409' 950 sx 7" Prod. Csg 26/29 L-80 BTC 6.184" Surf 2,650' 750 sx 5" Prod Liner 15 L-80 BTC 4.408" 2,454' 6,461' 500 sx JEWELRY DETAIL No. Depth ID OD Item 1 16.5' - - Dual Tubing Hanger, 2-7/8"x2-3/8" DCB 9" 5M 2 2,340' 2.313" 4.250' CMU Sliding Sleeve 3 2,377' 1.875" 2.250" TTS/Owens Tbg Patch (18' Long) 4 2,386' 2.875" 5.983" Baker FH Packer (Size 47132) 5 2,428' 2.313" 2.875" X -Profile 6 2,446' 1.875" 2.250" TTS/Owens Tbg Patch (20' Long) Tbg punch 2,450-2,451' 7 2,467' 4.250" 5.250" 1 HMC/ZXP Liner Hanger and Tieback Sleeve & Seals GRAVEL PACK DETAIL No. Depth ID OD Item 1.38" 2.25" TTS 2-7/8" Anchor Latch / 2-3/8" PBR Assy. A 5,440 1.75" 2.28" TTS Gravel Pack Packer 1-1/2' NU Pin; 2-1/2" Fish Neck SPF I Ft 1.75" 2.20' MOE w/ 1-1/2" NU LORD BxB B 5,457' 1.61" 1.90" 10 its - Blank Tbg w/1-1/2" NU LORD Pin x Box w/XOs 8 5,7904Its- 8" Enerjet 81 CoiPlow DB Screen w/ 2 Bow Spring 47-5 5,833' 1.375" 2.06" Centralizers Spaced 20 Apart w/ 1-1/4" NU 10RD 8 5,850 1.380' 2.06" 2jts- BJ Pro Weld Screen .008" Gauge 1-1/4" NU SORD 58-0 5,868'1 5,818' 5,750' jt- BJ CoilFlow DB Screen w/ 1 Bow Spring C 5,881' 1.375" 2.06" Centralizer w/ 1-1/4" NU logo 58-0 5,883'8 5,880' 5,818' its - BJ Pro Weld Screen .008" Gauge 1-1/4" NU 10RD 12 6,003' 1.380" 2.06" w/ 3 bow spring centralizers, spaced every 30' 60-2 6,005' 6,026' 5,959' 1 it- Bl Coil Flow DB Screen w/ 1 Bow Spring 12 6,018' 1.375" 2.06•• Centralizer w/ 1-1/4" NU SORD 60-2 6,021' - 2.05" Combination Bull Plug w/ 1-1/2" NU 1ORD 6 6,021' - 2.28" RBP Pulling Tool D 6,022' 6,118' 6,015' TTS Retrievable Bridge Plug 6 6,6' 2.28" E 6,02054' - - I Posi-Set Plug (capped with 11' of cement) 60-8 6"x7" hole Shoe @ 6,461' PBTD =6,043 MD/ 5,980 TVD TD = 6,469' MD/ 6,384' TVD Max Deviation 19.2° @ 6,000 Max Dogleg 2.8'/100 @ 2,700' Notes: TTS GP Packer takes a TTS 2-7/8" Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand Out @ 1,750# above injection rate @ h bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels & covered 16' of Blank Tubing Updated by DMA 09-05-19 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF I Ft Phase Comments 5/14/08 46-8 4,679" 4,689' 4,668' 4,678' 8 30[L2.W 8" Enerjet 5/14/08 47-5 4,747' 4,759' 4,735' 4,747' 8 128" Enerjet 7/15/02 8/11/06 58-0 5,800' 5,818' 5,750' 5,767' 12 182.0' PJ ' PJ Omega 7/15/02 8/11/06 58-0 5,872' 5,880' 5,818' 5,826' 12 82.0" PJ PJ Omega 8/11/06 60-2 6,021' 6,026' 5,959' 5,964' 12 5" PJ Omega 12/09/01 60-2 6,022' 6,042' 5,960 5,979' 6 202.0" HC10/22/01 60-8 6,080' 6,118' 6,015' 6,051' 6 382.0" PJ 60-8 6"x7" hole Shoe @ 6,461' PBTD =6,043 MD/ 5,980 TVD TD = 6,469' MD/ 6,384' TVD Max Deviation 19.2° @ 6,000 Max Dogleg 2.8'/100 @ 2,700' Notes: TTS GP Packer takes a TTS 2-7/8" Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand Out @ 1,750# above injection rate @ h bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels & covered 16' of Blank Tubing Updated by DMA 09-05-19 n Hila Alenke. IXC Ground Elev: 100.0' Above MSL KB -THF: 16.50'/ KB -GL: 15.0' 2 3 PaC)POSSD SCHEMATIC CASING DETAIL Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01 Size Type Wt EST TOC 46-8 a @ 2,400' 6 Btm Cmt . Liner Hanger 1 ZXP Packer 7 " @ 2,454' 7" Window Temp Log TOC' 2.750' @ 2,650' @ . p FS pL8'l'I04 PaC)POSSD SCHEMATIC CASING DETAIL Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01 Size Type Wt Grade 46-8 ID Top Btm Cmt 47-5 1 94 H-40 - - Surf It Driven 13-3/8" Surf. Csg 54.5 K-55 BTC 12.615" Surf 368' 425 sx 9-5/8" Int. Csg 47 N-80/5-95 LTC 8.681" Surf 2,409' 950 sx 4 +• _= 58-0 L-80 BTC 6.184" Surf 2,650' 750 sx 5" 5a-0 15 L-80 BTC 4.408" 2,454' 6,461' 500 sx 8 jts— BJ Pro Weld Screen .008" Gauge 1-1/4" NU LORD 12 6,003' 60 60.2 1: 58-0 6,005' 60.9 PaC)POSSD SCHEMATIC CASING DETAIL Lewis River Unit Well: LRU C-1RD Completion Ran: 12/03/01 PTD: 201-168 API: 50-283-20061-01 Size Type Wt Grade Conn. ID Top Btm Cmt 20" Conductor 94 H-40 - - Surf 75' Driven 13-3/8" Surf. Csg 54.5 K-55 BTC 12.615" Surf 368' 425 sx 9-5/8" Int. Csg 47 N-80/5-95 LTC 8.681" Surf 2,409' 950 sx 7" Prod. Csg 26/29 L-80 BTC 6.184" Surf 2,650' 750 sx 5" Prod Liner 15 L-80 BTC 4.408" 2,454' 6,461' 500 sx DETAIL IIyLTJ:IIl lY73rim No. Depth ID OD Item 1 16.5' - - Dual Tubing Hanger, 2-7/8"x2-3/8" DCB 9" 5M 2 2,340' 2.313" 4.250" CMU Sliding Sleeve 3 2,377' 1.875" 2.250" TTS/Owens Tbg Patch (18' Long) 4 2,386' 2.875" 5.983" Baker FH Packer (Size 4782) 5 2,428' 2.313" 2.875" X -Profile 6 2,446' 1.875" 2.250" TTS/Owens Tbg Patch (20' Long) Tbg punch 2,450'-2,451' 7 2,467' 4.250" 5.250" 1 HMC/ZXP Liner Hanger and Tieback Sleeve & Seals GRAVEL PACK DETAIL No. Depth ID OD Item 1.38" 2.25" TTS 2-7/8" Anchor Latch / 2-3/8" PBR ASSY. A 5,440' 1.75" 2.28" TTS Gravel Pack Packer 1-1/2' NU Pin; 2-1/2" Fish Neck 1.75" 2.20" MOE w/ 1-1/2" NU SORD BxB Comments TBD B 5,457' 1.61" 1.90" 30 its — Blank Tbg w/1-1/2" NU LORD Pin x Box w/XOs 5,790' 1375" 2A6„ 4jts— 81 Coili'low, DB Screen w/.2 Bow Spring 46-8 5,833' 4,689' 4,668' Centralizers Spaced 20' Apart w/ 1-1/4" NU 1ORD 8 5,850' 1.380" 2,06" 2 its— BJ Pro Weld Screen .008" Gauge 1-1/4" NU LORD 47-5 5,868' 1.375" 2.06" 1 jt— BJ ColiFlow DB Screen w/ 1 Bow Spring C 5,881' 60 1.68" Enerjet Centralizer w/ 1-1/4" NU 10RD 58-0 5,883' 1.380" 2.06" 8 jts— BJ Pro Weld Screen .008" Gauge 1-1/4" NU LORD 12 6,003' 60 2.0 PJ 2.0" PJ Omega w/ 3 bow spring centralizers, spaced every 30' 58-0 6,005' 1.375" 2.06" 1jt— BJ CoilFlow DB Screen w/1 Bow Spring 12 6,018' 60 2.0" P1 2.0" PJ Omega Centralizer w/ 1-1/4" NU 30RD 60-2 6,021' 6,026' 2.05" Combination Bull Plug w/ 1-1/2" NU LORD D 6,021' - 2.28" RBP Pulling Tool 60-2 6,022'2.28" - 5,960' TTS Retrievable Bridge Plug 6 6,026' 60 2.0" HC 10/22/01 E 6,054' - - Posi-Set Plug (capped with 11' of cement) 6"x7'• hole Shoe @ 6,461' PBTD=6,043 MD/ 5,980' TVD TD = 6,469' MD/ 6,384' TVD Max Deviation 19.2° @ 6,000' Max Dogleg 2.8°/10V @ 2,700' Notes: TTS GP Packer takes a TTS 2-7/8" Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BELS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand Out @ 1,750# above injection rate @ Y bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels 8, covered 16' of Blank Tubing Updated by TRH 09-05-1 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments TBD FS 2,944' 2,954' 2,942' 2,952' 10 5/14/08 46-8 4,679' 4,689' 4,668' 4,678' 8 10 60 1.68" Enerjet 5/14/08 47-5 4,747' 4,759' 4,735' 4,747' 8 12 60 1.68" Enerjet 7/15/02 8/11/06 58-0 5,800' 5,818' 5,750' 5,767' 12 18 60 2.0 PJ 2.0" PJ Omega 7/15/02 8/11/06 58-0 5,872' 5,880' 5,818' 5,826' 12 8 60 2.0" P1 2.0" PJ Omega 8/11/06 60-2 6,021' 6,026' 5,959' 5,964' 12 5 60 2.0" Pl Omega 12/09/01 60-2 6,022' 6,042' 5,960' 5,979' 6 20 60 2.0" HC 10/22/01 60-8 6,080' 1 6,118' 6,015' 6,051' 6 38 60 1 2.0" PJ 6"x7'• hole Shoe @ 6,461' PBTD=6,043 MD/ 5,980' TVD TD = 6,469' MD/ 6,384' TVD Max Deviation 19.2° @ 6,000' Max Dogleg 2.8°/10V @ 2,700' Notes: TTS GP Packer takes a TTS 2-7/8" Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BELS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand Out @ 1,750# above injection rate @ Y bpm (Injection Rate = 2,500 psig) Pumped 59.25 PPF into Perf Tunnels 8, covered 16' of Blank Tubing Updated by TRH 09-05-1 14 STANDARD WELL PROCEDURE Ilileorp Alaska. LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 ~_ STATE OF ALASKA J!~" ~ 8' _ ALA OIL AND GAS CONSERVATION COM ION ~~ ~' REPORT OF SUNDRY WELL OPERATIONS ~~~~ ,, ~ <~._; e{ 1. Operations Abandon Repair Well Plug Perforations Stimulate At~S;~ 8 ~ 1~ Performed: Alter Casin Pull Tubin Perforate New Pool Waiver Time Extensio ~` ~' !~^, ~' 9 ^ 9^ ^ ^ ~ ~ .~t~fii(fiiSSlO Change Approved Program ^ Operat. Shutdown^ Perforate ^~ Re-enter Suspended Wel#'i" v°~;+>~ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development- Exploratory^ 201-168 3. Address: P.O. Box 196347, Anch, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-283-20061-01- 7. KB Elevation (ft): 9. Well Name and Number: 16.5' Lewis River Unit C-01 RD, 8. Property Designation: ~ 10. Field/Pool(s): East Lewis River/ADL 0058798 Lewis River /Undefined gas 11. Present Well Condition Summary: Total Depth measured 6,469' ~ feet Plugs (measured) 6,043' - true vertical 6,384 ~ feet Junk (measured) 5,438' Effective Depth measured 5438' feet r ~~~ A~ u ~ ~ Zd~$ ' ~~ true vertical 5,404 + feet Casing Length Size MD TVD Burst Collapse Structural 75' 20" 75' 75' Conductor 368' 13-3/8" 368' 368' 2,730 psi 1,130 psi Surface 2,409' 9-5/8" 2,409' 2,408' 4,720 psi 3,880 psi Intermediate Production 2,650' 7" 2,650' 2,649' 4,980 psi 4,320 psi Liner 4,007 5" 6,461' 6,437' 8,290 psi 7,250 psi y14/L ~ Perforation depth: Measured depth: 4,679' - 6,042' ~~~-~~59' ~ ~,~ X689 True Vertical depth: 4,667' - 5,978' Tubing: (size, grade, and measured depth) 1.68" / 2-7/8" L-80/N-80 2,339' / 5,490' Packers and SSSV (type and measured depth) Baker FH PKR 2,386' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~ ~ ` S~ ~ + (' ~ '- ~b~r NA c Treatment descriptions including volumes used and final pressure: ~~~ ~~ ~5 ~2~ ~ a NA 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 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas 0 WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-173 Contact Chantal Walsh 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature 'C Phone 907-276-7600 Date 6/19/2008 -- - Form 10-404 Revised 04/2006 R' ~ I N A L s ~~ ~~~ ~ ~ ~~~6 Submit Original Only ~,~~~ Chevron Chevron -Alaska Daily Operations Summary Well Name LRU C-01 RD Field Name Lewis River API/UWI 502832006101 Lease/Serial ADL058798 CHEVNO QM2722 License No./Props... 2011680 Orig KB Elev (ftKB) Water Depth (ft) Jobs - Job Cat _ --- Type AFE No: - QG Eng Well Service Perforating UWDAK-R8033 ------ -------------------- - -- Daily Operations ~ 5/11/2008 00:00 - 5/12/2008 00:00 Operations Summary RU slickline and RIH 1-2/4" bailer. Tag fill at 5438' RKB POOH. RD slickline. 5/14/2008 00:00 - 5/15/2008 00:00 Operations Summary RU Eline. Pressure test equipment 250 psi low, 2500 psi high. MU 1.68" Power spiral Enerjet, 7.5 SPF, 45 degree phased. Correlate to tie in log. Perforate beluga zones - 4747' to 4759' and 4679' to 4689'. RD Eline. Chevron ~ • Lewis River Well C-1RD 06/19/08 CASING AND TUBING DETAIL RKB = 16.5' SIZE WT GRADE CONN ID TOP BTM1I. 20" - - - 75' 13-3/8" 54.5 Surf 368' 9-5/8" 47 Surf 2,409' 7" 26 & 29 29# window Surf 2650' 5" l5 L-80 Butt 4.408 2,454' 6,461' Tubin 2-7/8" 6.4 N-80 Butt SCC 2.441 Surf 5490' 1-1/4" 2.3 I. 80 CS H dril 1.380 Surf 2,339' JEWELRY DETAIL NO. De th Len th IU OD Item 16.5' Dual Tubin Han er, 2-7/8" x 2-3/8" DCB 9" 5M 1. 2386' 2.875 6.059 BAKER FH PACKER 2. 2377' 18' 1.875 2.25" TTS/Owens Tbg Patch 2395' RI OD 3. 2428' 2.310 2.875 "X" Nipple 4. 2446' 10' 1.875 2.25" TTS/Owens Tbg Patch 2456' RI OD 5. 2467' 4.25 5.25 HMC/ZXP Liner Hanger and Tieback Sleeve & SEALS Gravel Pack Completion All de the are referenced to Eline Tie-in to Schlumb °Com letion L "dated 7/1 X02 1.94' 1.38 2.25" T.T.S. 2-718" Anchor Latch / 2-3/8" PBR Assy. T.T.S. Gravel Pack Packer w/1-1/2" NU Pin A. 5440' 3.94' 1.75 2.28 & 2-1/2" TTS internal Fishing Neck 11.44' 1.75 2.20 MOE w/1-112" NU LORD Box x Box B. 5457' 332.81' 1.61 1.90 (10 Jts) Blank Tubing with 1-1/2" NU LORD Pin x Box w/ XO's Screen 18.05 5790' ros 2.54 1 375 2 06 (4 Jts.) BJ "CoilFlow DB" Screen w/ (2) Bow Spring Centralizers " 5833' sos Screen 22.08 . . NU 10RD conn. Spaced 20' apart. w/ 1 '/. 2.54 5850' 30.16' 1.38 2.06 (2 Jts.) BJ Pro Weld Screen .008 Gauge 1-t14" NU 10RD P x B 5868' ros 2.54 s 13 08 1 375 06 2 (1 Jts.) BJ "CoilFlow DB" Screen w/ Bow Spring Centralizers C' 5881' eos creen . 2.54 . . top and bottom. w/t '/." NU 10RD conn. 5883' ros 119 09' 1 38 06 2 (8 Jts.) BJ Pro Weld Screen .008 Gauge 1-1/4" NU 10RD P x B ' 6003' eos . . . wl (3) bow spring centralizers, spaced ever 30 6005' ros 2.54 S 13 09' 1 375 06 2 (1 Jts.) BJ °CoilFlow DB" Screen w/ Bow Spring Centralizers 6018' eos creen . 2.54' . . top and bottom. w/1 '/;' NU 10RD conn. 6021' 0.41' 2.05 Combination Bull Plug w/1-1/2" NU 10RD D 6021 1.25' 2.28 RBP Pulling Tool 6022' 3.68' 2.28 TTS Retrievable Bridge Plug 6026' btm Notes: TTS GP Packer takes a TTS 2-7/8" Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand out ~ 1,750# above Injection Rate n 1/2 BPM (INJECTION RATE = 2500 psig) Pumped 59.25 PPF into Perfs Tunnels & covered 18 of Blank Tubing PERFORATION INTERVAL Interval Accum. Date Zone Top Btm Amt spf Comments 12/11/2001 2,449' 2,450' I' 4 TBG PUNCH 5/14/2008 Belu a 4,679' 4,689' 10' 8 1.68" Power S iral Ener'et 5/14/2008 Belu a 4,747' 4,759' 12' 8 1.68" Power S iral Ener'et 7/15/2002 8/I 1/06 58-0 5,800' 5,818' 18' 12 2" PJ HC, 2" PJ Omega 7/15/2002 8/11/06 58-0 5,872' S.RRO' 8' 12 2" PJ HC, ~„ Pt Omega SI I I '_I~nn nn-' ~, ~ ~ ~,, rr t ~ 1,,,-, sand. LRU Clyd Current 6-19-08.doc Updated on 06/19/2008 BY: CRW TD = 6,469' TVD Max Hole Angle = 18 degrees at TD ChtVrt~r'! ~nciSCO Castro Chevron North erica Exploration and Production Technical Assistant 909 W. 9th Avenue "'~* "`~''~ Anchorage, AK 99501 #; =_E:-=~ Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE Tune 9, 2008 ~~A~1NEE~ JUN ~ ~ 200 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 a ~~,,J WELL LOG TYPE SCALE LOG DATE INTERVAL LOGGED RUN # B-LINE CD PJOTES -LAS, PDS, DLIS COMPLETION TB ST A-25RD RECORD 5" 4-Mar-08 6660-7092 1 1 1 PDS COMPLETION TB ST A-01 RD RECORD 5" 5-Mar-08 5697-6140 1 1 PDS COMPLETION TBU K-18RD RECORD 5" 21-Feb-08 10800-12400 1 1 PDS COMPLETION TBU K-26 RD RECORD 5" 24-Feb-08 10303-10323 1 1 PDS PERFORATING TBU G-22 RECORD 5" 3-Ma -08 10122-10229 PS-2 1 1 -DLIS-PDS PERFORATING TBU M-17 RECORD 5" 16-Feb-08 7298-7381 PS-11 1 1 PDS PERFORATING TBU M-17 RECORD 5" 14-Feb-OS 7296-7391 PS-9 1 1 PDS POSISET PLUG SETTING TBU M-17 RECORD 5" 11-Feb-08 6889-7430 PS-8 1 1 PDS PRESSURE TEMPERATURE TBU M-17 LOG 5" 15-Feb-08 5636-7398 PS-10 1 1 PDS DEPTH TBU M-17 DETERMINATION 5" 3-Feb-08 5782-7374.5 PS-7 1 1 PDS PERFORATING TBU M-17 RECORD 5" 19-Feb-08 5832-5856 PS-12 1 1 PDS POSISET PLUG SETTING TBU M-01 RECORD 5" 7-Jan-08 4792-5151 PS-2 1 PDS PERFORATING TBU M-01 RECORD 5" 18-Jan-08 4532-4580 PS-3 1 PDS HAPPY CEMENT BOND PDS, LAS, VALLEY B-12 LOG - SCMT 5" 18-Mar-08 3559-10315 1 1 1 DLIS COMPLETION PDS, DLIS, LRU C-01 RD RECORD 5" 14-Ma -08 4679-4759 1 1 FMA ( 1 1 1 1 I 1 I I SRU 32A-15 SHOOT R CORD 5" 10-Mar-08 5554-5582 1 1 PDS f `30 •-s~j~. //~<T~SI ---_-__ ~~~~~~ Please acknowledge receipt by signing and returning one copy of this transmittal or fAX,to 907 263 7828. Received 8~ ~;o' Date: AI.ASFu~ OI~i AI1ID G~.-~ COI~TSER`PATIOI~T C®MhIISSI®-~ Timothy C. Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 `~~ ~' M,~,Y ~ ~ 2QO~a Anchorage, AK 99519 Re: Lewis River, Lewis River Undefined Gas, C-OlRD Sundry Number: 308-173 Dear Mr. Brandenburg: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE.. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~\, ~~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Encl. ~~ ~~ STATE OF ALASKA Si ~~~~~~ ALA OIL AND GAS CONSERVATION COM~ION ~~ APPLICATION FOR SUNDRY APPROVALS MAY ~j~~V 20 AAC 2s.2so i ~1lacka (ail & Gas Cons. ml~issior 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate •~ Waiver WP1ch01•age Other^ Alter casing^ Repair well ^ Plug Perforations ^ Stim late ^ ~~ime Extension ^ u ~~ e Change approved program^ Pull Tubing ^ Perforate New Poo ~~ $~'Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 201-168 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 196247, Anchorage, AK 99519 50-283-20061-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q Lewis River Unit C-01 RD 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~` East Lewis River/ADL 0058798 16.5' Lewis River/T ~~°<s ~v~'' c.~! 12. PRESENT WELL CONDITION SUMMARY ,s. $-O Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6,469' ~ 6,384. 6,043' 6,023 6,043' Casing Length Size MD TVD Burst Collapse Structural 75' 20" 75' 75' Conductor 368' 13-3/8" 368' 368' 2,730 psi 1,130 psi Surface 2,409' 9-5i8" 2,409' 2,408' 4,720 psi 3,880 psi Intermediate Production 2,650' 7" 2,650' 2,649' 4,980 psi 4,320 psi Liner 4,007' S" 6,461' 6,437' 8,290 psi 7,250 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,800' to 6,042' 5749' to 5,978' 1.66"; 2-7/8" L-80; N-80; 2,339'; 5,490'; Packers and SSSV Type: Baker FH Pkr Packers and SSSV MD (ft): 2386' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 5/12/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ~ Plugged [] Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 1 B. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler - 907-263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature - - _1 Phone 907-276-7600 Date 5/8/2008 ~,. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. w, ~~ ` Co~~\ ~~V 1, (~~~~ l ~ ~ CL~ ~ ~~ ~ ~ ~~`-°~`~ `~~'~ Subsequent Form Required: ~~~ /-'.~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~~/.2- ~ r Form 10-403 Revised 06/2006 ~ L , ~ I U ~ ~~ sub: ~ ~~, Chevron • • Lewis River Well # LR C-O1RD 5/5/08 OBJECTIVE: • Perforate the Beluga Sand. PROCEDURE SUMMARY: • Rig up slickline. Run 1.80" gauge ring to 5000'. Bail fill if necessary. • Rig down and de-mobe slickline. • Rig up E-Line. Perforate the Beluga Sand from 4679' to 4689' (+/-) and from 4747' to 4759' (+/-). ----_. • Rig down and de-mobe E-Line. LR C-O1RD REVISED BY: BCA 5/5/08 Chevron . • Lewis River Well C-lyd Current as of 9/08/06 RKB = 16.5' CASING AND TUBING DETAIL SIZE W'T GRADE CONN ID TOP BTM. 20" - - - 75' 13-3/8" 54.5 Surf 368' 9-5/8" 47 Surf 2,409' 7" 26 & 29 29# window Surf 2650' 5" 15 L-80 Butt 4.408 2,454' 6,461' Tubin 2-7/8" 6.4 N-80 Butt SCC 2.441 Surf 5490' 1.66" 2.3 L-80 CS H dril 1.380 Surf 2,339' JEWELRY DETAIL NO. De th Len th ID OD Item 16.5' Dual Tubin Han er, 2-7/8" x 2-3/8" DCB 9" 5M 1. 2386' 2.875 6.059 BAKER FH PACKER 2. 2377' 18' 1.875 2.25" TTS/Owens Tbg Patch 2395' RI OD 3. 2428' 2.310 2.875 "X" Nipple 4. 2446' 10' 1.875 2.25" TTS/Owens Tbg Patch 2456' RI OD 5. 