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Home My WebLink About223-127CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Joseph Lastufka To:Guhl, Meredith D (OGC) Subject:RE: [EXTERNAL] 223-108 PBU NK-24, 223-110 PBU F-40A, 223-127 PBU L-294 Date:Thursday, December 11, 2025 3:15:53 PM Meredith, Thank you for checking, all 3 wells are either planned to be re-permitted or scheduled further out than the expiration date. Please cancel all 3 wells: PBU NK-24 (PTD #223-108) PBU F-40A (PTD #223-110) PBU L-294 (PTD #223-127) Please let me know if you need anything else. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Thursday, December 11, 2025 2:34 PM To: Joseph Lastufka <joseph.lastufka@hilcorp.com> Subject: [EXTERNAL] 223-108 PBU NK-24, 223-110 PBU F-40A, 223-127 PBU L-294 Hello Joe, The following three approved permits are nearing their expiration dates. Does Hilcorp plan to drill any of these three wells, or should they be marked canceled in the AOGCC database? 1. 223-108 PBU NK-24, expires 2/13/2026 2. 223-110 PBU F-40A, expires 1/3/2026 3. 223-127 PBU L-294, expires 1/2/2026 Thanks, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 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. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU L-294 Hilcorp Alaska, LLC Permit to Drill Number: 223-127 Surface Location: 2466' FSL, 4102' FEL, Sec 34, T12N, R11E, UM, AK Bottomhole Location: 637' FNL, 2054' FEL, Sec 19, T12N, R11E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie Chmielowski. Commissioner DATED this 2 day of January 2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.01.02 11:20:31 -09'00' 4-1/2"x3-1/2" Drilling Manager 12/19/23 Monty M Myers By Grace Christianson at 3:19 pm, Dec 19, 2023 DSR-12/19/23 223-127 50-029-23777-00-00 A.Dewhurst 28DEC23 *BOPE test to 3000 psi. Annular to 2500 psi. * Casing tests and FITs to AOGCC upon completion of FIT. MGR29DEC23*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.01.02 11:20:47 -09'00' 01/02/24 01/02/24 Prudhoe Bay West (PBU) L-294 Permit to Drill Application Version 1 12/12/2023 Table of Contents 1.0 Well Summary ........................................................................................................................... 2 2.0 Management of Change Information ........................................................................................ 3 3.0 Tubular Program:...................................................................................................................... 4 4.0 Drill Pipe Information: .............................................................................................................. 4 5.0 Internal Reporting Requirements ............................................................................................. 5 6.0 Planned Wellbore Schematic ..................................................................................................... 6 7.0 Drilling / Completion Summary ................................................................................................ 7 8.0 Mandatory Regulatory Compliance / Notifications .................................................................. 8 9.0 R/U and Preparatory Work ..................................................................................................... 10 10.0 N/U 13-5/8” 5M Diverter System ............................................................................................. 11 11.0 Drill 12-1/4” Hole Section ........................................................................................................ 13 12.0 Run 9-5/8” Surface Casing ...................................................................................................... 16 13.0 Cement 9-5/8” Surface Casing ................................................................................................. 22 14.0 ND Diverter, NU BOPE, & Test .............................................................................................. 27 15.0 Drill 8-1/2” Hole Section .......................................................................................................... 28 16.0 Run & Cement 7” Intermediate Casing .................................................................................. 31 17.0 Drill 6-1/8” Hole Section .......................................................................................................... 35 18.0 Run 4-1/2” x 3-1/2” Screen Liner ............................................................................................ 40 19.0 Run Upper Completion/ Post Rig Work ................................................................................. 46 20.0 Innovation Rig Diverter Schematic ......................................................................................... 50 21.0 Innovation Rig BOP Schematic ............................................................................................... 51 22.0 Wellhead Schematic ................................................................................................................. 52 23.0 Days Vs Depth .......................................................................................................................... 53 24.0 Formation Tops & Information............................................................................................... 54 25.0 Anticipated Drilling Hazards .................................................................................................. 56 26.0 Innovation Rig Layout ............................................................................................................. 62 27.0 FIT Procedure .......................................................................................................................... 63 28.0 Innovation Rig Choke Manifold Schematic ............................................................................ 64 29.0 Casing Design ........................................................................................................................... 65 30.0 MASP ....................................................................................................................................... 66 31.0 Spider Plot (NAD 27) (Governmental Sections) ...................................................................... 68 32.0 Surface Plat (As-Built) (NAD 27) ............................................................................................ 69 Page 2 Prudhoe Bay West L-294 SB Producer Drilling Procedure 1.0 Well Summary Well PBU L-294 Pad Prudhoe Bay L Pad Planned Completion Type 4-1/2” Gas Lift Target Reservoir(s) Schrader Bluff NB Sand Planned Well TD, MD / TVD 20,258’ MD / 4,073’ TVD PBTD, MD / TVD 20,248’ MD / 4,073’ TVD Surface Location (Governmental) 2466' FSL, 4102' FEL, Sec 34, T12N, R11E, UM, AK Surface Location (NAD 27) X= 582,813.3, Y=5,978,183.62 Top of Productive Horizon (Governmental)1301' FNL, 21' FEL, Sec 29, T12N, R11E, UM, AK TPH Location (NAD 27) X= 576,247.8, Y=5984905.7 BHL (Governmental) 637' FNL, 2054' FEL, Sec 19, T12N, R11E, UM, AK BHL (NAD 27) X= 568858, Y=5990778 AFE Drilling Days 35 AFE Completion Days 3 Maximum Anticipated Surface Pressure (intermediate) 1374 psi Maximum Anticipated Surface Pressure (production) 1374 psi Maximum Anticipated Pressure (Downhole/Reservoir) 1792 psig Work String 5” 19.5# S-135 NC 50 & 4” 14# HT38 Innovation KB Elevation above MSL: 26.5 ft + 46.9 ft = 73.4 ft GL Elevation above MSL: 46.9 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams Page 3 Prudhoe Bay West L-294 SB Producer Drilling Procedure 2.0 Management of Change Information Page 4 Prudhoe Bay West L-294 SB Producer Drilling Procedure 3.0 Tubular Program: Hole Section OD (in)ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) Cond 20” 19.25”---X-52Weld 12-1/4”9-5/8” 8.835”8.750”10.625”40 L-80 BTC 5,750 3,090 916 9-5/8” 8.681”8.525”10.625”47 L-80 BTC 6,870 4,750 1,086 8-1/2” 7” 6.184 6.125 7.644 29 L-80 VamTop 8,160 7,030 676 6-1/8” 3-1/2” 2.992 2.867 3.833 9.2 L-80 JFE Bear 10,160 10,540 207 4-1/2” 3.958 3.833 5 12.6 L-80 JFE BEAR 8,430 7,500 288 Tubing 4-1/2” 3.958 3.833 5 12.6 L-80 JFE BEAR 8,430 7,500 288 4.0 Drill Pipe Information: Hole Section OD (in) ID (in)TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn M/U (Min) M/U (Max) Tension (k-lbs) Surface & Intermediate 5”4.276”3.25” 6.625”19.5 S-135 DS50 36,100 43,100 560klb 5”4.276”3.25” 6.625”19.5 S-135 NC50 30,730 34,136 560klb Production 4”3.34 2.688 4.875 14 S-135 XT-39 17,700 21,200 553klb 4”3.34 2.688 4.875 14# S-135 HT-38 12,200 17,700 649klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 5 Prudhoe Bay West L-294 SB Producer Drilling Procedure 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on WellEz. x Report covers operations from 6am to 6am x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry. x Ensure time entry adds up to 24 hours total. x Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. x Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates x Submit a short operations update each work day to mmyers@hilcorp, nathan.sperry@hilcorp.com, jengel@hilcorp.com and joseph.lastufka@hilcorp.com 5.3 Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.4 EHS Incident Reporting x Health and Safety: Notify EHS field coordinator. x Environmental: Drilling Environmental Coordinator x Notify Drilling Manager & Drilling Engineer on all incidents x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to mmyers@hilcorp,com jengel@hilcorp.com and joseph.lastufka@hilcorp.com 5.6 Casing and Cement report x Send casing and cement report for each string of casing to mmyers@hilcorp.com jengel@hilcorp.com and joseph.lastufka@hilcorp.com 5.7 Hilcorp Contact List: Title Name Work Phone Email Drilling Manager Monty Myers 907.777.8431 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 jengel@hilcorp.com Drilling Engineer Nate Sperry 907.777.8450 nathan.sperry@hilcorp.com Completion Engineer Aras Worthington 907.440.7692 aras.worthington@hilcorp.com Geologist Kevin Eastham 907.777.8316 keastham@hilcorp.com Reservoir Engineer Natalie Brent 907.564.4313 nbrent@hilcorp.com EHS Manager