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Home My WebLink About2026_01_28_326-0651. 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: Well Clean Up 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD): 26450 N/A Casing Collapse Conductor Surface 2,260 Intermediate 4,750 Tieback 4,750 Intermediate 2 5,410 Production 9,210 Liner 9,210 Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:scott.leahy@santos.com Contact Phone: 907-330-4595 Authorized Title: Completions Specialist 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 2,851 Tieback 2,851 6,870 4,028 25,842 4,117 Length Scott Leahy 16,469 4-1/2" 16,469 4,414 11,590 2/20/2026 4,117 See attached packer report Perforation Depth MD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 11,590 Tubing Grade: Tubing MD (ft): See attached packer report Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 392984, 391445, 393020, 393019, 392991, 392970 225-108 601 W 5th Avenue, Suite 600, Anchorage, AK 99501 50-103-20927-00-00 Oil Search Alaska, LLC Pikka NDBi-034 Size Proposed Pools: P110S TVD Burst 16,469 Pikka Nanushuk Oil Pool N/A MD 6,870 5,020 128 2,379 128 3,014 11,997 3,046 7" 16,669 20"x34" 13-3/8" 128 9-5/8"9,146 3,014 4,013 7,240 2,319 4-1/2" 25,8429,373 4-1/2" 12.6ppf 4,807 ogrogogogam onnnnn nddddddd on e tdowdodoodontdown rillllll nd sssssss l e teeeeeeeete teeeete ell Cla h ntttttttt vicecececece Well Statu S posed wor PLLLLLL RRRR PL eddeed ed grigriggriiiggriigrity stsstssstst t eddddwn RRRRR eananannnan Up ogram NoNNNoNNoNNoNNNNNNNNNNN iccccc arrrryyy oesssssss N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov foregoing is true and the 01/25/2026 326-065 Page 1 of 1 Packer Set Depths - NDBi-034 Wellbore Name Item Des Btm (ftKB) Btm (TVD) (ftKB) Original Hole ZXP Liner Top Hanger Packer W/HRD-E Profile 16,502.7 4,027.3 Original Hole OH Packer #18 SN DF25-128716-26 16,714.9 4,096.6 Original Hole OH Packer #17 SN DF25-128716-25 16,780.4 4,112.0 Original Hole OH Packer #16 SN DF25-128716-23 17,280.3 4,151.9 Original Hole OH Packer #15 SN DF25-128716-2 17,905.6 4,152.8 Original Hole OH Packer #14 SN DF25-128716-5 18,486.8 4,153.6 Original Hole OH Packer #13 SN DF25-128716-20 19,073.2 4,154.3 Original Hole OH Packer #12 SN DF25-128716-12 19,702.1 4,153.7 Original Hole OH Packer #11 SN DF25-128716-10 20,246.4 4,151.1 Original Hole OH Packer #10 SN DF25-128716-16 20,827.1 4,148.1 Original Hole OH Packer #9 SN DF25-128716-6 21,410.8 4,145.0 Original Hole OH Packer #8 SN DF25-128716-18 21,950.2 4,143.1 Original Hole OH Packer #7 SN DF25-128716-9 22,577.7 4,141.0 Original Hole OH Packer #6 SN DF25-128716-30 23,162.3 4,139.1 Original Hole OH Packer #5 SN DF25-128716-15 23,703.7 4,136.0 Original Hole OH Packer #4 SN GC25-44844-10 24,245.4 4,132.0 Original Hole OH Packer #3 SN GC25-44844-8 24,831.0 4,126.1 Original Hole OH Packer #2 SN GC25-44844-7 25,374.1 4,121.9 Original Hole OH Packer #1 SN GC25-44844-9 25,751.9 4,118.2 Page 1 of 20 NDBi-034 Sundry Application Requirements 1. Affidavit of Notice –Attachment A 2. Plot showing well location, as well as ½ mile radius around well with all well penetrations, fractures, and faults within that radius –Attachment B 3. Identification of freshwater aquifers within ½ mile radius – There are no known underground sources of drinking water within a one-half mile radius of the current proposed well bore trajectory for NBDi-034. At the NDBi-034 location, the Permafrost interval extends down to approximately 1000-1400 ft and therefore, no shallow aquifers are located at the NDBi-034 location. Wells within the Pikka unit (see table below) have measured water salinity values >10,000 ppm and are not considered freshwater. 4. Plan for freshwater sampling – There are no known freshwater wells in the proximity to the proposed operations, therefore no water sampling planned. 5. Detailed casing and cementing information –Attachment C 6. Assessment of casing and cementing operations –Attachment C 7. Casing and tubing pressure test information –Attachment D 8. Pressure ratings for wellbore, wellhead, BOPE and treating head –Attachments D and I 9. Lithological and geological descriptions of each zone –Attachment E and below Prince Creek Formation Depth/Thickness: Surface to 968 feet (ft) total vertical depth subsea (TVDSS)/ 968 ft thick Lithological Description: The Prince Creek Formation (Fm) in the Pikka Unit area consists predominantly of massive, unconsolidated sand and gravel sequence with minor clays that were deposited in a non-marine, fluvial setting. Schrader Bluff Formation (Upper, Middle, Lower) Depth/Thickness: 968 to 2,372 ft TVDSS/1,404 ft thick Lithological Description: The Schrader Bluff Fm in the Pikka Unit area was deposited in a shallow marine to shelf setting and dominantly consists of light grey claystone in the Upper Schrader Bluff (including shell fragments, lignite, and cherts), grading to a dark mudstone in the Middle Schrader and grading to a massive blocky shale in the Lower Schrader Bluff. Interbedded volcanic ash was observed and increasing from the Lower Schrader Bluff Fm. There are some thin (<15 ft), poor-quality (high clay content, low permeability) sands present in the Upper Schrader Bluff Fm within the Pikka Unit. Tuluvak Formation Depth/Thickness: 2,372 to 3,294 ft TVDSS/ 922 ft thick Hydrocarbon Zone: 2,716 to 3,294 ft TVDSS Lithological Description: The Tuluvak Fm in the Pikka Unit area consists predominantly of claystone, siltstone, and thinly interbedded sandstones deposited in a prograding, shallow marine setting, grading with depth to the deep marine shales of the Seabee Fm. Sandstones. Upper Confining Zone Name Seabee Formation Depth/Thickness: 3,294 to 3,745 ft TVDSS/ 451 ft thick Lithological Description: The Seabee Fm in the Pikka Unit area consists predominantly of claystone, shale, and volcanic tuff deposited in a deep marine setting. The base of the Seabee Fm grades into a condensed organic shale and provides an excellent seal and confining interval above the Nanushuk Fm reservoirs and also acts as a thick second overlying confining unit. Nanushuk Formation Depth/Thickness: 3,745 to 4,699 ft TVDSS/ 954 ft thick Lithological Description: The Nanushuk Fm is the primary oil production zone for the Pikka Development. This formation is a thick accumulation of fluvial, deltaic, and shallow marine deposits and is the up-dip, shelf topset equivalent of the deeper water, slope-to-basin floor Torok Fm. The Nanushuk-Torok clinoform sets sequentially prograde from west to east. The Nanushuk Fm is often highly laminated and comprised of fine-grained sand, silt, and shale. It can contain lithic-clasts from various sedimentary and metamorphic sources. Distributary channel mouth bar deposits and shoreface sands comprise major sand packages in the Nanushuk Fm. Lower Confining Zone Name: Torok Formation Depth/Thickness: 4,699 to 5,598 ft TVDSS/899 ft thick Lithological Description: The Lower Torok sands are overlain by the Upper Torok Fm, which is up to 1,200 feet thick in the Pikka Unit. The Upper Torok is composed primarily of shale (Hue Shale) with some thin interbedded siltstones. Within the Upper Torok Fm, several condensed, impermeable shale layers called maximum flooding surfaces (MFS) are present. These are regionally extensive and provide excellent confining intervals. 10.Estimated fracture pressure for each zone listed below: Held IA Pressure (psi) IA PRV (psi) GORV (psi) Pump Trip Pressure (psi) Surface Line Pressure Test (psi) MAWP (psi) Stages 1-16 3,800 4,100 8,500 8,100 9,200 8,800 Note: GORV and pump trips to be set to 8700 psi to open Toe Sleeve Fracture gradient values for each stage are listed in detail within Attachment K. In general, the fracture gradient values for the confining zones and pay zone are listed below: Upper confining: Shale gradient – 0.71 psi/ft Fracturing: Sand gradient- 0.61 psi/ft Lower confining: Shale gradient- 0.69 psi/ft Mechanical condition of wells transecting the confining zones –Fiord 2, Fiord 3 Fiord 3A, NDB-027, NDB-037, NDBi-044. Please see Attachment B as reference. Stage MD Perf Depth (ft) TVD Perf Depth (ft) Max Frac Height (ft) Frac ½ Length (ft) Max Rate (bpm) Est. Max Pressure (psi) Max Prop Conc. (PPA) 1 25,601 4,120 234 338 40 7,373 8 2 25,058 4,125 251 413 40 7,285 8 3 24,514 4,129 238 349 40 7,158 8 4 23,969 4,134 235 349 40 7,018 8 5 23,428 4,137 235 333 40 6,970 8 6 22,845 4,140 233 331 40 6,817 8 7 22,260 4,143 228 302 40 6,671 8 8 21,673 4,144 225 296 40 6,539 8 9 21,095 4,147 353 493 40 6,260 8 10 20,513 4,149 231 314 40 6,186 8 11 19,929 4,153 241 506 40 5,972 8 12 19,342 4,154 256 469 40 6,269 10 13 18,755 4,154 240 503 40 6,096 10 14 18,172 4,153 234 487 40 5,981 10 15 17,591 4,152 225 464 40 5,814 10 16 17,008 4,145 235 478 40 5,638 10 11.Suspected fault or fracture that may transect the confining zones: There are no known faults within the ½ mile radius of NDB-040. Please See Attachment B. Note: Fractures are estimated to propagate along wellbore longitudinally at ~330o. 12.Detailed proposed fracturing program –Attachments F & K 13.Well Clean Up procedure –Attachment G Section (b) Casing Pressure Test – We will not be treating through production or intermediate casing strings. Section (c) Fracture String Pressure Test –Attachment H Section (d) Pressure Relieve Valve –Attachment I Proposed Wellbore Schematic –Attachment J Attachment A Oil Search (Alaska), LLC a subsidiary of Santos Limited 601 W 5th Avenue Anchorage, Alaska 99501 (T) +1 907 375 4642 —santos.com 1/2 -DQXDU\WK, 202 Owners, Landowners, Surface Owners and Operators See Distribution List Colville River Area North Slope Basin, Alaska Re: Notice of Operations under 20 AAC 25.283 of Oil Search (Alaska), LLC’s Sundry Application for a Fracture Stimulation for the Proposed NDBL-0Well Dear Owner, Landowner, Surface Owner and/or Operator, Oil Search (Alaska), LLC (OSA) is applying for a Sundry Application under 20 AAC 25.283 to perform a fracture stimulation of the proposed NDBL-0 well. This Notice is being sent by certified mail to meet the notification requirements under 20 AAC 25.283(a)(1)(A) and 20 AAC 25.283(a)(1)(B). The complete application is available for review upon request. If you wish to review the application, please contact Tim Jones, Land Manager, at the following: Tim Jones Land Manager Oil Search (Alaska), LLC 601 W 5th Ave Anchorage, AK 99501 Direct: 907-375-4624 tim.jones3@santos.com OSA, through a search of the public record, has identified you as an Owner, Landowner, Surface Owner or Operator (as defined in AOGCC regulations) within ½ mile of the proposed NDBL-0well trajectory and fracture stimulation. Please contact Tim Jones should you require additional information. Sincerely, Jacob Owens Commercial Analyst Distribution List: Alaska Division of Oil and Gas $UFWLF6ORSH5HJLRQDO&RUS .XXNSLN&RUS 2LO6HDUFK$ODVND//& 5HSVRO( 386$//& &RQRFR3KLOOLSV$ODVND,QF Sincerely, Jacob Owens 2/2 Contact Information: CERTIFIED MAIL CERTIFIED MAIL CERTIFIED MAIL CERTIFIED MAIL CERTIFIED MAIL State of Alaska Department of Natural Resources Alaska Division of Oil and Gas 550 W 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Arctic Slope Regional Corp. Attn: David Knutson 3900 C Street, Suite 801 Anchorage, AK 99503-5963 Kuukpik Corp 582 E. 36th Avenue Anchorage, AK 99503 Oil Search (Alaska), LLC 601 W 5th Ave Anchorage, AK 99501 Repsol E&P USA LLC 2455 Technology Forest Blvd. The Woodlands, TX 77381 &RQRFR3KLOOLSV$ODVND,QF $WWQ/DQG0DQDJHU 32%R[ $QFKRUDJH$. CERTIFIED MAIL ADL 392991 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 41.58% DNR - 58.42% ADL 392984 Surface Owners: Kuukpi OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 50% DNR - 50% ADL 392968 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 50% DNR - 50% ADL 392958 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 36.31% DNR - 63.69% ADL 392992 Surface Owners: State OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 0% DNR - 100% ADL 393021 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 19.22% DNR - 80.78% ADL 393019 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 33.1% DNR - 66.9% ADL 393018 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 29.67% DNR - 70.33% ADL 393020 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 26.59% DNR - 73.41% ADL 393015 Surface Owners: Kuukp OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 31.69% DNR - 68.31% ADL 393016 Surface Owners: Kuukp OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 33.17% DNR - 66.83% ADL 391445 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 41.98% DNR - 58.02% ADL 391455 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 46.4% DNR - 53.6% ADL 393011 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 25.71% DNR - 74.29% ADL 393010 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 38.54% DNR - 61.46% 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81(ADL 392970 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 40.29% DNR - 59.71% 81( &3$, $'/ 6XUIDFH2ZQHUVKLS'15 68%62:1(56 $65& '15 81( 81(81( 81( 9DQWRU OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD TARGET BOTTOM HOLE SURFACE LOCATION WELL TRAJECTORY .5-MILE BUFFER SANTOS LEASES CPAI LEASES SECTIONS KUUKPIK BOUNDARIES DATE: 1/8/2026. By: JB 00.10.2 Miles Project: AP-DRL-GEN_assorted Layout: AP-DRL-PE-M_NDBi34_well_ownership Map Frame: AP-DRL-PE-M_NDBi034_well_ownership GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 00.20.4 Kilometers PIKKA DEVELOPMENT NDBi-034 WELL AREA Attachment B 81(81(81(81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81(81( 81( 81( 81( 81( 81( 81( 81( ADL 392968 ADL 392991 ADL 392984 AD L 3 7 2 1 0 6 ADL 392958 ADL 392992 ADL 392970 ADL 393021 ADL 393019 ADL 393018 ADL 393020 ADL 393015 ADL 393016 ADL 393006 ADL 393007 ADL 391445 ADL 391454 ADL 391455 ADL 393009 ADL 393011 ADL 393010 COLVILLE RIV UNIT CD1-15PB1COLVILLE RIV UNIT CD1-15 COLVILLE RIV UNIT CD1-15PB2 QUGRUK 3A FIORD 2 QUGRUK 7 FIORD 3 QUGRUK 301 FIORD 3A DW-02 NDB-010 NDB-011 NDB-024 NDB-025 NDB-027 NDB-032 NDB-037 NDB-040 NDB-051 NDBi-006 NDBi-014 NDBi-016 NDBi-018 NDBi-030 NDBi-034 NDBi-036 NDBi-043A NDBi-044 NDBi-049 9DQWRU OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD 0.25-MILE BUFFER 0.5-MILE BUFFER NDBI-034 SURFACE LOCATION NDBI-034 BOTTOM HOLE PRODUCTION INTERVAL NDBI-034 OTHER DRILLED NDB WELLS EXPLORATION WELLS BOTTOM HOLES WELL TRAJECTORIES BY OTHERS SANTOS Leases CPAI LEASES SECTIONS FAULT LINE DATE: 1/6/2026. By: JN 00.10.2 Miles Project: AP-DRL-GEN_assorted Layout: AP-DRL-GEN-M_NDBi34_buffers GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 00.20.4 Kilometers PIKKA DEVELOPMENT NDBi-034 WELL WE L L N A M E S T A T U S C a s i n g S i z e To p o f O i l P o o l C o n f i n i n g La y e r ( M D ) To p o f O i l P o o l C o n f i n i n g La y e r ( T V D S S ) To p o f Ce m e n t (M D ) To p o f C e m e n t (T V D S S ) To p o f C e m e n t De t e r m i n e d By Re s e r v o i r S t a t u s Z o n a l I s o l a t i o n Ce m e n t O p e r a t i o n s S u m m a r y Me c h a n i c a l I n t e g r i t y Fi o r d 2 A b a n d o n d e d 9- 5 / 8 " 5 3 . 5 p p f t o 2, 2 3 1 ' M D . 8 - 1 / 2 " op e n h o l e t o T D a t 8, 4 0 0 ' . Op e n H o l e a b a n d o m e n t p l u g s in r e s e r v o i r . C a s e d h o l e pl u g b a c k s e t a b o v e hy d r o c a r b o n b e a r i n g z o n e s . Pl u g 1 s e t w i t h 5 5 b b l s o f C l a s s G c e m e n t a b o v e 1 1 . 2 p p g m u d a n d 20 b b l s H i - V i s a t 8 . 0 4 4 ' M D . T o p o f P l u g 1 t a g g e d w i t h 1 5 K d o w n a t 7 , 4 3 7 ' a n d c o v e r s hy d r o c a r b o n s o w n , K u p a r u k / J 4 , a t 7 , 7 9 4 ' - 7 , 9 9 4 ' . P l u g 2 w a s s e t o n t o p o f 1 1 . 2 p p g m u d w i t h 2 0 b b l s o f H i - v i s p i l l o n t o p a t ~ 3 ,3 0 0 ' . T o p o f c e m e n t p l u g 2 i s es t m a t e d a t 2 , 4 0 0 ' m d a n d c o v e r s a n a b n o r m a l p r e s s u r e z o n e C 3 0 ( 2 , 8 9 0 ' - 3 , 2 0 0 ' ) . C a s i n g s h o e p l u g ( # 3 ) i s s e t b e t w e n a p p r o x i m a t el y 2 , 1 7 5 - 2 , 3 3 1 ' M D . Ce m e n t r e a t a i n e r w a s s e t i n c a s i n g a t 2 , 1 7 5 ' m d w i t h 7 b b l s o f c l a s s G c e m e n t o n t o p t o ~ 2 , 0 7 5 ' . A b r i d g e p l u g w a s s e t a t 3 0 0 ' M D a n d h a d 1 9 b b l s o f a s u r f a c e pl u g s e t o n t o p o f i t ( p l u g # 4 ) . W e l l w a s c a p p e d a n d b a c k f i l l e d . We l l i s f u l l y a b a n d o n e d . 0 3 / 1 9 9 4 Fi o r d 3 A A b a n d o n d e d 9- 5 / 8 " 5 3 . 5 p p f t o 1, 8 0 5 ' M D . 8 - 1 / 2 Op e n h o l e t o T D a t 9, 1 4 8 ' M D Op e n H o l e a b a n d o m e n t p l u g s in r e s e r v o i r . C a s e d h o l e ab a n d o n m e n t p l u g s a b o v e hy d r o c a r b o n b e a r i n g z o n e s . Es t i m a t e o f P l u g 1 f r o m T D t o 8 , 4 3 0 ' M D c o v e r i n g H y d r o c a r b o n B e a r n i n g Z o n e - J - 4 ( 8 , 7 7 0 ' - 8 , 8 1 0 ' ) . E s t i m a t e o f P l u g 2 t o p a t 8 , 0 10 M D c o v e r i n g H y d r o c a r b o n Be a r i n g Z o n e - A l b i a n ( 8 , 1 1 0 ' - 8 , 1 3 0 ' ) . F o r C e m e n t p l u g 3 , A 2 0 B B L H I V i s p i l l w a s p l a c e d a t 2 7 5 0 a n d a c e m e n t p l u g w a s p l a c e d o ve r H y d r o c a r b o n B e a r n i n g Zo n e , K - 5 ( 2 , 4 9 0 ' - 2 , 7 0 0 ' ) . P l u g 3 w a s t a g g e d a t 2 , 3 9 1 ' . C e m e n t p l u g 4 b a s e s e t a t 1 9 0 5 M D w i t h w i t h c e m e n t r e t a i n e r s e t a t 1 , 73 0 ' M D . E s t i m a t e d t o p o f ce m e n t 4 p l u g i s 1 , 6 1 9 ' M D . B r i d g e p l u g s e t a t 3 0 0 ' M D a n d c o v e r e d w i t h s u r f a c e c e m e n t p l u g r o m 3 5 ' - 3 0 0 ' . We l l i s f u l l y a b a n d o n e d . 0 4 / 1 9 9 5 Fi o r d 3 A b a n d o n d e d 9- 5 / 8 " 5 3 . 5 p p f t o 1, 8 0 5 ' M D . 8 - 1 / 2 Op e n h o l e t o T D a t 7, 0 3 0 ' M D / T V D Op e n H o l e a b a n d o m e n t p l u g s in r e s e r v o i r . C a s e d h o l e pl u g b a c k s e t a b o v e hy d r o c a r b o n b e a r i n g z o n e s . Es t i m a t e o f p l u g 1 f r o m T D o f w e l l t o 6 , 0 9 0 ' c o v e r i n g h y d r o c a r b o n b e a r i n g z o n e , J - 4 ( 6 , 7 3 3 ' - 6 , 7 7 0 ' ) a n d h y d r o c a r b o n b e a r i n g z o n e f r o m 6 , 1 9 5 - 6 , 2 3 0 ' . 1 0 . 5 p p g mu d w i t h 2 0 b b l H I - V i s p l u g p r o v i d e d b a s e f o r P l u g 2 f r o m 2 , 6 5 0 ' t o 2 , 3 1 5 ' . P l u g # 2 t o p w a s c o n f i r m e d b y t a g . P l u g # 2 c o v e r s hy d r o c a r b o n b e a r i n g z o n e K - 5 (2 , 4 5 0 ' - 2 , 6 0 0 ' ) . 2 0 b b l H i - V i s p l u g p r o v i d e s b a s e f r o m c e m e n t p l u g # 3 a t 2 , 1 0 0 ' . P l u g 3 w a s c o n f i r m e d a t 1 , 6 5 9 ' w i t h a t a g . We l l w a s p l a n n e d t o b e s i d e t r a c k e d (f o r F i o r d 3 A ) a t a p p r o x i m a t e l y 1 , 9 0 0 ' . F i o r d 3 w a s a b a n d o n d e d w i t h o p s n o t e d i n t h e F i o r d 3 A P & A . We l l i s f u l l y a b a n d o n e d . 