2467' 4.25 5.25 HMC/ZXP Liner Hanger and Tieback Sleeve & SEALS Gravel Pack Completion All de the are referenced to Eline Tie-in to Sch/umb "Com letion Lo "dated 7/1 X02 1.94' 1.38 2.25" T.T.S. 2-7/8" Anchor Latch / 2-3/8" PBR Assy. ' T.T.S. Gravel Pack Packer w/1-1/2" NU Pin A. 5440' 3.94 1.75 2.28 & 2-1/2" TTS internal Fishing Neck 11.44' 1.75 2.20 MOE w/1-112" NU 10RD Box x Box B. 5457' 332.81' 1.61 1.90 (10 Jts) Blank Tubing with 1-1 /2" NU 10RD Pin x Box w/ XO's Screen 18.05 5790' Tos 2.54 1 375 2 06 (4 Jts.) BJ "CoilFlow DB" Screen w/ (2) Bow Spring Centralizers 5833' eos Screen 22.08 . . Spaced 20' apart. w/ 1 '/." NU 10RD conn. 2.54 5850' 30.16' 1.38 2.06 (2 Jts.) BJ Pro Weld Screen .008 Gauge 1-114" NU 10RD P x B C 5868' ToS 2.54 screen 13 08 1 375 06 2 1 Jts. BJ "CoilFlow DB" Screen w/ Bow S rln Centralizers p g ( ) 5881' eos . 2 54 . . , top and bottom. w/1 /." NU 10RD conn. 5883' Tos 119 09' 1 38 06 2 (8 Jts.) BJ Pro Weld Screen .008 Gauge 1-114" NU 10RD P x B 6003' aos . . . w/ (3) bow spring centralizers, spaced ever 30' 6005' Tos 2.54' screen 13 09' 1 375 2 06 1 Jts. BJ "CoilFlow DB" Screen wl Bow S rln Centralizers ( ) p g 6018' eos . 2 54' . . top and bottom. w/1 %." NU 10RD conn. 6021' 0.41' 2.05 Combination Bull Plug w/1-1 /2" NU 10RD D g021~ 1.25' 2.28 RBP Pulling Tool 6022' 3.68' 2.28 TTS Retrievable Bridge Plug 6026' btm Notes: TTS GP Packer takes a TTS 2-7/8" Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand out @ 1,750# above Injection Rate @ 1/2 BPM (INJECTION RATE = 2500 prig) Pumped 59.25 PPF into Perfs Tunnels & covered 16' of Blank Tubing PERFORATION INTERVAL Interval Accum. Date Zone Top Btm Amt spf Comments 12/11/2001 2,449' 2,450' 1' 4 TBG PUNCH 7/15/2002 8/11/06 58-0 5,800' 5,818' 18' 12 2" PJ HC, 2" PJ Omega 7/15/2002 8/11/06 58-0 5,872' 5,880' 8' 12 2" PJ HC, 2" PJ Omega 8/ 11 /2006 60-2 6,021' 6,026' S' 12 Perf top 5' of 60-2 sand. 12/9/2001 60-2 6,026' 6.042' 16' 6 '"' lhni "Ib~ Gun. Fill co~~ered 111'22!2001 6,080' h_111' 3S' LRU_Clyd_Current 9-08-06.doc Updated on 10/24/2006 BY: SLT TD = 6,469' TVD Max Hole Angle = 18 degrees at TD Chevron • • Lewis River Well C-lyd Proposed sisios CASING. AND Tl1BING DETAIL RKB = 16.5' SI7.E WT GRADE CON\ ID TOP BTM. zo" - - - 75' 13-3/8" 54.5 Surf 368' 9-5/8" 47 Surf 2,409' 7" 26 & 29 29# window Surf 2650' 5" 15 L-80 Butt 4.408 2,454' 6,461' Tubin 2-7/8" 6.4 N-80 Butt SCC 2.441 Surf 5490' 1-1/d" 2.3 L-80 CS }I dril 1.380 Surf 2,339' IEWF.I.RY DETAIL NO. De th Len th ID OD Item 16.5' Dual Tubin Han er, 2-7/8" x 2-3/8" DCB 9" 5M 1. 2386' 2.875 6.059 BAKER FH PACKER 2. 2377' 18' 1.875 2.25" TTS/Owens Tbg Patch 2395' RI OD 3. 2428' 2.310 2.875 "X" Nipple 4. 2446' 10' 1.875 2.25" TTS/Owens Tbg Patch 2456' RI OD 5. 2467' 4.25 5.25 HMC/ZXP Liner Hanger and Tieback Sleeve & SEALS Gravel Pack Completion All de the are referenced to Eline Tie-in to Sch/umb "Com /etion Lo "dated 7/15r02 1.94' 1.38 2.25" T.T.S. 2-7/8" Anchor Latch / 2-3/8" PBR Assy. T.T.S. Gravel Pack Packerwll-1/2" NU Pin A. 5440' 3.94' 1.75 2.28 & 2-112" TTS internal Fishing Neck 11.44' 1.75 2.20 MOE w/1-1/2" NU 10RD Box x Box B. 5457' 332.81' 1.61 1.90 (10 Jts) Blank Tubing with 1-1 /2" NU 10RD Pin x Box w/ XO's Screen 18.05 5790' ros 2.54 (4 Jts.) BJ "CoilFlow DB" Screen w/ (2) Bow Spring Centralizers 5833' eos Screen 22.08 1.375 2.06 Spaced 20' apart. w/ 1 '/." NU 10RD Conn. 2.54 5850' 30.16' 1.38 2.06 (2 Jts.) BJ Pro Weld Screen .008 Gauge 1-1/4" NU 10RD P x B 5868' ros 2.54 (1 Jts.) BJ "CoilFlow DB" Screen w/ Bow Spring Centralizers C 5881' eos screen 13.08 1.375 2.06 top and bottom. wl1 %:' NU 10RD conn. 2 54 5883' ros ' (8 Jts.) BJ Pro Weld Screen .008 Gauge 1-1/4" NU 10RD P x B 6003' eos 118,09 1.38 2.06 w/ (3) bow spring centralizers, spaced ever 30' ' 2.54 (1 Jts.) BJ "CoilFlow DB" Screen w/ Bow Spring Centralizers ros 6005 6018' eos screen 13.09' ' 1.375 2.06 top and bottom. w/1 '/." NU 10RD conn. 2.54 6021' 0.41' 2.05 Combination Bull Plug w/1-1 /2" NU 10RD 0 1' 1 25' 2.28 RBP Pulling Tool D 6 2 . 6022' 3.68' 2.28 TTS Retrievable Bridge Plug 6026' btm Notes: TTS GP Packer takes a TTS 2-7/8" Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand out @ 1,750# above Injection Rate @ 1/2 BPM (INJECTION RATE = 2500 psig) Pumped 59.25 PPF into Perfs Tunnels & coveed 16' of Blank Tubing PERFORATION INTERVAL Interval Accum. Date Zone Top Btm Amt spf Comments 12/11/2001 2,449' 2,450' 1' 4 TBG PUNCH ' licluea -1.r~79' ; r S~,' 10' S I'ru o,e~ °"' Rclu~a -iJ-}T -1.7~~I' 12' `i Pro osed 7/15/2002 8/11/06 58-0 ~ 5,800' 5,818' 18' 12 2" PJ HC, 2" PJ Omega 7/15/2002 8/11/06 58-0 5,872' 5,880' 8' 12 2" PJ HC, 2" PJ Omega 8/11 /2006 60-2 6,021' 6,026' S' 12 Perf to 5' of 60-2 sand. LRU_Clyd_Proposed 5-5-08.doc Updated on 10/24/2006 BY: SLT TD = 6,469' TVD Max Hole Angle = 18 degrees at TD STATE OF ALASKA ~ MAY 0 7 2008 ALA OIL AND GAS CONSERVATION COMM ON ' a APPLICATION FOR SUNDRY APPROVALSAiaska qil & Gas Cons. Commission 20 AAC 25.280 Anchorage 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Other Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool Q Re-enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit to ill Number: Union Oil Company of California Development Q Exploratory ^ 201-168 3. Address: Stratigraphic ^ Service ^ 6. Number: PO Box 196247, Anchorage, AK 99519 -283-20061-01 7. KB Elevation (ft): 9. Well Name and Number: 16.5' Lewis River Unit C-01 RD ' 8. Property Designation: 10. Field/Pools(s): East Lewis River/ADL 0058798 ~ Lewis River Field/T ~~.~/L e~/vt.~ (/L ~ /~~ 11. PRESENT WELL CONDITION SUMM Y Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth D (ft): Plugs (measured): Junk (measured): 6,469' 6,384 6,043' 23 6,043' Casing Length Size MD TVD Burst Collapse Structural 75' 20" 75' 75' Conductor 368' 13-3/8" 68' 368' 2,730 psi 1,130 psi Surface 2,409' 9-5/8" ~ 2,4 2,408' 4,720 psi 3,880 psi Intermediate 2,650' 7" ,650' 2,649' 4,980 psi 4,320 psi Production 4,007' 5" 6,461' 6,437' 8,290 psi 7,250 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tub' g Size: Tubing Grade: Tubing MD (ft): 5,800' to 6,042' 5749' to 5,978' 1.66"; 2-7/8" L-80; N-80; 2,339 ; 5,490'; Packers and SSSV Type: Baker FH Packer pop Packers and SSSV MD (ft): 2,386' y~. 12. Attachments: Description Summary of r po I 13. Well Class after proposed work: Detailed Operations Program ^ B Sket Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: ~ Commencing Operations: ~~ 5!12/2008 Oil ^ Gas 0 Plugged ^ Abandoned ^ 16. Verbal Approval: Dat :~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true d correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Branden rg Title Drilling Manager Signature ~ hone 907-276-7600 Date 5/5/2008 COMMISSION USE ONLY ~~~ f'~- ~3 vow` Conditions of approval: Notify Co fission so that a repre; Sundry Number: ~ .. ~ / ~lvr~e_ x ~rc.c 5 , 7; Plug Integrity ^ OP Test ^ Mect ~4t4~ ~ ~' j~~' Clearance ^ ~ u.~.+~.~. ~(y/~.GN Other: 'To ~ Gy l • ~~ 3 Subsequent Form Re fired: ~~~,L~4.t,f ~ " i~ «/( , s ` ~" . ~ 117 r~r.u~ ,.,'PROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ' og Form 10-403 Revised 07/20 ~ ~ ~ ~ Through Tbg Gravel Pack with CT Submit in Duplicate Chevron ~ • Lewis River Well # LR C-O1RD 5/5/08 OBJECTIVE: • Perforate~te Beluga Sand. / PROCEDURE SUMMARY: • Rig up slickline. Run 1.80" gauge ring to 5000'. Bail fill if necessary. • Rig down and de-mobe slickline. • Rig up E-Line. Perforate the Beluga Sand from 4679' to 4689' (+/-) and from 4747' to 4759' (+/-). • Rig down and de-mobe E-Line. ~,R C-01 RD REVISED BY: BCA 5/5/08 Chevron • Lewis River Well C-lyd Current as of 9/08/06 Notes: TTS GP Packer takes a TTS 2-7/8" Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Sluny below GP Packer @ 2 ppg Sand out @ 1,750# above Injection Rate @ 1 /2 BPM (INJECTION RATE = 2500 prig) Pumped 59.25 PPF into Perfs Tunnels & covered 16' of Blank Tubing Posis TOC Max Hole Angle = 18 degrees at TD ' LRU_C 1 rd_Current 9-08-06.doc Updated on 10/24/2006 BY: SLT Chevron ~ • Lewis River Well C-lyd Proposed sisios RKB = 16.5' recrNC ANTI TI1AINr ncT• ^r SIZE WT -- - GRADE CONK au ~ !1l L ID TOP BTM 20" - _ . 13-3/8" 54 5 - 75' . Surf 368' 9-5/8" " 47 Surf 2 409' 7 26 & 29 29# window Surf , 2650' 5" 15 L-80 Butt 4.408 2,454' 6 461' Tubin , 2-7/8" 6.4 N-80 Butt SCC 2.441 Surf 5490' 1-1/4" 2.3 L-80 CS H dril 1.380 Surf 2,339' I F'WGI AV IICTAii NO. De th Len th ID OD ~ ~. Item 16.5' Dual Tubin Han er, 2-7/8" x 2-3/8" DCB 9" SM 1. 2386' 2.875 6.059 BAKER FH PACKER 2. 2377' ' 18' 1.875 2.25" TTS/Owens Tbg Patch 2395 RI OD 3. 2428' 2.310 2.875 "X" Nipple 4. 2446' ' 10' 1.875 2.25" TTS/Owens Tbg Patch 2456 RI OD 5. 2467' 4.25 5.25 HMC/ZJ(P Liner Hanger and Tieback Sleeve & SEALS Gravel Pack Completion All de the are referenced to Eline Tie-in to Schlumb "Com letion L "dated 7/102 1.94' 1.38 2.25" T.T.S. 2-7/8" Anchor Latch / 2-3/8" PBR Assy. A. 5440' 3.94' 1.75 228 T.T.S. Gravel Pack Packer w/1-112" NU Pin & 2-1/2" TTS internal Fishing Neck 11.44' 1.75 2.20 MOE w/1-1 /2" NU 10RD Box x Box B. 5457' 332.81' 1.61 1.90 (10 Jts) Blank Tubing with 1-1/2" NU 10RD Pin x Box w/ XO's screen 18.05 5790' Tos ' 2.54 1.375 2 06 (4 Jts.) BJ "CoilFlow DB" Screen w/ (2) Bow Spring Centralizers 5833 eos Screen 22.08 . Spaced 20' apart. w/ 1 '/." NU 10RD Bonn. 2.54 5850' 30.16' 1.38 2.06 (2 Jts.) BJ Pro Weld Screen .008 Gauge 1-1/4" NU 10RD P x B C~ 5868' Tos ' 2'54 screen 13.08 1.375 2 06 (1 Jts.) BJ "CoilFlow DB" Screen w/ Bow Spring Centralizers 5881 eos 2.54 . top and bottom. w/1 '/." NU 10RD Conn. 5883' Tos ' 119.09' 1.38 2 06 (8 Jts.) BJ Pro Weld Screen .008 Gauge 1-1 /4" NU 10RD P x B 6003 aos . w/ (3) bow spring centralizers, spaced ever 30' 6005' Tos ' 2'54 screen 13.09' 1.375 2 06 (1 Jts.) BJ "CoilFlow DB" Screen w/ Bow S rin Centralizers P 9 6018 sos 2 54' . top and bottom. w/1 '/." NU 10RD Conn. 6021' 0.41' 2.05 Combination Bull Plug w/1-1/2" NU 10RD p. 6021' 1.25' 2.28 RBP Pulling Tool 6022' 6026' btm g gg~ 2,2g TTS Retrievable Bridge Plug Notes: TTS GP Packer takes a TTS 2-7/8" Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Slurry below GP Packer @ 2 ppg Sand out @ 1,750# above Injection Rate @ 1/2 BPM (INJECTION RATE = 2500 psig) Pumped 59.25 PPF into Perfs Tunnels & coveed 16' of Blank Tubing PERFORATION INTERVAL P~ Ti Interval Accum. Date Zone Top Btm Amt spf Comments 12/11/2001 2,449' 2,450' 1' 4 TBG PUNCH °"'' Belurta 4.679' -4_r,~~a' ;n' g Pro osed ''''' Belu~,a -1J-tT -1,79' 12' R Pro osed 7/]5/2002 8/11/06 58-0 5,800' 5,818' 18' 12 2" PJ HC, 2" PJ Omega 7/15/2002 8/11/06 58-0 5,872' 5,880' 8' 12 2" PJ HC, " 2 PJ Omega 8/11/2006 60-2 6,021' 6,026' S' 12 Perfto 5' of60-2 sand. LRU_Clyd_Proposed 5-5-08.doc Updated on 10/24/2006 BY: SLT Max Hole Angle = 18 degrees at TD Chevron F• Cisco Castro Chevron North A•ica Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: FCBN@chevron.com December 3, 2007 To: AOGCC Howard Okland 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 PERMIT # API NUMBER WELL LOG TYPE SCALE LOG DATE INTERVAL RUN B- FILM CD NOTES - i ~Ouv~D # ! ~i'';E LAS, ~ ~ j PDS, COMPLETION RECORD HALLIBURTON 175-005- BRIDGE PLUG, 2000 - 0 502832004700 LRU 1A CEMENT RETAINER 5" 1-Se -06 3911 1 1 1 1 PDS COMPLETION 178-U%5- RECORD TTS 2 7/8" 2280 - 0 502832996101 LRU C1 TUBING PATCH 5" 8-Se -06 2550 1 1 1 1 PDS COMPLETION RECORD 2" POWERJET OMEGA 175-005- 6 SPF, 60 DEGREE 2500 - 0 502832004700 LRU 1A PHASED 5" 9-Se -06 2750 1 1 1 1 PDS COMPLETION RECORD 2" POWERJET OMEGA 6 SPF 2 7/8" TTS 201-168- LRU RETRIEVABLE 11-Aug- 5600 - 0 502832006101 C1RD BRIDGE PLUG 5" 06 6013 1 1 1 1 PDS ~~,IN DEC ~. ~ 2Qt~7 moo! - l~ ~ ~ is ~3~ Please acknowledge receipt by signing and returning one copy of this tra`ns~~iittal or,FAX to 907 263 7828. Receive Date: ~~ ~- . . Chevron === Kellin A. Tabler Manager, Land & Government Affairs MidContinent! Alaska Chevron North America Exploration and Production 909 West 9th Avenue P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7600 Fax 907 263 7698 Email tablerk@chevron.com February 13, 2007 Mr. Kevin Banks, Acting Director Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 800 Anchorage, AK 99501-3560 LEWIS RIVER UNIT SCANNED MAR 2 9 2007 STATE OF ALASKA REVISED THIRTY-SECOND PLAN OF DEVELOPMENT AND OPERATIONS Dear Mr. Banks: Pursuant to the current State of Alaska regulations governing submittal and approval of Unit Plan of Development and Operations, 11 MC 83.343/11 MC 83.346, Union Oil Company of California, a Chevron company, as Unit Operator, submits the following Revised Thirty-second Plan of Development and Operations for the Lewis River Unit Area: 1. PERIOD This Plan shall cover the period from May 7, 2007 to May 6, 2008. II. WELL WORK REVIEW A. THIRTY-FIRST PLAN REVIEW ~ \~5-aOS- LRU 1-A was recompleted and flow tested at 2.4 MMCFPD in September 2006. The well was shut-in for the winter. Facility modifications are needed prior to putting this well onto production. ~ ~O\-\<o~ A thru-tubing gravel pack was installed in August 2006 in LRU C-1RD. Attempts to swab in the well were terminated in October 2006. The well would not maintain flow. B. THIRTY-SECOND PLAN POTENTIAL WORK Well C-1RD will be evaluated for an acid stimulation to remove formation damage that may have occurred during the installation of thru-tubing gravel pack. The acid stimulation may occur during the Thirty-second plan period. Development of the Belüga and Tyonek potential in the Lewis River ünit wiii depend on the results of additional flow testing of the LRU 1-A in early spring 2007, and the possible drilling of a new well in 2008/2009. Union Oil Company of California I A Chevron Company http://www.chevron.com . . Mr. Kevin Banks, Acting Director February 13, 2007 Page 2 Lam:! Term Development Plan Due to the remote location of the gas fields on the west side of the Cook Inlet, a winter drilling program may strand a drilling rig on the west side for the winter. The economics of the development opportunities at the west side properties cannot support the added cost of winter time, remote location drilling, and the high cost of having a drilling rig and all its ancillary equipment on standby for months. If a large enough work program can be developed and we determine that it can be safely and economically implemented through the winter months, we may be able to overcome the added burden that the ADF&G work season restriction presents. Union is working on a west side drilling/workover program that would include project(s) at the Lewis River Unit. Any drilling program on the west side of Cook Inlet must coordinate with drilling activity anticipated at other nearby west side fields. No one Unit alone can absorb the mob, demob and standby cost incurred by a stand alone operation. The largest gas field on the west side is the Beluga River Unit. It is anticipated that a rig will be mobilized to conduct in-field drilling activities in this Unit in the 2008/2009 timeframe, which would be the earliest that drilling activity is contemplated on the west side. With this activity, there may be an opportunity to utilize this rig in conjunction with other drilling activity on the west side. The timing of the Beluga River Unit drilling activity is expected to coincide with the Beluga River operator's market requirements. Regardless of the activity at the Beluga River Unit, Union's multi-well, multi-unit west side development program evaluation has a similar timing profile, e.g., planning will occur in 2007 with budgeting/drilling in 2008-2009. Market conditions will have the biggest influence and ultimately dictate drilling activity on the west side. Whether or not Agrium can secure a sufficient volume of gas to maintain seasonal operation of its Nitrogen Fertilizer Plant, the outcome of Marathon and ConocoPhillips LNG export license extension application and commitments to the unfilled utility markets are the market unknowns at this time. The range of possible outcomes of these events alone will have a significant influence and impact on the timing of any west side development thus, making long range commitment forecasting difficult at best to plan. Union Oil Company of California I A Chevron Company http://www.chevron.com . Mr. Kevin Banks, Acting Director February 13, 2007 Page 3 III. PRODUCTION PLAN . Cumulative Gas production from Lewis River Field for the period January 1, 1991 through December 31, 2006 is as follows: Date Mo-Yr 12/31/91 12/31/92 12/31/93 12/31/94 12/31/95 12/31/96 12/31/97 12/31/98 12/31/99 12/31/00 12/31/01 12/31/02 12/31/03 12/31/04 12/31/05 12/31/06 LRU 1-A MMCF 1,831 2,384 2,696 2,884 2,984 3,070 3,115 3,201 3,435 3,560 3,731 3,858 3,930 3,965 3,965 3,965 LRU C-l(& RD) MMCF 5,238 5,390 5,461 5,516 5,543 5,571 5,592 5,608 5,620 5,628 5,679 6,449 6,952 7,286 7,610 7,628 Total MMCF 7,069 7,774 8,157 8,400 8,527 8,641 8,707 8,809 9,055 9,188 9,410 10,307 10,882 11,251 11,575 11,593 The Lewis River D-l well is shut in and is not expected to be used for water disposal during the upcoming plan period. Injection to date is as follows: Date Year 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 Union Oil Company of California I A Chevron Company Yearly Inj. BBLS 4,601 3,144 4,203 2,578 2,769 6,571 4,321 1,839 1,173 2,408 1,481 2,486 993 1,672 o o Days on Inj. Per Year 67 21 34 58 32 78 36 20 20 34 32 67 24 70 o o http://www.chevron.com . . Mr, Kevin Banks, Acting Director February 13, 2007 Page 4 IV. SURFACE AND FACILITY OPERATIONS A. THIRTY-FIRST PLAN REVIEW Unocal was notified by the Alaska Department of Environmental Conservation (Solid Waste Program) that all post closure water quality monitoring requirements for the Lewis River 13-2 reserve pit had been met and no additional water quality monitoring was required. B. THIRTY-SECOND PLAN POTENTIAL WORK Due to the successful recompletion of LRU i-A, during the Thirty-second plan period, engineering will be completed to determine the necessary facility work to return this well to production. This work may include the installation/replacement of facilities such as compression, dehydration, piping and tanks during this plan period. Such work is contingent upon the results of additional flow testing of this well in early spring 2007. Union, as Unit Operator, reserves the right to propose modifications to this Plan should conditions so warrant; however, no modifications will be made without first obtaining permission from the appropriate governmental agencies. Very truly yours, UNION OIL COMPANY OF CALIFORNIA By: K n A. Tabler Manager, Land & Government Affairs APPROVED: ALASKA DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas This day of , 2007 By: KAT:GAO:dma cc: Gary Orr, CVX Daniel T. Seamount, AOGCC Dave Whitacre, CVX Union Oil Company of California I A Chevron Company http://www.chevron.com A STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMaN REPORT OF SUNDRY WELL OPERAW'ONS measured 6,469' feet true vertical ~. ~ 38ý"feet measured 6043 _ fee~~ true vertic~ f'17'i' feet 1 . Operations Abandon Performed: Alter Casing 0 Change Approved Program 0 2. Operator Name: Repair Well Pull Tubing 0 Operat. Shutdown 0 Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 16.5 8. Property Designation: H\ If. i.