Laura Green 907.777.8314 lagreen@hilcorp.com Drilling Tech Joe Lastufka 907.777.8400 Joseph.Lastufka@hilcorp.com _____________________________________________________________________________________ Revised By: JNL 12/11/2023 PROPOSED SCHEMATIC Prudhoe Bay Unit Well: PBU L-294 Last Completed: TBD PTD: TBD JEWELRY DETAIL No. MD Item ID 1 ~4,800’ X Nipple 3.813” 2 TBD 4.5”x1” GLM 3.833” 3 TBD 4.5”x1” GLM 3.833” 4 TBD 4.5”x1” GLM 3.833” 5 ~10,060’ 4.5”x1” GLM 3.833” 6 ~10,120’ XD HES Sliding Sleeve 3.813” 7 ~10,180’ Baker downhole gauge carrier 3.958” 8 ~10,240’ 4-1/2” HES AHR 7” x 4-1/2” Packer 3.865” 9 ~10,300’ X Nipple (@ bottom of 73 deg sail angle) 3.813” 10 ~10,750’ 4-1/2” WLEG 3.958” 11 ~10,750’ 7” x 4-1/2” Liner Hanger 3.958” 12 ~14,100’ 4-1/2” x 3-1/2” XO 2.992” 13 ~20,258’ 3-1/2” Shoe 2.992” GENERAL WELL INFO API: TBD Completion Date: TBD TD =20,258’(MD) / TD =4,074’(TVD) 4 20” Orig. KB Elev.: 73.6’ / GL Elev.: 47.1’ 7” 6 5 4 9 12 11 9-5/8” 8 1 2 3 250 Micron Screen PBTD =20,258’(MD) / PBTD = 4,074’(TVD) 10 & 117 5 12 4-1/2” 3 2 7 4-1/2”x3-1/2” TREE & WELLHEAD Tree Cameron 3-1/8" 5M w/ 3-1/8” 5M Cameron Wing Wellhead FMC 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs OPEN HOLE / CEMENT DETAIL Driven 20” Conductor 12-1/4”Stg 1 Lead – 433 sx / Tail – 395 sx Stg 2 Lead – 763 sx / tail - 270 sx 8-1/2” Tail – 356 sx 6-1/8” Uncemented Screen Liner CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5 / X56 / Weld N/A Surface 110’ N/A 9-5/8” Surface 47 / L-80 / BTC 8.525” Surface 2,500’ 0.0732 9-5/8” Surface 40 / L-80 / BTC 8.679” 2,500’ 6,000’ 0.0758 7” Intermediate 29 / L-80 / VamTop 6.184” Surface 10,920’ 0.0371 4-1/2” 250 Micron Screens 12.6 / L-80 / JFEBear 3.958” 10,770’ 14,100’ 0.0152 3-1/2” 250 Micron Screens 9.2 / L-80 / JFEBear 2.992” 14,100’ 20,258’ 0.0086 TUBING DETAIL 4-1/2" Tubing 12.6# / L-80 / JFE-Bear 3.958” Surface 10,240’ 0.0152 4-1/2” Tubing 12.6# / 13Cr / VT 3.958” 10,240’ 10,750’ 0.0152 WELL INCLINATION DETAIL KOP @ 250’ 90° Hole Angle = @ 13,200’ MD Page 7 Prudhoe Bay West L-294 SB Producer Drilling Procedure 7.0 Drilling / Completion Summary PBU L-294 is a grassroots producer planned to be drilled in the Schrader Bluff NB sands. L-294 is part of a multi-well program targeting the Schrader Bluff sand on PBU L-pad The directional plan is 12-1/4” surface hole and 9-5/8” surface casing set below the SV1. 8-1/2” intermediate hole will be drilled into the top of the Schrader Bluff NB sand, with 7” casing ran and cemented. A 6-1/8” lateral section will be drilled. A 4-1/2” x 3-1/2” screen liner will be run in the open hole section, followed by 4-1/2” gas lift tubing. The Innovation Rig will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately January 15, 2024, pending rig schedule. Surface casing will be run to 6,000’ MD / 2,713’ TVD and cemented to surface via a two stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to one of two locations: Primary: Prudhoe G&I on Pad 4 Secondary: the Milne Point “B” pad G&I facility General sequence of operations: 1. MIRU Innovation Rig to well site 2. N/U & Test 13-5/8” Diverter and 16” diverter line 3. Drill 12-1/4” hole to TD of surface hole section. Run and cement 9-5/8” surface casing 4. N/D diverter, N/U wellhead, NU 13-5/8” 5M BOP & Test 5. Drill 8-1/2” to section TD, Run and cement 7” casing 6. Drill 6-1/8” lateral to well TD 7. Run screen liner 8. Run Upper Completion 9. N/D BOP, N/U Tree, RDMO Reservoir Evaluation Plan: 1. Surface & Intermediate hole: No mud logging. Remote geologist. LWD: GR + Res 2. Production Hole: No mud logging. Remote geologist. LWD: GR + ADR (For geo-steering) Page 8 Prudhoe Bay West L-294 SB Producer Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that all drilling and completion operations comply with all applicable AOGCC regulations. Operations stated in this PTD application may be altered based on sound engineering judgement as wellbore conditions require, but no AOGCC regulations will be varied from without prior approval from the AOGCC. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x Review all conditions of approval of the PTD on the 10-401 form. Ensure that the conditions of approval are captured in shift handover notes until they are executed and complied with. x BOPs shall be tested at (2) week intervals during the drilling and completion of PBU L-294. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/3,000 psi & subsequent tests of the BOP equipment will be to 250/3,000 psi for 5/5 min (annular to 50% rated WP, 2,500 psi on the high test for initial and subsequent tests).Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements”. o Ensure the diverter vent line is at least 75’ away from potential ignition sources x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. x Casing pressure test criteria in 20 AAC 25.030 (e) Casing and Cementing,“A casing pressure test must be performed if BOPE is to be installed on a casing. The casing must be tested to hold a minimum surface pressure equal to 50 percent of the casing internal yield pressure. The test pressure must show stabilizing pressure and may not decline more than 10 percent within 30 minutes. The results of this test and any subsequent tests of the casing must be recorded as required by 20 AAC 25.070(1)”. AOGCC Regulation Variance Requests: No variance requests at this time Page 9 Prudhoe Bay West L-294 SB Producer Drilling Procedure Summary of Innovation BOP Equipment & Test Requirements Hole Section Equipment Test Pressure (psi) 12-1/4”x 13-5/8” 5M CTI Annular BOP w/ 16” diverter line Function Test Only 8-1/2” & 6-1/8” x 13-5/8” x 5M Control Technology Inc Annular BOP x 13-5/8” x 5M Control Technology Inc Double Gate o Blind ram in btm cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Control Technology Single ram x 3-1/8” x 5M Choke Line x 3-1/8” x 5M Kill line x 3-1/8” x 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/3,000 Subsequent Tests: 250/3,000 Primary closing unit: Control Technology Inc. (CTI), 6 station, 3,000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 24 hours notice prior to spud. x 24 hours notice prior to testing BOPs. x 24 hours notice prior to casing running & cement operations. x Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email:jim.regg@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email:Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email:melvin.rixse@alaska.gov Primary Contact for Opportunity to witness:AOGCC.Inspectors@alaska.gov Test Inspection notification standardization format:http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 10 Prudhoe Bay West L-294 SB Producer Drilling Procedure 9.0 R/U and Preparatory Work 9.1 L-294 will utilize a 20” conductor on L-pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD, COAs, and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4” nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat footprint of rig. 9.7 MIRU Innovation. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. 9.9 Mix spud mud for 12-1/4” surface hole section. Ensure mud temperatures are cool (<80qF). x Cold mud temps are necessary to mitigate hydrate breakout 9.10 Ensure 5” liners in mud pumps. x White Star Quattro 1,300 HP mud pumps are rated at 4,097 psi, 381 gpm @ 140 spm @ 96.5% volumetric efficiency. Page 11 Prudhoe Bay West L-294 SB Producer Drilling Procedure 10.0 N/U 13-5/8” 5M Diverter System 10.1 N/U 13-5/8” CTI BOP stack in diverter configuration (Diverter Schematic attached to program). x N/U 20” x 13-5/8” DSA x N/U 13 5/8”, 5M diverter “T”. x NU Knife gate & 16” diverter line. x Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). x Diverter line must be 75 ft from nearest ignition source x Place drip berm at the end of diverter line. x Utilized extensions if needed. 10.2 Notify AOGCC with 24 hour notice to witness. Function test diverter. x Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. x Ensure that the annular closes in less than 30 seconds (API Standard 64 3rd edition March 2018 section 12.6.2 for packing element ID less than or equal to 20”) 10.3 Ensure to set up a clearly marked “warning zone” is established on each side and ahead of the vent line tip. “Warning Zone” must include: x A prohibition on vehicle parking x A prohibition on ignition sources or running equipment x A prohibition on staged equipment or materials x Restriction of traffic to essential foot or vehicle traffic only. Page 12 Prudhoe Bay West L-294 SB Producer Drilling Procedure 10.4 Rig & Diverter Orientation: x May change on location Page 13 Prudhoe Bay West L-294 SB Producer Drilling Procedure 11.0 Drill 12-1/4” Hole Section 11.1 P/U 12-1/4” directional drilling assembly: x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Consider running a UBHO sub for wireline gyro.GWD will be the primary gyro tool. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Drill string will be 5” 19.5# S-135. x Run a solid float in the surface hole section. 11.2 Begin drilling out from 20” conductor at reduced flow rates to avoid broaching the conductor. x Consider using a trash bit to clean out conductor to mitigate potential damage from debris in conductor. 11.3 Drill 12-1/4” hole section to section TD below the SV1 sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. x Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. x Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6 deg / 100. x Hold a safety meeting with rig crews to discuss: x Conductor broaching ops and mitigation procedures. x Well control procedures and rig evacuation x Flow rates, hole cleaning, mud cooling, etc. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Keep mud as cool as possible to keep from washing out permafrost. x Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. x There have been ‘directional dead zones’ noted in PBW. Directional plan has a build up in DLS from 2 – 4, to allow gradual build. If possible get ahead of build rates while still meeting tangent hold target. x Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen x Slow in/out of slips and while tripping to keep swab and surge pressures low x Ensure shakers are functioning properly. Check for holes in screens on connections. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. x Adjust MW and viscosity as necessary to maintain hole stability,ensure MW is at a 9.5 at base of perm and at TD. x Perform gyro surveys until clean MWD surveys are seen. Take MWD surveys every stand drilled. x Gas hydrates have been seen at L-Pad Page 14 Prudhoe Bay West L-294 SB Producer Drilling Procedure x Take MWD and GWD surveys every stand until magnetic interference cleans up. After MWD surveys show clean magnetics, only take MWD surveys. x Surface Hole AC: x There are no wells with a clearance factor of <1.0 11.4 12-1/4” hole mud program summary: x Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.5+ ppg. MW for free gas and hydrates based upon offset wells Depth Interval MW (ppg) Surface – Base Permafrost 8.9+ Base Permafrost - TD 9.5+ (For Hydrates/Free Gas based on offset wells) x PVT System: PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. x Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. x Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. x Wellbore and mud stability:Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 – 9.0 range with caustic soda. Daily additions of ALDACIDE G / X-CIDE 207 MUST be made to control bacterial action. x Casing Running:Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). System Type:8.8 – 9.8 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL pH Temp Surface 8.8 –9.8 75-175 20 - 40 25-45 <10 8.5 –9.0 70 F Page 15 Prudhoe Bay West L-294 SB Producer Drilling Procedure System Formulation: Gel + FW spud mud Product Concentration Fresh Water soda Ash AQUAGEL caustic soda BARAZAN D+ BAROID 41 PAC-L /DEXTRID LT ALDACIDE G 0.905 bbl 0.5 ppb 15 - 20 ppb 0.1 ppb (8.5 – 9.0 pH) as needed as required for 8.8 – 9.2 ppg if required for <10 FL 0.1 ppb 11.5 At TD; PU 2-3 stands off bottom to avoid washing out the hole at TD, CBU, pump tandem sweeps and drop viscosity. Observe well for flow. 11.6 RIH to bottom, proceed to BROOH to HWDP x Pump at full drill rate (400-600 gpm), and maximize rotation. x Pull slowly, 5 – 10 ft / minute, adjust as dictated by hole conditions x Monitor well for any signs of packing off or losses. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. x If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.7 TOOH and LD BHA 11.8 No wireline logging program planned. Page 16 Prudhoe Bay West L-294 SB Producer Drilling Procedure 12.0 Run 9-5/8” Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 9-5/8” casing running equipment (CRT & Tongs) x Ensure 9-5/8” BTC x NC50 on rig floor and M/U to FOSV. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x R/U of CRT if hole conditions require. x R/U a fill up tool to fill casing while running if the CRT is not used. x Ensure all casing has been drifted to 8.75” on the location prior to running. x Top 2,500’ of casing 47# drift 8.525” x Actual depth to be dependent upon base of permafrost and stage tool x Be sure to count the total # of joints on the location before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking 120’ shoe track assembly consisting of: 9-5/8” Float Shoe 1 joint – 9-5/8” , 2 Centralizers 10’ from each end w/ stop rings 1 joint –9-5/8” , 1 Centralizer mid joint w/ stop ring 9-5/8” Float Collar w/ Stage Cementer Bypass Baffle ‘Top Hat’ 1 joint – 9-5/8” , 1 Centralizer mid joint with stop ring 9-5/8” HES Baffle Adaptor x Ensure bypass baffle is coreclty installed on top of float collar x Ensure proper operation of float equipment while picking up. x Ensure to record S/N’s of all float equipment and stage tool components. Page 17 Prudhoe Bay West L-294 SB Producer Drilling Procedure 12.5 Float Equipment and Stage tool equipment drawings Page 18 Prudhoe Bay West L-294 SB Producer Drilling Procedure 12.6 Continue running 9-5/8” surface casing x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: x Bowspring Centralizers only x 1 centralizer every joint to ~ 1000’ MD from shoe x 1 centralizer every 2 joints to ~ 2,000’ above shoe (top of lowest Ugnu) x Verify depth of lowest ugnu water sand for isolation with geologist x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. x Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cement returns to surface. 9-5/8” 47# L-80 BTC Make-Up Torques: Casing OD Minimum Optimum Maximum 9-5/8”Make Up to Triangle 9-5/8” 40# L-80 BTC Make-Up Torques: Casing OD Minimum Optimum Maximum 9-5/8”Make Up to Triangle Page 19 Prudhoe Bay West L-294 SB Producer Drilling Procedure Page 20 Prudhoe Bay West L-294 SB Producer Drilling Procedure Page 21 Prudhoe Bay West L-294 SB Producer Drilling Procedure 12.7 Install the Halliburton Type H ES-II Stage tool so that it is positioned at least 100’ TVD below the permafrost (~ 2,500’ MD, actual depth based upon base of permafrost) x Install centralizers over couplings on 5 joints below and 5 joints above stage tool. x Do not place tongs on ES cementer, this can cause damaged to the tool. x Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. 12.8 Continue running 9-5/8” surface casing x Centralizers: 1 centralizer every 3rd joint to 200’ from surface x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: o 1 centralizer every 2 joints to base of conductor 12.9 Centralizers 1/jt for 5 joints above and below stage tool. x Confirm stage tool depth compatibility with cancellation plug, inclination sensitive 12.10 The last 2,500’ of 9-5/8” will be 47#, from 2,500’ to Surface x Actual length of 47# may change due to depth of permafrost as drilled x Ensure drifted to 8.525” 12.11 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. Slow in and out of slips. 12.12 P/U landing joint and M/U to casing string. Position the casing shoe +/- 10’ from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.13 Lower casing to setting depth. Confirm measurements. 12.14 Have slips staged in cellar, along with necessary equipment for the operation. 12.15 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 22 Prudhoe Bay West L-294 SB Producer Drilling Procedure 13.0 Cement 9-5/8” Surface Casing 13.1 Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. x How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. x Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. x Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. x Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses x Review test reports and ensure pump times are acceptable. x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) – HEC rep to witness. Mix and pump cement per below calculations for the 1st stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 1st Stage Cement Volume: Section Calculation Vol (bbl) Vol (ft3) Vol (sks) 12-1/4" OH x 9-5/8" Casing (6,000'-1,000'-2,500') x 0.0558 bpf x 1.3 181.3 1017.0 Total Lead 181.3 1017.0 432.8 12-1/4" OH x 9-5/8" Casing 1000' x 0.0558 bpf x 1.3 = 72.5 406.8 9-5/8" Shoetrack 120' x 0.0758 bpf = 9.1 51.0 Total Tail 81.6 457.8 394.7 Le a d Ta i l Page 23 Prudhoe Bay West L-294 SB Producer Drilling Procedure Cement Slurry Design (1st Stage Cement Job) 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets “sticky”, cease pipe reciprocation and continu with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. x Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5” liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: x 2500’ x 0.0732 bpf + (6,000’-120’-2500’) x .0758 bpf = x = 439.3 bbls 80 bbls of tuned spacer to be left behind stage tool for preventing of contamination of cement in the annulus 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling Engineer. Lead Slurry Tail Slurry System EconoCem HalCem Density 12.0 lb/gal 15.8 lb/gal Yield 2.35 ft3/sk 1.16 ft3/sk Mixed Water 13.92 gal/sk 4.95 gal/sk Page 24 Prudhoe Bay West L-294 SB Producer Drilling Procedure 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. 13.15 Increase pressure to 3,300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. x Ensure the free fall stage tool opening plug is available. This is the back-up option to open the stage tool if the plugs are not bumped. 13.16 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Page 25 Prudhoe Bay West L-294 SB Producer Drilling Procedure Second Stage Surface Cement Job 13.17 Prepare for the 2 nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. Try to maintain flow rate through stage tool until 2nd stage is ready. Hold pre-job safety meeting. x Past wells have seen pressure increase while circulating through stage tool after reduced rate 13.18 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.19 Fill surface lines with water and pressure test. 13.20 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.21 Mix and pump cmt per below recipe for the 2 nd stage. 13.22 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. Cement will continue to be pumped until clean spacer is observed at surface. Estimated 2nd Stage Total Cement Volume: Cement Slurry Design (2nd Stage): Lead Slurry Tail Slurry System Arctic Cem HalCem Density 11.0 lb/gal 15.8 lb/gal Yield 2.535 ft3/sk 1.16 ft3/sk Mixed Water 12.2 gal/sk 5.06 gal/sk 13.23 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.24 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. Section Calculation Vol (bbl) Vol (ft3) Vol (sks) 20" Cond x 9-5/8" Casing 110' x 0.26 bpf 28.6 160.4 12-1/4" OH x 9-5/8" Casing (2000' - 110) x .0558 x 3 316.3 1774.3 Total Lead 344.9 1934.8 763.2 12-1/4" OH x 9-5/8" Casing (2500 - 2000') x .0558 bpf x 2 55.8 313.0 Total Tail 55.8 313.0 269.9 Le a d Ta i l Page 26 Prudhoe Bay West L-294 SB Producer Drilling Procedure 13.25 Displacement calculation: 2500’ x 0.0732 bpf = 183 bbls mud 13.26 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.27 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. 13.28 Land closing plug on stage collar and pressure up to 1,000 – 1,500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips. 13.29 Make initial cut on 9-5/8” final joint. L/D cut joint. Make final cut on 9-5/8”. Dress off stump. Install 9-5/8” wellhead. Ensure slip tension is between 50-100klb Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to jengel@hilcorp.com and joseph.lastufka@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 27 Prudhoe Bay West L-294 SB Producer Drilling Procedure 14.0 ND Diverter, NU BOPE, & Test 14.1 Give AOGCC 24hr notice of BOPE test, for test witness. 