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225-053
Originated: Delivered to:9-Oct-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2P-422A 50-103-20400-01 910312860 Kuparuk River Multi Finger Caliper Field & Processed 23-Sep-25 0 12 2P-422A 50-103-20400-01 910313140 Kuparuk River Multi Finger Caliper Field & Processed 28-Sep-25 0 13 2X-12A 50-029-21189-01 910262801 Kuparuk River Leak Detect Log Field- Final 26-Aug-25 0 14 3G-07A 50-103-20127-01 910313294 Kuparuk RiverLeak Detect LogField- Final 14-Sep-25 0 15 3K-20 50-029-23019-00 910312855 Kuparuk River Multi Finger Caliper Field & Processed 26-Sep-25 0 16 3K-32 50-029-22763-00 910292590 Kuparuk River Multi Finger Caliper Field & Processed 31-Aug-25 0 17 3Q-07 50-029-21682-00 910313132 Kuparuk River Tubing Cut Record Field- Final 28-Sep-25 0 18 3Q-09 50-029-21674-00 910313102 Kuparuk River Plug Setting Record Field- Final 13-Sep-25 0 19 3T-617 50-103-20918-00 910346072 Kuparuk River Radial Bond Record Field & Processed 25-Sep-25 0 110 1B-10 50-029-20656-00 910325714 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 16-Sep-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40970202-067195-176190-085201-088197-076186-194186-186225-053181-135T40974T40974T40975T40976T40977T40978T40979T40980T409813T-61750-103-20918-00910346072Kuparuk RiverRadial Bond RecordField & Processed25-Sep-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 13:02:18 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?KRU 3T-617 Yes No 9. Property Designation (Lease Number):10. Field: Torok Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 23186 5051 23184 5051 1798 None None Casing Collapse Structural Conductor Surface 2470 Intermediate 4790 Intermediate 7850 Liner 9210 Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Manabu Nozaki Manabu Nozaki Contact Email:Manabu.Nozaki@cop.com Contact Phone:907-265-6519 Authorized Title:Staff Completions Engineer Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8/29/2025 Length AOGCC USE ONLY 11590 Tubing Grade:Tubing MD (ft): TNT Packer: 6919' MD / 4915' TVD ZXP: 7092' MD / 4972' TVD Subsequent Form Required: Suspension Expiration Date: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL393884 / ADL025528 / ADL393883 225-053 P.O. Box 100360, Anchorage, Alaska 99510-0360 50-103-20918-00-00 ConocoPhillips Alaska Inc. Kuparuk Field Will perfs require a spacing exception due to property boundaries? Current Pools: Size Proposed Pools: MD PRESENT WELL CONDITION SUMMARY 6890 5210 119 2457 4697 119 2681 TVD Burst MPSP (psi):Plugs (MD): 7-5/8"6232 2642 7263 6270 20" 10-3/4" 80 993 4-1/2" 9/12/2025 2318416092 4-1/2" 5051 Halliburton TNT Prod Packer Baker ZXP, No SSSV L-80 10860 Perforation Depth TVD (ft):Perforation Depth MD (ft): 50187-5/8" m n P 2 6 5 6 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:03 am, Sep 02, 2025 A.Dewhurst 05SEP25 CDW 09/02/2025 VTL 9/5/2025 325-536 9/12/2025 10-404 DSR-9/10/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.10 11:16:01 -08'00'09/10/25 RBDMS JSB 091125 SECTION 1 - AFFIDAVIT 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). SECTION 2 – PLAT 20 AAC 25.283 (2)(A) Plat 1: Wells within 1/2 mile Table 1: Wells within 1/2 miles (2)(C) Business Unit ID Business Area ID Field Name API * Well Name Status Symbology Well in Frac Port 1/2 mi Buffer Open Interval in Frac Port 1/2 mi Buffer NAK NAK NORTH ALASKA EXPLORATION 501032064500 NUNA 1 SUSP Suspended Yes - Suspended Yes - Suspended NAK NAK NORTH ALASKA EXPLORATION 501032064570 NUNA 1PB1 PA Plugged and Abandoned Yes - P&A Yes - P&A NAK OU OOOGURUK UNIT 501032066000 NDST-02 SUSP Suspended Yes - Suspended Yes - Suspended NAK OU OOOGURUK UNIT 501032066070 NDST-02PB1 PA Plugged and Abandoned KUP TOROK TOROK 501032087870 3S-626PB1 PA Plugged and Abandoned KUP TOROK TOROK 501032088200 3T-621 ACTIVE Injector Produced Water Yes Yes KUP TOROK TOROK 501032088700 3T-603 ACTIVE Oil KUP TOROK TOROK 501032089000 3T-608 ACTIVE Injector Produced Water KUP TOROK TOROK 501032089600 3T-612 ACTIVE Injector Produced Water Yes Yes KUP TOROK TOROK 501032089900 3T-616 ACTIVE Oil Yes Yes KUP TOROK TOROK 501032089970 3T-616PB1 PROP Proposed Yes Yes KUP TOROK TOROK 501032089971 3T-616PB2 PROP Proposed KUP COYOTE COYOTE 501032090500 3T-731 ACTIVE Oil KUP COYOTE COYOTE 501032090700 3T-730 ACTIVE Injector Produced Water KUP TOROK TOROK 501032091400 3T-613 ACTIVE Oil Yes Yes KUP TOROK TOROK 501032091700 3T-605 ACTIVE Oil KUP TOROK TOROK 501032084200 3S-625 ACTIVE Injector Produced Water Yes Yes KUP TOROK TOROK 501032084400 3S-615 ACTIVE Oil Yes Yes KUP TOROK TOROK 501032077400 3S-611 ACTIVE Oil KUP TOROK TOROK 501032077700 3S-612 ACTIVE Injector Miscible Water Alternating Gas Yes Yes KUP TOROK TOROK 501032087500 3S-610 ACTIVE Oil KUP TOROK TOROK 501032087800 3S-626 ACTIVE Oil 3T-617 Frac Sundry Well - Wells within 1/2 Mile Buffer of Well Track SECTION 3 – FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), “That portions of the aquifers on the North Slope described by a ¼ mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field”. SECTION 4 – PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. SECTION 5 – DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented and tested in accordance with 20 AAC 25.030. See Wellbore schematic for casing details. Intermediate TOC SonicScope 3019' MD / 2697' TVD Surface Casing 10.75" 45.5# L80 H563 2681' MD /2457' TVD 45° Inc Cemented to Surface Conductor 20" Insulated 119' MD Cemented to Surface Upper Completion 1. 4ea SLB (VanOil) Gas Lift Mandrel 2. HES Opsis Dual Downhole Gauge 3. HES 7-5/8" x 4-½” TNT Packer 4. Arsenal Glass Disk (to be shared during frac) 5. HES Self-Aligned Muleshoe with Baker Shear Locator Lower Completion 1. Baker ZXP Packer and Flex-V Lock Hanger 2. 31ea AU Frac Sleeves 3. Alpha Sleeves (#15 and #16) 4. Citadel MOAS Shoe 3T-617 Moraine Producer Base Perm 1583' MD / 1548' TVD Top Coyote 4970' MD / 4066' TVD Top Torok Oil Pool (Moraine) 7220' MD / 5007' TVD Intermediate Casing 7.625" 29.7# L80 H563 7263' MD /5019' TVD (33.7# P110S H563 Heavy Heel) Production TOL ZXP LTP/HGR 7092' MD /4921' TVD 6.5” Production Hole 23186' MD / 5051' TVD Production Liner w/ Frac Sleeves 4.5" 12.6# P110S H563 23184' MD / 5051' TVD Cemented to top of liner Well Plan: Actual Updated: 08/04/2025 (All TVDs are TVDRKBs) CDW 09/02/2025 SECTION 6 – ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4” casing cement report on 07/07/2025 was pumped with 404 barrels of 11 ppg lead cement and 57 barrels 15.8 ppg tail cement. This was displaced with 228 bbl 9.8 ppg spud mud. The plug bumped and the floats held. The 7-5/8” casing cement report on 07/15/2025 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 99 barrels of 14.0 ppg lead cement, followed with 60 barrels of 15.3 ppg tail cement. This was displaced with 319 barrels of 10.0 ppg NAF. The plug bumped, pressure was bled off, and floats were confirmed to be holding. A cement bond log indicates competent cement with a cement top @ 3,019’ MD (2,698’ TVD). The 4-1/2” liner cement report on 07/30/2025 shows the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 450 barrels of 13.5 ppg cement. The cement was displaced with 9.5 ppg CI NaCl brine, and the plugs did not bump. Floats held. Estimated 60 bbls of cement lost and 77 bbls of NAF mud lost. The liner top packer was set and tested to 3850 psi for 10 minutes. The liner pressure test failed at 815 psi, confirming a wet shoe. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. The 4-1/2” liner cement report on 07/30/2025 shows the job was pumped as designed, indicating competentpjpp g, gp cementing operations. The cement job was pumped with 450 barrels of 13.5 ppg cement. The cement wasgp j p p ppg displaced with 9.5 ppg CI NaCl brine, and the plugs did not bump. Floats held. Estimated 60 bbls of cement lostp ppg , p g p and 77 bbls of NAF mud lost. The liner top packer was set and tested to 3850 psi for 10 minutes. The liner pp pressure test failed at 815 psi, confirming a wet shoe. , 3,019’ SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO PRESSURE- TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 07/08/2025 the 10-3/4” casing was pressure tested to 3,000 psi for 30 minutes. On 07/15/2025 the 7-5/8” casing was pressure tested to 4,000 psi for 30 minutes. On 08/03/2025 the 4-1/2” tubing was pressure tested to 4,200 psi. On 08/03/2025 The 7-5/8” casing by 4-1/2” tubing annulus was pressure tested to 3,850 psi. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,050 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 7-5/8" Annulus pressure test 3,850 4-1/2" Tubing pressure Test 4,200 Electronic PRV 8,050 Highest pump trip 7,550 SECTION 8 – PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight, ppf Grade API Burst, psi API Collapse, psi 10-3/4” 45.5 L-80 5,209 2,474 7-5/8” 29.7 L-80 6,885 4,789 7-5/8” 33.7 P-110S 10,860 7,870 4-1/2” 12.6 L-80 8,430 7,500 Table 2: Wellbore pressure ratings Stimulation Surface Rig-Up Kuparuk 10K Frac Tree SECTION 9 – DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, the Torok Oil Pool, has an average thickness of approximately 277 ft TVD over the course of the lateral section of well 3T-617, from where it intersects the top formation at 7,220’ MD (4,956’ TVDSS) to the TD of the well. The Torok Oil Pool is comprised of thinly interbedded sandstone, siltstone, and silty shale layers. The sandstone and siltstone components are litharenites, moderately to well sorted, and very fine grained. The silty shales are composed of clay-rich, moderately to poorly sorted silt and clay. The estimated fracture pressure for the Moraine interval is approximately 12.5-13.5 ppg. The overlying confining interval of the Torok Formation consists of mudstones and siltstones with a thickness of approximately 770’ TVD along the 3T-617 trajectory. The top of the Torok confining interval in the well starts at 5129’ MD (4,117’ TVDSS). The estimated fracture gradient of the overlying Torok formation is approximately 0.82 psi/ft. The underlying confining zone below the Base Moraine consists of lower Torok, HRZ, and Kalubik shales totaling approximately 500’ TVD. The estimated fracture gradient for this section ranges from 15-18 ppg, with the gradient increasing down section. The Base Moraine is estimated from seismic to be at 5,236 ft TVDSS at the heel while it was intersected at 5,100 ft TVDSS in the toe portion of the well. The estimated formation pressure within the Torok Oil Pool is 2,285psi at a depth of 5,200’ TVDSS. SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: Nuna 1: The 7-5/8” casing was cemented in place on 2/16/2012. The cement report indicates that the job was pumped with 40 bbls 15.8ppg Class G cement. The plugs bumped and partial returns were observed during the job. Suspension operations began on 1/18/2023 where a cement retainer was set at 9,062’ CTMD and 65bbls of Class G cement was pumped through the retainer. Another retainer was placed at 7,965’ MD and 48bbls of 15.8ppg cement was pumped with another 12 bbls laid on top of the retainer. The TOC was tagged at 7,003’ MD and a MIT-T performed to 1700 psi, witnessed by AOGCC on 3/1/2023. A tubing cut was completed at 6,960’ MD and the 4.5” tubing was then pulled. A CIBP was set at 6,910’ MD and tested to 1,200 psi. Cement was laid on top of the retainer and tagged at 6,621’ MD two times with 12klbs. Source: 211-155 Laserfiche WebLink Nuna 1 PH: Three abandonment plugs were placed on 2/10/2012. The three plugs were set as balanced plugs at the following depths: 7,347’-6,847’ MD with 52 bbls of 15.8ppg Class G cement, 6,847’-6,285’ MD with 60bbls of 15.8ppg Class G cement, and 6,285’-5,800’ MD with 49bbls of 17.0ppg Class G cement. The top plug was tagged with 25klbs at 5,790’ MD/4,192’ TVD/4,149’ TVDSS prior to kick off for the main wellbore. Source: 211-155 Laserfiche WebLink NDST-02: The 7-5/8” casing was cemented on 2/8/2013. The cement report indicates that the job was pumped with 60 bbls of 15.8ppg Premium Cement with 3% Halad (R)-344 low fluid loss control. Full circulation was seen throughout the entire job. Abandonment operations include: the tubing was cut at 8,316’ MD and was removed from the well. On 10/8/2024, coil tubing set a cement retainer at 10,441’ MD and pumped 110bbls of 15.8ppg cement into the 4.5” liner. Coil unstung from the retainer and laid an additional 68bbls of 15.8ppg cement on top of the retainer. The cement plug was not tagged due to issues with deviation/thick fluid, but a pressure test was completed to 1700 psi and witness by AOGCC on 10/12/2024 (pg. 2-6 at link). Another attempt to tag the TOC was completed on 2/8/2025 with coil tubing, tagging at 8,812’ MD with 4klbs and witnessed by AOGCC. Source: 212-163 Laserfiche WebLink 3T-621: The intermediate casing cement job was pumped with 82bbls of 15.3ppg cement. Plugs bumped and floats held. Source: 224-022 Laserfiche WebLink 3T-612: The intermediate casing cement job was pumped with 98 bbls of 14.0ppg lead cement and 58 bbls of 15.3ppg tail cement. Plugs bumped and floats held. Source: 224-128 Laserfiche WebLink 3T-616: The intermediate casing cement job was pumped with 117 bbls of 14.0ppg with BMII lead cement and 58bbls of 15.3ppg tail cement. Plugs bumped and floats held. Source: 224-138 Laserfiche WebLink 3T-616PB1: The abandonment plug consisted of 42bbls of 16.3ppg cement laid in at the heel of the wellbore into the 7-5/8” intermediate casing shoe. The cement top was then tagged at 9,065’ MD/5,104’ TVD/5,053’ TVDSS with 12klbs. At Nuna 1/PH, Moraine is isolated but shallower Coyote is not. CPAI is not planning to frac stage 28 as a result. See frac design attachment. -A.Dewhurst 05SEP25 Source: 224-138 Laserfiche WebLink 3T-613: The intermediate casing cement job was pumped with 211 bbls of 14.0ppg lead cement and 59 bbls of 15.3ppg tail cement. Plugs bumped and floats held. Source: 225-036 Laserfiche WebLink 3S-625: The 7-5/8” casing cement report on 9/29/2022 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 297 barrels of 15.3ppg cement with BMII. The cement was displaced with 574 barrels of 9.6ppg LSND drilling mud. The plug did not bump and 50% of shoe track volume was pumped. Losses totaled 21 barrels during the job. Cement floats held. A cement bond log indicates competent cement with a cement top @ 7,850’ MD / 3,970’ TVDRKB / 3,908’ TVDSS. Source: 222-079 Laserfiche WebLink 3S-615: The 7-5/8” casing cement report on 11/13/2022 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 200 barrels of 15.3 ppg lead cement with BMII, followed with 33 barrels of 15.3 ppg tail cement, displaced with 524 barrels of 9.6 ppg mud. The plug bumped, bled off pressure and pressure and floats were confirmed to be holding. A cement bond log indicates competent cement with a cement top @ 5,620 MD / 3,340’ TVDRKB / 3,279’ TVDSS. Source: 222-101 Laserfiche WebLink 3S-612: The 7-5/8” casing cement report on 11/4/2018 shows that the job was pumped as designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before dropping bottom plug, this was then chased with 303bbls of 15.8 ppg Class G cement and the top plug was dropped. This was chased with 9.5 ppg LSND mud. The plug bumped, pressured up to 1500 psi and held for 5 min. Floats were checked and they held. Full returns were seen throughout the job. A TOC was then logged and determined at 8,270’MD / 3,832’ TVDRKB / 3,768’ TVDSS Source: 218-111 Laserfiche WebLink SECTION 11 – LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that two faults transect the Torok Oil Pool reservoir within one half mile radius of the 3T-617 wellbore trajectory. These faults all strike NE-SW and are shown in Plat 1. They intersect the 3T-617 well trajectory at 19,734’ MD (Fault 1) and 20,382’ MD (Fault 2), respectively. Both faults are upthrown on the northern side, between ~10-30ft. Both faults encountered by the well are difficult to trace on the seismic data, due to a) lack of fine-scale resolution at the Torok Oil Pool level and b) lack of reflectivity in the overlying Torok shales, the result of the monotonous shaly lithology. Fault 1 is currently mapped to extend about 200ft into the Torok overburden, whereas it has the potential to penetrate through the overburden into the overlying hydrocarbon bearing Coyote Oil Pool. However, due to the shaly overburden and horizontal stress acting on the fault (interpreted to be 15.8 ppg at the fault’s mapped orientation) the presence of the fault will not interfere with containment. If there is any indication that a fracture has intersected any mapped fault (or any other faults unmapped to date) during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 3T-617 was completed in August 2025 as a horizontal producer in the Torok formation. The well is completed with a 4.5” tubing upper completion and a cemented 4.5” liner with a dart activated sliding sleeve lower completion. Because the liner cement job did not go as per plan, coiled tubing cleanout will be performed prior to the frac job. The first stage frac will be pumped through a toe initiator valve in the toe of the lateral. After the 1st stage, a dart will be dropped to shift open the 2nd stage sleeve and isolate the first stage. A frac will then be pumped through the 2nd stage. Darts will continue to be dropped to provide isolation from the previous stage and open each subsequent stage. Proposed Procedure: Halliburton Pumping Services: 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre- existing conditions. 