0 4 / 1 9 9 5 ND B - 0 3 7 A C T I V E 9 - 5 / 8 " 4 7 p p f 9 , 7 0 4 ' ( N a n u s h u k ) 3 , 7 3 0 ' ( N a n u s h u k ) 7 , 9 8 5 ' 3 , 3 9 7 ' l o g o p e n h o l e l i n e r f o r p r o d u c t i o n TO C 3 , 7 3 0 ' & p a c k e r @ 10 , 6 9 5 ' Ce m e n t J o b O b s e r v a t i o n s : Fo r t h e 1 s t s t a g e o f t h e c e m e n t j o b , w e h a v e a d e q u a t e i s o l a t i o n i n t h e u p p e r N a n u s h u k f o r m a t i o n s a c r o s s t h e h y d r o c a r b o n - b e a r i n g f o r m a t i o n s ( t o p hy d r o c a r b o n e s t i m a t e d w i t h i n N T 8 a t ~ 9 , 9 5 0 ’ M D ) .   T h i s i s s u p p o r t e d b y t h e C B L l o g , w h i c h i n d i c a t e s g o o d c e m e n t t h r o u g h o u t t h e f i r s t s t a g e a n d a T O C a t 7, 9 8 5 ’ M D . Fo r t h e 2 n d s t a g e o f t h e c e m e n t j o b , b a s e d o n j o b e x e c u t i o n r e s u l t s , c e m e n t i s o l a t i o n w a s a c h i e v e d a c r o s s t h e s i g n i f i c a n t h y d r o ca r b o n z o n e w i t h i n t h e u p p e r Tu l u v a k f o r m a t i o n .   Ou r a s s e s s m e n t i s t h a t w e h a v e a d e q u a t e i s o l a t i o n a c r o s s h y d r o c a r b o n - b e a r i n g f o r m a t i o n s i n t h e u p p e r N a n u s h u k f o r m a t i o n s , a s w e ll a s a d e q u a t e i s o l a t i o n f o r fr a c o p e r a t i o n s .   T h e 2 n d s t a g e c e m e n t j o b y i e l d e d a d e q u a t e i s o l a t i o n b e l o w , a c r o s s a n d a b o v e t h e T u l u v a k s i g n i f i c a n t h y d r o c a r b o n s . 1/ 9 / 2 0 2 5 , 9 - 5 / 8 " c a s i n g p r e s s u r e t e s t e d t o 4 , 0 0 0 p s i fo r 3 0 m i n . ND B - 0 2 7 A C T I V E 9 - 5 / 8 " 4 7 p p f 1 5 , 9 9 2 ' ( N a n u s h u k ) 3 , 7 3 0 . 9 ' ( N a n u s h u k ) 1 3 , 8 8 6 ' 3 , 5 1 6 ' l o g o p e n h o l e l i n e r f o r p r o d u c t i o n TO C 3 , 5 1 6 ' & p a c k e r @ 17 , 0 5 6 ' Ce m e n t J o b O b s e r v a t i o n s : 9- 5 / 8 ” 1 s t S t a g e : Fo r t h e 1 s t s t a g e o f t h e c e m e n t j o b , b a s e d o n j o b e x e c u t i o n r e s u l t s , c e m e n t i s o l a t i o n w a s a c h i e v e d a c r o s s t h e 9 - 5 / 8 ” s h o e . 9- 5 / 8 ” 2 n d S t a g e : Fo r t h e 2 n d s t a g e o f t h e c e m e n t j o b , b a s e d o n j o b e x e c u t i o n r e s u l t s , c e m e n t i s o l a t i o n w a s a c h i e v e d a c r o s s t h e s i g n i f i c a n t h y d r o ca r b o n z o n e w i t h i n t h e u p p e r Tu l u v a k f o r m a t i o n .   7” I n t e r m e d i a t e 2 L i n e r Th e S L B T O C l o g i n d i c a t e s a t r a n s i t i o n z o n e f r o m 1 3 , 3 5 0 ’ t o 1 3 , 8 8 6 ’ M D , w i t h t h e T O C a t 1 3 , 8 8 6 ’ M D ( 3 , 5 8 6 ’ T V D ) , a n d g o o d c e m e n t b o n d b e l o w t h i s d e p t h do w n t o t h e 7 ” s h o e .  Th i s p l a c e s c e m e n t ~ 2 2 4 ’ T V D a b o v e t h e t o p o f t h e N a n u s h u k . 9/ 3 0 / 2 0 2 5 , 9 - 5 / 8 " c a s i n g p r e s s u r e t e s t e d t o 4 , 3 0 0 ps i f o r 3 0 m i n . ND B i - 0 4 4 A C T I V E 9 - 5 / 8 " 4 7 p p f 9 6 7 8 ( N a n u s h u k ) 3 , 8 0 4 ( N a n u s h u k ) 7 9 6 4 3 , 4 9 6 l o g o p e n h o l e l i n e r f o r p r o d u c t i o n TO C 7 , 9 6 4 ' & p a c k e r @ 10 , 8 2 3 ' 1. 9 - 5 / 8 ” x 1 3 - 3 / 8 ” P r i m a r y c e m e n t j o b a. P u m p 8 0 b b l s 1 2 . 5 p p g t u n e d s p a c e r , 1 3 1 b b l s 1 3 . 0 p p g 4 0 0 s x s 1 . 8 4 f t ^ 3 / s x E c o n o C e m T p e I - I I l e a d c e m e n t , a n d 8 0 b b l s o f 1 5 . 3 p p g 1 . 2 4 f t ^ 3 / s x V e r s a c e m Ty p e I - I I T a i l . P l a n n e d T O C w a s ~ 8 , 3 5 0 ’ M D . b. N o r e t u r n s w h i l e d i s p l a c i n g c e m e n t j o b . W i p e r d a r t # 2 w a s l o d g e d i n t h e l i n e r r u n n i n g t o o l w h e n i t w a s r e c o v e r e d . T h e f o l l o w li n e r w i p e r p l u g w a s t h e n f o u n d ju s t b e l o w t h e 9 - 5 / 8 ” x 1 3 - 3 / 8 ” L i n e r t o p . A c l e a n o u t r u n w a s r e q u i r e d t o p u s h t h e f o l l o w l i n e r w i p e r p l u g t o b o t t o m a n d t h e s h oe t r a c k w a s d r i l l e d o u t . Dy n a m i c l o s s e s w e r e e n c o u n t e r e d w h i l e d r i l l i n g t h e f l o a t e q u i p m e n t i n d i c a t i n g t h e l o s t c i r c u l a t i o n z o n e h a d n o t b e e n i s o l a t e d . c. A c e m e n t r e t a i n e r w a s r u n i n t h e h o l e a n d s e t a t 1 1 , 0 1 0 ’ M D a n d a s e c o n d c e m e n t j o b w a s p u m p e d t h r o u g h t h e s h o e d. 1 5 b b l s 1 2 . 0 p p g t u n e d s p a c e r a n d 9 5 b b l s o f 1 5 . 3 p p g 1 . 2 4 f t ^ 3 / s x V e r s a c e m T y p e I - I I T a i l w e r e c i r c u l a t e d t h r o u g h t h e r e t a i n e r, a n d 5 b b l s w e r e p l a c e d o n t o p of t h e r e t a i n e r . 2. 9 - 5 / 8 ” S e c o n d a r y C e m e n t J o b a. R I H a n d o p e n u p t h e A r c h e r C f l e x c e m e n t t o o l . E s t a b l i s h c i r c u l a t i o n a n d p u m p 8 0 b b l s 1 2 . 5 p p g T u n e d s p a c e r 2 1 4 b b l s 1 5 . 3 p p g 1. 2 4 f t ^ 3 / s x V e r s a c e m T y p e I - II T a i l . 1 2 9 b b l s w e r e l o s t w h i l e d i s p l a c i n g . T h e L T P w a s s e t a nd 2 6 3 b b l s o f c o n t a m i n a t e d m u d / c e m e n t / s p a c e r w a s c i r c u l a t e d to s u r f a c e w h i l e c i r c u l a t i n g w i t h th e C f l e x r u n n i n g t o o l . A n a d d i t i o n a l 5 b b l s o f c e m e n t w a s c i r c u l a t e d o u t o f f t h e t o p o f t h e l i n e r w h e n c i r c u l a t i n g w i t h t h e l i ne r r u n n i n g t o o a t t h e t o p o f t h e li n e r . 3. 9 - 5 / 8 ” C e m e n t E v a l u a t i o n L o g s a. H E S C a s t t o o l w a s r u n i n t h e h o l e o n a w e l l t e c t r a c t o r . T h e 9 - 5 / 8 ” c e m e n t w a s l o g g e d . S h o w i n g t h e T O C o f t h e p r i m a r y j o b a t 7 ,9 6 4 ' M D . 01 / 3 0 / 2 4 , 9 - 5 / 8 " c a s i n g p r e s s u r e t e s t e d t o 4 2 8 4 p s i fo r 3 0 m i n u t e s Attachment C 9-5/8” 47# L80 HYDRIL 563 Liner Burst (Psi) Collapse (Psi) Tensile (klbs) ID (in) Drift ID (in) Connecti on OD (in) Make-up Torque (ft-lbs) Make-Up Loss (in) 6870 4750 1086 8.681 8.525 10.625 15800 4.050 7” 26# L80 HYDRIL 563 Liner Burst (Psi) Collapse (Psi) Tensile (klbs) ID (in) Drift ID (in) Connecti on OD (in) Make-up Torque (ft-lbs) Make-Up Loss (in) 7240 5410 604 6.276 6.151 7.656 13,700 4,050 Intermediate Liner Cement Job Execution Cement job pumped following the Halliburton Cementing Program Well Design 9-5/8” Intermediate 1 Liner x 9-5/8” Liner Top at 2,850” MD x 13-3/8” Casing Shoe at 3,014’ MD x 9-5/8” Archer Cflex Mechanical Stage tool: 6,588’ MD x 9-5/8” Shoe at 11,997’ MD 7” Intermediate 2 Liner x 7” Liner Top at 11,862’ MD x Shoe at 16,669’ MD Geology x Top of Tuluvak Sand Top at 3,724’ MD x Top of Tuluvak TS 790 formation at 6,527’ MD. x Top of the Nanushuk picked at 15,918’ MD/ 3,814’ TVD. Cement Job Planning/Execution A summary is provided below. See attached cementing reports for additional information. 9-5/8” INT1 Liner 1st Stage Cement Job -1st Stage of cement job planned with a full 15.3 ppg tail slurry at 30% excess, targeting 1,000’ MD above 9-5/8” shoe to ~10,997’ MD. This cement job is not isolating any permeable or hydrocarbon zones. -No losses were observed while running liner. Encountered minimal losses throughout the 1st stage cement job (20 bbls of losses after cement exited the shoe). -More details on the cement job can be referenced in the Wellview Cementing report. -A good FIT to 14.0ppg was achieved at the 9-5/8” shoe. -All indications of a successful 1st stage job. 9-5/8” INT1 Liner 2nd Stage Cement Job -2nd Stage of cement job planned with CFLEX ~50’ below the TS790. Planned with a full 14.5 ppg tail slurry at 100% excess, targeting TOC at the 9-5/8” liner top. This cement job is isolating the hydrocarbon zone within the upper Tuluvak formation. -Opened the CFLEX stage tool at ~6588’ MD and established circulation up to 8 bpm. Pumped the 2 nd stage cement job with full returns and good lift pressure. Closed the CFLEX and set the LTP, then circulated ~46 bbls clean cement back to surface. -All indications of a successful 2nd stage cement job. Lighter weight 14.5ppg cement seemed to help reduce ECDs resulting in no losses. 7” INT2 Liner Cement Job -1st Stage of cement job planned with a full 15.3 ppg tail slurry at 30% excess, targeting 200’ TVD above Top Nanushuk to ~14,892’ MD. Additionally, this well was planned with 145 bbl LVT spacer to be pumped ahead of the cement spacer to further lower cementing ECD. This cement job is isolating hydrocarbons in the Upper Nanushuk. -No issues or losses were encountered running liner and cementing the 1st stage cement job. -More details on the cement job can be referenced in the Wellview Cementing report. -A FIT of 14.0ppg was achieved at the 7” shoe. A SLB Sonic CBL was run on the 6- 1/8” drilling BHA – results are discussed below and report is attached. Observations 9-5/8” Intermediate 1 Liner: -For the 1st stage of the cement job, based on job execution results, cement isolation was achieved across the 9-5/8” shoe. -For the 2nd stage of the cement job, based on job execution results, cement isolation was achieved across the hydrocarbon zone within the upper Tuluvak formation. 7” Intermediate 2 Liner: -The SLB Sonic TOC Log indicates there is good cement coverage across and above the Upper Nanushuk formations. Summary as follows: o Top of Partial Cement is 13,814' MD / 3,503' TVD - 2104' MD / 311' TVD above TNAN o Top of Good Cement is 14,098' MD / 3,531' TVD - 1820' MD / 283' TVD above TNAN o Top of Nanushuk is 15,918’ MD / 3,814’ TVD Page 1/2 Well Name: NDBi-034 Report Printed: 1/12/2026www.peloton.com Cement API/UWI 50103209270000 Surface Legal Location Field Name Pikka PTD # 225108 State/Province Well Configuration Type Horizontal Ground Elevation (ft) 22.79 Casing Flange Elevation (ft) KB-Ground Distance (ft) 47.10 KB-Casing Flange Distance (ft) Spud Date 12/8/2025 09:00 Rig Release Date 1/12/2026 00:00 Surface Surface, Casing, 12/11/2025 07:45 Type Casing Cementing Start Date 12/11/2025 Cementing End Date 12/11/2025 Wellbore Original Hole String Surface Casing, 3,014.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Returns to Surface Cement Evaluation Results Good lift pressure observed. 100 bbls of clean cement to surface and no losses during cement job. Comment Cement 13-3/8” Surface casing as follows: - Rig to pump 40 bbl 10 ppg. 1 ppb PowerVis Spacer, at 4 bpm, 140 psi - Fill lines with 5 bbls water and pressure test to 4,000 psi for 5 minutes - Good test - Drop 1st bottom plug - Pump 80 bbls of 10.5 ppg Tuned Spacer at 5.0 bpm, 235 psi. - Release 2nd bottom plug. - Pump 440 bbls of 11.0 ppg ArcticCem lead cement at 5 bpm, excess volume 200% (973 sacks, yield 2.535 cu.ft/sk) - Pump 69 bbls of 15.3 ppg Type I/II tail at 5 bpm, excess volume 50% (312 sacks, yield 1.24 cu.ft/sk) - Drop top plug and followed by 20 bbls fresh water. - Perform displacement with rig pumps and 9.4 ppg mud - Utilized conductor jet line with water to help clear intermittent packoffs during displacement. - 140 bbls displaced at 4 bpm: ICP 206 psi 11% return flow, FCP 568 psi. - Reduce rate to 3 bpm and pump 291 bbls ICP 424 psi 10-20 % returns bump: Final circulating pressure 680 psi prior to plug bump. - Bump plug and increase pressure to 1,160 psi, held for 5 min. bled off, check floats – good. - Total displacement volume 431 bbls (measured by strokes at 96% pump efficiency). - Total losses for cement job and displacement: 0 bbls - Observed PowerVis interface at 87 bbls into displacement. - Dump to cuttings box 120 bbls. into displacement. - Observed Tuned Spacer with Red Dye Interface - Observed 100 bbls clean cement to surface - CIP at 12:50 hrs. - BOPE Test notification submitted to AOGCC, 12-9-25 @ 14:00 hrs for test date 12-11-25 @ 19:00 hrs. - Test witness waived by AOGCC Inspector Kam StJohn at 14:09 hrs 12/9/25 1, 0.0-3,024.0ftKB Top Depth (ftKB) 0.0 Bottom Depth (ftKB) 3,024.0 Full Return? No Vol Cement Ret (bbl) 100.0 Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 4 Final Pump Rate (bbl/min) 4 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 786.0 Plug Bump Pressure (psi) 680.0 Pipe Reciprocated? No Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Spacer Fluid Type Spacer Fluid Description Amount (sacks) Class Volume Pumped (bbl) 40.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) 3,024.0 Percent Excess Pumped (%) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) 10.00 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Cement Stage Fluid Additives Add Type Conc Tuned Spacer Fluid Type Tuned Spacer Fluid Description PowerVis Spacer Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) 3,024.0 Estimated Bottom Depth (ftKB) 3,024.0 Percent Excess Pumped (%) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) 10.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Cement Stage Fluid Additives Add Type Conc Lead Fluid Type Lead Fluid Description ArcticCem Amount (sacks) 973 Class I/II Volume Pumped (bbl) 440.0 Estimated Top (ftKB) 3,024.0 Estimated Bottom Depth (ftKB) 3,024.0 Percent Excess Pumped (%) 200.0 Yield (ft³/sack) 2.54 Mix H20 Ratio (gal/sack) 12.21 Free Water (%) 0.00 Density (lb/gal) 11.00 Plastic Viscosity (cP) 15.8 Thickening Time (hr) 22.50 1st Compressive Strength (psi) 500.0 Cement Stage Fluid Additives Add Type Conc Page 2/2 Well Name: NDBi-034 Report Printed: 1/12/2026www.peloton.com Cement API/UWI 50103209270000 Surface Legal Location Field Name Pikka PTD # 225108 State/Province Well Configuration Type Horizontal Ground Elevation (ft) 22.79 Casing Flange Elevation (ft) KB-Ground Distance (ft) 47.10 KB-Casing Flange Distance (ft) Spud Date 12/8/2025 09:00 Rig Release Date 1/12/2026 00:00 Surface Tail Fluid Type Tail Fluid Description Amount (sacks) 312 Class I/II Volume Pumped (bbl) 69.0 Estimated Top (ftKB) 3,024.0 Estimated Bottom Depth (ftKB) 3,024.0 Percent Excess Pumped (%) 50.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.59 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) 57.8 Thickening Time (hr) 10.75 1st Compressive Strength (psi) 500.0 Cement Stage Fluid Additives Add Type Conc Page 1/1 Well Name: NDBi-034 Report Printed: 1/12/2026www.peloton.com Cement API/UWI 50103209270000 Surface Legal Location Field Name Pikka PTD # 225108 State/Province Well Configuration Type Horizontal Ground Elevation (ft) 22.79 Casing Flange Elevation (ft) KB-Ground Distance (ft) 47.10 KB-Casing Flange Distance (ft) Spud Date 12/8/2025 09:00 Rig Release Date 1/12/2026 00:00 Intermediate Casing Cement Stage 1 Intermediate Casing Cement Stage 1, Casing, 12/18/2025 18:00 Type Casing Cementing Start Date 12/18/2025 Cementing End Date 12/18/2025 Wellbore Original Hole String Intermediate Liner, 11,997.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Cement job parameters / FIT Cement Evaluation Results Good lift pressure observed and only 20 bbls of losses after cement exited shoe. FIT to 14.0ppg EMW at 9 -5/8" shoe. Comment Cement 1st stage 9-5/8” Intermediate Liner - Pump 5 bbls water & Pressure test cement lines to 1,000 psi low 4,000 psi High. - Pump 76 bbl 12.5 ppg Tuned Spacer with Surfactant B and Musol A downhole at 4 bpm with 465 psi, - Release bottom pump down plug, chase with 80 bbls of 15.3 ppg Versacem Tail cement type I/II at 4 bpm, initial circulating pressure 800 psi. FCP 250 PSI. Open hole excess volume 30%. - Flush lines with 20 bbl. water to cuttings box - Release top pump down plug - Perform displacement with rig pumps and 11.5 ppg MOBM as follows: - 709 bbls 11.5 ppg OBM at 4 bpm, ICP 428 psi, 3 bpm FCP 450 psi. (Bottom pump down dart latch up confirmed at 54 bbls displaced.) - Pressured up 500 psi over FCP (955 psi) and held 5 min, bled off, checked floats. Floats held. - Total displacement volume 709 bbls (measured by strokes at 96% pump efficiency). CIP @ 23:30 hrs. - 86 bbl total losses during cement job and displacement, 20 bbl loss from cement exiting the shoe to bumping the plug. 1, 10,997.0-12,000.0ftKB Top Depth (ftKB) 10,997.0 Bottom Depth (ftKB) 12,000.0 Full Return? No Vol Cement Ret (bbl) Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 4 Final Pump Rate (bbl/min) 4 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 450.0 Plug Bump Pressure (psi) 955.0 Pipe Reciprocated? No Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Tuned Spacer Fluid Type Tuned Spacer Fluid Description Tuned Spacer 4# Red Dye 65 gal Surf B & Musol A Amount (sacks) Class Volume Pumped (bbl) 76.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) 12,000.0 Percent Excess Pumped (%) Yield (ft³/sack) 2.24 Mix H20 Ratio (gal/sack) 13.09 Free Water (%) Density (lb/gal) 12.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Cement Stage Fluid Additives Add Type Conc Tail Fluid Type Tail Fluid Description Versacem Amount (sacks) 363 Class I/II Volume Pumped (bbl) 80.0 Estimated Top (ftKB) 10,997.0 Estimated Bottom Depth (ftKB) 12,000.0 Percent Excess Pumped (%) 30.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.56 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) 129.0 Thickening Time (hr) 7.00 1st Compressive Strength (psi) 500.0 Cement Stage Fluid Additives Add Type Conc Page 1/1 Well Name: NDBi-034 Report Printed: 1/12/2026www.peloton.com Cement API/UWI 50103209270000 Surface Legal Location Field Name Pikka PTD # 225108 State/Province Well Configuration Type Horizontal Ground Elevation (ft) 22.79 Casing Flange Elevation (ft) KB-Ground Distance (ft) 47.10 KB-Casing Flange Distance (ft) Spud Date 12/8/2025 09:00 Rig Release Date 1/12/2026 00:00 Intermediate Casing Cement Stage 2 Intermediate Casing Cement Stage 2, Casing, 12/19/2025 13:00 Type Casing Cementing Start Date 12/19/2025 Cementing End Date 12/19/2025 Wellbore Original Hole String Intermediate Liner, 11,997.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Cement returns circulated off top of liner Cement Evaluation Results Good lift pressure observed when displacing cement. 46 bbls of clean cement returned to surface when circulating above the liner top after cement job. No losses during cement job. Comment Perform 2nd stage cementing of 9-5/8” 47# Intermediate casing by open hole annulus through Archer cementing tool as follows: - Fill lines with water and test 1,000 psi low, 4,000 psi high. - Mix and pump 80 bbls of 12.5 ppg Mud Flush at 4 bpm, ICP 543psi, FCP 324 - Mix and pump 79 bbls of 13.5 Tuned Spacer at 4.2 bpm, ICP 395 psi. FCP 304 psi, - Mix and pump 418 bbls of 14.5 ppg Swiftcem Type I-II Tail cement at 4 bpm, ICP 505 psi, final pump rate 4 bpm, FCP 440 psi. No losses observed. - Excess volume 100% (1,664 sacks, yield 1.39 cu ft/sk) - Displace cement with 144 bbls at 4 bpm, 296 psi ICP, 753 psi FCP. CIP @ 16:23 hrs. - No losses during cement job or displacement - Observed red dye at shakers 92 bbls into displacement - Circulate 46 bbls clean cement off liner top. 2, 2,873.0-6,593.0ftKB Top Depth (ftKB) 2,873.0 Bottom Depth (ftKB) 6,593.0 Full Return? Yes Vol Cement Ret (bbl) 46.0 Top Plug? No Bottom Plug? No Initial Pump Rate (bbl/min) 4 Final Pump Rate (bbl/min) 4 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 440.0 Plug Bump Pressure (psi) Pipe Reciprocated? No Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Mud Flush Fluid Type Mud Flush Fluid Description Mud Flush Spacer 8# Red Dye, 65 gal Surf B & Musol A Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 2.22 Mix H20 Ratio (gal/sack) 12.89 Free Water (%) Density (lb/gal) 12.