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Home My WebLink About2025_10_20_325-6481. 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 Cleanup 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?Pikka NDB-027 Yes No 9. Property Designation (Lease Number):10. Field: Pikka Nanushuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD): 26,914 4,095'26,907'4,095'N/A N/A Casing Collapse Conductor Surface 2260 Intermediate 4750 Tie-Back 4750 Intermediate 2 5410 Production 9210 Liner 9210 Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Scott Leahy 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 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 11590 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, 393018, 392970 225-066 601 W 5th Avenue, Suite 600, Anchorage, AK 99501 50-103-20922-00-00 Oil Search Alaska, LLC Length Size Proposed Pools: 128'128' P-110S TVD Burst 17,056' 11590 MD 6870 5020 6870 2,376' 3,401' 2,311' 3,997' 2,935' 11,995' 4-1/2" 128'20"x34" 13-3/8" 9-5/8" 2,935' Tieback2,780' 9,215' 17,056' Perforation Depth MD (ft): 2,780' 17,056' 4-1/2" 5,443'7"17,275'4,065'7240 11/8/2025 26,907'9,851' 4-1/2" 12.6ppf 4,095' See attached packer report m n P 2 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-648 Page 1 of 1 Packer Set Depths - NDB-027 Wellbore Name Item Des Btm (ftKB) Btm (TVD) (ftKB) Sidetrack 1 ZXP Liner Top Hanger Packer W/HRD-E Profile 17,089.6 4,008.4 Sidetrack 1 HES Zoneguard OH Packer #20 17,425.5 4,100.0 Sidetrack 1 HES Zoneguard OH Packer #19 17,491.2 4,112.0 Sidetrack 1 HES Zoneguard OH Packer #18 17,910.4 4,141.6 Sidetrack 1 HES Zoneguard OH Packer #17 18,369.4 4,141.1 Sidetrack 1 HES Zoneguard OH Packer #16 18,871.8 4,139.1 Sidetrack 1 HES Zoneguard OH Packer #15 19,499.0 4,136.8 Sidetrack 1 HES Zoneguard OH Packer #14 20,126.6 4,134.5 Sidetrack 1 HES Zoneguard OH Packer #13 20,628.1 4,132.2 Sidetrack 1 HES Zoneguard OH Packer #12 21,131.2 4,128.2 Sidetrack 1 HES Zoneguard OH Packer #11 21,676.3 4,123.7 Sidetrack 1 HES Zoneguard OH Packer #10 22,259.5 4,119.7 Sidetrack 1 HES Zoneguard OH Packer #9 22,762.9 4,117.7 Sidetrack 1 HES Zoneguard OH Packer #8 23,308.5 4,115.6 Sidetrack 1 HES Zoneguard OH Packer #7 23,850.8 4,113.5 Sidetrack 1 HES Zoneguard OH Packer #6 24,393.0 4,110.6 Sidetrack 1 HES Zoneguard OH Packer #5 24,934.6 4,106.5 Sidetrack 1 HES Zoneguard OH Packer #4 25,476.5 4,102.3 Sidetrack 1 HES Zoneguard OH Packer #3 25,979.0 4,099.1 Sidetrack 1 HES Zoneguard OH Packer #2 26,438.4 4,097.5 Sidetrack 1 HES Zoneguard OH Packer #1 26,775.9 4,096.0 Page 1 of 20 NDB-027 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 NBD-027. At the NDB-027 location, the Permafrost interval extends down to approximately 1000-1400 ft and therefore, no shallow aquifer (typically found down to 400 ft depth) are located at the NDB-027 location. 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 Dand I 9. Lithological and geological descriptions of each zone –Attachment E and below Prince Creek Formation Depth/Thickness: Surface to 971 feet (ft) total vertical depth subsea (TVDSS)/ 971 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: 971 to 2,379 ft TVDSS/1,408 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: 2,379 to 2,982 ft TVDSS/ 603 ft thick Hydrocarbon Zone: 2,724 to 2,982 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: 2,982 to 3,731ft TVDSS/ 749 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: 3,731 to 4,685 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: 4,685 to 5,584 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 1-18 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 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 26,665 4,097 214 260 40 7,719 8 2 26,205 4,098 231 315 40 7,728 8 3 25,744 4,100 344 452 40 7,495 8 4 25,201 4,105 353 469 40 7,358 8 5 24,659 4,109 355 499 40 7,784 10 6 24,118 4,112 355 499 40 7,619 10 7 23,575 4,115 354 498 40 7,488 10 8 23,032 4,117 350 489 40 7,320 10 9 22,486 4,119 350 467 40 7,145 10 10 21,944 4,122 350 487 40 7,014 10 11 21,399 4,126 349 486 40 6,846 10 12 20,855 4,131 352 492 40 6,672 10 13 20,312 4,134 224 448 40 6,587 10 14 19,768 4,136 210 416 40 6,692 11 15 19,223 4,138 190 356 40 6,589 11 16 18,678 4,140 215 427 40 6,660 12 17 18,137 4,141 241 388 40 6,480 12 18 17,634 4,130 218 412 40 6,316 12 Mechanical condition of wells transecting the confining zones –NDBi-030, NDB- 037, Fiord 3, Fiord 3A, and Fiord 2 are within 1/2-mile radius of NDB-027. Please see Attachment B as reference. 11.Suspected fault or fracture that may transect the confining zones: There is one known fault within the ½ mile radius of NDB-027. The fault is described as: Fault SM_NDB_004 falls within the ½ mile radius of the B-27 well and is oriented obliquely to the wellbore orientation. The fault is associated with the Fiord fault system and is mapped to tip out around 2000’ from the B-27 well. This fault has throw estimated to be around 25’ at the NDB-022 intersection and throw increases to the north from there. Please See Attachment B. Note: Fractures are estimated to propagate along wellbore longitudinally at ~330 o. 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 2FWREHU , 2025 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 NDB-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 NDB-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 NDB-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 Arctic Slope Regional Corp. Kuukpik Corp. Oil Search (Alaska), LLC Repsol E&P USA LLC ConocoPhillips Alaska, Inc. Sincerely, Jacob Owens 2/2 Contact Information: State of Alaska CERTIFIED MAIL Department of Natural Resources Alaska Division of Oil and Gas 550 W 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Arctic Slope Regional Corp. CERTIFIED MAIL Attn: David Knutson 3900 C Street, Suite 801 Anchorage, AK 99503-5963 Kuukpik Corp CERTIFIED MAIL 582 E. 36th Avenue Anchorage, AK 99503 Oil Search (Alaska), LLC CERTIFIED MAIL 601 W 5th Ave Anchorage, AK 99501 Repsol E&P USA LLC CERTIFIED MAIL 2455 Technology Forest Blvd. The Woodlands, TX 77381 ConocoPhillips Alaska, Inc. CERTIFIED MAIL Attn: Land Manager PO Box 100360 Anchorage AK 99510 81(81(81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81(81( 81( 81( 81( 81( 81( ADL 392991 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 41.58% DNR - 58.42% ADL 392984 Surface Owners: Kuu OIL SEARCH - 51%, R 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 e Owners: State %, REPSOL - 49% SUBS.OWNERS: 0% DNR - 100% ADL 392970 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 40.29% DNR - 59.71% 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: Ku OIL SEARCH - 51%, R SUBS.OWNERS: ASRC - 31.69% DNR ADL 393016 Surface Owners: Kuu OIL SEARCH - 51%, R SUBS.OWNERS: ASRC - 33.17% DNR ADL 39 Surface Owne OIL SEARCH - 51% SUBS.OW ASRC - 28.11% D ADL 393007 Surface Owners: Ku OIL SEARCH - 51%, R SUBS.OWNERS: ASRC - 34.35% DNR ADL 391445 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 41.98% DNR - 58.02% ADL 391454 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 36.61% DNR - 63.39% ADL 391455 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 46.4% DNR - 53.6% ADL 393009 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 40.59% DNR - 59.41% 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% Cono c o A D L 3 7 2 1 0 6 OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD NDB-027 BOTTOM HOLE NDB-027 SURFACE LOCATION PRODUCTION INTERVAL 0.5-MILE BUFFER NDB-027 TRAJECTORY CPAI LEASES SECTIONS SANTOS LEASES DATE: 9/29/2025. By: JB 00.10.2 Miles Project: AP-DRL-GEN_assorted Layout: AP-DRL-PE-M_NDB27_well_ownership Map Frame: AP-DRL-PE-M_NDB-027_well_ownership GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 00.20.4 Kilometers PIKKA DEVELOPMENT NDB-027 WELL AREA Attachment B ADL 392991 ADL 392984 ADL 392968 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 393011ADL 393010 Conoco ADL 372106 81(81(81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81(81( 81( 81( 81( 81( 81( 81( FIORD 3A FIORD 3 QUGRUK 301 QUGRUK 3A COLVILLE RIV UNIT CD1-15 FIORD 2 QUGRUK 7 CD1-15PB1 Colville River Unit CD1-15PB2 DW-02 NDB-010 NDB-011 NDB-024 NDB-025 NDB-027 NDB-032 NDB-037 NDB-040 NDB-051 NDBi-014 NDBi-016 NDBi-018 NDBi-030 NDBi-036 NDBi-043A NDBi-044 NDBi-049 0D[DU OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD 0.25-MILE BUFFER 0.5-MILE BUFFER PRODUCTION INTERVAL NDB-027 TRAJECTORY OTHER DRILLED NDB WELLS EXPLORATION WELLS NDB-027 BOTTOM HOLE BOTTOM HOLES WELL TRAJECTORIES BY OTHERS NDB-027 SURFACE LOCATION SECTIONS CPAI LEASES FAULT LINE DATE: 9/29/2025. By: JN 00.10.2 Miles Project: AP-DRL-GEN_assorted Layout: AP-DRL-GEN-M_NDB27_buffers GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 00.20.4 Kilometers PIKKA DEVELOPMENT NDB-027 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 ND B i - 0 3 0 A C T I V E 9 - 5 / 8 " 4 7 p p f 9 6 5 3 ( N a n u s h u k ) 3 , 7 9 6 ( N a n u s h u k ) 9 9 5 0 3 , 8 3 1 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 9 , 9 5 0 ' & p a c k e r @ 11 , 0 1 4 ' 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. Pu 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 0 6 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 - I I T a i l . P l a n n e d T O C w a s ~ 8 , 4 5 0 ’ M D . b. Li n e r w i p e r p l u g s y s t e m f a i l u r e . W h e n l o w e r l i n e r w i p e r p l u g l a n d e d o n l a n d i n g c o l l a r , p l u g b u m p e d l e a v i n g a l l c e m e n t i n s i d e 9 -5 / 8 " l i n e r . A c l e a n o u t r u n wa s r e q u i r e d t o d r i l l o u t a l l c e m e n t a n d t h e l a n d i n g c o l l a r w a s d r i l l e d o u t . 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 , 1 6 0 ’ M D a nd 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 i f f i c u l t y e st a b l i s h i n g g o o d c i r c u l a t i o n du e t o 8 0 b b l s o f w a t e r b a s e d 1 2 . 5 p p g s p a c e r l e f t a g a i n s t f o r m a t i o n f r o m i n i t i a l c e m e n t j o b . d. 78 b b l s 1 2 . 5 p p g t u n e d s p a c e r a n d 2 0 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 a s 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 3 b b l s w e r e p l a c e d o n to p o f t h e r e t a i n e r . L o s t 1 1 0 b b l s a f t e r c e m e n t e n t e r e d a nn u l u s . 2. 9- 5 / 8 ” 2 n d S t a g e C e m e n t J o b a. RI 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 M u d f l u s h S p a c e r , 7 8 b b l s 1 3 . 5 p p g T u n e d s p a c e r 2 5 2 b b l s 15 . 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 . N o l o s s e s p u m p i n g c e m e n t a n d 2 6 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 n d 5 0 b b l s o f c e m e n t w a s ci r c u l a t e d t o 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 t h e C f l e x r u n n i n g t o o l . 3. 9- 5 / 8 ” C e m e n t E v a l u a t i o n L o g a. Ba k e r S o u n d T r a k C B L t o o l w a s u s e d t o l o g c e m e n t a f t e r d r il l i n g o u t c e m e n t r e t a i n e r a n d f l o a t s h o e . T h e 9 - 5 / 8 ” 1 s t s t a g e 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 of t h e p r i m a r y j o b a t 9 , 9 5 0 ' M D . T o p o f h y d r o c a r b o n b e a r i n g z o n e i n t h e N a n u s h u k w a s i n t h e N T 7 a t 1 0 , 2 4 0 ' M D . 03 / 2 6 / 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 1 5 0 p s i fo r 3 0 m i n u t e s 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 . 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 2,780” MD x 13-3/8” Casing Shoe at 2,935’ MD x 9-5/8” Archer Cflex Mechanical Stage tool: 5,979’ MD x 9-5/8” Shoe at 11,995’ MD 7” Intermediate 2 Liner x 7” Liner Top at 11,832’ MD x Shoe at 17,275’ MD Geology x Top of Tuluvak Sand Top at 3,311’ MD x Top of Tuluvak TS 790 formation at 5,901’ MD. x Top of the Nanushuk picked at 15,992’ MD. Cement Job Planning/Execution See attached cementing reports starting on the next page for a summary of the work performed. Observations 9-5/8” 1st Stage: -For the 1st stage of the cement job, based on job execution results, cement isolation was achieved across the 9-5/8” shoe. 9-5/8” 2nd Stage: -For the 2nd stage of the cement job, based on job execution results, cement isolation was achieved across the significant hydrocarbon zone within the upper Tuluvak formation. 7” Intermediate 2 Liner -The SLB TOC log indicates a transition zone from 13,350’ to 13,886’ MD, with the TOC at 13,886’ MD (3,586’ TVD), and good cement bond below this depth down to the 7” shoe. This places cement ~224’ TVD above the top of the Nanushuk. Page 1 of 1 Cement - NDB-027 Intermediate #2 Casing Cement Page 1 of 1 Cement - NDB-027 Surface Casing Cement Page 1 of 2 Cement - NDB-027 Intermediate #1 Casing Cement Page 2 of 2 Cement - NDB-027 Intermediate #1 Casing Cement Attachment D Attachment E Attachment F We l l N a m e ND B - 0 2 7 10 / 1 4 / 2 5 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. 0 50 50 21 0 0 21 0 0 50 50 c P u m p C h e c k WF 26 4 0 42 5 47 5 17 8 5 0 19 9 5 0 42 5 47 5 0 47 5 dD F I T WF 26 4 0 25 0 72 5 1 0 5 0 0 3 0 4 5 0 2 5 0 7 2 5 0 7 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 0 16 8 0 1 6 8 0 0 0 4 0 7 6 5 2 0 Dr o p S t a g e 1 B a l l / C o l l e t F P 0 18 3 43 4 3 12 6 1 8 0 6 00 CS G - I V 3 7 6 8 3 0 St a g e 1 P A D XL 2 6 40 3 7 5 41 8 4 1 8 15 7 5 0 1 7 5 5 6 0 0 3 7 5 1 1 4 3 4 0 Sl o w f o r S e a t X L 2 6 18 50 46 8 4 6 8 21 0 0 1 9 6 5 6 0 0 5 0 1 1 9 3 5 0 Re s u m e P a d XL 2 6 40 1 46 9 4 6 9 42 1 9 6 9 8 0 0 1 1 1 9 4 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 59 4 5 9 4 52 5 0 2 4 9 4 8 50 2 7 5 0 2 7 CS G - I V 12 0 1 3 1 4 7 2 Fl a t XL 2 6 40 1 4 0 73 4 7 3 4 58 8 0 3 0 8 2 8 10 8 0 1 1 5 8 2 8 CS G - I V 12 9 1 4 4 2 8 3 Fl a t XL 2 6 40 1 7 0 90 4 9 0 4 71 4 0 3 7 9 6 8 18 9 0 2 3 4 7 3 0 CS G - I V 15 0 1 5 9 2 9 4 Fl a t XL 2 6 40 1 7 0 10 7 4 1 0 7 4 71 4 0 4 5 1 0 8 24 2 5 2 5 8 9 8 2 CS G - I V 14 4 1 7 3 7 10 5 Fl a t XL 2 6 40 1 7 0 12 4 4 1 2 4 4 71 4 0 5 2 2 4 8 29 2 1 4 8 8 1 9 6 CS G - I V 13 9 1 8 7 6 11 6 Fl a t XL 2 6 40 1 7 0 14 1 4 1 4 1 4 71 4 0 5 9 3 8 8 33 8 2 7 1 2 2 0 2 3 CS G - I V 13 4 2 0 1 0 12 7 Fl a t XL 2 6 40 1 4 0 15 5 4 1 5 5 4 58 8 0 6 5 2 6 8 31 4 0 0 1 5 3 4 2 3 CS G - I V 10 7 2 1 1 7 13 8 Fl a t XL 2 6 40 1 2 5 16 7 9 1 6 7 9 52 5 0 7 0 5 1 8 30 9 9 1 1 8 4 4 1 4 CS G - I V 92 2 2 0 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 9 4 1 6 9 4 63 0 7 1 1 4 8 0 1 8 4 4 1 4 1 5 2 2 2 4 15 0 Sp a c e r X L 2 6 40 15 17 0 9 1 7 0 9 63 0 7 1 7 7 8 0 1 8 4 4 1 4 1 5 2 2 3 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 17 1 2 1 7 1 2 12 6 7 1 9 0 4 0 1 8 4 4 1 4 3 2 2 4 2 17 0 St a g e 2 P A D XL 2 6 40 3 6 8 20 8 0 2 0 8 0 15 4 5 6 8 7 3 6 0 0 1 8 4 4 1 4 3 6 8 2 6 1 0 18 0 Sl o w f o r S e a t X L 2 6 18 50 21 3 0 2 1 3 0 21 0 0 8 9 4 6 0 0 1 8 4 4 1 4 5 0 2 6 6 0 19 0 Re s u m e P a d XL 2 6 40 3 2 21 6 2 2 1 6 2 13 4 4 9 0 8 0 4 0 1 8 4 4 1 4 3 2 2 6 9 2 20 1 Fl a t XL 2 6 40 1 6 5 23 2 7 2 3 2 7 69 3 0 9 7 7 3 4 66 3 5 1 9 1 0 4 9 CS G - I V 15 8 2 8 5 0 21 2 Fl a t XL 2 6 40 1 8 0 25 0 7 2 5 0 7 75 6 0 1 0 5 2 9 4 13 8 8 7 2 0 4 9 3 6 CS G - I V 16 5 3 0 1 5 22 3 Fl a t XL 2 6 40 1 9 5 27 0 2 2 7 0 2 81 9 0 1 1 3 4 8 4 21 6 8 2 2 2 6 6 1 7 CS G - I V 17 2 3 1 8 7 23 4 Fl a t XL 2 6 40 1 9 5 28 9 7 2 8 9 7 81 9 0 1 2 1 6 7 4 27 8 1 9 2 5 4 4 3 6 CS G - I V 16 6 3 3 5 3 24 5 Fl a t XL 2 6 40 1 9 5 30 9 2 3 0 9 2 81 9 0 1 2 9 8 6 4 33 5 1 0 2 8 7 9 4 6 CS G - I V 16 0 3 5 1 3 25 6 Fl a t XL 2 6 40 1 9 5 32 8 7 3 2 8 7 81 9 0 1 3 8 0 5 4 38 8 0 2 3 2 6 7 4 8 CS G - I V 15 4 3 6 6 7 26 7 Fl a t XL 2 6 40 1 8 5 34 7 2 3 4 7 2 77 7 0 1 4 5 8 2 4 41 4 9 3 3 6 8 2 4 1 CS G - I V 14 1 3 8 0 8 27 8 Fl a t XL 2 6 40 1 7 0 36 4 2 3 6 4 2 71 4 0 1 5 2 9 6 4 42 1 4 8 4 1 0 3 8 8 CS G - I V 12 5 3 9 3 3 28 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 36 5 7 3 6 5 7 63 0 1 5 3 5 9 4 0 4 1 0 3 8 8 1 5 3 9 4 8 29 0 Sp a c e r X L 2 6 40 15 36 7 2 3 6 7 2 63 0 1 5 4 2 2 4 0 4 1 0 3 8 8 1 5 3 9 6 3 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 7 5 3 6 7 5 12 6 1 5 4 3 5 0 0 4 1 0 3 8 8 3 3 9 6 6 31 0 St a g e 3 P A D XL 2 6 40 3 6 1 40 3 6 4 0 3 6 15 1 6 2 1 6 9 5 1 2 0 4 1 0 3 8 8 3 6 1 4 3 2 7 32 0 Sl o w f o r S e a t X L 2 6 18 50 40 8 6 4 0 8 6 21 0 0 1 7 1 6 1 2 0 4 1 0 3 8 8 5 0 4 3 7 7 HS D - ~ 6 0 m i n FL U I D Ne a t W a t e r CO M M E N T S HS D - 3 0 m i n 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 - D i s p l a c e P T We l l N a m e ND B - 0 2 7 10 / 1 4 / 2 5 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 33 0 Re s u m e P a d XL 2 6 40 3 9 41 