14.2 ND the diverter T, knife gate, diverter line & NU 11” x 13-5/8” 5M casing spool. 14.3 NU 13-5/8” x 5M BOP as follows: x BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13- 5/8” x 5M mud cross / 13-5/8” x 5M single gate x Double gate ram should be dressed with 4-1/2” x 7” VBRs in top cavity,blind ram in bottom cavity. x Single ram can be dressed with 2-7/8” x 5-1/2” VBRs or 5” solid body rams x NU bell nipple, install flowline. x Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). x Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve. 14.4 RU MPD RCD and related equipment 14.5 Run 5” BOP test plug 14.6 Test BOP to 250/3,000 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. x Test with 5” test joint and test VBR’s with 4-1/2” and 5” test joints x Confirm test pressures with PTD x Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug x Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 14.7 RD BOP test equipment 14.8 Dump and clean mud pits, send spud mud to G&I pad for disposal. 14.9 Mix 9.5 ppg spud mud to be used in intermediate hole 14.10 Set wearbushing in wellhead. 14.11 If needed, rack back as much 5” DP in derrick as possible to be used while drilling the hole section. 14.12 Ensure 5” liners in mud pumps. Page 28 Prudhoe Bay West L-294 SB Producer Drilling Procedure 15.0 Drill 8-1/2” Hole Section 15.1 P/U 8-1/2” directional drilling assembly: x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Drill string will be 5” 19.5# S-135. x Run a solid float in the intermediate hole section. 15.2 TIH to TOC above the shoetrack. Note depth TOC tagged on morning report. 15.3 RU and test casing to 2,500 psi / 30 min. Ensure to record volume / pressure (every ¼ bbl) and plot on FIT graph. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.4 Drill out shoe track and 20’ of new formation. 15.5 CBU and condition mud for FIT. 15.6 Conduct FIT to 11.5 ppg EMW. Chart Test. Ensure test is recorded on same chart as casing test. Document incremental volume pumped (and subsequent pressure) and volume returned. x 11.5 ppg provides >25 bbls based on 9.5ppg MW, 8.46 ppg PP (swab kick at 8.46 ppg BHP). x Email digital data for casing test and FIT to AOGCC upon completion – Melvin.rixse@alaska.gov x 15.7 Drill 8-1/2” hole section to section TD in the Schrader NB sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. x Efforts should be made to minimize dog legs. Keep DLS < 6 deg / 100. x Hold a safety meeting with rig crews to discuss: x Well control procedures x Flow rates, hole cleaning, etc. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. x Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen. x Slow in/out of slips and while tripping to keep swab and surge pressures low. x Ensure shakers are functioning properly. Check for holes in screens on connections. x Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a ~9.5 by TD. Page 29 Prudhoe Bay West L-294 SB Producer Drilling Procedure x Intermediate Hole AC: x There is one exploration well that has been P&A’d that has CF <1.0. The risk posed by these wells is damage to the drill bit, requiring a BHA trip x NWEILEEN-2 @ 7,125’ MD 15.8 8-1/2” hole mud program summary: x Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at same ppg as surface TD MW and ensure we TD with 9.5+ ppg. Depth Interval MW (ppg) Surface shoe - TD 9.5+ x PVT System: PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. x Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. x Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. x Wellbore and mud stability:Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 – 9.0 range with caustic soda. Daily additions of ALDACIDE G / X-CIDE 207 MUST be made to control bacterial action. x Casing Running:Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). System Type:8.8 – 9.8 ppg 6% Kcl LSND Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL pH Temp Intermediate 8.8 –9.8 75-175 20 - 40 25-45 <10 8.5 –9.0 70 F Page 30 Prudhoe Bay West L-294 SB Producer Drilling Procedure 15.9 At TD; PU 2-3 stands off bottom to avoid washing out the hole at TD, CBU, pump tandem sweeps and drop viscosity. 15.10 RIH to bottom, proceed to BROOH to surface casing shoe x Pump at full drill rate and maximize rotation. x Pull slowly, 5 – 10 ft / minute, adjust as dictated by hole conditions x Monitor well for any signs of packing off or losses. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. x If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 15.11 CBU at casing shoe 15.12 TOOH and LD BHA x Send LWD/GR & Res to AOGCC to confirm required TOC in the 8-1/2” x 7” Annulus 15.13 No wireline logging program planned Page 31 Prudhoe Bay West L-294 SB Producer Drilling Procedure 16.0 Run & Cement 7” Intermediate Casing 16.1 R/U and pull wearbushing. 16.2 R/U 7” casing running equipment (CRT & Tongs) x Ensure 7” VamTop x NC50 XO on rig floor and M/U to FOSV. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x R/U of CRT if hole conditions require. x R/U a fill up tool to fill casing while running if the CRT is not used. x Ensure all casing has been drifted. x Be sure to count the total # of joints on the location before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. x Plan to land the 7” casing on a mandrel hanger. 16.3 P/U shoe joint, visually verify no debris inside joint. 16.4 Continue M/U & thread locking 120’ shoe track assembly consisting of: 7” Float Shoe 1 joint – 7”, 2 Centralizers 10’ from each end w/ stop rings 1 joint –7”, 1 Centralizer mid joint w/ stop ring 1 joint – 7”, 1 Centralizer mid joint with stop ring 7” Float Collar 16.5 Continue running 7” intermediate casing x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: x 1 centralizer every joint to ~ 500’ MD above Schrader Bluff x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. 7” 29# L-80 VamTop Make-Up Torques: confirm Casing OD Minimum Optimum Maximum 7”8,460 ft-lbs 9,400 ft-lbs 10,340 ft-lbs Page 32 Prudhoe Bay West L-294 SB Producer Drilling Procedure Page 33 Prudhoe Bay West L-294 SB Producer Drilling Procedure 16.6 Continue running 7” casing x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. 16.7 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.8 Slow in and out of slips. 16.9 P/U landing joint and M/U to casing string. Position the casing shoe +/- 10’ from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 16.10 Lower casing to setting depth. Confirm measurements. 16.11 Have emergency slips staged along with necessary equipment for the operation. 16.12 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. 16.13 Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. x Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. x Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. x Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses x Review test reports and ensure pump times are acceptable. x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 16.14 Document efficiency of all possible displacement pumps prior to cement job. 16.15 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 16.16 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 16.17 Fill surface lines with water and pressure test. 16.18 Pump 60 bbls 11 ppg tuned spacer. 16.19 Mix and pump cmt per below recipe. Page 34 Prudhoe Bay West L-294 SB Producer Drilling Procedure 16.20 Cement volume based on annular volume + open hole excess (40%). Job will consist of tail, TOC brought to 500’ above Ugnu LA (Note: TOC may be adjusted if formations are found to be wet or hydrocarbon bearing.) x Prognosed Ugnu LA: 9,231’ MD, Planned TOC: 8,731’ MD x The two previous 3 string SB wells on L pad (L-292, L-293) had approved TOC 500’ MD above the Ugnu LA, uppermost significant oil Estimated Total Cement Volume: Cement Slurry Design (Single Stage Cement Job) 16.21 After pumping cement, drop top plug and displace cement with mud out of mud pits. x (10920-120)’ x .0371bpf = 400.7 bbl 16.22 Monitor returns closely while displacing cement. Adjust pump rate if necessary. 16.23 Land top plug on stage collar and pressure up to 500 psi over bump pressure. Bleed pressure and check floats. If floats are not holding, shut in and hold 500 psi over bump pressure until cement builds compressive strength. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note time cement in place & calculated top of cement Send final “As-Run” casing tally & casing and cement report to jengel@hilcorp.com and joseph.lastufka@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Section Calculation Vol (bbl) Vol (ft3) Vol (sks) 8.5" OH x 7" (10,920 - 8,731)' x 0.0226 bpf x 1.4 = 69.2 388.2 7" Shoetrack 120' x 0.0372 bpf = 4.5 25.2 Total Tail 73.7 413.5 356.4 Ta i l Tail Slurry System HalCem Density 15.8 lb/gal Yield 1.16 ft3/sk Mixed Water 5.06 gal/sk Page 35 Prudhoe Bay West L-294 SB Producer Drilling Procedure 17.0 Drill 6-1/8” Hole Section 17.1 MU 6-1/8” Cleanout BHA (Milltooth Bit & 1.22° PDM) 17.2 TIH w/ 6-1/8” cleanout BHA to float collar with 4” dp 17.3 RU and test casing to 2,500 psi / 30 min. Ensure to record volume / pressure (every ¼ bbl) and plot on FIT graph. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 17.4 Drill out shoe track and 20’ of new formation. 17.5 CBU and condition mud for FIT. 17.6 Conduct FIT to 12.0 ppg EMW. Chart Test. Ensure test is recorded on same chart as casing test. Document incremental volume pumped (and subsequent pressure) and volume returned. x 12.0 ppg desired to cover shoe strength for expected ECD’s. A 9.8 ppg FIT is the minimum required to drill ahead x 9.8 ppg provides >25 bbls based on 9.5ppg MW, 8.46ppg PP (swabbed kick at 9.5ppg BHP) x Email digital data for casing test and FIT to AOGCC upon completion – Melvin.rixse@alaska.gov 17.7 POOH and LD cleanout BHA 17.8 PU 6-1/8” directional BHA. x Ensure BHA components have been inspected previously. x Drift and caliper all components before MU. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Ensure MWD is RU and operational. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Drill string will be 4” 14# XT39 x Run a ported float in the production hole section. 17.9 6-1/8” hole section mud program summary: x Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. email Casing Test and FIT digital data immediately upon completion of FIT to AOGCC email - melvin.rixse@alaska.gov Page 36 Prudhoe Bay West L-294 SB Producer Drilling Procedure x Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. x Rheology: Keep viscosifier additions to an absolute minimum (N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning x Run the centrifuge continuously while drilling the production hole, this will help with solids removal. x Dump and dilute as necessary to keep drilled solids to an absolute minimum. x MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, & Toolpusher office. System Type:8.9 – 9.5 ppg Baradrill-N drilling fluid Properties: Interval Density PV YP LSYP Total Solids MBT HPHT Hardness Production 8.9-9.5 15-25 - ALAP 15 - 30 4-6 <10% <8 <11.0 <100 System Formulation: Product Concentration Water KCL KOH N-VIS DEXTRID LT BARACARB 5 BARACARB 25 BARACARB 50 BARACOR 700 BARASCAV D X-CIDE 207 0.955 bbl 11 ppb 0.1 ppb 1.0 – 1.5 ppb 5 ppb 4 ppb 4 ppb 2 ppb 1.0 ppb 0.5 ppb 0.015 ppb 17.10 TIH with 6-1/8” directional assembly to bottom 17.11 Install MPD RCD 17.12 Displace wellbore to 9.2 ppg Baradrill-N drilling fluid Page 37 Prudhoe Bay West L-294 SB Producer Drilling Procedure x Density may change based upon TD of intermediate hole section 17.13 Begin drilling 6-1/8” hole section, on-bottom staging technique: x Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8K. x Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations x If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to PU off bottom and restart on bottom staging technique. If stick slip continues, consider adding 0.5% lubes 17.14 Drill 6-1/8” hole section to section TD per Geologist and Drilling Engineer. x Flow Rate: 150-250 GPM, target min. AV’s 200 ft/min, 385 GPM x RPM: 120+ x Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low x Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection x Monitor Torque and Drag with pumps on every 5 stands x Monitor ECD, pump pressure & hookload trends for hole cleaning indication x Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. x Use ADR to stay in section. Reservoir plan is to stay in NB sand. x Limit maximum instantaneous ROP to < 250 FPH. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. x Target ROP is as fast as we can clean the hole without having to backream connections x Schrader Bluff NB Concretions: 4-6% Historically x MPD will be utilized to monitor pressure build up on connections. x 6-1/8” Lateral A/C: x There are no wells with CF < 1.0 17.15 Reference:Halliburton has a procedure for Schrader OH sidetracks based on lessons learned and best practices. Ensure the DD is referencing their procedure. x Patience is key! Getting kicked off too quickly might have been the cause of failed liner runs on past wells. x If a known fault is coming up, put a slight “kick-off ramp” in wellbore ahead of the fault so we have a nice place to low side. x Attempt to lowside in a fast drilling interval where the wellbore is headed up. x Orient TF to low side and dig a trough with high flowrates for the first 30 feet, working string back and forth. Trough for approximately 30 minutes. x Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. Page 38 Prudhoe Bay West L-294 SB Producer Drilling Procedure 17.16 At TD, CBU at least 4 times at 200 ft/min AV and rotation (120+ RPM). Pump tandem sweeps if needed x Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary x If seepage losses are seen while drilling, consider reducing MW at TD to 9.0 ppg minimum 17.17 Mix and pump 40 bbl 10 ppb SAPP pill. Line up to a closed loop system and circulate three SAP pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. 17.18 Displace 1.5 OH + liner volume with viscosified brine. x Proposed brine blend (same as used on M-16, aiming for an 8 on the 6 RPM reading) - KCl: 7.1ppb for 2% NaCl: 60.9ppg for 9.4ppg Lotorq: 1.5% Lube 776: 1.5% Soda Ash: as needed for 9.5pH Busan 1060: 0.42ppb Flo-Vis Plus: 1.25ppb x Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further discussion needed prior to BROOH. 17.19 Monitor the returned fluids carefully while displacing to brine. 17.20 Perform PST with 250 micron coupons after displacement 17.21 BROOH with the drilling assembly to the 7” casing shoe x Circulate at full drill rate (less if losses are seen, 350 GPM minimum). x Rotate at maximum RPM that can be sustained. x Pulling speed 5 – 10 min/stand (slip to slip time, not including connections), adjust as dictated by hole conditions x If backreaming operations are commenced, continue backreaming to the shoe 17.22 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOH. Page 39 Prudhoe Bay West L-294 SB Producer Drilling Procedure 17.23 CBU minimum two times at 7” shoe and clean casing with high vis sweeps. Perform PST test again. 17.24 Monitor well for flow/pressure build up with MPD. Increase fluid weight if necessary. x Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if well is breathing, treat all flow as an influx until proven otherwise x If necessary, increase MW at shoe for any higher than expected pressure seen x Ensure fluid coming out of hole has passed a PST at the possum belly 17.25 POOH and LD BHA. 17.26 Continue to POOH and stand back BHA if possible. Rabbit DP on TOOH, ensure rabbit diameter is sufficient for future ball drops. x Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 40 Prudhoe Bay West L-294 SB Producer Drilling Procedure 18.0 Run 4-1/2” x 3-1/2” Screen Liner 18.1 Well control preparedness: In the event of an influx of formation fluids while running the liner, the following well control response procedure will be followed: x P/U & M/U the 4” safety joint (with 3-1/2” crossover installed on bottom, TIW valve in open position on top, 3-1/2” handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 3-1/2” liner. x Ensure 4-1/2” xo and safety joint are available on floor as well x Slack off and with 4” DP across the BOP, shut in ram or annular on 4” DP. Close TIW. x Proceed with well kill operations. 18.2 R/U 3-1/2” liner running equipment. x Ensure 3-1/2” 9.2# JFEBear x 4” dp crossover is on rig floor and M/U to FOSV. x Ensure all casing has been drifted on the deck prior to running. x Be sure to count the total # of joints on the deck before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 18.3 Run ~ 6000’ of 3-1/2” Screens x Use JFE approved thread compound. Dope pin end only w/ paint brush. Wipe off excess. x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Use lift nubbins and stabbing guides for the liner run. 18.4 C/O handling Equipment to 4-1/2” 12.6# JFE Bear 18.5 Run 4-1/2” 12.6# JFE Bear Screens x Use JFE approved thread compound. Dope pin end only w/ paint brush. Wipe off excess. x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Use lift nubbins and stabbing guides for the liner run. x Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10 and 20 rpm x See data sheets on the next page for MU torque for the liner connections. Page 41 Prudhoe Bay West L-294 SB Producer Drilling Procedure Well: L-294 Approx Depth Description Liner Top Hanger/Packer Assembly (7" x 4-1/2")10,770' md 4-1/2" L-80 JFE Bear 250 micron screens 10,920' - 14,100' md Crossover 4-1/2" to 3-1/2" JFE BEAR 14,100' md 3-1/2" L-80 JFE BEAR 250 micron screens 14,100' md - 20,258' md 3-1/2" Shoe 20,258' md Page 42 Prudhoe Bay West L-294 SB Producer Drilling Procedure Page 43 Prudhoe Bay West L-294 SB Producer Drilling Procedure Page 44 Prudhoe Bay West L-294 SB Producer Drilling Procedure 18.6 Ensure to run enough liner to provide for setting the liner hanger at ~ 10,770 MD x Confirm set depth with completion engineer. 18.7 Ensure hanger/pkr will not be set in a 7” connection. x AOGCC regulations require a minimum 100’ overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 7” connection. 18.8 Before picking up Baker SLZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 18.7 M/U Baker SLZXP liner top packer to liner. 18.8 Note: PU, SO, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 18.9 RIH with liner no faster than 30 ft/min – this is to prevent buckling the liner and drill string and weight transfer to get liner to bottom with minimal rotation. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. x Ensure 4” DP/HWDP has been drifted x Fill drill pipe on the fly. Monitor FL and if filling is required due to losses/surging. 18.10 Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + SO depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 18.11 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 RPM. 18.12 If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 18.13 TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 18.14 Break circulation. Begin circulating at ~1 BPM and monitor pump pressures. Do not exceed 1,600 psi while circulating. Pusher tool is set at 2,100 psi with 5% shear screws but it should be discussed before exceeding 1,600 psi. Note all losses. Confirm all pressures with Baker 18.15 Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. Page 45 Prudhoe Bay West L-294 SB Producer Drilling Procedure 18.16 Shut down pumps. Drop setting ball down the workstring and pump slowly (1-2 BPM). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 18.17 Continue pressuring up to 2,700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the SLZXP liner hanger/packer to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,500 psi to release the HRDE running tool. 18.18 Bleed DP pressure to 0 psi. Pick up to expose rotating dog sub and set down 50K without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 RPM and set down 50K again. 18.19 PU to neutral weight, close BOP and test annulus to 1,500 psi for 10 minutes charted. 