2. Ensure the frac tree was tested to ~10,000 psi at rig. 3. Ensure all pre-frac well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,217’ MD / 2,108’ TVDRKB. 4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 5. MIRU 25 clean insulated Frac tanks (450 bbls usable volume per tank), with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with either seawater or treated produced water. 6. MIRU HES Frac Equipment. 7. PT Surface lines to ~9,500 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Bring up pumps and increase annulus pressure to 3,500 psi as the tubing pressures up. 10. Pump Frac Stages 1 through 32 (skipping Frac Stage 28 due to the proximity to Nuna-1) by following attached pump schedule at ~37 bpm with a maximum expected treating pressure of ~7,050 psi. 11. The well is ready for Post Frac well prep/production tree installation, coiled tubing cleanout and flowback. skipping Frac Stage 28 due to the proximity to Nuna-1 SECTION 13 – POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a de-sander unit until the fluids clean up at which time it will be turned over to production for initial clean up production. Frac Design Attachments: CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.48LAT LEASE3T-617SALES ORDERBHST (°F)139LONGFORMATIONMoraineDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval CL-28M BC-140X2 Losurf-300D MO-67 LD-6450 WG-36 OPTIFLO-III OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Crosslinker Surfactant Buffer Clay Control Gel Breaker BreakerBiocideInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In1:40:52 1-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:40:52 1-3 Shut-In Shut-In1:36:06 1-4 Shut-In Shut-In1:36:06 1-5 30# Hybor G-i Establish Stable Fluid 15 8,400 200 200 0:13:20 1:36:06 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.151-6 30# Hybor G-i Pad 37 24,250 577 577 0:15:36 1:22:46 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.151-7 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 1:07:10 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.151-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 12,000 286 298 12,000 0:08:04 0:59:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.151-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 16,000 381 415 32,000 0:11:14 0:51:17 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.151-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 16,000 381 432 48,000 0:11:42 0:40:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.151-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 10,000 238 281 40,000 0:07:37 0:28:20 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.151-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 8,000 190 229 36,000 0:06:12 0:20:44 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.151-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 6,400 152 186 32,000 0:05:03 0:14:31 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.151-14 30# Linear Flush 37 14,710 350 350 0:09:28 0:09:28 1.00 0.50 1.00 30.00 2.00 2.00 0.152-1 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:51:44 2-2 Shut-In Shut-In1:46:58 2-3 30# Linear Spacer and Dart Drop 5 1,260 30 30 0:06:00 1:46:58 1.00 0.50 1.00 30.00 2.00 2.000.152-4 30# Linear Displace Dart to Seat 15 13,431 320 320 0:21:19 1:40:58 1.00 0.50 1.00 30.00 2.00 2.000.152-5 30# Linear DFIT 10 1,680 40 40 0:04:00 1:19:39 1.00 0.50 1.00 30.00 2.00 2.000.152-6 Shut-In Shut-In1:15:39 2-7 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 1:15:39 1.00 0.50 1.00 30.00 2.00 2.000.152-8 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 1:14:18 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.152-9 30# Hybor G-i Pad 37 19,550 465 465 0:12:35 1:08:54 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.152-10 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:56:19 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.152-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 12,000 286 298 12,000 0:08:04 0:48:30 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.152-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 15,000 357 389 30,000 0:10:32 0:40:26 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.152-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 14,000 333 378 42,000 0:10:14 0:29:54 1.00 0.25 1.00 0.50 30.00 2.00 2.000.152-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 10,000 238 281 40,000 0:07:37 0:19:40 1.00 0.25 1.00 0.50 30.00 2.00 2.000.152-15 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 8,000 190 233 40,000 0:06:19 0:12:03 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.152-16 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 6,000 143 181 36,000 0:04:55 0:05:44 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.152-17 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.153-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 2.00 2.000.153-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.153-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.154-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 1:06:05 1.00 0.50 1.00 30.00 2.00 2.000.154-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 1:04:44 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:59:20 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-4 30# Hybor G-i Conditioning Pad 100M 0.2500 37 12,000 286 289 3,000 0:07:49 0:53:05 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:45:16 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:43:55 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:42:10 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:39:14 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:35:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:31:40 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:27:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:22:58 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:18:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:14:53 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.154-15 30# Linear Flush 37 13,726 327 327 0:08:50 0:12:20 1.00 0.50 1.00 30.00 2.00 2.000.154-16 Freeze Protect Freeze Protect 10 1,470 35 35 0:03:30 0:03:30 4-17 Shut-In Shut-InLiquid AdditivesDry AdditivesInterval 1Moraine@ 23012.88 - 23017.22 ft - °F"Alpha SleeveInterval 2Moraine@ 22469.47 - 22473.81 ft - °F"Frac Sleeve 1Interval 3Moraine@ 21971.3 - 21975.64 ft - °F"Frac Sleeve 2Interval 4Moraine@ 21473.47 - 21477.81 ft 138.9 °F"Frac Sleeve 3Conoco Phillips - 3T-617Planned Design1 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.48LAT LEASE3T-617SALES ORDERBHST (°F)139LONGFORMATIONMoraineDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval CL-28M BC-140X2 Losurf-300D MO-67 LD-6450 WG-36 OPTIFLO-III OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Crosslinker Surfactant Buffer Clay Control Gel Breaker BreakerBiocideInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives5-1 Shut-In Shut-In1:37:11 5-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:37:11 5-3 Shut-In Shut-In1:32:26 5-4 30# Linear Spacer and Dart Drop 5 1,260 30 30 0:06:00 1:32:26 1.00 0.50 1.00 30.00 2.00 2.000.155-5 30# Linear Displace Dart to Seat 15 13,408 319 319 0:21:17 1:26:26 1.00 0.50 1.00 30.00 2.00 2.000.155-6 30# Linear DFIT 10 1,680 40 40 0:04:00 1:05:09 1.00 0.50 1.00 30.00 2.00 2.000.155-7 Shut-In Shut-In1:01:09 5-8 Shut-In Shut-In1:01:09 5-9 30# Hybor G-i Establish Stable Fluid 15 8,400 200 200 0:13:20 1:01:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-10 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-11 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-15 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-16 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-17 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-18 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-19 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-20 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-21 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.155-22 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.156-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 2.00 2.000.156-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.156-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.157-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 2.00 2.000.157-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-4 30# Hybor G-i Conditioning Pad 100M 0.2500 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.157-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.00 0.158-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 1:05:16 1.00 0.50 1.00 30.00 2.00 2.000.158-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 1:03:55 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:58:31 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:52:15 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:44:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:43:06 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.0000 37 4,000 95 108 12,000 0:02:56 0:41:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:38:25 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:34:44 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:30:51 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:26:35 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:22:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:17:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:14:04 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.158-15 30# Linear Flush 37 12,453 296 296 0:08:01 0:11:31 1.00 0.50 1.00 30.00 2.00 2.000.158-16 Freeze Protect Freeze Protect 10 1,470 35 35 0:03:30 0:03:30 8-17 Shut-In Shut-InInterval 5Moraine@ 20975.79 - 20980.13 ft 138.9 °F"Frac Sleeve 4Interval 6Moraine@ 20478.18 - 20482.52 ft 138.7 °F"Frac Sleeve 5Interval 7Moraine@ 19979.71 - 19984.05 ft 138.6 °F"Frac Sleeve 6Interval 8Moraine@ 19481.55 - 19485.89 ft 138.5 °F"Frac Sleeve 7Conoco Phillips - 3T-617Planned Design2 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.48LAT LEASE3T-617SALES ORDERBHST (°F)139LONGFORMATIONMoraineDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval CL-28M BC-140X2 Losurf-300D MO-67 LD-6450 WG-36 OPTIFLO-III OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Crosslinker Surfactant Buffer Clay Control Gel Breaker BreakerBiocideInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives9-1 Shut-In Shut-In1:35:10 9-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:35:10 9-3 Shut-In Shut-In1:30:24 9-4 30# Linear Spacer and Dart Drop 5 1,260 30 30 0:06:00 1:30:24 1.00 0.50 1.00 30.00 2.00 2.000.159-5 30# Linear Displace Dart to Seat 15 12,134 289 289 0:19:16 1:24:24 1.00 0.50 1.00 30.00 2.00 2.000.159-6 30# Linear DFIT 10 1,680 40 40 0:04:00 1:05:09 1.00 0.50 1.00 30.00 2.00 2.000.159-7 Shut-In Shut-In1:01:09 9-8 Shut-In Shut-In1:01:09 9-9 30# Hybor G-i Establish Stable Fluid 15 8,400 200 200 0:13:20 1:01:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-10 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-11 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-15 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-16 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-17 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-18 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-19 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-20 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-21 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.159-22 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.1510-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 2.00 2.000.1510-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1510-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.1511-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 2.00 2.000.1511-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1511-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.00 0.1512-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 1:04:27 1.00 0.50 1.00 30.00 2.00 2.000.1512-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 1:03:06 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:57:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:51:26 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:43:38 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:42:17 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:40:32 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:37:36 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:33:55 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:30:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:25:46 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:21:20 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:16:35 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:13:15 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1512-15 30# Linear Flush 37 11,183 266 266 0:07:12 0:10:42 1.00 0.50 1.00 30.00 2.00 2.000.1512-16 Freeze Protect Freeze Protect 10 1,470 35 35 0:03:30 0:03:30 12-17 Shut-In Shut-InInterval 12Moraine@ 17495.88 - 17500.22 ft 138.5 °F"Frac Sleeve 11Interval 9Moraine@ 18983.34 - 18987.68 ft 138.5 °F"Frac Sleeve 8Interval 10Moraine@ 18485.15 - 18489.49 ft 138.4 °F"Frac Sleeve 9Interval 11Moraine@ 17988.65 - 17992.99 ft 138.3 °F"Frac Sleeve 10Conoco Phillips - 3T-617Planned Design3 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.48LAT LEASE3T-617SALES ORDERBHST (°F)139LONGFORMATIONMoraineDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval CL-28M BC-140X2 Losurf-300D MO-67 LD-6450 WG-36 OPTIFLO-III OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Crosslinker Surfactant Buffer Clay Control Gel Breaker BreakerBiocideInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives13-1 Shut-In Shut-In1:33:09 13-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:33:09 13-3 Shut-In Shut-In1:28:23 13-4 30# Linear Spacer and Dart Drop 5 1,260 30 30 0:06:00 1:28:23 1.00 0.50 1.00 30.00 2.00 2.000.1513-5 30# Linear Displace Dart to Seat 15 10,866 259 259 0:17:15 1:22:23 1.00 0.50 1.00 30.00 2.00 2.000.1513-6 30# Linear DFIT 10 1,680 40 40 0:04:00 1:05:09 1.00 0.50 1.00 30.00 2.00 2.000.1513-7 Shut-In Shut-In1:01:09 13-8 Shut-In Shut-In1:01:09 13-9 30# Hybor G-i Establish Stable Fluid 15 8,400 200 200 0:13:20 1:01:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-10 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-11 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-15 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-16 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50000 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-17 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-18 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-19 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-20 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-21 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1513-22 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.1514-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 2.00 2.000.1514-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.0000 