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Cement Stage Fluid Additives Add Type Conc Tuned Spacer Fluid Type Tuned Spacer Fluid Description Tuned Spacer 4# Red Dye, 65 gal Surf B & Musol A Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 1.91 Mix H20 Ratio (gal/sack) 10.72 Free Water (%) Density (lb/gal) 13.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Cement Stage Fluid Additives Add Type Conc Swiftcem Tail Fluid Type Swiftcem Tail Fluid Description Swiftcem Type I/II Tail Amount (sacks) 1,664 Class I/II Volume Pumped (bbl) 418.0 Estimated Top (ftKB) 2,873.0 Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) 100.0 Yield (ft³/sack) 1.39 Mix H20 Ratio (gal/sack) 10.72 Free Water (%) 0.00 Density (lb/gal) 14.50 Plastic Viscosity (cP) 49.5 Thickening Time (hr) 7.00 1st Compressive Strength (psi) 500.0 Cement Stage Fluid Additives Add Type Conc Page 1/1 Well Name: NDBi-034 Report Printed: 1/12/2026www.peloton.com Cement API/UWI 50103209270000 Surface Legal Location Field Name Pikka PTD # 225108 State/Province Well Configuration Type Horizontal Ground Elevation (ft) 22.79 Casing Flange Elevation (ft) KB-Ground Distance (ft) 47.10 KB-Casing Flange Distance (ft) Spud Date 12/8/2025 09:00 Rig Release Date 1/12/2026 00:00 7" Intermediate Casing Cement 7" Intermediate Casing Cement, Casing, 12/26/2025 08:44 Type Casing Cementing Start Date 12/26/2025 Cementing End Date 12/26/2025 Wellbore Original Hole String Intermediate 2 Liner, 16,669.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Cement Bond Log Cement Evaluation Results SLB SonicScope TOC Log: - Top of Partial Cement is 13,814' MD / 3,503' TVD - 2104' MD / 311' TVD above TNAN. - Top of Good Cement is 14,098' MD / 3,531' TVD - 1820' MD / 283' TVD above TNAN. - Top of Nanushuk is 15,918' MD / 3,814' TVD. Comment Cement 7” Intermediate liner. -PJSM with Third party and Rig personnel -Fill lines with water and pressure test to 4000 psi for 5 min. -Pump 145 bbls LVT at 4 bpm, 600 psi. -Pump 80 bbls of 12.5 ppg Tuned spacer at 3.8 bpm, 500 psi. -Release bottom Pump Down Plug -Pump 122 bbls of 15.3 ppg Type I/II VersaCem tail at 3.7 bpm, Excess Volume 30% (312 sacks, yield 1.24 cu.ft/sk). -Wash up Lines to cuttings box with 20 bbls water -Release top Pump Down Plug, -Perform displacement with rig pumps at 4 bpm. ICP 625 psi. FCP 670 psi with 350 bbls away. Reduce rate to 3 bpm, 600 psi to land plug at 369 bbls displacement. -Bump plug with 1,050 psi and hold for 5 mins. -No losses during cement job. -CIP at 13:47 hrs 1, 11,862.0-16,669.0ftKB Top Depth (ftKB) 11,862.0 Bottom Depth (ftKB) 16,669.0 Full Return? Yes Vol Cement Ret (bbl) Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 4 Final Pump Rate (bbl/min) 3 Avg Pump Rate (bbl/min) 3 Final Pump Pressure (psi) 670.0 Plug Bump Pressure (psi) 1,050.0 Pipe Reciprocated? No Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Spacer Fluid Type Spacer Fluid Description Tuned Spacer with 4lbs of red die and 65 gallons of surf B and musol A. Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 2.24 Mix H20 Ratio (gal/sack) 13.09 Free Water (%) Density (lb/gal) 12.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) Cement Stage Fluid Additives Add Type Conc Tail Fluid Type Tail Fluid Description VersaCem (Type I/II) Amount (sacks) 312 Class Type I/II Volume Pumped (bbl) 122.0 Estimated Top (ftKB) 14,750.0 Estimated Bottom Depth (ftKB) 16,660.0 Percent Excess Pumped (%) 30.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.57 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) 117.8 Thickening Time (hr) 8.00 1st Compressive Strength (psi) 500.0 Cement Stage Fluid Additives Add Type Conc Attachment D Attachment E Attachment F We l l N a m e ND B i - 0 3 4 01 / 1 2 / 2 6 P r e l i m i n a r y D e s i g n ST A G E C O M M E N T S P U M P D I R T Y V O L U M E D I R T Y V O L U M E PR O P P A N T # T Y P E P P T R A T E S T A G E C U M ST A G E C U M ST A G E C U M S I Z E S t a g e C u m Pr e F r a c - N o n P r o p p a n t s t a g e s (B P M ) ( B B L ) ( B B L ) (G A L ) ( G A L ) (L B S ) ( L B S ) ( B B L ) (B B L ) a WF b WF 2 6 0 0 0 0 0 c P u m p C h e c k WF 26 4 0 40 0 40 0 16 8 0 0 16 8 0 0 40 0 40 0 d HS D - M o n i t o r f o r ~ 3 0 m i n 40 0 0 1 6 8 0 0 0 4 0 0 eD F I T XL 26 4 0 30 0 70 0 1 2 6 0 0 2 9 4 0 0 3 0 0 7 0 0 f DF I T D i s p l a c e m e n t WF 26 4 0 40 0 11 0 0 1 6 8 0 0 4 6 2 0 0 4 0 0 1 1 0 0 g HS D - M o n i t o r f o r ~ 2 H 11 0 0 0 4 6 2 0 0 0 1 1 0 0 PU M P D I R T Y V O L U M E D I R T Y V O L U M E PR O P P A N T CL E A N V O L U M S T A G E A V E R A G E F L U I D R A T E S T A G E C U M T O T J O B ST A G E C U M ST A G E C U M S i z e o r S t a g e C u m # P P A T Y P E ( B P M ) ( B B L ) ( B B L ) ( B B L ) (G A L ) ( G A L ) (L B S ) ( L B S ) T y p e ( B B L ) ( B B L ) 1 0 Li n e o u t X L X L 2 6 40 40 40 1 1 4 0 16 8 0 4 7 8 8 0 0 0 4 0 1 1 4 0 2 0 Dr o p S t a g e 1 B a l l / C o l l e t F P 0 40 3 43 1 1 4 3 12 6 4 8 0 0 6 00 16 / 2 0 - C L 3 1 1 4 3 3 0 St a g e 1 P A D XL 2 6 40 3 5 9 40 2 1 5 0 2 15 0 7 8 6 3 0 8 4 0 0 3 5 9 1 5 0 2 4 0 Sl o w f o r S e a t XL 2 6 40 5 0 45 2 1 5 5 2 21 0 0 6 5 1 8 4 0 0 5 0 1 5 5 2 5 0 Re s u m e P a d XL 2 6 40 1 45 3 1 5 5 3 42 6 5 2 2 6 0 0 1 1 5 5 3 6 1 Fl a t ; A d d P a t i n a T r a c e r t o P O D XL 2 6 40 1 2 5 57 8 1 6 7 8 52 5 0 7 0 4 7 6 50 2 8 5 0 2 8 16 / 2 0 - C L 12 0 1 6 7 3 7 2 Fl a t XL 2 6 40 1 4 0 71 8 1 8 1 8 58 8 0 7 6 3 5 6 10 8 0 4 1 5 8 3 1 16 / 2 0 - C L 12 9 1 8 0 1 8 3 Fl a t XL 2 6 40 1 7 0 88 8 1 9 8 8 71 4 0 8 3 4 9 6 18 9 1 0 3 4 7 4 1 16 / 2 0 - C L 15 0 1 9 5 1 9 4 Fl a t XL 2 6 40 1 7 0 10 5 8 2 1 5 8 71 4 0 9 0 6 3 6 24 2 6 5 5 9 0 0 7 16 / 2 0 - C L 14 4 2 0 9 6 10 5 Fl a t XL 2 6 40 1 7 0 12 2 8 2 3 2 8 71 4 0 9 7 7 7 6 29 2 3 3 8 8 2 3 9 16 / 2 0 - C L 13 9 2 2 3 5 11 6 Fl a t XL 2 6 40 1 7 0 13 9 8 2 4 9 8 71 4 0 1 0 4 9 1 6 33 8 5 3 1 2 2 0 9 2 16 / 2 0 - C L 13 4 2 3 6 9 12 7 Fl a t XL 2 6 40 1 4 0 15 3 8 2 6 3 8 58 8 0 1 1 0 7 9 6 31 4 2 6 1 5 3 5 1 8 16 / 2 0 - C L 10 7 2 4 7 6 13 8 Fl a t XL 2 6 40 1 2 5 16 6 3 2 7 6 3 52 5 0 1 1 6 0 4 6 31 0 2 0 1 8 4 5 3 8 16 / 2 0 - C L 92 2 5 6 9 14 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 16 7 8 2 7 7 8 63 0 1 1 6 6 7 6 0 1 8 4 5 3 8 1 5 2 5 8 4 15 0 Sp a c e r X L 2 6 40 15 16 9 3 2 7 9 3 63 0 1 1 7 3 0 6 0 1 8 4 5 3 8 1 5 2 5 9 9 16 0 Dr o p S t a g e 2 B a l l / C o l l e t F P 0 40 3 16 9 6 2 7 9 6 12 6 1 1 7 4 3 2 0 1 8 4 5 3 8 3 2 6 0 2 17 0 St a g e 2 P A D XL 2 6 40 3 5 1 20 4 7 3 1 4 7 14 7 4 2 1 3 2 1 7 4 0 1 8 4 5 3 8 3 5 1 2 9 5 3 18 0 Sl o w f o r S e a t X L 2 6 18 50 20 9 7 3 1 9 7 21 0 0 1 3 4 2 7 4 0 1 8 4 5 3 8 5 0 3 0 0 3 19 0 Re s u m e P a d XL 2 6 40 4 9 21 4 6 3 2 4 6 20 5 8 1 3 6 3 3 2 0 1 8 4 5 3 8 4 9 3 0 5 2 20 1 Fl a t XL 2 6 40 1 5 0 22 9 6 3 3 9 6 63 0 0 1 4 2 6 3 2 60 3 3 1 9 0 5 7 1 16 / 2 0 - C L 14 4 3 1 9 5 21 2 Fl a t XL 2 6 40 1 7 5 24 7 1 3 5 7 1 73 5 0 1 4 9 9 8 2 13 5 0 5 2 0 4 0 7 6 16 / 2 0 - C L 16 1 3 3 5 6 22 3 Fl a t XL 2 6 40 2 0 0 26 7 1 3 7 7 1 84 0 0 1 5 8 3 8 2 22 2 4 7 2 2 6 3 2 2 16 / 2 0 - C L 17 7 3 5 3 3 23 4 Fl a t XL 2 6 40 2 0 0 28 7 1 3 9 7 1 84 0 0 1 6 6 7 8 2 28 5 4 7 2 5 4 8 7 0 16 / 2 0 - C L 17 0 3 7 0 2 24 5 Fl a t XL 2 6 40 2 0 0 30 7 1 4 1 7 1 84 0 0 1 7 5 1 8 2 34 3 9 1 2 8 9 2 6 1 16 / 2 0 - C L 16 4 3 8 6 6 25 6 Fl a t XL 2 6 40 2 0 0 32 7 1 4 3 7 1 84 0 0 1 8 3 5 8 2 39 8 2 7 3 2 9 0 8 8 16 / 2 0 - C L 15 8 4 0 2 4 26 7 Fl a t XL 2 6 40 1 7 0 34 4 1 4 5 4 1 71 4 0 1 9 0 7 2 2 38 1 6 0 3 6 7 2 4 8 16 / 2 0 - C L 13 0 4 1 5 4 27 8 Fl a t XL 2 6 40 1 3 5 35 7 6 4 6 7 6 56 7 0 1 9 6 3 9 2 33 5 0 1 4 0 0 7 4 9 16 / 2 0 - C L 10 0 4 2 5 4 28 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 35 9 1 4 6 9 1 63 0 1 9 7 0 2 2 0 4 0 0 7 4 9 1 5 4 2 6 9 29 0 Sp a c e r X L 2 6 40 15 36 0 6 4 7 0 6 63 0 1 9 7 6 5 2 0 4 0 0 7 4 9 1 5 4 2 8 4 30 0 Dr o p S t a g e 3 B a l l / C o l l e t F P 0 40 3 36 0 9 4 7 0 9 12 6 1 9 7 7 7 8 0 4 0 0 7 4 9 3 4 2 8 7 31 0 St a g e 3 P A D XL 2 6 40 3 4 3 39 5 2 5 0 5 2 14 4 0 6 2 1 2 1 8 4 0 4 0 0 7 4 9 3 4 3 4 6 3 0 FL U I D Ne a t W a t e r CO M M E N T S En s u r e S t a g e 1 b a l l / c o l l e t i s l o a d e d Pr i m e a n d P r e s s u r e T e s t Op e n w e l l We l l N a m e ND B i - 0 3 4 01 / 1 2 / 2 6 P r e l i m i n a r y D e s i g n ST A G E C O M M E N T S P U M P D I R T Y V O L U M E D I R T Y V O L U M E PR O P P A N T # T Y P E P P T R A T E S T A G E C U M ST A G E C U M ST A G E C U M S I Z E S t a g e C u m Pr e F r a c - N o n P r o p p a n t s t a g e s (B P M ) ( B B L ) ( B B L ) (G A L ) ( G A L ) (L B S ) ( L B S ) ( B B L ) ( B B L ) FL U I D Ne a t W a t e r 32 0 Sl o w f o r S e a t X L 2 6 18 50 40 0 2 5 1 0 2 21 0 0 2 1 4 2 8 4 0 4 0 0 7 4 9 5 0 4 6 8 0 33 0 Re s u m e P a d XL 2 6 40 5 7 40 5 9 5 1 5 9 23 9 4 2 1 6 6 7 8 0 4 0 0 7 4 9 5 7 4 7 3 7 34 1 Fl a t XL 2 6 40 1 5 0 42 0 9 5 3 0 9 63 0 0 2 2 2 9 7 8 60 3 3 4 0 6 7 8 2 16 / 2 0 - C L 14 4 4 8 8 0 35 2 Fl a t XL 2 6 40 1 7 5 43 8 4 5 4 8 4 73 5 0 2 3 0 3 2 8 13 5 0 5 4 2 0 2 8 7 16 / 2 0 - C L 16 1 5 0 4 1 36 3 Fl a t XL 2 6 40 2 0 0 45 8 4 5 6 8 4 84 0 0 2 3 8 7 2 8 22 2 4 7 4 4 2 5 3 4 16 / 2 0 - C L 17 7 5 2 1 8 37 4 Fl a t XL 2 6 40 2 0 0 47 8 4 5 8 8 4 84 0 0 2 4 7 1 2 8 28 5 4 7 4 7 1 0 8 1 16 / 2 0 - C L 17 0 5 3 8 8 38 5 Fl a t XL 2 6 40 2 0 0 49 8 4 6 0 8 4 84 0 0 2 5 5 5 2 8 34 3 9 1 5 0 5 4 7 3 16 / 2 0 - C L 16 4 5 5 5 1 39 6 Fl a t XL 2 6 40 2 0 0 51 8 4 6 2 8 4 84 0 0 2 6 3 9 2 8 39 8 2 7 5 4 5 2 9 9 16 / 2 0 - C L 15 8 5 7 1 0 40 7 Fl a t XL 2 6 40 1 7 0 53 5 4 6 4 5 4 71 4 0 2 7 1 0 6 8 38 1 6 0 5 8 3 4 6 0 16 / 2 0 - C L 13 0 5 8 3 9 41 8 Fl a t XL 2 6 40 1 3 5 54 8 9 6 5 8 9 56 7 0 2 7 6 7 3 8 33 5 0 1 6 1 6 9 6 1 16 / 2 0 - C L 10 0 5 9 3 9 42 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 55 0 4 6 6 0 4 63 0 2 7 7 3 6 8 0 6 1 6 9 6 1 1 5 5 9 5 4 43 0 Sp a c e r X L 2 6 40 15 55 1 9 6 6 1 9 63 0 2 7 7 9 9 8 0 6 1 6 9 6 1 1 5 5 9 6 9 44 0 Dr o p S t a g e 4 B a l l / C o l l e t F P 0 40 3 55 2 2 6 6 2 2 12 6 2 7 8 1 2 4 0 6 1 6 9 6 1 3 5 9 7 2 45 0 St a g e 4 P A D XL 2 6 40 3 3 4 58 5 6 6 9 5 6 14 0 2 8 2 9 2 1 5 2 0 6 1 6 9 6 1 3 3 4 6 3 0 6 46 0 Sl o w f o r S e a t X L 2 6 18 50 59 0 6 7 0 0 6 21 0 0 2 9 4 2 5 2 0 6 1 6 9 6 1 5 0 6 3 5 6 47 0 Re s u m e P a d XL 2 6 40 4 1 59 4 7 7 0 4 7 17 2 2 2 9 5 9 7 4 0 6 1 6 9 6 1 4 1 6 3 9 7 48 1 Fl a t XL 2 6 40 1 6 0 61 0 7 7 2 0 7 67 2 0 3 0 2 6 9 4 64 3 5 6 2 3 3 9 6 16 / 2 0 - C L 15 3 6 5 5 0 49 2 Fl a t XL 2 6 40 1 7 0 62 7 7 7 3 7 7 71 4 0 3 0 9 8 3 4 13 1 1 9 6 3 6 5 1 5 16 / 2 0 - C L 15 6 6 7 0 6 50 3 Fl a t XL 2 6 40 1 8 5 64 6 2 7 5 6 2 77 7 0 3 1 7 6 0 4 20 5 7 8 6 5 7 0 9 3 16 / 2 0 - C L 16 3 6 8 7 0 51 4 Fl a t XL 2 6 40 1 8 5 66 4 7 7 7 4 7 77 7 0 3 2 5 3 7 4 26 4 0 6 6 8 3 5 0 0 16 / 2 0 - C L 15 7 7 0 2 7 52 5 Fl a t XL 2 6 40 1 8 5 68 3 2 7 9 3 2 77 7 0 3 3 3 1 4 4 31 8 1 2 7 1 5 3 1 2 16 / 2 0 - C L 15 1 7 1 7 8 53 6 Fl a t XL 2 6 40 1 8 5 70 1 7 8 1 1 7 77 7 0 3 4 0 9 1 4 36 8 4 0 7 5 2 1 5 1 16 / 2 0 - C L 14 6 7 3 2 5 54 7 Fl a t XL 2 6 40 1 5 5 71 7 2 8 2 7 2 65 1 0 3 4 7 4 2 4 34 7 9 3 7 8 6 9 4 5 16 / 2 0 - C L 11 8 7 4 4 3 55 8 Fl a t XL 2 6 40 1 4 0 73 1 2 8 4 1 2 58 8 0 3 5 3 3 0 4 34 7 4 2 8 2 1 6 8 7 16 / 2 0 - C L 10 3 7 5 4 6 56 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 73 2 7 8 4 2 7 63 0 3 5 3 9 3 4 0 8 2 1 6 8 7 1 5 7 5 6 1 57 0 Sp a c e r X L 2 6 40 15 73 4 2 8 4 4 2 63 0 3 5 4 5 6 4 0 8 2 1 6 8 7 1 5 7 5 7 6 58 0 Dr o p S t a g e 5 B a l l / C o l l e t F P 0 40 3 73 4 5 8 4 4 5 12 6 3 5 4 6 9 0 0 8 2 1 6 8 7 3 7 5 7 9 59 0 St a g e 5 P A D XL 2 6 40 3 2 6 76 7 1 8 7 7 1 13 6 9 2 3 6 8 3 8 2 0 8 2 1 6 8 7 3 2 6 7 9 0 5 60 0 Sl o w f o r S e a t X L 2 6 18 50 77 2 1 8 8 2 1 21 0 0 3 7 0 4 8 2 0 8 2 1 6 8 7 5 0 7 9 5 5 61 0 Re s u m e P a d XL 2 6 40 4 9 77 7 0 8 8 7 0 20 5 8 3 7 2 5 4 0 0 8 2 1 6 8 7 4 9 8 0 0 4 62 1 Fl a t XL 2 6 40 1 6 5 79 3 5 9 0 3 5 69 3 0 3 7 9 4 7 0 66 3 6 8 2 8 3 2 3 16 / 2 0 - C L 15 8 8 1 6 2 63 2 Fl a t XL 2 6 40 1 8 0 81 1 5 9 2 1 5 75 6 0 3 8 7 0 3 0 13 8 9 1 8 4 2 2 1 4 16 / 2 0 - C L 16 5 8 3 2 8 64 3 Fl a t XL 2 6 40 1 9 5 83 1 0 9 4 1 0 81 9 0 3 9 5 2 2 0 21 6 9 1 8 6 3 9 0 4 16 / 2 0 - C L 17 2 8 5 0 0 65 4 Fl a t XL 2 6 40 1 9 5 85 0 5 9 6 0 5 81 9 0 4 0 3 4 1 0 27 8 3 4 8 9 1 7 3 8 16 / 2 0 - C L 16 6 8 6 6 6 66 5 Fl a t XL 2 6 40 1 9 5 87 0 0 9 8 0 0 81 9 0 4 1 1 6 0 0 33 5 3 2 9 2 5 2 7 0 16 / 2 0 - C L 16 0 8 8 2 5 67 6 Fl a t XL 2 6 40 1 9 5 88 9 5 9 9 9 5 81 9 0 4 1 9 7 9 0 38 8 3 1 9 6 4 1 0 1 16 / 2 0 - C L 15 4 8 9 7 9 68 7 Fl a t XL 2 6 40 1 8 5 90 8 0 1 0 1 8 0 77 7 0 4 2 7 5 6 0 41 5 2 8 1 0 0 5 6 2 8 16 / 2 0 - C L 14 1 9 1 2 1 69 8 Fl a t XL 2 6 40 1 7 0 92 5 0 1 0 3 5 0 71 4 0 4 3 4 7 0 0 42 1 8 7 1 0 4 7 8 1 5 16 / 2 0 - C L 12 6 9 2 4 6 70 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 92 6 5 1 0 3 6 5 63 0 4 3 5 3 3 0 0 1 0 4 7 8 1 5 1 5 9 2 6 1 71 0 Sp a c e r X L 2 6 40 15 92 8 0 1 0 3 8 0 63 0 4 3 5 9 6 0 0 1 0 4 7 8 1 5 1 5 9 2 7 6 72 0 Dr o p S t a g e 6 B a l l / C o l l e t F P 0 40 3 92 8 3 1 0 3 8 3 12 6 4 3 6 0 8 6 0 1 0 4 7 8 1 5 3 9 2 7 9 73 0 St a g e 6 P A D XL 2 6 40 3 1 7 96 0 0 1 0 7 0 0 13 3 1 4 4 4 9 4 0 0 0 1 0 4 7 8 1 5 3 1 7 9 5 9 6 74 0 Sl o w f o r S e a t X L 2 6 18 50 96 5 0 1 0 7 5 0 21 0 0 4 5 1 5 0 0 0 1 0 4 7 8 1 5 5 0 9 6 4 6 We l l N a m e ND B i - 0 3 4 01 / 1 2 / 2 6 P r e l i m i n a r y D e s i g n ST A G E C O M M E N T S P U M P D I R T Y V O L U M E D I R T Y V O L U M E PR O P P A N T # T Y P E P P T R A T E S T A G E C U M ST A G E C U M ST A G E C U M S I Z E S t a g e C u m Pr e F r a c - N o n P r o p p a n t s t a g e s (B P M ) ( B B L ) ( B B L ) (G A L ) ( G A L ) (L B S ) ( L B S ) ( B B L ) ( B B L ) FL U I D Ne a t W a t e r 75 0 Re s u m e P a d XL 2 6 40 8 3 97 3 3 1 0 8 3 3 34 8 6 4 5 4 9 8 6 0 1 0 4 7 8 1 5 8 3 9 7 2 9 76 1 Fl a t XL 2 6 40 1 6 5 98 9 8 1 0 9 9 8 69 3 0 4 6 1 9 1 6 66 3 6 1 0 5 4 4 5 1 16 / 2 0 - C L 15 8 98 8 7 77 2 Fl a t XL 2 6 40 1 8 0 10 0 7 8 1 1 1 7 8 75 6 0 4 6 9 4 7 6 13 8 9 1 1 0 6 8 3 4 2 16 / 2 0 - C L 16 5 10 0 5 2 78 3 Fl a t XL 2 6 40 1 9 5 10 2 7 3 1 1 3 7 3 81 9 0 4 7 7 6 6 6 21 6 9 1 1 0 9 0 0 3 2 16 / 2 0 - C L 17 2 10 2 2 5 79 4 Fl a t XL 2 6 40 1 9 5 10 4 6 8 1 1 5 6 8 81 9 0 4 8 5 8 5 6 27 8 3 4 1 1 1 7 8 6 6 16 / 2 0 - C L 16 6 10 3 9 0 80 5 Fl a t XL 2 6 40 1 9 5 10 6 6 3 1 1 7 6 3 81 9 0 4 9 4 0 4 6 33 5 3 2 1 1 5 1 3 9 8 16 / 2 0 - C L 16 0 10 5 5 0 81 6 Fl a t XL 2 6 40 1 9 5 10 8 5 8 1 1 9 5 8 81 9 0 5 0 2 2 3 6 38 8 3 1 1 1 9 0 2 2 9 16 / 2 0 - C L 15 4 10 7 0 4 82 7 Fl a t XL 2 6 40 1 8 5 11 0 4 3 1 2 1 4 3 77 7 0 5 1 0 0 0 6 41 5 2 8 1 2 3 1 7 5 6 16 / 2 0 - C L 14 1 10 8 4 5 83 8 Fl a t XL 2 6 40 1 7 0 11 2 1 3 1 2 3 1 3 71 4 0 5 1 7 1 4 6 42 1 8 7 1 2 7 3 9 4 3 16 / 2 0 - C L 12 6 10 9 7 1 84 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 11 2 2 8 1 2 3 2 8 63 0 5 1 7 7 7 6 0 1 2 7 3 9 4 3 1 5 10 9 8 6 85 0 Sp a c e r X L 2 6 40 15 11 2 4 3 1 2 3 4 3 63 0 5 1 8 4 0 6 0 1 2 7 3 9 4 3 1 5 11 0 0 1 86 0 Dr o p S t a g e 7 B a l l / C o l l e t F P 0 40 3 11 2 4 6 1 2 3 4 6 12 6 5 1 8 5 3 2 0 1 2 7 3 9 4 3 3 11 0 0 4 87 0 XL F l u s h ( D F I T ) XL 2 6 40 3 0 8 11 5 5 4 1 2 6 5 4 12 9 3 6 5 3 1 4 6 8 0 1 2 7 3 9 4 3 3 0 8 11 3 1 2 88 0 Sl o w f o r s e a t ( D F I T ) W F 2 6 18 50 11 6 0 4 1 2 7 0 4 21 0 0 5 3 3 5 6 8 0 1 2 7 3 9 4 3 5 0 1 1 3 6 2 89 DF I T F l u s h WF 2 6 40 23 0 1 1 8 3 4 1 2 9 3 4 96 6 0 5 4 3 2 2 8 23 0 1 1 5 9 2 90 30 0 0 f e e t M D + S u r f a c e E q m t FP 20 7 0 11 9 0 4 1 3 0 0 4 29 4 9 5 4 6 1 7 7 TO T A L S 13 0 0 4 54 6 1 7 7 12 7 3 9 4 3 We l l N a m e ND B i - 0 3 4 01 / 1 2 / 2 6 P r e l i m i n a r y D e s i g n ST A G E C O M M E N T S P U M P D I R T Y V O L U M E D I R T Y V O L U M E PR O P P A N T # T Y P E P P T R A T E S T A G E C U M ST A G E C U M ST A G E C U M S I Z E S t a g e C u m Pr e F r a c - N o n P r o p p a n t s t a g e s (B P M ) ( B B L ) ( B B L ) (G A L ) ( G A L ) (L B S ) ( L B S ) ( B B L ) (B B L ) a FP b WF 2 6 3. 5 40 40 16 8 0 16 8 0 40 40 0 40 c WF 2 6 3. 