2 5 4 1 2 5 16 3 8 1 7 3 2 5 0 0 4 1 0 3 8 8 3 9 4 4 1 6 34 1 Fl a t XL 2 6 40 1 6 5 42 9 0 4 2 9 0 69 3 0 1 8 0 1 8 0 66 3 5 4 1 7 0 2 4 CS G - I V 15 8 4 5 7 4 35 2 Fl a t XL 2 6 40 1 8 0 44 7 0 4 4 7 0 75 6 0 1 8 7 7 4 0 13 8 8 7 4 3 0 9 1 0 CS G - I V 16 5 4 7 3 9 36 3 Fl a t XL 2 6 40 1 9 5 46 6 5 4 6 6 5 81 9 0 1 9 5 9 3 0 21 6 8 2 4 5 2 5 9 2 CS G - I V 17 2 4 9 1 1 37 4 Fl a t XL 2 6 40 1 9 5 48 6 0 4 8 6 0 81 9 0 2 0 4 1 2 0 27 8 1 9 4 8 0 4 1 1 CS G - I V 16 6 5 0 7 7 38 5 Fl a t XL 2 6 40 1 9 5 50 5 5 5 0 5 5 81 9 0 2 1 2 3 1 0 33 5 1 0 5 1 3 9 2 1 CS G - I V 16 0 5 2 3 7 39 6 Fl a t XL 2 6 40 1 9 5 52 5 0 5 2 5 0 81 9 0 2 2 0 5 0 0 38 8 0 2 5 5 2 7 2 3 CS G - I V 15 4 5 3 9 1 40 7 Fl a t XL 2 6 40 1 8 5 54 3 5 5 4 3 5 77 7 0 2 2 8 2 7 0 41 4 9 3 5 9 4 2 1 6 CS G - I V 14 1 5 5 3 2 41 8 Fl a t XL 2 6 40 1 7 0 56 0 5 5 6 0 5 71 4 0 2 3 5 4 1 0 42 1 4 8 6 3 6 3 6 3 CS G - I V 12 5 5 6 5 7 42 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 56 2 0 5 6 2 0 63 0 2 3 6 0 4 0 0 6 3 6 3 6 3 1 5 5 6 7 2 43 0 Sp a c e r X L 2 6 40 15 56 3 5 5 6 3 5 63 0 2 3 6 6 7 0 0 6 3 6 3 6 3 1 5 5 6 8 7 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 56 3 8 5 6 3 8 12 6 2 3 6 7 9 6 0 6 3 6 3 6 3 3 5 6 9 0 45 0 St a g e 4 P A D XL 2 6 40 3 5 3 59 9 1 5 9 9 1 14 8 2 6 2 5 1 6 2 2 0 6 3 6 3 6 3 3 5 3 6 0 4 3 46 0 Sl o w f o r S e a t X L 2 6 18 50 60 4 1 6 0 4 1 21 0 0 2 5 3 7 2 2 0 6 3 6 3 6 3 5 0 6 0 9 3 47 0 Re s u m e P a d XL 2 6 40 4 7 60 8 8 6 0 8 8 19 7 4 2 5 5 6 9 6 0 6 3 6 3 6 3 4 7 6 1 4 0 48 1 Fl a t XL 2 6 40 1 6 5 62 5 3 6 2 5 3 69 3 0 2 6 2 6 2 6 66 3 5 6 4 2 9 9 8 CS G - I V 15 8 6 2 9 8 49 2 Fl a t XL 2 6 40 1 8 0 64 3 3 6 4 3 3 75 6 0 2 7 0 1 8 6 13 8 8 7 6 5 6 8 8 5 CS G - I V 16 5 6 4 6 4 50 3 Fl a t XL 2 6 40 1 9 5 66 2 8 6 6 2 8 81 9 0 2 7 8 3 7 6 21 6 8 2 6 7 8 5 6 7 CS G - I V 17 2 6 6 3 6 51 4 Fl a t XL 2 6 40 1 9 5 68 2 3 6 8 2 3 81 9 0 2 8 6 5 6 6 27 8 1 9 7 0 6 3 8 6 CS G - I V 16 6 6 8 0 1 52 5 Fl a t XL 2 6 40 1 9 5 70 1 8 7 0 1 8 81 9 0 2 9 4 7 5 6 33 5 1 0 7 3 9 8 9 6 CS G - I V 16 0 6 9 6 1 53 6 Fl a t XL 2 6 40 1 9 5 72 1 3 7 2 1 3 81 9 0 3 0 2 9 4 6 38 8 0 2 7 7 8 6 9 8 CS G - I V 15 4 7 1 1 5 54 7 Fl a t XL 2 6 40 1 8 5 73 9 8 7 3 9 8 77 7 0 3 1 0 7 1 6 41 4 9 3 8 2 0 1 9 0 CS G - I V 14 1 7 2 5 6 55 8 Fl a t XL 2 6 40 1 7 0 75 6 8 7 5 6 8 71 4 0 3 1 7 8 5 6 42 1 4 8 8 6 2 3 3 8 CS G - I V 12 5 7 3 8 1 56 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 75 8 3 7 5 8 3 63 0 3 1 8 4 8 6 0 8 6 2 3 3 8 1 5 7 3 9 6 57 0 Sp a c e r X L 2 6 40 15 75 9 8 7 5 9 8 63 0 3 1 9 1 1 6 0 8 6 2 3 3 8 1 5 7 4 1 1 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 76 0 1 7 6 0 1 12 6 3 1 9 2 4 2 0 8 6 2 3 3 8 3 7 4 1 4 59 0 St a g e 5 P A D XL 2 6 40 3 4 5 79 4 6 7 9 4 6 14 4 9 0 3 3 3 7 3 2 0 8 6 2 3 3 8 3 4 5 7 7 5 9 60 0 Sl o w f o r S e a t X L 2 6 18 50 79 9 6 7 9 9 6 21 0 0 3 3 5 8 3 2 0 8 6 2 3 3 8 5 0 7 8 0 9 61 0 Re s u m e P a d XL 2 6 40 1 79 9 7 7 9 9 7 42 3 3 5 8 7 4 0 8 6 2 3 3 8 1 7 8 1 0 62 1 Sc o u r XL 2 6 40 6 0 80 5 7 8 0 5 7 25 2 0 3 3 8 3 9 4 24 1 3 8 6 4 7 5 1 40 / 7 0 - C L 57 7 8 6 8 63 3 Sc o u r XL 2 6 40 1 2 0 81 7 7 8 1 7 7 50 4 0 3 4 3 4 3 4 13 3 4 8 8 7 8 0 9 9 40 / 7 0 - C L 10 6 7 9 7 4 64 0 Fl a t XL 2 6 40 5 0 82 2 7 8 2 2 7 21 0 0 3 4 5 5 3 4 0 8 7 8 0 9 9 5 0 8 0 2 4 65 1 Fl a t XL 2 6 40 2 0 0 84 2 7 8 4 2 7 84 0 0 3 5 3 9 3 4 80 4 3 8 8 6 1 4 2 CS G - I V 19 1 8 2 1 5 66 2 Fl a t XL 2 6 40 2 2 5 86 5 2 8 6 5 2 94 5 0 3 6 3 3 8 4 17 3 5 8 9 0 3 5 0 0 CS G - I V 20 7 8 4 2 2 67 4 Fl a t XL 2 6 40 2 7 5 89 2 7 8 9 2 7 11 5 5 0 3 7 4 9 3 4 39 2 3 2 9 4 2 7 3 2 CS G - I V 23 4 8 6 5 5 68 6 Fl a t XL 2 6 40 2 6 0 91 8 7 9 1 8 7 10 9 2 0 3 8 5 8 5 4 51 7 3 6 9 9 4 4 6 8 CS G - I V 20 5 8 8 6 1 69 8 Fl a t XL 2 6 40 2 4 0 94 2 7 9 4 2 7 10 0 8 0 3 9 5 9 3 4 59 5 0 2 1 0 5 3 9 7 0 CS G - I V 17 7 9 0 3 8 70 10 Fl a t XL 2 6 40 2 0 0 96 2 7 9 6 2 7 84 0 0 4 0 4 3 3 4 58 1 7 0 1 1 1 2 1 4 0 CS G - I V 13 8 9 1 7 6 71 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 96 4 2 9 6 4 2 63 0 4 0 4 9 6 4 0 1 1 1 2 1 4 0 1 5 9 1 9 1 72 0 Sp a c e r X L 2 6 40 15 96 5 7 9 6 5 7 63 0 4 0 5 5 9 4 0 1 1 1 2 1 4 0 1 5 9 2 0 6 73 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 96 6 0 9 6 6 0 12 6 4 0 5 7 2 0 0 1 1 1 2 1 4 0 3 9 2 0 9 74 0 St a g e 6 P A D XL 2 6 40 3 3 7 99 9 7 9 9 9 7 14 1 5 4 4 1 9 8 7 4 0 1 1 1 2 1 4 0 3 3 7 9 5 4 6 75 0 Sl o w f o r S e a t X L 2 6 18 50 10 0 4 7 1 0 0 4 7 21 0 0 4 2 1 9 7 4 0 1 1 1 2 1 4 0 5 0 9 5 9 6 We l l N a m e ND B - 0 2 7 10 / 1 4 / 2 5 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 76 0 Re s u m e P a d XL 2 6 40 1 10 0 4 8 1 0 0 4 8 42 4 2 2 0 1 6 0 1 1 1 2 1 4 0 1 9 5 9 7 77 1 Sc o u r XL 2 6 40 6 0 10 1 0 8 1 0 1 0 8 25 2 0 4 2 4 5 3 6 24 1 3 1 1 1 4 5 5 3 40 / 7 0 - C L 57 96 5 5 78 3 Sc o u r XL 2 6 40 1 2 0 10 2 2 8 1 0 2 2 8 50 4 0 4 2 9 5 7 6 13 3 4 8 1 1 2 7 9 0 2 40 / 7 0 - C L 10 6 97 6 1 79 0 Fl a t XL 2 6 40 5 0 10 2 7 8 1 0 2 7 8 21 0 0 4 3 1 6 7 6 0 1 1 2 7 9 0 2 5 0 98 1 1 80 1 Fl a t XL 2 6 40 2 0 0 10 4 7 8 1 0 4 7 8 84 0 0 4 4 0 0 7 6 80 4 3 1 1 3 5 9 4 4 CS G - I V 19 1 10 0 0 2 81 2 Fl a t XL 2 6 40 2 2 5 10 7 0 3 1 0 7 0 3 94 5 0 4 4 9 5 2 6 17 3 5 8 1 1 5 3 3 0 3 CS G - I V 20 7 10 2 0 9 82 4 Fl a t XL 2 6 40 2 7 5 10 9 7 8 1 0 9 7 8 11 5 5 0 4 6 1 0 7 6 39 2 3 2 1 1 9 2 5 3 4 CS G - I V 23 4 10 4 4 2 83 6 Fl a t XL 2 6 40 2 6 0 11 2 3 8 1 1 2 3 8 10 9 2 0 4 7 1 9 9 6 51 7 3 6 1 2 4 4 2 7 0 CS G - I V 20 5 10 6 4 8 84 8 Fl a t XL 2 6 40 2 4 0 11 4 7 8 1 1 4 7 8 10 0 8 0 4 8 2 0 7 6 59 5 0 2 1 3 0 3 7 7 3 CS G - I V 17 7 10 8 2 5 85 10 Fl a t XL 2 6 40 2 0 0 11 6 7 8 1 1 6 7 8 84 0 0 4 9 0 4 7 6 58 1 7 0 1 3 6 1 9 4 3 CS G - I V 13 8 10 9 6 3 86 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 11 6 9 3 1 1 6 9 3 63 0 4 9 1 1 0 6 0 1 3 6 1 9 4 3 1 5 10 9 7 8 87 0 Sp a c e r X L 2 6 40 15 11 7 0 8 1 1 7 0 8 63 0 4 9 1 7 3 6 0 1 3 6 1 9 4 3 1 5 10 9 9 3 88 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 7 1 1 1 1 7 1 1 12 6 4 9 1 8 6 2 0 1 3 6 1 9 4 3 3 10 9 9 6 89 0 XL F l u s h ( D F I T ) XL 2 6 40 3 2 8 12 0 3 9 1 2 0 3 9 13 7 7 6 5 0 5 6 3 8 0 1 3 6 1 9 4 3 3 2 8 11 3 2 4 90 0 Sl o w f o r s e a t ( L G D F I T ) W F 2 6 18 50 12 0 8 9 1 2 0 8 9 21 0 0 5 0 7 7 3 8 0 1 3 6 1 9 4 3 5 0 1 1 3 7 4 91 DF I T F l u s h WF 2 6 40 23 5 1 2 3 2 4 1 2 3 2 4 98 7 0 5 4 8 0 5 8 23 5 1 1 6 0 9 92 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 3 9 4 1 2 3 9 4 29 4 9 5 5 1 0 0 7 TO T A L S 13 1 1 9 55 1 0 0 7 13 6 1 9 4 3 We l l N a m e ND B - 0 2 7 10 / 1 4 / 2 5 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 3. 5 40 40 16 8 0 16 8 0 c WF 2 6 1. 0 0 0 16 8 0 0 0 d WF 26 3 . 5 36 0 36 0 1 5 1 2 0 1 6 8 0 0 3 6 0 3 6 0 e P u m p C h e c k WF 26 4 0 10 0 46 0 4 2 0 0 2 1 0 0 0 1 0 0 4 6 0 0 4 6 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 18 40 40 5 0 0 16 8 0 2 2 6 8 0 0 0 4 0 5 0 0 2 0 St a g e 7 P A D XL 2 6 40 3 0 0 34 0 8 0 0 12 6 0 0 3 5 2 8 0 00 CS G - I V 30 0 8 0 0 3 1 Sc o u r XL 2 6 40 6 0 40 0 8 6 0 25 2 0 3 7 8 0 0 24 1 3 2 4 1 3 40 / 7 0 - C L 57 8 5 7 4 3 Sc o u r XL 2 6 40 1 2 0 52 0 9 8 0 50 4 0 4 2 8 4 0 13 3 4 8 1 5 7 6 1 40 / 7 0 - C L 10 6 9 6 3 5 0 Fl a t XL 2 6 40 5 0 57 0 1 0 3 0 21 0 0 4 4 9 4 0 0 1 5 7 6 1 5 0 1 0 1 3 6 1 Fl a t XL 2 6 40 2 0 0 77 0 1 2 3 0 84 0 0 5 3 3 4 0 80 4 3 2 3 8 0 4 CS G - I V 19 1 1 2 0 5 7 2 Fl a t XL 2 6 40 2 2 5 99 5 1 4 5 5 94 5 0 6 2 7 9 0 17 3 5 8 4 1 1 6 3 CS G - I V 20 7 1 4 1 2 8 4 Fl a t XL 2 6 40 2 7 5 12 7 0 1 7 3 0 11 5 5 0 7 4 3 4 0 39 2 3 2 8 0 3 9 4 CS G - I V 23 4 1 6 4 5 9 6 Fl a t XL 2 6 40 2 6 0 15 3 0 1 9 9 0 10 9 2 0 8 5 2 6 0 51 7 3 6 1 3 2 1 3 0 CS G - I V 20 5 1 8 5 0 10 8 Fl a t XL 2 6 40 2 4 0 17 7 0 2 2 3 0 10 0 8 0 9 5 3 4 0 59 5 0 2 1 9 1 6 3 3 CS G - I V 17 7 2 0 2 7 11 10 Fl a t XL 2 6 40 2 0 0 19 7 0 2 4 3 0 84 0 0 1 0 3 7 4 0 58 1 7 0 2 4 9 8 0 2 CS G - I V 13 8 2 1 6 6 12 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 4 4 5 63 0 1 0 4 3 7 0 0 2 4 9 8 0 2 1 5 2 1 8 1 13 0 Sp a c e r X L 2 6 40 15 20 0 0 2 4 6 0 63 0 1 0 5 0 0 0 0 2 4 9 8 0 2 1 5 2 1 9 6 14 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 4 6 3 12 6 1 0 5 1 2 6 0 2 4 9 8 0 2 3 2 1 9 9 15 0 St a g e 8 P A D XL 2 6 40 3 2 0 23 2 3 2 7 8 3 13 4 4 0 1 1 8 5 6 6 0 2 4 9 8 0 2 3 2 0 2 5 1 9 16 0 Sl o w f o r S e a t X L 2 6 18 50 23 7 3 2 8 3 3 21 0 0 1 2 0 6 6 6 0 2 4 9 8 0 2 5 0 2 5 6 9 17 0 Re s u m e P a d XL 2 6 40 1 23 7 4 2 8 3 4 42 1 2 0 7 0 8 0 2 4 9 8 0 2 1 2 5 7 0 18 1 Sc o u r XL 2 6 40 4 0 24 1 4 2 8 7 4 16 8 0 1 2 2 3 8 8 16 0 9 2 5 1 4 1 1 40 / 7 0 - C L 38 2 6 0 8 19 3 Sc o u r XL 2 6 40 8 0 24 9 4 2 9 5 4 33 6 0 1 2 5 7 4 8 88 9 9 2 6 0 3 1 0 40 / 7 0 - C L 71 2 6 7 9 20 0 Re s u m e P a d XL 2 6 40 5 0 25 4 4 3 0 0 4 21 0 0 1 2 7 8 4 8 0 2 6 0 3 1 0 5 0 2 7 2 9 21 1 Fl a t XL 2 6 40 2 0 0 27 4 4 3 2 0 4 84 0 0 1 3 6 2 4 8 80 4 3 2 6 8 3 5 3 CS G - I V 19 1 2 9 2 0 22 2 Fl a t XL 2 6 40 2 2 5 29 6 9 3 4 2 9 94 5 0 1 4 5 6 9 8 17 3 5 8 2 8 5 7 1 1 CS G - I V 20 7 3 1 2 7 23 4 Fl a t XL 2 6 40 2 7 5 32 4 4 3 7 0 4 11 5 5 0 1 5 7 2 4 8 39 2 3 2 3 2 4 9 4 3 CS G - I V 23 4 3 3 6 1 24 6 Fl a t XL 2 6 40 2 6 0 35 0 4 3 9 6 4 10 9 2 0 1 6 8 1 6 8 51 7 3 6 3 7 6 6 7 9 CS G - I V 20 5 3 5 6 6 25 8 Fl a t XL 2 6 40 2 4 0 37 4 4 4 2 0 4 10 0 8 0 1 7 8 2 4 8 59 5 0 2 4 3 6 1 8 1 CS G - I V 17 7 3 7 4 3 26 10 Fl a t XL 2 6 40 2 0 0 39 4 4 4 4 0 4 84 0 0 1 8 6 6 4 8 58 1 7 0 4 9 4 3 5 1 CS G - I V 13 8 3 8 8 1 27 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 39 5 9 4 4 1 9 63 0 1 8 7 2 7 8 0 4 9 4 3 5 1 1 5 3 8 9 6 28 0 Sp a c e r X L 2 6 40 15 39 7 4 4 4 3 4 63 0 1 8 7 9 0 8 0 4 9 4 3 5 1 1 5 3 9 1 1 29 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 7 7 4 4 3 7 12 6 1 8 8 0 3 4 0 4 9 4 3 5 1 3 3 9 1 4 30 0 St a g e 9 P A D XL 2 6 40 3 1 2 42 8 9 4 7 4 9 13 1 0 4 2 0 1 1 3 8 0 4 9 4 3 5 1 3 1 2 4 2 2 6 31 0 Sl o w f o r S e a t X L 2 6 18 50 43 3 9 4 7 9 9 21 0 0 2 0 3 2 3 8 0 4 9 4 3 5 1 5 0 4 2 7 6 32 0 Re s u m e P a d XL 2 6 40 1 43 4 0 4 8 0 0 42 2 0 3 2 8 0 0 4 9 4 3 5 1 1 4 2 7 7 St a g e t o " L i n e o u t X L " 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 CO M M E N T S FL U I D Ne a t W a t e r 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 Dr o p B a l l Pu m p B a l l t o S e a t We l l N a m e ND B - 0 2 7 10 / 1 4 / 2 5 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 33 1 Sc o u r XL 2 6 40 4 0 43 8 0 4 8 4 0 16 8 0 2 0 4 9 6 0 16 0 9 4 9 5 9 6 0 40 / 7 0 - C L 38 4 3 1 6 34 3 Sc o u r XL 2 6 40 8 0 44 6 0 4 9 2 0 33 6 0 2 0 8 3 2 0 88 9 9 5 0 4 8 5 9 40 / 7 0 - C L 71 4 3 8 6 35 0 Re s u m e P a d XL 2 6 40 5 0 45 1 0 4 9 7 0 21 0 0 2 1 0 4 2 0 0 5 0 4 8 5 9 5 0 4 4 3 6 36 1 Fl a t XL 2 6 40 2 0 0 47 1 0 5 1 7 0 84 0 0 2 1 8 8 2 0 80 4 3 5 1 2 9 0 1 CS G - I V 19 1 4 6 2 8 37 2 Fl a t XL 2 6 40 2 2 5 49 3 5 5 3 9 5 94 5 0 2 2 8 2 7 0 17 3 5 8 5 3 0 2 6 0 CS G - I V 20 7 4 8 3 5 38 4 Fl a t XL 2 6 40 2 7 5 52 1 0 5 6 7 0 11 5 5 0 2 3 9 8 2 0 39 2 3 2 5 6 9 4 9 2 CS G - I V 23 4 5 0 6 8 39 6 Fl a t XL 2 6 40 2 6 0 54 7 0 5 9 3 0 10 9 2 0 2 5 0 7 4 0 51 7 3 6 6 2 1 2 2 7 CS G - I V 20 5 5 2 7 3 40 8 Fl a t XL 2 6 40 2 4 0 57 1 0 6 1 7 0 10 0 8 0 2 6 0 8 2 0 59 5 0 2 6 8 0 7 3 0 CS G - I V 17 7 5 4 5 0 41 10 Fl a t XL 2 6 40 2 0 0 59 1 0 6 3 7 0 84 0 0 2 6 9 2 2 0 58 1 7 0 7 3 8 9 0 0 CS G - I V 13 8 5 5 8 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 59 2 5 6 3 8 5 63 0 2 6 9 8 5 0 0 7 3 8 9 0 0 1 5 5 6 0 4 43 0 Sp a c e r X L 2 6 40 15 59 4 0 6 4 0 0 63 0 2 7 0 4 8 0 0 7 3 8 9 0 0 1 5 5 6 1 9 44 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 4 3 6 4 0 3 12 6 2 7 0 6 0 6 0 7 3 8 9 0 0 3 5 6 2 2 45 0 St a g e 1 0 P A D XL 2 6 40 3 0 3 62 4 6 6 7 0 6 12 7 2 6 2 8 3 3 3 2 0 7 3 8 9 0 0 3 0 3 5 9 2 5 46 0 Sl o w f o r S e a t X L 2 6 18 50 62 9 6 6 7 5 6 21 0 0 2 8 5 4 3 2 0 7 3 8 9 0 0 5 0 5 9 7 5 47 0 Re s u m e P a d XL 2 6 40 1 62 9 7 6 7 5 7 42 2 8 5 4 7 4 0 7 3 8 9 0 0 1 5 9 7 6 48 1 Sc o u r XL 2 6 40 4 0 63 3 7 6 7 9 7 16 8 0 2 8 7 1 5 4 16 0 9 7 4 0 5 0 8 40 / 7 0 - C L 38 6 0 1 4 49 3 Sc o u r XL 2 6 40 8 0 64 1 7 6 8 7 7 33 6 0 2 9 0 5 1 4 88 9 9 7 4 9 4 0 7 40 / 7 0 - C L 71 6 0 8 5 50 0 Fl a t XL 2 6 40 5 0 64 6 7 6 9 2 7 21 0 0 2 9 2 6 1 4 0 7 4 9 4 0 7 5 0 6 1 3 5 51 1 Fl a t XL 2 6 40 2 0 0 66 6 7 7 1 2 7 84 0 0 3 0 1 0 1 4 80 4 3 7 5 7 4 5 0 CS G - I V 19 1 6 3 2 6 52 2 Fl a t XL 2 6 40 2 2 5 68 9 2 7 3 5 2 94 5 0 3 1 0 4 6 4 17 3 5 8 7 7 4 8 0 8 CS G - I V 20 7 6 5 3 3 53 4 Fl a t XL 2 6 40 2 7 5 71 6 7 7 6 2 7 11 5 5 0 3 2 2 0 1 4 39 2 3 2 8 1 4 0 4 0 CS G - I V 23 4 6 7 6 7 54 6 Fl a t XL 2 6 40 2 6 0 74 2 7 7 8 8 7 10 9 2 0 3 3 2 9 3 4 51 7 3 6 8 6 5 7 7 6 CS G - I V 20 5 6 9 7 2 55 8 Fl a t XL 2 6 40 2 4 0 76 6 7 8 1 2 7 10 0 8 0 3 4 3 0 1 4 59 5 0 2 9 2 5 2 7 8 CS G - I V 17 7 7 1 4 9 56 10 Fl a t XL 2 6 40 2 0 0 78 6 7 8 3 2 7 84 0 0 3 5 1 4 1 4 58 1 7 0 9 8 3 4 4 8 CS G - I V 13 8 7 2 8 7 57 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 78 8 2 8 3 4 2 63 0 3 5 2 0 4 4 0 9 8 3 4 4 8 1 5 7 3 0 2 58 0 Sp a c e r X L 2 6 40 15 78 9 7 8 3 5 7 63 0 3 5 2 6 7 4 0 9 8 3 4 4 8 1 5 7 3 1 7 59 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 79 0 0 8 3 6 0 12 6 3 5 2 8 0 0 0 9 8 3 4 4 8 3 7 3 2 0 60 0 St a g e 1 1 P A D XL 2 6 40 2 9 5 81 9 5 8 6 5 5 12 3 9 0 3 6 5 1 9 0 0 9 8 3 4 4 8 2 9 5 7 6 1 5 61 0 Sl o w f o r S e a t X L 2 6 18 50 82 4 5 8 7 0 5 21 0 0 3 6 7 2 9 0 0 9 8 3 4 4 8 5 0 7 6 6 5 62 0 Re s u m e P a d XL 2 6 40 1 82 4 6 8 7 0 6 42 3 6 7 3 3 2 0 9 8 3 4 4 8 1 7 6 6 6 63 1 Sc o u r XL 2 6 40 4 0 82 8 6 8 7 4 6 16 8 0 3 6 9 0 1 2 16 0 9 9 8 5 0 5 7 40 / 7 0 - C L 38 7 7 0 5 64 3 Sc o u r XL 2 6 40 8 0 83 6 6 8 8 2 6 33 6 0 3 7 2 3 7 2 88 9 9 9 9 3 9 5 6 40 / 7 0 - C L 71 7 7 7 5 65 0 Re s u m e P a d XL 2 6 40 5 0 84 1 6 8 8 7 6 21 0 0 3 7 4 4 7 2 0 9 9 3 9 5 6 5 0 7 8 2 5 66 1 Fl a t XL 2 6 40 2 0 0 86 1 6 9 0 7 6 84 0 0 3 8 2 8 7 2 80 4 3 1 0 0 1 9 9 9 CS G - I V 19 1 8 0 1 7 67 2 Fl a t XL 2 6 40 2 2 5 88 4 1 9 3 0 1 94 5 0 3 9 2 3 2 2 17 3 5 8 1 0 1 9 3 5 7 CS G - I V 20 7 8 2 2 3 68 4 Fl a t XL 2 6 40 2 7 5 91 1 6 9 5 7 6 11 5 5 0 4 0 3 8 7 2 39 2 3 2 1 0 5 8 5 8 9 CS G - I V 23 4 8 4 5 7 69 6 Fl a t XL 2 6 40 2 6 0 93 7 6 9 8 3 6 10 9 2 0 4 1 4 7 9 2 51 7 3 6 1 1 1 0 3 2 5 CS G - I V 20 5 8 6 6 2 70 8 Fl a t XL 2 6 40 2 4 0 96 1 6 1 0 0 7 6 10 0 8 0 4 2 4 8 7 2 59 5 0 2 1 1 6 9 8 2 7 CS G - I V 17 7 8 8 3 9 71 10 Fl a t XL 2 6 40 2 0 0 98 1 6 1 0 2 7 6 84 0 0 4 3 3 2 7 2 58 1 7 0 1 2 2 7 9 9 7 CS G - I V 13 8 8 9 7 8 72 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 98 3 1 1 0 2 9 1 63 0 4 3 3 9 0 2 0 1 2 2 7 9 9 7 1 5 8 9 9 3 73 0 Sp a c e r X L 2 6 40 15 98 4 6 1 0 3 0 6 63 0 4 3 4 5 3 2 0 1 2 2 7 9 9 7 1 5 9 0 0 8 74 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 98 4 9 1 0 3 0 9 12 6 4 3 4 6 5 8 0 1 2 2 7 9 9 7 3 9 0 1 1 75 0 St a g e 1 2 P A D XL 2 6 40 2 8 7 10 1 3 6 1 0 5 9 6 12 0 5 4 4 4 6 7 1 2 0 1 2 2 7 9 9 7 2 8 7 9 2 9 8 We l l N a m e ND B - 0 2 7 10 / 1 4 / 2 5 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 76 0 Sl o w f o r S e a t X L 2 6 18 50 10 1 8 6 1 0 6 4 6 21 0 0 4 4 8 8 1 2 0 1 2 2 7 9 9 7 5 0 9 3 4 8 77 0 Re s u m e P a d XL 2 6 40 1 10 1 8 7 1 0 6 4 7 42 4 4 8 8 5 4 0 1 2 2 7 9 9 7 1 93 4 9 78 1 Fl a t XL 2 6 40 6 0 10 2 4 7 1 0 7 0 7 25 2 0 4 5 1 3 7 4 24 1 3 1 2 3 0 4 1 0 40 / 7 0 - C L 57 94 0 6 79 3 Fl a t XL 2 6 40 1 2 0 10 3 6 7 1 0 8 2 7 50 4 0 4 5 6 4 1 4 13 3 4 8 1 2 4 3 7 5 8 40 / 7 0 - C L 10 6 95 1 2 80 0 Fl a t XL 2 6 40 5 0 10 4 1 7 1 0 8 7 7 21 0 0 4 5 8 5 1 4 0 1 2 4 3 7 5 8 5 0 95 6 2 81 1 Fl a t XL 2 6 40 2 0 0 10 6 1 7 1 1 0 7 7 84 0 0 4 6 6 9 1 4 80 4 3 1 2 5 1 8 0 1 CS G - I V 19 1 97 5 4 82 2 Fl a t XL 2 6 40 2 2 5 10 8 4 2 1 1 3 0 2 94 5 0 4 7 6 3 6 4 17 3 5 8 1 2 6 9 1 5 9 CS G - I V 20 7 99 6 0 83 4 Fl a t XL 2 6 40 2 7 5 11 1 1 7 1 1 5 7 7 11 5 5 0 4 8 7 9 1 4 39 2 3 2 1 3 0 8 3 9 1 CS G - I V 23 4 10 1 9 4 84 6 Fl a t XL 2 6 40 2 6 0 11 3 7 7 1 1 8 3 7 10 9 2 0 4 9 8 8 3 4 51 7 3 6 1 3 6 0 1 2 7 CS G - I V 20 5 10 3 9 9 85 8 Fl a t XL 2 6 40 2 4 0 11 6 1 7 1 2 0 7 7 10 0 8 0 5 0 8 9 1 4 59 5 0 2 1 4 1 9 6 2 9 CS G - I V 17 7 10 5 7 6 86 10 Fl a t XL 2 6 40 2 0 0 11 8 1 7 1 2 2 7 7 84 0 0 5 1 7 3 1 4 58 1 7 0 1 4 7 7 7 9 9 CS G - I V 13 8 10 7 1 5 87 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 3 2 1 2 2 9 2 63 0 5 1 7 9 4 4 0 1 4 7 7 7 9 9 1 5 10 7 3 0 88 0 Sp a c e r X L 2 6 40 15 11 8 4 7 1 2 3 0 7 63 0 5 1 8 5 7 4 0 1 4 7 7 7 9 9 1 5 10 7 4 5 89 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 0 1 2 3 1 0 12 6 5 1 8 7 0 0 0 1 4 7 7 7 9 9 3 10 7 4 8 90 0 XL F l u s h ( D F I T ) XL 2 6 40 2 7 8 12 1 2 8 1 2 5 8 8 11 6 7 6 5 3 0 3 7 6 0 1 4 7 7 7 9 9 2 7 8 11 0 2 6 91 0 Sl o w f o r s e a t ( D F I T ) X L 2 6 18 50 12 1 7 8 1 2 6 3 8 21 0 0 5 3 2 4 7 6 0 1 4 7 7 7 9 9 5 0 1 1 0 7 6 92 DF I T F l u s h WF 2 6 40 23 3 1 2 4 1 1 1 2 8 7 1 97 8 6 5 4 0 5 8 2 23 3 1 1 3 0 9 93 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 8 1 1 2 9 4 1 29 4 9 5 4 3 5 3 1 TO T A L S 12 9 4 1 54 3 5 3 1 14 7 7 7 9 9 We l l N a m e ND B - 0 2 7 10 / 1 4 / 2 5 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 3. 