ð{, Lewis River ApI.. ~ß7f(t> ~ 11. Present Well Condition Summary: Total Depth Effective Depth RECEIVED NOV 0 8 2.006 Stimulate A\a*" I WaiverD Time Extension 0 Anchor«tOG Re-enter Suspended Well 0 5. Permit to Drill Number: 201-168 . 6. API Number: 50-283-20061-01 . 9. Well Name and Number: Lewis River Unit C-01 RD 4 10. Field/Pool(s): Lewis River FieldlTyonek h Plug Perforations Perforate New Pool 0 Perforate 0. 4. Well Class Before Work: Development 0 Stratigraphic 0 Exploratory 0 Service 0 ~(i ¡r,~ ttc."4 ç;,~ ¡ill> /f. ~'Crp Plugs (measured) 6043 Junk (measured) TVD Burst Collapse 75' 0 0 368' 2,730 psi 1 ,130 psi 2,408' 4,720 psi 3,880 psi 2,649' 4,980 psi 4,320 psi 6,437' 8,290 psi 7,250 psi 7~ .,',. .)" Casing Length Size MD Structural Conductor 75' 20" 75' Surface 368' 13-3/8" 368' Intermediate 2,409' 9-5/8" 2,409' Production 2,650' 7" 2,650' Liner 4,007' 5" 6,461' Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 000 267 0 0 15. Well Class after work: Exploratory 0 . 16. Well Status after work: Oil 0 Gas 0 ' WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Perforation depth: Measured depth: 2,450 to 6,042' True Vertical depth: 2,449 to 5,978' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Operation Summary Contact Steve Tyler 907263-7649 Printed Name Tim Brandenburg Signature Form 10-404 Revised 04/2006 1-1/4" Heat Strg 2-7/8" Tbg 2,200' 5,490' L-80 N-80 BOT "FH" Pkr 2,386' Tubing Pressure 500 100 Development 0 . Service 0 GINJ 0 WINJ 0 WDSPL Sundry Number or N/A if C.O. Exempt: 306-150 o Title Drilling Manager Phone 907263-7657 Date 11/2/2006 1i.'J.;O...·D···. "II.·."".. B. F' , "IÇ~ .Wl\.')· . l 9 2005 /1. .0' 7;;W~IY LRU C-01 RD' Primary Jeb Type Clean-Out Jobs Primary Jeb Type Clean-Out Daily Operations 5121/2006 00:00 - 5/22/2006 00:00 Operatens Summary RU Slickline, bailed from 3843' t03897'. Total of 12 bailer runs. One flapper failure run, the remaining had 3/4 full to full bailers with solids or sand. 5/22/2006 00:00 - 5/23/2006 00:00 .:: Operatens Summary ,~~ PJSM. RU slickline. RIH and found sand back up to 3851', bailed down to 3906'. Ran 11 bailer runs. Sand was moist. RD Slickline. Lost 30' from , yesterday's bailing operation but cleaned out 60' today getting a 30' gain. 5/2312006 00:00 - 5/24/2006 00:00 Operatens Summary PJSM RU slickline. RIH with 2.25"x 4' DD bailer to 3888' (28' high of previous night). Bailed to 3947' RKB. (11 bailer runs) RD slickline, secured well and .' turned well over to production. 7/27/200607:30 -7/28/2006 00:00 Operatiens Summary Mobing equipment out to West Side. 7/28/200600:00 - 7/29/200600:00 Operatens Summary Mobing equipment out to West Side. .7129/200600:00 - 7/30/200600:00 ':, Operatens Summary · Mobing equipment out to West Side. 7130/200600:00 - 7/31/2006 00:00 Operatens Summary Mobing equipment out to West Side. Addressing water well issues. ~ 7/31/200600:00 - 8/1/200600:00 :; Operatens Summary ": Mobing equipment out to West Side. Dealing with water well issues, and Generator electrical hook ups. Prepping location for coil, gas buster and tanks. 8/1/2006 00:00 - 8/212006 00:00 · Operatiens Summary Mobing equipment to location. Electical panel issue. 8121200600:00 - 8/3/200600:00 Operatens Summary Held SIMOPS meeting. Continuing to prep pad. Waiting on repair of electric panel. 8/3/2006 00:00 - 8/4/2006 00:00 Operatens Summary PTMS and SIMOPS. Waiting on electric repair of the generator. 8/4/2006 00:00 - 8/5/2006 00:00 Operatens Summary PTSM and SIMOPS. Pre spud and bear avoidance training. Coil tubing turnkey rig up. · 8/5/2006 00:00 - 8/6/2006 00:00 ~: Operations Summary < Continue turn key rig up of coil tubing unit 8/6/200600:00 - 8171200600:00 Operatiens Summary Finished coil tubing turn key rig up. Completed coiled tubing unit acceptance checklist. Put coil crew on standby waiting for electrical generation installation. 8171200600:00 - 8/8/200600:00 Operatiens Summary Mobing equipment. Waiting on electicians. .:: 8/8/2006 00:00 - 8/9/2006 00:00 Operations Summary Continue stand by for coil crews while waiting on electrical work. Continue to mobe and prep for all westside work. :. 8/9/2006 00:00 - 8/10/2006 00:00 Operations Summary Electric issues repaired. Mobe out Zylene trucks. Prep coil to start in AM. '. Daily Operations 8/1012006 00:00 - 8/11/2006 00:00 Operatens Summary Conducted JSA's. MU CO BHA. RIH with CT Dry tag @ 3862'. RI cleanout fill, taking small bites of 30 to 65 ft until clean @ 4500'. Reduce pump rate, RI @ 50 fUmin to EaT at 5500'. Continued RIH, tagged fill @ 5852'. Cleanout fill from 5852 to 6009'. No further progress past 6009'. CBU. POOH. LD BHA. RD injector head and secured operation. 8/11/200600:00 - 8/12/200600:00 Operatiens Summary SIMOPS/Safety/Pre job. Pressure tbg.csg annulus to 2500 psi. Good test. RIH with 2" Power Jet Omega guns, loaded 6 SPF, @ 60 degree phasing. Perforated 6021' to 6026' (gained 100 psi wellhead pressure), perforated 5873' to 5881' and 5801' to 5819'. RIH and tagged bottom at 6026'. Arm and PU TTS retrevable 2.28" bridge plug. Noted fluid level at 400 ft. Set top of bridge plug at 5475'. POOH and perform negative test on bridge plug, bled off 70 Ibs of wellhead pressure. Fill tubing with fluid for positive test. 8/1212006 00:00 - 8/13/2006 00:00 Operatens Summary Finish filling tbg with 9% KCL. Test bridge plug to 500 psi. Secure well. PJSM/SIMOPS. Layout Gravel Pack and assembly and prep. RU coil crew. Pump 10 bbls of inhibited 15% HCL followed with 10 bbls 9% KCL water and chased with 10 bblswater with soda ash. PU and run Thru Tubing Systems gravel pack assembly. 8/13/200600:00 - 8/14/2006 00:00 Operatens Summary PU injector head and make up running tool. Latch gravel pack assembly. RIH 100'. PJSM/SIMOPS. Open choke. RIH engauge bridge plug at 5453' ctm. Pick ; up 1200# over and let well equalize. PU 5' and release bridge plug. RIH, tag bottom at 6025.7' CTM. PJSM and launch 1/2" ball over gooseneck. Returns at . 11.5 bbls pumped. Ball on seat at 13.4 bbls away. Pressured up to 4550 psi and shear ball seat. Lock in pressure and monitor of packer test. Pump 44 bbls of 20/40 sand slurry wI HEC breaker. Achieved sand out at 1750 psi at .5bbls/min. Results 59.25 Ibs/ft in perfs and 15 ft up on btm blank joint. Circulated well clean with 70 total bbls, recovering 16 bbls of sand slurry (indicates 28 bbls of slurry below tool). Start N2 at 1200 SCFM. Noted tbglcsg annulus pressure dropped from 2280 psi to 300 psi during N2 pump sewquence. Attempt to unsting gravel pack seal assembly to trap 1400 psion wellbhead. Bring N2 online, establish circulation, and observed diesel in returns. Started circulating 9% KCL down coil while filling wellbore with 9% KCL. Pumped hi-vis pill and as pill rounded corner pulled up-strain freed pipe. POOH at maximum circulating rate. No solids in returns. 8/14/2006 00:00 - 8/15/2006 00:00 Operatiens Summary Lay down BHA and secure well. 8/24/2006 00:00 - 8/25/2006 00:00 Operatiens Summary ND Adapter plate from CT Work. Pull BPV from SS. Secure well. 8/25/200600:00 - 8/26/2006 00:00 Operatens Summary Operations Suspended. Capture rental tool costs 8/26/200600:00 - 8/27/2006 00:00 Operatiens Summary Operations Suspended. Capture rental tool costs 8/27/200600:00 - 8/28/2006 00:00 Operatiens Summary Operations Suspended. Capture rental tool costs 8/28/2006 00:00 - 8/29/2006 00:00 Operatiens Summary Operations Suspended. Capture rental tool costs 8/29/2006 00:00 - 8/30/2006 00:00 Operatiens Summary Operations Suspended. Capture rental tool costs. Operations Suspended - LS = 450 psi - Heater string = 420 psi - Tbg X Csg annulus = 350 psi - 13-3/8" X 9-518" = zero & surface csg + zero 8/30/200600:00 - 8131/2006 00:00 Operatiens Summary Operations Suspended. Capture rental tool costs. LS = 450 psi - Heater string = 420 psi - Tbg X Csg annulus = 350 psi - 13-3/8" X 9-518"= zero & surface csg=zero Had SLB crew wI crane trk re-install well house over well LRU C-01 RD Daily Operations '·8/31/200600:00 - 9/1/200600:00 :. Operatiens Summary Operations Suspended. Capture rental tool costs. LS = 450 psi - Heater string = 420 psi - Tbg X Csg annulus = 350 psi - 13-3/8" X 9-518" = zero & surface csg=zero 9/1/2006 00:00 - 9/2/2006 00:00 Operatiens Summary Operations Suspended. Capture rental tool costs. LS = 450 psi - Heater string = 420 psi - Tbg X Csg annulus = 350 psi - 13-3/8" X 9-518" = zero & surface csg=zero Had Peak suport crew clean pad 9/2/2006 00:00 - 9/312006 00:00 Operatens Summary LS = 450 psi - Heater string = 420 psi - Tbg X Csg annulus = 350 psi - 13-3/8" X 9-518" = 0 & surface csg = 0 PJSM. RU Slickline. RIH wI TTS pkr plug on 2-7/8" anchor. Set in GP pkr @ 5447'. POOH. RD. 9/3/2006 00:00 - 9/4/2006 00:00 Operatiens Summary Lubricate and bleed 37.5 bbls of 9% KCL. Starting pressure 350 psi annulus, 510 psi tbg. Pump at .5 BPM rate. Ending pressures 640 psi annulus and 330 psi tubing 9/4/2006 00:00 - 9/512006 00:00 Operatiens Summary Csg @ 550 psi, TP at 445 psi. Production bled gas from well. TP fell to 50 psi. Csg fell to 70 psi 9/5/2006 00:00 - 9/6/2006 00:00 Operatiens Summary Csg @ 148 psi; TP @ 100 psi PJSM. Test lines. Pump 21 bbls of 9% KCL. Final pressures Csg 480 psi; TP @ 320 psi. (Total Fluid pumped = 58.5 bbls) 9/612006 00:00 - 91712006 00:00 Operatiens Summary Tbg=370 psi Csg=510 psi SIMOPS & PJSM. Lube & bleed 61 bbls of 9% KCI. Tbg & csg =0 psi. Jug test well to 1000 psi. Bled to 200 psi in 2 min. repaired leak @ surface. Retest multiple times. 200 psi pressure lose over a 2 min period. SDFN. 91712006 00:00 - 9/8/2006 00:00 Operatiens Summary SIMOPS & PJSM. Slickline convey tbg stop & pack-off. Set @ 2554' (87' below ZXP Tie-back). Jug test wellbore to 1000 psi for 30 min. OK. Retest stop and pack-off @ 2375' (10' above pkr). pressure test tbg to 1500 psi for 30 min. OK. Retrieve plug & stop. RD. 9/8/2006 00:00 - 9/9/2006 00:00 Operatens Summary SIMOPS & PJSM. Displace 13 bbls of fluid out of tbg with N2. RI wI Eline, set tbg patches @ 2446'-2456' and 2377' -2395'. RD Eline. Pressure test tbg x csg annulus to 2500 psi. RIH wI slickline, retrieve pkr plug @ 5442'. SDFN 9/9/200600:00 - 9/10/2006 00:00 Operatiens Summary : Demobe equipment to barge landing. Attempt to surge well on. No Joy. Continue to clean well sites. 9/10/200600:00 - 9/11/200600:00 Operatiens Summary Continue with well site clean up. Back load equipment to dock. 9/11/200600:00 - 9/121200600:00 Operatiens Summary Continue cleaning pad. Hual fluids to injection well @ Ivan. 9/1212006 00:00 - 9/13/2006 00:00 Operatens Summary Continue cleaning pads. 9/13/200600:00 - 9/14/200600:00 Operatiens Summary Moving fluids to Ivan pad for injection. Daily Operations 9/14/200600:00 - 9/151200600:00 Operatiens Summary Load out barges. 9/15/200600:00 - 9/16/2006 00:00 Operatiens Summary · Load out barges · 9/161200600:00 - 9/17/200600:00 · Operatiens Summary , Final barge loaded. Final report. RKB= 16.5' 20" 75' 13-3/8" 54.5 368' 9-5/8" 47 2,409' 7" 26 & 29 2650' 5" 15 L-80 Butt 6,461 ' Tubin 2-7/8" 6.4 N-80 Butt SCC 2.441 1-1/4" 23 L-80 CS H dril 1.380 EOT @ 5490'. 5800-5818 5872-5880' 6022-6042' Posiset plug @ 6053' Toe@ 6043' TD 6,469' TVD Max Hole Angle = 18 degrees at TD LRU Clrd Current 9-08-06.doc NO, 16.5' 1. 2386' 2.875 2. 2377' 18' 1.875 2395' 3. 2428' 2.310 4. 2446' 10' 1.875 2456' 5. 2467' 5440' NU Notes: TTS GP Packer takes a TTS 2-7/8" Pulling Tool Pinned for 4,800# Release SLB Pumped 28 BBLS of 20/40 Sand Shmy below GP Packer @ 2 ppg Sand out @ 1,750# above Injectíon Rate @ II2 BPM (INJECTION RATE ~ 2500 psig) Pumped 59.25 PPF into Perfs Tunnels & covered 16' of Blank Tubing Date 12/11/2001 7/15/2002 8/11/06 7/15/2002 8111/06 8/11 12/9/2001 10/22/2001 Zone Comments 18' 12 58-0 8' 12 5' 16' 38' e e FRANK H. MURKOWSKI, GOVERNOR AI/ASHA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, AK 99519 Re: Lewis River Field, Tyonek, C-O 1 RD Sundry Number: 306-150 d-,{) \; \ b q; ,>c., Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thiSzg day of April, 2006 Encl. 073 4/28/:6 _ STATE OF ALASKA _ Ý .I~Gkjo ALA. OIL AND GAS CONSERVATION COMM.ON fA:" Cf}-'f/vu/" APPLICATION FOR SUNDRY APPROVALS I.-\¡:ì-~ 20 MC 25.280 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U Waiver U Other ~ Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Through Tbg Gravel Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D Pack with Coil Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 . Exploratory D 201-168 { 3. Address: Stratigraphic D Service D 6. API Number: PO Box 196247, Anchorage, AK 99519 50-283-20061-01 . 7. KB Elevation (ft): 9. Well Name and Number: >;;..... ,(. oc' '?~". 16.5' Lewis River Unit C-01 RD . 8. Property Designation: 10. Field/Pools(s): :; t' ;.! . East Lewis River Lewis River Field/Tyonek /'11;';;'::4,; 11. PRESENT WELL CONDITION SUMMARY " ·.·.t·...,..;"! .. Total Depth MD (ft): Total Depth TVD ~ Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured):- ............... Junk (measured): 6,469' "'5f>~ o(.Z'o'~ ¡.. 6,043' 6,023 6,043' Casing Length Size MD TVD Burst Collapse Structural 75' 20" 75' 75' Conductor 368' 13-3/8" 368' 368' 2,730 psi 1,130 psi Surface 2,409' 9-5/8" 2,409' 2,408' 4,720 psi 3,880 psi Intermediate 2,650' 7" 2,650' 2,649' 4,980 psi 4,320 psi Production 4,007' 5" 6,461' 6,437' 8,290 psi 7,250 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2,450 to 6,042' 2,449 to 5,978' 1-1/4"; 2-7/8" L-80; N-80; 2,200'; 5,490'; Packers and SSSV Type: Baker FH Packer Packers and SSSV MD (ft): 2,386' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/3/2006 Oil D Gas 0 Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature 7 ~C^_~:::::::':--Phone 907-276-7600 Date Lf - 2&. Ob ¿J' /7' COMMISSION USE ONLY po Sundry Numberë -1J Í:7 . /C{O Conditions of approval: Notify Commission so that a representative may witness ....,. Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D Other: ~ ()CC) Q~' ,~\,,\ M..~..., ~C)\> -\e'>~ RBDMS 8Ft MA V (\ ] 2006 Subsequent Form Required: ~\a((j~ COMMISSIONER APPROVED BY 4-71" Dk> Approved by: THE COMMISSION Date: V~~ -. ~ t{·2'·~ . . Form 10-403 Revised 07/2005 Thm"9hTbg G,,~I ea,'''' CT 0 RIG I N A L s*~~ e e Lewis River Unit LRU CIRD Reperfing existing zones and gravel packing ,¡ ~ MIRU Slickline Unit. Bail Fill to TOC @ 6043' ~ MIRU Eline. RIH Reperf all three intervals. - ~ PUMU TTS Ret Bridge Plug. RIH set bridge plug @ 5480'. POOH. RD. ~ MI Spot CT Unit. Tumkeyed RU Mobe. ~ Tumkeyed Mobe. Test CTC & BOPE ~ Accept CT unit. PUMU Screen & GP Equip. ~ MU CT to GP Equip. RIH Latch PT into BP. Release BP. Continue RIH. Set GP pkr @ 5480'. Circ/Sqz Gravel till pack-off is obtained. Reverse excess gravel out. Dry well out wI N2. POOH. ~ Tumkeyed De-Mobe. RKB = 16.5' Note: Tubing spool is odd with 9"5M top. (S. Lawrence 04/01) 13-3/8" 54.5 Smface 368' 9-5/8" 47 T' 26 & 29 29# 5" 15 L-80 Butt Tubing 2-7/8" 6.4 N-80 Butt see 2.441 surface 1-1/4" 2.3 L-80 es Hydril L 2. 3. 4. 2340' 2386' 2428' 2467' 2.310 2.875 2.310 4.25 4.13 6.059 2.875 5.25 CMU Sliding Sleeve BAKER FH PACKER "X" Nipple HMC/ZXP Liner Hanger and Tieback PROPOSED PERFORATION INTERVAL Accum. I 18' 8' END OF TUBING @ 5490'. Top offill suspected to be above top of perfs Last SL Tag on 11/08105 @ 5824' PERFS @ 5800-5818 and 5872-5880' (7/15/02) and 6022-6042' (12/9/01) Posìset plug at 6053 and cement top at 6043' Max Hole Angle = 18 degrees at TD TD = 6,469' TVD LR Clrd 091902 DRAWN BY: JIM RKB = 16.5' EOT @ 5490', Posíset plug @ 6653' Toe @ 6043' TD = 6,469' TVD Max Hole Angle = 18 degrees at TD LR_ C 1 rd _Proposed 20" 13-3/8" 9-5/8" 7" 54.5 47 26 & 29 15 Butt 29# window 4.408 L-80 6.4 2.3 N-80 L-80 Butt see es H dril 2.441 1.380 2340' 2.310 4.13 2386' 2.875 6.059 2428' 2.3]0 2.875 4. 2467' 4.25 5.25 Date ] 0/22/2001 ]2/9/2001 1 7/15/2002 7/15/2002 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc C( J^",,- Á~Q~ DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2011680 Well Name/No. LEWIS RIVER UNIT C-01RD Operator UNION OIL CO OF CALIFORNIA jp~ ;;;." J~~ l API No. 50-283-20061-01-00 MD 6469 ",/ TVD 6384 -- Completion Date 12/9/2001 ~ Completion Status 1-GAS ._- ------- - --- - ----. --- Current Status 1-GAS UIC N REQUIRED INFORMATION Mud Log No Samples No -~--.------_._- .-- Directional Survey - - ~ _/~' -- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log! Electr Data Digital Dataset Type M_ed/Frmt Number Na Log Log Run Scale Media No 5 BM 1 Interval Start Stop 5300 5975 (data taken from Logs Portion of Master Well Data Maint) --. OH/ CH Received Comments -- -.- - - ---- - Case 10/3/2002 2" HSD Powerjets i ;< 2Jfh:t .~-~ t - Well Cores/Samples Information: Sent Received Sample Set Number Comments Name Cuttings Interval Start Stop 2684 6469 1105 -~_.__. ¡ -. - - -- _J ADDITIONAL INFORMATION Well Cored? Y @ Daily History Received? ÐN Ø/N Chips Received? Y " N t Formation Tops Analysis Received? Y/N .. --- ---- /----- - ---- . - . Comments: ~~ \)~>,W--- ~~~. 'D~ rJ\--l '\..,.~ l.('~ ~ ~u ~~. r~- \N"'-.:tl\.~ ,ß-tv \~"'1'~JU--. ~ U/I\\I ~ q J,^-~ '-I C hGlJ-VL'.(¡,^- b ~ lAV1Uc..J. C~1n-\ ) \) ~ ~ C\.J wv }JjJ\ V\ t ~-..),t ~-1 .... C. \ Ji< ~ ,\ "=É Compliance Reviewed By: ~ (ù~'\-- ~ ~IJ) \)~\ col-¿ ~ ~ (C9 ~ ^-'~ r.... ~ '-t,J'-~ ýJ f ^ . A-.".~ r~ L...&~. '-- (N I»}",~ OtM¡~ÝÌ- Þ' (g yZ À- '-'l\ r - \:>"i}'-à '\vlì~') l \'~~; ~ l ~( u.J yt l~ \¡ \--~S \HJ ~~ ~ l ~ 'If r'è- ~ G 3 8 Có~ lt~~", ~ ), q ß-J /) ~~Jcl-f Þ\~ ~- ~ r~~J~~ (P~~tv. vtsp<f {Àll-MJrb ~$-pF- ~[J-¿~ (Ljl tl D~ ~C) l Date: --_.------- ---- ~~~~ -\-( ---.- .. (" ( a 0)- 11.0 '? .. . Unocal Alaska 909 w. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unocal.com UNOCALf> Beverly Harrison Business Ventures Assistant September 23, 2002 To: AOGCC Lisa Weerie 333 W. 7t Ave. Ste#100 Anchorage, AI{ 99501 DATA TRANSMITTAL - \0\ A-29RD ADN DIP DATA V'" 8/2/2002 12606-13220 1 B-Line A-29RD ADN DIP DATA V 8/2/2002 11950-12650 1 B-Line A-29RD ADN DIP DATA V 8/2/2002 12606-13220 1 CD A-29RD ADN DIP DATA V 8/2/2002 12029-12713 1 CD A-29RD CEMENT BOND LOG I GR I CCL V 2/5 INCH 81512002 5000-13211 1 B-Line . A-29RD CEMENT BOND LOG I GR I CCL v 2/5 INCH 8/512002 5000-13211 1 CD A-29RD CEMENT BOND LOG/GR/CCL V 2/5 INCH 8/512002 5000-13211 1 Film ~ A-29RD CEMENT RETAINER CASING PUNCHER V 5 INCH 1680-1999 1 B-Line 3 A-29RD CEMENT RETAINER CASING PUNCHER V 5 INCH 1680-1999 1 Film ~ A-29RD EPOCH FINAL WELL REPORTWI FORMATION LOG v 2 INCH 6130/2002 1786-13300 3 B-Line C6 A-29RD EPOCH FINAL WELL REPORT WI FORMATION LOG V 811/2002 1 CD a EPOCH FINAL WELL REPORT WI FORMATION LOG ý res A-29RD 8/1/2002 1 PAPER A-29RD MWD/GR MD COMPOSITE FIELD PRINT V 2 INCH 6/30/2002 1824-12685 1 Boline A-29RD PERFORATION DEPTH CONTROL MEMORY GR I CCL V 2 INCH 8/10/2002 12720-13240 1 B-Line A-29RD PERFORATION DEPTH CONTROL MEMORY GR I CCL v 2 INCH 8/10/2002 12720-13240 1 Film A-29RD PERFORATION RECORD 2 7/8" PJ HSD 6 SPF V 5 INCH 8/28/2002 13100-13207 1 B-Line -- ---- A-29RD PERFORATION RECORD 2 7/8" PJ HSD 6 SPF v 5 INCH 8/28/2002 13100-13207 1 Film A-29RD SCHLUMBERGER FORMATION EVALUATION LOGS v 8/2/2002 1 CD - A-29RD VISION SERVICE MD COMPOSITE FIELD PRINT V 2 INCH 6/3012002 1824-13300 1 B-Line - B-Line f k ~OO5 D-15RD2 PL ADVISOR I INJECTION PROFILE MEMORY PL T WIFLOVIEW v 5 INCH 3/17/2002 9150-10050 1 n~OhJ D-15RD2 PL ADVISOR I INJECTION PROFILE MEMORY PL T WlFLOVIEW v 5 INCH 3/17/2002 9150-10050 1 CD I DI-15 COMPLETION RECORD 2" HSD, POWER JETS v 5 INCH 5111/2002 11950-12555 1 B-Line (prO45 DI-15 COMPLETION RECORD.2" HSD, POWER JETS. v'" 5 INCH 5/11/2002 11950-12555 1 Film ~..OS1 DI-16 COMPLETION RECORD 2" HSD, POWER JETS ¡/ 5 INCH 5/9/2002 9800-1077 1 B-Line DI-16 COMPLETION RECORD 2" HSD, POWER JETS V 5 INCH 5/912002 9800-1077 1 Film ú) G-12RD3 COMPLETION RECORD 10' CEMENT PLUG V 5 INCH 6/2912002 13150-13608 1 B.Line [f) G-12RD3 COMPLETION RECORD 10' CEMENT PLUG ,/ 5 INCH 6/29/2002 13150-13608 1 Film 9 G-12RD3 COMPLETION RECORD 2.5" HSD PJ V 5 INCH 6/21/2002 13100-13696 1 B-Line iO i1 ., Please acknowledge receipt by signing and returning one copy of this transmittal or Received Date: oçr A/'!'::Ir..L.!J, .""~~ .'; """\ ç;i)i\~ ŸîÏ å baS l,OiW. CDmmiSSion Anchorage. - ( to . ~ G-12RD3 COMPLETION RECORD 2.5" HSD PJ / I 51NCH 6/21/2002 13100-13696 1 Film Q G-12RD3 COMPLETION RECORD POSISET PLUG 15' CEMENT v 5 INCH 6/27/2002 13150-13670 1 B-Line ~ G-12RD3 COMPLETION RECORD POSISET PLUG 15' CEMENT .,/' 5 INCH 6/2712002 13150-13670 1 CD G-12RD3 COMPLETION RECORD POSISET PLUG 15' CEMENT V 5 INCH 6/27/2002 13150-13670 1 Film 10~d51 K-30RD PERFORATING DEPTH CONTROL MEMORY GR / CCL v 5 INCH 218/2002 9544-12045 1 B-Line K-30RD PERFORATING DEPTH CONTROL MEMORY GR / CCL V"" 5 INCH 21812002 9544-12045 1 Film ~À\Dc;b LRU C-1RD COMPLETION REPORT 2" HSD POWER JETS ./ 5 INCH 7/15/2002 5300-5975 1 B-Line 0'" ;ý LRU C-1RD COMPLETION REPORT 2" HSD POWER JETS v 5 INCH 7/1512002 5300-5975 1 Film ~D..D-1 \ M-4 EPOCH MUD LOG v 2 INCH 10/31/1999 1473.ß430 1 B-Line M-4 EPOCH MUD LOG ./ 2 INCH 10/31/1999 1473.ß430 1 Vellum \D NNA-1 COMPLETION RECORD 2" HSD POWER JET v 5 INCH 4/3/2002 8600-9750 1 B-Line - NNA-1 COMPLETION RECORD 2" HSD POWER JET V 5 INCH 4/312002 8600-9750 1 Film ....... '~ NNA-1 GR / CCL CORRELATION FLUID LEVEL DETERMINATION v" 5 INCH 41212002 8600-9790 1 B-Line ~ ~ NNA-1 GR I CCL CORRELATION FLUID LEVEL DETERMINATION v" 5 INCH 4/212002 8600-9790 1 Film PEARL-1 COMPLETION RECORD 2" PJ HSD, 6 SPF V 5 INCH 3/2912002 5420-6066 1 B-Line PEARL-1 COMPLETION RECORD 2" PJ HSD, 6 SPF V' 5 INCH 3/2912002 3690-4250 1 B-Line PEARL-1 COMPLETION RECORD 2" PJ HSD, 6 SPF if 5 INCH 3/2912002 5420-6066 1 Film PEARL-1 COMPLETION RECORD 2" PJ HSD, 6 SPF v 5 INCH 3/29/2002 3690-4250 1 Film - PEARL-1 GR I CCL I PRESSURE I TEMPERATURE / TOP OF FLUID DETERMINATION V 5 INCH 3/28/2002 3550-6954 1 B-Line -- 0 PEARL-1 GR / CCL / PRESSURE I TEMPERATURE / TOP OF FLUID DETERMINATION ~ 51NCH 3/28/2002 3550-6954 1 Film ~ PEARL-1 GR I CCL / TEMPERATURE I PRESSURE / TOP OF FLUID, SAMPLE ,~ 5 INCH 3/29/2002 3550-6607 1 Boline PEARL-1 GR I CCL I TEMPERATURE I PRESSURE / TOP OF FLUID, SAMPLE ...~ 5 INCH 3/29/2002 3550-6607 1 Film <c) PEARL-1 GR / CCL TEMPERATURE, PRESSURE TOP OF FLUID, SAMPLE v 5 INCH 3/2912002 100-6948 1 B-Line PEARL-1 GR / CCL TEMPERATURE, PRESSURE TOP OF FLUID, SAMPLE v 5 INCH 3129/2002 1 00-6948 1 Film :do;;). SRU 12-15 COMPLETION RECORD 111/16" POWER PIVOT ./ 5 INCH 5/1612002 5400-5600 1 B-Line SRU 12-15 COMPLETION RECORD 111/16" POWER PIVOT ¡¡/ 5 INCH 5/16/2002 5400-5600 1 Film \~ SRU 12-15 COMPLETION RECORD POSISET PLUG 20' CEMENT PLUG / SINGH 3/1312002 4600-5642 1 B-Line SRU 12-27 CEMENT RETAINER CPST SETTING TOOL .r SINGH 612712002 5600-6346 1 B-Line {\ SRU 12-27 MD FIELD PRINT ,/" 215 INCH 6/29/2002 6044-6912 1 B-Line ,,\ SRU 12-27 NEUTRON I GR I CCL /' 215 INCH 6/26/2002 5600-6340 1 B-Line p SRU 12-27 NEUTRON / GR / CCL \/ 215 INCH 6/26/2002 5600-6340 1 CD ~t(Þ SRU 212- 27 5.5" THRU-TUBING POSISET PLUG CEMENT DUMPT BAILER 25' CEMENT PLUG..- SINGH 8/20/2002 6025-6050 1 B-Line SRU 212- ~þ 27 5.5" THRU-TUBING POSISET PLUG CEMENT DUMPT BAILER 25' CEMENT PLUG ~ Vs INCH 8/20/2002 6025-6050 1 CD " SRU 213- 10 2" HSD POWER JET 6 SPF COMPLETION RECORD v 5 INCH 8/4/2002 3800-4000 1 B-Line SRU 213- 10 ARRAY INDUCTION / DENSITY / CNL / GR / SP / CALIPER / PEX ...... SINGH 7/24/2002 1987-4105 1 B-Line SRU 213- 10 ARRAY INDUCTION / DENSITY / CNL I GR / SP / CALIPER / PEX ,/" 5 INCH 7/24/2002 1987-4105 1 CD SRU 213- "()c: 10 CEMENT BOND LOG / GR I CCL v SINGH 8/1/2002 0-4014 1 B-Line --- SRU 213- - 10 CEMENT BOND LOG I GR / CCL v' SINGH 8/1/2002 0-4014 1 CD \ ~ SRU 213- 10 COMPENSATED NEUTRON LOG IN CASING v SINGH 7/24/2002 1987-4105 1 B-Line SRU 213- 10 SLiMPULSE I GR / MD / FIELD PRINT v 2/5 INCH 7/18/2002 1952-4105 2 B-Line SRU 213- v 10 SLiMPULSE / GR / VD / FIELD PRINT 2/5 INCH 7118/2002 1952-4105 2 B-Line J ~ot( I SRU 23-33 111116 ENERJET GUN COMPLETION REPORT V SINGH 5/19/2002 10350-10625 1 B-Line \~ . Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. D~=f'"<!¿',- '-'F-'}, ij~._" ¿"'!> ~ ~ ~- y' ¡¡."..,.. ~ ~ ~. z..-,j! Date: Received B "¡~,,,.i,""" , '.'.'~" :"'. ',.'. "'", " . . r\I~.*:.¡;J; ",¡i !,J; l:J;i:¡;'::, \~..(;;:;; '"..:'~¡","'¡-f¡¡";';¡~"""" , .,-. '-' .. '.;;I...,:", ¡ '" ...., ' j.~n¡"':1I~"'B(~'c:r, . ,. ""1.Vl.....p., ,. } l ( Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: haITisonb@unoca1.com UNOCAL8 Beverly Harrison Business Ventures Assistant June 18, 2002 To: Lisa Weepie AOGCC 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL- Alaska / Lewis River Unit C-IRD Dry Samples LRU C-IRD 2684' - 4240' 4240' - 5800' 5800' - 6469' Box 1 of 3 Box 2 of3 Box 3 of 3 #//ór- ;j{ fJJ- ¿~g Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Date: 8 J~ Aa~~ Received B : w JLR {L ( (' Unocal Alaska 909 W. 9th Avenue Anchorage. AK 9950 I Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unocal.com UNOCALO Beverly Harrison Business Ventures Assistant May 3, 2002 To: Lisa Weepie AOGCC 333 W. 7th Ave, #100 Anchorage, AK 99501 DATA TRANSMITTAL - LEWIS RIVER UNIT ~DJ-/lc/(; , '" LOG WELL LOG TYPE SCALE" DATE INTERVAL CO MEDIUM ARRAY INDUCTION / NEUTRON DENSITY / GR / LRU C-1RD *PEX* 2/5 INCH 10/3/2001 2405-6450 1 Film ARRAY INDUCTION / NEUTRON DENSITY / GR / LRU C-1 RD *PEX* 2/5 INCH 10/3/2001 2405-6450 1 B-Line LRU C-1RD CALIPER PASS / GR 2 INCH 10/3/2001 2405-6450 1 Film LRU C-1RD CALIPER PASS / GR 2 INCH 10/3/2001 2405-6450 1 B-Line ---- '--,---- -,---_L.-~----- ----,- Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received Date: Al88ka Oil a Gas ConS. CornrnIion Anclrorage (' STATE OF ALASKA ,¡ ALASKA OIL AND GAS CONSERVATION Cl.J1MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: X 2. Name of Operator Unocal Oil Company of California (UNOCAL) 3. Address P. O. Box 196247, Anchorage, Ak 99519 4. Location of well at surface --.-. -"..---' ---. :/' "::: [,::'::.; . 0' FWL, 1,000' FSL, Sec. 35, T15N, R9W, SM ~ í1;:',': At Top Producing Interval ¡ , l. '~1.~_:t>L :; 469' FWL, 672' FSL, Sec. 35, T15N, R9W, SM, Vr.~i:¡i:¡- . At Total Depth ~ ~ø.~~ : 592' FWL, 606 FSL, Sec. 35, T15N, R9W, SM"-'-~""" '--"'..'- 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 100' GR/16'KB ADL-58798 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 9/21/2001 10/2/01 12/9/01 completed 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 6469' MD/6384' TVD 6053' MD/5989' TVD Yes: X No: 22. Type Electric or Other Logs Run AIT Density Neutron, GR 23. SUSPENDED: ABANDONED: SERVICE: 7. Permit Number 301-249/201-168 8. API Number 50- 283-20061-01 9. Unit or Lease Name Lewis River 10. Well Number C-1 rd 11. Field and Pool Lewis River 15. Water Depth, if offshore 16. No. of Completions NA 1 20. Depth where SSSV set 21. Thickness of Permafrost NA feet MD NA CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM 20" 0 75' 13-3/8" 54.5 0 368' 9-518" 47 0 2,409' 7" 29-26 N-80 0 2,674' 5" 15 L-80 2,454' 6,569' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) HOLE SIZE Driven CEMENTING RECORD Driven AMOUNT PULLED 6,022'-6042'MD 5,959'-5,978'TVD 425 sx 965 sx 750 sx 633 sx TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 5,490' 2,385' 2-3/8" 2,200' Heater String 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 17-1/2" 12-1/4" 8-112" 6 x 7" 25. 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 12-15-02 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF 1-3-02 24 TEST PERIOD => N/A 5MMCF/D Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF Press. 1,680 10 24-HOUR RATE => N/A 5MMCF/D 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. WATER-BBL 0 WATER-BBL 0 CHOKE SIZE GAS-OIL RATIO N/A OIL GRAVITY-API (corr) N/A None RECEIVED FEB 2 2 2002 Alaska Oil & Gas Cons. Commission Anchorage _.. AFE #148256 , Form 10-407 Rev. 7-1-80 RBD~~N~N:~DON:ERS~SI~ R \ GINA L Submit in duplicate ~~ ,i' 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. Top Tyonek Fm. 5,684' 5,640' RECEIVED FEB 2 2 2002 Alaska Oil & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Wellbore schematic, Daily Summary of Rig Operations, Directional Survey Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title DrillinQ ManaQer Date J.-~l-&~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". OR\G\NAL Form 10-407 ( Lets River C-l rd Summary 9/13/01-12/8/01 UNO CALf) DAY 1 9/13/01 MIRU KHR NO.9 DAY 2 9/14/01 CaNT. RU DAY 3 9/15/01 RU TOP DRIVE. DAY 4 9/16/01 BUILD BRINE IN PITS. INSTALL BPV IN LONG STRING (SHORT STRING BPV PREVIOUSLY INSTALLED). DAYS 9/17/01 CIRC 9.7PPG BRINE DOWN SHORT STRING. BULLHEAD 30 BBLS DOWN LONG STRING AT 1-1/2 BPM WITH 950 PSI. ND TREE. NU BOPE. TEST SAME TO 250 PSI /3000 PSI. PULL 1.66" CS HYDRIL HEATER STRING. GAS UNDER LONG STRING BPV. BULLHEAD 10.5 PPG MUD DOWN LONG STRING. PULL LONG STRING BPV. SCREW IN WITH LANDING JOINT. PULL SEALS FROM PACKER AT 2714'. CIRCULATE 10.6PPG MUD. GAS AT SURFACE WITH BOTTOMS UP. CIRC. HOLE CLEAN. DAY 6 9/18/01 POOH. LD 2-7/8" LONG STRING. CHANGE RAMS FROM 2-7/8" TO 3-1/2". TEST BLINDS AND 3-1/2" RAMS 250/3000 PSI. MU 6" FLAT BOTTOM MILL AND 6.059 WATERMELLON MILL. AND REMAINING BHA. RIH PU 3-1/2" DRILL PIPE. DAY 7 9/19/01 TAG PACKER AT 2715'. CBU. PUMP DRY JOB. POOH. LD BHA. RU E-LiNE. RIH AND SET RETAINER AT 2671' POOH. RD E-LiNE. TEST CASING TO 1500 PSI. MU STINGER. RIH PU 3-1/2" DRILL PIPE. STAB INTO RETAINER. SNAP OUT. SPACE OUT. RU DOWELL. PERFORM INJECTIVITY TEST. 1 BPM AT 1100 PSI FOR 5 BBLS, 2 BPM AT 1330 PSI FOR 5 BBLS, 3 BPM AT 1480 FOR 20 BBLS, 2 BPM AT 1350 PSI FOR 10BBLS, 1 BPM AT 1260 PSI FOR 5 BBlS AND 3 BPM AT 1480 PSI FOR 5 BBLS. TOTAL OF 50 BBLS PUMPED. BATCH CEMENT. DAY 8 9/20/01 PUMP 40 BBlS (190 SX) OF 15.8PPG CEMENT AT 3 BPM. FOLLOWED BY 2 BBLS OF WATER AND 13 BBlS OF MUD AT 2.7 BPM AITH 1100 PSI FINAL PRESSURE. UNSTING FROM RETAINER AND REVERSE TWO DP VOLUMES. APPROX 2 BBLS TO SURFACE. RD LRU C-I Summary.doc Page 1 of 7 2/20/02/5:02 PM ( (. Lew IS River C-1 rd Summary 9/13/01-12/8/01 DOWELL. POOH. TEST CASING TO 1500 PSI. GOOD TEST. PU BAKER ONE TRIP WINDOWMASTER WHIPSTOCK. RIH TO 2599'. RU SLlCKLINE. RIH WITH SPERRY SUN GYRO. POOH WITH GYRO. ORIENT WHIPSTOCK TO 60 DEGREES. TAG RETAINER WITH WHIPSTOCK AND SET SAME. MILL WINDOW FROM 2650'-2674'. DAY 9 9/21/01 CONT MILL WINDOW FROM 2674'-2684'. PUMP SWEEP. POOH. LD BHA. MILLS IN GAGE. PU BHA. 6-7" BICENTER BIT, 4-3/4" MOTOR WITH 1.15 DEG AKO. SLIDE FROM 2684'- 2721'. RUN SPERRY SUN GYRO. SURVEY AT 2710',2.65 DEG INC., 130 AZ. SLIDE 2758'- 2780'. DAY 10 9/22/01 ROTARY DRILL FROM 2780'-2851'. SURVEY AT 2803',4.6 DEG INC. 136 AZ. ROTARY DRILL TO 3129'. SURVEY 3080',4 DEG INC. 137 AZ. POOH TO 2650' AND REPAIR 37 PIN CABLE ON TOP DRIVE. RIH. ROTARY DRILL 3129'-3134'. DAY 11 9/23/01 CONT. ROATRY DRILL 3134'-3705'. DAY 12 9/24/01 CONT. ROTARY DRIL 3705'-3859'. REPAIR TOP DRIVE GRABER. ROTARY DRILL 3859'- 3975'. DAY 13 9/25/01 ROTARY DRILL FROM 3975'-4084'. CBU. POOH. TEST BOPE 250/ 3000PSI. MU BHA. DAY 14 9/26/01 MU BHA 6-7" BI-CENTER BIT, 1.15 AKO MOTOR. RIH TO 3958'. WASH AND REAM TO BOTTOM. ROTARY DRILL FROM 4084'-4607'. DAY 15 9/27/01 ROTARY DRILL 4607'-5193'. RAISE MUD WEIGHT TO 10.6 PPG AFTER SEEING CONNECTION GAS. DAY 16 9/28/01 ROTARY DRILL 5193'-5349'. CBU. POOH TO 4050'. RIH PU DRILL PIPE. WASH 5310'- 5349'. ROTARY DRILL 5349'-5553'. DAY 17 9/29/01 LRU C-l Summary.doc Page 2 of 7 2/20/02/5:02 PM ( ( LeWls River C-1rd Summary 9/13/01-12/8/01 CONT. ROTARY DRILL 5553'-5715'. CBU. DROP SURVEY. POOH. SURVEY OFF SCALE. MU NEW BIT. RIH. WASH FROM 5629'-5715'. ROTARY DRILL 5715'-5755'. DAY 18 9/30/01 ROTARY DRILL 5755'-5779'. WELL TOOK 11 BBLS. MIX CACO3 INTO SYSTEM. DRILL 5779'-5813'. NOTED FLOW. SI WELL. 110 PSI DP, 70 PSI CASING. CIRCULATE OUT USING DRILLERS METHOD. SLIGHT FLOW WITH NO PRESSURE BUILD UP. WEIGHT UP TO 10.8 PPG. ROTARY DRILL 5813'-6094'. WELL TOOK 25 BBL DRINK WHILE DRILLING SAND. DAY 19 10/1/01 ROTARY DRILL 6094'-6402'. DAY 20 10/2/01 CO NT. ROTARY DRILL 6402'-6469'. CBU. SHORT TRIP TO 5537'. PUMP HIGH VIS SWEEP. DROP SURVEY. POOH. SURVEY OFF OF 14 DEGREE SCALE. RU SCHLUMBERGER E- LINE. DAY 21 10/3/01 MU PLATFORM EXPRESS TOOLS. TROUBLE SHOOT PROBLEM WITH TOOLS AT SURFACE. RIH. SET DOWN AT 2800'. POOH AND INSTALL HOLE FINDER. RIH. WORK PAST LEDGES TO BOTTOM. TAG AT 6456' WLM. LOG FROM 6450'-2405'. POOH. RD E- LINE. TEST BOPE 2501 3000 PSI. RIH WITH 6" MILL TOOTH BIT, BHA, RIH AND MAKE WIPER TRIP. WELL STABLE. NO HOLE PROBLEMS. CBU. COND MUD. POOH. DAY 22 10/4/01 POOH. LD BHA. RU TO RUN 5" LINER. RIH WITH 5", 15#, L-80 BUTTRESS LINER. RIH. DAY 23 10/5/01 RIH WITH LINER TO A SHOE DEPTH OF 6461'. SET LINER HANGER AT 2454'. CEMENT LINER WITH 132 BBLSI XXX SX 15.8 PPG, G CEMENT. PARTIAL RETURNS DURING DISPLACMENT. LOST 56 BBLS. PU AND SET ZXP LINER TOP PACKER. TEST BACK SIDE TO 500 PSI. PU AND REVERSE OUT. NO CEMENT IN RETURNS. RD CEMENTING EQUIPMENT. POOH LD 3-1/2" DP. RU POLLARD WIRELINE. RUN TO 6317'. DA Y 24 10/6/01 POOH. LD 30 JTS 3-1/2" DP. RU APRS E-LiNE. RUN GYRO DATA SURVEY FROM FURFACE TO 6316'. POOH. RD APRS. RIH WITH DP. POOH LD DP. INSTALL 2-7/8" RAMS. TEST SAME 250/3000 PSI. RU TO PU TUBING. MU 4-1/8" MILL ON 7" CASING SCRAPER. RIH PU 2-7/8", 6.4#, L-80 IMP. BUTTRESS. LRU C-l Summary.doc Page 3 of 7 2/20/02/5:02 PM (' LeJ 1~ River C-l rd Summary 9/13/01-12/8/01 DAY 25 10/7/01 CONT. RIH PU 2-7/8", 6.4#, L-80 IMP. BUTTRESS. TAG AT 6306'. DISPLACE WELL TO 8.8 PPG, 9% KC!. POOH STANDING BACK TUBING. LD BHA. MU COMPLETION. WLEG, TAILPIPE, SEAL ASSEMBL V, X-NIPPLE, FH PACKER. CMU SLIDING SLEEVE. RIH. MU HANGER AND LAND SAME. DROP PRONG. SET FH PACKER. RU POLLARD SLlCKLINE. RIH RETRIEVE PRONG. RD SLlCKLINE. INSTALL BPV IN LONG STRING. RU TO RUN HEATER STRING. DAY 26 10/8/01 PU 1.66",2.3#, L-80, CS HVDRIL HEATER STRING. PICK UP 2338'. LAND HEATER STRING. INSTALL BPV. RD TUBING TOOLS. ND BOP'S. INSTALL TREE. TEST TO 3000 PSI. DAY 27 10/9/01 RD TOP DRIVE. RELEASE RIG AT 24:00HRS. DAY 28 10/19/01 RU COILED TUBING EQUIP. DAY 29 10/20/01 MU INJECTOR HEAD. TEST BOPE 250 I 3000PSI. RIH WI 1.5" CT AND JET OUT 90/0 KGI WATER TO 6200'. POOH. PAD TUBING WI 1850 PSI OF N2. DAY 30 10/21/01 RDCT. DAY 31 10/22/01 RU SCHLUMBERGER E-LiNE. MU PERF GUNS. RIH. TIE IN TO PLATFORM EXPRESS LOG DATED 10-3-01. PERFORATE TVONEK 6118'-6080' (38') WI 2" HC, 6SPF, 60 DEG GUNS. POOH. ALL GUNS FIRED. PRESSURE TO 2000 PSI. RD E-LiNE. FLOW WELL BACK WITH QUICK DROP TO 1650 PSI. SI WELL FOR BUILD UP. DAY 32 10/26/01 RU POLLARD SLlCKLINE. RUN EOT LOCATOR. EOT AT 5486' SLM. CORRECT TO ELM. TAG FILL AT 6067'. DAY 33 10/27/01 MIRU DOWELL CEMENT PUMPER. TEST LINES RO 3000 PSI. RU SLlCKLINE. PUMP DOWN TUBING AT 3.75 BPM. 2500-2750 PSI AND ATTEMPT TO PUSH FILL DOWN HOLE. LRU C-l Summary.doc Page 4 of 7 2/20/02/5:02 PM ( ( Lew IS River C-l rd Summary 9/13/01-12/8/01 RIH WITH SLlCKLINE. FILL AT 6090' (10' BELOW TOP PERF). HEATER STRING ANNULUS ALARM AT FACLILITY INDICATING POSIBLE OPEN SLIDING SLEEVE. RD SLlCKLINE. DAY 34 10/28/01 WELL SHUT IN. TUBING 500 PSI. ANNULUS 300 PSI. RU POLLARD SLlCKLINE. RIH AND SET PX PLUG AND PRONG IN X NIPPLE AT 2427'. ATTEMPT TO SHIFT SLIDING SLEEVE. NO INDICATION OF SHIFTING. REPLACE PX PLUG AND PRONG WITH NEW EQUIPMENT. BLEED PRESSURE OF TUBING AND ANNULUS. PUMP 20 BBLS OF WATER THROUGH LEAK. CONT. ATTEMPT TO SHIFT SLIDING SLEEVE WITHOUT SUCCESS. DAY 35 10/29/01 WELL SHUT IN. TUBING 500 PSI. ANNULUS 300 PSI. RU POLLARD SLlCKLINE. RIH AND SET PX PLUG AND PRONG IN X NIPPLE AT 2427'. ATTEMPT TO SHIFT SLIDING SLEEVE. NO INDICATION OF SHIFTING. REPLACE PX PLUG AND PRONG WITH NEW EQUIPMENT. BLEED PRESSURE OF TUBING AND ANNULUS. PUMP 20 BBLS OF WATER THROUGH LEAK. CONT. ATTEMPT TO SHIFT SLIDING SLEEVE WITHOUT SUCCESS. DAY 36 11/7/01 MIRU SCHLUMBERGER E-LiNE. TEST LUBRICATOR. SDFN. DAY 37 11/8/01 MU POSISET PLUG. RIH. DECIDE TO POOH AND MAKE E-LiNE TAG OF FILL FIRST. POSISET PLUG STUCK AT 1472'. FOUND E-LiNE BIRD NESTED IN LUBRICATOR. REPAIR SAME AND POOH. RECOVER TOOL. SDFN. DAY 38 11/9/01 RIH WITH CCL. TAG FILL AT 6045'. POOH. RD AND MOVE TO PCU NO.4. DA Y 39 11/11/01 MIRU E-LiNE. TUBING 500PSI, ANNULUS 200 PSI. PUMP DOWN TUBING WITH DOWELL. PRESSURE TO 2500PSI AFTER 12.4 BBLS. ANNULUS PRESSURE TO 2400 PSI. BLEED TUBING TO 600 PSI. RIH WITH CCL. TAG FILL AT 6061'. FREEZE PROTECT TUBING AND ANNULUS. PUMP METHANOL. PRESSURE TUBING TO 2200 PSI AND SHUT IN TRAPPING PRESSURE. SDFN. DAY 