18.20 Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 18.21 PU pulling running tool free of the packer and displace with at max rate to wash the liner top. Pump sweeps as needed. 18.22 POOH. LD and inspect running tools. If setting of liner hanger/packer proceeded as planned, LD DP on the TOOH. Note: Once running tool is LD, swap to the completion AFE. Page 46 Prudhoe Bay West L-294 SB Producer Drilling Procedure 19.0 Run Upper Completion/ Post Rig Work 19.1 RU to run 4-1/2”, 12.6#, L-80 JFEBear tubing. x Ensure wear bushing is pulled. x Ensure 4-1/2”, L-80, 12.6#, JFEBear x NC50 crossover is on rig floor and M/U to FOSV. x Ensure all tubing has been drifted in the pipe shed prior to running. x Be sure to count the total # of joints in the pipe shed before running. x Keep hole covered while RU casing tools. x Record OD’s, ID’s, lengths, SN’s of all components with vendor & model info. x Monitor displacement from wellbore while RIH. Page 47 Prudhoe Bay West L-294 SB Producer Drilling Procedure Page 48 Prudhoe Bay West L-294 SB Producer Drilling Procedure 19.2 PU, MU and RH with the following 4-1/2” completion jewelry (tally to be provided by Operations Engineer): x Tubing Jewelry to include: x 1x GLM w/ GLV Installed x 1x X Nipple x 3x GLM w/ GLV installed x 1x HEX Xd Sliding Sleeve x 1x Baker Gauge Carrier x 1x 7”x4-1/2” Ahr Packer x XX joints, 4-1/2”, 12.6#, 13Cr, Vamtop x 1x X Nipple w/ RHC x XX joints, 4-1/2”, 12.6#, 13Cr, Vamtop x 1x WLEG, set as close to 7” x 4-1/2” liner xo as possible *Note the packer setting and pressure testing procedure has been changed to reflect running TBG with live gas lift valve. Please consult the OE/DE if there are any questions before proceeding. 19.3 PU and MU the 4-1/2” tubing hanger. 19.4 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 19.5 Land the tubing hanger and RILDS. Lay down the landing joint. 19.6 Install 4” HP BPV. ND BOP. Install the plug off tool. 19.7 NU the tubing head adapter and NU the tree. 19.8 PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 19.9 Pull the plug off tool and BPV. 19.10 Forward circulate the well over to corrosion inhibited KCL follow by 160 bbls of diesel freeze protect for both tubing and IA to 5,000’ MD. 19.11 Drop the ball & rod and complete loading tubing and hydraulically set the packer as per Halliburton’s setting procedure 19.12 Pressure up and test the tubing to 3500 psi for MIT-T with 1000 psi on the IA. While holding pressure on the tubing pressure the IA up to 3,500psi. Test the IA to 3500 psi for CMIT-TxIA. Record and notate all pressure tests (30 minutes) on chart. 19.13 Bleed both the IA pressure to 0psi and tubing to 200 psi. 19.14 Rig up jumper from IA to tubing to allow freeze protect to swap. Page 49 Prudhoe Bay West L-294 SB Producer Drilling Procedure 19.15 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 19.16 RDMO Innovation i. POST RIG WELL WORK 1. Slickline a. Pull Ball & Rod, RHC Plug 2. Well Tie in 3. Put well on production Page 50 Prudhoe Bay West L-294 SB Producer Drilling Procedure 20.0 Innovation Rig Diverter Schematic Page 51 Prudhoe Bay West L-294 SB Producer Drilling Procedure 21.0 Innovation Rig BOP Schematic Page 52 Prudhoe Bay West L-294 SB Producer Drilling Procedure 22.0 Wellhead Schematic 7" casing Corrected drawing page 102. - mgr Superceded Wellhead Diagram. Page 53 Prudhoe Bay West L-294 SB Producer Drilling Procedure 23.0 Days Vs Depth Page 54 Prudhoe Bay West L-294 SB Producer Drilling Procedure 24.0 Formation Tops & Information Page 55 Prudhoe Bay West L-294 SB Producer Drilling Procedure Page 56 Prudhoe Bay West L-294 SB Producer Drilling Procedure 25.0 Anticipated Drilling Hazards 12-1/4” Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECD’s to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPM’s when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti-Collison: There are no known wells with a clearance factory <1.0. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. x Surface Hole AC: x There are no wells with a clearance factor of <1.0 Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. PBU L-pad has a history of H2S on wells in all reservoirs. Page 57 Prudhoe Bay West L-294 SB Producer Drilling Procedure 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 58 Prudhoe Bay West L-294 SB Producer Drilling Procedure 8-1/2” Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of > 300 gpm Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: Crossing faults, known or unknown, can result in drilling into unstable formations that may impact future drilling and liner runs. Talk with Geologist to ensure all known faults are identified and prepared for accordingly. H2S: Treat every hole section as though it has the potential for H2S. PBU L-pad has a history of H2S on wells in all reservoirs. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: Page 59 Prudhoe Bay West L-294 SB Producer Drilling Procedure Reservoir pressures are expected to be normal. Utilize MPD to mitigate any abnormal pressure seen. Gas Cut Mud Gas cut mud as been seen on L pad, ensure sufficient MW is used during hole section. Ensure gas detectors are always functioning. Watch swab effect. Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. Casing Running Casing running issue have been noted on L pad, gravels, stability wood chunks, etc. Watch casing run, and ensure to condition hole prior to running casing, ex: backream trouble intervals. 8-1/2” Section specific A/C: x NWEILEEN-2 has a CF of .537, it is a P&A’d exploration well. The only risk is damage to the bit Page 60 Prudhoe Bay West L-294 SB Producer Drilling Procedure 6-1/8” Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: Crossing faults, known or unknown, can result in drilling into unstable formations that may impact future drilling and liner runs. Talk with Geologist to ensure all known faults are identified and prepared for accordingly. H2S: Treat every hole section as though it has the potential for H2S. PBU L-pad has a history of H2S on wells in all reservoirs. 4. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 5. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 6. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 61 Prudhoe Bay West L-294 SB Producer Drilling Procedure Abnormal Pressures and Temperatures: Reservoir pressures are expected to be normal. Utilize MPD to mitigate any abnormal pressure seen. Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. 6-1/8” Lateral A/C: x There are no wells with a CF <1.0 Page 62 Prudhoe Bay West L-294 SB Producer Drilling Procedure 26.0 Innovation Rig Layout Page 63 Prudhoe Bay West L-294 SB Producer Drilling Procedure 27.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. 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WE L L D E T A I L S : P l a n : L - 2 9 4 N A D 1 9 2 7 ( N A D C O N C O N U S ) Al a s k a Z o n e 0 4 47 . 1 0 +N / - S + E / - W N o r t h i n g E a s t i n g La t i t u d e Lo n g i t u d e 0. 0 0 0. 0 0 59 7 8 1 8 3 . 6 2 58 2 8 1 3 . 3 0 7 0 ° 2 1 ' 1 . 3 6 0 0 N 1 4 9 ° 1 9 ' 3 9 . 5 2 0 4 W RE F E R E N C E I N F O R M A T I O N Co - o r d i n a t e ( N / E ) R e f e r e n c e : We l l P l a n : L - 2 9 4 , T r u e N o r t h Ve r t i c a l ( T V D ) R e f e r e n c e : L - 2 9 4 A s - B u i l t @ 7 3 . 6 0 u s f t Me a s u r e d D e p t h R e f e r e n c e : L- 2 9 4 A s - B u i l t @ 7 3 . 6 0 u s f t Ca l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e SU R V E Y P R O G R A M Da t e : 2 0 2 2 - 1 2 - 2 9 T 0 0 : 0 0 : 0 0 V a l i d a t e d : Y e s V e r s i o n : De p t h F r o m D e p t h T o S u r v e y / P l a n To o l 26 . 5 0 1 2 0 0 . 0 0 L - 29 4 w p 0 4 ( L - 2 9 4 ) G Y D _ Q u e s t G W D 12 0 0 . 0 0 6 0 0 0 . 0 0 L - 29 4 w p 0 4 ( L - 2 9 4 ) 3 _ M W D + I F R 2 + M S + S a g 60 0 0 . 0 0 1 0 9 2 0 . 0 0 L - 29 4 w p 0 4 ( L - 2 9 4 ) 3 _ M W D + I F R 2 + M S + S a g 10 9 2 0 . 0 0 2 0 2 5 8 . 1 2 L - 29 4 w p 0 4 ( L - 2 9 4 ) 3 _ M W D + I F R 2 + M S + S a g 0. 0 0 30 . 0 0 60 . 0 0 90 . 0 0 12 0 . 0 0 15 0 . 0 0 18 0 . 0 0 Centre to Centre Separation (60.00 usft/in) 0 3 2 5 6 5 0 9 7 5 1 3 0 0 1 6 2 5 1 9 5 0 2 2 7 5 2 6 0 0 2 9 2 5 3 2 5 0 3 5 7 5 3 9 0 0 4 2 2 5 4 5 5 0 4 8 7 5 5 2 0 0 5 5 2 5 5 8 5 0 6 1 7 5 Me a s u r e d D e p t h ( 6 5 0 u s f t / i n ) L- 2 9 2 L- 2 5 1 w p 0 2 L- 0 5 w p 0 6 L- 2 0 6 L- 2 5 4 L- 2 4 7 L- 2 4 7 w p 0 5 L- 1 0 0 NW E 1 - 0 1 L- 2 3 1 L- 2 5 3 NO G L O B A L F I L T E R : U s i n g u s e r d e f i n e d s e l e c t i o n & f i l t e r i n g c r i t e r i a 26 . 5 0 T o 2 0 2 5 8 . 1 2 Pr o j e c t : P r u d h o e B a y Si t e : L We l l : P l a n : L - 2 9 4 We l l b o r e : L - 2 9 4 Pl a n : L - 2 9 4 w p 0 4 La d d e r / S . F . P l o t s 1 o f 3 CA S I N G D E T A I L S TV D T V D S S M D S i z e N a m e 27 1 3 . 4 5 2 6 3 9 . 8 5 6 0 0 0 . 0 0 9 - 5 / 8 9 5 / 8 " x 1 2 1 / 4 " 40 4 5 . 7 5 3 9 7 2 . 1 5 1 0 9 2 0 . 0 0 7 7 " x 8 1 / 2 " 40 7 3 . 6 0 4 0 0 0 . 0 0 2 0 2 5 8 . 