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1514-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.1515-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 2.00 2.000.1515-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-4 30# Hybor G-i Conditioning Pad 100M 0.2500 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1515-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.00 0.1516-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 1:03:38 1.00 0.50 1.00 30.00 2.00 2.000.1516-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 1:02:17 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:56:53 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:50:37 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:42:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:41:28 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:39:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:36:47 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:33:06 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:29:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:24:57 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:20:31 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:15:46 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:12:25 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1516-15 30# Linear Flush 37 9,912 236 236 0:06:23 0:09:53 1.00 0.50 1.00 30.00 2.00 2.000.1516-16 Freeze Protect Freeze Protect 10 1,470 35 35 0:03:30 0:03:30 16-17 Shut-In Shut-InInterval 13Moraine@ 16999.88 - 17004.22 ft 138.9 °F"Frac Sleeve 12Interval 14Moraine@ 16502.17 - 16506.51 ft 139.3 °F"Frac Sleeve 13Interval 15Moraine@ 16004.53 - 16008.87 ft 139.3 °F"Frac Sleeve 14Interval 16Moraine@ 15506.25 - 15510.59 ft 139.2 °F"Frac Sleeve 15Conoco Phillips - 3T-617Planned Design4 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.48LAT LEASE3T-617SALES ORDERBHST (°F)139LONGFORMATIONMoraineDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval CL-28M BC-140X2 Losurf-300D MO-67 LD-6450 WG-36 OPTIFLO-III OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Crosslinker Surfactant Buffer Clay Control Gel Breaker BreakerBiocideInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives17-1 Shut-In Shut-In1:11:54 17-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:11:54 17-3 Shut-In Shut-In1:07:09 17-4 30# Linear Spacer and Dart Drop 5 1,260 30 30 0:06:00 1:07:09 1.00 0.50 1.00 30.00 2.00 2.000.1517-5 30# Hybor G-i Establish Stable Fluid 15 8,400 200 200 0:13:20 1:01:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-6 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-7 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.0000 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-15 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-16 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-17 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1517-18 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.1518-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1518-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.1519-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 2.00 2.000.1519-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1519-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.00 0.1520-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 1:02:49 1.00 0.50 1.00 30.00 2.00 2.000.1520-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 1:01:28 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:56:04 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:49:48 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:42:00 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:40:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:38:54 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:35:58 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:32:17 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:28:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:24:07 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:19:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:14:57 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:11:36 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1520-15 30# Linear Flush 37 8,640 206 206 0:05:34 0:09:04 1.00 0.50 1.00 30.00 2.00 2.000.1520-16 Freeze Protect Freeze Protect 10 1,470 35 35 0:03:30 0:03:30 20-17 Shut-In Shut-InInterval 17Moraine@ 15008.5 - 15012.84 ft 139.3 °F"Frac Sleeve 16Interval 18Moraine@ 14512.55 - 14516.89 ft 139.3 °F"Frac Sleeve 17Interval 19Moraine@ 14015.18 - 14019.52 ft 139.2 °F"Frac Sleeve 18Interval 20Moraine@ 13516.91 - 13521.25 ft 139.1 °F"Frac Sleeve 18Conoco Phillips - 3T-617Planned Design5 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.48LAT LEASE3T-617SALES ORDERBHST (°F)139LONGFORMATIONMoraineDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval CL-28M BC-140X2 Losurf-300D MO-67 LD-6450 WG-36 OPTIFLO-III OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Crosslinker Surfactant Buffer Clay Control Gel Breaker BreakerBiocideInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives21-1 Shut-In Shut-In1:29:07 21-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:29:07 21-3 Shut-In Shut-In1:24:21 21-4 30# Linear Spacer and Dart Drop 5 1,260 30 30 0:06:00 1:24:21 1.00 0.50 1.00 30.00 2.00 2.000.1521-5 30# Linear Displace Dart to Seat 15 8,322 198 198 0:13:13 1:18:21 1.00 0.50 1.00 30.00 2.00 2.000.1521-6 30# Linear DFIT 10 1,680 40 40 0:04:00 1:05:09 1.00 0.50 1.00 30.00 2.00 2.000.1521-7 Shut-In Shut-In1:01:09 21-8 Shut-In Shut-In1:01:09 21-9 30# Hybor G-i Establish Stable Fluid 15 8,400 200 200 0:13:20 1:01:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-10 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-11 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-15 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-16 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-17 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-18 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-19 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-20 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-21 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1521-22 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.1522-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 2.00 2.000.1522-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1522-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1522-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1522-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1522-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1522-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1522-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1522-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1522-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1522-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1522-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1522-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1522-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 2.00 2.000.1522-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 30.00 2.00 2.000.1523-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 2.00 2.000.1523-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1523-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1523-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1523-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1523-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1523-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1523-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1523-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1523-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1523-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 30.00 2.00 2.000.1523-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 30.00 2.00 2.000.1523-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 30.00 2.00 2.000.1523-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 30.00 2.00 2.000.1523-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 30.00 2.00 2.00 0.1524-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 1:02:00 1.00 0.50 1.00 30.00 2.00 2.000.1524-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 1:00:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:55:14 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:48:59 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:41:11 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:39:50 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:38:04 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:35:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:31:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:27:35 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:23:18 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:18:53 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:14:07 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:10:47 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1524-15 30# Linear Flush 37 7,367 175 175 0:04:44 0:08:14 1.00 0.50 30.00 2.00 2.000.1524-16 Freeze Protect Freeze Protect 10 1,470 35 35 0:03:30 0:03:30 0.50 30.0024-17 Shut-In Shut-In0.50 30.0025-1 Shut-In Shut-In1:11:54 25-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:11:54 25-3 Shut-In Shut-In1:07:09 25-4 30# Linear Spacer and Dart Drop 5 1,260 30 30 0:06:00 1:07:09 1.00 0.50 1.00 30.00 1.50 2.00 0.1525-5 30# Hybor G-i Establish Stable Fluid 15 8,400 200 200 0:13:20 1:01:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1525-6 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1525-7 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1525-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1525-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1525-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1525-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1525-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1525-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.15Interval 21Moraine@ 13020.03 - 13024.37 ft 139.2 °F"Frac Sleeve 20Interval 22Moraine@ 12522.04 - 12526.38 ft 139.1 °F"Frac Sleeve 21Interval 24Moraine@ 11525.53 - 11529.87 ft 139 °FInterval 25Moraine11027.71 - 11032.05 ft 138.8 °FInterval 23Moraine@ 12023.84 - 12028.18 ft 139 °FConoco Phillips - 3T-617Planned Design6 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.48LAT LEASE3T-617SALES ORDERBHST (°F)139LONGFORMATIONMoraineDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval CL-28M BC-140X2 Losurf-300D MO-67 LD-6450 WG-36 OPTIFLO-III OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Crosslinker Surfactant Buffer Clay Control Gel Breaker BreakerBiocideInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives25-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1525-15 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1525-16 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1525-17 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1525-18 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.1526-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 2.00 2.000.1526-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 1.50 2.000.1526-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 1.50 2.000.1526-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 1.50 2.000.1526-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 1.50 2.000.1526-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 1.50 2.000.1526-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1526-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1526-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1526-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1526-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1526-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1526-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1526-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1526-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.1527-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 1.50 2.000.1527-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 1.50 2.000.1527-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 1.50 2.000.1527-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 1.50 2.000.1527-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 1.50 2.000.1527-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1527-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1527-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1527-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1527-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1527-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1527-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1527-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1527-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1527-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.00 0.1528-1 Shut-In SKIP DO NOT OPEN29-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 1:00:56 1.00 0.50 1.00 30.00 2.000.1529-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:59:35 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:54:11 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:47:56 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:40:07 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:38:46 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:37:01 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:34:05 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:30:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:26:31 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:22:15 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:17:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:13:04 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:09:44 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1529-15 30# Linear Flush 37 5,723 136 136 0:03:41 0:07:11 1.00 0.50 1.00 30.00 2.00 2.000.1529-16 Freeze Protect Freeze Protect 10 1,470 35 35 0:03:30 0:03:30 29-17 Shut-In Shut-In30-1 Shut-In Shut-In1:11:54 30-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:11:54 30-3 Shut-In Shut-In1:07:09 30-4 30# Linear Spacer and Dart Drop 5 1,260 30 30 0:06:00 1:07:09 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-5 30# Hybor G-i Establish Stable Fluid 15 8,400 200 200 0:13:20 1:01:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-6 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-7 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-15 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-16 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-17 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1530-18 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.00 0.1531-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:54:34 1.00 0.50 1.00 30.00 2.00 2.00 0.1531-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:53:13 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1531-3 30# Hybor G-i Pad 37 9,720 231 231 0:06:15 0:47:49 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1531-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:41:33 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1531-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1531-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1531-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1531-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1531-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1531-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1531-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.15Interval 2@ 1Interval 26Moraine@ 10488.25 - 10492.59 ft 137.8 °FInterval 27Moraine@ 9990.36 - 9994.7 ft 136.8 °FInterval 29Moraine@ 8952.8 - 8957.14 ft 133.3 °FInterval 30Moraine@ 8454.48 - 8458.82 ft 131 °FInterval 31Moraine7916.62 - 7920.96 ft 128.3 °FConoco Phillips - 3T-617Planned Design7 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.48LAT LEASE3T-617SALES ORDERBHST (°F)139LONGFORMATIONMoraineDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval CL-28M BC-140X2 Losurf-300D MO-67 LD-6450 WG-36 OPTIFLO-III OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Crosslinker Surfactant Buffer Clay Control Gel Breaker BreakerBiocideInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives31-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.00 0.1531-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1531-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1531-15 30# Linear Spacer and Dart Drop 37 1,260 30 30 0:00:49 0:00:49 1.00 0.50 1.00 30.00 2.00 2.000.1532-1 30# Linear Pre-Pad 37 2,100 50 50 0:01:21 0:57:12 1.00 0.50 1.00 30.00 2.00 2.000.1532-2 30# Hybor G-i Establish Stable Fluid 37 8,400 200 200 0:05:24 0:55:51 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-3 30# Hybor G-i Pad 37 4,860 116 116 0:03:08 0:50:26 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-4 30# Hybor G-i Conditioning Pad 100M 0.25 37 12,000 286 289 3,000 0:07:49 0:47:19 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-5 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:39:30 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-6 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:38:09 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-7 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:36:24 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-8 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:33:29 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-9 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:29:47 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-10 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:25:54 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-11 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:21:38 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-12 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:17:12 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-13 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:12:27 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-14 30# Hybor G-i Proppant Laden Fluid 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:09:07 1.00 0.25 1.00 0.50 1.00 30.00 2.00 2.000.1532-15 30# Linear Flush 37 4,768 114 114 0:03:04 0:06:34 1.00 0.50 1.00 30.00 2.00 2.000.1532-16 Freeze Protect Freeze Protect 10 1,470 35 35 0:03:30 0:03:30 32-17 Shut-In Shut-In2,568,263 61,149 67,834 6,293,000Design Total (gal)Design Total (lbs)CL-28M BC-140X2 Losurf-300D MO-67 LD-6450 WG-36 OPTIFLO-III OPTIFLO-II BE-66,200,000(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)241,14393,000Initial Design Material Volume 2,306.4 576.6 2,547.5 1,273.0 2,492.3 76,379.2 5,060.0 5,090.8 382.1-3240.01057220,760-Whole Units to be ordered 112,306,360-CL-28M BC-140X2 Losurf-300D MO-67 LD-6450 WG-36 OPTIFLO-III OPTIFLO-II BE-6-(gpm) (gpm) (gpm) (gpm) (gpm) ppm ppm ppm ppm-Max Additive Rate 1.6 0.4 1.6 0.8 1.6 46.6 3.1 3.1 0.2-Min Additive RateFluid Type30# Hybor G30# LinearSeawaterFreeze Protect30# Hybor G-i---Proppant Type16/20 Ceramic100M---@ 7Interval 32@ 7460.06 - ft 126 °F10:29:16 Conoco Phillips - 3T-617Planned Design8 Hydraulic Fracturing Fluid Product Component Information Disclosure 2025-07-24 Alaska HARRISON BAY 50-103-20918-00-00 CONOCOPHILLIPS 3T 617 -150.26664371 70.42049225 NAD83 none Oil 5200 2439949.85 Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Ingredient Mass lbs Comments Company First Name Last Name Email Phone Produced Water (Density 8.5)Operator Base Fluid Density = 8.50 SEAWATER (SG 8.52)Operator Base Fluid Density = 8.52 BA-20 BUFFERING AGENT Halliburton Buffer BC-140 X2 Halliburton Initiator BE-6(TM) Bactericide Halliburton Microbiocide CAT-3 ACTIVATOR Halliburton Activator CL-28M CROSSLINKER Halliburton Crosslinker CLA-WEB(TM) Halliburton Clay Stabilizer Legend LD-6450 MultiChem Completion/Stimulati on LoSurf-300D Halliburton Non-ionic Surfactant MO-67 Halliburton pH Control OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker Patina Energy Flow Insurance Brass Patina Energy Additive ResMetrics Oil Phase Tracer ResMetrics Tracer ResMetrics Water Phase Tracer ResMetrics Tracer WG-36 GELLING AGENT Halliburton Gelling Agent Ceramic Proppant - Wanli Wanli Proppant SAND, COMMON BROWN 100 MESH Halliburton Proppant CarboLite 16/20 Carbo Ceramics Proppant Flow Insurance Copper Patina Energy Tracer Fresh Water Operator Base Fluid Ingredients Water 7732-18-5 95.00%59.44519%20787521 Ceramic Materials and Wares, Chemicals 66402-68-4 100.00%17.72988%6200000 Corundum 1302-74-5 60.00%10.63793%3720000 Mullite 1302-93-8 40.00%7.09195%2480000 Sodium chloride 7647-14-5 5.00%3.12869%1094081 Water 7732-18-5 100.00%1.32247%462458 Crystalline silica, quartz 14808-60-7 100.00%0.27184%95061 Guar gum 9000-30-0 100.00%0.21842%76379 Calcium chloride, dihyrate 10035-04-8 60.00%0.04575%15999 Borate salts Proprietary 60.00%0.04190%14653 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871- 6226 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Ethanol 64-17-5 60.00%0.03250%11364 Ammonium persulfate 7727-54-0 100.00%0.02911%10180 Monoethanolamine borate 26038-87-9 100.00%0.01674%5853 Heavy aromatic petroleum naphtha 64742-94-5 30.00%0.01625%5682 Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.01625%5682 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Sodium hydroxide 1310-73-2 30.00%0.01157%4045 Oxylated phenolic resin Proprietary 30.00%0.00873%3054 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Ethylene glycol 107-21-1 70.00%0.00555%1943 Oxyalkylated phenolic resin Proprietary 10.00%0.00542%1894 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Copolymer of acrylamide and sodium acrylate 25085-02-3 5.00%0.00381%1334 Potassium chloride 7447-40-7 5.00%0.00349%1222 Inorganic mineral 1317-65-3 5.00%0.00349%1222 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, branched 127087-87-0 5.00%0.00271%947 Naphthalene 91-20-3 5.00%0.00271%947 Water 7732-18-5 100.00%0.00243%850 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00109%382 Flow Insurance Copper Proprietary 100.00%0.00105%368 Patina Energy Product Stewardship test@patinae nergy.com 7205324886 Calcium magnesium carbonate 16389-88-1 1.00%0.00070%245 Gluteraldehyde 111-30-8 1.00%0.00070%245 Inorganic mineral Proprietary 1.00%0.00070%245 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Polymer Proprietary 1.00%0.00070%245 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Glycol Ether Proprietary 80.00%0.00061%214 ResMetrics Product Stewardship info@resmetr ics.com 8325921900 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00054%190 Sodium chloride 7647-14-5 1.00%0.00039%135 Proprietary1 Proprietary 20.00%0.00023%81 ResMetrics Product Stewardship info@resmetr ics.com 8325921900 C.I. pigment Orange 5 3468-63-1 1.00%0.00015%51 Proprietary NoN-hazardous Proprietary 100.00%0.00013%44 Patina Energy Product Stewardship test@patinae nergy.com 6692416025 Polymer Proprietary 0.10%0.00008%27 MultiChem Ana Djuric Ana.Djuric@ Halliburton.co m 281-871-5747 Methanesulfonic acid, 1-hydroxy-, sodium salt 870-72-4 0.10%0.00007%25 Sodium bisulfate 7681-38-1 0.10%0.00007%25 Ammonium acetate 631-61-8 100.00%0.00003%10 2,7-Naphthalenedisulfonic acid, 3- hydroxy-4-[(4-sulfor-1- naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00002%6 Ammonium salt Proprietary 60.00%0.00002%6 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Acetic acid 64-19-7 30.00%0.00001%3 EDTA/Copper chelate Proprietary 30.00%0.00001%3 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00001%3 5-Chloro-2-methyl-3(2H)- Isothaiazolone 26172-55-4 0.01%0.00001%3 Magnesium nitrate 10377-60-3 0.01%0.00001%3 Magensium chloride 7786-30-3 0.01%0.00001%3 Ammonium chloride 12125-02-9 5.00%0.00000%1 Ammonia 7664-41-7 1.00%0.00000%1 Quaternary amine Proprietary 0.10%0.00000%1 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Amine salts Proprietary 0.10%0.00000%1 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 * Total Water Volume sources may include fresh water, produced water, and/or recycled water _ ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.5 All component information listed was obtained from the supplier’s Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration’s (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D. Production Type: True Vertical Depth (TVD): Total Water Volume (gal)*: MSDS and Non-MSDS Ingredients are listed below the green line Well Name and Number: Longitude: Latitude: Long/Lat Projection: Indian/Federal: Fracture Date State: County: API Number: Operator Name: 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 3T-617 (PTD No. 225-053; Sundry No. 325-536) Paragraph Sub-Paragraph Section Complete? AOGCC Page 1 September 5, 2025 (a) Application for Sundry Approval (a)(1) Affidavit Provided with application. A.Dewhurst 05SEP25 (a)(2) Plat Provided with application. A.Dewhurst 05SEP25 (a)(2)(A) Well location Provided with application. Well lies in Section 1 of T12N, R7E, UM. A.Dewhurst 05SEP25 (a)(2)(B) Each water well within ½ mile None: According to the Water Estate map available through DNR’s Alaska Mapper application, there are no wells used for drinking water purposes known to lie within ½ mile of the surface location of KRU 3T-617. There are no subsurface water rights or temporary subsurface water rights within 5 miles of the surface location. A.Dewhurst 05SEP25 (a)(2)(C) Identify all well types within ½ mile Provided with application. The operator has identified 22 wells within ½-mile radius. A.Dewhurst 05SEP25 (a)(3) Freshwater aquifers: geological name; measured and true vertical depth This well lies within the boundary of the Kuparuk River Unit Aquifer Exemption map that shows the area exempted under Title 40 CFR 147.102(b)(3) as currently depicted on EPA Region 10’s “Alaska Oil & Gas Aquifer Exemptions Interactive Map”, available through EPA Region 10’s web site. Recent communication from the EPA to the AOGCC has indicated that the exempted aquifer area was fixed to the 1986 boundary/extents as defined when the exemption was granted. The AOGCC is currently seeking guidance from the EPA to confirm that the 3T pad is within the original boundary that was granted the exemption. A.Dewhurst 05SEP25 (a)(4) Baseline water sampling plan Not applicable. There are no water wells within a ½-mile radius of the wellbore trajectory. A.Dewhurst 05SEP25 (a)(5) Casing and cementing information Provided with application. Proposed schematic attached, as built not generated to date. TOC included. CDW 09/02/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 3T-617 (PTD No. 225-053; Sundry No. 325-536) Paragraph Sub-Paragraph Section Complete? AOGCC Page 2 September 5, 2025 (a)(6) Casing and cementing operation assessment 10-3/4” surface casing cemented to surface. 7-5/8” intermediate casing cemented from shoe of 7263 ft to TOC 3,019 ft (SonicScope), 4.5” production liner cemented to liner top, No issues with cement for the upcoming stimulation. CDW 09/02/2025 (a)(6)(A) Casing cemented below lowermost freshwater aquifer and conforms to 20 AAC 25.030 Only exempt freshwater aquifers are present. See Section (a)(3), above. Yes. A.Dewhurst 05SEP25 (a)(6)( B) Each hydrocarbon zone is isolated Yes, cement isolates each hydrocarbon zone. Coyote and Moraine isolated by 7-5/8" intermediate casing cement. TOC at 3,019' MD. A.Dewhurst 05SEP25/ CDW 09/02/2025 (a)(7) Pressure test: information and pressure-test plans for casing and tubing installed in well Provided with application. 3850 psi MITIA, 4200 psi MITT. CDW 09/02/2025 (a)(8) Pressure ratings and schematics: wellbore, wellhead, BOPE, treating head Provided with application. Maximum predicted treating pressure 7050 psi. 10K psi frac tree max. frac. Pressure limited by testing to 7318 psi. Pump knock out 7,550 psi and ePRV 8050 psi., tree test 10K psi, lines test 9500 psi. CDW 09/02/2025 (a)(9)(A) Fracturing and confining zones: lithologic description for each zone (a)(9)(B) Geological name of each zone (a)(9)(C) and (a)(9)(D) Measured and true vertical depths (a)(9)(E) Fracture pressure for each zone Upper confining zones: Torok Formation mudstone and siltstone having about 770’ of true vertical thickness (TVT). Fracture gradient is expected to range from about 0.82 psi/ft (15.8 ppg EMW). Fracturing Zone: Torok Oil Pool interbedded very fine-grained sandstone, siltstone and silty shale of around 277’ TVT. Fracture gradient expected to range from about 0.65 to 0.70 psi/ft (12.5 to 13.5 ppg EMW). Lower confining zones: Lower Torok, HRZ shale, and Kalubik shale that have an aggregate TVT about 500’. Fracture A.Dewhurst 05SEP25 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 3T-617 (PTD No. 225-053; Sundry No. 325-536) Paragraph Sub-Paragraph Section Complete? AOGCC Page 3 September 5, 2025 gradient expected to range from about 0.78 to 0.94 psi/ft (15 to 18 ppg EMW). See application for detailed depths. (a)(10) Location, orientation, report on mechanical condition of each well that may transect the confining zones and sufficient information to determine wells will not interfere with containment of hydraulic fracturing fluid within ½ mile of the proposed wellbore trajectory It is highly unlikely that any of the wells or wellbores within a ½-mile radius will interfere with hydraulic fracturing fluids from this operation because of cement isolation and / or separation distance. There are 22 wells within ½ mile of 3T-617 and 11 wells (including pilot holes and plugbacks) that penetrate the confining intervals. AOGCC evaluated all 11 wells (including plugbacks and sidetracks) that may transect the confining zones within the KRU 3T-617 Area of Review. CPAI has not identified any wells for increased monitoring during frac – but have decided to not frac stage 28 due to proximity to Nuna-1 which doesn’t have Coyote isolated. Max frac propped half-length of max 330 ft at stage 18 (15009 ft MD) , 190 ft at toe 23013 ft, and 250 ft at 7,460 ft (shallowest frac port). AOGCC finds it is unlikely that any of these wells will interfere with fracturing fluids due to cement-isolation and/or separation distance or direction. Latest AOR included via emails and sharepoint includes 3S and 3T and no pad wells and cementing/isolation details. A.Dewhurst 05SEP25/ CDW 09/02/2025 (a)(11) Faults and fractures, Sufficient information to determine no interference with containment of the hydraulic fracturing fluid within ½ mile of the proposed wellbore trajectory The operator has identified 2 faults that intersect KRU 3T-617. It is unlikely that these faults will interfere with containment of the injected fracturing fluids; however, if there are indications that a fracture has intersected a fault or natural-fracture interval during frac operations, the operator will go to flush and terminate the stage immediately. Description of the faults are in the application. A.Dewhurst 05SEP25 (a)(12) Proposed program for fracturing operation Provided with application. CDW 09/02/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 3T-617 (PTD No. 225-053; Sundry No. 325-536) Paragraph Sub-Paragraph Section Complete? AOGCC Page 4 September 5, 2025 (a)(12)(A) Estimated volume Provided with application. 67834 bbl total dirty volume (includes freeze protect). 