5 33 8 37 8 14 1 9 6 15 8 7 6 33 8 37 8 d P u m p C h e c k WF 26 4 0 10 0 47 8 42 0 0 20 0 7 6 10 0 47 8 0 4 7 8 PU M P D I R T Y V O L U M E D I R T Y V O L U M E PR O P P A N T CL E A N V O L U M S T A G E A V E R A G E F L U I D R A T E S T A G E C U M T O T J O B ST A G E C U M ST A G E C U M S i z e o r S t a g e C u m # P P A T Y P E ( B P M ) ( B B L ) ( B B L ) ( B B L ) (G A L ) ( G A L ) (L B S ) ( L B S ) T y p e ( B B L ) ( B B L ) 1 0 Li n e o u t X L X L 2 6 18 40 40 4 1 8 16 8 0 1 7 5 5 6 0 0 4 0 5 1 8 2 0 St a g e 7 P A D XL 2 6 40 4 5 0 49 0 8 6 8 18 9 0 0 3 6 4 5 6 00 16 / 2 0 - C L 45 0 9 6 8 3 1 Fl a t XL 2 6 40 1 6 5 65 5 1 0 3 3 69 3 0 4 3 3 8 6 66 3 6 6 6 3 6 16 / 2 0 - C L 15 8 1 1 2 6 4 2 Fl a t XL 2 6 40 1 8 0 83 5 1 2 1 3 75 6 0 5 0 9 4 6 13 8 9 1 2 0 5 2 7 16 / 2 0 - C L 16 5 1 2 9 1 5 3 Fl a t XL 2 6 40 1 9 5 10 3 0 1 4 0 8 81 9 0 5 9 1 3 6 21 6 9 1 4 2 2 1 8 16 / 2 0 - C L 17 2 1 4 6 4 6 4 Fl a t XL 2 6 40 1 9 5 12 2 5 1 6 0 3 81 9 0 6 7 3 2 6 27 8 3 4 7 0 0 5 1 16 / 2 0 - C L 16 6 1 6 2 9 7 5 Fl a t XL 2 6 40 1 9 5 14 2 0 1 7 9 8 81 9 0 7 5 5 1 6 33 5 3 2 1 0 3 5 8 3 16 / 2 0 - C L 16 0 1 7 8 9 8 6 Fl a t XL 2 6 40 1 9 5 16 1 5 1 9 9 3 81 9 0 8 3 7 0 6 38 8 3 1 1 4 2 4 1 4 16 / 2 0 - C L 15 4 1 9 4 3 9 7 Fl a t XL 2 6 40 1 8 5 18 0 0 2 1 7 8 77 7 0 9 1 4 7 6 41 5 2 8 1 8 3 9 4 1 16 / 2 0 - C L 14 1 2 0 8 4 10 8 Fl a t XL 2 6 40 1 7 0 19 7 0 2 3 4 8 71 4 0 9 8 6 1 6 42 1 8 7 2 2 6 1 2 8 16 / 2 0 - C L 12 6 2 2 1 0 11 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 19 8 5 2 3 6 3 63 0 9 9 2 4 6 0 2 2 6 1 2 8 1 5 2 2 2 5 12 0 Sp a c e r X L 2 6 40 15 20 0 0 2 3 7 8 63 0 9 9 8 7 6 0 2 2 6 1 2 8 1 5 2 2 4 0 13 0 Dr o p S t a g e 8 B a l l / C o l l e t F P 0 40 3 20 0 3 2 3 8 1 12 6 1 0 0 0 0 2 0 2 2 6 1 2 8 3 2 2 4 3 14 0 St a g e 8 P A D XL 2 6 40 2 9 9 23 0 2 2 6 8 0 12 5 5 8 1 1 2 5 6 0 0 2 2 6 1 2 8 2 9 9 2 5 4 2 15 0 Sl o w f o r S e a t X L 2 6 18 50 23 5 2 2 7 3 0 21 0 0 1 1 4 6 6 0 0 2 2 6 1 2 8 5 0 2 5 9 2 16 0 Re s u m e P a d XL 2 6 40 1 0 1 24 5 3 2 8 3 1 42 4 2 1 1 8 9 0 2 0 2 2 6 1 2 8 1 0 1 2 6 9 3 17 1 Fl a t XL 2 6 40 1 6 5 26 1 8 2 9 9 6 69 3 0 1 2 5 8 3 2 66 3 6 2 3 2 7 6 4 16 / 2 0 - C L 15 8 2 8 5 1 18 2 Fl a t XL 2 6 40 1 8 0 27 9 8 3 1 7 6 75 6 0 1 3 3 3 9 2 13 8 9 1 2 4 6 6 5 5 16 / 2 0 - C L 16 5 3 0 1 6 19 3 Fl a t XL 2 6 40 1 9 5 29 9 3 3 3 7 1 81 9 0 1 4 1 5 8 2 21 6 9 1 2 6 8 3 4 6 16 / 2 0 - C L 17 2 3 1 8 8 20 4 Fl a t XL 2 6 40 1 9 5 31 8 8 3 5 6 6 81 9 0 1 4 9 7 7 2 27 8 3 4 2 9 6 1 8 0 16 / 2 0 - C L 16 6 3 3 5 4 21 5 Fl a t XL 2 6 40 1 9 5 33 8 3 3 7 6 1 81 9 0 1 5 7 9 6 2 33 5 3 2 3 2 9 7 1 1 16 / 2 0 - C L 16 0 3 5 1 4 22 6 Fl a t XL 2 6 40 1 9 5 35 7 8 3 9 5 6 81 9 0 1 6 6 1 5 2 38 8 3 1 3 6 8 5 4 2 16 / 2 0 - C L 15 4 3 6 6 8 23 7 Fl a t XL 2 6 40 1 8 5 37 6 3 4 1 4 1 77 7 0 1 7 3 9 2 2 41 5 2 8 4 1 0 0 6 9 16 / 2 0 - C L 14 1 3 8 0 9 24 8 Fl a t XL 2 6 40 1 7 0 39 3 3 4 3 1 1 71 4 0 1 8 1 0 6 2 42 1 8 7 4 5 2 2 5 6 16 / 2 0 - C L 12 6 3 9 3 5 25 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 39 4 8 4 3 2 6 63 0 1 8 1 6 9 2 0 4 5 2 2 5 6 1 5 3 9 5 0 26 0 Sp a c e r X L 2 6 40 15 39 6 3 4 3 4 1 63 0 1 8 2 3 2 2 0 4 5 2 2 5 6 1 5 3 9 6 5 27 0 Dr o p S t a g e 9 B a l l / C o l l e t F P 0 40 3 39 6 6 4 3 4 4 12 6 1 8 2 4 4 8 0 4 5 2 2 5 6 3 3 9 6 8 28 0 St a g e 9 P A D XL 2 6 40 2 9 1 42 5 7 4 6 3 5 12 2 2 2 1 9 4 6 7 0 0 4 5 2 2 5 6 2 9 1 4 2 5 9 29 0 Sl o w f o r S e a t X L 2 6 18 50 43 0 7 4 6 8 5 21 0 0 1 9 6 7 7 0 0 4 5 2 2 5 6 5 0 4 3 0 9 30 0 Re s u m e P a d XL 2 6 40 1 0 9 44 1 6 4 7 9 4 45 7 8 2 0 1 3 4 8 0 4 5 2 2 5 6 1 0 9 4 4 1 8 31 1 Fl a t XL 2 6 40 1 6 5 45 8 1 4 9 5 9 69 3 0 2 0 8 2 7 8 66 3 6 4 5 8 8 9 3 16 / 2 0 - C L 15 8 4 5 7 6 32 2 Fl a t XL 2 6 40 1 8 0 47 6 1 5 1 3 9 75 6 0 2 1 5 8 3 8 13 8 9 1 4 7 2 7 8 3 16 / 2 0 - C L 16 5 4 7 4 1 33 3 Fl a t XL 2 6 40 1 9 5 49 5 6 5 3 3 4 81 9 0 2 2 4 0 2 8 21 6 9 1 4 9 4 4 7 4 16 / 2 0 - C L 17 2 4 9 1 3 St a g e t o " L i n e o u t X L " FL U I D Ne a t W a t e r CO M M E N T S En s u r e S t a g e 8 b a l l / c o l l e t i s l o a d e d Pr i m e a n d P r e s s u r e T e s t Op e n w e l l - D i s p l a c e P T D r o p B a l l a n d S D - 5 m i n Pu m p B a l l t o S e a t We l l N a m e ND B i - 0 3 4 01 / 1 2 / 2 6 P r e l i m i n a r y D e s i g n ST A G E C O M M E N T S P U M P D I R T Y V O L U M E D I R T Y V O L U M E PR O P P A N T # T Y P E P P T R A T E S T A G E C U M ST A G E C U M ST A G E C U M S I Z E S t a g e C u m Pr e F r a c - N o n P r o p p a n t s t a g e s (B P M ) ( B B L ) ( B B L ) (G A L ) ( G A L ) (L B S ) ( L B S ) ( B B L ) ( B B L ) FL U I D Ne a t W a t e r 34 4 Fl a t XL 2 6 40 1 9 5 51 5 1 5 5 2 9 81 9 0 2 3 2 2 1 8 27 8 3 4 5 2 2 3 0 8 16 / 2 0 - C L 16 6 5 0 7 9 35 5 Fl a t XL 2 6 40 1 9 5 53 4 6 5 7 2 4 81 9 0 2 4 0 4 0 8 33 5 3 2 5 5 5 8 3 9 16 / 2 0 - C L 16 0 5 2 3 8 36 6 Fl a t XL 2 6 40 1 9 5 55 4 1 5 9 1 9 81 9 0 2 4 8 5 9 8 38 8 3 1 5 9 4 6 7 0 16 / 2 0 - C L 15 4 5 3 9 3 37 7 Fl a t XL 2 6 40 1 8 5 57 2 6 6 1 0 4 77 7 0 2 5 6 3 6 8 41 5 2 8 6 3 6 1 9 8 16 / 2 0 - C L 14 1 5 5 3 4 38 8 Fl a t XL 2 6 40 1 7 0 58 9 6 6 2 7 4 71 4 0 2 6 3 5 0 8 42 1 8 7 6 7 8 3 8 4 16 / 2 0 - C L 12 6 5 6 5 9 39 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 59 1 1 6 2 8 9 63 0 2 6 4 1 3 8 0 6 7 8 3 8 4 1 5 5 6 7 4 40 0 Sp a c e r X L 2 6 40 15 59 2 6 6 3 0 4 63 0 2 6 4 7 6 8 0 6 7 8 3 8 4 1 5 5 6 8 9 41 0 Dr o p S t a g e 1 0 B a l l / C o l l e t F P 0 40 3 59 2 9 6 3 0 7 12 6 2 6 4 8 9 4 0 6 7 8 3 8 4 3 5 6 9 2 42 0 St a g e 1 0 P A D XL 2 6 40 2 8 2 62 1 1 6 5 8 9 11 8 4 4 2 7 6 7 3 8 0 6 7 8 3 8 4 2 8 2 5 9 7 4 43 0 Sl o w f o r S e a t X L 2 6 18 50 62 6 1 6 6 3 9 21 0 0 2 7 8 8 3 8 0 6 7 8 3 8 4 5 0 6 0 2 4 44 0 Re s u m e P a d XL 2 6 40 1 1 8 63 7 9 6 7 5 7 49 5 6 2 8 3 7 9 4 0 6 7 8 3 8 4 1 1 8 6 1 4 2 45 1 Fl a t XL 2 6 40 1 6 5 65 4 4 6 9 2 2 69 3 0 2 9 0 7 2 4 66 3 6 6 8 5 0 2 1 16 / 2 0 - C L 15 8 6 3 0 0 46 2 Fl a t XL 2 6 40 1 8 0 67 2 4 7 1 0 2 75 6 0 2 9 8 2 8 4 13 8 9 1 6 9 8 9 1 1 16 / 2 0 - C L 16 5 6 4 6 6 47 3 Fl a t XL 2 6 40 1 9 5 69 1 9 7 2 9 7 81 9 0 3 0 6 4 7 4 21 6 9 1 7 2 0 6 0 2 16 / 2 0 - C L 17 2 6 6 3 8 48 4 Fl a t XL 2 6 40 1 9 5 71 1 4 7 4 9 2 81 9 0 3 1 4 6 6 4 27 8 3 4 7 4 8 4 3 6 16 / 2 0 - C L 16 6 6 8 0 4 49 5 Fl a t XL 2 6 40 1 9 5 73 0 9 7 6 8 7 81 9 0 3 2 2 8 5 4 33 5 3 2 7 8 1 9 6 7 16 / 2 0 - C L 16 0 6 9 6 3 50 6 Fl a t XL 2 6 40 1 9 5 75 0 4 7 8 8 2 81 9 0 3 3 1 0 4 4 38 8 3 1 8 2 0 7 9 8 16 / 2 0 - C L 15 4 7 1 1 7 51 7 Fl a t XL 2 6 40 1 7 5 76 7 9 8 0 5 7 73 5 0 3 3 8 3 9 4 39 2 8 3 8 6 0 0 8 1 16 / 2 0 - C L 13 4 7 2 5 1 52 8 Fl a t XL 2 6 40 1 7 0 78 4 9 8 2 2 7 71 4 0 3 4 5 5 3 4 42 1 8 7 9 0 2 2 6 8 16 / 2 0 - C L 12 6 7 3 7 6 53 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 78 6 4 8 2 4 2 63 0 3 4 6 1 6 4 0 9 0 2 2 6 8 1 5 7 3 9 1 54 0 Sp a c e r X L 2 6 40 15 78 7 9 8 2 5 7 63 0 3 4 6 7 9 4 0 9 0 2 2 6 8 1 5 7 4 0 6 55 0 Dr o p S t a g e 1 1 B a l l / C o l l e t F P 0 40 3 78 8 2 8 2 6 0 12 6 3 4 6 9 2 0 0 9 0 2 2 6 8 3 7 4 0 9 56 0 St a g e 1 1 P A D XL 2 6 40 2 7 3 81 5 5 8 5 3 3 11 4 6 6 3 5 8 3 8 6 0 9 0 2 2 6 8 2 7 3 7 6 8 2 57 0 Sl o w f o r S e a t X L 2 6 18 50 82 0 5 8 5 8 3 21 0 0 3 6 0 4 8 6 0 9 0 2 2 6 8 5 0 7 7 3 2 58 0 Re s u m e P a d XL 2 6 40 1 5 2 83 5 7 8 7 3 5 63 8 4 3 6 6 8 7 0 0 9 0 2 2 6 8 1 5 2 7 8 8 4 59 1 Fl a t XL 2 6 40 1 7 0 85 2 7 8 9 0 5 71 4 0 3 7 4 0 1 0 68 3 7 9 0 9 1 0 5 16 / 2 0 - C L 16 3 8 0 4 7 60 2 Fl a t XL 2 6 40 2 0 0 87 2 7 9 1 0 5 84 0 0 3 8 2 4 1 0 15 4 3 4 9 2 4 5 3 9 16 / 2 0 - C L 18 4 8 2 3 1 61 3 Fl a t XL 2 6 40 2 2 0 89 4 7 9 3 2 5 92 4 0 3 9 1 6 5 0 24 4 7 2 9 4 9 0 1 1 16 / 2 0 - C L 19 4 8 4 2 5 62 4 Fl a t XL 2 6 40 2 2 0 91 6 7 9 5 4 5 92 4 0 4 0 0 8 9 0 31 4 0 2 9 8 0 4 1 3 16 / 2 0 - C L 18 7 8 6 1 2 63 5 Fl a t XL 2 6 40 2 2 0 93 8 7 9 7 6 5 92 4 0 4 1 0 1 3 0 37 8 3 0 1 0 1 8 2 4 3 16 / 2 0 - C L 18 0 8 7 9 2 64 6 Fl a t XL 2 6 40 2 2 0 96 0 7 9 9 8 5 92 4 0 4 1 9 3 7 0 43 8 0 9 1 0 6 2 0 5 2 16 / 2 0 - C L 17 4 8 9 6 6 65 7 Fl a t XL 2 6 40 1 9 0 97 9 7 1 0 1 7 5 79 8 0 4 2 7 3 5 0 42 6 5 0 1 1 0 4 7 0 2 16 / 2 0 - C L 14 5 9 1 1 1 66 8 Fl a t XL 2 6 40 1 7 0 99 6 7 1 0 3 4 5 71 4 0 4 3 4 4 9 0 42 1 8 7 1 1 4 6 8 8 9 16 / 2 0 - C L 12 6 9 2 3 7 67 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 99 8 2 1 0 3 6 0 63 0 4 3 5 1 2 0 0 1 1 4 6 8 8 9 1 5 9 2 5 2 68 0 Sp a c e r X L 2 6 40 15 99 9 7 1 0 3 7 5 63 0 4 3 5 7 5 0 0 1 1 4 6 8 8 9 1 5 9 2 6 7 69 0 Dr o p S t a g e 1 2 B a l l / C o l l e t F P 0 40 3 10 0 0 0 1 0 3 7 8 12 6 4 3 5 8 7 6 0 1 1 4 6 8 8 9 3 9 2 7 0 70 0 St a g e 1 2 P A D XL 2 6 40 2 6 4 10 2 6 4 1 0 6 4 2 11 0 8 8 4 4 6 9 6 4 0 1 1 4 6 8 8 9 2 6 4 9 5 3 4 71 0 Sl o w f o r S e a t X L 2 6 18 50 10 3 1 4 1 0 6 9 2 21 0 0 4 4 9 0 6 4 0 1 1 4 6 8 8 9 5 0 9 5 8 4 72 0 Re s u m e P a d XL 2 6 40 1 1 1 10 4 2 5 1 0 8 0 3 46 6 2 4 5 3 7 2 6 0 1 1 4 6 8 8 9 1 1 1 9 6 9 5 73 1 Fl a t XL 2 6 40 2 0 0 10 6 2 5 1 1 0 0 3 84 0 0 4 6 2 1 2 6 80 4 4 1 1 5 4 9 3 3 16 / 2 0 - C L 19 2 9 8 8 6 74 2 Fl a t XL 2 6 40 2 2 5 10 8 5 0 1 1 2 2 8 94 5 0 4 7 1 5 7 6 17 3 6 3 1 1 7 2 2 9 7 16 / 2 0 - C L 20 7 1 0 0 9 3 75 4 Fl a t XL 2 6 40 2 7 5 11 1 2 5 1 1 5 0 3 11 5 5 0 4 8 3 1 2 6 39 2 5 3 1 2 1 1 5 4 9 16 / 2 0 - C L 23 4 1 0 3 2 7 76 6 Fl a t XL 2 6 40 2 6 0 11 3 8 5 1 1 7 6 3 10 9 2 0 4 9 4 0 4 6 51 7 7 5 1 2 6 3 3 2 4 16 / 2 0 - C L 20 5 1 0 5 3 2 We l l N a m e ND B i - 0 3 4 01 / 1 2 / 2 6 P r e l i m i n a r y D e s i g n ST A G E C O M M E N T S P U M P D I R T Y V O L U M E D I R T Y V O L U M E PR O P P A N T # T Y P E P P T R A T E S T A G E C U M ST A G E C U M ST A G E C U M S I Z E S t a g e C u m Pr e F r a c - N o n P r o p p a n t s t a g e s (B P M ) ( B B L ) ( B B L ) (G A L ) ( G A L ) (L B S ) ( L B S ) ( B B L ) ( B B L ) FL U I D Ne a t W a t e r 77 8 Fl a t XL 2 6 40 2 4 0 11 6 2 5 1 2 0 0 3 10 0 8 0 5 0 4 1 2 6 59 5 5 8 1 3 2 2 8 8 1 16 / 2 0 - C L 17 7 1 0 7 0 9 78 10 Fl a t XL 2 6 40 2 0 0 11 8 2 5 1 2 2 0 3 84 0 0 5 1 2 5 2 6 58 2 3 3 1 3 8 1 1 1 4 16 / 2 0 - C L 13 9 10 8 4 8 79 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 11 8 4 0 1 2 2 1 8 63 0 5 1 3 1 5 6 0 1 3 8 1 1 1 4 1 5 10 8 6 3 80 0 Sp a c e r X L 2 6 40 15 11 8 5 5 1 2 2 3 3 63 0 5 1 3 7 8 6 0 1 3 8 1 1 1 4 1 5 10 8 7 8 81 0 Dr o p S t a g e 1 3 B a l l / C o l l e t F P 0 40 3 11 8 5 8 1 2 2 3 6 12 6 5 1 3 9 1 2 0 1 3 8 1 1 1 4 3 10 8 8 1 82 0 XL F l u s h ( D F I T ) XL 2 6 40 2 5 5 12 1 1 3 1 2 4 9 1 10 7 1 0 5 2 4 6 2 2 0 1 3 8 1 1 1 4 2 5 5 11 1 3 6 83 0 Sl o w f o r s e a t ( D F I T ) X L 2 6 18 50 12 1 6 3 1 2 5 4 1 21 0 0 5 2 6 7 2 2 0 1 3 8 1 1 1 4 5 0 1 1 1 8 6 84 DF I T F l u s h WF 2 6 40 23 0 1 2 3 9 3 1 2 7 7 1 96 6 0 5 3 8 9 0 2 23 0 1 1 4 1 6 85 30 0 0 f e e t M D + S u r f a c e E q m t FP 20 7 0 12 4 6 3 1 2 8 4 1 29 4 9 5 4 1 8 5 1 TO T A L S 12 9 0 1 54 1 8 5 1 13 8 1 1 1 4 We l l N a m e ND B i - 0 3 4 01 / 1 2 / 2 6 P r e l i m i n a r y D e s i g n ST A G E C O M M E N T S P U M P D I R T Y V O L U M E D I R T Y V O L U M E PR O P P A N T # T Y P E P P T R A T E S T A G E C U M ST A G E C U M ST A G E C U M S I Z E S t a g e C u m Pr e F r a c - N o n P r o p p a n t s t a g e s (B P M ) ( B B L ) ( B B L ) (G A L ) ( G A L ) (L B S ) ( L B S ) ( B B L ) (B B L ) a FP b WF 2 6 4 40 40 16 8 0 16 8 0 40 40 c WF 2 6 3. 5 28 5 32 5 11 9 7 0 13 6 5 0 28 5 32 5 d P u m p C h e c k WF 26 4 10 0 42 5 42 0 0 17 8 5 0 10 0 42 5 0 4 2 5 PU M P D I R T Y V O L U M E D I R T Y V O L U M E PR O P P A N T CL E A N V O L U M S T A G E A V E R A G E F L U I D R A T E S T A G E C U M T O T J O B ST A G E C U M ST A G E C U M S i z e o r S t a g e C u m # P P A T Y P E ( B P M ) ( B B L ) ( B B L ) ( B B L ) (G A L ) ( G A L ) (L B S ) ( L B S ) T y p e ( B B L ) ( B B L ) 1 0 Li n e o u t X L X L 2 6 18 40 40 4 6 5 16 8 0 1 9 5 3 0 0 0 4 0 4 6 5 2 0 St a g e 1 3 P A D XL 2 6 40 4 2 5 46 5 8 9 0 17 8 5 0 3 7 3 8 0 00 16 / 2 0 - C L 42 5 8 9 0 3 1 Fl a t XL 2 6 40 2 0 0 66 5 1 0 9 0 84 0 0 4 5 7 8 0 80 4 4 8 0 4 4 16 / 2 0 - C L 19 2 1 0 8 2 4 2 Fl a t XL 2 6 40 2 2 5 89 0 1 3 1 5 94 5 0 5 5 2 3 0 17 3 6 3 2 5 4 0 7 16 / 2 0 - C L 20 7 1 2 8 8 5 4 Fl a t XL 2 6 40 2 7 5 11 6 5 1 5 9 0 11 5 5 0 6 6 7 8 0 39 2 5 3 6 4 6 6 0 16 / 2 0 - C L 23 4 1 5 2 2 6 6 Fl a t XL 2 6 40 2 6 0 14 2 5 1 8 5 0 10 9 2 0 7 7 7 0 0 51 7 7 5 1 1 6 4 3 5 16 / 2 0 - C L 20 5 1 7 2 7 7 8 Fl a t XL 2 6 40 2 4 0 16 6 5 2 0 9 0 10 0 8 0 8 7 7 8 0 59 5 5 8 1 7 5 9 9 2 16 / 2 0 - C L 17 7 1 9 0 5 8 10 Fl a t XL 2 6 40 2 0 0 18 6 5 2 2 9 0 84 0 0 9 6 1 8 0 58 2 3 3 2 3 4 2 2 5 16 / 2 0 - C L 13 9 2 0 4 3 9 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 18 8 0 2 3 0 5 63 0 9 6 8 1 0 0 2 3 4 2 2 5 1 5 2 0 5 8 10 0 Sp a c e r X L 2 6 40 15 18 9 5 2 3 2 0 63 0 9 7 4 4 0 0 2 3 4 2 2 5 1 5 2 0 7 3 11 0 Dr o p S t a g e 1 4 B a l l / C o l l e t F P 0 40 3 18 9 8 2 3 2 3 12 6 9 7 5 6 6 0 2 3 4 2 2 5 3 2 0 7 6 12 0 St a g e 1 4 P A D XL 2 6 40 2 4 6 21 4 4 2 5 6 9 10 3 3 2 1 0 7 8 9 8 0 2 3 4 2 2 5 2 4 6 2 3 2 2 13 0 Sl o w f o r S e a t X L 2 6 18 50 21 9 4 2 6 1 9 21 0 0 1 0 9 9 9 8 0 2 3 4 2 2 5 5 0 2 3 7 2 14 0 Re s u m e P a d XL 2 6 40 8 9 22 8 3 2 7 0 8 37 3 8 1 1 3 7 3 6 0 2 3 4 2 2 5 8 9 2 4 6 1 15 1 Fl a t XL 2 6 40 1 9 0 24 7 3 2 8 9 8 79 8 0 1 2 1 7 1 6 76 4 2 2 4 1 8 6 7 16 / 2 0 - C L 18 2 2 6 4 3 16 3 Fl a t XL 2 6 40 2 1 5 26 8 8 3 1 1 3 90 3 0 1 3 0 7 4 6 23 9 1 5 2 6 5 7 8 3 16 / 2 0 - C L 19 0 2 8 3 3 17 5 Fl a t XL 2 6 40 2 4 0 29 2 8 3 3 5 3 10 0 8 0 1 4 0 8 2 6 41 2 7 0 3 0 7 0 5 2 16 / 2 0 - C L 19 7 3 0 3 0 18 7 Fl a t XL 2 6 40 2 4 0 31 6 8 3 5 9 3 10 0 8 0 1 5 0 9 0 6 53 8 7 4 3 6 0 9 2 6 16 / 2 0 - C L 18 3 3 2 1 3 19 9 Fl a t XL 2 6 40 2 2 0 33 8 8 3 8 1 3 92 4 0 1 6 0 1 4 6 59 4 7 5 4 2 0 4 0 1 16 / 2 0 - C L 15 7 3 3 7 0 20 10 Fl a t XL 2 6 40 1 9 0 35 7 8 4 0 0 3 79 8 0 1 6 8 1 2 6 55 3 2 1 4 7 5 7 2 2 16 / 2 0 - C L 13 2 3 5 0 2 21 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 35 9 3 4 0 1 8 63 0 1 6 8 7 5 6 0 4 7 5 7 2 2 1 5 3 5 1 7 22 0 Sp a c e r X L 2 6 40 15 36 0 8 4 0 3 3 63 0 1 6 9 3 8 6 0 4 7 5 7 2 2 1 5 3 5 3 2 23 0 Dr o p S t a g e 1 5 B a l l / C o l l e t F P 0 40 3 36 1 1 4 0 3 6 12 6 1 6 9 5 1 2 0 4 7 5 7 2 2 3 3 5 3 5 24 0 St a g e 1 5 P A D XL 2 6 40 2 3 7 38 4 8 4 2 7 3 99 5 4 1 7 9 4 6 6 0 4 7 5 7 2 2 2 3 7 3 7 7 2 25 0 Sl o w f o r S e a t X L 2 6 18 50 38 9 8 4 3 2 3 21 0 0 1 8 1 5 6 6 0 4 7 5 7 2 2 5 0 3 8 2 2 26 0 Re s u m e P a d XL 2 6 40 9 8 39 9 6 4 4 2 1 41 1 6 1 8 5 6 8 2 0 4 7 5 7 2 2 9 8 3 9 2 0 27 1 Fl a t XL 2 6 40 1 9 0 41 8 6 4 6 1 1 79 8 0 1 9 3 6 6 2 76 4 2 4 8 3 3 6 4 16 / 2 0 - C L 18 2 4 1 0 2 28 3 Fl a t XL 2 6 40 2 1 5 44 0 1 4 8 2 6 90 3 0 2 0 2 6 9 2 23 9 1 5 5 0 7 2 8 0 16 / 2 0 - C L 19 0 4 2 9 2 29 5 Fl a t XL 2 6 40 2 4 0 46 4 1 5 0 6 6 10 0 8 0 2 1 2 7 7 2 41 2 7 0 5 4 8 5 4 9 16 / 2 0 - C L 19 7 4 4 8 8 30 7 Fl a t XL 2 6 40 2 4 0 48 8 1 5 3 0 6 10 0 8 0 2 2 2 8 5 2 53 8 7 4 6 0 2 4 2 3 16 / 2 0 - C L 18 3 4 6 7 1 31 9 Fl a t XL 2 6 40 2 2 0 51 0 1 5 5 2 6 92 4 0 2 3 2 0 9 2 59 4 7 5 6 6 1 8 9 8 16 / 2 0 - C L 15 7 4 8 2 9 32 10 Fl a t XL 2 6 40 1 9 0 52 9 1 5 7 1 6 79 8 0 2 4 0 0 7 2 55 3 2 1 7 1 7 2 1 9 16 / 2 0 - C L 13 2 4 9 6 0 33 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 53 0 6 5 7 3 1 63 0 2 4 0 7 0 2 0 7 1 7 2 1 9 1 5 4 9 7 5 34 0 Sp a c e r X L 2 6 40 15 53 2 1 5 7 4 6 63 0 2 4 1 3 3 2 0 7 1 7 2 1 9 1 5 4 9 9 0 St a g e t o " L i n e o u t X L " FL U I D Ne a t W a t e r CO M M E N T S En s u r e S t a g e 1 4 b a l l / c o l l e t i s l o a d e d Pr i m e a n d P r e s s u r e T e s t Di s p l a c e P T - S D 5 M i n Pu m p B a l l t o S e a t We l l N a m e ND B i - 0 3 4 01 / 1 2 / 2 6 P r e l i m i n a r y D e s i g n ST A G E C O M M E N T S P U M P D I R T Y V O L U M E D I R T Y V O L U M E PR O P P A N T # T Y P E P P T R A T E S T A G E C U M ST A G E C U M ST A G E C U M S I Z E S t a g e C u m Pr e F r a c - N o n P r o p p a n t s t a g e s (B P M ) ( B B L ) ( B B L ) (G A L ) ( G A L ) (L B S ) ( L B S ) ( B B L ) ( B B L ) FL U I D Ne a t W a t e r 35 0 Dr o p S t a g e 1 6 B a l l / C o l l e t F P 0 40 3 53 2 4 5 7 4 9 12 6 2 4 1 4 5 8 0 7 1 7 2 1 9 3 4 9 9 3 36 0 St a g e 1 6 P A D XL 2 6 40 2 2 8 55 5 2 5 9 7 7 95 7 6 2 5 1 0 3 4 0 7 1 7 2 1 9 2 2 8 52 2 1 37 0 Sl o w f o r S e a t X L 2 6 18 50 56 0 2 6 0 2 7 21 0 0 2 5 3 1 3 4 0 7 1 7 2 1 9 5 0 52 7 1 38 0 Re s u m e P a d XL 2 6 40 1 0 7 57 0 9 6 1 3 4 44 9 4 2 5 7 6 2 8 0 7 1 7 2 1 9 1 0 7 53 7 8 39 1 Fl a t XL 2 6 40 1 9 0 58 9 9 6 3 2 4 79 8 0 2 6 5 6 0 8 76 4 2 7 2 4 8 6 1 16 / 2 0 - C L 18 2 55 6 0 40 3 Fl a t XL 2 6 40 2 1 5 61 1 4 6 5 3 9 90 3 0 2 7 4 6 3 8 23 9 1 5 7 4 8 7 7 7 16 / 2 0 - C L 19 0 57 5 0 41 5 Fl a t XL 2 6 40 2 4 0 63 5 4 6 7 7 9 10 0 8 0 2 8 4 7 1 8 41 2 7 0 7 9 0 0 4 6 16 / 2 0 - C L 19 7 59 4 7 42 7 Fl a t XL 2 6 40 2 4 0 65 9 4 7 0 1 9 10 0 8 0 2 9 4 7 9 8 53 8 7 4 8 4 3 9 2 0 16 / 2 0 - C L 18 3 61 3 0 43 9 Fl a t XL 2 6 40 2 2 0 68 1 4 7 2 3 9 92 4 0 3 0 4 0 3 8 59 4 7 5 9 0 3 3 9 5 16 / 2 0 - C L 15 7 62 8 7 44 10 Fl a t XL 2 6 40 1 9 0 70 0 4 7 4 2 9 79 8 0 3 1 2 0 1 8 55 3 2 1 9 5 8 7 1 6 16 / 2 0 - C L 13 2 6 4 1 9 45 0 XL F l u s h XL 26 40 10 7 0 1 4 7 4 3 9 42 0 3 1 0 7 5 8 10 6 4 2 9 46 0 LG F l u s h WF 26 40 17 8 7 1 9 2 7 6 1 7 74 7 6 3 1 8 2 3 4 17 8 6 6 0 7 47 30 0 0 f e e t M D + S u r f a c e E q m t FP 20 7 0 72 6 2 7 6 8 7 29 4 9 3 2 1 1 8 3 TO T A L S 76 4 7 32 1 1 8 3 95 8 7 1 6 Up d a t e d 1 / 1 3 / 2 0 2 5 1/ 1 3 / 2 0 2 6 TB D AK T S C A S t a t u s No r t h S l o p e TB D Pr e TB D TB D TB D Tr a d e N a m e S u p p l i e r P u r p o s e I n g r e d i e n t s N a m e C A S # Pe r c e n t a g e b y Ma s s o f In g r e d i e n t Pe r c e n t o f I n g r e d i e n t in T o t a l M a s s Pu m p e d Ma s s o f I n g r e d i e n t (l b s ) SM E Tr a c e r c o Ca r r i e r F l u i d So y M e t h y l E s t e r 67 7 8 4 - 8 0 - 9 10 0 #V A L U E ! 16 4 . 9 0 5 5 7 6 0 0 0 0 T- 1 6 0 C Tr a c e r c o Ch e m i c a l T r a c e r 2, 4 , 6 - T r i b r o m o t o l u e n e 63 2 0 - 4 0 - 7 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 1 6 2 A Tr a c e r c o Ch e m i c a l T r a c e r 1, 4 - D i b r o m o b e n z e n e 10 6 - 3 7 - 6 10 0 #V A L U E ! 1. 1 0 2 3 1 0 0 0 0 0 T- 1 6 3 A Tr a c e r c o Ch e m i c a l T r a c e r 1, 4 - D i i o d o b e n z e 62 4 - 3 8 - 4 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 1 6 4 B Tr a c e r c o Ch e m i c a l T r a c e r 2- B r o m o n a p h t h a l e n e 58 0 - 1 3 - 2 10 0 #V A L U E ! 1. 1 0 2 3 1 0 0 0 0 0 T- 7 2 0 Tr a c e r c o Ch e m i c a l T r a c e r 1, 2 , 4 , 5 - T e t r a b r o m o b e n z e n e 63 6 - 2 8 - 2 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 7 1 9 Tr a c e r c o Ch e m i c a l T r a c e r 3, 4 - D i c h l o r o b e n z o p h e n o n e 62 8 4 - 7 9 - 3 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 7 5 8 Tr a c e r c o Ch e m i c a l T r a c e r 3, 4 - D i f l u o r o b e n z o p h e n o n e 85 1 1 8 - 0 7 - 6 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 7 1 2 Tr a c e r c o Ch e m i c a l T r a c e r 1, 2 , 3 - T r i c h l o r o b e n z e n e 87 - 6 1 - 6 10 0 #V A L U E ! 2. 2 0 4 6 2 0 0 0 0 0 T- 7 8 4 Tr a c e r c o Ch e m i c a l T r a c e r 2, 4 , 6 - T r i b r o m o a n i s o l e 60 7 - 9 9 - 8 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 7 7 6 Tr a c e r c o Ch e m i c a l T r a c e r 1, 4 - D i b r o m o n a p h t h a l e n e 83 - 5 3 - 4 10 0 #V A L U E ! 0. 6 6 1 3 8 6 0 0 0 0 T- 7 5 7 Tr a c e r c o Ch e m i c a l T r a c e r 3, 3 ' - D i f l u o r o b e n z o p h e n o n e 34 5 - 7 0 - 0 10 0 #V A L U E ! 0. 6 6 1 3 8 6 0 0 0 0 T- 7 2 1 Tr a c e r c o Ch e m i c a l T r a c e r 4, 4 ' - D i c h l o r o b e n z o p h e n o n e 90 - 9 8 - 2 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 7 3 4 Tr a c e r c o Ch e m i c a l T r a c e r 1- B r o m o - 2 - ( t r i f l u o r o m e t h y l ) b e n z e n e 39 2 - 8 3 - 6 10 0 #V A L U E ! 0. 6 6 1 3 8 6 0 0 0 0 T- 7 5 0 Tr a c e r c o Ch e m i c a l T r a c e r 1, 4 - D i b r o m o - 2 - f l u o r o b e n z e n e 14 3 5 - 5 2 - 5 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 7 5 1 Tr a c e r c o Ch e m i c a l T r a c e r Bi s ( 4 - b r o m o p h e n y l ) e t h e r 20 5 0 - 4 7 - 7 10 0 #V A L U E ! 1. 5 4 3 2 3 4 0 0 0 0 T- 1 6 6 A Tr a c e r c o Ch e m i c a l T r a c e r 5- I o d o - m - x y l e n e 22 4 4 5 - 4 1 - 6 10 0 #V A L U E ! 1. 1 0 2 3 1 0 0 0 0 0 Wa t e r Tr a c e r c o Ca r r i e r F l u i d Wa t e r 77 3 2 - 1 8 - 5 10 0 #V A L U E ! 13 4 . 