5 40 40 16 8 0 16 8 0 c WF 2 6 1. 0 0 0 16 8 0 0 0 0 d WF 26 3 . 5 31 0 31 0 1 3 0 2 0 1 4 7 0 0 3 1 0 3 1 0 e P u m p C h e c k WF 26 4 0 10 0 41 0 4 2 0 0 1 8 9 0 0 1 0 0 4 1 0 0 4 1 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 18 40 40 4 5 0 16 8 0 2 0 5 8 0 0 0 4 0 4 5 0 2 0 St a g e 1 3 P A D XL 2 6 40 2 2 0 26 0 6 7 0 92 4 0 2 9 8 2 0 00 CS G - I V 22 0 6 7 0 3 1 Sc o u r XL 2 6 40 6 0 32 0 7 3 0 25 2 0 3 2 3 4 0 24 1 3 2 4 1 3 40 / 7 0 - C L 57 7 2 7 4 3 Sc o u r XL 2 6 40 1 2 0 44 0 8 5 0 50 4 0 3 7 3 8 0 13 3 4 8 1 5 7 6 1 40 / 7 0 - C L 10 6 8 3 3 5 0 Re s u m e P a d XL 2 6 40 5 0 49 0 9 0 0 21 0 0 3 9 4 8 0 0 1 5 7 6 1 5 0 8 8 3 6 1 Fl a t XL 2 6 40 2 0 0 69 0 1 1 0 0 84 0 0 4 7 8 8 0 80 4 3 2 3 8 0 4 CS G - I V 19 1 1 0 7 5 7 2 Fl a t XL 2 6 40 2 2 5 91 5 1 3 2 5 94 5 0 5 7 3 3 0 17 3 5 8 4 1 1 6 3 CS G - I V 20 7 1 2 8 2 8 4 Fl a t XL 2 6 40 2 7 5 11 9 0 1 6 0 0 11 5 5 0 6 8 8 8 0 39 2 3 2 8 0 3 9 4 CS G - I V 23 4 1 5 1 5 9 6 Fl a t XL 2 6 40 2 6 0 14 5 0 1 8 6 0 10 9 2 0 7 9 8 0 0 51 7 3 6 1 3 2 1 3 0 CS G - I V 20 5 1 7 2 0 10 8 Fl a t XL 2 6 40 2 4 0 16 9 0 2 1 0 0 10 0 8 0 8 9 8 8 0 59 5 0 2 1 9 1 6 3 3 CS G - I V 17 7 1 8 9 7 11 10 Fl a t XL 2 6 40 2 0 0 18 9 0 2 3 0 0 84 0 0 9 8 2 8 0 58 1 7 0 2 4 9 8 0 2 CS G - I V 13 8 2 0 3 6 12 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 19 0 5 2 3 1 5 63 0 9 8 9 1 0 0 2 4 9 8 0 2 1 5 2 0 5 1 13 0 Sp a c e r X L 2 6 40 15 19 2 0 2 3 3 0 63 0 9 9 5 4 0 0 2 4 9 8 0 2 1 5 2 0 6 6 14 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 19 2 3 2 3 3 3 12 6 9 9 6 6 6 0 2 4 9 8 0 2 3 2 0 6 9 15 0 St a g e 1 4 P A D XL 2 6 40 2 7 0 21 9 3 2 6 0 3 11 3 4 0 1 1 1 0 0 6 0 2 4 9 8 0 2 2 7 0 2 3 3 9 16 0 Sl o w f o r S e a t X L 2 6 18 50 22 4 3 2 6 5 3 21 0 0 1 1 3 1 0 6 0 2 4 9 8 0 2 5 0 2 3 8 9 17 0 Re s u m e P a d XL 2 6 40 6 0 23 0 3 2 7 1 3 25 2 0 1 1 5 6 2 6 0 2 4 9 8 0 2 6 0 2 4 4 9 18 1 Fl a t XL 2 6 40 2 0 5 25 0 8 2 9 1 8 86 1 0 1 2 4 2 3 6 82 4 4 2 5 8 0 4 6 CS G - I V 19 6 2 6 4 5 19 3 Fl a t XL 2 6 40 2 0 5 27 1 3 3 1 2 3 86 1 0 1 3 2 8 4 6 22 7 9 4 2 8 0 8 4 0 CS G - I V 18 1 2 8 2 6 20 5 Fl a t XL 2 6 40 2 3 5 29 4 8 3 3 5 8 98 7 0 1 4 2 7 1 6 40 3 8 4 3 2 1 2 2 4 CS G - I V 19 2 3 0 1 8 21 7 Fl a t XL 2 6 40 2 3 5 31 8 3 3 5 9 3 98 7 0 1 5 2 5 8 6 52 7 0 7 3 7 3 9 3 1 CS G - I V 17 9 3 1 9 8 22 9 Fl a t XL 2 6 40 2 1 0 33 9 3 3 8 0 3 88 2 0 1 6 1 4 0 6 56 7 1 4 4 3 0 6 4 5 CS G - I V 15 0 3 3 4 8 23 11 Fl a t XL 2 6 40 1 8 0 35 7 3 3 9 8 3 75 6 0 1 6 8 9 6 6 55 8 7 0 4 8 6 5 1 5 CS G - I V 12 1 3 4 6 9 24 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 35 8 8 3 9 9 8 63 0 1 6 9 5 9 6 0 4 8 6 5 1 5 1 5 3 4 8 4 25 0 Sp a c e r X L 2 6 40 15 36 0 3 4 0 1 3 63 0 1 7 0 2 2 6 0 4 8 6 5 1 5 1 5 3 4 9 9 26 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 0 6 4 0 1 6 12 6 1 7 0 3 5 2 0 4 8 6 5 1 5 3 3 5 0 2 27 0 St a g e 1 5 P A D XL 2 6 40 2 6 2 38 6 8 4 2 7 8 11 0 0 4 1 8 1 3 5 6 0 4 8 6 5 1 5 2 6 2 3 7 6 4 28 0 Sl o w f o r S e a t X L 2 6 18 50 39 1 8 4 3 2 8 21 0 0 1 8 3 4 5 6 0 4 8 6 5 1 5 5 0 3 8 1 4 29 0 Re s u m e P a d XL 2 6 40 6 3 39 8 1 4 3 9 1 26 4 6 1 8 6 1 0 2 0 4 8 6 5 1 5 6 3 3 8 7 7 30 1 Fl a t XL 2 6 40 1 9 0 41 7 1 4 5 8 1 79 8 0 1 9 4 0 8 2 76 4 1 4 9 4 1 5 6 CS G - I V 18 2 4 0 5 9 31 3 Fl a t XL 2 6 40 2 1 5 43 8 6 4 7 9 6 90 3 0 2 0 3 1 1 2 23 9 0 5 5 1 8 0 6 1 CS G - I V 19 0 4 2 4 8 32 5 Fl a t XL 2 6 40 2 4 0 46 2 6 5 0 3 6 10 0 8 0 2 1 3 1 9 2 41 2 4 3 5 5 9 3 0 4 CS G - I V 19 6 4 4 4 5 Pu m p B a l l t o S e a t 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 Op e n w e l l - D i s p l a c e P T Dr o p B a l l St a g e t o " L i n e o u t X L " We l l N a m e ND B - 0 2 7 10 / 1 4 / 2 5 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 33 7 Fl a t XL 2 6 40 2 4 0 48 6 6 5 2 7 6 10 0 8 0 2 2 3 2 7 2 53 8 2 8 6 1 3 1 3 2 CS G - I V 18 3 4 6 2 8 34 9 Fl a t XL 2 6 40 2 2 0 50 8 6 5 4 9 6 92 4 0 2 3 2 5 1 2 59 4 1 5 6 7 2 5 4 8 CS G - I V 15 7 47 8 5 35 11 Fl a t XL 2 6 40 1 9 0 52 7 6 5 6 8 6 79 8 0 2 4 0 4 9 2 58 9 7 4 7 3 1 5 2 1 CS G - I V 12 8 49 1 3 36 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 52 9 1 5 7 0 1 63 0 2 4 1 1 2 2 0 7 3 1 5 2 1 1 5 49 2 8 37 0 Sp a c e r X L 2 6 40 15 53 0 6 5 7 1 6 63 0 2 4 1 7 5 2 0 7 3 1 5 2 1 1 5 49 4 3 38 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 0 9 5 7 1 9 12 6 2 4 1 8 7 8 0 7 3 1 5 2 1 3 49 4 6 39 0 St a g e 1 6 P A D XL 2 6 40 2 5 4 55 6 3 5 9 7 3 10 6 6 8 2 5 2 5 4 6 0 7 3 1 5 2 1 2 5 4 52 0 0 40 0 Sl o w f o r S e a t X L 2 6 18 50 56 1 3 6 0 2 3 21 0 0 2 5 4 6 4 6 0 7 3 1 5 2 1 5 0 52 5 0 41 0 Re s u m e P a d XL 2 6 40 9 6 57 0 9 6 1 1 9 40 3 2 2 5 8 6 7 8 0 7 3 1 5 2 1 9 6 53 4 6 42 1 Fl a t XL 2 6 40 1 8 0 58 8 9 6 2 9 9 75 6 0 2 6 6 2 3 8 72 3 9 7 3 8 7 6 0 CS G - I V 17 2 55 1 8 43 2 Fl a t XL 2 6 40 2 0 0 60 8 9 6 4 9 9 84 0 0 2 7 4 6 3 8 15 4 3 0 7 5 4 1 9 0 CS G - I V 18 4 57 0 2 44 4 Fl a t XL 2 6 40 2 2 0 63 0 9 6 7 1 9 92 4 0 2 8 3 8 7 8 31 3 8 5 7 8 5 5 7 5 CS G - I V 18 7 58 8 9 45 6 Fl a t XL 2 6 40 2 2 0 65 2 9 6 9 3 9 92 4 0 2 9 3 1 1 8 43 7 7 7 8 2 9 3 5 2 CS G - I V 17 4 60 6 2 46 8 Fl a t XL 2 6 40 2 2 0 67 4 9 7 1 5 9 92 4 0 3 0 2 3 5 8 54 5 4 4 8 8 3 8 9 5 CS G - I V 16 2 62 2 5 47 10 Fl a t XL 2 6 40 2 0 0 69 4 9 7 3 5 9 84 0 0 3 1 0 7 5 8 58 1 7 0 9 4 2 0 6 5 CS G - I V 13 8 63 6 3 48 12 Fl a t XL 2 6 40 1 8 0 71 2 9 7 5 3 9 75 6 0 3 1 8 3 1 8 59 1 8 3 1 0 0 1 2 4 9 CS G - I V 11 7 64 8 0 49 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 71 4 4 7 5 5 4 63 0 3 1 8 9 4 8 0 1 0 0 1 2 4 9 1 5 64 9 5 50 0 Sp a c e r X L 2 6 40 15 71 5 9 7 5 6 9 63 0 3 1 9 5 7 8 0 1 0 0 1 2 4 9 1 5 65 1 0 51 0 Dr o p S t a g e 1 7 B a l l / C o l l e t F P 0 40 3 71 6 2 7 5 7 2 12 6 3 1 9 7 0 4 0 1 0 0 1 2 4 9 3 65 1 3 52 0 St a g e 1 7 P A D XL 2 6 40 2 4 5 74 0 7 7 8 1 7 10 2 9 0 3 2 9 9 9 4 0 1 0 0 1 2 4 9 2 4 5 67 5 8 53 0 Sl o w f o r S e a t X L 2 6 18 50 74 5 7 7 8 6 7 21 0 0 3 3 2 0 9 4 0 1 0 0 1 2 4 9 5 0 68 0 8 54 0 Re s u m e P a d XL 2 6 40 1 0 5 75 6 2 7 9 7 2 44 1 0 3 3 6 5 0 4 0 1 0 0 1 2 4 9 1 0 5 69 1 3 55 1 Fl a t XL 2 6 40 1 8 0 77 4 2 8 1 5 2 75 6 0 3 4 4 0 6 4 72 3 9 1 0 0 8 4 8 7 CS G - I V 17 2 70 8 6 56 2 Fl a t XL 2 6 40 2 0 0 79 4 2 8 3 5 2 84 0 0 3 5 2 4 6 4 15 4 3 0 1 0 2 3 9 1 7 CS G - I V 18 4 72 7 0 57 4 Fl a t XL 2 6 40 2 2 0 81 6 2 8 5 7 2 92 4 0 3 6 1 7 0 4 31 3 8 5 1 0 5 5 3 0 2 CS G - I V 18 7 74 5 6 58 6 Fl a t XL 2 6 40 2 2 0 83 8 2 8 7 9 2 92 4 0 3 7 0 9 4 4 43 7 7 7 1 0 9 9 0 7 9 CS G - I V 17 4 76 3 0 59 8 Fl a t XL 2 6 40 2 2 0 86 0 2 9 0 1 2 92 4 0 3 8 0 1 8 4 54 5 4 4 1 1 5 3 6 2 3 CS G - I V 16 2 77 9 2 60 10 Fl a t XL 2 6 40 2 0 0 88 0 2 9 2 1 2 84 0 0 3 8 8 5 8 4 58 1 7 0 1 2 1 1 7 9 3 CS G - I V 13 8 79 3 1 61 12 Fl a t XL 2 6 40 1 8 0 89 8 2 9 3 9 2 75 6 0 3 9 6 1 4 4 59 1 8 3 1 2 7 0 9 7 6 CS G - I V 11 7 80 4 8 62 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 89 9 7 9 4 0 7 63 0 3 9 6 7 7 4 0 1 2 7 0 9 7 6 1 5 80 6 3 63 0 Sp a c e r X L 2 6 40 15 90 1 2 9 4 2 2 63 0 3 9 7 4 0 4 0 1 2 7 0 9 7 6 1 5 80 7 8 64 0 Dr o p S t a g e 1 8 B a l l / C o l l e t F P 0 40 3 90 1 5 9 4 2 5 12 6 3 9 7 5 3 0 0 1 2 7 0 9 7 6 3 80 8 1 65 0 St a g e 1 8 P A D XL 2 6 40 2 3 8 92 5 3 9 6 6 3 99 9 6 4 0 7 5 2 6 0 1 2 7 0 9 7 6 2 3 8 83 1 9 66 0 Sl o w f o r S e a t X L 2 6 18 50 93 0 3 9 7 1 3 21 0 0 4 0 9 6 2 6 0 1 2 7 0 9 7 6 5 0 83 6 9 67 0 Re s u m e P a d XL 2 6 40 1 1 2 94 1 5 9 8 2 5 47 0 4 4 1 4 3 3 0 0 1 2 7 0 9 7 6 1 1 2 84 8 1 68 1 Fl a t XL 2 6 40 1 8 0 95 9 5 1 0 0 0 5 75 6 0 4 2 1 8 9 0 72 3 9 1 2 7 8 2 1 5 CS G - I V 17 2 86 5 4 69 2 Fl a t XL 2 6 40 2 0 0 97 9 5 1 0 2 0 5 84 0 0 4 3 0 2 9 0 15 4 3 0 1 2 9 3 6 4 4 CS G - I V 18 4 88 3 7 70 4 Fl a t XL 2 6 40 2 2 0 10 0 1 5 1 0 4 2 5 92 4 0 4 3 9 5 3 0 31 3 8 5 1 3 2 5 0 3 0 CS G - I V 18 7 90 2 4 71 6 Fl a t XL 2 6 40 2 2 0 10 2 3 5 1 0 6 4 5 92 4 0 4 4 8 7 7 0 43 7 7 7 1 3 6 8 8 0 6 CS G - I V 17 4 91 9 8 72 8 Fl a t XL 2 6 40 2 2 0 10 4 5 5 1 0 8 6 5 92 4 0 4 5 8 0 1 0 54 5 4 4 1 4 2 3 3 5 0 CS G - I V 16 2 93 6 0 73 10 Fl a t XL 2 6 40 2 0 0 10 6 5 5 1 1 0 6 5 84 0 0 4 6 6 4 1 0 58 1 7 0 1 4 8 1 5 2 0 CS G - I V 13 8 94 9 9 74 12 Fl a t XL 2 6 40 1 8 0 10 8 3 5 1 1 2 4 5 75 6 0 4 7 3 9 7 0 59 1 8 3 1 5 4 0 7 0 3 CS G - I V 11 7 9 6 1 6 We l l N a m e ND B - 0 2 7 10 / 1 4 / 2 5 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 XL F l u s h XL 2 6 40 10 1 0 8 4 5 1 1 2 5 5 42 0 4 7 2 7 1 0 10 9 6 2 6 76 Li n e a r F l u s h WF 2 6 40 18 7 1 1 0 3 2 1 1 4 4 2 78 5 4 4 8 0 5 6 4 18 7 9 8 1 3 77 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 1 0 2 1 1 5 1 2 29 4 9 4 8 3 5 1 3 TO T A L S 11 5 1 2 48 3 5 1 3 15 4 0 7 0 3 Additive Additive Description D206 Antifoam Agent 0.0 Gal/mGal 10 gal F103 Surfactant 1.0 Gal/mGal 1,344.0 gal J450 Stabilizing Agent 0.4 Gal/mGal 620.0 gal J475 Breaker J475 5.3 lb/mGal 7,434.0 lbm J511 Stabilizing Agent 1.8 lb/mGal 2,478.0 lbm J532 Crosslinker 2.2 Gal/mGal 3,098.0 gal J580 Gel J580 26.0 lb/mGal 34,944.0 lbm J753 Enzyme Breaker J753 0.1 Gal/mGal 93.0 gal M002 Additive 0.0 lb/mGal 1 lbm M117 Clay Control Agent 323.9 lb/mGal 455,593.2 lbm M275 Bactericide 0.3 lb/mGal 427.0 lbm S522-1620 Propping Agent varied concentrations 4,005,045.0 lbm S522-4070 Propping Agent varied concentrations 121,040.0 lbm S901-1620 Proppant with Scale Inhibitor S901- 1620 varied concentrations 127,820.0 lbm S902-1620 Proppant with Scale Inhibitor S902- 16/20 varied concentrations 127,821.0 lbm ~ 69 % ~ 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 1,344,000 gal † Proprietary Technology The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. Fluid Name & Volume Concentration Volume Disclosure Type: Pre-Job Well Completed: Date Prepared: 10/17/2025 State: Alaska County/Parish: North Slope Borough Case: Client: Oil Search Alaska Well: PIKKA NDB-027 Basin/Field: Pikka # SLB-Private Page: 1 / 1 Up d a t e d 1 0 / 0 3 / 2 0 2 5 10 / 3 / 2 0 2 5 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 ! 15 1 . 4 5 7 3 9 4 0 0 0 0 T- 7 1 6 Tr a c e r c o Ch e m i c a l T r a c e r 1, 3 , 5 - T r i b r o m o b e n z e n e 62 6 - 3 9 - 1 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 1 6 1 B Tr a c e r c o Ch e m i c a l T r a c e r 4- I o d o t o l u e n e 62 4 - 3 1 - 7 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 7 3 1 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 - 3 , 5 - d i c h l o r o b e n z e n e 19 7 5 2 - 5 5 - 7 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 7 1 8 Tr a c e r c o Ch e m i c a l T r a c e r 4- C h l o r o b e n z o p h e n o n e 13 4 - 8 5 - 0 10 0 #V A L U E ! 0. 6 6 1 3 8 6 0 0 0 0 T- 1 6 8 A Tr a c e r c o Ch e m i c a l T r a c e r 1- C h l o r o - 4 - i o d o b e n z e n e 63 7 - 8 7 - 6 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 1 6 8 C 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 - 4 - i o d o b e n z e n e 58 9 - 8 7 - 7 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 7 6 9 Tr a c e r c o Ch e m i c a l T r a c e r 4- F l u o r o b e n z o p h e n o n e 34 5 - 8 3 - 5 10 0 #V A L U E ! 1. 1 0 2 3 1 0 0 0 0 0 T- 7 4 8 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 - c h l o r o b e n z e n e 69 4 - 8 0 - 4 10 0 #V A L U E ! 2. 2 0 4 6 2 0 0 0 0 0 T- 7 0 6 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 - 4 - c h l o r o b e n z e n 10 6 - 3 9 - 8 10 0 #V A L U E ! 2. 2 0 4 6 2 0 0 0 0 0 T- 1 6 0 D Tr a c e r c o Ch e m i c a l T r a c e r 2, 4 , 5 - T r i b r o m o t o l u e n e 32 7 8 - 8 8 - 4 10 0 #V A L U E ! 0. 6 6 1 3 8 6 0 0 0 0 T- 7 5 6 Tr a c e r c o Ch e m i c a l T r a c e r 3, 5 - D i f l u o r o b e n z o p h e n o n e 17 9 1 1 3 - 8 9 - 4 10 0 #V A L U E ! 0. 6 6 1 3 8 6 0 0 0 0 T- 1 6 3 B Tr a c e r c o Ch e m i c a l T r a c e r 1, 2 - D i i o d o b e n z e n e 61 5 - 4 2 - 9 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 1 6 5 B Tr a c e r c o Ch e m i c a l T r a c e r 2- I o d o b i p h e n y l 21 1 3 - 5 1 - 1 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 1 6 5 C Tr a c e r c o Ch e m i c a l T r a c e r 9- B r o m o p h e n a n t h r e n e 57 3 - 1 7 - 1 10 0 #V A L U E ! 0. 6 6 1 3 8 6 0 0 0 0 T- 1 6 5 G 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 f l u o r e n e 11 3 3 - 8 0 - 8 10 0 #V A L U E ! 0. 8 8 1 8 4 8 0 0 0 0 T- 1 6 6 C Tr a c e r c o Ch e m i c a l T r a c e r 1- I o d o - 3 , 4 - d i m e t h y l b e n z e n e 31 5 9 9 - 6 1 - 8 10 0 #V A L U E ! 1. 1 0 2 3 1 0 0 0 0 0 T- 1 6 8 B Tr a c e r c o Ch e m i c a l T r a c e r 1, 2 - D i c h l o r o - 4 - i o d o b e n z e n e 20 5 5 5 - 9 1 - 3 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 1 6 9 C Tr a c e r c o Ch e m i c a l T r a c e r 2, 4 - D i b r o m o m e s i t y l e n e 69 4 2 - 9 9 - 0 10 0 #V A L U E ! 0. 8 8 1 8 4 8 0 0 0 0 T- 1 6 4 C Tr a c e r c o So l i d 1- I o d o n a p h t h a l e n e 90 - 1 4 - 2 10 0 #V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 7 2 9 Tr a c e r c o So l i d 1, 4 - D i b r o m o - 2 , 5 - d i m e t h y l b e n z e n e 10 7 4 - 2 4 - 4 10 0 #V A L U E ! 2. 2 0 4 6 2 0 0 0 0 0 T- 1 6 0 B Tr a c e r c o So l i d 3, 5 - D i b r o m o t o l u e n e 16 1 1 - 9 2 - 3 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 ! 11 0 . 1 3 7 2 7 4 0 0 0 0 T- 1 5 8 d 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 f l u o r o b e n z o a t e 52 2 6 5 1 - 4 4 - 1 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 4 0 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 - 3 - F l u o r o b e n z o a t e 49 9 - 5 7 - 0 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 5 8 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 , 6 - D i f l u o r o b e n z o a t e 61 8 5 - 2 8 - 0 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 - 0 2 7 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 T- 1 9 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 - ( T r i f l u o r o m e t h y l ) b e n z o a t e 25 8 3 2 - 5 8 - 0 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 9 0 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 - ( T r i f l u o r o m e t h y l ) b e n z o a t e 29 6 6 - 4 4 - 1 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 5 8 f 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 f l u o r o b e n z o a t e 16 0 4 8 1 9 - 0 8 - 0 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 1 0 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 - 3 - f l u o r o b e n z o a t e 13 8 2 1 0 6 - 8 3 - 3 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 5 0 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 - f l u o r o - 3 - ( T r i f l u o r o m e t h y l ) - b e n z o a t e 17 0 1 4 4 6 - 4 1 - 4 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 5 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 - 3 - f l u o r o - 5 - ( T r i f l u o r o m e t h y l ) - b e n z o a t e 15 3 5 1 6 9 - 5 9 - 5 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 9 0 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 - 3 - ( T r i f l u o r o m e t h y l ) b e n z o a t e 69 2 2 6 - 4 1 - 1 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 7 6 d 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 , 5 - t r i f l u o r o b e n z o a t e 11 8 0 4 9 3 - 1 2 - 2 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 4 0 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 - f l u o r o b e n z o a t e 49 0 - 9 7 - 1 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 2 5 7 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 - 3 , 5 - d i ( T r i f l u o r o m e t h y l ) b e n z o a t e 87 4 4 1 - 9 6 - 1 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 1 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 - c h l o r o - 4 , 5 - d i f l u o r o b e n z o a t e 14 2 1 7 6 1 - 1 6 - 1 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 1 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 - 3 - c h l o r o - 2 , 4 - d i f l u o r o b e n z o a t e 13 9 6 7 6 2 - 3 4 - 7 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 1 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 - 4 - c h l o r o - 3 - f l u o r o b e n z o a t e 14 2 1 0 2 9 - 8 8 - 0 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 2 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 - 3 - c h l o r o - 2 - f l u o r o b e n z o a t e 14 2 1 0 2 9 - 8 9 - 1 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 2 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 - 4 - f l u o r o - 3 - m e t h y l b e n z o a t e 14 3 1 8 6 8 - 1 8 - 6 10 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 Attachment G NDB-027 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 NDB-027 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 H NDB-027 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. Flow check for 10 minutes. 