6.3M lb total proppant CDW 09/02/2025 (a)(12)(B) Additives: names, purposes, concentrations Provided with application. CDW 09/02/2025 (a)(12)(C) Chemical name and CAS number of each Provided with application. Halliburton, Patina, and Resmetrics chemicals disclosures provided. Proprietary chemicals on file at AOGCC. CDW 09/02/2025 (a)(12)(D) Inert substances, weight or volume of each Provided with application. CDW 09/02/2025 (a)(12)(E) Maximum treating pressure with supporting info to determine appropriateness for program Based on stated testing, AOGCC will limit surface frac pressure to 7318 psi Max. CPAI estimates max treating pressure of 7050 psi. Max pressure is 7550-8050 psi ePRV. With 3500 psi back pressure IA (IA popoff set 3600 psi), max tubing differential should be 3818 psi. CDW 09/02/2025 (a)(12)(F) Fractures – height, length, MD and TVD to top, description of fracturing model Provided with application. The maximum anticipated half-length of the induced fractures is 300’. The maximum fracture height is anticipated to be 275’. See the application for details. A.Dewhurst 05SEP25 (a)(13) Proposed program for post-fracturing well cleanup and fluid recovery Well cleanout and flowback procedure provided with application. No disposal identified but CPAI 3T has options. CDW 09/02/2025 (b)Testing of casing or intermediate casing Tested >110% of max anticipated pressure 3500 psi back pressure, plan to test to 3850 psi, popoff set as 3600 psi CDW 09/02/2025 (c) Fracturing string (c)(1) Packer >100’ below TOC of production or intermediate casing 4.5” tubing will be anchored with a liner top packer set at 7092 ft (casing shoe 7263 ft) with shallowest sleeve planned for 7460 ft (skip stage 28 only). TOC in 7-5/8” casing at 3019 ft. SonicScope CBL conservatively shows good cement at area of interest so no cement concerns. CDW 09/02/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 3T-617 (PTD No. 225-053; Sundry No. 325-536) Paragraph Sub-Paragraph Section Complete? AOGCC Page 5 September 5, 2025 (c)(2) Tested >110% of max anticipated pressure differential Tubing test of 4200 psi. Max pressure differential allowed is 3818 psi. With 3500 psi IA hold, max allowed surface frac pressure is calculated as 7318 psi to satisfy 110% CDW 09/02/2025 (d) Pressure relief valve Line pressure <= test pressure, remotely controlled shut-in device 9500 psi line pressure test, pump knock out 7550-8050 psi ePRV. IA PRV set as 3600 psi. CDW 09/02/2025 (e) Confinement Frac fluids confined to approved formations Provided with application. CDW 09/02/2025 (f) Surface casing pressures Monitored with gauge and pressure relief device IA PRV set at 3600 psi. Surface annulus open. Frac pressures continuously monitored. CDW 09/02/2025 (g) Annulus pressure monitoring & notification 500 psi criteria During hydraulic fracturing operations, all annulus pressures must be continuously monitored and recorded. If at any time during hydraulic fracturing operations the annulus pressure increases more than 500 psig above those anticipated increases caused by pressure or thermal transfer, the operator shall: CDW 09/02/2025 (g)(1) Notify AOGCC within 24 hours (g)(2) Corrective action or surveillance (g)(3) Sundry to AOGCC (h) Sundry Report (i) Reporting (i)(1) FracFocus Reporting (i)(2) AOGCC Reporting: printed & electronic (j) Post-frac water sampling plan Not required (see Section (a)(3), above). A.Dewhurst 05SEP25 (k) Confidential information Clearly marked and specific facts supporting nondisclosure Non-confidential well. A.Dewhurst 05SEP25 (l) Variances requested Modifications of deadlines, requests for variances or waivers No plan for post fracture water well analysis. Commission may require this depending on performance of the fracturing operation. Originated: ,§I 701 W Sth Avenue Anchorage, AK 99501 (907) 273-1700 m (907)273-4760 fax Delivered to: Alaska Oil & Gas Conservation Commission ATTN: Gavin Gluyas Anchorage, Alaska 99501-3539 RANSM ITTAL DATE - TRANSMITTAL# 225-053 T40848 3T-617 50-103-20918-00-00 225-053 1w- KUPARUK RIVER r MWDILWDIDD rIN r r VISION Service FINAL FIELD 28-Jul-25 r. r 1 Formation Evaluation Drilling Mechanics Depth 1 1 r • NA NA NA r NA TeleSCcopeTrulink/DigiScope ,Spliced Time 1 1 NA TeleScope/Trulink Time-LWD003 1 1 NA Trulink Time-LWD004 1 1 NA DigiScope Recorded Mode Per Well 4 1 1 arcVISION/PeriScope/adnVISION - Spliced LWD001 4 2 2 arcVISION LWD003 4 2 2 arcVISION LWD004 4 2 2 PeriScope/adnVISION Real Time Per Well 4 1 1 arcVISION/PeriScope/adnVISION- Spliced LWD Tool Specific LWD001 NA NA 2 arcVISION LWD003 NA NA 2 arcVISION LWD004 NA NA 4 PeriScope/adnVISION Survey Well Data 1 NA NA NA 9 1 TeleScope/TruLink/DigiScope Top of Cement Real Time Recorded Mode LWD003 LWD003 1 6 1 1 1 1 1 1 NA NA NA NA SonicScope SonicScope insmittal Receipt G'Dya: A Transmittal Receipt signature confirms that a package (box, Gavin Gluyas Date:2025.09.0408:24:30 envelope, etc.) has been received and the contents of the package X-08,00, have been verified to match the media noted above. The specific nt Name Signature Date content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. !ase return via courier or sign/scan and email a copy to Schlumberger. SLB-Private 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 Chris Brillon Wells Engineering Manager Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re: Kuparuk River Field, Torok Oil Pool, KRU 3T-617 Conoco Phillips Alaska, Inc. Permit to Drill Number: 225-053 Surface Location: 1844' FSL, 446' FWL, SENE S1 T12N R7E Bottomhole Location: 4518' FSL, 5270' FWL, SENW S21 T13N R7E Dear Mr. Brillon: 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 L. Chmielowski Commissioner DATED this 1st day of July 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.01 15:27:01 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 23185.54 TVD: 5051 4a. Location of Well (Governmental Section): 7.Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 7/13/2025 Total Depth:9. Acres in Property:14. Distance to Nearest Property: 9.9' to ADL393883 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 51.1 15. Distance to Nearest Well Open Surface: x-467656 y- 6003571 Zone- 4 12 to Same Pool: 1220' to 3T-612 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94 H-40 Welded 80.9 39.1 39.1 120 120 13.5" 10.75" 45.5 L80 Hyd563 2645.97 39.1 39.1 2685.07 2436 9.875" 7.625" 29.7 L80 Hyd563 6420.9 39.1 39.1 6460 4842 9.875" 7.625" 33.7 P110-S Hyd563 800 6460 4841.8 7260 5022 6.5" 4.5" 12.6 P110-S Hyd563 16075.54 7110 5001.35 23185.54 5051 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Brian Broussard Chris Brillon Contact Email:Brian.T.Broussard@cop.com Wells Engineering Manager Contact Phone:907-263-4090 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10 yds P.O. Box 100360 Anchorage, Alaska, 99510-0360 Kuparuk River Field Torok Oil Pool 1844' FSL, 446' FWL, SENE S1 T12N R7E ADL393884 / ADL025528 / ADL393883 (including stage data) 5004' FSL, 2498' FWL, NWSE S2 T12N R7E LONS 01-013 4518' FSL, 5270' FWL, SENW S21 T13N R7E 5645/2560/5760 GL / BF Elevation above MSL (ft): 2316 1798 18. Casing Program: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips Alaska Inc. 59-52-180 KRU 3T-617 823sks 11ppg, 273sks 15.8ppg 346sks 14ppg, 277sks 15.3ppg Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks 1412sks 13.5ppg Casing Length Size Cement Volume MD Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Surface Conductor/Structural Liner Production Intermediate Perforation Depth MD (ft): Perforation Depth TVD (ft): 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Authorized Title: Authorized Signature: Commission Use Only See cover letter for other requirements. Stratigraphic Test No Mud log req'd: Yes No No Directional svy req'd: Yes No Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis Single Well Gas Hydrates No Inclination-only svy req'd: Yes No Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal No No Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Grace Christianson at 11:40 am, Jun 16, 202511:41 am, Jun 16, 2025 Variance of the diverter requirement under 20AAC 25.035(h)(2) is approved. X 7/3/25 Initial BOP test to 5000 psig; subsequent BOP test to 4000 psig Annular preventer test to 2500 psig BOPE testing on a 21-day interval is approved with the attached conditions Intermediate I cement evaluation may use SonicScope under the attached Conditions of Approval Surface casing LOT and annular LOT to the AOGCC as soon as available Cement logs must be reviewed with the AOGCC as soon as available and prior to running the production liner. VTL 6/24/2025 DSR-6/18/25 Yes 50-103-20918-00-00 SFD 6/30/2025 225-053 ($8 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.01 15:27:14 -08'00' 07/01/25 07/01/25 RBDMS JSB 070325 <ZhϯdͲϲϭϳ Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. .58'67 CPAI’s request to allow BOPE testing on a 21-day interval is approved with the following conditions: - CPAI must continue to implement the Between Wells Maintenance Program as approved by AOGCC. - The initial test after rigging up BOPE to drill a well must be to the rated working pressure as provided in API Standard 53. - CPAI is encouraged to take advantage of opportunities to test within the 21-day time limit. - CPAI must adhere to original equipment manufacturer recommendations and replacement parts for BOPE. - Requests for extensions beyond 21 days must include justification with supporting information demonstrating the additional time is necessary for well control purposes or to mitigate a stuck drill string. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 9, 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill 3T-617 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Moraine Producer well from the 3T drilling pad. The intended spud date for this well is 7/09/2025. It is intended that Doyon 142 be used to drill the well. 3T-617 will utilize a 13 1/2” surface hole drilled to TD and 10 3/4” casing will be set and cemented to surface. As noted in section 4 of the attached proposed drilling program, the low maximum anticipated surface pressure of the well allows use of a three preventer BOPE per 20 AAC 25.035 (e) (1) (A) (i-iii). The fourth preventer will contain solid body pipe rams that will be sized for the intermediate casing string. The 9 7/8” intermediate hole will be drilled and set in the Moraine reservoir. A 7 5/8” casing string will be set and cemented from TD to secure the shoe and cover 250’TVD above any hydrocarbon-bearing zones (Coyote). The production interval will be comprised of a 6 1/2” horizontal hole that will be landed and geo-steered in the Moraine formation. The well will be completed as a fracture stimulated Producer with 4 1/2” liner and frac sleeves, cemented in place. The upper completion will include a production packer with GLM’s and a downhole guage tied back to surface. A variance is requested for a BOPE test interval of 21 days for this project. Doyon 142 is a strong participant in the CPAI BOPE between well maintenance program, reflected by low failure rates in BOP tests since its entry into the CPAI fleet. The variance allows effective drilling and completion of problematic zones, or longer intervals during the well construction. It is also requested that a variance of the diverter requirement under 20AAC 25.035(h)(2) is granted for well 3T-617. At 3T, there has not been any significant indication of shallow gas hydreates to date through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Brian Broussard at 907-263-4090 (Brian.T.Broussard@conocophillips.com) or Chris Brillon at 907-265-6120. Sincerely, cc: 3T-617 Well File / Jenna Taylor ATO 1560 Will Earhart ATO 1552 Brian Broussard Chris Brillon ATO 1548 Drilling Engineer Jiedi Wu ATO 1418 Brian Broussard I am the author of this document 2025.06.09 14:58:49-08'00' Brian Broussard variance is requested for a BOPE test interval of 21 days Recommend approving requested variance of the diverter requirement under 20AAC 25.035(h)(2). SFD variance of the diverter requirement 3T-617 PTD Page 1 of 11 3T-617 Application for Permit to Drill Document Table of Contents 1. Well Name .............................................................................................................................................................. 2 2. Location Summary ................................................................................................................................................. 2 3. Proposed Drilling Program..................................................................................................................................... 4 4. Blowout Prevention Equipment ............................................................................................................................. 5 5. Diverter System ..................................................................................................................................................... 5 6. MASP Calculations ................................................................................................................................................ 6 7. Procedure for Conducting Formation Integrity Tests ............................................................................................. 6 8. Casing and Cementing Program ........................................................................................................................... 7 9. Drilling Fluid Program ............................................................................................................................................ 7 10. Abnormally Pressured Formation Information ................................................................................................... 8 11. Seismic Analysis ................................................................................................................................................ 8 12. Seabed Condition Analysis ................................................................................................................................ 8 13. Evidence of Bonding .......................................................................................................................................... 8 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ...................................................................... 8 15. Drilling Hazards Summary ................................................................................................................................. 9 16. Proposed Completion Schematic ..................................................................................................................... 11 3T-617 PTD Page 2 of 11 1. Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 3T-617 2. Location Summary Requirements of 20 AAC 25.005(c)(2) Location at Surface 1,844 FSL, 446 FWL, SENE S1 T12N R7E, UM NAD 1927 Northings: 6003571 Eastings:467656 RKB Elevation 51.1’AMSL Pad Elevation 12’AMSL Top of Productive Horizon (Heel) 5004‘ FSL, 2498‘ FWL, NWSE S2 T12N R7E, UM NAD 1927 Northings: 6006745 Eastings: 464440 Measured Depth, RKB: 7,245’ Total Vertical Depth, RKB: 5,018 Total Vertical Depth, SS: 4,967 Total Depth (Toe) 4518‘ FSL, 5270‘ FWL, SENW S21 T13N R7E, UM NAD 1927 Northings: 6022118 Eastings: 460401 Measured Depth, RKB: 23,186 Total Vertical Depth, RKB: 5,051 Total Vertical Depth, SS: 5,000 Pad Layout 3T-617 PTD Page 3 of 11 Well Plat 3T-617 PTD Page 4 of 11 3. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) 1. MIRU Doyon 142 onto 3T-617 2. Rig up and test diverter and riser, dewater cellar as needed. 3. Drill 13 1/2” hole to the surface casing point as per the directional plan. 4. Run and cement 10 3/4” surface casing to surface. 5. Install BOPE and MPD equipment. 6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr regulatory notice). 7. Pick up and run in hole with 9 7/8” drilling BHA to drill the intermediate hole section. 8. Chart casing pressure test to 3,000 psi for 30 minutes. 9. Drill out 20’ of new hole and perform LOT. Maximum LOT to 18.0 ppg. Minimum LOT required to drill ahead is 11.0 ppg EMW. 10. Drill 9 7/8” hole to section TD, setting pipe 5-10’ TVD in the Moraine Reservoir using near-bit GR. (LWD Program: GR/RES, near-bit GR). 11. Run 7 5/8” casing and cement to a minimum of 250’ TVD above any hydrocarbon bearing zones (cementing schematic attached). Pressure test casing if possible on plug bump to 4000 psi. 12. Freeze protect down the Outer Annulus (10 3/4” surface casing x 7 5/8” intermediate casing annulus). 13. Test BOPE to 250 psi low / 4,000 psi high (24-48 Regulatory notice). 14. Pick up and run in hole with 6 1/2” drilling BHA. Log top of cement with sonic tool in real-time mode. 15. Chart casing pressure test to 4,000 psi for 30 minutes if not tested on plug bump. 16. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 16 ppg. Minimum required leak-off value is 11.0 ppg EMW. 17. Drill 6 1/2” hole to section TD (LWD Program: GR/RES/Den/Neu/Sonic). 18. Pull out of hole with drilling BHA. Review intermediate cement job details and sonic log TOC. 19. Run 4 1/2” liner with toe valve, frac sleeves, and liner hanger and packer to TD of 23,186 MD. 20. Cement liner in place. 21. Run 4 1/2” upper completion with glass plug, production packer, downhole gauge, and gas lift mandrels. Space out and land tubing hanger. 22. Pressure test hanger seals to 5,000 psi. 23. Pressure test against the glass plug to set production packer, test tubing to 4,200 psi, chart test. 24. Bleed tubing pressure to 2,200 psi and test IA to 3,850 psi, chart test. 25. Install HP-BPV. 26. Nipple down BOP. 27. Install tubing head adapter assembly. N/U frac tree and test to 10,000 psi/5 minutes. 