40 11/12/01 TUBING PRESSURE AT 2100 PSI. PUMP INTO TUBING AND RAISE PRESSURE TO 2500PSI. SDFN. LRU C-I Summary.doc Page 5 of 7 2120/02/5:02 PM ( (" Lew IS River C-1 rd Summary 9/13/01-12/8/01 DAY 41 11/13/01 TUBING PRESSURE AT 2460 PSI. RIH WITH CCL. TAG FILL AT 6063'. POOH. MU POSISET THROGH TUBING BRIDGE PLUG. RIH. SET PACKER AT 6054.3'. POOH. MU DUMP BAILER. RIH WITH BAILER NO.1 AND DUMP CEMENT ON PLUG. POOH. SDFN. DA Y 42 11/14/01 TUBING PRESSURE AT 2450 PSI. RIH WITH CCL AND TAG CEMENT AT 6048'. POOH. RIH WITH NO.2 BAILER. DUMPED CEMENT. TEORETICAL TOC AT 6043'. POOH. PUMP INTO TUBING AND RAISE PRESSURE TO 2700 PSI. DA Y 43 11/15/01 TUBING PRESSSURE 2550 PSI. RIH WITH CCL AND TAG CEMENT AT 6042.5'. POOH. RIG DOWN E-LiNE. DA Y 44 11/30/01 MIRU KHR RIG NO.9 TO REPAIR TUBING LEAK DA Y 45 12/1/01 CONT. TURNKEY RU. ACCEPT RIG AT 18:00 HRS. NO TREE AND NU BOPE. DA Y 46 12/2/01 CONT. NU BOPE. TEST BOPE 300/3000PSI. ENGAGE HEATER STRING. PULL HANGER TO FLOOR. POOH LD 1.66 HEATER STRING. MU 2-7/8" LANDING JOINT. PULL ON TUBING STRING. NO INDICATION OF PACKER PULLING FREE. PACKER APPARENTLY NOT SET. PULL HANGER TO FLOOR. DAY 47 12/3/01 POOH STANDING BACK TUBING. RECOVERED FH PACKER AND FOUND IT SHEARED AND LEAKING AT MANDREL. REPLACE PACKER AND RIH WITH COMPLETION. LAND COMPLETION. RU POLLARD SLlCKLINE. RIH AND SET PX PLUG AND PRONG AND SET IN X-NIPPLE BELOW PACKER. SET PACKER WITH 2600 PSI. RIH TO RECOVER PRONG. SET DOWN AT 2379'. POOH. RIH WI 2.240 LIB. SET DOWN AT 2379' POOH. SLIGHT BEVEL ON 0.0. SUSPECT OVER TORQUED TUBING. ORDER OUT SWEDGE. RIH WITH 1.75" BAILER TO PRONG AT 2430'. POOH, NO RECOVERY. DA Y 48 12/4/01 RIH W/2.25" SWEDGE. WORK THROGH TIGHT SPOT. POOH. RIH W/2.374" SWEDGE. UNABLE TO GET BELOW HANGER. REPLACE WITH 2.31" GR. RIH AND BEAT THROGH RESTRICTION AT 2379'. RIH WITH PULLING TOOL AND RECOVER PRONG AND PLUG. INSTALL BPV IN LONG STRING. RD SLlCKLINE. RUN 1.66" HEATER STRING. DISPLACE LRU C-l Summary.doc Page 6 of 7 2/20/02/5:02 PM ( ( Lew IS River C-1 rd Summary 9/13/01-12/8/01 ANNULUS TO DIESEL. INSTALL BPV IN HEATER STRING. NO BOPE. NU TREE. INSTALL TWC'S. TEST TREE 25013000 PSI. PULL TWC'S AND INSTALL BPV'S. RELEASE RIG. DA Y 49 12/8/01 RU SLlCKLINE. SWAB TUBING TO 1300'MD. RD SLlCKLINE. MIRU E-LiNE. SDFN. DAY 50 12/9/01 RIH AND PUNCH TUBING AT 2,450'-2,451' TO PREVENT FUTURE TREATING PRESSURE FROM UNSEATING PACKER. POOH. MU GUN NO.1. RIH. PERFORATE TYONEK 6,022'- 6,042'ELM WI 2", 6SPF, 60 DEG HOLLOW CARRIER GUNS.PRESSURE BUILT FROM 0 TO 450 PSI POOH. RELEASE WELL TO PRODUCTION. LRU C-l Summary.doc Page 7 of 7 2/20/02/5:02 PM (' (' ewis River Well C-lrd ACTUAL UNOCAL8 ¡.' SIZE \Yf 20" 13-3/8" 54.5 9-5/8" 47 7" 26 & 29 5" IS Tubing 2-7/8" 6.4 1-114" 2.3 CASING AND TUBING DETAIL GRADE CONN II) T<W ßT1\1. 75' 368' 2,409' 2650' 6,461 ' RKB = 16.5' L-80 Butt 29# window 4.408 Surface Surface Surface 2,454' N-80 L-80 Butt see es Hydril 2.441 surface 5490' 2,200' ~ ! NO. D~th 1 16.5' 3 2466.67 4 2385.66 5 2427.61 A 2338.60 ID JEWELRY DETAIL OD Item Dual Tubing Hanger, 2-7/8" x 2-3/8" DCB 9" 5M 4.25 2.875 2.310 1.380 5.25 6.059 2.875 1.660 HMC/ZXP Liner Hanger and Tieback Sleeve & SEALS BAKER FH PACKER "X" Nipple 1-114", CS Hydril HEATER STRING PROPOSED PERFORATION INTERV AL Interval Accum. ---'--Date-------Zõne--- ------Top-'--- ---Btm--' -Ainf-n ---.- --8pl'-- -CommentS ...- ___un~u --- --- -_J~l'QPQ-~~!!- - - ------_._._~,-Q~O~ -- - - ~).!!~'- _n- )~~- ..._-~._---_~~:r_~æII>RQ1lI1__.. on __Bn__- A -.-----..- ----....- -- -------'-'-"---'-.---.--.-.-.--.-.--...--. --..__.--..--._----_._---_..---- '-'--"'-"'-'----'__'__B -._..- -. _n.. -.. -..- -- ..-. 5 ---___--J!_B_"_--- ----------- --__~~~§9.~_- __~ð51~ ----_.!~-----'---_'__~_B____- TJ:JG Pu.Nç_I-!.. ---- - ----.- --'u .--.--.--.....-- .---...- .--.-----.--.---.. ---'-""-"----'---'. ---- ..w.----...---. ---------.---.-. -- -..--.--..------. _-.BB _.n_..' ---. -. .-- _B_' ...-. _"B ---.. ..-. -.....----.-... -.. 6,022' 6,042' 20' 6 2" THRU TBG GUN ...------.----.-.--.- -.......---...-.-- -----..-.-.........-..---.-.----..--..- -......--- -. .--. - '-,'-"'_'_'n .---.-..u_.. ŒJ _'_B'__'__-----. 'U-_"_'B_--'__"'-'--'--",-,-"" -------.. .--.-.-..-..-.-...-.- ---'---'--'-"""""---U_-------"'__-".n .....-_. .- '-"-'-'.._..mm 3 I END OF TUBING @ 5490'. PERFS 6022-6042' Posiset plug at 6053 and cement top at 6043' Max Hole Angle = 18 degrees at TD TD = 6,469' TVD LR C-1 ACTUAL I.doc DRAWN BY: JIM REVISED: 10110/01 ~yr~/dat~ ( Gyrodata Incorporated 1682 W. Sa m Houston Pk\vy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 December 4, 2001 Drilling Department Unocal 909 9th Street Anchorage, AK 99504 Re: CD-1 RD Lewis River, Alaska Enclosed, please find one (1) original, four (4) copies, and one (1) disk of the completed survey of the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. ~erely, Ii.----.'" #>7- ?::.-4 ¿~ ~ Ernest E. Surman Jr. Y'" Assistant Operations Manager EES:lnr Serving the Worldwide Energy Industry with Precision Survey Instíumentation , gyroLdat~ ( Gyrodata Incorporated 1682 W. Sam Houston Pk'Ny. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY RE PO RT UNOCAL CD-1 RD H & R #9 LEWIS RIVER, AK AK1 001 GME524 OCTOBER 6, 2001 CO.PV Serving the Worldwide Energy Industry with Precision Survey Instrumentation A Gyrodata Directional Survey for UNOCAL Well: CD-1RD --"- Location: H & R DRILLING #9, LE\\1IS RIVER, ALASKA Job Number: AK1001GME524 Run Date: 10/6/01 11:58:53 AM Surveyor: Tom Stoddard Calculation Method: MINIMUM CURVATURE Survey Latitude: 61.300000 deg. N Azimuth Couection: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location ---- Closure Calculated from Well Head Location Horizontal Coordinates Calculated from ,\1 ell Head Location A Gyrodata Directional Survey UNOCAL Well: CD-1RD Location: H & R DRILLING #9, LEWIS RIVER, ALASKA Job Number: AK1001GME524 MEASURED IN C L AZIrvruTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINA TES feet deg. deg. deg. min. deg./ feet feet deg. feet 100 ft. 0.0 0.00 0.00 N 0 0 E 0.00 0.0 0.0 0.0 0.00 N 0.00 E -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- ~- 0 - 6298 FT. RATE GYROSCOPIC MULTISHOT SURVEY RUN INSIDE CASING ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO H & R DRILLING #9 RK.B. -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- 100.0 0.29 342.46 N 17 32 W 0.29 100.0 0.3 342.5 0.24 N 0.08 vV 200.0 0.39 357.18 N 2 49 W 0.14 200.0 0.8 348.4 0.82 N 0.17W 300.0 0.71 11.53 N 11 32 E 0.34 300.0 1.8 358.0 1.77 N 0.06 W 400.0 0.62 12.83 N 12 50 E 0.08 400.0 2.9 3.6 2.90 N 0.18 E 500.0 0.82 63.50 N 63 30 E 0.64 500.0 3.9 14.1 3.75 N 0.94 E 600.0 1.47 83.10 N 83 6 E 0.75 600.0 5.1 34.0 4.23 N 2.85 E 700.0 1.89 89.00 N 89 0 E 0.45 699.9 7.3 52.7 4.41 N 5.78 E 800.0 1.97 87.05 N 87 3 E 0.10 799.9 10.2 63.7 4.53 N 9.14 E 900.0 2.12 76.82 N 76 49 E 0.40 899.8 13.6 68.3 5.04 N 12.66 E 1000.0 2.01 78.25 N 78 15 E 0.13 999.7 17.2 70.2 5.81 N 16.17 E 1100.0 2.17 65.56 N 65 34 E 0.49 1099.7 20.8 70.5 6.95 N 19.61 E -- 1200.0 2.29 70.34 N 70 20 E 0.22 1199.6 24.7 70.1 8.41 N 23.22 E - 1300.0 2.17 64.10 N 64 6 E 0.27 1299.5 28.6 69.7 9.91 N 26.81 E 1400.0 2.00 64.33 N 64 20 E 0.17 1399.4 32.2 69.1 11.49 N 30.08 E 1500.0 2.10 63.55 N 63 33 E 0.11 1499.4 35.8 68.6 13.07 N 33.30 E 1600.0 1.92 66.59 N 66 35 E 0.21 1599.3 39.3 68.3 14.55 N 36.47 E 1700.0 1.75 61.01 N 61 1 E 0.24 1699.3 42.5 67.9 15.95 N 39.34 E 1800.0 1.71 64.85 N 64 51 E 0.12 1799.2 45.5 67.6 17.33 N 42.03 E 1900.0 1.37 70.84 N 70 50 E 0.38 1899.2 48.1 67.6 18.35 N 44.51 E 2000.0 1.53 64.91 N 64 54 E 0.22 1999.2 50.7 67.6 19.31 N 46.84 E 2 A Gyrodata Directional Survey UNOCAL Well: CD-IRD Location: H & R DRILLING #9, LEWIS RIVER, ALASKA Job Number: AKI001GME524 deg. deg. BORE HOLE BEARING deg. min. DOGLEG SEVERITY deg./ 100 f1. VERTICAL DEPTH feet CLOSURE DIST. AZIMUTH feet deg. HORlZONTAL COORDINA TES feet MEASURED DEPTH feet INCL AZIMUTH 2100.0 1.43 59.59 N 59 35 E 0.17 2099.1 53.2 67.3 20.50 N 49.12 E _.~ 2200.0 1.42 70.41 N 70 25 E 0.27 2199.1 55.7 67.2 21.55 N 51.37 E 2300.0 1.45 58.94 N 58 57 E 0.29 2299.1 58.2 67.1 22.62 N 53.62 E 2400.0 1.25 72.80 N 72 48 E 0.38 2399.0 60.5 67.1 23.60 N 55.75 E 2500.0 1.07 35.64 N 35 38 E 0.76 2499.0 62.4 66.7 24.68 N 57.33 E 2600.0 0.89 21.23 N 21 14 E 0.31 2599.0 63.8 65.8 26.16 N 58.16 E 2700.0 2.42 128.39 S 51 37 E 2.81 2699.0 65.3 66.9 25.57 N 60.09 E 2800.0 4.26 148.30 S 31 42 E 2.15 2798.8 67.1 71.7 21.10 N 63.70 E 2900.0 4.64 151.24 S 28 46 E 0.44 2898.5 69.1 78.0 14.40 N 67.60 E 3000.0 4.39 143.91 S 36 5 E 0.63 2998.2 72.2 83.8 7.75 N 71.80 E 3100.0 4.30 146.11 S 33 53 E 0.19 3097.9 76.2 88.8 1.55 N 76.15 E 3200.0 4.16 142.24 S 37 45 E 0.32 3197.6 80.6 93.2 4.43 S 80.46 E 3300.0 4.15 140.26 S 39 44 E 0.14 3297.4 85.6 96.8 10.08 S 84.99 E 3400.0 3.83 135.17 S 44 50 E 0.48 3397.1 90.9 99.6 15.23 S 89.66 E 3500.0 3.62 138.18 S 41 49 E 0.29 3496.9 96.2 102.0 19.95 S 94.12 E _. 3600.0 3.59 139.50 S 40 30 E 0.09 3596.7 101.3 104.1 24.69 S 98.25 E 3700.0 3.49 138.85 S 41 9 E 0.11 3696.5 106.4 106.0 29.36 S 102.29 E 3800.0 3.72 143.87 S 36 8 E 0.39 3796.3 111.6 107.9 34.27 S 106.20 E 3900.0 4.12 140.84 S 39 10 E 0.45 3896.1 117.3 109.8 39.67 S 110.38 E 4000.0 4.97 136.64 S 43 22 E 0.91 3995.8 124.3 111.5 45.61 S 115.63 E 4100.0 6.38 140.61 S 39 23 E 1.46 4095.3 133.2 113.5 53.06 S ]22.13 E 4200.0 7.28 137.32 S 42 41 E 0.98 4194.6 144.0 115.5 62.01 S 129.95 E 4300.0 7.82 140.39 S 39 37 E 0.67 4293.7 156.1 117.4 71.91 S 138.58 E 4400.0 8.07 137.55 S 42 27 E 0.47 4392.7 169.1 119.1 82.33 S 147.66 E 3 A Gyrodata Directional Survey UNOCAL Well: CD-1RD Location: H & R DRILLING #9, LEWIS RIVER, ALASKA Job Number: AKI00IGME524 MEASURED INCL AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COO RD IN A TES feet deg. deg. deg. min. deg./ feet feet deg. feet 100 ft. 4500.0 8.89 137.68 S 42 19 E 0.81 4491.7 183.1 120.6 93.22 S 157.60 E 4600.0 9.56 132.95 S 47 198.6 121.8 104.58 S ] 68.88 E --~-. 3 E 1.01 4590.4 4700.0 10.23 136.16 S 43 51 E 0.87 4688.9 215.4 122.8 1] 6.65 S 181.11 E 4800.0 11.14 132.93 S 47 4 E 1.09 4787.1 233.6 123.7 ]29.63 S 194.33 E 4900.0 12.61 131. 64 S 48 22 E 1.50 4885.0 254.0 124.4 143.47 S 209.56 E 5000.0 13.82 131.22 S 48 47 E 1.21 4982.3 276.7 125.0 158.59 S 226.71 E 5100.0 14.30 130.35 S 49 39 E 0.52 5079.3 300.9 125.4 174.47 S 245.11 E 5200.0 14.89 129.23 S 50 46 E 0.65 5176.1 326.0 125.8 190.59 S 264.48 E 5300.0 15.46 127.95 S 52 3 E 0.66 5272.6 352.1 126.0 206.91 S 284.94 E 5400.0 15.77 126.42 S 53 35 E 0.51 5368.9 379.1 126.1 223.18 S 306.39 E 5500.0 16.87 125.40 S 54 36 E 1.14 5464.9 407.1 126.1 239.65 S 329.15 E 5600.0 17.92 123.63 S 56 22 E 1.17 5560.3 437.0 126.0 256.58 S 353.79 E 5700.0 18.62 122.71 S 57 17 E 0.76 5655.3 468.3 125.8 273.72 S 380.02 E 5800.0 19.04 121.91 S 58 6 E 0.50 5749.9 500.6 125.5 290.97 S 407.30 E 5900.0 19.03 121.39 S 58 37 E 0.17 5844.5 533.1 125.3 308.08 S 435.07 E 6000.0 19.23 120.27 S 59 44 E 0.42 5939.0 565.8 125.0 324.88 S 463.21 E .'-"----. 6100.0 18.69 119.73 S 60 16 E 0.57 6033.5 598.2 124.8 341.12 S 491.35 E 6200.0 18.36 118.06 S 61 56 E 0.62 6128.4 629.8 124.5 356.48 S 519.16 E 6298.0 17.59 117.42 S 62 35 E 0.81 6221.6 659.8 124.2 370.56 S 545.93 E Final Station Closure: Distance: 659.81 ft Az: 124.17 deg. 4 UNOCAL Well: CD-1 RD Location: H & R DRILLING #9, LEWIS RIVER, ALASKA 0 -,-- I , J , I , , - r - - - - - - - -I- I I I I , I I I -,- I -50 -1- - - - - J - - - - - - - - , - - - - - - - - I I , I I I I --,- I I I I -------,--------r------- I , , I -1 00 -1- - - - -, - - - - - - - - - - - - - -- - - i ,- - I I -,- I I I £ -150 '---' I , ---------------- J I -- - - - - - - - - - - - -- - - - - - - <.9 z I I- er: 0 z -200 -1- - - - -: - - - - - - - -- ~ - - - - - - - - ~ - - - - - - - - -- - - - - I I -300 -,- - - -- - - - - - - - - - - - - - - - - -350 -L - - - - '- - - - - - - - _1 - - - - - - - - L - - - - - - . _1- - - - - - -- - ..J - - - - - - - - 1. - - - - - - . - '- - - - 0 250 300 EASTING (ft) 50 100 150 200 -------, I , I , I , I I ---------, J .. Gyrodata, Inc. AK1 001 GME524 DEFINITIVE -- - - - - r , I - - - - - -- - - r - - , I I i -------, I I I -- - - - - ".1.\ - - -- -!- -- - - - - " - - - - -- - - " - Ä---¡-- -; - - - -~ Ä.A ; Äj, ~ I J Â" , ----- I Ä------1- --""""'~ : I I 'ì... I 'A , --- ~ ----T--- ' " - - - - - --, - . - - - - - ,- - ~. I c- ~~ >':..~ ----+-- -------'--~~ I -. - I - - - I ~~: ---.------- I ----- I ------_.~ I ------, , - I ;~~ I : ~~; -- ! '------- , J --------, I - - - - ; , ' n_- '_n_: ; ~ ' - . - ': :.t.~1 . '. _c- _n ',J. -- , , "- - -- ! - ! _250 -1- . - - - - , - - - -'- - - - - - - - -'- - - -- -.L----- . -- I I , , - - - - - - -"I , ------- I I I ---- --- I I , I I I - .1- I I I I I J I - - - - - - - 1 - 350 400 I I I I - I- I I , I - ,-' ~-~. 450 BOTTOM HOLE LatA TED ' MD: 6298.00 À 'A. Â 500 ~-L ~- I .6.' 550 UNOCAL Well: CD-1 RD Location: H & R DRILLING #9, LEWIS RIVER, ALASKA 6.0 1 I I 5.5 -1-- ~ - - - -- - - - -,- -- - , 1 - - - - - - - L - - - - - - - - - - - - - ~ - - - - - - - - - - - - - -,- - - - - - - - - - - - - - L - - - - - I " I 5.0 - -- - - - - - - - - - - - - -,- - - - - - - - - - - - - r - - - - - - - - - - - - - ~ - - - - - - - - - - - - - -,- - - - - - - - - -- - - - - r - - - - - - -- , I 1 -- -- - -- -- -- I - - - - - - L - - - -- - - - - - - - - - -l - - - - - - - -- - -- - - - -1- -- - -- -- - - - - - - - - - L - - - - - - ! ¡ ! 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UNOCAL Well: CD-1 RD . Location: H & R DRILLING #9, LEWIS RIVER, ALASKA Gýrodata, Inc. AK1001 GME524 DEFINITIVE I ~ ; ': --- - . r - ~).~~~i~l\^~.L...'i.- : . . - u -. "J:, "'-'¡,.-J., , - ----, I, , ";6.-"'-"'-Å-"~'.. HOLE - - - í : , '. - - . . - - . . or -'4.¿BOTTOM , ' . , - - " - - - - 'OCATED I A. , '-------- , 'L 00' '/ -- -'----- 'MD:6298. I ' uu, , , I - '. -- --, , ' -- -I -- , , , -- -- -~---------:--- -- I: ¡ -1----- : 1200 -1- --, i" -- - -- -- , . , I '---------:-- : ' . -, . ---~- ---¡- : , ~ - - - - I, , : ---, I --- --- -- , ----" --- . '- ---- , . : , -- -- ---: - -- : l~ ' -----"-----r--:-- : : Ä . . -. - " , , '--'-",- 'J. I, , , --- 800 -1- - - - -,- k 1\.. \:. .. i! I, ; - - - -- - - - , -- - . , \ / '\ I I I, -' - . - , '\A /' i\ '/ '----, . " ~ Ä I \ I! --- ' , " , '- - - - , , ' , , " I - - - . ,i/\..v"\ '\1 If_I--.-. , , , A A~.. '.- . - c )¡. - - A "" , , ' - A H, ! ¡, , , -'------ , \ i; , '- ' 'I I, , -, - - - ' !', '_n_'n ' I I, __,_n- ' I; '____n ~ - - - - - -\- -)- - - - -:- -- ! -------- -, AI - , - \ i , - ' , _L_- \1 ~ ____u~n i I - -, - - I " - - - : - _1- - - - -;- - - - - - - - - ! i --L--_-- 1 ------- I - - - - - - -' -- - -- 20.0 -1- - - - - T - I ¥A. 140.0 100.0 :r: I- :J 2 N « i ! I J J i 60.0 -1- - - - -- t í i I i I 40.0 -1- - - - - J- , - I i I ?""""'" " -. I - 0.0 -1- - 1 ¡_n______--~----- í ! i ,Î I; 340. 0 rr=t~- I ,-__,__- --------'--------------- ----- ------ ------ - - - ------ - - -- I ! , I , I I -- - - - - -r -- - - - -- - -- - - -- - -- - ¡- - - -- -- -- - - - - -- - - -/- -- - - - - - - - - -- - - -1- - -- - - - - - - - - - - -t - - - - - -- -- - - 0 5000 1000 6000 7000 2000 3000 4000 MEASURED DEPTH (ft) '}1 . . ~lJ~lJ~ @ ~fL~~~~ TONY KNOWLES, GOVERNOR DEPT. OF ENVIRONMENTAL CONSERVATION / DIVISION OF ENVIRONMENTAL HEALTH SOLID WASTE PROGRAM 410 WILLOUGHBY AVE JUNEA U, ALASKA 99687 h Up :/Iwww .state.ak.us/dec/deh Telephone: (907) 465-5162 Fax: (907) 465-5362 \ " . October 23, 2001 IyP-C Harry A. Eaton. ,~ ~/' '" RES Manager r/~D Unocal Alaska \~Q-\~\ A OCr :1 260 Caviar Street \>~~ \~ 1"'3.-~\ ~$kaOIi'~ 0 ¿OO! Kenai, Alaska 99611 . b -()\ ~ ~ \ <¡;A - ~ '\ ';) .q;: C4?s. t% . ' . ~ I~c-~~ ~o.~~~c;.~ rage ~/S8iQ Reference: Issuance of Permanent Closure Approval for Inactive Reserve Pits locate~ at Lewis River t\-I, B-1, C-~, D- 'and Pretty Creek # 2 located on the west side of Cook Inl~ (\"~-o~.S ~ ,~S OCr'"" '., nñ~ 1-0\ \'\~-aa~ ... ~ "'Co-CJ~\~;r (, I C!-I Dear Mr. Eaton: '::Jf...'> t;1\-'i~ \. ~Ca...~ ~ ~- ~ '- . \>~~ ~I~~~\o c.-\ Q~ dO\-\~~ The Alaska Department of Environmental Conservation (ADEC) has completed review and public notice for pennanent closure approval for the above reference reserve pits located in the Susitna Flats State Game Refuge. The closure applications provided the required information describing the history of the reserve pit(s), the present condition of the reserve pits(s), results of any required water sampling and an assessment of the potential risks posed by the drilling waste to human health and the environment. At these locations, the reserve pits are backfilled and there is no exposed ddlling waste. ADEC coordinated several field inspections of the sites with the Alaska Department of Fish and Game and the Alaska Department of Natural Resources. , Public notice requesting comments on the closure requests was published September 20 and 21, 2001 in the Anchorage Daily News and posted on the state web site September 21,2001. No public comments objecting to closure approval were received in response to this public notice. ADEC has determined that the reserve pit at this site meets the closure requirements of 18 AAC 60.440. Closure Approval Under authority of 18 AAC 60.440 (j), ADEC grants pennanent closure approval to Unocal Alaska for the inactive reserve pits at the following sites: 11 1) '\ \ , 2) ( ( . . ' .' .~ Unocal Alaska Mr. Harry A. Eaton October 23, 2001 Page 2 of 2 Well Name /' Lewis River 1 (A-I) Lewis River B-1 ../ Lewis River C-l .r Lewis River D-l / Pretty Creek #2 ../ MTRS Sec. 02, T14N, R9W, SM Sec. 10, TI4N, R9W, SM . Sec. 35, T15N, R9W, SM Sec. 35, T15N, R9W, SM Sec. 33, TI4N, R9W, SM Landowner ADF&G/ ADNR ADF&G/ADNR ADF&G/ ADNR ADF&G/ADNR ADF&G/ADNR API Number 50-283-20047-00 50-283-20052-00 50-283-20061-00 50-283-20068-00 50-283-20022-90 - Terms and Conditions This permanent closure approval is subject to the following terms and conditions: In accordance with 18 AAC 60.440(1), the ~epartment will require additional investigation, assessment, monitoring or remediati~n if new information regarding conditions at the reselVe pit facilities indicates that' further actions' are necessary to protect human health or the environment. ' ;" , The approval granted by this letter is for the inactive drilling waste reserve pit(s) only. Closure for the pad as a whole (if required) must be c:oordinated between the owner/operator and the appropriate, land owner/manager.' , j Any person who disagrees with any portion of this decision mé\Y,request an adjudicatory hearing in accordance with 18 AAC 15.200':310. The requ~st should be mailèd to ,the Commissioner of the Department of Environmental Conservation, 555 Cordova Ave. Anchorage, AK 99501. If a hearing is not requested within thirty (30) days of the date of this letter, the right of appeal is waived. If an adjudicatory hearing is requested and granted, this decision remains in full effect during the , adju~icatory process. Sincerely, ~€r\. ~c<d Heather Stockard Solid Waste Program Manager Heather Stockard@envircon.state.ak.us cc: 'i",.TomMaundër-AOGCC "".." , "c. '..,,:, ':'c' ",:' ',' :' ",' " " ' Deborah Heebner, ADNR, Anchorage Wayne Dolezal, ADF&G, Anchorage John Hammelman, U nacal f 1\ 't ~ ~1r&\1rŒ (ID~ &\~&\~[r&&\ AlAS IiA. 