9. POOH with liner hanger running tool. 10.Prepare to run upper completion. NDB-027 4-1/2” Upper Completion Section Summary Procedure: 11.Run 4-1/2” 12.6 ppf P110S TSH563 tubing and downhole jewellery. 12.Circulate out the OBM from liner top to surface with 9.2 ppg NaCl Brine. 13.Land tubing hanger. 14.MIT-IA to 4,000 psi for 30 minutes on rig. (Post rig move, pressure tested to 4,300 psi for 30 minutes and passed (09/30/2025)) 15.MIT-T to 3,500 psi for 30 minutes on rig. (Post rig move, pressure tested to 5,500 psi for 30 minutes and passed (09/30/2025)) a. Post rig more pressure test criteria: (8,800 psi MAWP – 3,800 psi IA hold) * 1.1 = 5,500 psi tubing 16.Nipple down BOP stack and install 10k frac tree. 17.RDMO Attachment I Attachment J Tuluvak Sand @ 3,311' MD Top Nan 3.2 @17,344' MD Top Nanushuk @15,992' NDB-027 Well Schematic (As-Built) 20" Insulated Conductor128' MD 9-5/8" Liner Hanger and Liner Top Packer 2,780' MD 13-3/8" 68 ppf L-80 Surface Casing 2,935' MD 4-½”, 12.6ppf P-110S Production Liner26,907' MD 4-½” Liner Hanger/Top Packer17,056' MD GL 69.74' RKB – MSL 09/29/2025 9-5/8" Tieback2,780' MD 9-5/8" Cflex Stage Tool (50' MD below TS790)5,979' MD 7" TOC (224' TVD above top Nanushuk) 13,886' MD 7", 26ppf L-80 Production Liner17,275' MD 9-5/8", 47ppf L-80 Intermediate Liner 11,995' MD 9-5/8" Primary TOC (1000' MD above shoe) 10,995' MD 7" Liner Hanger and Liner Top Packer 11,832' MD 23 29 10 47 48 8-½” Openhole TD26,914' 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 PB1 Sidetrack 12,000' MD 12¼” openhole # Completion Item Top Depth (MD') Depth (TVD') Inc ID" OD" 1 X Landing Nipple 1543 1480 29 3.813 5.201 2 Gaslift Mandrel 1.5" 2308 2080 52 3.865 7.640 3 X Landing Nipple 2379 2120 54 3.813 5.203 4 D/H Psi-Temp Gauge 16717 3900 76 3.864 5.830 5 EGL Valve 16822 3930 74 3.958 5.900 6 Tieback Seal Assy (No-Go) 17056 4000 71 3.860 5.190 7 7" x 4.5" LH/Packer 17103 4010 71 5.000 5.960 8 #20 Openhole Packer 17421 4100 78 3.898 5.755 9 #19 Openhole Packer 17487 4110 81 3.898 5.700 10 Stg 18 - Collet Sleeve 18 17634 4130 84 3.735 5.634 11 #18 Openhole Packer 17906 4140 89 3.898 5.755 12 Stg 17 - Collet Sleeve 17 18137 4141 90 3.735 5.634 13 #17 Openhole Packer 18365 4141 90 3.898 5.755 14 Stg 16 - Collet Sleeve 16 18678 4140 90 3.735 5.634 15 #16 Openhole Packer 18868 4139 90 3.898 5.755 16 Stg 15 - Collet Sleeve 15 19223 4138 90 3.735 5.634 17 #15 Openhole Packer 19495 4137 90 3.898 5.755 18 Stg 14 - Collet Sleeve 14 19768 4136 90 3.735 5.634 19 #14 Openhole Packer 20122 4134 90 3.898 5.755 20 Stg 13 - Collet Sleeve 13 20312 4134 90 3.735 5.634 21 #13 Openhole Packer 20624 4132 90 3.898 5.755 22 Stg 12 - Collet Sleeve 12 20855 4131 90 3.735 5.634 23 #12 Openhole Packer 21127 4128 90 3.898 5.755 24 Stg 11 - Collet Sleeve 11 21399 4126 91 3.735 5.634 25 #11 Openhole Packer 21672 4124 90 3.898 5.755 26 Stg 10 - Collet Sleeve 10 21944 4122 90 3.735 5.634 27 #10 Openhole Packer 22255 4120 90 3.898 5.755 28 Stg 9 - Collet Sleeve 9 22486 4119 90 3.735 5.634 29 #9 Openhole Packer 22759 4118 90 3.898 5.755 30 Stg 8- Collet Sleeve 8 23032 4117 90 3.735 5.634 31 #8 Openhole Packer 23304 4116 90 3.898 5.755 32 Stg 7 - Collet Sleeve 7 23575 4115 90 3.735 5.634 33 #7 Openhole Packer 23847 4113 90 3.898 5.755 34 Stg 6- Collet Sleeve 6 24118 4112 90 3.735 5.634 35 #6 Openhole Packer 24389 4111 90 3.898 5.755 36 Stg 5 - Collet Sleeve 5 24659 4109 90 3.735 5.634 37 #5 Openhole Packer 24930 4107 91 3.898 5.755 38 Stg 4 - Collet Sleeve 4 25201 4105 90 3.735 5.634 39 #4 Openhole Packer 25472 4102 91 3.898 5.755 40 Stg 3 - Collet Sleeve 3 25744 4100 90 3.735 5.634 41 #3 Openhole Packer 25975 4099 90 3.898 5.755 42 Stg 2 - Collet Sleeve 2 26205 4098 90 3.735 5.634 43 #2 Openhole Packer 26434 4098 90 3.898 5.755 44 Stg 1 - Collet Sleeve 1 26665 4097 90 3.735 5.634 45 #1 Openhole Packer 26772 4096 90 3.898 5.755 46 Toe Sleeve 26879 4095 90 3.500 5.750 47 WIV Collar 26892 4095 90 0.875 5.620 48 Eccentric shoe 26905 4095 90 3.840 5.200 Attachment K Kinetix-Frac Completion Report Santos Country: United States Well Name: NDB-027 Operator: Santos Field: Pikka Formation: Nanushuk Prepared By: Maylu Ramones Report Date: October 15th 2025 Table of Contents Well Description ......................................................................................................................................................................................... 5 Stage 1 ....................................................................................................................................................................................................... 6 Zoneset Simulated: ................................................................................................................................................................................ 6 Pumping Schedule Simulated: ............................................................................................................................................................. 10 Simulation Summary: ........................................................................................................................................................................... 11 Stage 2 ..................................................................................................................................................................................................... 12 Zoneset Simulated: .............................................................................................................................................................................. 12 Pumping Schedule Simulated: ............................................................................................................................................................. 16 Simulation Summary: ........................................................................................................................................................................... 17 Stage 3 ..................................................................................................................................................................................................... 18 Zoneset Simulated: .............................................................................................................................................................................. 18 Pumping Schedule Simulated: ............................................................................................................................................................. 22 Simulation Summary: ........................................................................................................................................................................... 23 Stage 4 ..................................................................................................................................................................................................... 24 Zoneset Simulated: .............................................................................................................................................................................. 24 Pumping Schedule Simulated: ............................................................................................................................................................. 28 Simulation Summary: ........................................................................................................................................................................... 29 Stage 5 ..................................................................................................................................................................................................... 30 Zoneset Simulated: .............................................................................................................................................................................. 30 Pumping Schedule Simulated: ............................................................................................................................................................. 34 Simulation Summary: ........................................................................................................................................................................... 35 Stage 6 ..................................................................................................................................................................................................... 36 Zoneset Simulated: .............................................................................................................................................................................. 36 Pumping Schedule Simulated: ............................................................................................................................................................. 40 Stage 7 ..................................................................................................................................................................................................... 42 Zoneset Simulated: .............................................................................................................................................................................. 42 Pumping Schedule Simulated: ............................................................................................................................................................. 46 Simulation Summary: ........................................................................................................................................................................... 47 Stage 8 ..................................................................................................................................................................................................... 48 Zoneset Simulated: .............................................................................................................................................................................. 48 Pumping Schedule Simulated: ............................................................................................................................................................. 52 Simulation Summary: ........................................................................................................................................................................... 53 Stage 9 ..................................................................................................................................................................................................... 54 Attachment K- NDB-027 Page 3 of 113 Zoneset Simulated: .............................................................................................................................................................................. 54 Pumping Schedule Simulated: ............................................................................................................................................................. 58 Simulation Summary: ........................................................................................................................................................................... 59 Stage 10 ................................................................................................................................................................................................... 60 Zoneset Simulated: .............................................................................................................................................................................. 60 Pumping Schedule Simulated: ............................................................................................................................................................. 64 Simulation Summary: ........................................................................................................................................................................... 65 Stage 11 ................................................................................................................................................................................................... 66 Zoneset Simulated: .............................................................................................................................................................................. 66 Pumping Schedule Simulated: ............................................................................................................................................................. 70 Simulation Summary: ........................................................................................................................................................................... 71 Stage 12 ................................................................................................................................................................................................... 72 Zoneset Simulated: .............................................................................................................................................................................. 72 Pumping Schedule Simulated: ............................................................................................................................................................. 76 Simulation Summary: ........................................................................................................................................................................... 77 Stage 13 ................................................................................................................................................................................................... 78 Zoneset Simulated: .............................................................................................................................................................................. 78 Pumping Schedule Simulated: ............................................................................................................................................................. 82 Simulation Summary: ........................................................................................................................................................................... 83 Stage 14 ................................................................................................................................................................................................... 84 Zoneset Simulated: .............................................................................................................................................................................. 84 Pumping Schedule Simulated: ............................................................................................................................................................. 88 Simulation Summary: ........................................................................................................................................................................... 89 Stage 15 ................................................................................................................................................................................................... 90 Zoneset Simulated: .............................................................................................................................................................................. 90 Pumping Schedule Simulated: ............................................................................................................................................................. 94 Simulation Summary: ........................................................................................................................................................................... 95 Stage 16 ................................................................................................................................................................................................... 