28. Freeze protect down tubing and annulus. 29. Secure well. Rig down and move out. Please note – This well will be frac’d 3T-617 PTD Page 5 of 11 4.Blowout Prevention Equipment Requirements of 20 AAC 25.005(c)(3 & 7) Please reference BOP schematics on file for Doyon 142. Doyon 142 will use a BOPE stack equipped with an annular preventer, fixed 7 5/8” solid body rams, blind/shear rams and variable rams while drilling and running casing in the intermediate section of 3T-617. 3T-617 has a MASP of 1,798 psi in the intermediate hole section using the methodology in section 6 MASP calculations. With a MASP less than 3000 psi ConocoPhillips classifies the operation as a Class 2. Per 20AAC 25.035.e.a.A: For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least three preventers, including: i. One equipped with pipe rams that fit the size of drill pipe, tubing or casing begin used, except that pipe rams need not be sixed to bottom-hole assemblies and drill collars. ii. One with blind rams iii. One annular type Intermediate Drilling/Casing Production Proposed Configuration: Proposed Configuration: Annular Preventer (iii) Annular Preventer 7 5/8” fixed rams during drilling Intermediate VBRs in Upper Cavity Blind/Shear Rams (ii) Blind/Shear Rams VBRs (i) VBRs in Lower Cavity 5. Diverter System (Requirements of 20 AAC 25.005(c)(7)) A diverter waiver is requested, as there have been no indications of hydrates on 3T pad, with 3T-613 and 3T-621 well surface shoes within 500’ of the 3T-617. On AOGCC's map, the the nearest casing shoes to that in proposed well 3T-617 are: 3T-612 (224-128) 190' SSE: Max gas observed of 168 units while drilling surface hole across the base of permafrost. These gas measurements were previously discussed during permitting of KRU 3T-731. That permit indicates surface hole gas readings for well KRU 3T-612 are not credible due to values over 300 units before spudding. CPAI suspects gas sensor was not calibrated. (For additional information, see Well History File 224-156. p. 69). 3T-731 (224-156) 320' SSE: No mention of shallow gas at permafrost base or in surface hole. 3T-730 (225-010) 416' SW: No mention of shallow gas at permafrost base or in surface hole. 3T-608 (224-094) 720' ENE: No mention of shallow gas at permafrost base or in surface hole. 3T-621 (224-022) 820' WNW : No mention of shallow gas at permafrost base or in surface hole. SFD diverter waiver is requested Recommend approving requested diverter variance. SFD 3T-617 PTD Page 6 of 11 6. MASP Calculations Requirements of 20 AAC 25.005(c)(4) (A) maximum downhole pressure and maximum potential surface pressure; Maximum Potential Surface Pressure (MPSP) is determined as the lesser of: Method 1: surface pressure at breakdown of the formation casing seat with a gas gradient to the surface Method 2: formation pore pressure at the next casing point less a gas gradient to the surface Method 1 Method 2 ܯܲܵܲ = [(ܨܩ × 0.052 )െܩܽݏ ܩݎܽ݀݅݁݊ݐ] × ܸܶܦ ܯܲܵܲ = ܨܲܲ െ (ܩܽݏ ܩݎܽ݀݅݁݊ݐ) × ܸܶܦ Where: FG – Fracture gradient at the casing seat in lb/gal 0.052 – Conversion from lb/gal to psi/ft Gas Gradient – 0.1 psi/ft TVD – True Vertical Depth of casing seat in ft RKB Where: FPP – Formation Pore Pressure at the next casing point Gas Gradient – 0.1 psi/ft The following presents data used for calculation of Maximum Potential Surface Pressure (MPSP) while drilling: Section Hole Size Previous CSG Section TD MPSP psi MPSP MPSP Size MD TVD FG ppg Pore Pressure ppg | psi MD TVD Pore Pressure ppg | psi Method 1 psi Method 2 psi SURF 13 1/2 20 119.1 119.1 10.9 8.6 53 2,685 2,460 8.6 1100 56 56 854 INTRM 9 7/8 10 3/4 2,685 2,460 13.0 8.6 1,100 7,260 5,022 8.6 2246 1,417 1,417 1,744 PROD 6 1/2 7 5/8 7,260 5,022 13.0 8.6 2246 23,186 5,179 8.6 2,316 1,798 2,893 1,798 (B) data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary 7. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) Drill out the casing shoe and perform LOT/FIT as per the procedure that ConocoPhillips Alaska has on file with the Commission. 3T-617 PTD Page 7 of 11 8. Casing and Cementing Program Requirements of 20 AAC 25.005 (c)(6) Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 20 42 94 H40 Welded Cemented to surface with 10 yds slurry 10 3/4 13 1/2 45.50 L80 Hyd563 Cement to Surface 7 5/8 9 7/8 29.70 33.70 L80 P110-S Hyd563 250’ TVD or 500’ MD, whichever is greater, above upper most producing zone (Coyote) 4 1/2 6 1/2 12.60 P110-S Hyd563 Frac sleeves with swell packers (uncemented) Cementing Calculations 10 3/4” Surface Casing run to 2,685 ’ MD / 2,460 ’ TVD Cement 2,685 MD to 2,185 (500’ of tail) with Class G + Add's@ 15.8 PPG, and from 2,185' to surface with 11 ppg Arctic Lite Crete. Assume 200% excess annular volume in permafrost and 50% excess below the permafrost (1,569 ’ MD), zero excess in 20” conductor. Lead 2,085 ft3 => 823 sx of 11 ppg Class G + Add's @ 2.5346 ft3 /sk Tail 316 ft3 => 273 sx of 15.8ppg Class G + Add's @ 1.1582 ft3/sk 7 5/8” Intermediate Casing run to 7,260’ MD / 5,022 ’ TVD Top of slurry is designed to be at 4,621 ’ MD, which is 250’ TVD above the prognosis shallowest hydrocarbon bearing zone, Coyote. If a shallower hydrocarbon zone of producible volumes is encountered while drilling, a 2-stage cement job will be performed to isolate this zone. Assume 50% excess annular volume. Lead 529ft3 => 346 sx of 14 ppg Class G + Add's@ 1.53 ft3 /sk assuming 50% excess in 9 7/8” hole Tail 343 ft3 => 277 sx of 15.3 ppg Class G + Add's @ 1.24 ft3/sk assuming 50% excess in 9 7/8” hole 4-1/2” Production Liner run to 23,186’ MD / 5,051 ’ TVD Cement Liner from 23,186’ MD to 7,110’ MD (liner top) with Class G + Add’s @ 13.5 ppg. Assume 20% excess in the open hole, and 0% excess inside intermediate casing. Lead 2,357 ft3 => 1412 sx of 13.5 ppg Class G + Add's @ 1.67 ft3 /sk 9. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate Production Hole Size in. 13 1/2 9 7/8 6 1/2 Casing Size in. 10 3/4 7 5/8 4 1/2 Density PPG 8.6 – 9.8 9.0 – 9.5 10 PV cP 20-50 <22 <20 YP lb./100 ft2 30 - 80 20 - 30 9-13 Funnel Viscosity s/qt. 250 – 300 40-60 35-50 Initial Gels lb./100 ft2 30 - 50 10 - 18 6-15 10 Minute Gels lb./100 ft2 50 - 70 <25 8-20 API Fluid Loss cc/30 min. <10 < 10.0 N/A HPHT Fluid Loss cc/30 min. N/A N/A < 2 pH 9.5-10 9.5-10 N/A 3T-617 PTD Page 8 of 11 Surface Hole: A water based spud mud will be used for the surface interval. Mud engineer to perform regular mud checks to maintain proper specifications. The mud weight will be maintained at 9.8 ppg by use of solids control system and dilutions where necessary. Intermediate: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight at or below 9.5 ppg for formation stability and be prepared to add loss circulation material if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important. The mud will be weighted up to 9.5 ppg before pulling out of the hole. Production Hole: The horizontal production interval will be drilled with a Non-Aqueous Fluid (NAF) mud system weighted to 10 ppg. MPD will be utilized to add back pressure during connections to minimize pressure cycling. A heavy pill will be placed in the well during the trip out process to ensure an 11.1 ppg EMW is held on the formation. Diagram of Doyon 142 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 10. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. 12. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. 13. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 3T-617 PTD Page 9 of 11 15. Drilling Hazards Summary 13 1/2" Hole / 10 3/4” Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Follow real time surveys very closely, gyro survey as needed to ensure survey accuracy. Gas Hydrates Low If observed – control drill, reduce pump rates and circulating time, reduce mud temperatures Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Running sands and gravels Low Maintain planned mud properties, increase mud weight, use weighted sweeps Lost Circulation Moderate Monitor ECDs for signs of packoff before losses occur. Keep hole clean and utilize LCM sweeps to regain circulation. 9 7/8” Hole /7 5/8” Casing Interval Event Risk Level Mitigation Strategy Sloughing shale / Tight hole / Stuck Pipe Low Good hole cleaning, pre-treatment with LCM, stabilized BHA, maintain planned mud weights and adjust as needed, real time equivalent circulating density (ECD) monitoring Lost circulation Moderate Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Pressure (Coyote / K3) Low Well control drills, check for flow during connections, increase mud weight if necessary. 6 1/2” Hole / 4 1/2” Liner - Horizontal Production Interval Event Risk Level Mitigation Strategy Lost circulation Moderate Reduce pump rates, real time ECD monitoring, maintain mud rheology, add lost circulation material Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Moderate Well control drills, check for flow during connections, increased mud weight. Offset injectors shut-in. Differential Sticking Moderate Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Running Liner to Bottom Moderate Properly clean hole on the trip out with BHA, perform clean out run if necessary, utilize super sliders for weight transfer if needed, monitor T&D real time 3T-617 PTD Page 10 of 11 Well Proximity Risks: 3T is a multi-well pad, with 8 existing wells. Directional drilling / collision avoidance information as required by AOGCC 20 ACC 25.050 (b) is provided in the following attachments. The 3T-617 has a close approach with the Nuna 1. The Nuna 1 is a suspended well that is expected to be fully P&Ad by the time the 3T-617 is being drilled. Stratigraphic separation of 85’ TVD and several gamma markers will be used to confirm separation during the close approach. Drilling Area Risks: Reservoir Pressure: The reservoir pressure is expected to be elevated, estimated at 9.0 ppg, due to offset injection on the 3T- 621 and 3T-612. The 3T-621 will be shut-in in May to reduce the pore pressure to 9.0 ppg and the 3T-612 will be shut-in during drilling to prevent communication between wells. The rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. The overburden logs will be evaluated to ensure no hydrocarbon bearing zones are above the known Coyote. If identified, the primary intermediate cement job will be replanned to cover the zone as per the agency regulations. Lost Circulation: Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. 3T-617 has a close approach with the Nuna 1 expected to be fully P&Ad by the time the 3T-617 is being drilled pp 3T-617 PTD Page 11 of 11 16. Proposed Completion Schematic 39 500 500 800 800 1100 1100 1500 1500 2000 2000 3000 3000 5000 5000 8000 8000 12000 12000 18000 18000 23186 3T-617 wp10 Plan Summary 0 4 Dogleg Severity0 3500 7000 10500 14000 17500 21000 Measured Depth 10-3/4" Surface Casing 7-5/8" Intermediate Casing 4-1/2" Production Liner 30.0 30.0 60.0 60.0 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in] 3950100150200250300350400 449 499 548 597 645 694 742 3T-616 3950100150200250300350400 449 499 548 597 645 694 742 3T-616PB1 3950100150200250300350400 449 499 548 597 645 694 742 3T-616PB2 3950100150200250300350400450499549 598 647 696 744 3T-614 wp06 3950100150200250300350400450500550600649699749 799849899949999104910991149119912491299134913991449150015501600165017001750180118511902195220032054210421553T-615 wp06 3950100150200250300350400450500550600650700750800850900950100110511101115112011251130113511400145015001550160016501700175118013T-618 wp06 0 3000 True Vertical Depth0 3000 6000 9000 12000 15000 18000 Vertical Section at 338.38° 10-3/4" Surface Casing 7-5/8" Intermediate Casing 4-1/2" Production Liner 18 35 Centre to Centre Separation0 425 850 1275 1700 2125 2550 2975 Measured Depth Equivalent Magnetic Distance DDI 7.253 SURVEY PROGRAM Date: 2019-07-03T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 39.00 800.00 3T-617 wp10 (3T-617) r.5 SDI_KPR_ADK+SAG 800.00 2680.00 3T-617 wp10 (3T-617) MWD+IFR2+SAG+MS 2680.00 7250.00 3T-617 wp10 (3T-617) MWD+IFR2+SAG+MS 7250.00 23185.54 3T-617 wp10 (3T-617) MWD+IFR2+SAG+MS Ground / 12.00 CASING DETAILS TVD MD Name 2460.00 2685.07 10-3/4" Surface Casing 5022.33 7260.00 7-5/8" Intermediate Casing 5051.00 23185.54 4-1/2" Production Liner Mag Model & Date: BGGM2024 30-Jul-25 Magnetic North is 13.66° East of True North (Magnetic Declinatio Mag Dip & Field Strength: 80.60° 57168.40nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.002 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.003 500.00 2.00 318.00 499.96 2.59 -2.34 1.00 318.00 3.27 Start Build 2.004 1517.12 22.34 318.00 1489.00 161.12 -145.07 2.00 0.00 203.23 Start 108.12 hold at 1517.12 MD5 1625.23 22.34 318.00 1589.00 191.66 -172.57 0.00 0.00 241.76 Start DLS 2.25 TFO -10.006 2650.99 45.24 312.50 2436.00 587.95 -577.02 2.25 -10.00 759.17 Start 20.00 hold at 2650.99 MD7 2670.99 45.24 312.50 2450.08 597.54 -587.49 0.00 0.00 771.94 Start 2135.00 hold at 2670.99 MD8 4805.99 45.24 312.50 3953.43 1621.69 -1705.20 0.00 0.00 2135.82 Start DLS 2.00 TFO 6.819 6049.82 69.99 315.54 4614.60 2348.56 -2451.85 2.00 6.81 3086.63 Start 958.78 hold at 6049.82 MD10 7008.59 69.99 315.54 4942.72 2991.55 -3082.84 0.00 0.00 3916.86 Start DLS 3.00 TFO 66.57 11 7893.39 82.00 340.00 5159.58 3712.86 -3531.89 3.00 66.57 4752.87 Start Build 3.00 12 8093.39 88.00 340.00 5177.00 3900.00 -3600.00 3.00 0.00 4951.94 Start DLS 2.00 TFO 58.29 13 8406.49 91.30 345.33 5178.93 4198.71 -3693.25 2.00 58.29 5263.99 Start 2426.41 hold at 8406.49 MD 14 10832.90 91.30 345.33 5124.07 6545.38 -4307.77 0.00 0.00 7672.00 Start DLS 1.50 TFO 156.08 15 10927.38 90.00 345.90 5123.00 6636.88 -4331.25 1.50 156.08 7765.72 3T Eberly T02 030325 Start DLS 1.50 TFO -179.53 1610961.71 89.48 345.90 5123.15 6670.19 -4339.61 1.50 -179.53 7799.76 Start 1291.56 hold at 10961.71 MD 17 12253.27 89.48 345.90 5134.76 7922.76 -4654.34 0.00 0.00 9080.18 Start DLS 1.00 TFO -10.54 18 12305.66 90.00 345.80 5135.00 7973.56 -4667.14 1.00 -10.54 9132.13 3T Eberly T03 030325 Start DLS 1.00 TFO 2.94 19 12451.35 91.46 345.87 5133.15 8114.81 -4702.79 1.00 2.94 9276.57 Start 1013.31 hold at 12451.35 MD 2013464.66 91.46 345.87 5107.42 9097.16 -4950.00 0.00 0.0010280.91 Start DLS 1.00 TFO -179.92 21 13540.16 90.70 345.87 5106.00 9170.36 -4968.42 1.00 -179.9210355.75 3T Eberly T04 030325 Start DLS 1.00 TFO -179.93 2213608.21 90.02 345.87 5105.57 9236.35 -4985.03 1.00 -179.9310423.22 Start 4617.22 hold at 13608.21 MD 2318225.44 90.02 345.87 5104.00 13713.93 -6112.00 0.00 0.00 15001.05 Start DLS 1.00 TFO -172.33 2418227.41 90.00 345.87 5104.00 13715.84 -6112.48 1.00 -172.3315003.00 3T Eberly T05 030325 Start DLS 1.00 TFO -177.22 2518300.84 89.27 345.83 5104.47 13787.04 -6130.43 1.00 -177.2215075.81 Start 864.03 hold at 18300.84 MD 2619164.87 89.27 345.83 5115.53 14624.73 -6341.86 0.00 0.00 15932.47 Start DLS 1.00 TFO 1.22 2719238.23 90.00 345.85 5116.00 14695.86 -6359.80 1.00 1.2216005.21 3T Eberly T06 030325 Start DLS 1.00 TFO 6.57 28 19290.94 90.52 345.91 5115.76 14746.98 -6372.66 1.00 6.57 16057.47 Start 283.56 hold at 19290.94 MD 2919574.50 90.52 345.91 5113.17 15022.00 -6441.69 0.00 0.00 16338.58 Start DLS 1.50 TFO -0.79 3019672.94 92.00 345.89 5111.00 15117.44 -6465.66 1.50 -0.7916436.14 3T Eberly T07 030325 Start DLS 1.50 TFO -0.31 31 19765.88 93.39 345.88 5106.63 15207.48 -6488.30 1.50 -0.3116528.19 Start 758.82 hold at 19765.88 MD 3220524.71 93.39 345.88 5061.70 15942.10 -6673.06 0.00 0.00 17279.20 Start DLS 1.50 TFO -179.62 33 20750.99 90.00 345.86 5055.00 16161.41 -6728.27 1.50 -179.6217503.42 3T Eberly T08 030325 Start DLS 1.50 TFO -172.26 34 20824.56 88.91 345.71 5055.70 16232.72 -6746.33 1.50 -172.2617576.38 Start 516.29 hold at 20824.56 MD 35 21340.85 88.91 345.71 5065.56 16732.95 -6873.73 0.00 0.00 18088.36 Start DLS 2.00 TFO 129.83 36 21450.70 87.50 347.40 5069.00 16839.73 -6899.26 2.00 129.8318197.03 3T Eberly T09 030325 Start DLS 2.00 TFO 97.08 37 21470.35 87.45 347.79 5069.87 16858.90 -6903.48 2.00 97.0818216.41 Start 125.81 hold at 21470.35 MD 38 21596.17 87.45 347.79 5075.46 16981.75 -6930.06 0.00 0.0018340.41 Start DLS 2.00 TFO -37.34 39 21743.80 89.80 346.00 5079.00 17125.48 -6963.52 2.00 -37.3418486.36 3T Eberly T10 040225 Start DLS 2.00 TFO -86.99 40 21836.48 89.90 344.15 