8 2 9 0 1 8 0 0 0 0 T- 1 4 0 c Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 4 - F l u o r o b e n z o a t e 49 9 - 9 0 - 1 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 5 8 a Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 2 , 4 - D i f l u o r o b e n z o a t e 17 6 5 - 0 8 - 8 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 5 8 b Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 2 , 5 - D i f l u o r o b e n z o a t e 52 2 6 5 1 - 4 2 - 9 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 5 8 e Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 3 , 5 - D i f l u o r o b e n z o a t e 53 0 1 4 1 - 3 9 - 0 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 7 6 a Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 2 , 3 , 4 - t r i f l u o r o b e n z o a t e 40 2 9 5 5 - 4 1 - 3 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 7 6 b Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 2 , 3 , 6 - t r i f l u o r o b e n z o a t e 18 0 3 8 4 5 - 0 7 - 9 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 7 6 c Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 2 , 4 , 5 - t r i f l u o r o b e n z o a t e 52 2 6 5 1 - 4 8 - 5 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 8 0 1 Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 2 - c h l o r o b e n z o a t e 17 2 6 4 - 7 4 - 3 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 8 0 3 Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 4 - c h l o r o b e n z o a t e 36 8 6 - 6 6 - 6 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 8 0 4 Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 2 , 3 - d i c h l o r o b e n z o a t e 11 8 5 3 7 - 8 4 - 1 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 8 0 5 Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 2 , 4 - D i c h l o r o b e n z o a t e 38 4 0 2 - 1 1 - 8 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 8 0 6 Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 2 , 5 - d i c h l o r o b e n z o a t e 63 8 9 1 - 9 8 - 5 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 8 0 8 Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 3 , 4 - d i c h l o r o b e n z o a t e 17 2 7 4 - 1 0 - 1 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 8 0 9 Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 3 , 5 - d i c h l o r o b e n z o a t e 15 4 8 6 2 - 4 0 - 5 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 1 1 Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 2 - c h l o r o - 4 - f l u o r o b e n z o a t e 88 5 4 7 1 - 4 3 - 1 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 1 2 Tr a c e r c o Ch e m i c a l T r a c e r So d i u m - 2 - c h l o r o - 5 - f l u o r o b e n z o a t e 13 8 2 1 0 6 - 7 9 - 7 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 Re p o r t T y p e ( P r e o r P o s t J o b ) To t a l W a t e r V o l u m e ( g a l ) : Wa t e r M a s s F r a c t i o n To t a l M a s s P u m p e d ( l b s ) Co u n t y : AP I N u m b e r : Op e r a t o r N a m e : O i l S e a r c h A l a s k a , L L C We l l N a m e a n d N u m b e r : N D B i - 0 3 4 Hy d r a u l i c F r a c t u r i n g F l u i d P r o d u c t C o m p o n e n t I n f o r m a t i o n D i s c l o s u r e Ma n u f a c t u r e r C o n t a c t T r a c e r c o 4 1 0 6 N e w W e s t D r . P a s a d e n a T e x a s 7 7 5 0 7 T e l : 2 8 1 - 2 9 1 - 7 7 6 9 Fr a c t u r e D a t e St a t e : Ap p r o v e d F o r T r a c e r c o Additive Additive Description D206 Antifoam Agent 0.0 Gal/mGal 10 gal F103 Surfactant 1.0 Gal/mGal 1,227.0 gal J450 Stabilizing Agent 0.5 Gal/mGal 562.0 gal J475 Breaker J475 6.0 lb/mGal 7,360.0 lbm J511 Stabilizing Agent 1.8 lb/mGal 2,248.0 lbm J532 Crosslinker 2.3 Gal/mGal 2,809.0 gal J580 Gel J580 26.0 lb/mGal 31,894.0 lbm J753 Enzyme Breaker J753 0.1 Gal/mGal 84.0 gal M002 Additive 0.0 lb/mGal 2 lbm M117 Clay Control Agent 333.3 lb/mGal 408,898.0 lbm M275 Bactericide 0.3 lb/mGal 396.0 lbm S522-1620 Propping Agent varied concentrations 3,616,519.0 lbm ~ 70 % ~ 27 % ~ 3 % < 1 % < 1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.01 % < 0.01 % < 0.01 % < 0.01 % < 0.01 % < 0.001 % < 0.001 % < 0.001 % < 0.001 % < 0.001 % < 0.001 % < 0.001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % < 0.00001 % 100 % 9000-90-2 Amylase, alpha Total * Mix water is supplied by the client. Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. * The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRC - Chemicals as of the date of the document was produced. Any new updates will not be reflected in this document. 7632-00-0 Sodium nitrite 533-74-4 Tetrahydro-3,5-dimethyl-1,3,5-thiadiazine-2-thione 2634-33-5 1,2-benzisothiazolin-3-one 9005-65-6 Sorbitan monooleate, ethoxylated 11138-66-2 Xanthan Gum 9004-32-4 Sodium carboxymethylcellulose 36089-45-9 2-Propenoic acid, 2-ethylhexyl ester, polymer with 2-hydroxyethyl 2-propenoate 68937-55-3 Siloxanes and Silicones, di-Me, 3-hydroxypropyl Me, ethoxylated propoxylated 24634-61-5 Potassium (E,E)-hexa-2,4-dienoate 64-19-7 Acetic acid (impurity) 1310-73-2 Sodium hydroxide 68308-89-4 Fatty acids, C18-unsatd., dimers, ethoxylated propoxylated 14464-46-1 Cristobalite 532-32-1 Sodium benzoate 1338-41-6 Sorbitan stearate 67762-90-7 Siloxanes and silicones, dimethyl, reaction products with silica 127-08-2 Acetic acid, potassium salt (impurity) 14808-60-7 Quartz, Crystalline silica 55965-84-9 5-chloro-2-methyl-4-isothiazolin-3-one and 2-methyl-4-isothiazolin-3-one 7786-30-3 Magnesium chloride 63148-62-9 Dimethyl siloxanes and silicones 14807-96-6 Magnesium silicate hydrate (talc) 9002-84-0 poly(tetrafluoroethylene) 111-42-2 2,2'-Iminodiethanol 112-42-5 1-undecanol (impurity) 7631-86-9 Silicon Dioxide (Impurity) 10377-60-3 Magnesium nitrate 68131-39-5 Ethoxylated Alcohol 37288-54-3 Beta-Mannanase 91053-39-3 Diatomaceous earth, calcined 111-76-2 2-butoxyethanol 34398-01-1 Ethoxylated C11 Alcohol 25038-72-6 Vinylidene chloride/methylacrylate copolymer 9003-35-4 Phenolic resin 50-70-4 Sorbitol 67-63-0 Propan-2-ol 56-81-5 1, 2, 3 - Propanetriol 102-71-6 2,2`,2"-nitrilotriethanol 1303-96-4 Sodium tetraborate decahydrate 68715-83-3 2-Butenedioic acid (2Z)-, polymer with sodium 2-propene-1-sulfonate 7647-14-5 Sodium chloride 7727-54-0 Diammonium peroxodisulphate 66402-68-4 Ceramic materials and wares, chemicals 7447-40-7 Potassium chloride 9000-30-0 Guar gum CAS Number Chemical Name Mass Fraction - Water (Including Mix Water Supplied by Client)* YF126ST:WF126 gal † Proprietary Technology The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. 1,226,694 Fluid Name & Volume Concentration Volume Disclosure Type: Pre-Job Well Completed: Date Prepared: 1/9/2026 State: Alaska County/Parish: North Slope Borough Case: Client: Oil Search Alaska Well: PIKKA NDBi-034 Basin/Field: Pikka # SLB-Private Page: 1 / 1 Hydraulic Fracturing Chemical Information Disclosure Supplier: Patina Energy 20 Kg Patina Copper Flow Insurance Proprietary chemical information on ﬁle supplied by Patina Energy to the AOGCC. Attachment G NDBi-034 Well Clean Up Summary Flow Periods Flowback Period Duration (hours)Purpose/Remarks Ramp Up 72-96 Bring well on slowly (16/64th) via adjustable choke, change as necessary to achieve stable flow. Monitor returns for proppant and adjust choke as necessary to avoid damage to reservoir proppant pack and minimize surface equipment erosion. Santos Subsurface Team will advise choke changes/rates during ramp up period. Clean Up 48+ Continue clean up period until there is a meaningful decline in solids volume to surface in combination with 2-3% WC. See Chart 1. Step Down 48-72 Measure well productivity and inflow performance. Build Up 240-336 Goal to identify linear-flow period after 10 hours. Table 1 Chart 1 Per regulation 20 AAC 25.235 (d) 6, Santos is requesting AOGCC permission to flare the produced gas for the duration of the development well flowback work. Total volume of gas per the flowback program outlined in Table 1 is approximately 15 MMscf. Well Flowback - Operational Summary: x Total flowback volume (including ramp up, clean up and step down periods) not to exceed 2.0X TLTR (total load to recover) from the frac job. Santos to contact AOGCC when 1.5X TLTR is recovered and provide update on solids content and WC. If necessary, additional flowback volume exceeding 2.0X TLTR may be approved if both parties agree after reviewing actual flowback data. x Target Clean Up Flow Rate: 4500 BPD & 2.2 mmscf/d. x Choke Setting: Use adjustable choke to achieve a flow rate at approximately 100 psi per hour drawdown or until well is stable. Watch BS&W and adjust drawdown rate as needed. The Santos Subsurface Team or Santos Well Test Supervisor will advise choke changes based on well performance and solids production. x Proppant Production: Proppant production is expected and will be managed by bringing on the well slowly and beaning up choke based on well performance and bottoms up solids production. x Annulus Pressure: The annulus pressure is expected to increase due to thermal expansion. The maximum annular pressure is 2,000 psi, bleed down as necessary. x Sampling: Per Surface Sampling Program below in Table 2. Metering Standard Fluid Rates & Volumes - Tank Straps will be used for all reported fluid rates & volumes, in addition there will be turbine meters on the oil and water legs of the separator for reference. Gas Rates & Volumes - A micromotion Coriolis flow meter will be used for gas rates & volumes. Table 2 g Attachment H NDBi-034 4-1/2” Production Liner Section Summary Procedure: 1. Run 4-1/2” 12.6 ppf P-110S TSH563 lower completions per tally. 2. Drop 1.125” phenolic ball during circulation to close WIV collar. 3. Pressure up to close the WIV at 1,485 psi. 4. Continue increasing pressure to start setting the liner hanger/packer at 2,500 psi. 5. Set the openhole packers and neutralize pusher tool to 4,300 psi. 6. Before releasing, pressure test the IA to top liner hanger/packer to 3,500 psi for 10 min and passed. 7. Release running tool from liner hanger. 8. Circulate viscosified brine. 9. Flow check for 10 minutes. 10.POOH with liner hanger running tool. 11.Prepare to run upper completion. NDBi-034 4-1/2” Upper Completion Section Summary Procedure: 12.Run 4-1/2” 12.6 ppf P110S TSH563 tubing and downhole jewellery. 13.Circulate out the OBM from liner top to surface with 9.2 ppg NaCl Brine. 14.Land tubing hanger. 15.MIT-IA to 4,000 psi for 30 minutes on rig (planned). (Post rig move, pressure test to 4,300 psi for 30 minutes (Planned)) 16.MIT-T to 3,500 psi for 30 minutes on rig (Planned). (Post rig move, pressure test to 5,500 psi for 30 minutes (Planned)) a. Post rig more pressure test criteria: (8,800 psi MAWP – 3,800 psi IA hold) * 1.1 = 5,500 psi tubing 17.Nipple down BOP stack and install 10k frac tree. 18.RDMO NDBi-034 Well Clean Up Procedure 1. Move in and rig up Well Clean Up Surface Equipment as per P&ID and Pad Layout/Flow Diagram 2. Perform Low pressure air test of 100 – 120 psi, hold 10 minutes. (N2 will be used if hydrocarbon is present) 3. Pressure test all surface equipment and hardline upstream of the choke manifold to 5000psi and hold 15 minutes. Pressure test all surface equipment and hardline downstream of the choke manifold (with exception of flare) to 1000 psi and hold 15 minutes. Cap the gas line to the flare and test with air to 120 psi, hold 15 minutes. (N2 will be used if hydrocarbon is present). 4. Perform clean-up operations as per procedures. 5. Perform sampling as per procedures. 6. Rig down and demobilize equipment. Attachment I Attachment J Tuluvak Sand @ 3,724' MD Top Nan 3.2 @16,688' MD Top Nanushuk @15,918' NDBi-034 Well Schematic (As Built) 20" Insulated Conductor128' MD 20" Insulated Conductor128' MD 9-5/8" Liner Hanger and Liner Top Packer 2,851' MD 9-5/8" Liner Hanger and Liner Top Packer 2,851' MD 13-3/8" 68 ppf L-80 Surface Casing 3,014' MD 13-3/8" 68 ppf L-80 Surface Casing 3,014' MD 4-½”, 12.6ppf P-110S Production Liner25,842' MD 4-½”, 12.6ppf P-110S Production Liner25,842' MD 4-½” Liner Hanger/Top Packer16,469' MD 4-½” Liner Hanger/Top Packer16,469' MD GL 69.74' RKB – Bottom Flange 01/12/2026 9-5/8" Tieback2,851' MD 9-5/8" Tieback2,851' MD 9-5/8" Cflex Stage Tool (50' MD below TS790)6,588' MD 9-5/8" Cflex Stage Tool (50' MD below TS790)6,588' MD 7" TOC (200' TVD above top Nanushuk) 14,098' MD 7" TOC (200' TVD above top Nanushuk) 14,098' MD 7", 26ppf L-80 Production Liner16,669' MD 7", 26ppf L-80 Production Liner16,669' MD 9-5/8", 47ppf L-80 Intermediate Liner 11,997' MD 9-5/8", 47ppf L-80 Intermediate Liner 11,997' MD 9-5/8" Primary TOC (1000' MD above shoe) 10,997' MD 9-5/8" Primary TOC (1000' MD above shoe) 10,997' MD 7" Liner Hanger and Liner Top Packer 11,862' MD 7" Liner Hanger and Liner Top Packer 11,862' MD 23 29 10 47 44 8-½” Openhole TD26,450' MD 8-½” Openhole TD26,450' MD 46 454341393735333127252119171513119 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 448 7 6 5 4 3 2 1 # Completion Item Top Depth (MD') Depth (TVD') Inc ID" OD" 1 X Landing Nipple 1463 1420 26 3.813 5.201 2 Gaslift Mandrel 1.5" 2352 2084 54 3.865 7.640 3 X Landing Nipple 2420 2123 56 3.813 5.201 4 D/H Psi-Temp Gauge 16213 3914 68 3.864 5.830 5 EGL Valve 16318 3957 66 3.958 5.900 6 Tieback Seal Assy 16469 4414 67 3.860 5.190 7 7" x 4.5" LH/Packer 16469 4414 67 5.000 5.960 8 #18 OH Packer 16711 4096 75 3.898 5.750 9 #17 OH packer 16777 4111 78 3.898 5.750 10 Stg 16 - Collet Sleeve 16 17008 4145 86 3.735 5.634 11 #16 OH packer 17276 4152 90 3.898 5.750 12 Stg 15 - Collet Sleeve 15 17591 4152 90 3.735 5.634 13 #15 OH packer 17902 4153 90 3.898 5.750 14 Stg 14 - Collet Sleeve 14 18172 4153 90 3.735 5.634 15 #14 OH packer 18483 4154 90 3.898 5.750 16 Stg 13 - Collet Sleeve 13 18755 4154 90 3.735 5.634 17 #13 OH packer 19069 4154 90 3.898 5.750 18 Stg 12 - Collet Sleeve 12 19342 4154 90 3.735 5.634 19 #12 OH packer 19698 4152 90 3.898 5.750 20 Stg 11 - Collet Sleeve 11 19929 4153 90 3.735 5.634 21 #11 OH packer 20243 4151 90 3.898 5.750 22 Stg 10 - Collet Sleeve 10 20513 4149 90 3.735 5.634 23 #10 OH packer 20823 4148 90 3.898 5.750 24 Stg 9 - Collet Sleeve 9 21095 4147 90 3.735 5.634 25 #9 OH packer 21407 4145 90 3.898 5.750 26 Stg 8 - Collet Sleeve 8 21673 4144 90 3.735 5.634 27 #8 OH packer 21946 4143 90 3.898 5.750 28 Stg 7 - Collet Sleeve 7 22260 4143 90 3.735 5.634 29 #7 OH packer 22574 4141 90 3.898 5.750 30 Stg 6 - Collet Sleeve 6 22845 4140 90 3.735 5.634 31 #6 OH packer 23158 4139 90 3.898 5.750 32 Stg 5 - Collet Sleeve 5 23428 4137 90 3.735 5.634 33 #5 OH packer 23700 4136 90 3.898 5.750 34 Stg 4 - Collet Sleeve 4 23969 4134 90 3.735 5.634 35 #4 OH packer 24241 4132 91 3.898 5.750 36 Stg 3 - Collet Sleeve 3 24514 4129 91 3.735 5.634 37 #3 OH packer 24827 4126 91 3.898 5.750 38 Stg 2 - Collet Sleeve 2 25058 4125 90 3.735 5.634 39 #2 OH packer 25370 4122 91 3.898 5.750 40 Stg 1 - Collet Sleeve 1 25601 4120 91 3.735 5.634 41 #1 OH packer 25748 4118 91 3.898 5.750 42 Toe Sleeve 25814 4117 91 3.500 5.750 43 WIV Collar 25827 4117 91 N/A 5.620 44 Eccentric shoe 25840 4117 91 3.930 5.210 Attachment K Kinetix-Frac Completion Report Santos Country: United States Well Name: NDBi-034 Operator: Santos Field: Pikka Formation: Nanushuk Prepared By: Javier Del Real Report Date: January 8th 2026 NDBI-034 Stage N/A Page 2 of 97 Stage 1 ǣ Zoneset name: Stage 1 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4007.97 29.83 0.7 2816.1 2786554.2 0.25 2500 Shale 4037.8 26.73 0.66 2665.6 2786554.2 0.25 2500 Top 3.2 NAN CS 4064.53 3.61 0.6 2460.1 1159218.9 0.26 600 Siltstone 4068.14 1.81 0.62 2510.6 1629236.3 0.26 1500 CleanSandstone 4069.95 1.8 0.6 2446.6 979798.8 0.26 600 Siltstone 4071.75 3.61 0.61 2468.5 1350455.1 0.26 1500 CleanSandstone 4075.36 3.58 0.61 2487.1 1206390.9 0.26 600 Siltstone 4078.94 3.61 0.61 2477 1313860.7 0.26 1500 CleanSandstone 4082.55 7.18 0.61 2480.3 1266403.2 0.26 600 Siltstone 4089.73 1.81 0.61 2479 1082935.6 0.26 1500 DirtySandstone 4091.54 1.8 0.62 2549.6 1222900.8 0.26 600 Shale 4093.34 1.8 0.62 2554.8 1419038.4 0.26 2500 DirtySandstone 4095.14 1.81 0.61 2519 1403385.6 0.26 600 NDBI-034 Stage N/A Page 3 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Siltstone 4096.95 8.99 0.62 2534.7 1402756.3 0.26 1500 Shale 4105.94 3.61 0.66 2690.6 2181052.3 0.25 2500 DirtySandstone 4109.55 5.41 0.62 2553.7 1662780.4 0.26 1500 Siltstone 4114.96 1.77 0.63 2584.7 1963674.5 0.26 2500 DirtySandstone 4116.73 3.71 0.62 2561.8 1742901.7 0.26 1500 Siltstone 4120.44 5.41 0.63 2597.6 1681056.2 0.26 2500 Siltstone 4125.85 1.81 0.62 2566.9 1561073 0.26 1500 DirtySandstone 4127.66 1.8 0.62 2551.5 1262913.1 0.26 2500 Siltstone 4129.46 3.58 0.63 2611 1816969.7 0.26 1500 Shale 4133.04 11.02 0.65 2673.5 2238744.4 0.25 2500 CleanSandstone 4144.06 1.97 0.61 2516.1 1001510.6 0.26 600 Siltstone 4146.03 4 0.62 2571.8 1571504.2 0.26 1500 CleanSandstone 4150.03 2 0.6 2511.3 1267177.7 0.26 600 Shale 4152.03 2.01 0.66 2728.6 2789765.8 0.25 2500 Siltstone 4154.04 2 0.62 2563.7 1409418.9 0.26 1500 Shale 4156.04 2.1 0.66 2731.2 2789765.8 0.25 2500 NDBI-034 Stage N/A Page 4 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) DirtySandstone 4158.14 4 0.61 2537.7 1435306.6 0.26 1500 Siltstone 4162.14 4 0.62 2590.1 1765617.4 0.26 2500 DirtySandstone 4166.14 4 0.61 2559.2 1435651.3 0.26 1500 CleanSandstone 4170.14 2.1 0.59 2465.2 935658.3 0.26 2500 Siltstone 4172.24 4.01 0.62 2596.3 1491142.7 0.26 1500 Shale 4176.25 2 0.66 2744.4 2789765.8 0.25 2500 DirtySandstone 4178.25 10.99 0.62 2581.4 1462838 0.26 1500 Shale 4189.24 27 0.65 2740.2 2560999.9 0.25 2500 Siltstone 4216.24 2 0.63 2673.8 1857874.8 0.26 1500 Shale 4218.24 10.01 0.66 2770.5 2552268.6 0.25 2500 Siltstone 4228.25 2 0.63 2651.7 1509543.6 0.26 1500 Shale 4230.25 4.1 0.64 2708.7 2349461.1 0.25 2500 Siltstone 4234.35 2 0.64 2693.6 1482677.8 0.25 1500 Shale 4236.35 96.39 0.65 2797.8 2604074 0.25 2500 DirtySandstone 4332.74 2 0.61 2643.6 1153391 0.26 1500 Shale 4334.74 38.19 0.65 2851.7 2733692 0.25 2500 NDBI-034 Stage N/A Page 5 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Siltstone 4372.93 2 0.62 2716.3 1526263.4 0.26 1500 Shale 4374.93 46.23 0.65 2880.7 2704369.9 0.25 2500 Siltstone 4421.16 1.97 0.64 2808.1 1825853.3 0.25 1500 Shale 4423.13 9.84 0.65 2891.5 2657615 0.25 2500 ǣ Name: Stage 1 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 1 PAD 40 YF126ST 16800 400 10 2 1 PPA 40 YF126ST 5027.5 125 CarboLite 16/20 1 5027.5 3.12 3 2 PPA 40 YF126ST 5402.2 140 CarboLite 16/20 2 10804.4 3.5 4 3 PPA 40 YF126ST 6303.8 170 CarboLite 16/20 3 18911.4 4.25 5 4 PPA 40 YF126ST 6066.9 170 CarboLite 16/20 4 24267.6 4.25 6 5 PPA 40 YF126ST 5847.3 170 CarboLite 16/20 5 29236.5 4.25 7 6 PPA 40 YF126ST 5642.9 170 CarboLite 16/20 6 33857.4 4.25 8 7 PPA 40 YF126ST 4490.2 140 CarboLite 16/20 7 31431.4 3.5 NDBI-034 Stage N/A Page 6 of 97 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 9 8 PPA 40 YF126ST 3878.3 125 CarboLite 16/20 8 31026.4 3.13 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 28.25 24.84 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 59459.1 184562.6 1610 40.25 NDBI-034 Stage N/A Page 7 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 1 7373.4 233.68 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4025.9 4259.58 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 1 2.87 675.77 168.87 0.5 NDBI-034 Stage N/A Page 8 of 97 Stage 2 ǣ Zoneset name: Stage 2 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4012.99 29.83 0.7 2819.68 2786554.2 0.25 2500 Shale 4042.81 26.73 0.66 2668.84 2786554.2 0.25 2500 Top 3.2 NAN CS 4069.52 3.61 0.6 2463.18 1159218.9 0.26 600 Siltstone 4073.16 1.81 0.62 2513.65 1629236.3 0.26 1500 CleanSandstone 4074.97 1.8 0.6 2449.69 979798.8 0.26 600 Siltstone 4076.77 3.61 0.61 2471.59 1350455.1 0.26 1500 CleanSandstone 4080.38 3.58 0.61 2490.15 1206390.9 0.26 600 Siltstone 4083.96 3.61 0.61 2480 1313860.7 0.26 1500 CleanSandstone 4087.57 7.18 0.61 2483.34 1266403.2 0.26 600 Siltstone 4094.75 1.81 0.61 2482.03 1082935.6 0.26 1500 DirtySandstone 4096.56 1.8 0.62 2552.66 1222900.8 0.26 600 Shale 4098.36 1.8 0.62 2557.89 1419038.4 0.26 2500 NDBI-034 Stage N/A Page 9 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) DirtySandstone 4100.13 1.81 0.61 2522.06 1403385.6 0.26 600 Siltstone 4101.97 8.99 0.62 2537.87 1402756.3 0.26 1500 Shale 4110.96 3.61 0.66 2693.93 2181052.3 0.25 2500 DirtySandstone 4114.57 5.41 0.62 2556.87 1662780.4 0.26 1500 Siltstone 4119.98 1.77 0.63 2587.91 1963674.5 0.26 2500 DirtySandstone 4121.75 3.71 0.62 2564.99 1742901.7 0.26 1500 Siltstone 4125.46 5.41 0.63 2600.82 1681056.2 0.26 2500 Siltstone 4130.87 1.81 0.62 2570.07 1561073 0.26 1500 DirtySandstone 4132.68 1.8 0.62 2554.55 1262913.1 0.26 2500 Siltstone 4134.48 3.58 0.63 2614.16 1816969.7 0.26 1500 Shale 4138.06 