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 w. rrn AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Williamson . Drilling Manager Unocal PO Box 196247 Anchorage AK 99519 Re: Lewis River C-1 R.D U nocal Pennit No: 201-168 Sur Loc: 0' FWL, 1000' FSL, Sec. 35, T15N, R9W, SM Btmhole Loc. 0' FWL, 1000' FSL, Sec. 35, T15N, R9W, SM Dear Mr. Williamson: Enclosed is the approved application for pennit to redrill the above referenced well. The pennit to redrill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal has not been requested as part of the Pennit to Drill application for Lewis River C-l. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION DATED this 13th day of September 2001 jj c/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. !( ( Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7671 UNOCAL8 Dan Williamson Drilling Manager Wednesday September 5,2001 Ms. Julie Heusser, Commissioner AOGCC 333 West th Ave., Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill Lewis River Field Well C-1 rd West Side, Cook Inlet Dear Commissioner Heusser, Please find the following amendments to the Permit to Drill Application previously submitted by Unocal. These amendments include the following: 1) Kick off at 2,666' MD/TVD as opposed to 4,220'. The original plan called for the removal of the existing completion to allow for the deep kick off. In light of new information, it appears that the removal of the existing completion would be extremely difficult to accomplish as a result of perf debris on one of the packers. As such the new plan is to set a retainer at 2,675' and pump an abandonment slurry below the retainer (See Sundry Amendment dated 9/4/01). After the abandonment is performed, the whipstock will be set on the retainer, a window milled and a 6" hole drilled from 2,666' to 6,350' TVD. The well is still proposed as a "blind" sidetrack to cut new sand face in the Tyonek Reservoir. A multishot survey will be performed upon completion of the well. 2) A 5" liner is being substituted for the 4-1/2" originally proposed for additional future wellbore utility. The liner top will remain at 2,500' MD. The cement plan is revised to bring cement into the liner lap. The anticipated start date for this well work is September 12, 2001. If you have any question please do not hesitate to call Tim Brandenburg at 263-7657. RECEiVED SEP 0 5 2001 O. R \ G \ h I A L' Alaska Oil & Gas cons., Commission , \j Anchorage ( ( !llt:J il!ltlili~7 Dan Williamson Drilling Manager RECE~'~~~""'~J) SEP 0 5 /001 Alaska Oil & Gas Con",; ç:cn'lrnission Anchora~'::(- :( STATE OF ALASKA t ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 # ~1r h-~' C¡Ja.J11 øQj>l~ ~ 2/0 / 1a. Type of work Drill: Re-Entry: 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage. Alaska, 99519-6247 4. Location of well at surface 0' FWL, 1,000' FSL, Section 35, T15N, R9W, SM At top of productive interval Same At total depth Same 12. Distance to nearest property line 1,000' feet 16. To be completed for deviated wells Kickoff depth: 2,666' feet Maximum hole angle: 6.89 18. Casing program size Specifications Hole Casing Weight Grade Coupling Length Existing 20" A 75' Existing 13-3/8" 54.5 A 368' Existing 9-518" 47 A 2,409' Existing 7" 29-26 N-80 6,569' 6" 5" 15# L-80 3,855' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Approved by Redrill: X Deepen: 1 b. Type of well Service: 13. Distance to nearest well 3,021' 6,570' 6,570' measured true vertical 5,609' 5,609' Length Size 75' 368' 2,409' 6,569' 20" 13-3/8" 9-518" 7" ,I ^ 1 _. - "'" , ..... ".., u- r... Uf Form 10-401 Rev. 12-195 Taylor SeamounJ O,'RI' r:;,._.",r[: l\! .Ii~ !' , i .,,; '" l' , ¡.....) t \ Ii: ¿', ", Exploratory: Stratigraphic Test: Developement Gas: X Single Zone: 5. Datum Elevation (DF or KB) 10. Field and Pool 100' GR/16'KB feet Lewis River 6. Property Designation ADL 58798 7. Unit or property Name Lewis River 8. Well number C-1 9. Approximate spud date 9/12/01 14. Number of acres in property Development Oil: Multiple Zone: Number 11. Type Bond (see 20 AAC 25.025) Amount U 62-9269 $200,000 15. Proposed depth (MD and TVD) feet 1,280 6,355' MD/6,350' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 499 psig At total depth (TVD) Setting Depth measured See Attached" Perforation Data Sheet" true vertical 20. Attachments: Filing fee: X Property Plat: BOP Sketch: X Diverter Sketch: Drilling fluid program: X Time vs. depth plot: Refraction analysis: Seabed report: 21. I herby c~ that the foregoing is true and correct to the best of my knowledge: Signed: /Dð~1A))~ Æ ~ Mmif)VI Title: f) ~llt I tAl; Ii ~ b 11 Commission Use Only / /I Permit Number API number , Approval date n /",,-, l / See cover letter DlO \.- \ ~ ¥ 50- ;)¥" ~ ~ ~ 0 aeo \ -(J \ v¡ Iff I /1 for other requirements Conditions of approval Samples required: [] Yes 1)( No Mud log required. [] es 'P\No Hydrogen sulfide measures [] Yes ~No Directional survey required [] Yes 'K No Required working pressure for BOPE [] 2M; ~3M; [] 5M; [] 10M; [] 15M Other: Top Bottom MD TVD 75' 75' 368' 368' 2,409' 2,409' 6,569' 6,569' 6,355' 6,350' MD 75' 368' 2,409' 6,569' 2,500' TVD 75' 368' 2,409' 6,569' 2,500' feet feet Plugs (measured) feet feet Junk (measured) Cemented Measured depth Driven 425 sx "G" 965 sx "G" 750 sx "G" 75' 368' 2,409' 6,569' Commissioner by order of the Commission 3,202 psig Quantity of cement (include stage data) Driven 425 sx 965 sx 750 sx 116 sx R E1- C E e V? F,': r"), I ¡.".~, I.", SEP 0 5 ?i'JU1 Alaska Oil & Gas Cons. Comrn¡s5íor~ Anchorage True vertical depth 75' 368' 2,409' 6,569' Drilling program: X 20 AAC 25.050 requirements: X Date: q)15J 'ð /' -t Date: q jj ~ /tJ' I I ' Submit in triplicate t , (' Procedure Summary of Proposed LRU C-1 rd (Amended 9/5/01) 20 AAC 25.005(c) 5,13 and 14 1) Kill well with 10ppg mud. 2) NU BOPE and pressure test to 3,000 psi. 3) Pull 1-1/4" CS Hydril Heater String 4) Pull seals from Packer at 2,714'. POOH laying down 2-7/8" Tubing. 5) RIH and set Bridge Plug at 2,675'. 6) Pump 366 sx cement through the retainer. The above covered under Sundry for Abandonment. 7) Set whipstock and mill window at 2,666'MD/TVD and drill 20' of formation. 8) Perform leak off test. 9) POOH with Milling Assembly. 10) Drill 6" hole minimum departure sidetrack to 6,355' MO/6,350' TVD (Upper Tyonek). 11) Run 5" Liner from 6,409' to 2,500'. 12) Cement with approx. 116 sacks of 12 ppg "Lite Crete" cement. 13) Set liner top packer at 2,500'. 14) Run 2-7/8" tubing and 1-1/4" CS Hydril heater string. 15) Stab 2-7/8" tubing into liner top packer. 16) NO BOPE/NU Tree. 17) Move rig. 18) Swab tubing for desired underbalance. 19) Perforate Upper Tyonek. The cuttings and mud generated from this project will be processed and injected into Ivan River 14-31 which is currently pending an Injection Order for conversion to Class \I Disposal Service. ( ( LRU C-1 rd Casing Design (Amended 9/5/01) 20AAC 25.005 (c) (6) 20 AAC 25.005 (c) 5,13 and 14 7" Production Casing: 26#, N-80 from 0 to 4,220' KOP (29# was also run but location in string cannot be substantiated so the design is based on the weaker of the two).: Worst case for burst would be in the event of a gas kick while drilling at TO. If the Maximum Anticipated Surface pressure were encountered, the SI pressure against the 7" production casing would be 638 psi. Burst = 638 psi. 7",26#, N-80 @ 7,240psi for burst Safety Factor = 11.3 OK Worst case for collapse is if lost returns occur while drilling below the 7" casing. Collapse = (9.5x.052x4,220')-(4,220'-.1) 26#, N-80 rated @ 5,410 psi collapse = 1,663 psi for full evacuation Safety Factor = 3.25 OK Tension = NA (casing already in place and cemented) 5", 15#, L-80 Buttress Liner from 2,500' MD/TVD to 6355'MD Burst: There are no significant burst requirements for a production liner Worst case for collapse is when the well is unloaded of fluid and has 0 psi Tubing Pressure, Collapse (9.5x.052x6350')-(6350'x.1) = 2501 psi for full evacuation 5", 15#, L-80 rated @ 7,250 psi collapse Safety Factor = 2.89 OK Tension = (6,355'-2,500') X 15# = 57K Rated = 350K for body yield Safety Factor = 6.14 OK ( ~ Lewis River Unit C-1 rd Cementing Program (Amended 9/5/01) 5" Liner 6" Hole @ 6,355' MD, Top of liner at 2,500' Cement Volume for liner based on open hole volume plus 20%, and shoe joints. Estimated Volume is: 6,355'TD-2,500'TOC = 3,855' x 0.05994 cuft/ft (6" hole x 5" liner) x 1.20 = 277 cuft 120' shoe track x .1059 cuft/ft (5" Liner Capacity) = 12.71 cuft Total Cement = 277+ 12.71 = 289.71cft or 116 sx (2.48 yield) of Lite Crete Cement @ 12 ppg wI additives. Lite Crete Cement is being used to mitigate any possible losses to the formation. UNOCALe L. R. C-O 1 RD Proposed Well Profile - Geodetic Report Schlumberger Report Date: Client: Field: Structure / Slot: Well: Borehole: UWI/API#: Survey Name / Date: Tort / AHD / DOl/ ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: September 5, 2001 Survey / DLS Computation Method: Minimum Curvature 1 Lubinski Unocal Only Vertical Section Azimuth: 130.000° Lewis River feali bil ity stud Vertical Section Origin: N 0.000 ft, E 0.000 f1 C-011 C-01 TVD Reference Datum: KB C-01 TVD Reference Elevation: 116.0 ft relative to MSL C-01 RD 502832006101 Magnetic Declination: 21.265° C-01 RD (P6) 1 September 5, 2001 Total Field Strength: 55635.730 nT 13.785° 1100.00 ft/3.140 10.016 Magnetic Dip: 74.024° I -~ NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: September 20, 2001 N 61.34287651, W 150.85259229 Magnetic Declination Model: BGGM 2001 N 2683768.000 ftUS, E 350296.000 ftUS North Reference: True North -0.74816700° Total Corr Mag North .> True North: +21.265° 0.99992550 Local Coordinates Referenced To: Well Head Grid Coordinates MD Incl Azim TVD VSec NJ-S EJ.W DLS Northing Easting (ft) (O) (O) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) ftUS 2666.00 0.00 130.00 2666.00 0.00 0.00 0.00 0.00 2683768.00 350296.00 N 61.34287651 W 150.85259229 2678.50 2.00 130.00 2678.50 0.22 -0.14 0.17 16.00 2683767.86 350296.17 N 61.34287613 W 150.85259132 2691.50 2.00 130.00 2691.49 0.67 -0.43 0.51 0.00 2683767.56 350296.50 N 61.34287534 W 150.85258938 2700.00 2.42 130.00 2699.98 1.00 -0.64 0.77 5.00 2683767.35 350296.76 N 61.34287476 W 150.85258790 2789.35 6.89 130.00 2789.02 8.26 -5.31 6.32 5.00 2683762.61 350302.25 N 61.34286199 W 150.85255630 3208.77 6.89 130.00 3205.40 58.59 -37.66 44.88 0.00 2683729.76 350340.38 N 61.34277351 W 150.85233672 3300.00 5.98 130.00 3296.06 68.82 -44.24 52.71 1.00 2683723.08 350348.12 N 61.34275551 W 150.85229213 3400.00 4.98 130.00 3395.60 78.37 -50.38 60.03 1.00 2683716.84 350355.36 N 61.34273871 W 150.85225045 3500.00 3.98 130.00 3495.29 86.18 -55.40 66.01 1.00 2683711.75 350361.28 N 61.34272498 W 150.85221639 3600.00 2.98 130.00 3595.11 92.25 -59.30 70.66 1.00 2683707.79 350365.87 N 61.34271432 W 150.85218992 ,"""""--- 3700.00 1.98 130.00 3695.01 96.58 -62.08 73.98 1.00 2683704.96 350369.16 N 61.34270671 W 150.85217101 3800.00 0.98 130.00 3794.98 99.16 -63.74 75.96 1.00 2683703.28 350371.12 N 61.34270217 W 150.85215974 3898.03 0.00 130.00 3893.00 100.00 -64.28 76.60 1.00 2683702.73 350371.75 N 61.34270069 W 150.85215609 5808.03 0.00 130.00 5803.00 100.00 -64.28 76.60 0.00 2683702.73 350371.75 N 61.34270069 W 150.85215609 6355.03 0.00 130.00 6350.00 100.00 -64.28 76.60 0.00 2683702.73 350371.75 N 61.34270069 W 150.85215609 Station ID Top Window Base Whipstock KOP 5/100 End Bid Drp 1/100 End Drp Target TO LeQal Description: Surface: 997 FSL 12 FEL S34 T15N R9W SM Tie-In: 997 FSL 12 FEL S34 T15N R9W SM Target: 933 FSL 5215 FEL S35 T15N R9W SM BHL: 933 FSL 5215 FEL S35 T15N R9W SM NorthinQ (Y) rftUSl 2683768.00 2683768.00 2683702.73 2683702.73 EastinQ eX) fftUSl 350296.00 350296.00 350371.75 350371.75 C-01 RD (P6) report.xls Page 1 of 1 9/5/2001-8:01 AM ( ( VERTICAL SECTION VIEW Client: Unocal Well: Field: C-01RD (P6) Lewis River Schlumberger UNOCALe - """- Q)..J ~C/) o~ a Q) a > ~ 0 II .Q 3000 c co .- <t= ~ a --- a .s::. . ......<.0 C. ~ Q)~ 000 m ~ 4000 0 .. .- 'to- t:: Q) Q)IX: > > Q) Q) 2W I- Structure: C-01 Section At: 130.00 deg Date: September 05, 2001 0 , I ------1----------1-------- I ; ; i I i I i ..1.--- .... I ! . ...... -Proposal -Survey 1000 2000 .............................. ..........................................................................."'.."'.........""""..........."'..."""'.................. ............................................................................................................................................ .......................................... Top Window 2666 MD 2666 TVD 0.00' 130.00' az 0 da artura Base Whlpstock2 78 MD 2678 TVD 2.00' 130.00' az 0 departure . ..-. KOP 5/10 2691 MD 2691 TVD . 2.00' 13000' az 1 departure ------"---End BI 2789 MD 2789 TVD 6.89' 30.00' az 8 departure -...-......-- .--_.____n...__...-.......- ----......---___..._n___...- Hold A gre6~ä9.õ-m_-_n.._.. -.~"'.-. Drp 1/100 3209 MD 3205 TVD 6.89' 13 .00' az 59 doparl ro ""."""""'."n"....... ....................................................................... ...................................................................... ..... End Drp 3898 MD 3893 TVD 0.00' 13 . 0' az 100 dopa ure ........................".. 5000 I ! I I i ! """'.""""""""""",""""""""""""""""""""""""""""""""""'""......................"""""'""""""""".""""""" ..... ......................................................................................................................................1........................................... I ! Hold An Ie 0.00° 6000 I i Target I . ~~~~ I ..............................t-..................................................................... .....................................................................................................""""""""'~~Ö~'~ëJ¡"~~~.~"~~"""""""""""""""""""""""'.""..j......................................... I I I I I I C-O1 TO 6355 MD 6350 TVD 0.00' 130.00' az 100 doparture 7000 .............................. """"""""""""""""""""""""""""""""""'. ..................................................................... """"""."""""""""'.."""""""'.""""""""'" ......................................................................!.......................................... -2000 -1000 0 1000 2000 Vertical Section Departure at 130.00 deg from (0.0, 0.0). (1 in = 1000 feet) KOP 5/100 ' Base Whipstock . 2691 MD 2691 TVD i ! 2678 MD 2678 TVD ¡ 2.00' 130.00' az ¡ --- !_:'";~oo'~~I/"E j, /R' 7__2789 t,1D 2789TVD ToPWondow/ ¡ 6.89'!T3"O.00----az-- 2666 MD 2666TVD! 58 ~ E ~',~n~æ I I UNOCAL8 0 ^ ^ ^ I I- 0:: 0 -20 Z -40 I I- :::> 0 en V V -60 V -80 --- PLAN VIEW Client: Unocal Well: Field: Structure: Scale: C-01RD (P6) Lewis River Date: C-01 1 in = 20 ft 05-Sep-2001 -20 0 20 40 ---- ----- -20 0 20 «< WEST 40 60 80 True North Mag Dec ( E 21.265° ) ~ Drp 11100 ¡ 3209 MD ~205 TVD 6.89' 13O.j:¡o' az 388 45E¡ -- -~- -- -- - --- -------- -- -- Target -------------- 5808 MD 5803 TVD 0.00' 130.00' az 645 77E End Drp 3898 MD 3693 TVD 0.00' 130.00' az 645 77E ~TD : 6355 MD 6350 TVD 0.00' 130.00' az 645 77E Schlumberger 100 ---- 0 -~---- -20 -40 ~--- -60 ------- ~----- ------ -----.-----.-------------+-- -80 60 EAST »> 80 100 ~, ,," ( I UNOCAL8 UNOCAL Alaska Drilling Department 8/13/01 To: Mr. Tom Maunder AOGCC From: Tim Brandenburg Ph. (907) 263-7657 Re: Lewis River C-lrd Schematics Pages including cover sheet: Mr. Maunder, Please accept my apologies for not having included these in the Permit to Drill. If you need me to re-submit the Permit to Drill with these included, let me know. Tim RECE IVED AUG 1 3 2001 Alaska Oil & Gas Cons. Commission Anchorage JØG IftDG 2-7/'. I.'" .-10 RrfUSS MØD HODEL 8XV1. WIUL%R. RftRIEVABLI ISn At 310' 1 ".8 ft)'IKLESS aft£L cœrraoL LID IWIDED wrm 10 8AU! onl -Vft. JÞ~ At'. 271. ' . . : OTIS -Vft. 'ACKIIt At'. 2912 I Oftl 8D.:,ILJDUQ SLU\'2.AIf 295..' . ~IDI ,8!,¡ft alas c sa 'fill DftAu,I. ' orIS .D~' SLIDI. 8L!1V8 At' 3'83'.' . . ' " ons -vaT8 PACKD A'f ..' 3-=t'1¿¡ "' ¡,': . , ...' . , Oft. 8SA 8 ILJDDlG SLIE\'B Alf 3761' " . OTIS 81. 81"r.a A't 421" œIB lfVI"AUB U-Blft'RY GDtDB .If 424" , . ," " (' Proposed Abandonment """ ,'~' . , ", ' ( LEWIS R~~ ~ FIELu WELL C-l ...... 'i,' ' .., . . , . '. . . " " I TtJBIN G D IT m.. ~ '20- . 7~ " 1. - '. . '" 2.. .1 :s. 0 ..t.. .' ,. ~.,. 7. 8. t. 10. ." . . " . . ' " . . . :: :..~~~~Ir.~. ' ,.. " ,. ..'."'. .. , ., õ:,.:.~".:~,:;,.,...:,:, . , '.. o"'~~:""""":"':!..., ,,"""::""'..:'..~, ':.,:':... ,.'., ,,". ;,","..:,/.. 8BO~ SDDQ 1';'1"4. cS' ftDRXL "' _XBG ~ A't 2019' '. , ".' , . , ' .. . " ..,:,':'\::;:;::;"":"Jr~\-:"':,:';'~P;,:"'¡:":"'\~~.' ',:..',-~,Io"" 0..::60, '...,-,"",\\. ,,¡:::...:,' ',." ':"'-':":"~"""'~ ,.>.'.' ::'.",,: ~"';'"~,"'i.I-'r:"""'õ:-c...-~AN",,,:.. '\"~!':':"?;""":~;o":I~\"':"~'ì.~..~~~:.i"'?:"'~~'-: ~...:.,:;..,.;"( ... ' '..-: :::. ... .: ':"'~;'~""':'" '~""":"':"": ":'~'f::::.4:'.;; ..~":'.t '.,~-+.o:.' :",':;.'~:;. . ~;" ",.:.;,.,..,:~",:..,.....,':',."..,.:..,...":'~:¡,~>'y':""\"':~:":;',',::-,.';'~" .,r-.,.:" De"".¡-ersetat .,.' ,".' ".'" "':" ."""",'6".', J ,.', .::'~.:' ~UI.&Ü "..'.'" ...'~'~"'.'":~I' ~"I"'" .,.."'0.," ~ ~~ <:tJ.;~*':"""""'~'A'~"":~;"":' ~.....~.~:..., ,'. "'....~I'" '.,' . ~;. '. ,; approxo 2,675' W:~,~~~,'¡~(~;~~~.,~(.:i;t':~,,:',:,~,;:;'~"t..~~~~i:;:;f~~~~,{~~~~j¡;...;~: ~~":11.'ë.;~1~'~.t ~:;, ,:.: ""';,.".'.,"',". '~f ' "......,; " ~ '\t~'~~r,"'¿; ~',-ti:,'J.'~'" ;;-:':f..I.:~~;:..;.....o"'4.