96 Zoneset Simulated: .............................................................................................................................................................................. 96 Pumping Schedule Simulated: ........................................................................................................................................................... 100 Simulation Summary: ......................................................................................................................................................................... 101 Stage 17 ................................................................................................................................................................................................. 102 Zoneset Simulated: ............................................................................................................................................................................ 102 Pumping Schedule Simulated: ........................................................................................................................................................... 106 Simulation Summary: ......................................................................................................................................................................... 107 Attachment K- NDB-027 Page 4 of 113 Stage 18 ................................................................................................................................................................................................. 108 Zoneset Simulated: ............................................................................................................................................................................ 108 Pumping Schedule Simulated: ........................................................................................................................................................... 112 Simulation Summary: ......................................................................................................................................................................... 113 Attachment K- NDB-027 Page 5 of 113 Well Description Completion Stages and Perforations Stage Perforation Top MD Spacing Perforation Top TVD (ft) (ft) (ft) 18 17634 497 4130.63 17 18137 535 4141.96 16 18678 539 4139.88 15 19223 539 4137.9 14 19768 538 4135.81 13 20312 537 4133.88 12 20855 538 4130.42 11 21399 539 4125.94 10 21944 536 4121.75 9 22486 540 4118.69 8 23032 537 4116.69 7 23575 537 4114.53 6 24118 535 4112.36 5 24659 536 4108.82 4 25201 537 4104.48 3 25744 455 4100.41 2 26205 454 4098.4 1 26665 0 4096.62 Attachment K- NDB-027 Page 6 of 113 Stage 1 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 1 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 7718.5 psi 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 29.82 0.7 2816.05 2786554.2 0.25 2500 Shale 4037.8 26.74 0.66 2665.65 2786554.2 0.25 2500 Top 3.2 NAN CS 4064.53 3.6 0.6 2460.13 1159218.9 0.26 600 Siltstone 4068.14 1.8 0.62 2510.6 1629236.3 0.26 1500 CleanSandstone 4069.95 1.8 0.6 2446.64 979798.8 0.26 600 Siltstone 4071.75 3.6 0.61 2468.54 1350455.1 0.26 1500 CleanSandstone 4075.36 3.6 0.61 2487.11 1206390.9 0.26 600 Siltstone 4078.94 3.6 0.61 2476.95 1313860.7 0.26 1500 CleanSandstone 4082.55 7.2 0.61 2480.29 1266403.2 0.26 600 Attachment K- NDB-027 Page 7 of 113 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 4089.73 1.8 0.61 2478.99 1082935.6 0.26 1500 DirtySandstone 4091.54 1.8 0.62 2549.62 1222900.8 0.26 600 Shale 4093.34 1.8 0.62 2554.84 1419038.4 0.26 2500 DirtySandstone 4095.14 1.8 0.62 2519.02 1403385.6 0.26 600 Siltstone 4096.95 9 0.62 2534.68 1402756.3 0.26 1500 Shale 4105.94 3.6 0.66 2690.6 2181052.3 0.25 2500 DirtySandstone 4109.55 5.4 0.62 2553.68 1662780.4 0.26 1500 Siltstone 4114.96 1.8 0.63 2584.72 1963674.5 0.26 2500 DirtySandstone 4116.73 3.7 0.62 2561.8 1742901.7 0.26 1500 Siltstone 4120.44 5.4 0.63 2597.63 1681056.2 0.26 2500 Siltstone 4125.85 1.8 0.62 2566.88 1561073 0.26 1500 DirtySandstone 4127.66 1.8 0.62 2551.5 1262913.1 0.26 2500 Siltstone 4129.46 3.6 0.63 2610.97 1816969.7 0.26 1500 Shale 4133.04 11 0.65 2673.48 2238744.4 0.25 2500 CleanSandstone 4144.06 2 0.61 2516.11 1001510.6 0.26 600 Siltstone 4146.03 4 0.62 2571.81 1571504.2 0.26 1500 Attachment K- NDB-027 Page 8 of 113 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) CleanSandstone 4150.03 2 0.6 2511.33 1267177.7 0.26 600 Shale 4152.03 2 0.66 2728.59 2789765.8 0.25 2500 Siltstone 4154.04 2 0.62 2563.69 1409418.9 0.26 1500 Shale 4156.04 2.1 0.66 2731.21 2789765.8 0.25 2500 DirtySandstone 4158.14 4 0.61 2537.73 1435306.6 0.26 1500 Siltstone 4162.14 4 0.62 2590.08 1765617.4 0.26 2500 DirtySandstone 4166.14 4 0.61 2559.19 1435651.3 0.26 1500 CleanSandstone 4170.14 2.1 0.59 2465.21 935658.3 0.26 2500 Siltstone 4172.24 4 0.62 2596.32 1491142.7 0.26 1500 Shale 4176.25 2 0.66 2744.4 2789765.8 0.25 2500 DirtySandstone 4178.25 11 0.62 2581.38 1462838 0.26 1500 Shale 4189.24 27 0.65 2740.2 2560999.9 0.25 2500 Siltstone 4216.24 2 0.63 2673.77 1857874.8 0.26 1500 Shale 4218.24 10 0.66 2770.51 2552268.6 0.25 2500 Siltstone 4228.25 2 0.63 2651.72 1509543.6 0.26 1500 Shale 4230.25 4.1 0.64 2708.72 2349461.1 0.25 2500 Attachment K- NDB-027 Page 9 of 113 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 4234.35 2 0.64 2693.64 1482677.8 0.25 1500 Shale 4236.35 96.4 0.65 2797.78 2604074 0.25 2500 DirtySandstone 4332.74 2 0.61 2643.6 1153391 0.26 1500 Shale 4334.74 38.2 0.66 2851.73 2733692 0.25 2500 Siltstone 4372.93 2 0.62 2716.27 1526263.4 0.26 1500 Shale 4374.93 46.2 0.66 2880.74 2704369.9 0.25 2500 Siltstone 4421.16 2 0.64 2808.08 1825853.3 0.25 1500 Shale 4423.13 9.84 0.65 2891.47 2657615 0.25 2500 Attachment K- NDB-027 Page 10 of 113 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 125 CarboLite 16/20- SG 1 5027 3.13 3 2 PPA 40 YF126ST 5400.5 140 CarboLite 16/20- SG 2 10801 3.5 4 3 PPA 40 YF126ST 6300.9 170 CarboLite 16/20- SG 3 18902.7 4.25 5 4 PPA 40 YF126ST 6063.6 170 CarboLite 16/20- SG 4 24254.4 4.25 6 5 PPA 40 YF126ST 5843.5 170 CarboLite 16/20- SG 5 29217.5 4.25 7 6 PPA 40 YF126ST 5638.5 170 CarboLite 16/20- SG 6 33831 4.25 8 7 PPA 40 YF126ST 4486.3 140 CarboLite 16/20- SG 7 31404.1 3.5 9 8 PPA 40 YF126ST 3874.4 125 CarboLite 16/20- SG 8 30995.2 3.12 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 28.27 24.84 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 59434.7 184432.9 1610 40.25 Attachment K- NDB-027 Page 11 of 113 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 1 MD: [26665, 26671] 7718.5 214.19 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4027.34 4241.53 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 1 MD: [26665, 26671] 520.05 172.4 0.593 Attachment K- NDB-027 Page 12 of 113 Stage 2 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 2 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 6000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 7727.7 psi 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 4000 30.62 0.7 2810.68 2786554.2 0.25 2500 Shale 4030.62 26.74 0.66 2656.9 2786554.2 0.25 2500 Top 3.2 NAN CS 4057.36 3.6 0.6 2455.79 1159218.9 0.26 600 Siltstone 4060.96 1.8 0.62 2506.17 1629236.3 0.26 1500 CleanSandstone 4062.76 1.8 0.6 2442.26 979798.8 0.26 600 Siltstone 4064.56 3.6 0.61 2464.21 1350455.1 0.26 1500 CleanSandstone 4068.16 3.6 0.61 2482.68 1206390.9 0.26 600 Siltstone 4071.76 3.6 0.61 2472.65 1313860.7 0.26 1500 CleanSandstone 4075.36 7.2 0.61 2475.93 1266403.2 0.26 600 Attachment K- NDB-027 Page 13 of 113 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 4082.56 1.8 0.61 2474.58 1082935.6 0.26 1500 DirtySandstone 4084.36 1.8 0.62 2545.12 1222900.8 0.26 600 Shale 4086.16 1.8 0.62 2550.33 1419038.4 0.26 2500 DirtySandstone 4087.96 1.8 0.62 2514.65 1403385.6 0.26 600 Siltstone 4089.76 9 0.62 2530.25 1402756.3 0.26 1500 Shale 4098.76 3.6 0.66 2685.87 2181052.3 0.25 2500 DirtySandstone 4102.36 5.4 0.62 2549.24 1662780.4 0.26 1500 Siltstone 4107.76 1.8 0.63 2580.24 1963674.5 0.26 2500 DirtySandstone 4109.56 3.7 0.62 2557.3 1742901.7 0.26 1500 Siltstone 4113.26 5.4 0.63 2593.05 1681056.2 0.26 2500 Siltstone 4118.66 1.8 0.62 2562.37 1561073 0.26 1500 DirtySandstone 4120.46 1.8 0.62 2547 1262913.1 0.26 2500 Siltstone 4122.26 3.6 0.63 2606.41 1816969.7 0.26 1500 Shale 4125.86 11 0.65 2668.86 2238744.4 0.25 2500 CleanSandstone 4136.86 2 0.61 2511.68 1001510.6 0.26 600 Siltstone 4138.86 4 0.62 2567.33 1571504.2 0.26 1500 Attachment K- NDB-027 Page 14 of 113 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) CleanSandstone 4142.86 2 0.6 2507.04 1267177.7 0.26 600 Shale 4144.86 2 0.66 2723.83 2789765.8 0.25 2500 Siltstone 4146.86 2 0.62 2559.23 1409418.9 0.26 1500 Shale 4148.86 2.1 0.66 2726.49 2789765.8 0.25 2500 DirtySandstone 4150.96 4 0.61 2533.31 1435306.6 0.26 1500 Siltstone 4154.96 4 0.62 2585.63 1765617.4 0.26 2500 DirtySandstone 4158.96 4 0.61 2554.83 1435651.3 0.26 1500 CleanSandstone 4162.96 2.1 0.59 2460.93 935658.3 0.26 2500 Siltstone 4165.06 4 0.62 2591.91 1491142.7 0.26 1500 Shale 4169.06 2 0.66 2739.73 2789765.8 0.25 2500 DirtySandstone 4171.06 11 0.62 2576.94 1462838 0.26 1500 Shale 4182.06 27 0.65 2735.51 2560999.9 0.25 2500 Siltstone 4209.06 2 0.63 2669.18 1857874.8 0.26 1500 Shale 4211.06 10 0.66 2765.74 2552268.6 0.25 2500 Siltstone 4221.06 2 0.63 2647.23 1509543.6 0.26 1500 Shale 4223.06 4.1 0.64 2704.07 2349461.1 0.25 2500 Attachment K- NDB-027 Page 15 of 113 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 4227.16 2 0.64 2689.11 1482677.8 0.25 1500 Shale 4229.16 96.4 0.65 2793.12 2604074 0.25 2500 DirtySandstone 4325.56 2 0.61 2639.2 1153391 0.26 1500 Shale 4327.56 38.2 0.66 2847.06 2733692 0.25 2500 Siltstone 4365.76 2 0.62 2711.76 1526263.4 0.26 1500 Shale 4367.76 46.2 0.66 2876.01 2704369.9 0.25 2500 Siltstone 4413.96 2 0.64 2803.5 1825853.3 0.25 1500 Shale 4415.96 14.04 0.65 2888.21 2657615 0.25 2500 Attachment K- NDB-027 Page 16 of 113 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 6636.3 165.02 CarboLite 16/20- SG 1 6636.3 4.13 3 2 PPA 40 YF126ST 6945 180.03 CarboLite 16/20- SG 2 13890 4.5 4 3 PPA 40 YF126ST 7230.2 195.07 CarboLite 16/20- SG 3 21690.6 4.88 5 4 PPA 40 YF126ST 6958.4 195.09 CarboLite 16/20- SG 4 27833.6 4.88 6 5 PPA 40 YF126ST 6706.3 195.11 CarboLite 16/20- SG 5 33531.5 4.88 7 6 PPA 40 YF126ST 6471.8 195.12 CarboLite 16/20- SG 6 38830.8 4.88 8 7 PPA 40 YF126ST 5932.5 185.13 CarboLite 16/20- SG 7 41527.5 4.63 9 8 PPA 40 YF126ST 5273.3 170.13 CarboLite 16/20- SG 8 42186.4 4.25 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.6 23.31 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 71053.8 226126.7 1930.7 48.27 Attachment K- NDB-027 Page 17 of 113 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 2 MD: [26205, 26211] 7727.7 230.68 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4018.4 4249.08 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 2 MD: [26205, 26211] 629.18 177.41 0.54 Attachment K- NDB-027 Page 18 of 113 Stage 3 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 3 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 7494.5 psi 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 4000 30.62 0.7 2810.68 2786554.2 0.25 2500 Shale 4030.62 26.74 0.66 2656.9 2786554.2 0.25 2500 Top 3.2 NAN CS 4057.36 3.6 0.6 2455.79 1159218.9 0.26 600 Siltstone 4060.96 1.8 0.62 2506.17 1629236.3 0.26 1500 CleanSandstone 4062.76 1.8 0.6 2442.26 979798.8 0.26 600 Siltstone 4064.56 3.6 0.61 2464.21 1350455.1 0.26 1500 CleanSandstone 4068.16 3.6 0.61 2482.68 1206390.9 0.26 600 Siltstone 4071.76 3.6 0.61 2472.65 1313860.7 0.26 1500 CleanSandstone 4075.36 7.2 0.61 2475.93 1266403.2 0.26 600 Attachment K- NDB-027 Page 19 of 113 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 4082.56 1.8 0.61 2474.58 1082935.6 0.26 1500 DirtySandstone 4084.36 1.8 0.62 2545.12 1222900.8 0.26 600 Shale 4086.16 1.8 0.62 2550.33 1419038.4 0.26 2500 DirtySandstone 4087.96 1.8 0.62 2514.65 1403385.6 0.26 600 Siltstone 4089.76 9 0.62 2530.25 1402756.3 0.26 1500 Shale 4098.76 3.6 0.66 2685.87 2181052.3 0.25 2500 DirtySandstone 4102.36 5.4 0.62 2549.24 1662780.4 0.26 1500 Siltstone 4107.76 1.8 0.63 2580.24 1963674.5 0.26 2500 DirtySandstone 4109.56 3.7 0.62 2557.3 1742901.7 0.26 1500 Siltstone 4113.26 5.4 0.63 2593.05 1681056.2 0.26 2500 Siltstone 4118.66 1.8 0.62 2562.37 1561073 0.26 1500 DirtySandstone 4120.46 1.8 0.62 2547 1262913.1 0.26 2500 Siltstone 4122.26 3.6 0.63 2606.41 1816969.7 0.26 1500 Shale 4125.86 11 0.65 2668.86 2238744.4 0.25 2500 CleanSandstone 4136.86 2 0.61 2511.68 1001510.6 0.26 600 Siltstone 4138.86 4 0.62 2567.33 1571504.2 0.26 1500 Attachment K- NDB-027 Page 20 of 113 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) CleanSandstone 4142.86 2 0.6 2507.04 1267177.7 0.26 600 Shale 4144.86 2 0.66 2723.83 2789765.8 0.25 2500 Siltstone 4146.86 2 0.62 2559.23 1409418.9 0.26 1500 Shale 4148.86 2.1 0.66 2726.49 2789765.8 0.25 2500 DirtySandstone 4150.96 4 0.61 2533.31 1435306.6 0.26 1500 Siltstone 4154.96 4 0.62 2585.63 1765617.4 0.26 2500 DirtySandstone 4158.96 4 0.61 2554.83 1435651.3 0.26 1500 CleanSandstone 4162.96 2.1 0.59 2460.93 935658.3 0.26 2500 Siltstone 4165.06 4 0.62 2591.91 1491142.7 0.26 1500 Shale 4169.06 2 0.66 2739.73 2789765.8 0.25 2500 DirtySandstone 4171.06 11 0.62 2576.94 1462838 0.26 1500 Shale 4182.06 27 0.65 2735.51 2560999.9 0.25 2500 Siltstone 4209.06 2 0.63 2669.18 1857874.8 0.26 1500 Shale 4211.06 10 0.66 2765.74 2552268.6 0.25 2500 Siltstone 4221.06 2 0.63 2647.23 1509543.6 0.26 1500 Shale 4223.06 4.1 0.64 2704.07 2349461.1 0.25 2500 Attachment K- NDB-027 Page 21 of 113 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 4227.16 2 0.64 2689.11 1482677.8 0.25 1500 Shale 4229.16 96.4 0.65 2793.12 2604074 0.25 2500 DirtySandstone 4325.56 2 0.61 2639.2 1153391 0.26 1500 Shale 4327.56 38.2 0.66 2847.06 2733692 0.25 2500 Siltstone 4365.76 2 0.62 2711.76 1526263.4 0.26 1500 Shale 4367.76 46.2 0.66 2876.01 2704369.9 0.25 2500 Siltstone 4413.96 2 0.64 2803.5 1825853.3 0.25 1500 Shale 4415.96 14.04 0.65 2888.21 2657615 0.25 2500 Attachment K- NDB-027 Page 22 of 113 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 6636.3 165.02 CarboLite 16/20- SG 1 6636.3 4.13 3 2 PPA 40 YF126ST 6945 180.03 CarboLite 16/20- SG 2 13890 4.5 4 3 PPA 40 YF126ST 7230.2 195.07 CarboLite 16/20- SG 3 21690.6 4.88 5 4 PPA 40 YF126ST 6958.4 195.09 CarboLite 16/20- SG 4 27833.6 4.88 6 5 PPA 40 YF126ST 6706.3 195.11 CarboLite 16/20- SG 5 33531.5 4.88 7 6 PPA 40 YF126ST 6471.8 195.12 CarboLite 16/20- SG 6 38830.8 4.88 8 7 PPA 40 YF126ST 5932.5 185.13 CarboLite 16/20- SG 7 41527.5 4.63 9 8 PPA 40 YF126ST 5273.3 170.13 CarboLite 16/20- SG 8 42186.4 4.25 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.6 23.31 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 71053.8 226126.7 1930.7 48.27 Attachment K- NDB-027 Page 23 of 113 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 3 MD: [25744, 25750] 7494.5 343.83 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 3996.92 4340.75 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 3 MD: [25744, 25750] 903.24 292.18 0.3 Attachment K- NDB-027 Page 24 of 113 Stage 4 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 4 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 6000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 7358.1 psi 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 4000 36.02 0.7 2812.61 2786554.2 0.25 2500 Shale 4036.02 26.74 0.66 2660.45 2786554.2 0.25 2500 Top 3.2 NAN CS 4062.76 3.6 0.6 2459.06 1159218.9 0.26 600 Siltstone 4066.36 1.8 0.62 2509.5 1629236.3 0.26 1500 CleanSandstone 4068.16 1.8 0.6 2445.51 979798.8 0.26 600 Siltstone 4069.96 3.6 0.61 2467.49 1350455.1 0.26 1500 CleanSandstone 4073.56 3.6 0.61 2485.97 1206390.9 0.26 600 Attachment K- NDB-027 Page 25 of 113 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 4077.16 3.6 0.61 2475.93 1313860.7 0.26 1500 CleanSandstone 4080.76 7.2 0.61 2479.21 1266403.2 0.26 600 Siltstone 4087.96 1.8 0.61 2477.85 1082935.6 0.26 1500 DirtySandstone 4089.76 1.8 0.62 2548.48 1222900.8 0.26 600 Shale 4091.56 1.8 0.62 2553.7 1419038.4 0.26 2500 DirtySandstone 4093.36 1.8 0.62 2517.97 1403385.6 0.26 600 Siltstone 4095.16 9 0.62 2533.59 1402756.3 0.26 1500 Shale 4104.16 3.6 0.66 2689.4 2181052.3 0.25 2500 DirtySandstone 4107.76 5.4 0.62 2552.6 1662780.4 0.26 1500 Siltstone 4113.16 1.8 0.63 2583.63 1963674.5 0.26 2500 DirtySandstone 4114.96 3.7 0.62 2560.66 1742901.7 0.26 1500 Siltstone 4118.66 5.4 0.63 2596.46 1681056.2 0.26 2500 Siltstone 4124.06 1.8 0.62 2565.73 