11.02 0.65 2676.67 2238744.4 0.25 2500 CleanSandstone 4149.08 1.97 0.61 2519.16 1001510.6 0.26 600 Siltstone 4151.05 4 0.62 2574.85 1571504.2 0.26 1500 CleanSandstone 4155.05 2 0.6 2514.37 1267177.7 0.26 600 Shale 4157.02 2.01 0.66 2731.93 2789765.8 0.25 2500 Siltstone 4159.06 2 0.62 2566.73 1409418.9 0.26 1500 NDBI-034 Stage N/A Page 10 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4161.06 2.1 0.66 2734.54 2789765.8 0.25 2500 DirtySandstone 4163.16 4 0.61 2540.77 1435306.6 0.26 1500 Siltstone 4167.16 4 0.62 2593.27 1765617.4 0.26 2500 DirtySandstone 4171.16 4 0.61 2562.24 1435651.3 0.26 1500 CleanSandstone 4175.13 2.1 0.59 2468.11 935658.3 0.26 2500 Siltstone 4177.23 4.01 0.62 2599.37 1491142.7 0.26 1500 Shale 4181.27 2 0.66 2747.74 2789765.8 0.25 2500 DirtySandstone 4183.27 10.99 0.62 2584.43 1462838 0.26 1500 Shale 4194.26 27 0.65 2743.53 2560999.9 0.25 2500 Siltstone 4221.26 2 0.63 2676.96 1857874.8 0.26 1500 Shale 4223.26 10.01 0.66 2773.85 2552268.6 0.25 2500 Siltstone 4233.27 2 0.63 2654.92 1509543.6 0.26 1500 Shale 4235.27 4.1 0.64 2711.92 2349461.1 0.25 2500 Siltstone 4239.37 2 0.64 2696.83 1482677.8 0.25 1500 Shale 4241.37 96.39 0.65 2801.11 2604074 0.25 2500 DirtySandstone 4337.76 2 0.61 2646.65 1153391 0.26 1500 NDBI-034 Stage N/A Page 11 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4339.73 38.19 0.65 2854.92 2733692 0.25 2500 Siltstone 4377.95 2 0.62 2719.46 1526263.4 0.26 1500 Shale 4379.92 46.23 0.65 2883.93 2704369.9 0.25 2500 Siltstone 4426.18 1.97 0.64 2811.27 1825853.3 0.25 1500 Shale 4428.15 9.84 0.65 2894.81 2657615 0.25 2500 NDBI-034 Stage N/A Page 12 of 97 ǣ Name: Stage 2 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 2 PAD 40 YF126ST 18900 450 11.25 2 1 PPA 40 YF126ST 6033.2 150 CarboLite 16/20 1 6033.2 3.75 3 2 PPA 40 YF126ST 6752.7 175 CarboLite 16/20 2 13505.4 4.37 4 3 PPA 40 YF126ST 7416.2 200 CarboLite 16/20 3 22248.6 5 5 4 PPA 40 YF126ST 7137.5 200 CarboLite 16/20 4 28550 5 6 5 PPA 40 YF126ST 6879.2 200 CarboLite 16/20 5 34396 5 7 6 PPA 40 YF126ST 6638.7 200 CarboLite 16/20 6 39832.2 5 8 7 PPA 40 YF126ST 5452.4 170 CarboLite 16/20 7 38166.8 4.25 9 8 PPA 40 YF126ST 4188.4 135 CarboLite 16/20 8 33507.2 3.37 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 27.23 23.94 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 69398.3 216239.4 1879.99 47 NDBI-034 Stage N/A Page 13 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 2 7285 251.48 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4062.41 4313.89 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 2 2.35 825.9 184.62 0.45 NDBI-034 Stage N/A Page 14 of 97 Stage 3 ǣ Zoneset name: Stage 3 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4017.98 29.83 0.7 2823.16 2786554.2 0.25 2500 Shale 4047.8 26.73 0.66 2672.18 2786554.2 0.25 2500 Top 3.2 NAN CS 4074.54 3.61 0.6 2466.22 1159218.9 0.26 600 Siltstone 4078.15 1.81 0.62 2516.84 1629236.3 0.26 1500 CleanSandstone 4079.95 1.8 0.6 2452.59 979798.8 0.26 600 Siltstone 4081.76 3.61 0.61 2474.63 1350455.1 0.26 1500 CleanSandstone 4085.37 3.58 0.61 2493.2 1206390.9 0.26 600 Siltstone 4088.94 3.61 0.61 2483.05 1313860.7 0.26 1500 CleanSandstone 4092.55 7.18 0.61 2486.38 1266403.2 0.26 600 Siltstone 4099.74 1.81 0.61 2485.08 1082935.6 0.26 1500 DirtySandstone 4101.54 1.8 0.62 2555.86 1222900.8 0.26 600 Shale 4103.35 1.8 0.62 2561.08 1419038.4 0.26 2500 NDBI-034 Stage N/A Page 15 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) DirtySandstone 4105.15 1.81 0.61 2525.11 1403385.6 0.26 600 Siltstone 4106.96 8.99 0.62 2540.92 1402756.3 0.26 1500 Shale 4115.94 3.61 0.66 2697.12 2181052.3 0.25 2500 DirtySandstone 4119.55 5.41 0.62 2559.92 1662780.4 0.26 1500 Siltstone 4124.97 1.77 0.63 2590.95 1963674.5 0.26 2500 DirtySandstone 4126.74 3.71 0.62 2568.04 1742901.7 0.26 1500 Siltstone 4130.45 5.41 0.63 2603.86 1681056.2 0.26 2500 Siltstone 4135.86 1.81 0.62 2573.11 1561073 0.26 1500 DirtySandstone 4137.66 1.8 0.62 2557.74 1262913.1 0.26 2500 Siltstone 4139.47 3.58 0.63 2617.35 1816969.7 0.26 1500 Shale 4143.04 11.02 0.65 2680.01 2238744.4 0.25 2500 CleanSandstone 4154.07 1.97 0.61 2522.21 1001510.6 0.26 600 Siltstone 4156.04 4 0.62 2578.05 1571504.2 0.26 1500 CleanSandstone 4160.04 2 0.6 2517.42 1267177.7 0.26 600 Shale 4162.04 2.01 0.66 2735.12 2789765.8 0.25 2500 Siltstone 4164.04 2 0.62 2569.92 1409418.9 0.26 1500 NDBI-034 Stage N/A Page 16 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4166.04 2.1 0.66 2737.73 2789765.8 0.25 2500 DirtySandstone 4168.14 4 0.61 2543.82 1435306.6 0.26 1500 Siltstone 4172.15 4 0.62 2596.32 1765617.4 0.26 2500 DirtySandstone 4176.15 4 0.61 2565.28 1435651.3 0.26 1500 CleanSandstone 4180.15 2.1 0.59 2471.15 935658.3 0.26 2500 Siltstone 4182.25 4.01 0.62 2602.56 1491142.7 0.26 1500 Shale 4186.25 2 0.66 2750.93 2789765.8 0.25 2500 DirtySandstone 4188.25 10.99 0.62 2587.62 1462838 0.26 1500 Shale 4199.25 27 0.65 2746.72 2560999.9 0.25 2500 Siltstone 4226.25 2 0.63 2680.15 1857874.8 0.26 1500 Shale 4228.25 10.01 0.66 2777.04 2552268.6 0.25 2500 Siltstone 4238.25 2 0.63 2657.96 1509543.6 0.26 1500 Shale 4240.26 4.1 0.64 2715.11 2349461.1 0.25 2500 Siltstone 4244.36 2 0.64 2700.02 1482677.8 0.25 1500 Shale 4246.36 96.39 0.65 2804.3 2604074 0.25 2500 DirtySandstone 4342.75 2 0.61 2649.69 1153391 0.26 1500 NDBI-034 Stage N/A Page 17 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4344.75 38.19 0.65 2858.26 2733692 0.25 2500 Siltstone 4382.94 2 0.62 2722.5 1526263.4 0.26 1500 Shale 4384.94 46.23 0.65 2887.27 2704369.9 0.25 2500 Siltstone 4431.17 1.97 0.64 2814.46 1825853.3 0.25 1500 Shale 4433.14 9.84 0.65 2898 2657615 0.25 2500 ǣ Name: Stage 3 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 3 PAD 40 YF126ST 18900 450 11.25 2 1 PPA 40 YF126ST 6033.2 150 CarboLite 16/20 1 6033.2 3.75 3 2 PPA 40 YF126ST 6752.7 175 CarboLite 16/20 2 13505.4 4.37 4 3 PPA 40 YF126ST 7416.2 200 CarboLite 16/20 3 22248.6 5 5 4 PPA 40 YF126ST 7137.5 200 CarboLite 16/20 4 28550 5 6 5 PPA 40 YF126ST 6879.2 200 CarboLite 16/20 5 34396 5 7 6 PPA 40 YF126ST 6638.7 200 CarboLite 16/20 6 39832.2 5 NDBI-034 Stage N/A Page 18 of 97 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 8 7 PPA 40 YF126ST 5452.4 170 CarboLite 16/20 7 38166.8 4.25 9 8 PPA 40 YF126ST 4188.4 135 CarboLite 16/20 8 33507.2 3.37 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 27.23 23.94 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 69398.3 216239.4 1879.99 47 NDBI-034 Stage N/A Page 19 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 3 7157.7 237.62 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4036 4273.62 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 3 2.98 697.03 181.31 0.53 NDBI-034 Stage N/A Page 20 of 97 Stage 4 ǣ Zoneset name: Stage 4 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4022.97 29.83 0.7 2826.64 2786554.2 0.25 2500 Shale 4052.79 26.73 0.66 2675.51 2786554.2 0.25 2500 Top 3.2 NAN CS 4079.53 3.61 0.6 2469.12 1159218.9 0.26 600 Siltstone 4083.14 1.81 0.62 2519.89 1629236.3 0.26 1500 CleanSandstone 4084.94 1.8 0.6 2455.63 979798.8 0.26 600 Siltstone 4086.75 3.61 0.61 2477.53 1350455.1 0.26 1500 CleanSandstone 4090.35 3.58 0.61 2496.24 1206390.9 0.26 600 Siltstone 4093.93 3.61 0.61 2486.09 1313860.7 0.26 1500 CleanSandstone 4097.54 7.18 0.61 2489.43 1266403.2 0.26 600 Siltstone 4104.72 1.81 0.61 2488.12 1082935.6 0.26 1500 DirtySandstone 4106.53 1.8 0.62 2558.9 1222900.8 0.26 600 Shale 4108.33 1.8 0.62 2564.12 1419038.4 0.26 2500 NDBI-034 Stage N/A Page 21 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) DirtySandstone 4110.14 1.81 0.61 2528.15 1403385.6 0.26 600 Siltstone 4111.94 8.99 0.62 2543.96 1402756.3 0.26 1500 Shale 4120.93 3.61 0.66 2700.46 2181052.3 0.25 2500 DirtySandstone 4124.54 5.41 0.62 2562.96 1662780.4 0.26 1500 Siltstone 4129.95 1.77 0.63 2594.14 1963674.5 0.26 2500 DirtySandstone 4131.73 3.71 0.62 2571.08 1742901.7 0.26 1500 Siltstone 4135.43 5.41 0.63 2607.05 1681056.2 0.26 2500 Siltstone 4140.85 1.81 0.62 2576.16 1561073 0.26 1500 DirtySandstone 4142.65 1.8 0.62 2560.79 1262913.1 0.26 2500 Siltstone 4144.46 3.58 0.63 2620.54 1816969.7 0.26 1500 Shale 4148.03 11.02 0.65 2683.2 2238744.4 0.25 2500 CleanSandstone 4159.06 1.97 0.61 2525.25 1001510.6 0.26 600 Siltstone 4161.02 4 0.62 2581.09 1571504.2 0.26 1500 CleanSandstone 4165.03 2 0.6 2520.32 1267177.7 0.26 600 Shale 4167.03 2.01 0.66 2738.46 2789765.8 0.25 2500 Siltstone 4169.03 2 0.62 2572.97 1409418.9 0.26 1500 NDBI-034 Stage N/A Page 22 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4171.03 2.1 0.66 2741.07 2789765.8 0.25 2500 DirtySandstone 4173.13 4 0.61 2546.86 1435306.6 0.26 1500 Siltstone 4177.13 4 0.62 2599.37 1765617.4 0.26 2500 DirtySandstone 4181.14 4 0.61 2568.47 1435651.3 0.26 1500 CleanSandstone 4185.14 2.1 0.59 2474.05 935658.3 0.26 2500 Siltstone 4187.24 4.01 0.62 2605.6 1491142.7 0.26 1500 Shale 4191.24 2 0.66 2754.27 2789765.8 0.25 2500 DirtySandstone 4193.24 10.99 0.62 2590.66 1462838 0.26 1500 Shale 4204.23 27 0.65 2749.92 2560999.9 0.25 2500 Siltstone 4231.23 2 0.63 2683.34 1857874.8 0.26 1500 Shale 4233.23 10.01 0.66 2780.37 2552268.6 0.25 2500 Siltstone 4243.24 2 0.63 2661.15 1509543.6 0.26 1500 Shale 4245.24 4.1 0.64 2718.3 2349461.1 0.25 2500 Siltstone 4249.34 2 0.64 2703.07 1482677.8 0.25 1500 Shale 4251.35 96.39 0.65 2807.64 2604074 0.25 2500 DirtySandstone 4347.74 2 0.61 2652.74 1153391 0.26 1500 NDBI-034 Stage N/A Page 23 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4349.74 38.19 0.65 2861.59 2733692 0.25 2500 Siltstone 4387.93 2 0.62 2725.55 1526263.4 0.26 1500 Shale 4389.93 46.23 0.65 2890.46 2704369.9 0.25 2500 Siltstone 4436.15 1.97 0.64 2817.65 1825853.3 0.25 1500 Shale 4438.12 9.84 0.65 2901.33 2657615 0.25 2500 ǣ Name: Stage 4 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 4 PAD 40 YF126ST 17850 425 10.62 2 1 PPA 40 YF126ST 6435.4 160 CarboLite 16/20 1 6435.4 4 3 2 PPA 40 YF126ST 6559.8 170 CarboLite 16/20 2 13119.6 4.25 4 3 PPA 40 YF126ST 6859.9 185 CarboLite 16/20 3 20579.7 4.62 5 4 PPA 40 YF126ST 6602.2 185 CarboLite 16/20 4 26408.8 4.62 6 5 PPA 40 YF126ST 6363.2 185 CarboLite 16/20 5 31816 4.62 7 6 PPA 40 YF126ST 6140.8 185 CarboLite 16/20 6 36844.8 4.62 NDBI-034 Stage N/A Page 24 of 97 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 8 7 PPA 40 YF126ST 4971.2 155 CarboLite 16/20 7 34798.4 3.87 9 8 PPA 40 YF126ST 4343.5 140 CarboLite 16/20 8 34748 3.5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.99 23.74 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 66126 204750.7 1789.98 44.75 NDBI-034 Stage N/A Page 25 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 4 7018.2 235.29 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 4 2.97 697.87 177.89 0.53 NDBI-034 Stage N/A Page 26 of 97 Stage 5 ǣ Zoneset name: Stage 5 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4025.98 29.83 0.7 2828.67 2786554.2 0.25 2500 Shale 4055.81 26.73 0.66 2677.4 2786554.2 0.25 2500 Top 3.2 NAN CS 4082.55 3.61 0.6 2471.01 1159218.9 0.26 600 Siltstone 4086.15 1.81 0.62 2521.77 1629236.3 0.26 1500 CleanSandstone 4087.96 1.8 0.6 2457.37 979798.8 0.26 600 Siltstone 4089.76 3.61 0.61 2479.42 1350455.1 0.26 1500 CleanSandstone 4093.37 3.58 0.61 2498.13 1206390.9 0.26 600 Siltstone 4096.95 3.61 0.61 2487.98 1313860.7 0.26 1500 CleanSandstone 4100.56 7.18 0.61 2491.17 1266403.2 0.26 600 Siltstone 4107.74 1.81 0.61 2489.86 1082935.6 0.26 1500 DirtySandstone 4109.55 1.8 0.62 2560.79 1222900.8 0.26 600 Shale 4111.35 1.8 0.62 2566.01 1419038.4 0.26 2500 NDBI-034 Stage N/A Page 27 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) DirtySandstone 4113.16 1.81 0.61 2530.04 1403385.6 0.26 600 Siltstone 4114.96 8.99 0.62 2545.85 1402756.3 0.26 1500 Shale 4123.95 3.61 0.66 2702.34 2181052.3 0.25 2500 DirtySandstone 4127.56 5.41 0.62 2564.85 1662780.4 0.26 1500 Siltstone 4132.97 1.77 0.63 2596.03 1963674.5 0.26 2500 DirtySandstone 4134.74 3.71 0.62 2572.97 1742901.7 0.26 1500 Siltstone 4138.45 5.41 0.63 2608.94 1681056.2 0.26 2500 Siltstone 4143.86 1.81 0.62 2578.05 1561073 0.26 1500 DirtySandstone 4145.67 1.8 0.62 2562.67 1262913.1 0.26 2500 Siltstone 4147.47 3.58 0.63 2622.43 1816969.7 0.26 1500 Shale 4151.05 11.02 0.65 2685.08 2238744.4 0.25 2500 CleanSandstone 4162.07 1.97 0.61 2526.99 1001510.6 0.26 600 Siltstone 4164.04 4 0.62 2582.98 1571504.2 0.26 1500 CleanSandstone 4168.04 2 0.6 2522.21 1267177.7 0.26 600 Shale 4170.05 2.01 0.66 2740.49 2789765.8 0.25 2500 Siltstone 4172.05 2 0.62 2574.85 1409418.9 0.26 1500 NDBI-034 Stage N/A Page 28 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4174.05 2.1 0.66 2743.1 2789765.8 0.25 2500 DirtySandstone 4176.15 4 0.61 2548.75 1435306.6 0.26 1500 Siltstone 4180.15 4 0.62 2601.25 1765617.4 0.26 2500 DirtySandstone 4184.15 4 0.61 2570.21 1435651.3 0.26 1500 CleanSandstone 4188.16 2.1 0.59 2475.79 935658.3 0.26 2500 Siltstone 4190.26 4.01 0.62 2607.49 1491142.7 0.26 1500 Shale 4194.26 2 0.66 2756.3 2789765.8 0.25 2500 DirtySandstone 4196.26 10.99 0.62 2592.55 1462838 0.26 1500 Shale 4207.25 27 0.65 2751.95 2560999.9 0.25 2500 Siltstone 4234.25 2 0.63 2685.23 1857874.8 0.26 1500 Shale 4236.25 10.01 0.66 2782.26 2552268.6 0.25 2500 Siltstone 4246.26 2 0.63 2663.04 1509543.6 0.26 1500 Shale 4248.26 4.1 0.64 2720.18 2349461.1 0.25 2500 Siltstone 4252.36 2 0.64 2705.1 1482677.8 0.25 1500 Shale 4254.36 96.39 0.65 2809.53 2604074 0.25 2500 DirtySandstone 4350.75 2 0.61 2654.63 1153391 0.26 1500 NDBI-034 Stage N/A Page 29 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4352.76 38.19 0.65 2863.48 2733692 0.25 2500 Siltstone 4390.94 2 0.62 2727.43 1526263.4 0.26 1500 Shale 4392.95 46.23 0.65 2892.49 2704369.9 0.25 2500 Siltstone 4439.17 1.97 0.64 2819.53 1825853.3 0.25 1500 Shale 4441.14 9.84 0.65 2903.22 2657615 0.25 2500 NDBI-034 Stage N/A Page 30 of 97 ǣ Name: Stage 5 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 5 PAD 40 YF126ST 18900 450 11.25 2 1 PPA 40 YF126ST 6636.5 165 CarboLite 16/20 1 6636.5 4.12 3 2 PPA 40 YF126ST 6945.6 180 CarboLite 16/20 2 13891.2 4.5 4 3 PPA 40 YF126ST 7230.8 195 CarboLite 16/20 3 21692.4 4.87 5 4 PPA 40 YF126ST 6959.1 195 CarboLite 16/20 4 27836.4 4.87 6 5 PPA 40 YF126ST 6707 195 CarboLite 16/20 5 33535 4.87 7 6 PPA 40 YF126ST 6472.8 195 CarboLite 16/20 6 38836.8 4.88 8 7 PPA 40 YF126ST 5933.4 185 CarboLite 16/20 7 41533.8 4.62 9 8 PPA 40 YF126ST 5274.3 170 CarboLite 16/20 8 42194.4 4.25 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.6 23.32 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 71059.5 226156.5 1929.98 48.25 NDBI-034 Stage N/A Page 31 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 5 6969.9 235.31 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4044.87 4280.18 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 5 5.62 666.7 182.82 0.56 NDBI-034 Stage N/A Page 32 of 97 Stage 6 ǣ Zoneset name: Stage 6 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4030.97 29.83 0.7 2832.15 2786554.2 0.25 2500 Shale 4060.79 26.73 0.66 2680.73 2786554.2 0.25 2500 Top 3.2 NAN CS 4087.53 3.61 0.6 2474.05 1159218.9 0.26 600 Siltstone 4091.14 1.81 0.62 2524.82 1629236.3 0.26 1500 CleanSandstone 4092.95 1.8 0.6 2460.42 979798.8 0.26 600 Siltstone 4094.75 3.61 0.61 2482.47 1350455.1 0.26 1500 CleanSandstone 4098.36 3.58 0.61 2501.18 1206390.9 0.26 600 Siltstone 4101.94 3.61 0.61 2491.02 1313860.7 0.26 1500 CleanSandstone 4105.54 7.18 0.61 2494.21 1266403.2 0.26 600 Siltstone 4112.73 1.81 0.61 2492.91 1082935.6 0.26 1500 DirtySandstone 4114.53 1.8 0.62 2563.98 1222900.8 0.26 600 Shale 4116.34 1.8 0.62 2569.2 1419038.4 0.26 2500 NDBI-034 Stage N/A Page 33 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) DirtySandstone 4118.14 1.81 0.61 2533.08 1403385.6 0.26 600 Siltstone 4119.95 8.99 0.62 2548.89 1402756.3 0.26 1500 Shale 4128.94 3.61 0.66 2705.68 2181052.3 0.25 2500 DirtySandstone 4132.55 5.41 0.62 2568.04 1662780.4 0.26 1500 Siltstone 4137.96 1.77 0.63 2599.08 1963674.5 0.26 2500 DirtySandstone 4139.73 3.71 0.62 2576.16 1742901.7 0.26 1500 Siltstone 4143.44 5.41 0.63 2612.13 1681056.2 0.26 2500 Siltstone 4148.85 1.81 0.62 2581.24 1561073 0.26 1500 DirtySandstone 4150.66 1.8 0.62 2565.72 1262913.1 0.26 2500 Siltstone 4152.46 3.58 0.63 2625.47 1816969.7 0.26 1500 Shale 4156.04 11.02 0.65 2688.42 2238744.4 0.25 2500 CleanSandstone 4167.06 1.97 0.61 2530.04 1001510.6 0.26 600 Siltstone 4169.03 4 0.62 2586.02 1571504.2 0.26 1500 CleanSandstone 4173.03 2 0.6 2525.25 1267177.7 0.26 600 Shale 4175.03 2.01 0.66 2743.68 2789765.8 0.25 2500 Siltstone 4177.03 2 0.62 2577.9 1409418.9 0.26 1500 NDBI-034 Stage N/A Page 34 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4179.04 2.1 0.66 2746.29 2789765.8 0.25 2500 DirtySandstone 4181.14 4 0.61 2551.79 1435306.6 0.26 1500 Siltstone 4185.14 4 0.62 2604.44 1765617.4 0.26 2500 DirtySandstone 4189.14 4 0.61 2573.26 1435651.3 0.26 1500 CleanSandstone 4193.14 2.1 0.59 2478.84 935658.3 0.26 2500 Siltstone 4195.24 4.01 0.62 2610.53 1491142.7 0.26 1500 Shale 4199.25 2 0.66 2759.49 2789765.8 0.25 2500 DirtySandstone 4201.25 10.99 0.62 2595.6 1462838 0.26 1500 Shale 4212.24 27 0.65 2755.14 2560999.9 0.25 2500 Siltstone 4239.24 2 0.63 2688.42 1857874.8 0.26 1500 Shale 4241.24 10.01 0.66 2785.59 2552268.6 0.25 2500 Siltstone 4251.25 2 0.63 2666.08 1509543.6 0.26 1500 Shale 4253.25 4.1 0.64 2723.37 2349461.1 0.25 2500 Siltstone 4257.35 2 0.64 2708.29 1482677.8 0.25 1500 Shale 4259.35 96.39 0.65 2812.86 2604074 0.25 2500 DirtySandstone 4355.74 2 0.61 2657.67 1153391 0.26 1500 NDBI-034 Stage N/A Page 35 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4357.74 38.19 0.65 2866.82 2733692 0.25 2500 Siltstone 4395.93 2 0.62 2730.63 1526263.4 0.26 1500 Shale 4397.93 46.23 0.65 2895.82 2704369.9 0.25 2500 Siltstone 4444.16 1.97 0.64 2822.72 1825853.3 0.25 1500 Shale 4446.13 9.84 0.65 2906.56 2657615 0.25 2500 NDBI-034 Stage N/A Page 36 of 97 ǣ Name: Stage 6 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 6 PAD 40 YF126ST 18900 450 11.25 2 1 PPA 40 YF126ST 6636.5 165 CarboLite 16/20 1 6636.5 4.12 3 2 PPA 40 YF126ST 6945.6 180 CarboLite 16/20 2 13891.2 4.5 4 3 PPA 40 YF126ST 7230.8 195 CarboLite 16/20 3 21692.4 4.87 5 4 PPA 40 YF126ST 6959.1 195 CarboLite 16/20 4 27836.4 4.87 6 5 PPA 40 YF126ST 6707 195 CarboLite 16/20 5 33535 4.87 7 6 PPA 40 YF126ST 6472.8 195 CarboLite 16/20 6 38836.8 4.88 8 7 PPA 40 YF126ST 5933.4 185 CarboLite 16/20 7 41533.8 4.62 9 8 PPA 40 YF126ST 5274.3 170 CarboLite 16/20 8 42194.4 4.25 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.6 23.32 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 71059.5 226156.5 1929.98 48.25 NDBI-034 Stage N/A Page 37 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max SurfacePressure (psi) Max Height (ft) Stage 6 6816.8 233.23 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4047.45 4280.68 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 6 3.73 662.58 181.14 0.56 NDBI-034 Stage N/A Page 38 of 97 Stage 7 ǣ Zoneset name: Stage 7 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4036.48 29.83 0.7 2836.07 2786554.2 0.25 2500 Shale 4066.31 26.73 0.66 2684.36 2786554.2 0.25 2500 Top 3.2 NAN CS 4093.04 3.61 0.6 2477.39 1159218.9 0.26 600 Siltstone 4096.65 1.81 0.62 2528.15 1629236.3 0.26 1500 CleanSandstone 4098.46 1.8 0.6 