5079.24 17215.03 -6987.39 2.00 -86.9918578.41 Start 196.06 hold at 21836.48 MD 41 22032.54 89.90 344.15 5079.60 17403.63 -7040.94 0.00 0.00 18773.47 Start DLS 2.00 TFO 43.62 4222108.71 91.00 345.20 5079.00 17477.09 -7061.07 2.00 43.6218849.18 3T Eberly T11 040225 Start DLS 2.00 TFO 39.02 4322188.31 92.24 346.20 5076.75 17554.19 -7080.72 2.00 39.0218928.09 Start 504.84 hold at 22188.31 MD 44 22693.15 92.24 346.20 5057.05 18044.09 -7201.03 0.00 0.00 19427.86 Start DLS 1.50 TFO -119.71 45 22785.46 91.55 345.00 5054.00 18133.45 -7223.97 1.50 -119.7119519.38 3T Eberly T12 040225 Start DLS 1.50 TFO -126.54 46 22941.17 90.16 343.12 5051.68 18283.15 -7266.72 1.50 -126.5419674.30 Start 244.37 hold at 22941.17 MD 47 23185.54 90.16 343.12 5051.00 18516.99 -7337.66 0.00 0.00 19917.84 3T Eberly T13 040225 TD at 23185.54 FORMATION TOP DETAILS TVDPath Formation 1342.00 Ugnu C 1537.00 Base Perm 1607.00 Ugnu B 1722.00 Ugnu A 2024.00 West Sak 2386.00 West Sak Base 2548.00 C-80 2612.00 C-50 3009.00 C-40 3734.00 C-35 4073.00 Coyote 4168.00 Coyote Base 5018.00 Moraine 5156.00 Lower Moraine By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by Plan 12+39 @ 51.00usft (D142) -25000250050007500True Vertical Depth0 2500 5000 7500 10000 12500 15000 17500 20000Vertical Section at 338.38°10-3/4" Surface Casing7-5/8" Intermediate Casing4-1/2" Production Liner100020003000400050006000700080009000 1 000 0110001200013000 14000 15000 16000 17 000 18 000190002000021000220002300023186 0°30°45°60°70°90°91 °89°9 1 ° 90°89°91° 9 3 °89°9 2 ° 3T-617 wp10 Ugnu CBase PermUgnu BUgnu AWest SakWest Sak BaseC-80C-50C-40C-35CoyoteCoyote BaseMoraineLower Moraine3T-617 wp108:48, May 08 2025Section View 035007000105001400017500South(-)/North(+)-17500 -14000 -10500 -7000 -3500 0 3500 7000 10500West(-)/East(+)10-3/4" Surface Casing7-5/8" Intermediate Casing4-1/2" Production Liner50010001500200025003000350040004500500050513T-617 wp103T-617 wp10While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise.8:49, May 08 20253ODQ9LHZ 0.000.751.502.253.003.754.505.256.006.757.50Separation Factor0 1250 2500 3750 50006250 7500 8750 10000 11250 12500 13750 15000 16250 17500 18750 20000 21250 22500Measured Depth (2500 usft/in)NDST-02Nuna 1Nuna 1PB13S-6123S-6153T-6123T-6133T-613 wp123T-6163T-616PB13T-6213T-609 wp0STOP DrillingTake Immediate ActionCaution - Monitor CloselyNormal OperationsProject: Kuparuk River Unit_2Site: Kuparuk 3T PadWell: 3T-617Wellbore: 3T-617Design: 3T-617 wp10 0 35 Centre to Centre Separation0 400 800 1200 1600 2000 Partial Measured Depth3T-616Equivalent Magnetic Distance 3T-617 wp10 Ladder View 0 150 300 Centre to Centre Separation0 3500 7000 10500 14000 17500 21000 Measured Depth3T-6033T-605 wp12.13T-6083T-6123T-6133T-613 wp123T-6163T-616PB13T-616PB23T-6213T-731Equivalent Magnetic Distance SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.00 800.00 3T-617 wp10 (3T-617) r.5 SDI_KPR_ADK+SAG 800.00 2680.00 3T-617 wp10 (3T-617) MWD+IFR2+SAG+MS 2680.00 7250.00 3T-617 wp10 (3T-617) MWD+IFR2+SAG+MS 7250.00 23185.54 3T-617 wp10 (3T-617) MWD+IFR2+SAG+MS 10:18, May 08 2025 CASING DETAILS TVD MD Name 2460.00 2685.07 10-3/4" Surface Casing 5022.33 7260.00 7-5/8" Intermediate Casing 5051.00 23185.54 4-1/2" Production Liner 39 500 500 800 800 1100 1100 1500 1500 2000 2000 3000 3000 5000 5000 8000 8000 12000 12000 18000 18000 23186 3T-617 wp10 TC View 30 30 60 60 90 90 120 120 150 150 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in] 9149 9194 9240 9286 9331 9377 9423 9469 9514 9560 9605 9650 9695 9740 9786 Nuna 1 3950100150200250 300350400450499549599648698747797846895944 993 1042109111391188123712851334138214311479152815781627167517231772182018681915196320112059210721552202225022982346239324412489253625842632268127302779282828772925297330213069 31163T-612 39 50100150200250300350400450500549599 64969974979984889894899810481097114711971247129613461396144614961546159616451695174417941844189319431992204220912141219022402289 2339 2388 2438248825382588263826823T-613 39501001502002503003504004505005495996496997497988488989489981047109711471197124712961346139614461496154615961645169517441794184318931942199220412091214021902239228923382388243724872536258626352685 2735 2784 2833 3T-613 wp12 3950100150200250300350400449 499 548 597 645 694 742 789 837 883 930 976 1021 1065 3T-616 3950100150200250300350400449 499 548 597 645 694 742 789 837 883 930 976 1021 1065 3950100150200250300350400449 499 548 597 645 694 742 789 837 883 930 976 1021 1065 3950100150200250300350400450499549598648697746 3T-609 wp06 3950100150200250300350400450500549599648698748797847896945995 3T-610 wp05 501001502002503003504004505005495996486987477968458949439921041109011391188123712851334138214311479 3T-611 wp10 3950100150200250300350400450499549598 647 696 744 792 839 885 931 976 1020 1063 3T-614 wp06 3950100150200250300350400450500550600649699749 799849899949999104910991149119912491299134913991449150015501600165017001750180118511902195220032054210421552206225723082359 2411 2462 2513 2565 2617 2668 2716 3T-615 wp06 3950100150200250300350400450500550600650700750800850900950100110511101115112011251130113511400145015001550160016501700175118011851190119512002205221022153 22032254230423552405245625072557260826592709275828082857290629553003 3T-618 wp06 3950100150200250300350400451501551601652702753803853904954100410551105115512061256130613571407145715081558 16081658 170917601811186219131964201520662117216822192270232123722423247425252576262726782728277728272877 2926 2976 3025 3074 3122 3T-619 wp07.1 3950100150200250300351401451501552602652703753804854905955 3T-620 wp05 v5 SURVEY PROGRAM Date: 2019-07-03T00:00:00 Validated: Yes Version: From To Tool 39.00 800.00 r.5 SDI_KPR_ADK+SAG 800.00 2680.00 MWD+IFR2+SAG+MS 2680.00 7250.00 MWD+IFR2+SAG+MS 7250.00 23185.54 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 2460.00 2685.07 10-3/4" Surface Casing 5022.33 7260.00 7-5/8" Intermediate Casing5051.00 23185.54 4-1/2" Production Liner SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.003 500.00 2.00 318.00 499.96 2.59 -2.34 1.00 318.00 3.27 Start Build 2.004 1517.12 22.34 318.00 1489.00 161.12 -145.07 2.00 0.00 203.23 Start 108.12 hold at 1517.12 MD5 1625.23 22.34 318.00 1589.00 191.66 -172.57 0.00 0.00 241.76 Start DLS 2.25 TFO -10.006 2650.99 45.24 312.50 2436.00 587.95 -577.02 2.25 -10.00 759.17 Start 20.00 hold at 2650.99 MD7 2670.99 45.24 312.50 2450.08 597.54 -587.49 0.00 0.00 771.94 Start 2135.00 hold at 2670.99 MD8 4805.99 45.24 312.50 3953.43 1621.69 -1705.20 0.00 0.00 2135.82 Start DLS 2.00 TFO 6.81 9 6049.82 69.99 315.54 4614.60 2348.56 -2451.85 2.00 6.81 3086.63 Start 958.78 hold at 6049.82 MD 10 7008.59 69.99 315.54 4942.72 2991.55 -3082.84 0.00 0.00 3916.86 Start DLS 3.00 TFO 66.57 11 7893.39 82.00 340.00 5159.58 3712.86 -3531.89 3.00 66.57 4752.87 Start Build 3.00 12 8093.39 88.00 340.00 5177.00 3900.00 -3600.00 3.00 0.00 4951.94 Start DLS 2.00 TFO 58.29 13 8406.49 91.30 345.33 5178.93 4198.71 -3693.25 2.00 58.29 5263.99 Start 2426.41 hold at 8406.49 MD 1410832.90 91.30 345.33 5124.07 6545.38 -4307.77 0.00 0.00 7672.00 Start DLS 1.50 TFO 156.08 1510927.38 90.00 345.90 5123.00 6636.88 -4331.25 1.50 156.08 7765.72 3T Eberly T02 030325 Start DLS 1.50 TFO -179.53 1610961.71 89.48 345.90 5123.15 6670.19 -4339.61 1.50 -179.53 7799.76 Start 1291.56 hold at 10961.71 MD 1712253.27 89.48 345.90 5134.76 7922.76 -4654.34 0.00 0.00 9080.18 Start DLS 1.00 TFO -10.54 1812305.66 90.00 345.80 5135.00 7973.56 -4667.14 1.00 -10.54 9132.13 3T Eberly T03 030325 Start DLS 1.00 TFO 2.94 19 12451.35 91.46 345.87 5133.15 8114.81 -4702.79 1.00 2.94 9276.57 Start 1013.31 hold at 12451.35 MD 2013464.66 91.46 345.87 5107.42 9097.16 -4950.00 0.00 0.0010280.91 Start DLS 1.00 TFO -179.92 21 13540.16 90.70 345.87 5106.00 9170.36 -4968.42 1.00 -179.9210355.75 3T Eberly T04 030325 Start DLS 1.00 TFO -179.93 2213608.21 90.02 345.87 5105.57 9236.35 -4985.03 1.00 -179.9310423.22 Start 4617.22 hold at 13608.21 MD 2318225.44 90.02 345.87 5104.00 13713.93 -6112.00 0.00 0.00 15001.05 Start DLS 1.00 TFO -172.33 2418227.41 90.00 345.87 5104.00 13715.84 -6112.48 1.00 -172.3315003.00 3T Eberly T05 030325 Start DLS 1.00 TFO -177.22 2518300.84 89.27 345.83 5104.47 13787.04 -6130.43 1.00 -177.2215075.81 Start 864.03 hold at 18300.84 MD 2619164.87 89.27 345.83 5115.53 14624.73 -6341.86 0.00 0.00 15932.47 Start DLS 1.00 TFO 1.22 2719238.23 90.00 345.85 5116.00 14695.86 -6359.80 1.00 1.2216005.21 3T Eberly T06 030325 Start DLS 1.00 TFO 6.57 28 19290.94 90.52 345.91 5115.76 14746.98 -6372.66 1.00 6.57 16057.47 Start 283.56 hold at 19290.94 MD 2919574.50 90.52 345.91 5113.17 15022.00 -6441.69 0.00 0.00 16338.58 Start DLS 1.50 TFO -0.79 3019672.94 92.00 345.89 5111.00 15117.44 -6465.66 1.50 -0.7916436.14 3T Eberly T07 030325 Start DLS 1.50 TFO -0.31 31 19765.88 93.39 345.88 5106.63 15207.48 -6488.30 1.50 -0.3116528.19 Start 758.82 hold at 19765.88 MD 3220524.71 93.39 345.88 5061.70 15942.10 -6673.06 0.00 0.00 17279.20 Start DLS 1.50 TFO -179.62 33 20750.99 90.00 345.86 5055.00 16161.41 -6728.27 1.50 -179.6217503.42 3T Eberly T08 030325 Start DLS 1.50 TFO -172.26 34 20824.56 88.91 345.71 5055.70 16232.72 -6746.33 1.50 -172.2617576.38 Start 516.29 hold at 20824.56 MD 35 21340.85 88.91 345.71 5065.56 16732.95 -6873.73 0.00 0.00 18088.36 Start DLS 2.00 TFO 129.83 36 21450.70 87.50 347.40 5069.00 16839.73 -6899.26 2.00 129.8318197.03 3T Eberly T09 030325 Start DLS 2.00 TFO 97.08 37 21470.35 87.45 347.79 5069.87 16858.90 -6903.48 2.00 97.0818216.41 Start 125.81 hold at 21470.35 MD 38 21596.17 87.45 347.79 5075.46 16981.75 -6930.06 0.00 0.0018340.41 Start DLS 2.00 TFO -37.34 39 21743.80 89.80 346.00 5079.00 17125.48 -6963.52 2.00 -37.3418486.36 3T Eberly T10 040225 Start DLS 2.00 TFO -86.99 40 21836.48 89.90 344.15 5079.24 17215.03 -6987.39 2.00 -86.9918578.41 Start 196.06 hold at 21836.48 MD 41 22032.54 89.90 344.15 5079.60 17403.63 -7040.94 0.00 0.00 18773.47 Start DLS 2.00 TFO 43.62 4222108.71 91.00 345.20 5079.00 17477.09 -7061.07 2.00 43.6218849.18 3T Eberly T11 040225 Start DLS 2.00 TFO 39.02 4322188.31 92.24 346.20 5076.75 17554.19 -7080.72 2.00 39.02 18928.09 Start 504.84 hold at 22188.31 MD 44 22693.15 92.24 346.20 5057.05 18044.09 -7201.03 0.00 0.00 19427.86 Start DLS 1.50 TFO -119.71 45 22785.46 91.55 345.00 5054.00 18133.45 -7223.97 1.50 -119.7119519.38 3T Eberly T12 040225 Start DLS 1.50 TFO -126.54 46 22941.17 90.16 343.12 5051.68 18283.15 -7266.72 1.50 -126.54 19674.30 Start 244.37 hold at 22941.17 MD 47 23185.54 90.16 343.12 5051.00 18516.99 -7337.66 0.00 0.00 19917.84 3T Eberly T13 040225 TD at 23185.54 3T-617 wp10AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.00 800.00 r.5 SDI_KPR_ADK+SAG800.00 2680.00 MWD+IFR2+SAG+MS2680.00 7250.00 MWD+IFR2+SAG+MS7250.00 23185.54 MWD+IFR2+SAG+MSCASING DETAILSTVD MD Name2460.00 2685.07 10-3/4" Surface Casing5022.33 7260.00 7-5/8" Intermediate Casing5051.00 23185.54 4-1/2" Production Liner1010202030304040505060600901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [20 usft/in]39501001502002503003504004494995485976456947423T-61639501001502002503003504004494995485976456947423950100150200250300350400449499548597645694742501001502002503003504004504995495986476967447923T-614 wp0650100150200250300350400450500550600649699749799849899949999104910991149119912491299134913991449150015501600165017001750180118511902195220032054210421553T-615 wp06501001502002503003504004505005506006507007508008509009501001105111011151120112511301135114001450150015501600165017001751180118513T-618 wp0639 500500 800800 11001100 15001500 20002000 30003000 50005000 80008000 1200012000 1800018000 23186From Colour To MD39.00 To 2700.00MD Azi TFace39.00 0.00 0.00300.00 0.00 0.00500.00 318.00 318.001517.12 318.00 0.001625.23 318.00 0.002650.99 312.50 -10.002670.99 312.50 0.004805.99 312.50 0.006049.82 315.54 6.817008.59 315.54 0.007893.39 340.00 66.578093.39 340.00 0.008406.49 345.33 58.2910832.90 345.33 0.0010927.38 345.90 156.0810961.71 345.90 -179.5312253.27 345.90 0.0012305.66 345.80 -10.5412451.35 345.87 2.9413464.66 345.87 0.0013540.16 345.87 -179.9213608.21 345.87 -179.9318225.44 345.87 0.0018227.41 345.87 -172.3318300.84 345.83 -177.2219164.87 345.83 0.0019238.23 345.85 1.2219290.94 345.91 6.5719574.50 345.91 0.0019672.94 345.89 -0.7919765.88 345.88 -0.3120524.71 345.88 0.0020750.99 345.86 -179.6220824.56 345.71 -172.2621340.85 345.71 0.0021450.70 347.40 129.8321470.35 347.79 97.0821596.17 347.79 0.0021743.80 346.00 -37.3421836.48 344.15 -86.9922032.54 344.15 0.0022108.71 345.20 43.6222188.31 346.20 39.0222693.15 346.20 0.0022785.46 345.00 -119.7122941.17 343.12 -126.5423185.54 343.12 0.00 3T-617 wp10AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.00 800.00 r.5 SDI_KPR_ADK+SAG800.00 2680.00 MWD+IFR2+SAG+MS2680.00 7250.00 MWD+IFR2+SAG+MS7250.00 23185.54 MWD+IFR2+SAG+MSCASING DETAILSTVD MD Name2460.00 2685.07 10-3/4" Surface Casing5022.33 7260.00 7-5/8" Intermediate Casing5051.00 23185.54 4-1/2" Production Liner3030606090901201201501501801800901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]263226812730277928282877292529733021306931163164321032573T-612263826823T-6132635268527352784283328832931298030283T-613 wp12261726682716276428123T-615 wp062608265927092758280828572906295530033052310031473T-618 wp06262726782728277728272877292629763025307431223171321832663T-619 wp07.139 500500 800800 11001100 15001500 20002000 30003000 50005000 80008000 1200012000 1800018000 23186From Colour To MD2600.00 To 7300.00MD Azi TFace39.00 0.00 0.00300.00 0.00 0.00500.00 318.00 318.001517.12 318.00 0.001625.23 318.00 0.002650.99 312.50 -10.002670.99 312.50 0.004805.99 312.50 0.006049.82 315.54 6.817008.59 315.54 0.007893.39 340.00 66.578093.39 340.00 0.008406.49 345.33 58.2910832.90 345.33 0.0010927.38 345.90 156.0810961.71 345.90 -179.5312253.27 345.90 0.0012305.66 345.80 -10.5412451.35 345.87 2.9413464.66 345.87 0.0013540.16 345.87 -179.9213608.21 345.87 -179.9318225.44 345.87 0.0018227.41 345.87 -172.3318300.84 345.83 -177.2219164.87 345.83 0.0019238.23 345.85 1.2219290.94 345.91 6.5719574.50 345.91 0.0019672.94 345.89 -0.7919765.88 345.88 -0.3120524.71 345.88 0.0020750.99 345.86 -179.6220824.56 345.71 -172.2621340.85 345.71 0.0021450.70 347.40 129.8321470.35 347.79 97.0821596.17 347.79 0.0021743.80 346.00 -37.3421836.48 344.15 -86.9922032.54 344.15 0.0022108.71 345.20 43.6222188.31 346.20 39.0222693.15 346.20 0.0022785.46 345.00 -119.7122941.17 343.12 -126.5423185.54 343.12 0.00 3T-617 wp10AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.00 800.00 r.5 SDI_KPR_ADK+SAG800.00 2680.00 MWD+IFR2+SAG+MS2680.00 7250.00 MWD+IFR2+SAG+MS7250.00 23185.54 MWD+IFR2+SAG+MSCASING DETAILSTVD MD Name2460.00 2685.07 10-3/4" Surface Casing5022.33 7260.00 7-5/8" Intermediate Casing5051.00 23185.54 4-1/2" Production Liner3030606090901201201501501801800901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]91049149919492409286933193779423946995149560960596509695974097869830Nuna 139 500500 800800 11001100 15001500 20002000 30003000 50005000 80008000 1200012000 1800018000 23186From Colour To MD7200.00 To 23186.00MD Azi TFace39.00 0.00 0.00300.00 0.00 0.00500.00 318.00 318.001517.12 318.00 0.001625.23 318.00 0.002650.99 312.50 -10.002670.99 312.50 0.004805.99 312.50 0.006049.82 315.54 6.817008.59 315.54 0.007893.39 340.00 66.578093.39 340.00 0.008406.49 345.33 58.2910832.90 345.33 0.0010927.38 345.90 156.0810961.71 345.90 -179.5312253.27 345.90 0.0012305.66 345.80 -10.5412451.35 345.87 2.9413464.66 345.87 0.0013540.16 345.87 -179.9213608.21 345.87 -179.9318225.44 345.87 0.0018227.41 345.87 -172.3318300.84 345.83 -177.2219164.87 345.83 0.0019238.23 345.85 1.2219290.94 345.91 6.5719574.50 345.91 0.0019672.94 345.89 -0.7919765.88 345.88 -0.3120524.71 345.88 0.0020750.99 345.86 -179.6220824.56 345.71 -172.2621340.85 345.71 0.0021450.70 347.40 129.8321470.35 347.79 97.0821596.17 347.79 0.0021743.80 346.00 -37.3421836.48 344.15 -86.9922032.54 344.15 0.0022108.71 345.20 43.6222188.31 346.20 39.0222693.15 346.20 0.0022785.46 345.00 -119.7122941.17 343.12 -126.5423185.54 343.12 0.00 3T-617 wp10Spider Plot10:02, May 08 202539.00 To 23185.54Northing (5000 usft/in)Easting (5000 usft/in)35404550NDST-0235404550NDST-02PB135404550Nuna 135404550Nuna 1PB1354045503S-612354045503S-61535403T-730354045503T-603354045503T-605 wp12.1354045503T-608354045503T-6123T-613354045503T-613 