1 2 3 - 1 / 2 3 1 / 2 " x 6 1 / 8 " &O H D U D Q F H 6 X P P D U \ $Q W L F R O O L V L R Q 5 H S R U W ' H F H P E H U +L O F R U S 1 R U W K 6 O R S H / / & 3U X G K R H % D \ /3O D Q / / / Z S 5H I H U H Q F H ' H V L J Q / 3 O D Q / / / Z S &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H :H O O & R R U G L Q D W H V 1 ( 1 : 'D W X P + H L J K W / $ V % X L O W # X V I W 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K *H R G H W L F 6 F D O H ) D F W R U $ S S O L H G 9H U V L R Q % X L O G ( 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W 12 * / 2 % $ / ) , / 7 ( 5 8 V L Q J X V H U G H I L Q H G V H O H F W L R Q I L O W H U L Q J F U L W HU L D 6F D Q 7 \ S H 6F D Q 7 \ S H 3U X G K R H % D \ +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q / / Z S &R P S D U L V R Q : H O O 1 D P H : H O O E R U H 1 D P H ' H V L J Q #0 H D V X U H G 'H S W K X V I W 0L Q L P X P 'L V W D Q F H X V I W (O O L S V H 6H S D U D W L R Q X V I W #0 H D V X U H G 'H S W K XV I W &O H D U D Q F H )D F W R U 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W 6L W H 1 D P H 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H 5H I H U H Q F H ' H V L J Q / 3 O D Q / / / Z S 0H D V X U H G 'H S W K X V I W 6X P P D U \ % D V H G R Q 0L Q L P X P 6H S D U D W L R Q : D U Q L Q J // / / &O H D U D Q F H ) D F W R U 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / $ / $ (O O L S V H 6 H S D U D W L R Q 3 D V V / / $ / $ &O H D U D Q F H ) D F W R U 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / / / &O H D U D Q F H ) D F W R U 3 D V V / / / 3 % / / 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V / / / 3 % / / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % &H Q W U H ' L V W D Q F H 3 D V V / / 3 % / 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V ' H F H P E H U &2 0 3 $ 6 6 3D J H R I 3U X G K R H % D \ +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q / / Z S &R P S D U L V R Q : H O O 1 D P H : H O O E R U H 1 D P H ' H V L J Q #0 H D V X U H G 'H S W K X V I W 0L Q L P X P 'L V W D Q F H X V I W (O O L S V H 6H S D U D W L R Q X V I W #0 H D V X U H G 'H S W K XV I W &O H D U D Q F H )D F W R U 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W 6L W H 1 D P H 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H 5H I H U H Q F H ' H V L J Q / 3 O D Q / / / Z S 0H D V X U H G 'H S W K X V I W 6X P P D U \ % D V H G R Q 0L Q L P X P 6H S D U D W L R Q : D U Q L Q J / / / &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / Z S (O O L S V H 6 H S D U D W L R Q 3 D V V / / / Z S &O H D U D Q F H ) D F W R U 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / / Z S &O H D U D Q F H ) D F W R U 3 D V V / / / Z S &O H D U D Q F H ) D F W R U 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V 1: ( / / (O O L S V H 6 H S D U D W L R Q 3 D V V 1: ( / / &O H D U D Q F H ) D F W R U 3 D V V 1: ( 1 : ( 1 : ( (O O L S V H 6 H S D U D W L R Q 3 D V V 1: ( 1 : ( 1 : ( &O H D U D Q F H ) D F W R U 3 D V V 3O D Q / / / Z S &O H D U D Q F H ) D F W R U 3 D V V 3O D Q / / / Z S &O H D U D Q F H ) D F W R U 3 D V V 3O D Q / / / Z S (O O L S V H 6 H S D U D W L R Q 3 D V V ' H F H P E H U &2 0 3 $ 6 6 3D J H R I 3U X G K R H % D \ +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q / / Z S &R P S D U L V R Q : H O O 1 D P H : H O O E R U H 1 D P H ' H V L J Q #0 H D V X U H G 'H S W K X V I W 0L Q L P X P 'L V W D Q F H X V I W (O O L S V H 6H S D U D W L R Q X V I W #0 H D V X U H G 'H S W K XV I W &O H D U D Q F H )D F W R U 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W 6L W H 1 D P H 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H 5H I H U H Q F H ' H V L J Q / 3 O D Q / / / Z S 0H D V X U H G 'H S W K X V I W 6X P P D U \ % D V H G R Q 0L Q L P X P 6H S D U D W L R Q : D U Q L Q J 3O D Q / / / Z S &O H D U D Q F H ) D F W R U 3 D V V :L O G F D W , , , &O H D U D Q F H ) D F W R U 3 D V V , , 3 % , 3 % &O H D U D Q F H ) D F W R U 3 D V V 1: ( 1 : ( 1 : ( &O H D U D Q F H ) D F W R U 3 D V V 1: ( , / ( ( 1 1 : ( , / ( ( 1 1 : ( , / ( ( 1 &O H D U D Q F H ) D F W R U )$ , / 1: ( , / ( ( 1 1 : ( , / ( ( 1 1 : ( , / ( ( 1 &H Q W U H ' L V W D Q F H 3D V V 6X U Y H \ W R R O S U R J U D P )U R P X V I W 7R X V I W 6X U Y H \ 3 O D Q 6 X U Y H \ 7 R R O / Z S * < ' B 4 X H V W * : ' / Z S B 0 : ' , ) 5 0 6 6 D J / Z S B 0 : ' , ) 5 0 6 6 D J / Z S B 0 : ' , ) 5 0 6 6 D J (O O L S V H H U U R U W H U P V D U H F R U U H O D W H G D F U R V V V X U Y H \ W R R O W L H R Q S R LQ W V 6H S D U D W L R Q L V W K H D F W X D O G L V W D Q F H E H W Z H H Q H O O L S V R L G V &D O F X O D W H G H O O L S V H V L Q F R U S R U D W H V X U I D F H H U U R U V &O H D U D Q F H ) D F W R U ' L V W D Q F H % H W Z H H Q 3 U R I L O H V ' L V W D Q F H % H W Z H H Q 3 U R I L O H V ( O O L S V H 6 H S D U D W L R Q 'L V W D Q F H % H W Z H H Q F H Q W U H V L V W K H V W U D L J K W O L Q H G L V W D Q F H E H W Z H H Q ZH O O E R U H F H Q W U H V $O O V W D W L R Q F R R U G L Q D W H V Z H U H F D O F X O D W H G X V L Q J W K H 0 L Q L P X P & X U Y D WX U H P H W K R G ' H F H P E H U &2 0 3 $ 6 6 3D J H R I 0. 0 0 1. 0 0 2. 0 0 3. 0 0 4. 0 0 Separation Factor 60 5 0 6 3 2 5 6 6 0 0 6 8 7 5 7 1 5 0 7 4 2 5 7 7 0 0 7 9 7 5 8 2 5 0 8 5 2 5 8 8 0 0 9 0 7 5 9 3 5 0 9 6 2 5 9 9 0 0 1 0 1 7 5 1 0 4 5 0 1 0 7 2 5 1 1 0 0 0 1 1 2 7 5 Me a s u r e d D e p t h ( 5 5 0 u s f t / i n ) L- 2 9 2 L- 2 9 3 NW E I L E E N - 2 L- 2 9 5 w p 0 6 No - G o Z o n e - S t o p D r i l l i n g Co l l i s i o n A v o i d a n c e R e q u i r e d Co l l i s i o n R i s k P r o c e d u r e s R e q . WE L L D E T A I L S : P l a n : L - 2 9 4 N A D 1 9 2 7 ( N A D C O N C O N U S ) Al a s k a Z o n e 0 4 47 . 1 0 +N / - S + E / - W N o r t h i n g E a s t i n g La t i t u d e Lo n g i t u d e 0. 0 0 0. 0 0 59 7 8 1 8 3 . 6 2 58 2 8 1 3 . 3 0 70 ° 2 1 ' 1 . 3 6 0 0 N 14 9 ° 1 9 ' 3 9 . 5 2 0 4 W RE F E R E N C E I N F O R M A T I O N Co - o r d i n a t e ( N / E ) R e f e r e n c e : We l l P l a n : L - 2 9 4 , T r u e N o r t h Ve r t i c a l ( T V D ) R e f e r e n c e : L - 2 9 4 A s - B u i l t @ 7 3 . 6 0 u s f t Me a s u r e d D e p t h R e f e r e n c e : L- 2 9 4 A s - B u i l t @ 7 3 . 6 0 u s f t Ca l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e SU R V E Y P R O G R A M Da t e : 2 0 2 2 - 1 2 - 2 9 T 0 0 : 0 0 : 0 0 V a l i d a t e d : Y e s V e r s i o n : De p t h F r o m D e p t h T o S u r v e y / P l a n To o l 26 . 5 0 1 2 0 0 . 0 0 L - 29 4 w p 0 4 ( L - 2 9 4 ) G Y D _ Q u e s t G W D 12 0 0 . 0 0 6 0 0 0 . 0 0 L - 29 4 w p 0 4 ( L - 2 9 4 ) 3 _ M W D + I F R 2 + M S + S a g 60 0 0 . 0 0 1 0 9 2 0 . 0 0 L - 29 4 w p 0 4 ( L - 2 9 4 ) 3 _ M W D + I F R 2 + M S + S a g 10 9 2 0 . 0 0 2 0 2 5 8 . 1 2 L - 29 4 w p 0 4 ( L - 2 9 4 ) 3 _ M W D + I F R 2 + M S + S a g 0. 0 0 30 . 0 0 60 . 0 0 90 . 0 0 12 0 . 0 0 15 0 . 0 0 18 0 . 0 0 Centre to Centre Separation (60.00 usft/in) 60 5 0 6 3 2 5 6 6 0 0 6 8 7 5 7 1 5 0 7 4 2 5 7 7 0 0 7 9 7 5 8 2 5 0 8 5 2 5 8 8 0 0 9 0 7 5 9 3 5 0 9 6 2 5 9 9 0 0 1 0 1 7 5 1 0 4 5 0 1 0 7 2 5 1 1 0 0 0 1 12 7 5 Me a s u r e d D e p t h ( 5 5 0 u s f t / i n ) NO G L O B A L F I L T E R : U s i n g u s e r d e f i n e d s e l e c t i o n & f i l t e r i n g c r i t e r i a 26 . 5 0 T o 2 0 2 5 8 . 1 2 Pr o j e c t : P r u d h o e B a y Si t e : L We l l : P l a n : L - 2 9 4 We l l b o r e : L - 2 9 4 Pl a n : L - 2 9 4 w p 0 4 La d d e r / S . F . P l o t s 2 o f 3 CA S I N G D E T A I L S TV D T V D S S M D S i z e N a m e 27 1 3 . 4 5 2 6 3 9 . 8 5 6 0 0 0 . 0 0 9 - 5 / 8 9 5 / 8 " x 1 2 1 / 4 " 40 4 5 . 7 5 3 9 7 2 . 1 5 1 0 9 2 0 . 0 0 7 7 " x 8 1 / 2 " 40 7 3 . 6 0 4 0 0 0 . 0 0 2 0 2 5 8 . 1 2 3 - 1 / 2 3 1 / 2 " x 6 1 / 8 " &O H D U D Q F H 6 X P P D U \ $Q W L F R O O L V L R Q 5 H S R U W ' H F H P E H U +L O F R U S 1 R U W K 6 O R S H / / & 3U X G K R H % D \ /3O D Q / / / Z S 5H I H U H Q F H ' H V L J Q / 3 O D Q / / / Z S &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H :H O O & R R U G L Q D W H V 1 ( 1 : 'D W X P + H L J K W / $ V % X L O W # X V I W 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K *H R G H W L F 6 F D O H ) D F W R U $ S S O L H G 9H U V L R Q % X L O G ( 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W 12 * / 2 % $ / ) , / 7 ( 5 8 V L Q J X V H U G H I L Q H G V H O H F W L R Q I L O W H U L Q J F U L W HU L D 6F D Q 7 \ S H 6F D Q 7 \ S H 3U X G K R H % D \ +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q / / Z S &R P S D U L V R Q : H O O 1 D P H : H O O E R U H 1 D P H ' H V L J Q #0 H D V X U H G 'H S W K X V I W 0L Q L P X P 'L V W D Q F H X V I W (O O L S V H 6H S D U D W L R Q X V I W #0 H D V X U H G 'H S W K XV I W &O H D U D Q F H )D F W R U 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W 6L W H 1 D P H 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H 5H I H U H Q F H ' H V L J Q / 3 O D Q / / / Z S 0H D V X U H G 'H S W K X V I W 6X P P D U \ % D V H G R Q 0L Q L P X P 6H S D U D W L R Q : D U Q L Q J // / / &O H D U D Q F H ) D F W R U 3 D V V / / $ / $ &O H D U D Q F H ) D F W R U 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / / / / &O H D U D Q F H ) D F W R U 3 D V V / / / 3 % / / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / &H Q W U H ' L V W D Q F H 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / / &H Q W U H ' L V W D Q F H 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / / &H Q W U H ' L V W D Q F H 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / / Z S (O O L S V H 6 H S D U D W L R Q 3 D V V / / / Z S &O H D U D Q F H ) D F W R U 3 D V V / / / (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3 D V V ' H F H P E H U &2 0 3 $ 6 6 3D J H R I 3U X G K R H % D \ +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q / / Z S &R P S D U L V R Q : H O O 1 D P H : H O O E R U H 1 D P H ' H V L J Q #0 H D V X U H G 'H S W K X V I W 0L Q L P X P 'L V W D Q F H X V I W (O O L S V H 6H S D U D W L R Q X V I W #0 H D V X U H G 'H S W K XV I W &O H D U D Q F H )D F W R U 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W 6L W H 1 D P H 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H 5H I H U H Q F H ' H V L J Q / 3 O D Q / / / Z S 0H D V X U H G 'H S W K X V I W 6X P P D U \ % D V H G R Q 0L Q L P X P 6H S D U D W L R Q : D U Q L Q J / / / &O H D U D Q F H ) D F W R U 3 D V V / / / &H Q W U H ' L V W D Q F H 3 D V V / / 3 % / 3 % &H Q W U H ' L V W D Q F H 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V / / / &O H D U D Q F H ) D F W R U 3D V V / / / &H Q W U H ' L V W D Q F H 3D V V / / 3 % / 3 % &H Q W U H ' L V W D Q F H 3 D V V / / 3 % / 3 % &O H D U D Q F H ) D F W R U 3 D V V / / 3 % / 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 3O D Q / / / Z S (O O L S V H 6 H S D U D W L R Q 3 D V V 3O D Q / / / Z S &O H D U D Q F H ) D F W R U 3 D V V 3O D Q / / / Z S &H Q W U H ' L V W D Q F H 3 D V V 3O D Q / / / Z S (O O L S V H 6 H S D U D W L R Q 3 D V V 3O D Q / / / Z S &O H D U D Q F H ) D F W R U 3 D V V :L O G F D W , , , &H Q W U H ' L V W D Q F H 3 D V V , , , (O O L S V H 6 H S D U D W L R Q 3 D V V , , , &O H D U D Q F H ) D F W R U 3 D V V , , 3 % , 3 % &H Q W U H ' L V W D Q F H 3 D V V , , 3 % , 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V , , 3 % , 3 % &O H D U D Q F H ) D F W R U 3 D V V 1: ( 1 : ( 1 : ( &O H D U D Q F H ) D F W R U 3 D V V 1: ( 1 : ( 1 : ( (O O L S V H 6 H S D U D W L R Q 3 D V V 1: ( 1 : ( 1 : ( &H Q W U H ' L V W D Q F H 3 D V V 1: ( , / ( ( 1 1 : ( , / ( ( 1 1 : ( , / ( ( 1 &O H D U D Q F H ) D F W R U 3 D V V ' H F H P E H U &2 0 3 $ 6 6 3D J H R I 3U X G K R H % D \ +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q / / Z S 6X U Y H \ W R R O S U R J U D P )U R P X V I W 7R X V I W 6X U Y H \ 3 O D Q 6 X U Y H \ 7 R R O / Z S * < ' B 4 X H V W * : ' / Z S B 0 : ' , ) 5 0 6 6 D J / Z S B 0 : ' , ) 5 0 6 6 D J / Z S B 0 : ' , ) 5 0 6 6 D J (O O L S V H H U U R U W H U P V D U H F R U U H O D W H G D F U R V V V X U Y H \ W R R O W L H R Q S R LQ W V 6H S D U D W L R Q L V W K H D F W X D O G L V W D Q F H E H W Z H H Q H O O L S V R L G V &D O F X O D W H G H O O L S V H V L Q F R U S R U D W H V X U I D F H H U U R U V &O H D U D Q F H ) D F W R U ' L V W D Q F H % H W Z H H Q 3 U R I L O H V ' L V W D Q F H % H W Z H H Q 3 U R I L O H V ( O O L S V H 6 H S D U D W L R Q 'L V W D Q F H % H W Z H H Q F H Q W U H V L V W K H V W U D L J K W O L Q H G L V W D Q F H E H W Z H H Q ZH O O E R U H F H Q W U H V $O O V W D W L R Q F R R U G L Q D W H V Z H U H F D O F X O D W H G X V L Q J W K H 0 L Q L P X P & X U Y D WX U H P H W K R G ' H F H P E H U &2 0 3 $ 6 6 3D J H R I 0. 