1561073 0.26 1500 DirtySandstone 4125.86 1.8 0.62 2550.34 1262913.1 0.26 2500 Siltstone 4127.66 3.6 0.63 2609.82 1816969.7 0.26 1500 Shale 4131.26 11 0.65 2672.35 2238744.4 0.25 2500 Attachment K- NDB-027 Page 26 of 113 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) CleanSandstone 4142.26 2 0.61 2514.96 1001510.6 0.26 600 Siltstone 4144.26 4 0.62 2570.68 1571504.2 0.26 1500 CleanSandstone 4148.26 2 0.6 2510.3 1267177.7 0.26 600 Shale 4150.26 2 0.66 2727.38 2789765.8 0.25 2500 Siltstone 4152.26 2 0.62 2562.56 1409418.9 0.26 1500 Shale 4154.26 2.1 0.66 2730.04 2789765.8 0.25 2500 DirtySandstone 4156.36 4 0.61 2536.6 1435306.6 0.26 1500 Siltstone 4160.36 4 0.62 2588.99 1765617.4 0.26 2500 DirtySandstone 4164.36 4 0.61 2558.15 1435651.3 0.26 1500 CleanSandstone 4168.36 2.1 0.59 2464.12 935658.3 0.26 2500 Siltstone 4170.46 4 0.62 2595.27 1491142.7 0.26 1500 Shale 4174.46 2 0.66 2743.28 2789765.8 0.25 2500 DirtySandstone 4176.46 11 0.62 2580.27 1462838 0.26 1500 Shale 4187.46 27 0.65 2739.03 2560999.9 0.25 2500 Siltstone 4214.46 2 0.63 2672.6 1857874.8 0.26 1500 Shale 4216.46 10 0.66 2769.28 2552268.6 0.25 2500 Attachment K- NDB-027 Page 27 of 113 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 4226.46 2 0.63 2650.62 1509543.6 0.26 1500 Shale 4228.46 4.1 0.64 2707.53 2349461.1 0.25 2500 Siltstone 4232.56 2 0.64 2692.54 1482677.8 0.25 1500 Shale 4234.56 96.4 0.65 2796.64 2604074 0.25 2500 DirtySandstone 4330.96 2 0.61 2642.5 1153391 0.26 1500 Shale 4332.96 38.2 0.66 2850.6 2733692 0.25 2500 Siltstone 4371.16 2 0.62 2715.11 1526263.4 0.26 1500 Shale 4373.16 46.2 0.66 2879.55 2704369.9 0.25 2500 Siltstone 4419.36 2 0.64 2806.93 1825853.3 0.25 1500 Shale 4421.36 9.84 0.65 2890.36 2657615 0.25 2500 Attachment K- NDB-027 Page 28 of 113 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 18900 450 11.25 2 1 PPA 40 YF126ST 6636.3 165.02 CarboLite 16/20- SG 1 6636.3 4.13 3 2 PPA 40 YF126ST 6945 180.03 CarboLite 16/20- SG 2 13890 4.5 4 3 PPA 40 YF126ST 7230.2 195.07 CarboLite 16/20- SG 3 21690.6 4.88 5 4 PPA 40 YF126ST 6958.4 195.09 CarboLite 16/20- SG 4 27833.6 4.88 6 5 PPA 40 YF126ST 6706.3 195.11 CarboLite 16/20- SG 5 33531.5 4.88 7 6 PPA 40 YF126ST 6471.8 195.12 CarboLite 16/20- SG 6 38830.8 4.88 8 7 PPA 40 YF126ST 5932.5 185.13 CarboLite 16/20- SG 7 41527.5 4.63 9 8 PPA 40 YF126ST 5273.3 170.13 CarboLite 16/20- SG 8 42186.4 4.25 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.6 23.31 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 71053.8 226126.7 1930.7 48.27 Attachment K- NDB-027 Page 29 of 113 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 4 MD: [25201, 25207] 7358.1 352.57 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4001.3 4353.87 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 4 MD: [25201, 25207] 937.04 269.96 0.34 Attachment K- NDB-027 Page 30 of 113 Stage 5 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 5 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 6000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 7783.9 psi 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 4000 39.62 0.7 2813.87 2786554.2 0.25 2500 Shale 4039.62 26.74 0.66 2662.81 2786554.2 0.25 2500 Top 3.2 NAN CS 4066.36 3.6 0.6 2461.24 1159218.9 0.26 600 Siltstone 4069.96 1.8 0.62 2511.72 1629236.3 0.26 1500 CleanSandstone 4071.76 1.8 0.6 2447.67 979798.8 0.26 600 Siltstone 4073.56 3.6 0.61 2469.67 1350455.1 0.26 1500 CleanSandstone 4077.16 3.6 0.61 2488.17 1206390.9 0.26 600 Attachment K- NDB-027 Page 31 of 113 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 4080.76 3.6 0.61 2478.11 1313860.7 0.26 1500 CleanSandstone 4084.36 7.2 0.61 2481.39 1266403.2 0.26 600 Siltstone 4091.56 1.8 0.61 2480.03 1082935.6 0.26 1500 DirtySandstone 4093.36 1.8 0.62 2550.72 1222900.8 0.26 600 Shale 4095.16 1.8 0.62 2555.94 1419038.4 0.26 2500 DirtySandstone 4096.96 1.8 0.62 2520.18 1403385.6 0.26 600 Siltstone 4098.76 9 0.62 2535.81 1402756.3 0.26 1500 Shale 4107.76 3.6 0.66 2691.76 2181052.3 0.25 2500 DirtySandstone 4111.36 5.4 0.62 2554.83 1662780.4 0.26 1500 Siltstone 4116.76 1.8 0.63 2585.89 1963674.5 0.26 2500 DirtySandstone 4118.56 3.7 0.62 2562.9 1742901.7 0.26 1500 Siltstone 4122.26 5.4 0.63 2598.72 1681056.2 0.26 2500 Siltstone 4127.66 1.8 0.62 2567.96 1561073 0.26 1500 DirtySandstone 4129.46 1.8 0.62 2552.56 1262913.1 0.26 2500 Siltstone 4131.26 3.6 0.63 2612.09 1816969.7 0.26 1500 Shale 4134.86 11 0.65 2674.67 2238744.4 0.25 2500 Attachment K- NDB-027 Page 32 of 113 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) CleanSandstone 4145.86 2 0.61 2517.14 1001510.6 0.26 600 Siltstone 4147.86 4 0.62 2572.91 1571504.2 0.26 1500 CleanSandstone 4151.86 2 0.6 2512.48 1267177.7 0.26 600 Shale 4153.86 2 0.66 2729.74 2789765.8 0.25 2500 Siltstone 4155.86 2 0.62 2564.78 1409418.9 0.26 1500 Shale 4157.86 2.1 0.66 2732.4 2789765.8 0.25 2500 DirtySandstone 4159.96 4 0.61 2538.8 1435306.6 0.26 1500 Siltstone 4163.96 4 0.62 2591.23 1765617.4 0.26 2500 DirtySandstone 4167.96 4 0.61 2560.36 1435651.3 0.26 1500 CleanSandstone 4171.96 2.1 0.59 2466.25 935658.3 0.26 2500 Siltstone 4174.06 4 0.62 2597.51 1491142.7 0.26 1500 Shale 4178.06 2 0.66 2745.64 2789765.8 0.25 2500 DirtySandstone 4180.06 11 0.62 2582.49 1462838 0.26 1500 Shale 4191.06 27 0.65 2741.37 2560999.9 0.25 2500 Siltstone 4218.06 2 0.63 2674.88 1857874.8 0.26 1500 Shale 4220.06 10 0.66 2771.64 2552268.6 0.25 2500 Attachment K- NDB-027 Page 33 of 113 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 4230.06 2 0.63 2652.87 1509543.6 0.26 1500 Shale 4232.06 4.1 0.64 2709.83 2349461.1 0.25 2500 Siltstone 4236.16 2 0.64 2694.83 1482677.8 0.25 1500 Shale 4238.16 96.4 0.65 2798.99 2604074 0.25 2500 DirtySandstone 4334.56 2 0.61 2644.69 1153391 0.26 1500 Shale 4336.56 38.2 0.66 2852.96 2733692 0.25 2500 Siltstone 4374.76 2 0.62 2717.35 1526263.4 0.26 1500 Shale 4376.76 46.2 0.66 2881.91 2704369.9 0.25 2500 Siltstone 4422.96 2 0.64 2809.21 1825853.3 0.25 1500 Shale 4424.96 9.84 0.65 2892.71 2657615 0.25 2500 Attachment K- NDB-027 Page 34 of 113 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 15960 380 9.5 2 1 PPA Scour 40 YF126ST 2414.7 60 CarboLite 40/70 1 2414.7 1.5 3 3 PPA Scour 40 YF126ST 4457.5 120 CarboLite 40/70 3 13372.5 3 4 Resume PAD 40 YF126ST 2100 50 1.25 5 1 PPA 40 YF126ST 8043 200 CarboLite 16/20- SG 1 8043 5 6 2 PPA 40 YF126ST 8679.6 225 CarboLite 16/20- SG 2 17359.2 5.63 7 4 PPA 40 YF126ST 9808.7 275 CarboLite 16/20- SG 4 39234.8 6.87 8 6 PPA 40 YF126ST 8623.7 260 CarboLite 16/20- SG 6 51742.2 6.5 9 8 PPA 40 YF126ST 7438.8 240 CarboLite 16/20- SG 8 59510.4 6 10 10 PPA 40 YF126ST 5818 200 CarboLite 16/20- SG 10 58180 5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 33.99 29.53 Attachment K- NDB-027 Page 35 of 113 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 73344 249856.8 2010 50.25 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 5 MD: [24659, 24665] 7783.9 psi 355.26 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4005.03 4360.29 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 5 MD: [24659, 24665] 997.39 276.77 0.37 Attachment K- NDB-027 Page 36 of 113 Stage 6 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 6 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 7618.8 psi 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 4010 33.62 0.7 2818.77 2786554.2 0.25 2500 Shale 4043.62 26.74 0.66 2665.44 2786554.2 0.25 2500 Top 3.2 NAN CS 4070.36 3.6 0.6 2463.66 1159218.9 0.26 600 Siltstone 4073.96 1.8 0.62 2514.19 1629236.3 0.26 1500 CleanSandstone 4075.76 1.8 0.6 2450.07 979798.8 0.26 600 Siltstone 4077.56 3.6 0.61 2472.09 1350455.1 0.26 1500 CleanSandstone 4081.16 3.6 0.61 2490.61 1206390.9 0.26 600 Attachment K- NDB-027 Page 37 of 113 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 4084.76 3.6 0.61 2480.54 1313860.7 0.26 1500 CleanSandstone 4088.36 7.2 0.61 2483.82 1266403.2 0.26 600 Siltstone 4095.56 1.8 0.61 2482.45 1082935.6 0.26 1500 DirtySandstone 4097.36 1.8 0.62 2553.22 1222900.8 0.26 600 Shale 4099.16 1.8 0.62 2558.44 1419038.4 0.26 2500 DirtySandstone 4100.96 1.8 0.62 2522.64 1403385.6 0.26 600 Siltstone 4102.76 9 0.62 2538.29 1402756.3 0.26 1500 Shale 4111.76 3.6 0.66 2694.38 2181052.3 0.25 2500 DirtySandstone 4115.36 5.4 0.62 2557.32 1662780.4 0.26 1500 Siltstone 4120.76 1.8 0.63 2588.4 1963674.5 0.26 2500 DirtySandstone 4122.56 3.7 0.62 2565.38 1742901.7 0.26 1500 Siltstone 4126.26 5.4 0.63 2601.24 1681056.2 0.26 2500 Siltstone 4131.66 1.8 0.62 2570.45 1561073 0.26 1500 DirtySandstone 4133.46 1.8 0.62 2555.03 1262913.1 0.26 2500 Siltstone 4135.26 3.6 0.63 2614.62 1816969.7 0.26 1500 Shale 4138.86 11 0.65 2677.26 2238744.4 0.25 2500 Attachment K- NDB-027 Page 38 of 113 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) CleanSandstone 4149.86 2 0.61 2519.57 1001510.6 0.26 600 Siltstone 4151.86 4 0.62 2575.39 1571504.2 0.26 1500 CleanSandstone 4155.86 2 0.6 2514.9 1267177.7 0.26 600 Shale 4157.86 2 0.66 2732.37 2789765.8 0.25 2500 Siltstone 4159.86 2 0.62 2567.25 1409418.9 0.26 1500 Shale 4161.86 2.1 0.66 2735.03 2789765.8 0.25 2500 DirtySandstone 4163.96 4 0.61 2541.24 1435306.6 0.26 1500 Siltstone 4167.96 4 0.62 2593.72 1765617.4 0.26 2500 DirtySandstone 4171.96 4 0.61 2562.81 1435651.3 0.26 1500 CleanSandstone 4175.96 2.1 0.59 2468.61 935658.3 0.26 2500 Siltstone 4178.06 4 0.62 2600 1491142.7 0.26 1500 Shale 4182.06 2 0.66 2748.27 2789765.8 0.25 2500 DirtySandstone 4184.06 11 0.62 2584.96 1462838 0.26 1500 Shale 4195.06 27 0.65 2743.98 2560999.9 0.25 2500 Siltstone 4222.06 2 0.63 2677.42 1857874.8 0.26 1500 Shale 4224.06 10 0.66 2774.26 2552268.6 0.25 2500 Attachment K- NDB-027 Page 39 of 113 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 4234.06 2 0.63 2655.38 1509543.6 0.26 1500 Shale 4236.06 4.1 0.64 2712.39 2349461.1 0.25 2500 Siltstone 4240.16 2 0.64 2697.38 1482677.8 0.25 1500 Shale 4242.16 96.4 0.65 2801.61 2604074 0.25 2500 DirtySandstone 4338.56 2 0.61 2647.13 1153391 0.26 1500 Shale 4340.56 38.2 0.66 2855.58 2733692 0.25 2500 Siltstone 4378.76 2 0.62 2719.83 1526263.4 0.26 1500 Shale 4380.76 46.2 0.66 2884.53 2704369.9 0.25 2500 Siltstone 4426.96 2 0.64 2811.75 1825853.3 0.25 1500 Shale 4428.96 9.84 0.65 2895.32 2657615 0.25 2500 Attachment K- NDB-027 Page 40 of 113 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 15750 375 9.38 2 1 PPA Scour 40 YF126ST 2414.7 60 CarboLite 40/70 1 2414.7 1.5 3 3 PPA Scour 40 YF126ST 4457.5 120 CarboLite 40/70 3 13372.5 3 4 Resume PAD 40 YF126ST 2100 50 1.25 5 1 PPA 40 YF126ST 8043 200 CarboLite 16/20- SG 1 8043 5 6 2 PPA 40 YF126ST 8679.6 225 CarboLite 16/20- SG 2 17359.2 5.63 7 4 PPA 40 YF126ST 9808.7 275 CarboLite 16/20- SG 4 39234.8 6.87 8 6 PPA 40 YF126ST 8623.7 260 CarboLite 16/20- SG 6 51742.2 6.5 9 8 PPA 40 YF126ST 7438.8 240 CarboLite 16/20- SG 8 59510.4 6 10 10 PPA 40 YF126ST 5818 200 CarboLite 16/20- SG 10 58180 5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 33.8 29.36 Attachment K- NDB-027 Page 41 of 113 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 73134 249856.8 2005 50.12 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 6 MD: [24118, 24124] 7618.8 psi 354.56 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4008.82 4363.38 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 6 MD: [24118, 24124] 997.79 290.7 0.36 Attachment K- NDB-027 Page 42 of 113 Stage 7 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 7 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 7487.8 psi 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 4010 35.72 0.7 2819.5 2786554.2 0.25 2500 Shale 4045.72 26.74 0.66 2666.82 2786554.2 0.25 2500 Top 3.2 NAN CS 4072.46 3.6 0.6 2464.93 1159218.9 0.26 600 Siltstone 4076.06 1.8 0.62 2515.48 1629236.3 0.26 1500 CleanSandstone 4077.86 1.8 0.6 2451.33 979798.8 0.26 600 Siltstone 4079.66 3.6 0.61 2473.36 1350455.1 0.26 1500 CleanSandstone 4083.26 3.6 0.61 2491.89 1206390.9 0.26 600 Siltstone 4086.86 3.6 0.61 2481.82 1313860.7 0.26 1500 CleanSandstone 4090.46 7.2 0.61 2485.09 1266403.2 0.26 600 Attachment K- NDB-027 Page 43 of 113 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 4097.66 1.8 0.61 2483.73 1082935.6 0.26 1500 DirtySandstone 4099.46 1.8 0.62 2554.52 1222900.8 0.26 600 Shale 4101.26 1.8 0.62 2559.75 1419038.4 0.26 2500 DirtySandstone 4103.06 1.8 0.62 2523.94 1403385.6 0.26 600 Siltstone 4104.86 9 0.62 2539.58 1402756.3 0.26 1500 Shale 4113.86 3.6 0.66 2695.76 2181052.3 0.25 2500 DirtySandstone 4117.46 5.4 0.62 2558.62 1662780.4 0.26 1500 Siltstone 4122.86 1.8 0.63 2589.72 1963674.5 0.26 2500 DirtySandstone 4124.66 3.7 0.62 2566.69 1742901.7 0.26 1500 Siltstone 4128.36 5.4 0.63 2602.57 1681056.2 0.26 2500 Siltstone 4133.76 1.8 0.62 2571.76 1561073 0.26 1500 DirtySandstone 4135.56 1.8 0.62 2556.33 1262913.1 0.26 2500 Siltstone 4137.36 3.6 0.63 2615.95 1816969.7 0.26 1500 Shale 4140.96 11 0.65 2678.61 2238744.4 0.25 2500 CleanSandstone 4151.96 2 0.61 2520.85 1001510.6 0.26 600 Siltstone 4153.96 4 0.62 2576.7 1571504.2 0.26 1500 Attachment K- NDB-027 Page 44 of 113 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) CleanSandstone 4157.96 2 0.6 2516.17 1267177.7 0.26 600 Shale 4159.96 2 0.66 2733.75 2789765.8 0.25 2500 Siltstone 4161.96 2 0.62 2568.55 1409418.9 0.26 1500 Shale 4163.96 2.1 0.66 2736.41 2789765.8 0.25 2500 DirtySandstone 4166.06 4 0.61 2542.52 1435306.6 0.26 1500 Siltstone 4170.06 4 0.62 2595.02 1765617.4 0.26 2500 DirtySandstone 4174.06 4 0.61 2564.1 1435651.3 0.26 1500 CleanSandstone 4178.06 2.1 0.59 2469.85 935658.3 0.26 2500 Siltstone 4180.16 4 0.62 2601.3 1491142.7 0.26 1500 Shale 4184.16 2 0.66 2749.65 2789765.8 0.25 2500 DirtySandstone 4186.16 11 0.62 2586.25 1462838 0.26 1500 Shale 4197.16 27 0.65 2745.35 2560999.9 0.25 2500 Siltstone 4224.16 2 0.63 2678.75 1857874.8 0.26 1500 Shale 4226.16 10 0.66 2775.64 2552268.6 0.25 2500 Siltstone 4236.16 2 0.63 2656.7 1509543.6 0.26 1500 Shale 4238.16 4.1 0.64 2713.73 2349461.1 0.25 2500 Attachment K- NDB-027 Page 45 of 113 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 4242.26 2 0.64 2698.71 1482677.8 0.25 1500 Shale 4244.26 96.4 0.65 2802.98 2604074 0.25 2500 DirtySandstone 4340.66 2 0.61 2648.41 1153391 0.26 1500 Shale 4342.66 38.2 0.66 2856.95 2733692 0.25 2500 Siltstone 4380.86 2 0.62 2721.14 1526263.4 0.26 1500 Shale 4382.86 46.2 0.66 2885.9 2704369.9 0.25 2500 Siltstone 4429.06 2 0.64 2813.09 1825853.3 0.25 1500 Shale 4431.06 9.84 0.65 2896.69 2657615 0.25 2500 Attachment K- NDB-027 Page 46 of 113 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 15330 365 9.12 2 1 PPA Scour 40 YF126ST 2414.7 60 CarboLite 40/70 1 2414.7 1.5 3 3 PPA Scour 40 YF126ST 4457.5 120 CarboLite 40/70 3 13372.5 3 4 Resume PAD 40 YF126ST 2100 50 1.25 5 1 PPA 40 YF126ST 8043 200 CarboLite 16/20- SG 1 8043 5 6 2 PPA 40 YF126ST 8679.6 225 CarboLite 16/20- SG 2 17359.2 5.63 7 4 PPA 40 YF126ST 9808.7 275 CarboLite 16/20- SG 4 39234.8 6.87 8 6 PPA 40 YF126ST 8623.7 260 CarboLite 16/20- SG 6 51742.2 6.5 9 8 PPA 40 YF126ST 7438.8 240 CarboLite 16/20- SG 8 59510.4 6 10 10 PPA 40 YF126ST 5818 200 CarboLite 16/20- SG 10 58180 5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 33.42 29 Attachment K- NDB-027 Page 47 of 113 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 72714 249856.8 1995 49.87 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 7 MD: [23575, 23581] 7487.8 psi 354 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 7 MD: [23575, 23581] 996.68 287.4 0.35 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4010.2 4364.2 Attachment K- NDB-027 Page 48 of 113 Stage 8 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 8 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 7319.5 psi 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 4020 27.92 0.7 2823.77 2786554.2 0.25 2500 Shale 4047.92 26.74 0.66 2668.27 2786554.2 0.25 2500 Top 3.2 NAN CS 4074.66 3.6 0.6 2466.26 1159218.9 0.26 600 Siltstone 4078.26 1.8 0.62 2516.84 1629236.3 0.26 1500 CleanSandstone 4080.06 1.8 0.6 2452.66 979798.8 0.26 600 Siltstone 4081.86 3.6 0.61 2474.7 1350455.1 0.26 1500 CleanSandstone 4085.46 3.6 0.61 2493.23 1206390.9 0.26 600 Siltstone 4089.06 3.6 0.61 2483.15 1313860.7 0.26 1500 CleanSandstone 4092.66 7.2 0.61 2486.43 1266403.2 0.26 600 Attachment K- NDB-027 Page 49 of 113 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 4099.86 1.8 0.61 2485.06 1082935.6 0.26 1500 DirtySandstone 4101.66 1.8 0.62 2555.89 1222900.8 0.26 600 Shale 4103.46 1.8 0.62 2561.12 1419038.4 0.26 2500 DirtySandstone 4105.26 1.8 0.62 2525.29 1403385.6 0.26 600 Siltstone 4107.06 9 0.62 2540.94 1402756.3 0.26 1500 Shale 4116.06 3.6 0.66 2697.2 2181052.3 0.25 2500 DirtySandstone 4119.66 5.4 0.62 2559.99 1662780.4 0.26 1500 Siltstone 4125.06 1.8 0.63 2591.1 