wp12354045503T-616354045503T-616PB1354045503T-616PB23540455 0553T-62135403T-73035403T-7313 5 4 0 4 5503T-601 wp05 v53 5 4 0 4 5503T-602 wp05 v5354045503T-604 wp05 v5354045503T-606 wp08354045503T-607 wp05354045503T-609 wp06354045503T-610 wp05354045503T-611 wp1035404 5 503T-614 wp06354 0 45503T-615 wp06354 0 45503T-618 wp06354045503T-619 wp07.135404 5 503T-620 wp05 v5354045503T-622 wp0835404 5 503T-623 wp05 v5354045503T-624 wp05 v5354045503T-625 wp0735404 5 503T-626 wp05 v5354045503T-627 wp05 v53 5 4 0 4 5 503T-628 wp06354045503T-629 wp05 v5354045503T-617 wp10 3T-617 wp10Spider Plot10:03, May 08 202539.00 To 23185.54Northing (900 usft/in)Easting (900 usft/in)35NDST-0235NDST-02PB135404550Nuna 135404550Nuna 1PB13S-6123S-61535403T-730353T-60335403T-605 wp12.135403T-608354045503T-6123T-613353T-613 wp123T-6163T-616PB13T-616PB23540455 0553T-62135403T-73035403T-7313T-601 wp05 v53T-602 wp05 v5353T-604 wp05 v535403T-606 wp0835403T-607 wp0535403T-609 wp0635403T-610 wp05354045503T-611 wp103T-614 wp063T-615 wp063T-618 wp0635403T-619 wp07.1353T-620 wp05 v535403T-622 wp08353T-623 wp05 v5353T-624 wp05 v535403T-625 wp073T-626 wp05 v53T-627 wp05 v53 53T-628 wp06353T-629 wp05 v5354045503T-617 wp10 3T-617 wp10Spider Plot10:04, May 08 202539.00 To 23185.54Northing (300 usft/in)Easting (300 usft/in)1520NDST-021520NDST-02PB115202530Nuna 115202530Nuna 1PB13S-61215202 5 30353T-7301520253T-603152025303T-605 wp12.152025303T-608152025303T-61215203T-6131520253T-613 wp12153T-616153T-616PB1153T-616PB21520253T-62115202 5 30353T-73015202 530 353T-731152 03T-601 wp05 v51 5 2 03T-602 wp05 v51520253T-604 wp05 v51520253T-606 wp081520253T-607 wp05152025303T-609 wp06152025303T-610 wp05152025303T-611 wp10153T-614 wp061520253T-615 wp061520253T-618 wp06152025303T-619 wp07.11520253T-620 wp05 v5152025303T-622 wp081520253T-623 wp05 v51520253T-624 wp05 v51520253T-625 wp071520253T-626 wp05 v53T-627 wp05 v51520253T-628 wp061520253T-629 wp05 v515202530353T-617 wp10 3T-617 wp10Spider Plot10:05, May 08 202539.00 To 23185.54Northing (65 usft/in)Easting (65 usft/in)101214NDST-02101214NDST-02PB110123T-73024681012143T-6082468 10121416183T-61224681012143T-61324681012143T-613 wp12246810123T-616246810122468101224 68101214163T-62110123T-730123234363T-7312463T-606 wp08246810123T-607 wp0524681012143T-609 wp06246810123T-610 wp052468101214163T-611 wp1024681012143T-614 wp062468101214163T-615 wp06246810121416183T-618 wp06246810121416183T-619 wp07.12468101214163T-620 wp05 v52468101214163T-622 wp0824681012143T-623 wp05 v524681012143T-624 wp05 v524681012143T-625 wp07246810123T-626 wp05 v5243T-627 wp05 v5123T-628 wp062468101214163T-617 wp10 3T-617 wp10NDST-02NDST-02PB1Nuna 1Nuna 1PB13S-6123S-6153T-6033T-6083T-6123T-613 wp123T-6163T-616PB13T-616PB23T-6213T-607 wp053T-609 wp063T-610 wp053T-611 wp103T-614 wp063T-619 wp07.13T-622 wp083T-624 wp05 v53T-625 wp073T-627 wp05 v53T-628 wp063T-629 wp05 v53-D View3T-617 wp109:15, May 08 2025 3T-617 wp10NDST-02NDST-02PB1Nuna 1Nuna 1PB13S-6123S-6153T-6033T-6083T-6123T-613 wp123T-6163T-616PB13T-6213T-602 wp05 v53T-607 wp053T-609 wp063T-610 wp053T-611 wp103T-614 wp063T-619 wp07.13T-622 wp083T-624 wp05 v53T-625 wp073T-628 wp063T-629 wp05 v53-D View3T-617 wp109:16, May 08 2025 3T-617 wp10NDST-02NDNuna 1Nuna 1PB13S-6123S-6153T-6033T-605 wp12.13T-6083T-6123T-613 wp123T-6163T-616PB13T-6213T-601 wp05 v53T-602 wp05 v53T-606 wp083T-607 wp053T-609 wp063T-610 wp053T-611 wp103T-614 wp063T-619 wp07.13T-622 wp083T-624 wp05 v53T-625 wp073T-628 wp063T-629 wp05 v53-D View3T-617 wp109:16, May 08 2025 35007000105001400017500South(-)/North(+) (3500 usft/in)-17500 -14000 -10500 -7000 -3500 0 3500 7000 10500West(-)/East(+) (3500 usft/in)40604080410041204140NDST-0240604080410041204140NDST-02PB140604080410041204140Nuna 140604080410041204140Nuna 1PB13S-6123S-615406040804100412041403T-603406040804100412041403T-605 wp12.1406040804100412041403T-608406040804100412041403T-612406040804100412041403T-613 wp123T-6163T-616PB1406040804100412041403 T -6 2 1 4 0 6 04080410041204140 3T-601 wp05 v54 0 6 040804100412041403T-602 wp05 v5406040804100412041403T-604 wp05 v5406040804100412041403T-606 wp08406040804100412041403T-607 wp05406040804100412041403T-609 wp06406040804100412041403T-610 wp05406040804100412041403T-611 wp103T-614 wp06406040804100412041403T-615 wp064 0 6 04080410041204140 3T-618 wp06406040804100412041403T-619 wp07.1406040804100412041403T-620 wp05 v5406040804100412041403T-622 wp08406040804100412041403T-623 wp05 v540804100412041403T-624 wp05 v5406040804100412041403T-625 wp07406040804100412041403T-626 wp05 v53T-627 wp05 v53T-628 wp063T-629 wp05 v5406040804100412041403T-617 wp103T-617 wp10Quarter Mile View9:18, May 08 2025WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T Eberly T02 030325 5123.00 Circle (Radius: 100.00)3T Eberly T03 030325 5135.00 Circle (Radius: 100.00)3T Eberly T04 030325 5106.00 Circle (Radius: 100.00)3T Eberly T05 030325 5104.00 Circle (Radius: 100.00)3T Eberly T06 030325 5116.00 Circle (Radius: 100.00)3T Eberly T07 030325 5111.00 Circle (Radius: 100.00)3T Eberly T08 030325 5055.00 Circle (Radius: 100.00)3T Eberly T09 030325 5069.00 Circle (Radius: 100.00)3T Eberly T10 040225 5079.00 Circle (Radius: 100.00)3T Eberly T11 040225 5079.00 Circle (Radius: 100.00)3T Eberly T12 040225 5054.00 Circle (Radius: 100.00)3T Eberly T13 040225 5051.00 Circle (Radius: 100.00)3T Eberly T01 030325 5177.00 Circle (Radius: 100.00)3T Eberly T01 QM 5177.00 Circle (Radius: 1350.00)3T Eberly T04 QM 5106.00 Circle (Radius: 1350.00)3T Eberly T05 QM 5104.00 Circle (Radius: 1320.00)3T Eberly T13 QM 5051.00 Circle (Radius: 1350.00) 35007000105001400017500South(-)/North(+) (3500 usft/in)-17500 -14000 -10500 -7000 -3500 0 3500 7000 10500West(-)/East(+) (3500 usft/in)50505100Nuna 150505100Nuna 1PB13S-612505051003T-6127-5/8" Intermediate Casing4-1/2" Production Liner505051003T-617 wp103T-617 wp10Quarter Mile View9:24, May 08 2025WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T Eberly T02 030325 5123.00 Circle (Radius: 100.00)3T Eberly T03 030325 5135.00 Circle (Radius: 100.00)3T Eberly T04 030325 5106.00 Circle (Radius: 100.00)3T Eberly T05 030325 5104.00 Circle (Radius: 100.00)3T Eberly T06 030325 5116.00 Circle (Radius: 100.00)3T Eberly T07 030325 5111.00 Circle (Radius: 100.00)3T Eberly T08 030325 5055.00 Circle (Radius: 100.00)3T Eberly T09 030325 5069.00 Circle (Radius: 100.00)3T Eberly T10 040225 5079.00 Circle (Radius: 100.00)3T Eberly T11 040225 5079.00 Circle (Radius: 100.00)3T Eberly T12 040225 5054.00 Circle (Radius: 100.00)3T Eberly T13 040225 5051.00 Circle (Radius: 100.00)3T Eberly T01 030325 5177.00 Circle (Radius: 100.00)3T Eberly T01 QM 5177.00 Circle (Radius: 1350.00)3T Eberly T04 QM 5106.00 Circle (Radius: 1350.00)3T Eberly T05 QM 5104.00 Circle (Radius: 1320.00)3T Eberly T13 QM 5051.00 Circle (Radius: 1350.00) 02004006008001000South(-)/North(+) (200 usft/in)-1200 -1000 -800 -600 -400 -200 0 200West(-)/East(+) (200 usft/in)3T-6033T-605 wp12.124603T-60824603T-6123T-61324603T-613 wp123T-6163T-616PB13T-616PB224603 T -6 2 1 2 46 0 3T-7302 4 6 0 3T-7313T-601 wp05 v53T-602 wp05 v53T-604 wp05 v53T-606 wp0824603T-607 wp0524603T-609 wp0624603T-610 wp0524603T-611 wp103T-614 wp0624603T-615 wp0624603T-618 wp0624603T-619 wp07.124603T-620 wp05 v524603T-622 wp0824603T-623 wp05 v524603T-624 wp05 v524603T-625 wp073T-626 wp05 v510-3/4" Surface Casing24603T-617 wp103T-617 wp10Quarter Mile View9:38, May 08 2025WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T Eberly T02 030325 5123.00 Circle (Radius: 100.00)3T Eberly T03 030325 5135.00 Circle (Radius: 100.00)3T Eberly T04 030325 5106.00 Circle (Radius: 100.00)3T Eberly T05 030325 5104.00 Circle (Radius: 100.00)3T Eberly T06 030325 5116.00 Circle (Radius: 100.00)3T Eberly T07 030325 5111.00 Circle (Radius: 100.00)3T Eberly T08 030325 5055.00 Circle (Radius: 100.00)3T Eberly T09 030325 5069.00 Circle (Radius: 100.00)3T Eberly T10 040225 5079.00 Circle (Radius: 100.00)3T Eberly T11 040225 5079.00 Circle (Radius: 100.00)3T Eberly T12 040225 5054.00 Circle (Radius: 100.00)3T Eberly T13 040225 5051.00 Circle (Radius: 100.00)3T Eberly T01 030325 5177.00 Circle (Radius: 100.00)3T-617 Srf Csg 2460.25 Circle (Radius: 500.00) 02004006008001000South(-)/North(+) (200 usft/in)-1200 -1000 -800 -600 -400 -200 0 200West(-)/East(+) (200 usft/in)24603T-6122 46 0 3T-7302 4 6 0 3T-73110-3/4" Surface Casing24603T-617 wp103T-617 wp10Quarter Mile View9:39, May 08 2025WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T Eberly T02 030325 5123.00 Circle (Radius: 100.00)3T Eberly T03 030325 5135.00 Circle (Radius: 100.00)3T Eberly T04 030325 5106.00 Circle (Radius: 100.00)3T Eberly T05 030325 5104.00 Circle (Radius: 100.00)3T Eberly T06 030325 5116.00 Circle (Radius: 100.00)3T Eberly T07 030325 5111.00 Circle (Radius: 100.00)3T Eberly T08 030325 5055.00 Circle (Radius: 100.00)3T Eberly T09 030325 5069.00 Circle (Radius: 100.00)3T Eberly T10 040225 5079.00 Circle (Radius: 100.00)3T Eberly T11 040225 5079.00 Circle (Radius: 100.00)3T Eberly T12 040225 5054.00 Circle (Radius: 100.00)3T Eberly T13 040225 5051.00 Circle (Radius: 100.00)3T Eberly T01 030325 5177.00 Circle (Radius: 100.00)3T-617 Srf Csg 2460.25 Circle (Radius: 500.00) 3T-617 wp10 Surface Location 3T-617 wp10 Surface Location # Schlumberger-Confidential 3T-617 wp10 Surface Casing 3T-617 wp10 Surface Casing # Schlumberger-Confidential 3T-617 wp10 Top Moraine 3T-617 wp10 Top Moraine # Schlumberger-Confidential 3T-617 wp10 Intermediate Csg 3T-617 wp10 Intermediate Csg # Schlumberger-Confidential 3T-617 wp10 TD 3T-617 wp10 TD # Schlumberger-Confidential Certificate Of Completion Envelope Id: 0C5BA808-A2B8-4B97-853A-F237B66C9044 Status: Completed Subject: Complete with Docusign: PTD_Application_3T-617.pdf Source Envelope: Document Pages: 70 Signatures: 1 Envelope Originator: Certificate Pages: 4 Initials: 0 Brian Broussard AutoNav: Enabled EnvelopeId Stamping: Disabled Time Zone: (UTC-06:00) Central Time (US & Canada) 925 N Eldridge Pkwy Houston, TX 77079 Brian.T.Broussard@conocophillips.com IP Address: 138.32.8.5 Record Tracking Status: Original 6/9/2025 6:00:17 PM Holder: Brian Broussard Brian.T.Broussard@conocophillips.com Location: DocuSign Signer Events Signature Timestamp Chris Brillon chris.l.brillon@conocophillips.com Wells Engineering Manager Security Level: Email, Account Authentication (None)Signature Adoption: Pre-selected Style Using IP Address: 107.77.205.143 Signed using mobile Sent: 6/9/2025 6:01:38 PM Viewed: 6/9/2025 6:46:16 PM Signed: 6/9/2025 6:46:42 PM Electronic Record and Signature Disclosure: Accepted: 6/9/2025 6:46:16 PM ID: ffa3f4b7-fbc1-4665-b28d-c3ed2ecb29bc In Person Signer Events Signature Timestamp Editor Delivery Events Status Timestamp Agent Delivery Events Status Timestamp Intermediary Delivery Events Status Timestamp Certified Delivery Events Status Timestamp Carbon Copy Events Status Timestamp Witness Events Signature Timestamp Notary Events Signature Timestamp Envelope Summary Events Status Timestamps Envelope Sent Hashed/Encrypted 6/9/2025 6:01:38 PM Certified Delivered Security Checked 6/9/2025 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From:Broussard, Brian T To:Davies, Stephen F (OGC) Cc:Loepp, Victoria T (OGC); Dewhurst, Andrew D (OGC); Smith, Matt; Hobbs, Greg S Subject:RE: [EXTERNAL]KRU 3T-617 (PTD 225-053) - Question Date:Friday, June 27, 2025 10:38:47 PM Attachments:image001.pngimage003.pngimage004.png Hi Stephen, Please find explanations for the gas and losses on the 3T-612 below. To summarize, I believe that the evidence provided shows that these incidents were one-offs not related to shallow gas, and I would still like to move forward with our request for the diverter waiver. I believe Matt Smith (cc’d) and Andy have discussed the 3T-612 surface gas previously for the 3T-731 PTD (see screenshot below). We believe that the high baseline gas was due to an improperly calibrated gas sensor. We have since requested additional focus that the gas sensor has been calibrated before spud. The readings have been very consistent since. As for the losses on the 3T-612, we lost 64 bbl while drilling at 835’. We pumped a 25 bbl 30 ppb pill of LCM and the losses were immediately healed, and we saw no further losses while drilling. I believe this was a very minor loss event that was easily handled by the rig. We lost an additional 125 bbl while running surface casing. This was our second well with Baroid as our mud provider, and the mud engineers were having difficulty maintaining our required mud spec parameters in the surface hole on this well. The specs for the surface job can be found below. The gold line shows the 3T-612. The rheology, most importantly the Funnel Viscosity, can be seen to have been significantly lower than the previous two wells. This resulted in the mud being thinner than usual, and we saw severe washout with large gravel in our returns and difficulty running casing. We pumped 240 bbl of excess cement, but we only saw trace spacer at surface at the end of the cement job. We then pumped a top job and tagged cement with the job string at 84’ before circulating cement around. I believe that this poor mud was the main driver of these losses in the surface hole. Thanks, Brian Broussard Drilling Engineer – Kuparuk 700 G Street, Anchorage, AK 99501 Cell: 337.967.0516 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Friday, June 27, 2025 10:29 AM To: Broussard, Brian T <Brian.T.Broussard@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]KRU 3T-617 (PTD 225-053) - Question CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Brian, I'm reviewing Hilcorp's Permit to Drill Application for KRU 3T-617 and I have a question regarding CPAI’s requested diverter waiver. I’ve reviewed the daily drilling reports for the five existing nearby wells that have surface casing shoes within about 800’ of 3T-617. The drilling reports for four of those five wells did not report or mention shallow gas while drilling the surface hole interval. However, the records for KRU 3T-612, which has the nearest surface casing shoe to that proposed for well 3T-617 (separation will be about 190’), report a maximum observed gas measurement of 168 units while drilling the section of hole across the base of permafrost. Can CPAI please provide more detail about the gas measurements from the surface hole in 3T-612 (measurement values, associated depths, interpreted source(s), etc.), and why the surface interval in 3T-617 should not be drilled using a diverter? Note also that there were reports of significant losses while drilling the surface hole in 3T-612. Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov 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 no greater 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. 225-053 KRU 3T-617 TOROK OIL KUPARUK RIVER WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 3T-617Initial Class/TypeDEV / PENDGeoArea890Unit11160On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2250530Field & Pool:KUPARUK RIVER, TOROK OIL - 490169NA1 Permit fee attachedYes Surface Location lies within ADL0025528; Top Productive Interval lies in ADL0392959;2 Lease number appropriateYes TD lies within ADL0393884.3 Unique well name and numberYes KUPARUK RIVER, TOROK OIL - 490169 - governed by CO 725A4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes 80' conductor18 Conductor string providedYes SC set at 2685' MD19 Surface casing protects all known USDWsYes 146% excess20 CMT vol adequate to circulate on conductor & surf csgNo21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedYes27 If diverter required, does it meet regulationsYes Max reservoir pressure is 2316 psig(8.6 ppg EMW); will drill w/ 9.0-10.0 ppg EMW28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP is 1798 psig; will test BOPs to 4000 psig30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)No H2S is present in significant quantities in 3S-Pad wells to south; see Kuparuk H2S Report.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected pressure range is 0.446 to 0.467 psi/ft (8.6 to 9 ppg EMW). Operator's planned mud program36 Data presented on potential overpressure zonesNA appears sufficient to control anticipated pressures and maintain wellbore stability.37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate6/26/2025ApprVTLDate6/17/2025ApprSFDDate6/26/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 7/1/2025