0 0 1. 0 0 2. 0 0 3. 0 0 4. 0 0 Separation Factor 11 0 0 0 1 1 5 0 0 1 2 0 0 0 1 25 0 0 1 3 0 0 0 1 3 5 0 0 1 4 0 0 0 1 4 5 0 0 1 5 0 0 0 1 5 5 0 0 1 6 0 0 0 1 6 5 0 0 1 7 0 0 0 1 7 5 0 0 1 8 0 0 0 1 8 5 0 0 1 9 0 0 0 1 9 5 0 0 2 0 0 0 0 2 0 5 0 0 Me a s u r e d D e p t h ( 1 0 0 0 u s f t / i n ) L- 2 9 2 P B 1 L- 2 9 2 L- 2 1 1 P B 1 L- 2 9 3 L- 2 9 3 P B 1 NW E I L E E N - 2 I- 1 0 0 P B 1 No - G o Z o n e - S t o p D r i l l i n g Co l l i s i o n A v o i d a n c e R e q u i r e d Co l l i s i o n R i s k P r o c e d u r e s R e q . WE L L D E T A I L S : P l a n : L - 2 9 4 N A D 1 9 2 7 ( N A D C O N C O N U S ) Al a s k a Z o n e 0 4 47 . 1 0 +N / - S + E / - W N o r t h i n g E a s t i n g La t i t u d e Lo n g i t u d e 0. 0 0 0. 0 0 59 7 8 1 8 3 . 6 2 58 2 8 1 3 . 3 0 70 ° 2 1 ' 1 . 3 6 0 0 N 14 9 ° 1 9 ' 3 9 . 5 2 0 4 W RE F E R E N C E I N F O R M A T I O N Co - o r d i n a t e ( N / E ) R e f e r e n c e : We l l P l a n : L - 2 9 4 , T r u e N o r t h Ve r t i c a l ( T V D ) R e f e r e n c e : L - 2 9 4 A s - B u i l t @ 7 3 . 6 0 u s f t Me a s u r e d D e p t h R e f e r e n c e : L- 2 9 4 A s - B u i l t @ 7 3 . 6 0 u s f t Ca l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e SU R V E Y P R O G R A M Da t e : 2 0 2 2 - 1 2 - 2 9 T 0 0 : 0 0 : 0 0 V a l i d a t e d : Y e s V e r s i o n : De p t h F r o m D e p t h T o S u r v e y / P l a n To o l 26 . 5 0 1 2 0 0 . 0 0 L - 29 4 w p 0 4 ( L - 2 9 4 ) G Y D _ Q u e s t G W D 12 0 0 . 0 0 6 0 0 0 . 0 0 L - 29 4 w p 0 4 ( L - 2 9 4 ) 3 _ M W D + I F R 2 + M S + S a g 60 0 0 . 0 0 1 0 9 2 0 . 0 0 L - 29 4 w p 0 4 ( L - 2 9 4 ) 3 _ M W D + I F R 2 + M S + S a g 10 9 2 0 . 0 0 2 0 2 5 8 . 1 2 L - 29 4 w p 0 4 ( L - 2 9 4 ) 3 _ M W D + I F R 2 + M S + S a g 0. 0 0 30 . 0 0 60 . 0 0 90 . 0 0 12 0 . 0 0 15 0 . 0 0 18 0 . 0 0 Centre to Centre Separation (60.00 usft/in) 11 0 0 0 1 1 5 0 0 1 2 0 0 0 1 2 5 0 0 1 30 0 0 1 3 5 0 0 1 4 0 0 0 1 4 5 0 0 1 5 0 0 0 1 5 5 0 0 1 6 0 0 0 1 6 5 0 0 1 7 0 0 0 1 7 5 0 0 1 8 0 0 0 1 8 5 0 0 1 9 0 0 0 1 9 5 0 0 2 0 0 0 0 2 0 5 0 0 Me a s u r e d D e p t h ( 1 0 0 0 u s f t / i n ) NO G L O B A L F I L T E R : U s i n g u s e r d e f i n e d s e l e c t i o n & f i l t e r i n g c r i t e r i a 26 . 5 0 T o 2 0 2 5 8 . 1 2 Pr o j e c t : P r u d h o e B a y Si t e : L We l l : P l a n : L - 2 9 4 We l l b o r e : L - 2 9 4 Pl a n : L - 2 9 4 w p 0 4 La d d e r / S . F . P l o t s 3 o f 3 CA S I N G D E T A I L S TV D T V D S S M D S i z e N a m e 27 1 3 . 4 5 2 6 3 9 . 8 5 6 0 0 0 . 0 0 9 - 5 / 8 9 5 / 8 " x 1 2 1 / 4 " 40 4 5 . 7 5 3 9 7 2 . 1 5 1 0 9 2 0 . 0 0 7 7 " x 8 1 / 2 " 40 7 3 . 6 0 4 0 0 0 . 0 0 2 0 2 5 8 . 1 2 3 - 1 / 2 3 1 / 2 " x 6 1 / 8 " Page 52 Prudhoe Bay West L-294 SB Producer Drilling Procedure 22.0 Wellhead Schematic Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME:______________________________________ PTD:_____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD:__________________________POOL:____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. PBU L-294 223-127 X PRUDHOE BAY SCHRADER BLUFF OIL POOL W E L L P E R M I T C H E C K L I S T Co m p a n y Hi l c o r p N o r t h S l o p e , L L C We l l N a m e : PR U D H O E B A Y U N O R I N L - 2 9 4 In i t i a l C l a s s / T y p e DE V / P E N D Ge o A r e a 89 0 Un i t 11 6 5 0 On / O f f S h o r e On Pr o g r a m DE V Fi e l d & P o o l We l l b o r e s e g An n u l a r D i s p o s a l PT D # : 22 3 1 2 7 0 PR U D H O E B A Y , S C H R A D E R B L U F O I L - 6 4 0 1 3 NA 1 P e r m i t f e e a t t a c h e d Ye s AD L 0 2 8 2 3 9 , A D L 0 4 7 4 4 9 , a n d A D L 0 4 7 4 4 6 2 L e a s e n u m b e r a p p r o p r i a t e Ye s 3 U n i q u e w e l l n a m e a n d n u m b e r Ye s P R U D H O E B A Y , S C H R A D E R B L U F O I L - 6 4 0 1 3 5 - g o v e r n e d b y 5 0 5 C 4 W e l l l o c a t e d i n a d e f i n e d p o o l Ye s 5 W e l l l o c a t e d p r o p e r d i s t a n c e f r o m d r i l l i n g u n i t b o u n d a r y NA 6 W e l l l o c a t e d p r o p e r d i s t a n c e f r o m o t h e r w e l l s Ye s 7 S u f f i c i e n t a c r e a g e a v a i l a b l e i n d r i l l i n g u n i t Ye s 8 I f d e v i a t e d , i s w e l l b o r e p l a t i n c l u d e d Ye s 9 O p e r a t o r o n l y a f f e c t e d p a r t y Ye s 10 O p e r a t o r h a s a p p r o p r i a t e b o n d i n f o r c e Ye s 11 P e r m i t c a n b e i s s u e d w i t h o u t c o n s e r v a t i o n o r d e r Ye s 12 P e r m i t c a n b e i s s u e d w i t h o u t a d m i n i s t r a t i v e a p p r o v a l Ye s 13 C a n p e r m i t b e a p p r o v e d b e f o r e 1 5 - d a y w a i t NA 14 W e l l l o c a t e d w i t h i n a r e a a n d s t r a t a a u t h o r i z e d b y I n j e c t i o n O r d e r # ( p u t I O # i n c o m m e n t s ) ( F o r NA 15 A l l w e l l s w i t h i n 1 / 4 m i l e a r e a o f r e v i e w i d e n t i f i e d ( F o r s e r v i c e w e l l o n l y ) NA 16 P r e - p r o d u c e d i n j e c t o r : d u r a t i o n o f p r e - p r o d u c t i o n l e s s t h a n 3 m o n t h s ( F o r s e r v i c e w e l l o n l y ) NA 17 N o n c o n v e n . g a s c o n f o r m s t o A S 3 1 . 0 5 . 0 3 0 ( j . 1 . A ) , ( j . 2 . A - D ) Ye s 2 0 " 1 2 9 . 5 # X - 5 2 d r i v e n t o 1 1 0 ' 18 C o n d u c t o r s t r i n g p r o v i d e d Ye s 19 S u r f a c e c a s i n g p r o t e c t s a l l k n o w n U S D W s Ye s 9 - 5 / 8 " f u l l y c e m e n t e d f r o m r e s e r v o i r t o s u r f a c e . T w o s t a g e c e m e n t j o b t h r o u g h p o r t e d c o l l a r . 20 C M T v o l a d e q u a t e t o c i r c u l a t e o n c o n d u c t o r & s u r f c s g Ye s 21 C M T v o l a d e q u a t e t o t i e - i n l o n g s t r i n g t o s u r f c s g Ye s 22 C M T w i l l c o v e r a l l k n o w n p r o d u c t i v e h o r i z o n s Ye s 9 - 5 / 8 " f u l l y c e m e n t e d f r o m t o s u r f a c e . T w o s t a g e c e m e n t j o b t h r o u g h p o r t e d c o l l a r f o r s u r f a c e c a s i n g . 23 C a s i n g d e s i g n s a d e q u a t e f o r C , T , B & p e r m a f r o s t Ye s I n n o v a t i o n r i g h a s a d e q u a t e t a n k a g e a n d g o o d t r u c k i n g s u p p o r t 24 A d e q u a t e t a n k a g e o r r e s e r v e p i t NA T h i s i s a g r a s s r o o t s w e l l . 25 I f a r e - d r i l l , h a s a 1 0 - 4 0 3 f o r a b a n d o n m e n t b e e n a p p r o v e d Ye s H a l l i b u r t o n c o l l i s i o n s c a n s h o w s n o c l o s e a p p r o a c h e s t o a c t i v e o r s u s p e n d e d w e l l s w i t h H S E r i s k 26 A d e q u a t e w e l l b o r e s e p a r a t i o n p r o p o s e d Ye s 1 6 " D i v e r t e r b e l o w B O P E 27 I f d i v e r t e r r e q u i r e d , d o e s i t m e e t r e g u l a t i o n s Ye s A l l f l u i d s o v e r b a l a n c e d t o e x p e c t e d p o r e p r e s s u r e . 28 D r i l l i n g f l u i d p r o g r a m s c h e m a t i c & e q u i p l i s t a d e q u a t e Ye s 1 a n n u l a r , 3 r a m s t a c k t e s t e d t o 3 0 0 0 p s i . 29 B O P E s , d o t h e y m e e t r e g u l a t i o n Ye s 1 3 - 5 / 8 " , 5 0 0 0 p s i s t a c k t e s t e d t o 3 0 0 0 p s i . 30 B O P E p r e s s r a t i n g a p p r o p r i a t e ; t e s t t o ( p u t p s i g i n c o m m e n t s ) Ye s I n n o v a t i o n h a s 2 - 9 / 1 6 " p i p e r b a l l v a l v e s , 1 m a n u a l a n d 1 r e m o t e h y d r a u l i c c h o k e . 31 C h o k e m a n i f o l d c o m p l i e s w / A P I R P - 5 3 ( M a y 8 4 ) Ye s 32 W o r k w i l l o c c u r w i t h o u t o p e r a t i o n s h u t d o w n Ye s M o n i t o r i n g w i l l b e r e q u i r e d . 33 I s p r e s e n c e o f H 2 S g a s p r o b a b l e NA T h i s i s a d e v e l o p m e n t w e l l . 34 M e c h a n i c a l c o n d i t i o n o f w e l l s w i t h i n A O R v e r i f i e d ( F o r s e r v i c e w e l l o n l y ) No H 2 S m e a s u r e s r e q u i r e d . M a x r e a d i n g o f 3 0 0 p p m a t L - 2 0 4 ( 2 0 2 1 ) 35 P e r m i t c a n b e i s s u e d w / o h y d r o g e n s u l f i d e m e a s u r e s Ye s N o r m a l p r e s s u r e g r a d i e n t e x p e c t e d ( 8 . 5 p p g o r l e s s ) . M P D w i l l m i t i g a t e a n y a b n o r m a l p r e s s u r e s e n c o u n t e r e d 36 D a t a p r e s e n t e d o n p o t e n t i a l o v e r p r e s s u r e z o n e s NA 37 S e i s m i c a n a l y s i s o f s h a l l o w g a s z o n e s NA 38 S e a b e d c o n d i t i o n s u r v e y ( i f o f f - s h o r e ) NA 39 C o n t a c t n a m e / p h o n e f o r w e e k l y p r o g r e s s r e p o r t s [ e x p l o r a t o r y o n l y ] Ap p r AD D Da t e 12 / 2 8 / 2 0 2 3 Ap p r MG R Da t e 12 / 2 8 / 2 0 2 3 Ap p r AD D Da t e 12 / 2 8 / 2 0 2 3 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e *&: JL C 1 / 2 / 2 0 2 4