~:: :,~'I::,:'~. I~, ':íi~~:~;'r:7t,~ ::";:-"(?':' ~~'~ J-¡':' r'::~' '", ,f:",',. ,;",.......,...."".,..,':;.:,'0:"", "',".4',::,,~' "";,,;"~,,""',",,,:,,",i.:,.',,:,'. .' PERFORATION RICORD .. , . ':,. 3 . :.!, ~, ,'r""""'"1":'_."...."-,,. ".".;".' '., . " ...".;q: .' ',' 'i.:~:'¡";~~ ".;' ,'",,\:'~~i:~'~ ' .7': ,2997';"3022~. ....: OPEl covEÌa.U) .:us ( ;~;"." :;a~i"\"':£""':";' "";"" "':,"; "':'3008'~303a" . ":8QZ'D DS'l .. . g.: >,;{_..::;~. 5' """, 31'9'-3190' SQZ'D Dft " ).;'~ff" .t";:'~. " 0 32""-3252' OPEl ,'.~,::r, "", - 0"", ..rs' -t.. - 3412'-3419' cpa ~"~~~~~ ". I" ~I:; ".":.;.~I; 34"2'-3458.! 0.. Dft 7 ¡'SO'-3110' .SQz;» DSf ',~, "~"""'~ ~""~~~~.t:+ ':;:':~"I:;::i1'I' '0 ì~794" ' . ..' .. :. OÍiD ", '. "'" ' .. ' . . .. ,:. ~~...", .' .;.. . ,.' . . .t. , ":::'~.:,~'::::~;~:'.',':::' . í":"" ',' ,~"","","'~'" .'.. ,.,...'"..,...::,...,.,.~..¡. 8--3904, ": ...08a",.... , ,.aD ..',. .." ',' ',",!-'..~,":;':""3'3Ò'-3137' ..':'::.opa' ., ",.,._",~. :"~ ': :.'" :J,~~..:.;.,.,~,..::,~,..."j.57.-31'a~..:""'~-~ ,":"'~; '. '.'IIB':'" ~.:..~,,', "'ò: ,-r "..:' .4050'-"0"" . 0.. Dft "'",'" ,I "':" ,- ,," .. :." 411.'P411I" œBl lIB '. :. 4181' -111'" OPD 118 . . 4305' -4335' SQS' D Dft . ,4450' ';"¡..70' 8QS' D . Dft 4473' -&411 ~ SQS' D Dft . . 580"-5812' 5114' -583'" 583" -58'" ' ,SUI'-sa,,' . 5876'-58'9' :' 5'12"-581" .,' . '. 1130'-"4'" , .. ,~...~,.~,'~';',:-:"':~:""'~""""~"""""":'~".'~"":' ..~~,~. .,,~.:. '0'8'~'0~' 612"-6i4¡' '~::"~":'~., - ' .,' .A.,. , . .', , ;~~:...<"\'.. '.'""'f.~.'.., '\1.';',~... '.. ' ,. "~.'~"~': -: ,"",~f~I'\';.r»-...;o,;\o..,:...,. . r" ~/;'.~":"; ;.~, ,\0 ':':::";::'X ;.>,:,.:,~~~.: ", :ro",,:-.,:' "","\",.,:,",,;,,:,.:..:..J"'. .:",',.'\' """.:":~"'..-:",... ':\\t,~oic:':' :,: '~"-~"'" (;...'...::.¡~. ~,;~,:,;,:, ' iI~,~~.,\......!",.. .';,,¡/"':t.i.":;.~~,r',:;;,¡,. 4:,.Y,t,...,.r.'I,:r...' . ,'"11' .,', . 'L:..~1V'_~,,"~""~"""'¡""-:-"- ~ . ..'..' ,. \,. :,:.. p-,iJ ..47 I"'r."""""~' "'t'"".~..,, ,'. ',.'.' , , I' ~\.' i;~'~~:"'::.'~':~¡.$.~' '~l" 2.409",:.:',:l'~~;, ' t:'.".', ':,," ""'."",. , . ,..'" . . : ~ TS "i:à-\ c.:r re~Þ ~ ~1 ~ '... !>O"i."£ . .' , I, S2.'fcJ- ,.¡~ !:'~':. ",:":"'>~~..j .:,~.!~~~~.. :.:'.. :. ,..' ~"-r"'~ ,~,,~:""o?"". ..,' . to' ' . , , " " .' ,', r ~,. ,UPPER BELUGA 2. 2745'-27.7' 2751'-277.' :ESOLA~JO. 8QZ SQIID Dft ' . " , ".." .' Toe. 1508' EZSV . 8&09' ; SQZ'D .QI'D 8QI'D ,SQI'D Dft SQZ'D SQZ'D SQZ'D " "', .' ..' ". '. . ' ~ I . , ' '. UPPER " . ", . 1YONEK ,¡ i o. i ~"" "'~~ ",,"', .,:~ : : Toe 8.IO1â . "." 'EZ!aV.' 1025' , , . EZ!V .. .1110' 7" 28 Ie 29 . 856S' . ' '," . , .' , '. . . " . . ~, ' '. , f.'~ ,,: :.., '. ',: "', '. ", "" y ."" ."" ' , . , .,..,:",:""\\",..""'".,:,,,, . ., .,'. " :" .'., : .,;0, ,""Y ... ", , "': . " T ,; ""' . . , ' .. . U8 DB 0" ÐB '," . . . " . -, .'~ ,.' " '. VI' ft 1ft ft Vf 1J'I VI '. ' I , O'ER . ,~',"'..' ",,:':~':""."':"~~,"":" ........." DS't :ESOLA~ .. Dft ISOLATED ,'. O'ER . , . . . " " QR8 12-15-81 ~: ( .Jewis River Well C-lrd Proposed UNOCALe RKB = 14.5' 1 "I SIZE WT 20" 13-3/8" 54.5 9-518" 47 7" 26 & 29 5" 15 Tubing 2-7/8" 6.4 1-114" CASING AND TUBING DETAIL GRADE CONN ID N-80 Butt SC CS Hydril TOP BTM. 75' Surface 368' Surface 2,409' Surface 6,569' 4.408 2,500' 6,355' 2.441 5,780' 2,400' L-80 Butt NO. 1 2 3 Depth 15' ID JEWELRY DETAIL OD Item Dual Tubing Hanger, 2-7/8" x 2-3/8" DCB 9" 5M Sliding Sleeve, 2-7/8" Butt HMC/ZXP Liner Hanger 2,500' A 2,400' Heater String 1-114", CS Hydril A PERFORATION HISTORY Interval Accum. Date Zone Top .ßtm Amt spf Comments Proposed 5,820' 5,900' 80' Proposed 5,930' 5,950' 20' ---- 2 3 ¿] TD = 6,350' TVD Max Hole Angle = 6.89 deg @ TD LR C-1 Proposed Rev IV.doc DRAWN BY: tcb REVISED: 12/21/98 , . { \ " .. . ... ( '. , '.\ LEWI S RIVER ~ FIELu . , ' ,WELL C-l . ' TUBING DETAIL 3, 4 "" , " ,-::,':-,..:::/::;,> ",..' o)99'7';"'30"~'~ .. opeN CO.'ERLAP' ,) ',"B ' ,,' '",' ',""",', ",8 .-', C'" ... 'i :... .' ";"""';',:'" "':'3008'-3038" ":SQZ'D DST ' 5 c.¡,,' f , 3169' ~3190' SQZ 'D DS'! . 3246'-3252' OPEN 6 3412'-3419' OPEN 3442'-345~~ OPEN DST :,:..,:,,~, ,.?,t;~~~",:" ", "," ,~.. , , ..,', , 7 "..', 3650'-3680' .SQZ:'» DST '. ".,- :""c.U'" ~,,~:"':'t,".¿f;~~"'-~~'~~ 'x/.. ":~8"':"""'" .";"':""":':""<"':"':""':""','::'~7å'o"~794' ""',"'OPU'" ,', '" :",::"""l '.;)'J~~',"'~~:", ,"""',', " ,,', ":',,,:,' :':."':""::"':',"'\::'<"':":'389'8'-3"904,", "~"~opeD " ' I"""'" "", '",','," ',' """"""""""" "',' "l;MJ'"", :':':":',...:.',,"" "',""':".':"""""'" ",..' .. ..' ",',', '-:-::'","',"",'~930"'3937' ,,':'OPEH'" , " ", " UIDDLÈ, :,' , 4'b4""::,"""<::-':,':"'3~57'-3960"'" ,',":", "OPEN' ,'" ,', " ~"""" ".'",," '- ': 4050'-4064' OPEN DST BELUGA' , 9,,"'" " :', : 4114'.4118;' OPEN , 10 ",' . ,'4181'.4189' OPEN , '.4305'-4335' sgZ'D DST . 4450'~4470' SQZ'D 'DST 4473'-4491~ SQZ'D DST '. -°20" . 7S' " ' ", 13-3/8H 54.51 ' : .,' Ó 368' , : ~:rs ~ (.:- re~Y~~Þ 7/111-"" ~O"2,"l.' I , i, S 2.'1 ~ ... "g '2~, ;>,' ':',',':,.'",: " ""'~(;'on?,t ',,", :"',"~':':t,¡'JiJ,',-""¡.i;;"~';',~~,, ,":","" ," .;:>'r'-'"c:;,;","',;:;;>,,""'" I" ' ' ¡, , ' . UPPER BELUGA I :' ¡ , Toe 0 ISOS' EZSV . 5609' UPPER TYONEK " " ': ":", ", ':. ','.,',' , ,':: ' : Toe 0,6010' :" "EZSV 0: 6025' . . , EZSV '06110' "1 26 ck 29f 0 65691 - SaV ., ," ", , " ' . 1 ' ~~G STRING 2-7/88 6.4' 1-80 B~RESS BA"ER MODEL 8)."\'E- WIRELINE RETRIE\'ABLE SSSV AT 310' 1/4. STAl~USS STEEL CONTROL LINE BANDED WITH 1 0 BA"~DS 2., ,I OTIS .VST- PACKER AT 0 271.& ' ' : 3. ' OTIS .VST8 PACEER AT 2912' . ..... OTIS -SA-: SLIDING SUE\tE .AT 2954' ,.,. 'CARBIDE BLAST RINGS CSEE THE OETA'IL), , 6. 0'1'1'5 .n.' SLIDING SLEEVE AT 3683',' 1. . OTIS 8\'51'8 PACKER AT ~' 3::rU,~/ ' > ': 8. O'1'IS 8XA. SLIDING SLEE\'E AT 3761' , 9. 'OTIS 8X. NIPPLE AT 4216' 10. OTIS WIR£LIIE BE-ENTRY GOIDB AT 4249' 1. . , ~, " '., . , ", ':-.." ,','...., '" 0' ",', ' " , ' " ' , ' , ,', ,,:0,' '", . ':' ~ :..-,',,':,.' ,',' .': "0."",, ,',"" "'" ,', ':'.' , ".'. ' ' " " , ' ,': ", .",c," ,'," ':, Co , ", . , ,A." SHORT STRING 1~114. CS B!DRIL TOBING TAIL AT 2019' " , , ' ' , . " , .', ',' ,"" , 2" Ii ";:::'~:~:,:::r::;i":':"';:);::::"""\::.,:"\,t,: ',!\::\:,;;:'\"':::\(:":'::~,:':~\;,,~~,";::,""::':>..'>:~:" \ ", PERFORATION RECORD 2745'-2747' 27511-2778' ISOLATION SQZ SQZ'O OS'!' , ' , ":':~"":""",->,:,..."','~">'.,:",:, ',', , , . DB DB OB " " ,'æ:"'",.,",,','" "",.'. ":,,'MB',':'" " :': ':, ' ",.: ' , , , , , 8" MB '.' " , ./ 131' 0'1' I 1r1' UT 01' OT aT SgZ'D SgZ'D SQZ'O ,SQZ'D J)ST SQZ'D SQZ'O SgZ'D 5808..' -5812' 5814'-5834' 583,7' -5846' 5849'-5869' 587"-5879" .'. 5882"-5898' ",'".'.." 5930'-~946" ' , """':"""""'~:,""':""" "'..,..,',,..~~~';~~~'~~~'o~ "'::'. 61261-61"6' / , " ",' ',' ",'" ": ' '... "" :" ,',', ',",.' ".".':,": ..', " ...'"", OPEN DST ISOLATED ',' ' , DSR rrtW l ~-15-89 AUG 1 3 ZOO, . Alaska 011 & Ga~ cons, Commission A\1cnOraaø OPEN ^ ~nl~^~n-~ (, UNOCAL8 (.LORi eWIS ver Well C-lrd Proposed CASING AND TUBING DETAIL GRADE CONN ID TOP BTM, 75' Surface 36S' Surface 2,409' Surface 6,569' 3.95S 2,500' 6,409' 2.441 5,7S0' 2,400' RKB = 14.5' 1 SIZE WT 20" 13-3/S" 54.5 9-5/S" 47 7" 26 & 29 4-112" 12.6 Tubing 2-7/S" 6.4 1-114" NO. Depth ID 1 IS' 2 3 2,500' A 2,400' L-SO Butt N-80 Butt SC CS Hydril JEWELRY DETAIL OD Item Dual Tubing Hanger, 2-7/8" x 2-3/8" DCB 9" 5M Sliding Sleeve, 2-7/8" Butt HMClZXP Liner Hanger Heater String 1-114", CS Hydri1 PERFORATION HISTORY Interval Accorn. Date Zone Top Btm Amt spf Comments Proposed 5,820' 5,900' 80' Proposed 5,930' 5,950' 20' i " i "':i. 2 .. " A 3 LI ."" TD = 6,350' Max Hole Angle = 3.54 deg @ TD LR C-l Proposed Rev III.doc DRAWN BY: tcb REVISED: 12/21/98 \ ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ,>ùQ~~~d ~(S- 20 AAC 25 005 / ,'\ . / 1a. Type of work Drill: Redrill: X 1b. Type of well Exploratory: StratigraPhi~~: Development Oil: Re-Entry: Deepen: Service: Developement Gas: X S' gle Zone: Multiple Zone: 2. Name of Operator 5. Datum Elevation (OF or KB) / 10. Field and Pool Unocal 100' GR/16'KB feet Lewis River 3. Address 6. Property Designation / P.O. Box 196247 Anchorage, Alaska, 99519-6247 ADL 58798 4. Location of well at surface 7. Unit or property Na7 11. Type Bond (see 20 AAC 25.025) 0' FWL, 1,000' FSL, Section 35, T15N, R9W, SM Lewis River At top of productive interval 8. Well number / Number Same C-1rJ U 62-9269 At total depth 9. APproximaiPud date Amount Same 9/1/01 $200,000 12. Distance to nearest 13. Distance to nearest well 14, NU~Of acres in property 15. Proposed depth (MD and TVD) property line 1,000' feet 3,021' feet 1,280 6,409' MD/6,350' TVD feet 16. To be completed for deviated wells 17 'z.~iciPated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 4,220' feet Maximum hole angle: 3.54 Mé ¡mum surface 499 psig At total depth (TVD) 3,202 psig 18. Casing program / Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Leooth MD TVD MD TVD (include stage data) Existing 20" A /15' 75' 75' 75' 75' Driven Existing 13-3/8" 54.5 A /368' 368' 368' 368' 368' 425 sx Existing 9-5/8" 47 A 1/ 2,409' 2,409' 2,409' 2,409' 2,409' 965 sx Existing 7" 29-26 N-80 I 6,569' 6,569' 6,569' 6,569' 6,569' 750 sx 6" 4-1/2" 12.6 L-80 / 3,600' 2,500' 2,500' 6,409' 6,350' 86 sx 19. To be completed for Redrill, Re-entry, and Deepen 0 erations. RECEIVED Present well condition summary Total depth: measured 6,570' feet Plugs (measured) true vertical 6,570' feet 1 3 2001 AUG Effective depth: measured 5,6 9' feet Junk (measured) Alaska Oil & Gas Cons. Commission true vertical 5 09' feet Anchorage Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 75' 20" Driven 75' 75' Surface 3 ' 13-3/8" 425 sx "G" 368' 368' Intermediate ~09' 9-518" 965 sx "G" 2,409' 2,409' Production ,569' 7" 750 sx "G" 6,569' 6,569' Liner Perforation depth: m sured See Attached" Perforation Data Sheet" rue vertical 20. Attachments: ~~ fee: X Property Plat: BOP Sketch: X Diverter Sketch: Drilling program: X Drilling fluid progr : X Time vs. depth plot: Refraction analysis: Seabed report: 20 MC 25.050 requirements: X 21. I herby certi~ze foregoing is true and correct to the best of my knowledge: d~~ I ~ N' I' t !IJ. g'~-{)l Signed: J rM hv ~ Title: J tY-t[ IVli¡ laY', Date: , Commission Use Only I J . Permit Num~~ ;¡ API number Approval date See cover letter z.ð!- b' 50- ;2? 3- 2.0C> b 1-0/ for other requirements conditi~ approval Samples required: [] Yes IX'No Mud log required: [] Yes ~No Hydroge sulfide measures [] Yes M No Directional survey required [] Yes 'WNo Require working pressure for BOPE [] 2M; [] 3M; [] 5M; [] 10M; [] 15M Other: by order of Approved by Commissioner the Commission Date: Form 10-401 Rev. 12-1-85 OR\G\NAL Submit in triplicate , . h ( ,1 i( Procedure Summary of Proposed LRU C-1 rd 20 AAC 25.005(c) 5,13 and 14 / 7~>i / ~OJ p~~ t;" ( ç 2) NU BOPE and pressure test to 3,000 psi. /, . Pull 1-1/4" CS Hydril Heater String . . 1) MIRU. 4) Pull 2-7/8" Tubing completion removin , packers at 2,714',2,912' and 3,716'. 5) RIH set Bridge plug at 4,220' (Belo lowermost productive perforation). 6) Set whipstock and mill window a d drill 20' of formation. 8) POOH with Milling Assem y. # 7) Perform leak off test. 9) Drill 6" hole minimum' parture sidetrack to 6,409' MD/6,350' TVD (Upper Tyonek). . 10) Run 4-1/2" Liner fro 6,409' to 2,500'. i 11) Cement with ap , ox. 86 sacks of 12 ppg "Lite Crete" cement. 12) Set liner top cker at 2,500'. 13) Run 2-7/8',~' ubing and 1-1/4" CS Hydril heater string. 14) Stab 2-7178" tubing into liner top packer. 15) ND B PE/NU Tree. 17) wab tubing for desired underbalance. 1 ) Perforate Upper Tyonek. The cuttings and mud generated from this project will be processed and injected into Ivan River 14-31 which is currently pending an Injection Order for conversion to Class II Disposal Service. { " ~l Lewis River C-1 rd Hazard Analysis for APD 20AAC 25.005 (c) 4 (A) The maximum original pore pressure occurred in a sand interval from 2,990'- 3, 065'. While drilling the original well a flow was detected while tripping out of the hole. The flow was controlled with a 10.5 ppg mud though mud weight was allowed to climb to 11 ppg. It is believed that the interval was swabbed in during the trip out of the hole. The apparent original over pressure in this interval appears to have been an isolated anomalous occurrence. OST data for the intervals below this sand indicate pore pressures between 8.8 and 9.6 ppg. Additionally other wells in the area were drilled with mud weights ranging from 9.2 ppg to 10.7 ppg in the same interval. Most notably, LRU B-1 was drilled through the entire interval with a less than 10 ppg mud weight. (See C-1 rd Offset Mud Weight Attachment). This zone has been commingled with other Upper Beluga Intervals and has been in communication/production since the wells original 1979 completion. The zone is believed to be partially pressure depleted at this time with a reservoir pressure estimated at 1,496 psi at 3,022' (.49 gradient or 9.52 ppg EMW). If for any reason this interval is still significantly over pressured it will be identified once the well is displaced with kill weight fluid. The well will be killed initially with 10 ppg mud. The well design is predicated on using an 11 ppg mud weight with a 9.7 ppg EMW pore pressure at TO. (B) While losses were not recorded in the drilling of the original well in these intervals, lost circulation is a possibility in the pressure-depleted intervals. The Upper Tyonek is estimated to be at a .34 psi or 6.6ppg EWM, Adequate supplies of lost circulation material and water will be kept on the C-1 rd location before drilling commences. Crews will be briefed on the strategy for dealing with losses should they occur. (C) H2S production has not been identified in any of the West Side Fields operated by Unocal. ¡( (, Lewis River Well No. C-1 rd Bottomhole Pressure Information The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the LRU C-1 rd. Lewis River C-1 was originally drilled in 1979 by Cities Services. At that time it was the third well to be drilled in the Unit. A flow occurred while tripping out from 3,044' TVD with 9.7 ppg mud. It is believed that this kick was swabbed in. The mud was weighted up to 10.5 ppg to kill the well. The mud was raised that same day to 11-10.9 ppg with no indication as to why. The well was drilled without further problems. The pore pressure gradient was estimated from the following information: Initial Well BHP ~ ~ 9.52 Depth TVD LRU C-1 1 ,599 3,227' 1,860 3,984' 8.97 2,760 5,877' 9.03 3,202 6,350' 9.7 LRU A-1 2,037 4,158' 9.42 2,666 5,247' 9,77 Current BHP Depth Well ~ TVD ~ LRU C-1 1,387 3,227' 8.26 1,713 3,984' 8.26 2,016 5,877' 6.6 3,202 6,350' 9,7 Comment 7/79, initial BHP before production 7/79, initial BHP before production 7/79, initial BHP before production 9/75 Comment Post Production Pre Depletion For this design, a shoe depth of 2,745' TVD is being used as this is the uppermost set of perforations in the 7" production casing string. The fracture gradient at this point is ( ~... <- conservatively estimated at .75 psilft or 14.5 ppg. This number is derived from a positive test obtained against the perforations with a 10.9 ppg brine completion fluid performed during a 1989 workover. Additionally this design assumes a worst case kill weight of 10.5 ppg for the zone at 3,044'. Additionally the design assumes a 9.7 ppg equivalent pore pressure at TD. Casing Pore Casing Setting Fracture Pressure Mud Pore ASP Size Depth Gradient Gradient Weight Pressure Drilling {kù (TVD ft) (Ibs/gal) (Ibs/gal) ~ ~ ~ 7 2,745' 14.5 9 11 1,284 495 4-1/2 liner 6,350' 15.38 9.7 11 3,203 Procedure for Calculating Anticipated Surface Pressure While Drilling ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat (with gas bubble just below shoe and mud gradient above shoe) or 2) formation pore pressure at the next casing point less 3/4 gas gradient and 1/4 mud gradient to the surface as follows: 1) ASP = (FGx.052xD) - (MWx.052xD) = (14.5 x .052 x 2,745) - (11 x .052 x 2,745) = 499 psi OR 2) ASP = FPP - (0.1 gas gradient x D x.75) - (MW x .052 x D x .25) = 3,203psi - (.1 x 6,350 x .75) - (11 x .052 x 6,350 x .25) = 3,320 - 476 - 908 = 1 ,819 psi 2 LRU C-lrd ( ( Kick Tolerance for LRU C-1 rd With 11 ppg mud in the hole and a gas bubble in the well and an estimated shoe frac gradient of 14.47 ppg, the shoe will fail at 495 psi of surface pressure «14.47-11) x.052 x 2,745'). At the most vulnerable point for shoe failure when the gas bubble is just below the 7" casing shoe (or in this case shallowest perforations), the hydrostatic pressure situation will be as follows: + 499 psi max surface pressure without fracturing the shoe + 2,745' x .052 x 11 ppg mud in the surface casing = 1570 psi + Gas height (Ht) x 0.1 psi/ft gas bubble just below surface casing + (6350'-2,745'-Ht) x .052 x 11 ~ mud below the gas bubble = 9.7 x .052 x 6,350' TVD = 3,203 psi estimated formation pressure Solving the above equation for Ht: 499 + 1,570 + 0.1 Ht + (6350'-2745'-Ht) .572 = 3,203 499 +1,570 +0.1 Ht + 2062 - .572 Ht = 3,203 928 = .472 Ht Ht = 1,966' (TVD height of gas bubble just below shoe which will cause shoe fracture failure) The gas volume is 1,966' x (.0194 bbl/ft for a 4" Drill pipe x 6" annulus) = 38 bbl If the gas volume at the shoe is 38 bbl, then the original gas kick volume when it first entered the wellbore at 6,350' TVD would be: P1 xV1 = P2XV2 P1 = 11 x 6,350' x .052 = 3,632 psi hydrostatic pressure at TD V1 = X, unknown gas volume at TD P2 = (499 psi surf pressure wlo fracturing shoe) + (11 ppg x .052 x 2745') = 2,065 psi pressure at shoe V 2 = 38 bbl gas bubble just below 7" shoe V1 = 38 bbl x 2,065 psi/3,632 psi = 21 bbl kick tolerance at 6350' TVD. This size of kick should be able to be detected with close monitoring of the trip tank and with the help of a mudl°!1I1ing unit which will be operating during the drilling of this well. 3 LRU C-lrd ( ~ ~ q¡ ~. <::> ~~~Q cJ S LRU C-1 rd Casing Design 20AAC 25.005 (c) (6) 7" Production Casin : 26#, N-80 from 0 to 4,220' KOP 9# was also run but location in strin cannot be substantiated so the de n is based on the weaker of the two ).: Worst case for burst would be in the event of a 9 s kick while drilling at TO. If the Maximum Anticipated Surface p ssure were encountered, the SI pressure against the 7" production casing wo d be 495 psi. Burst = 499 psi. 7", 26#, N-80 7,240psi for burst Safety Factor = 14.6 OK Worst case for collapse is if lost re rns occur while drilling below the 7" casing. Collapse = (10 x.052x4, 0')-(4,220'-.1), 26#, N-80 rated @ 5,410 psi collapse = 1,772 psi for II evacuation Safety Factor = 3.14 OK Tension = NA (casing alre y in place and cemented) 4-1/2", 12.6#, L-80 Bu ress Liner from 2,500' MDITVD to 6409' TVD6350'MD Burst: There is no gnificant burst requirments for a production liner Worst case for c lIapse is when the well is unloaded of fluid and has 0 psi Tubing Pressure, Coli se (1 Ox.052x6350')-(6350'x.1) = 2667 psi for full evacuation 12.6#, L-80 rated @ 7,500 psi collapse Safety Factor = 2.81 OK Tensio = (6,409'-2,500') X 12.6# = 49K Rated = 288K for body yield Safety Factor = 5.877 OK ..'