1963674.5 0.26 2500 DirtySandstone 4126.86 3.7 0.62 2568.06 1742901.7 0.26 1500 Siltstone 4130.56 5.4 0.63 2603.95 1681056.2 0.26 2500 Siltstone 4135.96 1.8 0.62 2573.13 1561073 0.26 1500 DirtySandstone 4137.76 1.8 0.62 2557.69 1262913.1 0.26 2500 Siltstone 4139.56 3.6 0.63 2617.34 1816969.7 0.26 1500 Shale 4143.16 11 0.65 2680.03 2238744.4 0.25 2500 CleanSandstone 4154.16 2 0.61 2522.18 1001510.6 0.26 600 Siltstone 4156.16 4 0.62 2578.06 1571504.2 0.26 1500 Attachment K- NDB-027 Page 50 of 113 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) CleanSandstone 4160.16 2 0.6 2517.5 1267177.7 0.26 600 Shale 4162.16 2 0.66 2735.2 2789765.8 0.25 2500 Siltstone 4164.16 2 0.62 2569.9 1409418.9 0.26 1500 Shale 4166.16 2.1 0.66 2737.86 2789765.8 0.25 2500 DirtySandstone 4168.26 4 0.61 2543.86 1435306.6 0.26 1500 Siltstone 4172.26 4 0.62 2596.39 1765617.4 0.26 2500 DirtySandstone 4176.26 4 0.61 2565.45 1435651.3 0.26 1500 CleanSandstone 4180.26 2.1 0.59 2471.15 935658.3 0.26 2500 Siltstone 4182.36 4 0.62 2602.67 1491142.7 0.26 1500 Shale 4186.36 2 0.66 2751.1 2789765.8 0.25 2500 DirtySandstone 4188.36 11 0.62 2587.61 1462838 0.26 1500 Shale 4199.36 27 0.65 2746.78 2560999.9 0.25 2500 Siltstone 4226.36 2 0.63 2680.15 1857874.8 0.26 1500 Shale 4228.36 10 0.66 2777.08 2552268.6 0.25 2500 Siltstone 4238.36 2 0.63 2658.08 1509543.6 0.26 1500 Shale 4240.36 4.1 0.64 2715.14 2349461.1 0.25 2500 Attachment K- NDB-027 Page 51 of 113 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 4244.46 2 0.64 2700.11 1482677.8 0.25 1500 Shale 4246.46 96.4 0.65 2804.41 2604074 0.25 2500 DirtySandstone 4342.86 2 0.61 2649.75 1153391 0.26 1500 Shale 4344.86 38.2 0.66 2858.39 2733692 0.25 2500 Siltstone 4383.06 2 0.62 2722.5 1526263.4 0.26 1500 Shale 4385.06 46.2 0.66 2887.34 2704369.9 0.25 2500 Siltstone 4431.26 2 0.64 2814.49 1825853.3 0.25 1500 Shale 4433.26 9.84 0.65 2898.13 2657615 0.25 2500 Attachment K- NDB-027 Page 52 of 113 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 15120 360 9 2 1 PPA Scour 40 YF126ST 1610 40 CarboLite 40/70 1 1610 1 3 3 PPA Scour 40 YF126ST 2971.6 80 CarboLite 40/70 3 8914.8 2 4 Resume PAD 40 YF126ST 2100 50 1.25 5 1 PPA 40 YF126ST 8043 200 CarboLite 16/20- SG 1 8043 5 6 2 PPA 40 YF126ST 8679.6 225 CarboLite 16/20- SG 2 17359.2 5.63 7 4 PPA 40 YF126ST 9808.7 275 CarboLite 16/20- SG 4 39234.8 6.87 8 6 PPA 40 YF126ST 8623.7 260 CarboLite 16/20- SG 6 51742.2 6.5 9 8 PPA 40 YF126ST 7438.8 240 CarboLite 16/20- SG 8 59510.4 6 10 10 PPA 40 YF126ST 5818 200 CarboLite 16/20- SG 10 58180 5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 31.05 26.9 Attachment K- NDB-027 Page 53 of 113 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 70213.4 244594.4 1930 48.25 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 8 MD: [23032, 23038] 7319.5 349.88 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4013.79 4363.67 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 8 MD: [23032, 23038] 978.39 281.77 0.37 ` Attachment K- NDB-027 Page 54 of 113 Stage 9 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 9 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 6000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 7144.5 psi 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 4020 28.92 0.7 2824.12 2786554.2 0.25 2500 Shale 4048.92 26.74 0.66 2668.92 2786554.2 0.25 2500 Top 3.2 NAN CS 4075.66 3.6 0.6 2466.86 1159218.9 0.26 600 Siltstone 4079.26 1.8 0.62 2517.46 1629236.3 0.26 1500 CleanSandstone 4081.06 1.8 0.6 2453.26 979798.8 0.26 600 Siltstone 4082.86 3.6 0.61 2475.3 1350455.1 0.26 1500 CleanSandstone 4086.46 3.6 0.61 2493.84 1206390.9 0.26 600 Siltstone 4090.06 3.6 0.61 2483.76 1313860.7 0.26 1500 CleanSandstone 4093.66 7.2 0.61 2487.04 1266403.2 0.26 600 Attachment K- NDB-027 Page 55 of 113 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 4100.86 1.8 0.61 2485.67 1082935.6 0.26 1500 DirtySandstone 4102.66 1.8 0.62 2556.52 1222900.8 0.26 600 Shale 4104.46 1.8 0.62 2561.74 1419038.4 0.26 2500 DirtySandstone 4106.26 1.8 0.62 2525.9 1403385.6 0.26 600 Siltstone 4108.06 9 0.62 2541.56 1402756.3 0.26 1500 Shale 4117.06 3.6 0.66 2697.85 2181052.3 0.25 2500 DirtySandstone 4120.66 5.4 0.62 2560.61 1662780.4 0.26 1500 Siltstone 4126.06 1.8 0.63 2591.73 1963674.5 0.26 2500 DirtySandstone 4127.86 3.7 0.62 2568.68 1742901.7 0.26 1500 Siltstone 4131.56 5.4 0.63 2604.58 1681056.2 0.26 2500 Siltstone 4136.96 1.8 0.62 2573.75 1561073 0.26 1500 DirtySandstone 4138.76 1.8 0.62 2558.31 1262913.1 0.26 2500 Siltstone 4140.56 3.6 0.63 2617.97 1816969.7 0.26 1500 Shale 4144.16 11 0.65 2680.68 2238744.4 0.25 2500 CleanSandstone 4155.16 2 0.61 2522.79 1001510.6 0.26 600 Siltstone 4157.16 4 0.62 2578.68 1571504.2 0.26 1500 Attachment K- NDB-027 Page 56 of 113 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) CleanSandstone 4161.16 2 0.6 2518.11 1267177.7 0.26 600 Shale 4163.16 2 0.66 2735.85 2789765.8 0.25 2500 Siltstone 4165.16 2 0.62 2570.52 1409418.9 0.26 1500 Shale 4167.16 2.1 0.66 2738.51 2789765.8 0.25 2500 DirtySandstone 4169.26 4 0.61 2544.47 1435306.6 0.26 1500 Siltstone 4173.26 4 0.62 2597.01 1765617.4 0.26 2500 DirtySandstone 4177.26 4 0.61 2566.07 1435651.3 0.26 1500 CleanSandstone 4181.26 2.1 0.59 2471.75 935658.3 0.26 2500 Siltstone 4183.36 4 0.62 2603.29 1491142.7 0.26 1500 Shale 4187.36 2 0.66 2751.75 2789765.8 0.25 2500 DirtySandstone 4189.36 11 0.62 2588.23 1462838 0.26 1500 Shale 4200.36 27 0.65 2747.44 2560999.9 0.25 2500 Siltstone 4227.36 2 0.63 2680.78 1857874.8 0.26 1500 Shale 4229.36 10 0.66 2777.74 2552268.6 0.25 2500 Siltstone 4239.36 2 0.63 2658.71 1509543.6 0.26 1500 Shale 4241.36 4.1 0.64 2715.78 2349461.1 0.25 2500 Attachment K- NDB-027 Page 57 of 113 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 4245.46 2 0.64 2700.75 1482677.8 0.25 1500 Shale 4247.46 96.4 0.65 2805.07 2604074 0.25 2500 DirtySandstone 4343.86 2 0.61 2650.36 1153391 0.26 1500 Shale 4345.86 38.2 0.66 2859.05 2733692 0.25 2500 Siltstone 4384.06 2 0.62 2723.12 1526263.4 0.26 1500 Shale 4386.06 46.2 0.66 2888 2704369.9 0.25 2500 Siltstone 4432.26 2 0.64 2815.12 1825853.3 0.25 1500 Shale 4434.26 9.84 0.65 2898.78 2657615 0.25 2500 Attachment K- NDB-027 Page 58 of 113 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 14700 350 8.75 2 1 PPA Scour 40 YF126ST 1610 40 CarboLite 40/70 1 1610 1 3 3 PPA Scour 40 YF126ST 2971.6 80 CarboLite 40/70 3 8914.8 2 4 Resume PAD 40 YF126ST 2100 50 1.25 5 1 PPA 40 YF126ST 8043 200 CarboLite 16/20- SG 1 8043 5 6 2 PPA 40 YF126ST 8679.6 225 CarboLite 16/20- SG 2 17359.2 5.63 7 4 PPA 40 YF126ST 9808.7 275 CarboLite 16/20- SG 4 39234.8 6.87 8 6 PPA 40 YF126ST 8623.7 260 CarboLite 16/20- SG 6 51742.2 6.5 9 8 PPA 40 YF126ST 7438.8 240 CarboLite 16/20- SG 8 59510.4 6 10 10 PPA 40 YF126ST 5818 200 CarboLite 16/20- SG 10 58180 5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 30.64 26.51 Attachment K- NDB-027 Page 59 of 113 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 69793.4 244594.4 1920 48 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 9 MD: [22486, 22492] 7144.5 psi 349.76 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4014.81 4364.57 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 9 MD: [22486, 22492] 933.42 280.46 0.38 Attachment K- NDB-027 Page 60 of 113 Stage 10 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 10 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 7014 psi 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 4010 42.02 0.7 2821.71 2786554.2 0.25 2500 Shale 4052.02 26.74 0.66 2670.96 2786554.2 0.25 2500 Top 3.2 NAN CS 4078.76 3.6 0.6 2468.74 1159218.9 0.26 600 Siltstone 4082.36 1.8 0.62 2519.37 1629236.3 0.26 1500 CleanSandstone 4084.16 1.8 0.6 2455.12 979798.8 0.26 600 Siltstone 4085.96 3.6 0.61 2477.18 1350455.1 0.26 1500 CleanSandstone 4089.56 3.6 0.61 2495.73 1206390.9 0.26 600 Siltstone 4093.16 3.6 0.61 2485.64 1313860.7 0.26 1500 CleanSandstone 4096.76 7.2 0.61 2488.92 1266403.2 0.26 600 Attachment K- NDB-027 Page 61 of 113 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 4103.96 1.8 0.61 2487.55 1082935.6 0.26 1500 DirtySandstone 4105.76 1.8 0.62 2558.45 1222900.8 0.26 600 Shale 4107.56 1.8 0.62 2563.68 1419038.4 0.26 2500 DirtySandstone 4109.36 1.8 0.62 2527.81 1403385.6 0.26 600 Siltstone 4111.16 9 0.62 2543.48 1402756.3 0.26 1500 Shale 4120.16 3.6 0.66 2699.88 2181052.3 0.25 2500 DirtySandstone 4123.76 5.4 0.62 2562.53 1662780.4 0.26 1500 Siltstone 4129.16 1.8 0.63 2593.68 1963674.5 0.26 2500 DirtySandstone 4130.96 3.7 0.62 2570.61 1742901.7 0.26 1500 Siltstone 4134.66 5.4 0.63 2606.54 1681056.2 0.26 2500 Siltstone 4140.06 1.8 0.62 2575.68 1561073 0.26 1500 DirtySandstone 4141.86 1.8 0.62 2560.23 1262913.1 0.26 2500 Siltstone 4143.66 3.6 0.63 2619.93 1816969.7 0.26 1500 Shale 4147.26 11 0.65 2682.68 2238744.4 0.25 2500 CleanSandstone 4158.26 2 0.61 2524.67 1001510.6 0.26 600 Siltstone 4160.26 4 0.62 2580.6 1571504.2 0.26 1500 Attachment K- NDB-027 Page 62 of 113 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) CleanSandstone 4164.26 2 0.6 2519.98 1267177.7 0.26 600 Shale 4166.26 2 0.66 2737.89 2789765.8 0.25 2500 Siltstone 4168.26 2 0.62 2572.43 1409418.9 0.26 1500 Shale 4170.26 2.1 0.66 2740.55 2789765.8 0.25 2500 DirtySandstone 4172.36 4 0.61 2546.36 1435306.6 0.26 1500 Siltstone 4176.36 4 0.62 2598.94 1765617.4 0.26 2500 DirtySandstone 4180.36 4 0.61 2567.97 1435651.3 0.26 1500 CleanSandstone 4184.36 2.1 0.59 2473.58 935658.3 0.26 2500 Siltstone 4186.46 4 0.62 2605.22 1491142.7 0.26 1500 Shale 4190.46 2 0.66 2753.79 2789765.8 0.25 2500 DirtySandstone 4192.46 11 0.62 2590.14 1462838 0.26 1500 Shale 4203.46 27 0.65 2749.46 2560999.9 0.25 2500 Siltstone 4230.46 2 0.63 2682.75 1857874.8 0.26 1500 Shale 4232.46 10 0.66 2779.77 2552268.6 0.25 2500 Siltstone 4242.46 2 0.63 2660.65 1509543.6 0.26 1500 Shale 4244.46 4.1 0.64 2717.77 2349461.1 0.25 2500 Attachment K- NDB-027 Page 63 of 113 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 4248.56 2 0.64 2702.72 1482677.8 0.25 1500 Shale 4250.56 96.4 0.65 2807.09 2604074 0.25 2500 DirtySandstone 4346.96 2 0.61 2652.26 1153391 0.26 1500 Shale 4348.96 38.2 0.66 2861.08 2733692 0.25 2500 Siltstone 4387.16 2 0.62 2725.05 1526263.4 0.26 1500 Shale 4389.16 46.2 0.66 2890.03 2704369.9 0.25 2500 Siltstone 4435.36 2 0.64 2817.09 1825853.3 0.25 1500 Shale 4437.36 9.84 0.65 2900.81 2657615 0.25 2500 Attachment K- NDB-027 Page 64 of 113 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 14280 340 8.5 2 1 PPA Scour 40 YF126ST 1610 40 CarboLite 40/70 1 1610 1 3 3 PPA Scour 40 YF126ST 2971.6 80 CarboLite 40/70 3 8914.8 2 4 Resume PAD 40 YF126ST 2100 50 1.25 5 1 PPA 40 YF126ST 8043 200 CarboLite 16/20- SG 1 8043 5 6 2 PPA 40 YF126ST 8679.6 225 CarboLite 16/20- SG 2 17359.2 5.63 7 4 PPA 40 YF126ST 9808.7 275 CarboLite 16/20- SG 4 39234.8 6.87 8 6 PPA 40 YF126ST 8623.7 260 CarboLite 16/20- SG 6 51742.2 6.5 9 8 PPA 40 YF126ST 7438.8 240 CarboLite 16/20- SG 8 59510.4 6 10 10 PPA 40 YF126ST 5818 200 CarboLite 16/20- SG 10 58180 5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 30.22 26.13 Attachment K- NDB-027 Page 65 of 113 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 69373.4 244594.4 1910 47.75 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 10 MD: [21944, 21950] 7014 349.7 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4016.99 4366.69 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 10 MD: [21944, 21950] 973.86 289.1 0.37 Attachment K- NDB-027 Page 66 of 113 Stage 11 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 11 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6846.4 psi 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 4020 35.82 0.7 2826.54 2786554.2 0.25 2500 Shale 4055.82 26.74 0.66 2673.46 2786554.2 0.25 2500 Top 3.2 NAN CS 4082.56 3.6 0.6 2471.04 1159218.9 0.26 600 Siltstone 4086.16 1.8 0.62 2521.72 1629236.3 0.26 1500 CleanSandstone 4087.96 1.8 0.6 2457.4 979798.8 0.26 600 Siltstone 4089.76 3.6 0.61 2479.49 1350455.1 0.26 1500 CleanSandstone 4093.36 3.6 0.61 2498.05 1206390.9 0.26 600 Siltstone 4096.96 3.6 0.61 2487.95 1313860.7 0.26 1500 Attachment K- NDB-027 Page 67 of 113 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) CleanSandstone 4100.56 7.2 0.61 2491.23 1266403.2 0.26 600 Siltstone 4107.76 1.8 0.61 2489.85 1082935.6 0.26 1500 DirtySandstone 4109.56 1.8 0.62 2560.82 1222900.8 0.26 600 Shale 4111.36 1.8 0.62 2566.05 1419038.4 0.26 2500 DirtySandstone 4113.16 1.8 0.62 2530.15 1403385.6 0.26 600 Siltstone 4114.96 9 0.62 2545.83 1402756.3 0.26 1500 Shale 4123.96 3.6 0.66 2702.37 2181052.3 0.25 2500 DirtySandstone 4127.56 5.4 0.62 2564.89 1662780.4 0.26 1500 Siltstone 4132.96 1.8 0.63 2596.06 1963674.5 0.26 2500 DirtySandstone 4134.76 3.7 0.62 2572.97 1742901.7 0.26 1500 Siltstone 4138.46 5.4 0.63 2608.93 1681056.2 0.26 2500 Siltstone 4143.86 1.8 0.62 2578.04 1561073 0.26 1500 DirtySandstone 4145.66 1.8 0.62 2562.57 1262913.1 0.26 2500 Siltstone 4147.46 3.6 0.63 2622.33 1816969.7 0.26 1500 Shale 4151.06 11 0.65 2685.14 2238744.4 0.25 2500 CleanSandstone 4162.06 2 0.61 2526.98 1001510.6 0.26 600 Attachment K- NDB-027 Page 68 of 113 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 4164.06 4 0.62 2582.96 1571504.2 0.26 1500 CleanSandstone 4168.06 2 0.6 2522.28 1267177.7 0.26 600 Shale 4170.06 2 0.66 2740.39 2789765.8 0.25 2500 Siltstone 4172.06 2 0.62 2574.78 1409418.9 0.26 1500 Shale 4174.06 2.1 0.66 2743.05 2789765.8 0.25 2500 DirtySandstone 4176.16 4 0.61 2548.68 1435306.6 0.26 1500 Siltstone 4180.16 4 0.62 2601.3 1765617.4 0.26 2500 DirtySandstone 4184.16 4 0.61 2570.3 1435651.3 0.26 1500 CleanSandstone 4188.16 2.1 0.59 2475.82 935658.3 0.26 2500 Siltstone 4190.26 4 0.62 2607.59 1491142.7 0.26 1500 Shale 4194.26 2 0.66 2756.29 2789765.8 0.25 2500 DirtySandstone 4196.26 11 0.62 2592.49 1462838 0.26 1500 Shale 4207.26 27 0.65 2751.94 2560999.9 0.25 2500 Siltstone 4234.26 2 0.63 2685.15 1857874.8 0.26 1500 Shale 4236.26 10 0.66 2782.27 2552268.6 0.25 2500 Siltstone 4246.26 2 0.63 2663.03 1509543.6 0.26 1500 Attachment K- NDB-027 Page 69 of 113 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 4248.26 4.1 0.64 2720.2 2349461.1 0.25 2500 Siltstone 4252.36 2 0.64 2705.14 1482677.8 0.25 1500 Shale 4254.36 96.4 0.65 2809.57 2604074 0.25 2500 DirtySandstone 4350.76 2 0.61 2654.57 1153391 0.26 1500 Shale 4352.76 38.2 0.66 2863.57 2733692 0.25 2500 Siltstone 4390.96 2 0.62 2727.41 1526263.4 0.26 1500 Shale 4392.96 46.2 0.66 2892.52 2704369.9 0.25 2500 Siltstone 4439.16 2 0.64 2819.5 1825853.3 0.25 1500 Shale 4441.16 9.84 0.65 2903.29 2657615 0.25 2500 Attachment K- NDB-027 Page 70 of 113 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 14070 335 8.37 2 1 PPA Scour 40 YF126ST 1610 40 CarboLite 40/70 1 1610 1 3 3 PPA Scour 40 YF126ST 2971.6 80 CarboLite 40/70 3 8914.8 2 4 Resume PAD 40 YF126ST 2100 50 1.25 5 1 PPA 40 YF126ST 8043 200 CarboLite 16/20- SG 1 8043 5 6 2 PPA 40 YF126ST 8679.6 225 CarboLite 16/20- SG 2 17359.2 5.63 7 4 PPA 40 YF126ST 9808.7 275 CarboLite 16/20- SG 4 39234.8 6.87 8 6 PPA 40 YF126ST 8623.7 260 CarboLite 16/20- SG 6 51742.2 6.5 9 8 PPA 40 YF126ST 7438.8 240 CarboLite 16/20- SG 8 59510.4 6 10 10 PPA 40 YF126ST 5818 200 CarboLite 16/20- SG 10 58180 5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 30 25.94 Attachment K- NDB-027 Page 71 of 113 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 69163.4 244594.4 1905 47.63 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 11 MD: [21399, 21405] 6846.4 349.21 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4021.27 4370.48 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 11 MD: [21399, 21405] 971.79 289.96 0.37 Attachment K- NDB-027 Page 72 of 113 Stage 12 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 12 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 6000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6672 psi 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 4020 38.82 0.7 2827.59 2786554.2 0.25 2500 Shale 4058.82 26.74 0.66 2675.43 2786554.2 0.25 2500 Top 3.2 NAN CS 4085.56 3.6 0.6 2472.85 1159218.9 0.26 600 Siltstone 4089.16 1.8 0.62 2523.57 1629236.3 0.26 1500 CleanSandstone 4090.96 1.8 0.6 2459.21 979798.8 0.26 600 Siltstone 4092.76 3.6 0.61 2481.3 1350455.1 0.26 1500 CleanSandstone 4096.36 3.6 0.61 2499.88 1206390.9 0.26 600 Siltstone 4099.96 3.6 0.61 2489.77 1313860.7 0.26 1500 Attachment K- NDB-027 Page 73 of 113 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) CleanSandstone 4103.56 7.2 0.61 2493.05 1266403.2 0.26 600 Siltstone 4110.76 1.8 0.61 2491.67 1082935.6 0.26 1500 DirtySandstone 4112.56 1.8 0.62 2562.69 1222900.8 0.26 600 Shale 4114.36 1.8 0.62 2567.92 1419038.4 0.26 2500 DirtySandstone 4116.16 1.8 0.62 2531.99 