2463.76 979798.8 0.26 600 Siltstone 4100.26 3.61 0.61 2485.8 1350455.1 0.26 1500 CleanSandstone 4103.87 3.58 0.61 2504.51 1206390.9 0.26 600 Siltstone 4107.45 3.61 0.61 2494.36 1313860.7 0.26 1500 CleanSandstone 4111.06 7.18 0.61 2497.55 1266403.2 0.26 600 Siltstone 4118.24 1.81 0.61 2496.24 1082935.6 0.26 1500 DirtySandstone 4120.05 1.8 0.62 2567.31 1222900.8 0.26 600 Shale 4121.85 1.8 0.62 2572.53 1419038.4 0.26 2500 NDBI-034 Stage N/A Page 39 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) DirtySandstone 4123.65 1.81 0.61 2536.56 1403385.6 0.26 600 Siltstone 4125.46 8.99 0.62 2552.37 1402756.3 0.26 1500 Shale 4134.45 3.61 0.66 2709.3 2181052.3 0.25 2500 DirtySandstone 4138.06 5.41 0.62 2571.37 1662780.4 0.26 1500 Siltstone 4143.47 1.77 0.63 2602.56 1963674.5 0.26 2500 DirtySandstone 4145.24 3.71 0.62 2579.5 1742901.7 0.26 1500 Siltstone 4148.95 5.41 0.63 2615.61 1681056.2 0.26 2500 Siltstone 4154.36 1.81 0.62 2584.57 1561073 0.26 1500 DirtySandstone 4156.17 1.8 0.62 2569.05 1262913.1 0.26 2500 Siltstone 4157.97 3.58 0.63 2628.95 1816969.7 0.26 1500 Shale 4161.55 11.02 0.65 2691.9 2238744.4 0.25 2500 CleanSandstone 4172.57 1.97 0.61 2533.37 1001510.6 0.26 600 Siltstone 4174.54 4 0.62 2589.5 1571504.2 0.26 1500 CleanSandstone 4178.54 2 0.6 2528.59 1267177.7 0.26 600 Shale 4180.54 2.01 0.66 2747.3 2789765.8 0.25 2500 Siltstone 4182.55 2 0.62 2581.24 1409418.9 0.26 1500 NDBI-034 Stage N/A Page 40 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4184.55 2.1 0.66 2749.92 2789765.8 0.25 2500 DirtySandstone 4186.65 4 0.61 2555.13 1435306.6 0.26 1500 Siltstone 4190.65 4 0.62 2607.78 1765617.4 0.26 2500 DirtySandstone 4194.65 4 0.61 2576.74 1435651.3 0.26 1500 CleanSandstone 4198.65 2.1 0.59 2482.03 935658.3 0.26 2500 Siltstone 4200.75 4.01 0.62 2614.02 1491142.7 0.26 1500 Shale 4204.76 2 0.66 2763.11 2789765.8 0.25 2500 DirtySandstone 4206.76 10.99 0.62 2598.93 1462838 0.26 1500 Shale 4217.75 27 0.65 2758.76 2560999.9 0.25 2500 Siltstone 4244.75 2 0.63 2691.9 1857874.8 0.26 1500 Shale 4246.75 10.01 0.66 2789.22 2552268.6 0.25 2500 Siltstone 4256.76 2 0.63 2669.56 1509543.6 0.26 1500 Shale 4258.76 4.1 0.64 2727 2349461.1 0.25 2500 Siltstone 4262.86 2 0.64 2711.77 1482677.8 0.25 1500 Shale 4264.86 96.39 0.65 2816.49 2604074 0.25 2500 DirtySandstone 4361.25 2 0.61 2661.01 1153391 0.26 1500 NDBI-034 Stage N/A Page 41 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4363.25 38.19 0.65 2870.44 2733692 0.25 2500 Siltstone 4401.44 2 0.62 2733.96 1526263.4 0.26 1500 Shale 4403.44 46.23 0.65 2899.3 2704369.9 0.25 2500 Siltstone 4449.67 1.97 0.64 2826.21 1825853.3 0.25 1500 Shale 4451.64 9.84 0.65 2910.18 2657615 0.25 2500 NDBI-034 Stage N/A Page 42 of 97 ǣ Name: Stage 7 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 7 PAD 40 YF126ST 18900 450 11.25 2 1 PPA 40 YF126ST 6636.5 165 CarboLite 16/20 1 6636.5 4.12 3 2 PPA 40 YF126ST 6945.6 180 CarboLite 16/20 2 13891.2 4.5 4 3 PPA 40 YF126ST 7230.8 195 CarboLite 16/20 3 21692.4 4.87 5 4 PPA 40 YF126ST 6959.1 195 CarboLite 16/20 4 27836.4 4.87 6 5 PPA 40 YF126ST 6707 195 CarboLite 16/20 5 33535 4.87 7 6 PPA 40 YF126ST 6472.8 195 CarboLite 16/20 6 38836.8 4.88 8 7 PPA 40 YF126ST 5933.4 185 CarboLite 16/20 7 41533.8 4.62 9 8 PPA 40 YF126ST 5274.3 170 CarboLite 16/20 8 42194.4 4.25 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.6 23.32 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 71059.5 226156.5 1929.98 48.25 NDBI-034 Stage N/A Page 43 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 7 6671.4 228.64 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4051.51 4280.15 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 7 4.33 604.23 191.4 0.59 NDBI-034 Stage N/A Page 44 of 97 Stage 8 ǣ Zoneset name: Stage 8 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4039.47 29.83 0.7 2838.1 2786554.2 0.25 2500 Shale 4069.29 26.73 0.66 2686.39 2786554.2 0.25 2500 Top 3.2 NAN CS 4096.03 3.61 0.6 2479.13 1159218.9 0.26 600 Siltstone 4099.64 1.81 0.62 2530.04 1629236.3 0.26 1500 CleanSandstone 4101.44 1.8 0.6 2465.5 979798.8 0.26 600 Siltstone 4103.25 3.61 0.61 2487.54 1350455.1 0.26 1500 CleanSandstone 4106.86 3.58 0.61 2506.25 1206390.9 0.26 600 Siltstone 4110.43 3.61 0.61 2496.1 1313860.7 0.26 1500 CleanSandstone 4114.04 7.18 0.61 2499.44 1266403.2 0.26 600 Siltstone 4121.23 1.81 0.61 2498.13 1082935.6 0.26 1500 DirtySandstone 4123.03 1.8 0.62 2569.2 1222900.8 0.26 600 Shale 4124.84 1.8 0.62 2574.42 1419038.4 0.26 2500 DirtySandstone 4126.64 1.81 0.61 2538.31 1403385.6 0.26 600 NDBI-034 Stage N/A Page 45 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Siltstone 4128.44 8.99 0.62 2554.11 1402756.3 0.26 1500 Shale 4137.43 3.61 0.66 2711.19 2181052.3 0.25 2500 DirtySandstone 4141.04 5.41 0.62 2573.26 1662780.4 0.26 1500 Siltstone 4146.46 1.77 0.63 2604.44 1963674.5 0.26 2500 DirtySandstone 4148.23 3.71 0.62 2581.38 1742901.7 0.26 1500 Siltstone 4151.94 5.41 0.63 2617.5 1681056.2 0.26 2500 Siltstone 4157.35 1.81 0.62 2586.46 1561073 0.26 1500 DirtySandstone 4159.15 1.8 0.62 2570.94 1262913.1 0.26 2500 Siltstone 4160.96 3.58 0.63 2630.84 1816969.7 0.26 1500 Shale 4164.53 11.02 0.65 2693.79 2238744.4 0.25 2500 CleanSandstone 4175.56 1.97 0.61 2535.26 1001510.6 0.26 600 Siltstone 4177.53 4 0.62 2591.39 1571504.2 0.26 1500 CleanSandstone 4181.53 2 0.6 2530.33 1267177.7 0.26 600 Shale 4183.53 2.01 0.66 2749.34 2789765.8 0.25 2500 Siltstone 4185.53 2 0.62 2583.12 1409418.9 0.26 1500 Shale 4187.53 2.1 0.66 2751.95 2789765.8 0.25 2500 NDBI-034 Stage N/A Page 46 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) DirtySandstone 4189.63 4 0.61 2556.87 1435306.6 0.26 1500 Siltstone 4193.64 4 0.62 2609.66 1765617.4 0.26 2500 DirtySandstone 4197.64 4 0.61 2578.48 1435651.3 0.26 1500 CleanSandstone 4201.64 2.1 0.59 2483.77 935658.3 0.26 2500 Siltstone 4203.74 4.01 0.62 2615.9 1491142.7 0.26 1500 Shale 4207.74 2 0.66 2765.14 2789765.8 0.25 2500 DirtySandstone 4209.74 10.99 0.62 2600.82 1462838 0.26 1500 Shale 4220.73 27 0.65 2760.79 2560999.9 0.25 2500 Siltstone 4247.74 2 0.63 2693.79 1857874.8 0.26 1500 Shale 4249.74 10.01 0.66 2791.11 2552268.6 0.25 2500 Siltstone 4259.74 2 0.63 2671.45 1509543.6 0.26 1500 Shale 4261.75 4.1 0.64 2728.89 2349461.1 0.25 2500 Siltstone 4265.85 2 0.64 2713.66 1482677.8 0.25 1500 Shale 4267.85 96.39 0.65 2818.37 2604074 0.25 2500 DirtySandstone 4364.24 2 0.61 2662.75 1153391 0.26 1500 Shale 4366.24 38.19 0.65 2872.33 2733692 0.25 2500 NDBI-034 Stage N/A Page 47 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Siltstone 4404.43 2 0.62 2735.85 1526263.4 0.26 1500 Shale 4406.43 46.23 0.65 2901.33 2704369.9 0.25 2500 Siltstone 4452.66 1.97 0.64 2828.09 1825853.3 0.25 1500 Shale 4454.63 9.84 0.65 2912.07 2657615 0.25 2500 NDBI-034 Stage N/A Page 48 of 97 ǣ Name: Stage 8 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 8 PAD 40 YF126ST 18900 450 11.25 2 1 PPA 40 YF126ST 6636.5 165 CarboLite 16/20 1 6636.5 4.12 3 2 PPA 40 YF126ST 6945.6 180 CarboLite 16/20 2 13891.2 4.5 4 3 PPA 40 YF126ST 7230.8 195 CarboLite 16/20 3 21692.4 4.87 5 4 PPA 40 YF126ST 6959.1 195 CarboLite 16/20 4 27836.4 4.87 6 5 PPA 40 YF126ST 6707 195 CarboLite 16/20 5 33535 4.87 7 6 PPA 40 YF126ST 6472.8 195 CarboLite 16/20 6 38836.8 4.88 8 7 PPA 40 YF126ST 5933.4 185 CarboLite 16/20 7 41533.8 4.62 9 8 PPA 40 YF126ST 5274.3 170 CarboLite 16/20 8 42194.4 4.25 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.6 23.32 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 71059.5 226156.5 1929.98 48.25 NDBI-034 Stage N/A Page 49 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 8 6539.3 225.15 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4052.05 4277.2 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 8 4.55 591.24 193.3 0.61 NDBI-034 Stage N/A Page 50 of 97 Stage 9 ǣ Zoneset name: Stage 9 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4045.18 29.83 0.7 2842.16 2786554.2 0.25 2500 Shale 4075 26.73 0.66 2690.01 2786554.2 0.25 2500 Top 3.2 NAN CS 4101.74 3.61 0.6 2482.61 1159218.9 0.26 600 Siltstone 4105.35 1.81 0.62 2533.52 1629236.3 0.26 1500 CleanSandstone 4107.15 1.8 0.6 2468.98 979798.8 0.26 600 Siltstone 4108.96 3.61 0.61 2491.02 1350455.1 0.26 1500 CleanSandstone 4112.57 3.58 0.61 2509.73 1206390.9 0.26 600 Siltstone 4116.14 3.61 0.61 2499.58 1313860.7 0.26 1500 CleanSandstone 4119.75 7.18 0.61 2502.92 1266403.2 0.26 600 Siltstone 4126.94 1.81 0.61 2501.61 1082935.6 0.26 1500 DirtySandstone 4128.74 1.8 0.62 2572.82 1222900.8 0.26 600 Shale 4130.54 1.8 0.62 2578.05 1419038.4 0.26 2500 NDBI-034 Stage N/A Page 51 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) DirtySandstone 4132.35 1.81 0.61 2541.93 1403385.6 0.26 600 Siltstone 4134.15 8.99 0.62 2557.74 1402756.3 0.26 1500 Shale 4143.14 3.61 0.66 2714.96 2181052.3 0.25 2500 DirtySandstone 4146.75 5.41 0.62 2576.74 1662780.4 0.26 1500 Siltstone 4152.17 1.77 0.63 2608.07 1963674.5 0.26 2500 DirtySandstone 4153.94 3.71 0.62 2585.01 1742901.7 0.26 1500 Siltstone 4157.64 5.41 0.63 2620.98 1681056.2 0.26 2500 Siltstone 4163.06 1.81 0.62 2590.08 1561073 0.26 1500 DirtySandstone 4164.86 1.8 0.62 2574.56 1262913.1 0.26 2500 Siltstone 4166.67 3.58 0.63 2634.47 1816969.7 0.26 1500 Shale 4170.24 11.02 0.65 2697.56 2238744.4 0.25 2500 CleanSandstone 4181.27 1.97 0.61 2538.74 1001510.6 0.26 600 Siltstone 4183.23 4 0.62 2594.87 1571504.2 0.26 1500 CleanSandstone 4187.24 2 0.6 2533.81 1267177.7 0.26 600 Shale 4189.24 2.01 0.66 2753.11 2789765.8 0.25 2500 Siltstone 4191.24 2 0.62 2586.6 1409418.9 0.26 1500 NDBI-034 Stage N/A Page 52 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4193.24 2.1 0.66 2755.57 2789765.8 0.25 2500 DirtySandstone 4195.34 4 0.61 2560.35 1435306.6 0.26 1500 Siltstone 4199.34 4 0.62 2613.29 1765617.4 0.26 2500 DirtySandstone 4203.35 4 0.61 2582.11 1435651.3 0.26 1500 CleanSandstone 4207.35 2.1 0.59 2487.25 935658.3 0.26 2500 Siltstone 4209.45 4.01 0.62 2619.38 1491142.7 0.26 1500 Shale 4213.45 2 0.66 2768.77 2789765.8 0.25 2500 DirtySandstone 4215.45 10.99 0.62 2604.3 1462838 0.26 1500 Shale 4226.44 27 0.65 2764.42 2560999.9 0.25 2500 Siltstone 4253.44 2 0.63 2697.41 1857874.8 0.26 1500 Shale 4255.45 10.01 0.66 2794.88 2552268.6 0.25 2500 Siltstone 4265.45 2 0.63 2675.08 1509543.6 0.26 1500 Shale 4267.45 4.1 0.64 2732.51 2349461.1 0.25 2500 Siltstone 4271.56 2 0.64 2717.28 1482677.8 0.25 1500 Shale 4273.56 96.39 0.65 2822.14 2604074 0.25 2500 DirtySandstone 4369.95 2 0.61 2666.23 1153391 0.26 1500 NDBI-034 Stage N/A Page 53 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4371.95 38.19 0.65 2876.1 2733692 0.25 2500 Siltstone 4410.14 2 0.62 2739.47 1526263.4 0.26 1500 Shale 4412.14 46.23 0.65 2905.11 2704369.9 0.25 2500 Siltstone 4458.37 1.97 0.64 2831.72 1825853.3 0.25 1500 Shale 4460.33 9.84 0.65 2915.84 2657615 0.25 2500 ǣ Name: Stage 9 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 9 PAD 40 YF126ST 18900 450 11.25 2 1 PPA 40 YF126ST 6636.5 165 CarboLite 16/20 1 6636.5 4.12 3 2 PPA 40 YF126ST 6945.6 180 CarboLite 16/20 2 13891.2 4.5 4 3 PPA 40 YF126ST 7230.8 195 CarboLite 16/20 3 21692.4 4.87 5 4 PPA 40 YF126ST 6959.1 195 CarboLite 16/20 4 27836.4 4.87 6 5 PPA 40 YF126ST 6707 195 CarboLite 16/20 5 33535 4.87 7 6 PPA 40 YF126ST 6472.8 195 CarboLite 16/20 6 38836.8 4.88 NDBI-034 Stage N/A Page 54 of 97 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 8 7 PPA 40 YF126ST 5933.4 185 CarboLite 16/20 7 41533.8 4.62 9 8 PPA 40 YF126ST 5274.3 170 CarboLite 16/20 8 42194.4 4.25 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.6 23.32 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 71059.5 226156.5 1929.98 48.25 NDBI-034 Stage N/A Page 55 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 9 6260.1 353.49 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4039 4392.49 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 9 1.39 985.25 294.84 0.31 NDBI-034 Stage N/A Page 56 of 97 Stage 10 ǣ Zoneset name: Stage 10 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4044.16 29.83 0.7 2841.43 2786554.2 0.25 2500 Shale 4074.02 26.73 0.66 2689.43 2786554.2 0.25 2500 Top 3.2 NAN CS 4100.72 3.61 0.6 2482.03 1159218.9 0.26 600 Siltstone 4104.33 1.81 0.62 2532.94 1629236.3 0.26 1500 CleanSandstone 4106.14 1.8 0.6 2468.4 979798.8 0.26 600 Siltstone 4107.94 3.61 0.61 2490.44 1350455.1 0.26 1500 CleanSandstone 4111.55 3.58 0.61 2509.15 1206390.9 0.26 600 Siltstone 4115.12 3.61 0.61 2499 1313860.7 0.26 1500 CleanSandstone 4118.77 7.18 0.61 2502.34 1266403.2 0.26 600 Siltstone 4125.92 1.81 0.61 2500.89 1082935.6 0.26 1500 DirtySandstone 4127.76 1.8 0.62 2572.1 1222900.8 0.26 600 Shale 4129.53 1.8 0.62 2577.32 1419038.4 0.26 2500 NDBI-034 Stage N/A Page 57 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) DirtySandstone 4131.33 1.81 0.61 2541.21 1403385.6 0.26 600 Siltstone 4133.14 8.99 0.62 2557.02 1402756.3 0.26 1500 Shale 4142.13 3.61 0.66 2714.24 2181052.3 0.25 2500 DirtySandstone 4145.73 5.41 0.62 2576.16 1662780.4 0.26 1500 Siltstone 4151.15 1.77 0.63 2607.49 1963674.5 0.26 2500 DirtySandstone 4152.92 3.71 0.62 2584.28 1742901.7 0.26 1500 Siltstone 4156.63 5.41 0.63 2620.4 1681056.2 0.26 2500 Siltstone 4162.04 1.81 0.62 2589.36 1561073 0.26 1500 DirtySandstone 4163.85 1.8 0.62 2573.84 1262913.1 0.26 2500 Siltstone 4165.65 3.58 0.63 2633.89 1816969.7 0.26 1500 Shale 4169.23 11.02 0.65 2696.83 2238744.4 0.25 2500 CleanSandstone 4180.25 1.97 0.61 2538.02 1001510.6 0.26 600 Siltstone 4182.22 4 0.62 2594.29 1571504.2 0.26 1500 CleanSandstone 4186.22 2 0.6 2533.23 1267177.7 0.26 600 Shale 4188.22 2.01 0.66 2752.38 2789765.8 0.25 2500 Siltstone 4190.26 2 0.62 2586.02 1409418.9 0.26 1500 NDBI-034 Stage N/A Page 58 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4192.22 2.1 0.66 2754.99 2789765.8 0.25 2500 DirtySandstone 4194.32 4 0.61 2559.77 1435306.6 0.26 1500 Siltstone 4198.33 4 0.62 2612.56 1765617.4 0.26 2500 DirtySandstone 4202.33 4 0.61 2581.38 1435651.3 0.26 1500 CleanSandstone 4206.33 2.1 0.59 2486.53 935658.3 0.26 2500 Siltstone 4208.43 4.01 0.62 2618.8 1491142.7 0.26 1500 Shale 4212.43 2 0.66 2768.19 2789765.8 0.25 2500 DirtySandstone 4214.44 10.99 0.62 2603.72 1462838 0.26 1500 Shale 4225.43 27 0.65 2763.84 2560999.9 0.25 2500 Siltstone 4252.43 2 0.63 2696.69 1857874.8 0.26 1500 Shale 4254.43 10.01 0.66 2794.3 2552268.6 0.25 2500 Siltstone 4264.44 2 0.63 2674.35 1509543.6 0.26 1500 Shale 4266.44 4.1 0.64 2731.93 2349461.1 0.25 2500 Siltstone 4270.54 2 0.64 2716.56 1482677.8 0.25 1500 Shale 4272.54 96.39 0.65 2821.42 2604074 0.25 2500 DirtySandstone 4368.93 2 0.61 2665.65 1153391 0.26 1500 NDBI-034 Stage N/A Page 59 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4370.93 38.19 0.65 2875.37 2733692 0.25 2500 Siltstone 4409.12 2 0.62 2738.75 1526263.4 0.26 1500 Shale 4411.12 46.23 0.65 2904.38 2704369.9 0.25 2500 Siltstone 4457.35 1.97 0.64 2831.14 1825853.3 0.25 1500 Shale 4459.32 9.84 0.65 2915.11 2657615 0.25 2500 ǣ Name: Stage 10 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 10 PAD 40 YF126ST 18900 450 11.25 2 1 PPA 40 YF126ST 6636.5 165 CarboLite 16/20 1 6636.5 4.12 3 2 PPA 40 YF126ST 6945.6 180 CarboLite 16/20 2 13891.2 4.5 4 3 PPA 40 YF126ST 7230.8 195 CarboLite 16/20 3 21692.4 4.87 5 4 PPA 40 YF126ST 6959.1 195 CarboLite 16/20 4 27836.4 4.87 6 5 PPA 40 YF126ST 6707 195 CarboLite 16/20 5 33535 4.87 7 6 PPA 40 YF126ST 6472.8 195 CarboLite 16/20 6 38836.8 4.88 NDBI-034 Stage N/A Page 60 of 97 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 8 7 PPA 40 YF126ST 5933.4 185 CarboLite 16/20 7 41533.8 4.62 9 8 PPA 40 YF126ST 5274.3 170 CarboLite 16/20 8 42194.4 4.25 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.6 23.32 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 71059.5 226156.5 1929.98 48.25 NDBI-034 Stage N/A Page 61 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Bottomhole Pressure (psi) Max Height (ft) Stage 10 3611.6 230.56 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4062.26 4292.82 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 10 3.28 628.88 184.18 0.47 NDBI-034 Stage N/A Page 62 of 97 Stage 11 ǣ Zoneset name: Stage 11 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4061.35 10.01 0.73 2975.3 1461000.3 0.22 2500 Shale 4071.36 14.99 0.69 2834.76 1762000.5 0.22 2500 Nanushuk 3 SS 4086.35 15.32 0.68 2775.88 1898000.5 0.22 2000 Top Nan 4101.67 6 0.65 2664.2 838900.2 0.27 1000 Shale 4107.68 2.01 0.7 2895.1 2665000.7 0.23 2500 Nan DS 4109.68 1.47 0.64 2617.5 819400.2 0.27 1500 Nan DS 4111.15 2 0.64 2648.82 1222000.3 0.26 1500 Nan CS 4113.16 13.03 0.63 2595.16 869100.2 0.27 1000 Nan CS 4126.18 1.47 0.61 2529.75 1002000.3 0.27 1000 Nan CS 4127.66 4.01 0.65 2663.91 706600.2 0.28 1000 Nan CS 4131.66 8.99 0.61 2510.6 1166000.3 0.27 1000 Nan CS 4140.65 7.02 0.65 2693.21 769000.2 0.27 1000 NDBI-034 Stage N/A Page 63 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan CS 4147.67 5.48 0.62 2575.58 1278000.4 0.26 1000 Nan CS 4153.15 13.02 0.65 2699.01 691700.2 0.28 1000 Nan DS 4166.17 2.49 0.68 2852.89 1748000.4 0.26 1500 Nan DS 4168.67 12.5 0.64 2655.21 1111000.3 0.27 1500 Nan DS 4181.17 4.01 0.7 2927.73 1692000.4 0.26 1500 Nan DS 4185.17 2.49 0.65 2709.01 822100.2 0.27 1500 Shale 4187.66 2 0.7 2919.46 2665000.7 0.23 2500 Nan DS 4189.67 4 0.65 2716.12 1159000.3 0.27 1500 Nan DS 4193.67 4.01 0.63 2630.69 838300.2 0.27 1000 Shale 4197.67 4 0.7 2958.19 2665000.7 0.23 2500 Nan DS 4201.67 6 0.65 2715.83 1133000.3 0.27 1500 Shale 4207.68 2.01 0.7 2933.39 2665000.7 0.23 2500 Nan DS 4209.68 2 0.63 2647.08 1078000.3 0.27 1500 Nan DS 4211.68 6.49 0.67 2816.05 1694000.4 0.26 1500 Nan DS 4218.18 4.01 0.62 2608.5 898500.2 0.27 1500 Nan DS 4222.18 3.47 0.65 2745.13 929100.3 0.27 1500 NDBI-034 Stage N/A Page 64 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4225.66 2 0.7 2945.86 2665000.7 0.23 2500 Nan DS 4227.66 12.5 0.65 2731.93 1562000.4 0.26 1500 Nan DS 4240.16 2.01 0.66 2781.53 1397000.4 0.26 1500 Shale 4242.16 2 0.7 2957.46 2665000.7 0.23 2500 Nan DS 4244.16 2 0.65 2763.55 1242000.3 0.26 1500 Shale 4246.16 8 0.69 2928.31 2665000.7 0.23 2500 Nan DS 4254.17 2 0.64 2723.81 932500.2 0.27 1500 Shale 4256.17 4.01 0.7 2967.91 2665000.7 0.23 2500 Nan DS 4260.17 6 0.65 2753.83 1427000.4 0.26 1500 Shale 4266.17 8.01 0.7 2976.32 2665000.7 0.23 2500 Nan DS 4274.18 6.49 0.65 2800.53 1469000.4 0.26 1500 Shale 4280.68 6.01 0.69 2951.52 2665000.7 0.23 2500 Nan DS 4286.68 2 0.64 2759.92 838400.2 0.27 1000 Shale 4288.68 1.97 0.7 2989.95 2665000.7 0.23 2500 Nan DS 4290.65 4 0.65 2790.24 1469000.4 0.26 1500 Shale 4294.65 2 0.7 2994.01 2665000.7 0.23 2500 NDBI-034 Stage N/A Page 65 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan DS 4296.65 6 0.67 2884.22 1545000.4 0.26 1500 Shale 4302.66 12.01 0.7 3003.15 2665000.7 0.23 2500 Nan DS 4314.67 2.5 0.65 2787.92 1214000.3 0.27 1500 Shale 4317.16 20.01 0.69 2981.4 2665000.7 0.23 2500 NDBI-034 Stage N/A Page 66 of 97 ǣ Name: Stage 11 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 11 PAD 40 YF126ST 19950 475 11.88 2 1 PPA 40 YF126ST 6837.6 170 CarboLite 16/20 1 6837.6 4.25 3 2 PPA 40 YF126ST 7717.4 200 CarboLite 16/20 2 15434.8 5 4 3 PPA 40 YF126ST 8157.8 220 CarboLite 16/20 3 24473.4 5.5 5 4 PPA 40 YF126ST 7851.2 220 CarboLite 16/20 4 31404.8 5.5 6 5 PPA 40 YF126ST 7566.9 220 CarboLite 16/20 5 