. \ ( Lewis River Unit C-1rd Cementing Program 4-1/2" Liner 6" Hole @ 6,350' MO, Top of liner at 2,50 Cement Volume for liner based on 0 en hole volume plus 20%,and shoe joints. Estimated Volume is: 2,000' (6,350'-4,850') x 0.08 cuft/ft (6" hole x 4-1/2" liner) x 1.20 = 206 cuft Total Cement = w/ additives. ft/ft (4-1/2"" Liner Capacity) = 6.83 cuft 6+ 6.83 = 213 cft or 86 sx (2.48 yield) of Lite Crete Cement @ 12 ppg Lite Cre Cement is being used to mitigate any possible losses to the formation. ':>Ù~CLQ~~ ~{c; ." UNOCAL8 2000 4000 6000 ê ~ s::: ... c. () c 8000 10000 12000 14000 8.00 0 9.00 10.00 Lewis River C~1 Offset Mud Weights -+- LRU C-1 --+- LRU No.1 -+- LR No. 0-1 LR No. B-1 ~. LR No. 13-2 11.00 12.00 13.00 Mud Weight (PPG) 14.00 15.00 16.00 LRC-O1RD Proposed Well Profile - Geodetic Report July 13, 2001 . nocal L~ver C-O11 C C-01 C-01RD 502832006101 C-01RD (P2) I July 13,2001 3.536° / 133.80 ft 12.6751 0.021 NAD27 Alaska State Planes, Zone 01, U N 52 47 34.505, W 1334041.219 N 350296.000 flUS, E 2683768.000 flUS +D.06466420° 1.00087250 Repo~ Client: Field: Structure I Slot: Well: Borehole: UWIlAPI#: Survey Name I Date: Tort I AHD I 0011 ERD ratio: Grid Coordinate System: Location LatILong: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: Station 10 MD eft) - 4217.00 4229.60 4242.60 4274.91 5861.07 Top Window Base Whipstock KOP 5/100 End Crv Target TO 6409.11 Le"al Description: - Schlumberger Survey I DLS Computation Method: nly Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Minimum Curvature I Lubinski 90.000° N 0.000 ft, E 0.000 f KB 116.0 ft relative to MSL sibility study 3.54 90.00 6350.00 Surface: 28653181 FSL 5436125 FEL S1 T105S R82E CM Tie-In: 28653181 FSL 5436125 FEL S1 T105S R82E CM Target: 28653222 FSL 5436028 FEL S1 T105S R82E CM BHL: 28653236 FSL 5435995 FEL S1 T105S R82E CM C-01 RD (P2) report.xls Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .) True North: Local Coordinates Referenced To: 21.684° 55252.889 nT 70.910° August 15, 2001 BGGM 2001 True North +21.684° Well Head ~. DLS e/100,!!! 0.00 ~ 0.00 5.00 0.00 Geographic Coordinates Latitude I Longitude N 524734.505 W 1334041.219 N 524734.505 W 1334041.215 N 524734.505 W 1334041.208 N 524734.505 W 1334041.183 N 524734.505 W 1334039.592 133.80 0.00 133.80 0.00 350296.15 01.92 N 52 47 34.505 W 1334039.042 Northin" (Y) rftUS1 350296.00 350296.00 350296.11 350296.15 i ] ~ ~ r--- \f, -- Eastin" eX) rftUS1 2683768.00 2683768.00 2683868.09 2683901.91 Page 1 of 1 7/13/2001-9:39 AM ( ( VERTICAL Client: Well: Field: SECTION VIEW Unocal C-01 Schlumberger Lewis River UNOCAL8 .- ~ .- CJ.).....J ~(f) o~ 0 CJ.) 0 > T""" 0 II .Q 3000 c m .- Lt= T"""O """"'0 ..c . ~c.o Q.T""" CJ.)T""" 000 m ~ 4000 u .. . - ..... t CJ.) CJ.)e::: > > CJ.) CJ.) ::J- s....W I- Structure: C-01RD (P2) Section At: 90.00 deg Date: July 13, 2001 0 i ..........t....................... """"""""""""""""""""""""""'"... 1000 ! i ..............................................................................................1.................................................................... I I I I I I ...........1...... .....j................. I I 2000 "'..'..'.".'.'.".'.."'.'...""...'....'.".".".'...1.'.""'................................. ."""""..'..'.'.'..'."..""'....... -......................................... ............................ I I I ToPwindow4217JD 4162TVD * 0.00' 90.00' az 0 ~' perturB ...... I BII. Whlpltock4 30 MD 4175 TVD """"""""""""""""""""""""""""""""'" /". , ..,.......".".".....,.. """"""""""""""",""'......, , ' ' ",,/ 1.92 90.00 az departure .............,........"., ':~~:'::';~~"::~='~~'~"~;~~~'~;~;'~~""~'~~'~"~~""'"""""""",,"""""......, ...,..,....,............................,.., ::..."-.....,,...- 1.92' 90.00' ez 11 departuro '-. End Cry 4275 M 4220 TVD 3.54' 90.00' e 2 doparlura 5000 """""""""""""""""""""""""""" """"""""""""""""""""1""""""""""""""""""""""""""""""""""" """"'......................................"....................................................."""""""""""""""""""""""""""""""""""""""" II Hold Anglt 3.540 , I I Targat I I .---------.--- ~~5~~ M~.~O~O:z TVD .., '-""'-"I...--._.--.__.__......'~:""'r......._._-_."_'_-_" 6000 C-O1 7000 i TD I 6409 MD 6350 TVD i 3.54' 90.00' az 1 134 departure I . i ........................... """""""""""""""""""""""""""""""""" """""""""""""""""""'..................,.......... ..................................................."...............'................................................................. """"""""""""""""""""" -2000 -1000 0 1000 2000 Vertical Section Departure at 90.00 deg from (0.0, 0.0). (1 in = 1000 feet) UMOCAL8 ^ ^ ^ I l- e::: 0 z I I- ::::> 0 -20 C/) v v v 0 40 True North Mag Dec ( E 21.68° ) 20 I Â I-Proposal ~1\T~ -SuNey i~ -, i Top Window i 4217MD 4162TVD ¡ 0.00' 90.00' az : ON OE , ! ! Base Whipj;tock ¡v........¡ 4230MD 1175TVD , ; 1.92' 9O.00'az ! / ON OE I C-O1 V ¡ 7~ ' KOP 5~OO End Cry , 4243"ÌD 4188TVD 4275MD 4220!JVD 1.92' pO.OO' az 3.54' 90.00' ao! "'I "" I 0 -..---- -40 0 20 PLAN VIEW Client: Unocal Well: Field: Structure: Scale: Date: C-01RD (P2) Lewis River C-01 1 in = 20 ft 13-Jul-2001 -.--....- -- 40 «< WEST 60 100 120 80 Target 5861 MD 5803 TVD 3.54' 90.00' az 0 N 100 E / . . . . . . . . . . . . . . . . .. -,.--..-...--.. --.. --..... -.- ~..... - ....-..- ............ ..._... --."-..."-"."."-"".."""."-... 60 100 120 80 EAST »> Schlumberger 140 40 20 0 TO 6409 MD 6350 TVD 3.54' 90.00' az 0 N 134 E -20 -40 140 .. ~. .J' rO f'-.. '^' .'-', ( ( 99 I' 4 '" " - - Q. r; - - ~ ~ C\ " - ~ . Q I b - 1"1 f') GROUND LEVEL ELEVATION B.O.P. STACK' ALl. FlANGES 11- . 5000 * UNL.ESS NOTED OTHERWISE 1/2.. SPACINGS ARE SHOWN FOR RING GASKE'I'S " DRiLUNG INC. rlg9 B.O.P. STACK SCALE: 3/8. = J '-0" October. 1998 , . , ' ( TO FLARE m 9 A @œ@ TO FlARE ~' TO DEGASSER - t- .,' m PLAL'T VIEW CHOKE LINE FROM B.O.P. SECTION' AA ' ~ DRILLING INC. Rig 9 Choke Manifold 3" x 5 000# , 6'.4' 4' 4'.6' . MUD MIX HOPPER 6'.4' -D---$-----JCJt MUD MIX HOPPER ~ -- 6' ~ q DISCHARGE 6' MANIFOLD 6' DESIlTER 6' 6' 6' 6' 6' G PIll TANK B LEGEND -D- CONCENTRIC REDUCER @J BOTTOM MUD GUN lOW PRESSURE TYPE - GATEVALVE ---iNJ- BUTTERFLY VALVE C/W FlANGES X AGITATOR -y SUCTION VALVE, TEE TYPE ~K EOUAUZER ,- ~ SUCTION VALVE, Ell TYPE OR SKIMMER 10" :> S' flOW UNE TO MUD PUMPS )t -ìir }( 3' B MUD SYSTEM SCHEMATIC 10" 3' B NOT SHOWN ARE TANK CLEAN-DUTS SUMP SUCTION OR STEAM TRACE UNES Total Active System = 1,135 bbls (Not including Trip Tank) TO SUMP 10' 6' ~xo Degasser 3. B WEll RETURNS 12' 12". ....--~ S""" SHAK..:-r¡ rr ,"ALE SHAKER ~ )( 3' 3' FROM MANIFOLD 8' 368 MUD GAS SEPARATOR TO Fù\RE 8- .:. =ïì S' 3' B 8".3' II. .RkR 6' <: EJ TRIP TANK ,. 1OEVI81ON ... 1-.1 110m DRILLING INC. ~- MUD TANK SCHEMATIC RIG 8 @-EJ- FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WERE SUBMITTED ~.~ ~~~. ...~.... .. ~ .. NVØJøErCBEahTMEN10~NQ;. ... OS-AUG-01IDRILLPERMITC1RD IOSO13000352 C-j r< f) FORM 4-2B181 (REV. 11-95) PRINTED IN U.SA DETACH STUB BEFORE DEPOSITING CHECK CITIBANK DELAWARE A"'Sub"sidiary of Citicoip ONE PENN'S WAY NEW CASTLE, DE 19720 62-20 311 UNOCA L8 ... ~_. ~u - . VEN()QRNO; DATE CHECK NO. 1031?4S ..IOS-AUG-\Q!] 20004700 ~ DISCOUNT NET Date 09-AUG-01 100.00 .-...cc. 100.00 2004700 pay One Hundreq Do11ars And 00 Cents************************************** --... ~ ", 'i To tpe ordër of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501 United States III 200~ 700111.:0 3 ~ ~OO 20 ~.: 100.00 100.00 Union Oil Company of California Accounts Payable Field Disbursing Check ~m~'!;~ * * 100 . 00 months from above date. J~ 3 ~ ~ ~ 8 .~ 3 7 III ( ~. ~ rff'ffl... ",c.'...'<."~...;\I. 'J. J' ~ ~r., July 12,2001 UNOCAL 909 West 9th Avenue Anchorage, Alaska 99501 A TTN: Tim Brandenburg Tim., Enclosed is the revised mud program for your upcoming Lewis River C-l Well. Included is a well summary, economic summary, interval summary, and the project team. This program is for a Flo-Pro/Kla-Gard system with 6% KCL similar to the program used on SCD 22-4. We have had success with this system on the North Slope and on the Kenai Penni- suI a in the past year in inhibiting shale hydration, minimizing washouts and hole enlargements, and in reducing dilution rates. We recommend the use of Lubetex and Soltex in the initial makeup of the system. Mud weights up to 11.0 ppg can be expected. The completion costs for this well assumes using 6% KCl brine. Please call me if you have any questions regarding the mud program. Lee Dewees Proj ect Engineer M-I Drilling Fluids 907 274-5533 M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilliNG FLUIDS ,C ( ( Well Summary Lewis River C-1 Casing Size (in) Hole Size (in) Casing Program Depth TVD Mud System (ft) (ft) Mud Weight (ppg) Sum Days Cumulative Mud Cost Existing 4300' Drill water in 8.5 3 $1875 7" wellbore 4300' 4 1/2" 6" To Flo-ProlKla-Gard 9.5 - 11.0 14 $85,000 Liner 6200' M-I Drilling Fluids LLC. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax .Keyls sue .1 Hole Cleaning [(ey Lftsue 2 Lost Circulation Key Issue 3 Liner on .Bottom Key .Issue 4 .Hole Stability Key Lf!;sue 5 Coal Stability . Maintain adequate rheology (LSRV +/- 40,000 cps) to insure good hole cleaning. . Periodic additions of Safecarb Fine or Medium will control seepage losses. . Mix and spot a clean high-viscosity (70,000 cps) fluid in the open hole section prior to running casing. . Maintain 4 - 6 ppb KlaGard concentration through the en- tire interval. Maintain 4 - 6 ppb of Soltex. Add Dualflo and Ploypac UL as required. . WBM = Maintain KlaGard, Soltex, and KCL concentration through the entire interval. DRILLING FLUIDS ( ( Economics Summary Lewis River C-l De-completion 0 $1,875 $1,875 3 3 Drilling 4300' to 6200" $59,375 $70,000 $8,750 14 17 Completion 21 $9000 $81,500 $2,500 4 . Well cost includes 6% KCl completion fluid. . Full time engineering service is included in cost. . No provision for lubricant cost.. . Costs do not include any consideration for lost circulation or stuck pipe. M-I Drilling Fluids LL.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilliNG FLUIDS . ( ¡~ Interval Summary - Lewis River C-1 . . . . 4300.'. - .6200' Drilling Fluid System Flo-Pro / Kla-Gard/6 % KCL Key Products Flo- Vis / Kla-Gard / Barite / Soltex / Caustic Soda / Lubetex / Dual- Flo/KCL/DD/Drill XT/ Solids Control Shale Shakers / Desilter / Centrifuge / Ditch Magnets PotentialProblems Window Milling / Hole Cleaning / Lost Circulation / Directional Control/Drill Solids/ Hole Stability/ Soughing Coal/Bit Balling Interval Drilling Fluid Properties Depth Mud Plastic Yield API Lubricant Total Interval WEtight Viscosity... Point Fluid Loss percøntage Solids I (0) (PQS) (çp) '~.(I:)l1Þ~ft~). Onl/~Øœ!~l... ..... ...(?æ) .. (%) ...'..... ..... ........... .. .. 4300' (clean-out) 8.5-9.0 5 - 7 25- 35 8 - 10 0 0 - 1 4300'-6200' 9.5-1 1 .0 10-1 8 20 - 30 < 6 1 - 2 2 - 10 . Build initial volume with 6% KCL, 2+ ppb Flovis, Caustic for 9.0 pH, 6 ppb Kla-Gard, 2 ppb Dual-Flol, 4 ppb Soltex, 1/4 ppb Greencide 25G, 2 % Lubetex and 56 ppb MI Bar. . Initial volume requirements should be 500-600 bbls . Ensure proper placement of ditch magnets to capture metal cuttings . RIH, set whipstock, displace well to Flo-Pro fluid, begin milling when fluid passes mill. . Pump high-viscosity sweeps as needed to insure good hole cleaning. . Keep drill solids to a minimum by aggressive use of all solids control equipment, dilution with 6% KCL, and maintaining 4+ ppb concentration of Kla-Gard (shale inhibitor). . Maintain fluid loss control with additions of Dual-Flo, Soltex, and PolyPac UL. . At T.D., sweep hole, spot a clean FloPro pill (35 -40 yield point) with 5% Lubetex and 6 ppb Kla-Gard in the open hole prior to running 4 1/2" liner. Estimated volume 25 - 30 bbls . Run and set liner, clean pits, displace well to 6% KCL completion fluid M-I Drilling Fluids LLC. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilLING FLUIDS ( I ( Interval Summary LCM Lewis River 4300' ."6200"'" ' Lost Circulation Recommended LCM Pill Formulas Problems Key Products Drilling Fluid / M-I Seal; MIX ll; Safe-Carb; Nut Plug; Fine, Me- dium, Coarse / X-C Polymer Form A Set Lost Circulation Pill (Slight Losses), Volume MIX II/Nut Plug M-I Seal M-I Seal x-c of Mud Fine " MediUm Coarse Polymer ".1 (barr~I$) (ppb) ," (ppb) (pÞÞ) (ppb) 30 15 0 0 1/4 Lost Circulation Pill (Moderate Losses) Volume ôfMûd (Þé1r~el$) 40 MIX II/Nut Plug Fine (PPt?) 20 M-I Seal Medium (þJ;Jtj) 20 M-I Seal e6ärse (ppþ) 0 x-c PoIYrt1Ør (ppþ) 1/2 Lost Circulation Pill (Severe Losses) Volume MIX II/Nut Plug M-I Seal M-I Seal X-C of Mud Fine Medium Coarse Polymer (barrels) (ppb) (ppb) (ppb) (ppb) 50 20 20 10 1 . Spot the pill across the loss zone, add while drilling for seepage losses. . Consider use of Safe Carb products/other combinations of LCM can be used. . Confirm material size compatibility with BHA. . Use Form A Set for extreme losses M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilLING FLUIDS ,~ ( ( Project Team Lewis River C-1 Ed Butts FieldEngineer JìmBr()WI1 Field Engineer " "".... " , " , " '....'.. ' " , " .." .. t", 'D'" ",'.., , "'.'.',',,~e~~e~~... .,' .. . ~Ï'()je~fErigirieer. , ~ ~ ,.., .. .... , , ........ ,.., " , .. rI]>eënBryan' " '.l'écJtSetvicé '. Gus Wik Warehouse Manager . MI Project Engineer and Tech Service Engineer will coordinate between the Unocal office, rig, ware- house, and the M-I field engineers. . Well progress will be monitored to look for any changes which will improve the efficiency of the opera- tion or avert trouble.. Project Team Title Work Cellular Craig Bieber District Manager 907 274-5051 907229-1196 Deen Bryan Tech Service 907274-5003 907223-1634 Lee Dewees Project Engineer 907274-5533 907 227- Gus Wik Warehouse Manager 907776-8680 907 252-4218 Jim Brown Field Engineer 907776-6833 Ed Butts Field Engineer 907 776-6833 M-I Drilling Fluids LLc. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilLING FLUIDS L.¡ (- , ~I ')",l-'" -C,""")--'r)..;"'C" ?t~.:1~"" C. - i' (.." .' 1_..-- , ~, .ç:;;. -, C"- ~.~, --II'. """if' ..."7""( r",-::'" ((.,:::'11 (,.....¡ ..'"::'1"'-'.' , / I I I~A b y~' I + I L. ~~-t 1'7'1~ / ¡ -----+-- /35 ".. .... ~i) I {' --- \ .... ¡-l I UNOCA -100% I I I I I ------ ------+------ I I I 26 320(j) AC 25 3-31-00 ADL-381247 ------ UNOCA -100% .. 10: (: f5N= 21 22 23 DXYlUSA 256~ AC 28 3-3~ -94 27 ADL -365401 I ------ I I I I I I +----.--- I I I ~ I ~ 9 I I +- ---- I I I I I -$1 33 LE~IS RDI ~ I .~ 34 ...._.....~~.., t:28d AC : . g P ITR 11 . LEw! R -tt . AJJL- 8798 : UNOCA~ UNOCA 100%: LE SRIAA O~%" : ITR 61 rïí] : 3 .... r..~ 640 AC L;~R13-2 HBP AJ)L-58802 DANC 4 .-.--.--.-- 10 128ÖAC .HBP ADL--58801 ---_._- 1 ILE I I I I I 44801 AC . W - -EHT -ApIp-~AL - - -- ADL -381232 16 1.5 14 24 19 ----- 30 - - -_. _. 36 31 -- LEWIS RIVER -tJNrT 6 - - ._- - --.- 12 7 UNOCALfa Unocal North AmerIcan 011 lie Gal Dlvilion ALASKA BUSINESS UNIT C1> ., -c ::i I EXHIBIT II A" LEWIS RIVER FIELD =- LoJ -I " d Q.. " OJ In d CI.o -I " N g' :¡:; «- d '- c::o " C1> C :¡:; «- d '- c::o " ..::. UNIT OUTLINE REVISED JANUARY 1, 1994 ( \ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~ ÆJbv- ¿¡wlf L- I,e! CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDv EXPLORATION INJECTION WELL INJECTION WELL RED RILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ~ ANNULA~ DISfOSAL ( VNO --rr ANNULAR DISPOSAL L-J YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well, The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. serv wellbore seg _ann. disposal para req - 112 2-0 ON/OFF SHORE ctV WEll PERMIT CHECKLIST COMPANY /'J, WEll NAME FIELD & POOL S Q::;:> S 6d INIT CLASS /- ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. .. . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient aaeage available' in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat induded.. . . . . . . . . . . .'. . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can.be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided .. . . . . . . ., . . . . . . . . . 15. Suñace casing protects all known USDWs. . . '. . . . . . . . 16. CMT vol adequate to circulate on conductor & suñ csg. . . . . 17. CMT vol adequate to ,tie-in long string to suñ csg. . . . . . . . 18. CMT will cover all known productive horizons. , . . . '. . . . . 19. Casing'designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate weilbore separation proposed.. . . . . . : . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . , 24. Drilling .fluid program schematic & equip list adequate. . ~ . . 25. BOPEs, do they meet regulation. . . . . . . . . . ~ . . . . . B~TE 26, BOPE press rating appropriate; test to s~ psig. ~ . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdöwn. . . . . . . . . . . 29, Is presence of H25 gas probable.. . . . . . . . . . . . . . . . 30, Permit can be issued wlo hydrogen sulfide measures. . . . '. 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . R -"D"T~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ~} 34. Contact name/phone for weekly progress reports [exploratory onl ANNULAR DISPOSAl35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste, .. to surface; , , ' (C) will not impair mechanical integrity ~f the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and ' E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING:.,' UIC/Annular ~: ~Þ8~ ~ --....:.. 6~sy ,ß .2/,6 /" - I JMR . ~ h;¿AO\ R E.AJE } t: .(J.fß;t! ò / ENGINEERING GEOLOGY APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) UNIT# ~ C\...-- .4. ~tr;J A ;e-/- ¿(jJ¡" , c 0 Z 0 -t ~ ::0 (' <è - -t' m -' Z -t .J: - Y N Y N tÞ Þ ::0 m » ( ./ , .. Comments/lnstr~tions: ~\~ \~i"'-,-'\. ~~,,-\ç: J ~ I d ~