37834.5 5.5 7 6 PPA 40 YF126ST 7302.6 220 CarboLite 16/20 6 43815.6 5.5 8 7 PPA 40 YF126ST 6093.9 190 CarboLite 16/20 7 42657.3 4.75 9 8 PPA 40 YF126ST 5274.3 170 CarboLite 16/20 8 42194.4 4.25 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 25.99 22.78 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 76751.7 244652.4 2084.98 52.12 NDBI-034 Stage N/A Page 67 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 11 5971.5 240.91 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4066.44 4307.35 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 11 1.39 1012.59 184.6 0.39 NDBI-034 Stage N/A Page 68 of 97 Stage 12 ǣ Zoneset name: Stage 12 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4062.37 10.01 0.73 2976.17 1461000.3 0.22 2500 Shale 4072.38 14.99 0.69 2835.49 1762000.5 0.22 2500 Nanushuk 3 SS 4087.37 15.32 0.68 2776.46 1898000.5 0.22 2000 Top Nan 4102.69 6 0.65 2664.78 838900.2 0.27 1000 Shale 4108.69 2.01 0.7 2895.82 2665000.7 0.23 2500 Nan DS 4110.7 1.47 0.64 2618.22 819400.2 0.27 1500 Nan DS 4112.17 2 0.64 2649.55 1222000.3 0.26 1500 Nan CS 4114.17 13.03 0.63 2595.89 869100.2 0.27 1000 Nan CS 4127.2 1.47 0.61 2530.47 1002000.3 0.27 1000 Nan CS 4128.67 4.01 0.65 2664.63 706600.2 0.28 1000 Nan CS 4132.68 8.99 0.61 2511.18 1166000.3 0.27 1000 Nan CS 4141.67 7.02 0.65 2693.79 769000.2 0.27 1000 NDBI-034 Stage N/A Page 69 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan CS 4148.69 5.48 0.62 2576.31 1278000.4 0.26 1000 Nan CS 4154.17 13.02 0.65 2699.73 691700.2 0.28 1000 Nan DS 4167.19 2.49 0.68 2853.62 1748000.4 0.26 1500 Nan DS 4169.69 12.5 0.64 2655.93 1111000.3 0.27 1500 Nan DS 4182.19 4.01 0.7 2928.46 1692000.4 0.26 1500 Nan DS 4186.19 2.49 0.65 2709.74 822100.2 0.27 1500 Shale 4188.68 2 0.7 2920.19 2665000.7 0.23 2500 Nan DS 4190.68 4 0.65 2716.85 1159000.3 0.27 1500 Nan DS 4194.69 4.01 0.63 2631.27 838300.2 0.27 1000 Shale 4198.69 4 0.7 2958.91 2665000.7 0.23 2500 Nan DS 4202.69 6 0.65 2716.56 1133000.3 0.27 1500 Shale 4208.69 2.01 0.7 2934.11 2665000.7 0.23 2500 Nan DS 4210.7 2 0.63 2647.66 1078000.3 0.27 1500 Nan DS 4212.7 6.49 0.67 2816.78 1694000.4 0.26 1500 Nan DS 4219.19 4.01 0.62 2609.08 898500.2 0.27 1500 Nan DS 4223.2 3.47 0.65 2745.85 929100.3 0.27 1500 NDBI-034 Stage N/A Page 70 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4226.67 2 0.7 2946.59 2665000.7 0.23 2500 Nan DS 4228.67 12.5 0.65 2732.51 1562000.4 0.26 1500 Nan DS 4241.17 2.01 0.66 2782.11 1397000.4 0.26 1500 Shale 4243.18 2 0.7 2958.19 2665000.7 0.23 2500 Nan DS 4245.18 2 0.65 2764.27 1242000.3 0.26 1500 Shale 4247.18 8 0.69 2929.04 2665000.7 0.23 2500 Nan DS 4255.18 2 0.64 2724.39 932500.2 0.27 1500 Shale 4257.19 4.01 0.7 2968.63 2665000.7 0.23 2500 Nan DS 4261.19 6 0.65 2754.56 1427000.4 0.26 1500 Shale 4267.19 8.01 0.7 2977.04 2665000.7 0.23 2500 Nan DS 4275.2 6.49 0.65 2801.11 1469000.4 0.26 1500 Shale 4281.69 6.01 0.69 2952.1 2665000.7 0.23 2500 Nan DS 4287.7 2 0.64 2760.5 838400.2 0.27 1000 Shale 4289.7 1.97 0.7 2990.68 2665000.7 0.23 2500 Nan DS 4291.67 4 0.65 2790.96 1469000.4 0.26 1500 Shale 4295.67 2 0.7 2994.74 2665000.7 0.23 2500 NDBI-034 Stage N/A Page 71 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan DS 4297.67 6 0.67 2884.95 1545000.4 0.26 1500 Shale 4303.67 12.01 0.7 3003.88 2665000.7 0.23 2500 Nan DS 4315.68 2.5 0.65 2788.64 1214000.3 0.27 1500 Shale 4318.18 20.01 0.69 2982.12 2665000.7 0.23 2500 ǣ Name: Stage 12 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 12 PAD 40 YF126ST 17850 425 CarboLite 16/20 0 0 10.62 2 1 PPA 40 YF126ST 8044.2 200 CarboLite 16/20 1 8044.2 5 3 2 PPA 40 YF126ST 8682.2 225 CarboLite 16/20 2 17364.4 5.62 4 4 PPA 40 YF126ST 9814.1 275 CarboLite 16/20 4 39256.4 6.87 5 6 PPA 40 YF126ST 8630.4 260 CarboLite 16/20 6 51782.4 6.5 6 8 PPA 40 YF126ST 7446 240 CarboLite 16/20 8 59568 6 7 10 PPA 40 YF126ST 5824.7 200 CarboLite 16/20 10 58247 5 NDBI-034 Stage N/A Page 72 of 97 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.93 23.29 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 66291.6 234262.4 1825 45.62 NDBI-034 Stage N/A Page 73 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 12 6268.9 256 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4062.43 4318.43 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 12 1.64 937.77 217.17 0.42 NDBI-034 Stage N/A Page 74 of 97 Stage 13 ǣ Zoneset name: Stage 13 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4062.76 10.01 0.73 2976.32 1461000.3 0.22 2500 Shale 4072.77 14.99 0.69 2835.78 1762000.5 0.22 2500 Nanushuk 3 SS 4087.76 15.32 0.68 2776.75 1898000.5 0.22 2000 Top Nan 4103.08 6 0.65 2665.07 838900.2 0.27 1000 Shale 4109.09 2.01 0.7 2895.97 2665000.7 0.23 2500 Nan DS 4111.09 1.47 0.64 2618.37 819400.2 0.27 1500 Nan DS 4112.57 2 0.64 2649.84 1222000.3 0.26 1500 Nan CS 4114.57 13.03 0.63 2596.03 869100.2 0.27 1000 Nan CS 4127.59 1.47 0.61 2530.62 1002000.3 0.27 1000 Nan CS 4129.07 4.01 0.65 2664.92 706600.2 0.28 1000 Nan CS 4133.07 8.99 0.61 2511.47 1166000.3 0.27 1000 Nan CS 4142.06 7.02 0.65 2694.08 769000.2 0.27 1000 NDBI-034 Stage N/A Page 75 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan CS 4149.08 5.48 0.62 2576.6 1278000.4 0.26 1000 Nan CS 4154.56 13.02 0.65 2700.02 691700.2 0.28 1000 Nan DS 4167.59 2.49 0.68 2853.91 1748000.4 0.26 1500 Nan DS 4170.08 12.5 0.64 2656.08 1111000.3 0.27 1500 Nan DS 4182.58 4.01 0.7 2928.75 1692000.4 0.26 1500 Nan DS 4186.58 2.49 0.65 2710.03 822100.2 0.27 1500 Shale 4189.07 2 0.7 2920.48 2665000.7 0.23 2500 Nan DS 4191.08 4 0.65 2717.14 1159000.3 0.27 1500 Nan DS 4195.08 4.01 0.63 2631.56 838300.2 0.27 1000 Shale 4199.08 4 0.7 2959.06 2665000.7 0.23 2500 Nan DS 4203.08 6 0.65 2716.85 1133000.3 0.27 1500 Shale 4209.09 2.01 0.7 2934.4 2665000.7 0.23 2500 Nan DS 4211.09 2 0.63 2647.95 1078000.3 0.27 1500 Nan DS 4213.09 6.49 0.67 2817.07 1694000.4 0.26 1500 Nan DS 4219.59 4.01 0.62 2609.37 898500.2 0.27 1500 Nan DS 4223.59 3.47 0.65 2746.14 929100.3 0.27 1500 NDBI-034 Stage N/A Page 76 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4227.07 2 0.7 2946.88 2665000.7 0.23 2500 Nan DS 4229.07 12.5 0.65 2732.8 1562000.4 0.26 1500 Nan DS 4241.57 2.01 0.66 2782.4 1397000.4 0.26 1500 Shale 4243.57 2 0.7 2958.48 2665000.7 0.23 2500 Nan DS 4245.57 2 0.65 2764.56 1242000.3 0.26 1500 Shale 4247.57 8 0.69 2929.18 2665000.7 0.23 2500 Nan DS 4255.58 2 0.64 2724.68 932500.2 0.27 1500 Shale 4257.58 4.01 0.7 2968.92 2665000.7 0.23 2500 Nan DS 4261.58 6 0.65 2754.85 1427000.4 0.26 1500 Shale 4267.59 8.01 0.7 2977.33 2665000.7 0.23 2500 Nan DS 4275.59 6.49 0.65 2801.4 1469000.4 0.26 1500 Shale 4282.09 6.01 0.69 2952.39 2665000.7 0.23 2500 Nan DS 4288.09 2 0.64 2760.79 838400.2 0.27 1000 Shale 4290.09 1.97 0.7 2990.97 2665000.7 0.23 2500 Nan DS 4292.06 4 0.65 2791.25 1469000.4 0.26 1500 Shale 4296.06 2 0.7 2995.03 2665000.7 0.23 2500 NDBI-034 Stage N/A Page 77 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan DS 4298.06 6 0.67 2885.24 1545000.4 0.26 1500 Shale 4304.07 12.01 0.7 3004.17 2665000.7 0.23 2500 Nan DS 4316.08 2.5 0.65 2788.93 1214000.3 0.27 1500 Shale 4318.57 20.01 0.69 2982.27 2665000.7 0.23 2500 ǣ Name: Stage 13 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 13 PAD 40 YF126ST 17850 425 CarboLite 16/20 0 0 10.62 2 1 PPA 40 YF126ST 8044.2 200 CarboLite 16/20 1 8044.2 5 3 2 PPA 40 YF126ST 8682.2 225 CarboLite 16/20 2 17364.4 5.62 4 4 PPA 40 YF126ST 9814.1 275 CarboLite 16/20 4 39256.4 6.87 5 6 PPA 40 YF126ST 8630.4 260 CarboLite 16/20 6 51782.4 6.5 6 8 PPA 40 YF126ST 7446 240 CarboLite 16/20 8 59568 6 7 10 PPA 40 YF126ST 5824.7 200 CarboLite 16/20 10 58247 5 NDBI-034 Stage N/A Page 78 of 97 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.93 23.29 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 66291.6 234262.4 1825 45.62 NDBI-034 Stage N/A Page 79 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 13 6096.1 240.22 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4067.79 4308.01 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 13 1.58 1005.16 183.49 0.44 NDBI-034 Stage N/A Page 80 of 97 Stage 14 ǣ Zoneset name: Stage 14 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4062.76 10.01 0.73 2976.32 1461000.3 0.22 2500 Shale 4072.77 14.99 0.69 2835.78 1762000.5 0.22 2500 Nanushuk 3 SS 4087.76 15.32 0.68 2776.75 1898000.5 0.22 2000 Top Nan 4103.08 6 0.65 2665.07 838900.2 0.27 1000 Shale 4109.09 2.01 0.7 2895.97 2665000.7 0.23 2500 Nan DS 4111.09 1.47 0.64 2618.37 819400.2 0.27 1500 Nan DS 4112.57 2 0.64 2649.84 1222000.3 0.26 1500 Nan CS 4114.57 13.03 0.63 2596.03 869100.2 0.27 1000 Nan CS 4127.59 1.47 0.61 2530.62 1002000.3 0.27 1000 Nan CS 4129.07 4.01 0.65 2664.92 706600.2 0.28 1000 Nan CS 4133.07 8.99 0.61 2511.47 1166000.3 0.27 1000 Nan CS 4142.06 7.02 0.65 2694.08 769000.2 0.27 1000 NDBI-034 Stage N/A Page 81 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan CS 4149.08 5.48 0.62 2576.6 1278000.4 0.26 1000 Nan CS 4154.56 13.02 0.65 2700.02 691700.2 0.28 1000 Nan DS 4167.59 2.49 0.68 2853.91 1748000.4 0.26 1500 Nan DS 4170.08 12.5 0.64 2656.08 1111000.3 0.27 1500 Nan DS 4182.58 4.01 0.7 2928.75 1692000.4 0.26 1500 Nan DS 4186.58 2.49 0.65 2710.03 822100.2 0.27 1500 Shale 4189.07 2 0.7 2920.48 2665000.7 0.23 2500 Nan DS 4191.08 4 0.65 2717.14 1159000.3 0.27 1500 Nan DS 4195.08 4.01 0.63 2631.56 838300.2 0.27 1000 Shale 4199.08 4 0.7 2959.06 2665000.7 0.23 2500 Nan DS 4203.08 6 0.65 2716.85 1133000.3 0.27 1500 Shale 4209.09 2.01 0.7 2934.4 2665000.7 0.23 2500 Nan DS 4211.09 2 0.63 2647.95 1078000.3 0.27 1500 Nan DS 4213.09 6.49 0.67 2817.07 1694000.4 0.26 1500 Nan DS 4219.59 4.01 0.62 2609.37 898500.2 0.27 1500 Nan DS 4223.59 3.47 0.65 2746.14 929100.3 0.27 1500 NDBI-034 Stage N/A Page 82 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4227.07 2 0.7 2946.88 2665000.7 0.23 2500 Nan DS 4229.07 12.5 0.65 2732.8 1562000.4 0.26 1500 Nan DS 4241.57 2.01 0.66 2782.4 1397000.4 0.26 1500 Shale 4243.57 2 0.7 2958.48 2665000.7 0.23 2500 Nan DS 4245.57 2 0.65 2764.56 1242000.3 0.26 1500 Shale 4247.57 8 0.69 2929.18 2665000.7 0.23 2500 Nan DS 4255.58 2 0.64 2724.68 932500.2 0.27 1500 Shale 4257.58 4.01 0.7 2968.92 2665000.7 0.23 2500 Nan DS 4261.58 6 0.65 2754.85 1427000.4 0.26 1500 Shale 4267.59 8.01 0.7 2977.33 2665000.7 0.23 2500 Nan DS 4275.59 6.49 0.65 2801.4 1469000.4 0.26 1500 Shale 4282.09 6.01 0.69 2952.39 2665000.7 0.23 2500 Nan DS 4288.09 2 0.64 2760.79 838400.2 0.27 1000 Shale 4290.09 1.97 0.7 2990.97 2665000.7 0.23 2500 Nan DS 4292.06 4 0.65 2791.25 1469000.4 0.26 1500 Shale 4296.06 2 0.7 2995.03 2665000.7 0.23 2500 NDBI-034 Stage N/A Page 83 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan DS 4298.06 6 0.67 2885.24 1545000.4 0.26 1500 Shale 4304.07 12.01 0.7 3004.17 2665000.7 0.23 2500 Nan DS 4316.08 2.5 0.65 2788.93 1214000.3 0.27 1500 Shale 4318.57 20.01 0.69 2982.27 2665000.7 0.23 2500 ǣ Name: Stage 14 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 14 PAD 40 YF126ST 16170 385 CarboLite 16/20 0 0 9.62 2 1 PPA 40 YF126ST 7642 190 CarboLite 16/20 1 7642 4.75 3 3 PPA 40 YF126ST 7972.4 215 CarboLite 16/20 3 23917.2 5.37 4 5 PPA 40 YF126ST 8255 240 CarboLite 16/20 5 41275 6 5 7 PPA 40 YF126ST 7697.4 240 CarboLite 16/20 7 53881.8 6 6 9 PPA 40 YF126ST 6609.8 220 CarboLite 16/20 9 59488.2 5.5 7 10 PPA 40 YF126ST 5533.3 190 CarboLite 16/20 10 55333 4.75 NDBI-034 Stage N/A Page 84 of 97 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 27 22.92 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 59879.9 241537.2 1680 42 NDBI-034 Stage N/A Page 85 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 14 5981.2 234.52 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4066.56 4301.08 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 14 1.57 973.84 180.12 0.42 NDBI-034 Stage N/A Page 86 of 97 Stage 15 ǣ Zoneset name: Stage 15 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4063.16 10.01 0.73 2976.61 1461000.3 0.22 2500 Shale 4073.16 14.99 0.69 2836.07 1762000.5 0.22 2500 Nanushuk 3 SS 4088.16 15.32 0.68 2777.04 1898000.5 0.22 2000 Top Nan 4103.48 6 0.65 2665.36 838900.2 0.27 1000 Shale 4109.48 2.01 0.7 2896.26 2665000.7 0.23 2500 Nan DS 4111.48 1.47 0.64 2618.66 819400.2 0.27 1500 Nan DS 4112.96 2 0.64 2649.98 1222000.3 0.26 1500 Nan CS 4114.96 13.03 0.63 2596.32 869100.2 0.27 1000 Nan CS 4127.99 1.47 0.61 2530.91 1002000.3 0.27 1000 Nan CS 4129.46 4.01 0.65 2665.07 706600.2 0.28 1000 Nan CS 4133.46 8.99 0.61 2511.62 1166000.3 0.27 1000 Nan CS 4142.45 7.02 0.65 2694.37 769000.2 0.27 1000 NDBI-034 Stage N/A Page 87 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan CS 4149.48 5.48 0.62 2576.74 1278000.4 0.26 1000 Nan CS 4154.95 13.02 0.65 2700.31 691700.2 0.28 1000 Nan DS 4167.98 2.49 0.68 2854.2 1748000.4 0.26 1500 Nan DS 4170.47 12.5 0.64 2656.37 1111000.3 0.27 1500 Nan DS 4182.97 4.01 0.7 2929.04 1692000.4 0.26 1500 Nan DS 4186.98 2.49 0.65 2710.18 822100.2 0.27 1500 Shale 4189.47 2 0.7 2920.77 2665000.7 0.23 2500 Nan DS 4191.47 4 0.65 2717.28 1159000.3 0.27 1500 Nan DS 4195.47 4.01 0.63 2631.85 838300.2 0.27 1000 Shale 4199.48 4 0.7 2959.35 2665000.7 0.23 2500 Nan DS 4203.48 6 0.65 2716.99 1133000.3 0.27 1500 Shale 4209.48 2.01 0.7 2934.69 2665000.7 0.23 2500 Nan DS 4211.48 2 0.63 2648.24 1078000.3 0.27 1500 Nan DS 4213.48 6.49 0.67 2817.21 1694000.4 0.26 1500 Nan DS 4219.98 4.01 0.62 2609.52 898500.2 0.27 1500 Nan DS 4223.98 3.47 0.65 2746.29 929100.3 0.27 1500 NDBI-034 Stage N/A Page 88 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4227.46 2 0.7 2947.17 2665000.7 0.23 2500 Nan DS 4229.46 12.5 0.65 2733.09 1562000.4 0.26 1500 Nan DS 4241.96 2.01 0.66 2782.69 1397000.4 0.26 1500 Shale 4243.96 2 0.7 2958.77 2665000.7 0.23 2500 Nan DS 4245.96 2 0.65 2764.71 1242000.3 0.26 1500 Shale 4247.97 8 0.69 2929.47 2665000.7 0.23 2500 Nan DS 4255.97 2 0.64 2724.97 932500.2 0.27 1500 Shale 4257.97 4.01 0.7 2969.21 2665000.7 0.23 2500 Nan DS 4261.98 6 0.65 2754.99 1427000.4 0.26 1500 Shale 4267.98 8.01 0.7 2977.62 2665000.7 0.23 2500 Nan DS 4275.98 6.49 0.65 2801.69 1469000.4 0.26 1500 Shale 4282.48 6.01 0.69 2952.68 2665000.7 0.23 2500 Nan DS 4288.48 2 0.64 2761.08 838400.2 0.27 1000 Shale 4290.49 1.97 0.7 2991.26 2665000.7 0.23 2500 Nan DS 4292.45 4 0.65 2791.4 1469000.4 0.26 1500 Shale 4296.46 2 0.7 2995.32 2665000.7 0.23 2500 NDBI-034 Stage N/A Page 89 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan DS 4298.46 6 0.67 2885.53 1545000.4 0.26 1500 Shale 4304.46 12.01 0.7 3004.46 2665000.7 0.23 2500 Nan DS 4316.47 2.5 0.65 2789.08 1214000.3 0.27 1500 Shale 4318.96 20.01 0.69 2982.56 2665000.7 0.23 2500 ǣ Name: Stage 15 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 15 PAD 40 YF126ST 16170 385 CarboLite 16/20 0 0 9.62 2 1 PPA 40 YF126ST 7642 190 CarboLite 16/20 1 7642 4.75 3 3 PPA 40 YF126ST 7972.4 215 CarboLite 16/20 3 23917.2 5.37 4 5 PPA 40 YF126ST 8255 240 CarboLite 16/20 5 41275 6 5 7 PPA 40 YF126ST 7697.4 240 CarboLite 16/20 7 53881.8 6 6 9 PPA 40 YF126ST 6609.8 220 CarboLite 16/20 9 59488.2 5.5 7 10 PPA 40 YF126ST 5533.3 190 CarboLite 16/20 10 55333 4.75 NDBI-034 Stage N/A Page 90 of 97 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 27 22.92 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 59879.9 241537.2 1680 42 NDBI-034 Stage N/A Page 91 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max SurfacePressure (psi) Max Height (ft) Stage 15 5813.7 225.22 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4003 4228.22 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 15 1.74 928.49 174.72 0.44 NDBI-034 Stage N/A Page 92 of 97 Stage 16 ǣ Zoneset name: Stage 16 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4056.76 10.01 0.73 2972 1461000.3 0.22 2500 Shale 4066.77 14.99 0.69 2831.6 1762000.5 0.22 2500 Nanushuk 3 SS 4081.76 15.32 0.68 2772.7 1898000.5 0.22 2000 Top Nan 4097.08 6 0.65 2661.2 838900.2 0.27 1000 Shale 4103.08 2.01 0.7 2891.8 2665000.7 0.23 2500 Nan DS 4105.09 1.47 0.64 2614.6 819400.2 0.27 1500 Nan DS 4106.56 2 0.64 2645.9 1222000.3 0.26 1500 Nan CS 4108.56 13.03 0.63 2592.3 869100.2 0.27 1000 Nan CS 4121.59 1.47 0.61 2527 1002000.3 0.27 1000 Nan CS 4123.06 4.01 0.65 2661 706600.2 0.28 1000 Nan CS 4127.07 8.99 0.61 2507.8 1166000.3 0.27 1000 Nan CS 4136.06 7.02 0.65 2690.2 769000.2 0.27 1000 NDBI-034 Stage N/A Page 93 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan CS 4143.08 5.48 0.62 2572.8 1278000.4 0.26 1000 Nan CS 4148.56 13.02 0.65 2696.1 691700.2 0.28 1000 Nan DS 4161.58 2.49 0.68 2849.8 1748000.4 0.26 1500 Nan DS 4164.07 12.5 0.64 2652.3 1111000.3 0.27 1500 Nan DS 4176.57 4.01 0.7 2924.5 1692000.4 0.26 1500 Nan DS 4180.58 2.49 0.65 2706.1 822100.2 0.27 1500 Shale 4183.07 2 0.7 2916.3 2665000.7 0.23 2500 Nan DS 4185.07 4 0.65 2713.2 1159000.3 0.27 1500 Nan DS 4189.07 4.01 0.63 2627.8 838300.2 0.27 1000 Shale 4193.08 4 0.7 2954.9 2665000.7 0.23 2500 Nan DS 4197.08 6 0.65 2712.9 1133000.3 0.27 1500 Shale 4203.08 2.01 0.7 2930.2 2665000.7 0.23 2500 Nan DS 4205.09 2 0.63 2644.2 1078000.3 0.27 1500 Nan DS 4207.09 6.49 0.67 2813 1694000.4 0.26 1500 Nan DS 4213.58 4.01 0.62 2605.6 898500.2 0.27 1500 Nan DS 4217.59 3.47 0.65 2742.2 929100.3 0.27 1500 NDBI-034 Stage N/A Page 94 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Shale 4221.06 2 0.7 2942.7 2665000.7 0.23 2500 Nan DS 4223.06 12.5 0.65 2728.9 1562000.4 0.26 1500 Nan DS 4235.56 2.01 0.66 2778.5 1397000.4 0.26 1500 Shale 4237.57 2 0.7 2954.3 2665000.7 0.23 2500 Nan DS 4239.57 2 0.65 2760.6 1242000.3 0.26 1500 Shale 4241.57 8 0.69 2925.1 2665000.7 0.23 2500 Nan DS 4249.57 2 0.64 2720.8 932500.2 0.27 1500 Shale 4251.57 4.01 0.7 2964.7 2665000.7 0.23 2500 Nan DS 4255.58 6 0.65 2750.9 1427000.4 0.26 1500 Shale 4261.58 8.01 0.7 2973.1 2665000.7 0.23 2500 Nan DS 4269.59 6.49 0.65 2797.5 1469000.4 0.26 1500 Shale 4276.08 6.01 0.69 2948.3 2665000.7 0.23 2500 Nan DS 4282.09 2 0.64 2756.9 838400.2 0.27 1000 Shale 4284.09 1.97 0.7 2986.8 2665000.7 0.23 2500 Nan DS 4286.06 4 0.65 2787.3 1469000.4 0.26 1500 Shale 4290.06 2 0.7 2990.8 2665000.7 0.23 2500 NDBI-034 Stage N/A Page 95 of 97 Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan DS 4292.06 6 0.67 2881.2 1545000.4 0.26 1500 Shale 4298.06 12.01 0.7 3000 2665000.7 0.23 2500 Nan DS 4310.07 2.5 0.65 2785 1214000.3 0.27 1500 Shale 4312.57 20.01 0.69 2978.2 2665000.7 0.23 2500 ǣ Name: Stage 16 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 16 PAD 40 YF126ST 16170 385 CarboLite 16/20 0 0 9.62 2 1 PPA 40 YF126ST 7642 190 CarboLite 16/20 1 7642 4.75 3 3 PPA 40 YF126ST 7972.4 215 CarboLite 16/20 3 23917.2 5.37 4 5 PPA 40 YF126ST 8255 240 CarboLite 16/20 5 41275 6 5 7 PPA 40 YF126ST 7697.4 240 CarboLite 16/20 7 53881.8 6 6 9 PPA 40 YF126ST 6609.8 220 CarboLite 16/20 9 59488.2 5.5 7 10 PPA 40 YF126ST 5533.3 190 CarboLite 16/20 10 55333 4.75 NDBI-034 Stage N/A Page 96 of 97 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 27 22.92 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 59879.9 241537.2 1680 42 NDBI-034 Stage N/A Page 97 of 97 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 16 5637.8 235.62 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4068.97 4304.59 Summary Table: Propped Fracture Results Case FCD Closed Fracture Parameters Perforation FCD Length (ft) Height (ft) Avg Wellbore Width (in) Stage 16 1.78 956.28 181.31 0.47