1403385.6 0.26 600 Siltstone 4117.96 9 0.62 2547.68 1402756.3 0.26 1500 Shale 4126.96 3.6 0.66 2704.34 2181052.3 0.25 2500 DirtySandstone 4130.56 5.4 0.62 2566.75 1662780.4 0.26 1500 Siltstone 4135.96 1.8 0.63 2597.95 1963674.5 0.26 2500 DirtySandstone 4137.76 3.7 0.62 2574.84 1742901.7 0.26 1500 Siltstone 4141.46 5.4 0.63 2610.82 1681056.2 0.26 2500 Siltstone 4146.86 1.8 0.62 2579.91 1561073 0.26 1500 DirtySandstone 4148.66 1.8 0.62 2564.43 1262913.1 0.26 2500 Siltstone 4150.46 3.6 0.63 2624.23 1816969.7 0.26 1500 Shale 4154.06 11 0.65 2687.08 2238744.4 0.25 2500 CleanSandstone 4165.06 2 0.61 2528.8 1001510.6 0.26 600 Attachment K- NDB-027 Page 74 of 113 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 4167.06 4 0.62 2584.82 1571504.2 0.26 1500 CleanSandstone 4171.06 2 0.6 2524.1 1267177.7 0.26 600 Shale 4173.06 2 0.66 2742.36 2789765.8 0.25 2500 Siltstone 4175.06 2 0.62 2576.63 1409418.9 0.26 1500 Shale 4177.06 2.1 0.66 2745.02 2789765.8 0.25 2500 DirtySandstone 4179.16 4 0.61 2550.51 1435306.6 0.26 1500 Siltstone 4183.16 4 0.62 2603.17 1765617.4 0.26 2500 DirtySandstone 4187.16 4 0.61 2572.14 1435651.3 0.26 1500 CleanSandstone 4191.16 2.1 0.59 2477.6 935658.3 0.26 2500 Siltstone 4193.26 4 0.62 2609.45 1491142.7 0.26 1500 Shale 4197.26 2 0.66 2758.26 2789765.8 0.25 2500 DirtySandstone 4199.26 11 0.62 2594.34 1462838 0.26 1500 Shale 4210.26 27 0.65 2753.89 2560999.9 0.25 2500 Siltstone 4237.26 2 0.63 2687.06 1857874.8 0.26 1500 Shale 4239.26 10 0.66 2784.23 2552268.6 0.25 2500 Siltstone 4249.26 2 0.63 2664.91 1509543.6 0.26 1500 Attachment K- NDB-027 Page 75 of 113 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 4251.26 4.1 0.64 2722.12 2349461.1 0.25 2500 Siltstone 4255.36 2 0.64 2707.04 1482677.8 0.25 1500 Shale 4257.36 96.4 0.65 2811.53 2604074 0.25 2500 DirtySandstone 4353.76 2 0.61 2656.4 1153391 0.26 1500 Shale 4355.76 38.2 0.66 2865.53 2733692 0.25 2500 Siltstone 4393.96 2 0.62 2729.27 1526263.4 0.26 1500 Shale 4395.96 46.2 0.66 2894.48 2704369.9 0.25 2500 Siltstone 4442.16 2 0.64 2821.41 1825853.3 0.25 1500 Shale 4444.16 9.84 0.65 2905.25 2657615 0.25 2500 Attachment K- NDB-027 Page 76 of 113 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 13650 325 8.12 2 1 PPA Scour 40 YF126ST 2414.7 60 CarboLite 40/70 1 2414.7 1.5 3 3 PPA Scour 40 YF126ST 4457.5 120 CarboLite 40/70 3 13372.5 3 4 Resume PAD 40 YF126ST 2100 50 1.25 5 1 PPA 40 YF126ST 8043 200 CarboLite 16/20- SG 1 8043 5 6 2 PPA 40 YF126ST 8679.6 225 CarboLite 16/20- SG 2 17359.2 5.63 7 4 PPA 40 YF126ST 9808.7 275 CarboLite 16/20- SG 4 39234.8 6.87 8 6 PPA 40 YF126ST 8623.7 260 CarboLite 16/20- SG 6 51742.2 6.5 9 8 PPA 40 YF126ST 7438.8 240 CarboLite 16/20- SG 8 59510.4 6 10 10 PPA 40 YF126ST 5818 200 CarboLite 16/20- SG 10 58180 5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 31.85 27.55 Attachment K- NDB-027 Page 77 of 113 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 71034 249856.8 1955 48.87 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 12 MD: [20855, 20861] 6672 352.42 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4023.63 4376.05 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 12 MD: [20855, 20861] 984.29 285.96 0.37 Attachment K- NDB-027 Page 78 of 113 Stage 13 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 13 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6586.7 psi 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 4056.76 10 0.73 2971.97 1461000.3 0.22 2500 Shale 4066.77 15 0.7 2831.57 1762000.5 0.22 2500 Nanushuk 3 SS 4081.76 15.3 0.68 2772.69 1898000.5 0.22 2000 Top Nan 4097.08 6 0.65 2661.15 838900.2 0.27 1000 Shale 4103.08 2 0.7 2891.76 2665000.7 0.23 2500 Nan DS 4105.09 1.5 0.64 2614.6 819400.2 0.27 1500 Nan DS 4106.56 2 0.64 2645.92 1222000.3 0.26 1500 Nan CS 4108.56 13 0.63 2592.26 869100.2 0.27 1000 Attachment K- NDB-027 Page 79 of 113 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 4121.59 1.5 0.61 2526.99 1002000.3 0.27 1000 Nan CS 4123.06 4 0.65 2661.01 706600.2 0.28 1000 Nan CS 4127.07 9 0.61 2507.85 1166000.3 0.27 1000 Nan CS 4136.06 7 0.65 2690.16 769000.2 0.27 1000 Nan CS 4143.08 5.5 0.62 2572.82 1278000.4 0.26 1000 Nan CS 4148.56 13 0.65 2696.11 691700.2 0.28 1000 Nan DS 4161.58 2.5 0.68 2849.85 1748000.4 0.26 1500 Nan DS 4164.07 12.5 0.64 2652.31 1111000.3 0.27 1500 Nan DS 4176.57 4 0.7 2924.54 1692000.4 0.26 1500 Nan DS 4180.58 2.5 0.65 2706.11 822100.2 0.27 1500 Shale 4183.07 2 0.7 2916.27 2665000.7 0.23 2500 Nan DS 4185.07 4 0.65 2713.22 1159000.3 0.27 1500 Nan DS 4189.07 4 0.63 2627.79 838300.2 0.27 1000 Shale 4193.08 4 0.7 2954.85 2665000.7 0.23 2500 Nan DS 4197.08 6 0.65 2712.93 1133000.3 0.27 1500 Shale 4203.08 2 0.7 2930.2 2665000.7 0.23 2500 Attachment K- NDB-027 Page 80 of 113 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 4205.09 2 0.63 2644.18 1078000.3 0.27 1500 Nan DS 4207.09 6.5 0.67 2813.01 1694000.4 0.26 1500 Nan DS 4213.58 4 0.62 2605.6 898500.2 0.27 1500 Nan DS 4217.59 3.5 0.65 2742.23 929100.3 0.27 1500 Shale 4221.06 2 0.7 2942.67 2665000.7 0.23 2500 Nan DS 4223.06 12.5 0.65 2728.89 1562000.4 0.26 1500 Nan DS 4235.56 2 0.66 2778.49 1397000.4 0.26 1500 Shale 4237.57 2 0.7 2954.27 2665000.7 0.23 2500 Nan DS 4239.57 2 0.65 2760.65 1242000.3 0.26 1500 Shale 4241.57 8 0.69 2925.12 2665000.7 0.23 2500 Nan DS 4249.57 2 0.64 2720.76 932500.2 0.27 1500 Shale 4251.57 4 0.7 2964.72 2665000.7 0.23 2500 Nan DS 4255.58 6 0.65 2750.93 1427000.4 0.26 1500 Shale 4261.58 8 0.7 2973.13 2665000.7 0.23 2500 Nan DS 4269.59 6.5 0.65 2797.49 1469000.4 0.26 1500 Shale 4276.08 6 0.69 2948.33 2665000.7 0.23 2500 Attachment K- NDB-027 Page 81 of 113 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 4282.09 2 0.64 2756.88 838400.2 0.27 1000 Shale 4284.09 2 0.7 2986.76 2665000.7 0.23 2500 Nan DS 4286.06 4 0.65 2787.34 1469000.4 0.26 1500 Shale 4290.06 2 0.7 2990.82 2665000.7 0.23 2500 Nan DS 4292.06 6 0.67 2881.17 1545000.4 0.26 1500 Shale 4298.06 12 0.7 2999.96 2665000.7 0.23 2500 Nan DS 4310.07 2.5 0.65 2785.01 1214000.3 0.27 1500 Shale 4312.57 20 0.69 2978.2 2665000.7 0.23 2500 Attachment K- NDB-027 Page 82 of 113 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 13440 320 8 2 1 PPA Scour 40 YF126ST 2414.7 60 CarboLite 40/70 1 2414.7 1.5 3 3 PPA Scour 40 YF126ST 4457.5 120 CarboLite 40/70 3 13372.5 3 4 Resume PAD 40 YF126ST 2100 50 1.25 5 1 PPA 40 YF126ST 8043 200 CarboLite 16/20- SG 1 8043 5 6 2 PPA 40 YF126ST 8679.6 225 CarboLite 16/20- SG 2 17359.2 5.63 7 4 PPA 40 YF126ST 9808.7 275 CarboLite 16/20- SG 4 39234.8 6.87 8 6 PPA 40 YF126ST 8623.7 260 CarboLite 16/20- SG 6 51742.2 6.5 9 8 PPA 40 YF126ST 7438.8 240 CarboLite 16/20- SG 8 59510.4 6 10 10 PPA 40 YF126ST 5818 200 CarboLite 16/20- SG 10 58180 5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 31.64 27.37 Attachment K- NDB-027 Page 83 of 113 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 70824 249856.8 1950 48.75 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 13 MD: [20312, 20318] 6586.7 223.79 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4063.31 4287.1 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 13 MD: [20312, 20318] 896.29 177.58 0.43 Attachment K- NDB-027 Page 84 of 113 Stage 14 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 14 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6692 psi 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 4058.79 10 0.73 2973.42 1461000.3 0.22 2500 Shale 4068.8 15 0.7 2833.02 1762000.5 0.22 2500 Nanushuk 3 SS 4083.79 15.3 0.68 2773.99 1898000.5 0.22 2000 Top Nan 4099.11 6 0.65 2662.46 838900.2 0.27 1000 Shale 4105.12 2 0.7 2893.21 2665000.7 0.23 2500 Nan DS 4107.12 1.5 0.64 2615.9 819400.2 0.27 1500 Nan DS 4108.6 2 0.64 2647.23 1222000.3 0.26 1500 Nan CS 4110.6 13 0.63 2593.56 869100.2 0.27 1000 Attachment K- NDB-027 Page 85 of 113 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 4123.62 1.5 0.61 2528.3 1002000.3 0.27 1000 Nan CS 4125.1 4 0.65 2662.31 706600.2 0.28 1000 Nan CS 4129.1 9 0.61 2509.01 1166000.3 0.27 1000 Nan CS 4138.09 7 0.65 2691.47 769000.2 0.27 1000 Nan CS 4145.11 5.5 0.62 2573.98 1278000.4 0.26 1000 Nan CS 4150.59 13 0.65 2697.41 691700.2 0.28 1000 Nan DS 4163.62 2.5 0.68 2851.3 1748000.4 0.26 1500 Nan DS 4166.11 12.5 0.64 2653.61 1111000.3 0.27 1500 Nan DS 4178.61 4 0.7 2925.99 1692000.4 0.26 1500 Nan DS 4182.61 2.5 0.65 2707.42 822100.2 0.27 1500 Shale 4185.1 2 0.7 2917.72 2665000.7 0.23 2500 Nan DS 4187.11 4 0.65 2714.53 1159000.3 0.27 1500 Nan DS 4191.11 4 0.63 2629.1 838300.2 0.27 1000 Shale 4195.11 4 0.7 2956.16 2665000.7 0.23 2500 Nan DS 4199.11 6 0.65 2714.24 1133000.3 0.27 1500 Shale 4205.12 2 0.7 2931.65 2665000.7 0.23 2500 Attachment K- NDB-027 Page 86 of 113 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 4207.12 2 0.63 2645.49 1078000.3 0.27 1500 Nan DS 4209.12 6.5 0.67 2814.46 1694000.4 0.26 1500 Nan DS 4215.62 4 0.62 2606.91 898500.2 0.27 1500 Nan DS 4219.62 3.5 0.65 2743.53 929100.3 0.27 1500 Shale 4223.1 2 0.7 2944.12 2665000.7 0.23 2500 Nan DS 4225.1 12.5 0.65 2730.19 1562000.4 0.26 1500 Nan DS 4237.6 2 0.66 2779.79 1397000.4 0.26 1500 Shale 4239.6 2 0.7 2955.58 2665000.7 0.23 2500 Nan DS 4241.6 2 0.65 2761.95 1242000.3 0.26 1500 Shale 4243.6 8 0.69 2926.57 2665000.7 0.23 2500 Nan DS 4251.61 2 0.64 2722.07 932500.2 0.27 1500 Shale 4253.61 4 0.7 2966.17 2665000.7 0.23 2500 Nan DS 4257.61 6 0.65 2752.24 1427000.4 0.26 1500 Shale 4263.62 8 0.7 2974.58 2665000.7 0.23 2500 Nan DS 4271.62 6.5 0.65 2798.79 1469000.4 0.26 1500 Shale 4278.12 6 0.69 2949.63 2665000.7 0.23 2500 Attachment K- NDB-027 Page 87 of 113 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 4284.12 2 0.64 2758.18 838400.2 0.27 1000 Shale 4286.12 2 0.7 2988.21 2665000.7 0.23 2500 Nan DS 4288.09 4 0.65 2788.64 1469000.4 0.26 1500 Shale 4292.09 2 0.7 2992.27 2665000.7 0.23 2500 Nan DS 4294.09 6 0.67 2882.48 1545000.4 0.26 1500 Shale 4300.1 12 0.7 3001.41 2665000.7 0.23 2500 Nan DS 4312.11 2.5 0.65 2786.32 1214000.3 0.27 1500 Shale 4314.6 20 0.69 2979.66 2665000.7 0.23 2500 Attachment K- NDB-027 Page 88 of 113 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 15960 380 9.5 2 1 PPA 40 YF126ST 8244 205 CarboLite 16/20- SG 1 8244 5.12 3 3 PPA 40 YF126ST 7598.2 205 CarboLite 16/20- SG 3 22794.6 5.12 4 5 PPA 40 YF126ST 8077.6 235 CarboLite 16/20- SG 5 40388 5.88 5 7 PPA 40 YF126ST 7530.6 235 CarboLite 16/20- SG 7 52714.2 5.88 6 9 PPA 40 YF126ST 6302.5 210 CarboLite 16/20- SG 9 56722.5 5.25 7 11 PPA 40 YF126ST 5079.9 180 CarboLite 16/20- SG 11 55878.9 4.5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 27.15 23.03 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 58792.8 236742.2 1649.99 41.25 Attachment K- NDB-027 Page 89 of 113 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 14 MD: [19768, 19774] 6692 210.34 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4066.12 4276.46 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 14 MD: [19768, 19774] 832.12 163.54 0.46 Attachment K- NDB-027 Page 90 of 113 Stage 15 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 15 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6588.6 psi 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 4060.76 10 0.73 2974.87 1461000.3 0.22 2500 Shale 4070.77 15 0.7 2834.47 1762000.5 0.22 2500 Nanushuk 3 SS 4085.76 15.3 0.68 2775.3 1898000.5 0.22 2000 Top Nan 4101.08 6 0.65 2663.76 838900.2 0.27 1000 Shale 4107.09 2 0.7 2894.66 2665000.7 0.23 2500 Nan DS 4109.09 1.5 0.64 2617.06 819400.2 0.27 1500 Nan DS 4110.56 2 0.64 2648.53 1222000.3 0.26 1500 Nan CS 4112.57 13 0.63 2594.73 869100.2 0.27 1000 Attachment K- NDB-027 Page 91 of 113 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 4125.59 1.5 0.61 2529.46 1002000.3 0.27 1000 Nan CS 4127.07 4 0.65 2663.47 706600.2 0.28 1000 Nan CS 4131.07 9 0.61 2510.31 1166000.3 0.27 1000 Nan CS 4140.06 7 0.65 2692.77 769000.2 0.27 1000 Nan CS 4147.08 5.5 0.62 2575.29 1278000.4 0.26 1000 Nan CS 4152.56 13 0.65 2698.72 691700.2 0.28 1000 Nan DS 4165.58 2.5 0.68 2852.6 1748000.4 0.26 1500 Nan DS 4168.08 12.5 0.64 2654.92 1111000.3 0.27 1500 Nan DS 4180.58 4 0.7 2927.44 1692000.4 0.26 1500 Nan DS 4184.58 2.5 0.65 2708.58 822100.2 0.27 1500 Shale 4187.07 2 0.7 2919.17 2665000.7 0.23 2500 Nan DS 4189.07 4 0.65 2715.83 1159000.3 0.27 1500 Nan DS 4193.08 4 0.63 2630.26 838300.2 0.27 1000 Shale 4197.08 4 0.7 2957.61 2665000.7 0.23 2500 Nan DS 4201.08 6 0.65 2715.54 1133000.3 0.27 1500 Shale 4207.09 2 0.7 2933.1 2665000.7 0.23 2500 Attachment K- NDB-027 Page 92 of 113 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 4209.09 2 0.63 2646.65 1078000.3 0.27 1500 Nan DS 4211.09 6.5 0.67 2815.76 1694000.4 0.26 1500 Nan DS 4217.59 4 0.62 2608.07 898500.2 0.27 1500 Nan DS 4221.59 3.5 0.65 2744.84 929100.3 0.27 1500 Shale 4225.07 2 0.7 2945.57 2665000.7 0.23 2500 Nan DS 4227.07 12.5 0.65 2731.5 1562000.4 0.26 1500 Nan DS 4239.57 2 0.66 2781.1 1397000.4 0.26 1500 Shale 4241.57 2 0.7 2957.03 2665000.7 0.23 2500 Nan DS 4243.57 2 0.65 2763.26 1242000.3 0.26 1500 Shale 4245.57 8 0.69 2927.88 2665000.7 0.23 2500 Nan DS 4253.58 2 0.64 2723.23 932500.2 0.27 1500 Shale 4255.58 4 0.7 2967.47 2665000.7 0.23 2500 Nan DS 4259.58 6 0.65 2753.54 1427000.4 0.26 1500 Shale 4265.58 8 0.7 2975.88 2665000.7 0.23 2500 Nan DS 4273.59 6.5 0.65 2800.1 1469000.4 0.26 1500 Shale 4280.09 6 0.69 2951.08 2665000.7 0.23 2500 Attachment K- NDB-027 Page 93 of 113 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 4286.09 2 0.64 2759.49 838400.2 0.27 1000 Shale 4288.09 2 0.7 2989.52 2665000.7 0.23 2500 Nan DS 4290.06 4 0.65 2789.95 1469000.4 0.26 1500 Shale 4294.06 2 0.7 2993.58 2665000.7 0.23 2500 Nan DS 4296.06 6 0.67 2883.93 1545000.4 0.26 1500 Shale 4302.07 12 0.7 3002.72 2665000.7 0.23 2500 Nan DS 4314.07 2.5 0.65 2787.63 1214000.3 0.27 1500 Shale 4316.57 20 0.69 2980.96 2665000.7 0.23 2500 Attachment K- NDB-027 Page 94 of 113 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 15750 375 9.38 2 1 PPA 40 YF126ST 7641.8 190.02 CarboLite 16/20- SG 1 7641.8 4.75 3 3 PPA 40 YF126ST 7971.7 215.07 CarboLite 16/20- SG 3 23915.1 5.38 4 5 PPA 40 YF126ST 8253.9 240.13 CarboLite 16/20- SG 5 41269.5 6 5 7 PPA 40 YF126ST 7696.2 240.17 CarboLite 16/20- SG 7 53873.4 6 6 9 PPA 40 YF126ST 6608.3 220.19 CarboLite 16/20- SG 9 59474.7 5.5 7 11 PPA 40 YF126ST 5367.5 190.19 CarboLite 16/20- SG 11 59042.5 4.75 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.56 22.44 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 59289.4 245217 1670.77 41.77 Attachment K- NDB-027 Page 95 of 113 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 15 MD: [19223, 19229] 6588.6 190.48 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4063.31 4253.79 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 15 MD: [19223, 19229] 711.25 144.5 0.61 Attachment K- NDB-027 Page 96 of 113 Stage 16 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 16 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6659.9 psi 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 4060.76 10 0.73 2974.87 1461000.3 0.22 2500 Shale 4070.77 15 0.7 2834.47 1762000.5 0.22 2500 Nanushuk 3 SS 4085.76 15.3 0.68 2775.3 1898000.5 0.22 2000 Top Nan 4101.08 6 0.65 2663.76 838900.2 0.27 1000 Shale 4107.09 2 0.7 2894.66 2665000.7 0.23 2500 Nan DS 4109.09 1.5 0.64 2617.06 819400.2 0.27 1500 Nan DS 4110.56 2 0.64 2648.53 1222000.3 0.26 1500 Nan CS 4112.57 13 0.63 2594.73 869100.2 0.27 1000 Attachment K- NDB-027 Page 97 of 113 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 4125.59 1.5 0.61 2529.46 1002000.3 0.27 1000 Nan CS 4127.07 4 0.65 2663.47 706600.2 0.28 1000 Nan CS 4131.07 9 0.61 2510.31 1166000.3 0.27 1000 Nan CS 4140.06 7 0.65 2692.77 769000.2 0.27 1000 Nan CS 4147.08 5.5 0.62 2575.29 1278000.4 0.26 1000 Nan CS 4152.56 13 0.65 2698.72 691700.2 0.28 1000 Nan DS 4165.58 2.5 0.68 2852.6 1748000.4 0.26 1500 Nan DS 4168.08 12.5 0.64 2654.92 1111000.3 0.27 1500 Nan DS 4180.58 4 0.7 2927.44 1692000.4 0.26 1500 Nan DS 4184.58 2.5 0.65 2708.58 822100.2 0.27 1500 Shale 4187.07 2 0.7 2919.17 2665000.7 0.23 2500 Nan DS 4189.07 4 0.65 2715.83 1159000.3 0.27 1500 Nan DS 4193.08 4 0.63 2630.26 838300.2 0.27 1000 Shale 4197.08 4 0.7 2957.61 2665000.7 0.23 2500 Nan DS 4201.08 6 0.65 2715.54 1133000.3 0.27 1500 Shale 4207.09 2 0.7 2933.1 2665000.7 0.23 2500 Attachment K- NDB-027 Page 98 of 113 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 4209.09 2 0.63 2646.65 1078000.3 0.27 1500 Nan DS 4211.09 6.5 0.67 2815.76 1694000.4 0.26 1500 Nan DS 4217.59 4 0.62 2608.07 898500.2 0.27 1500 Nan DS 4221.59 3.5 0.65 2744.84 929100.3 0.27 1500 Shale 4225.07 2 0.7 2945.57 2665000.7 0.23 2500 Nan DS 4227.07 12.5 0.65 2731.5 1562000.4 0.26 1500 Nan DS 4239.57 2 0.66 2781.1 1397000.4 0.26 1500 Shale 4241.57 2 0.7 2957.03 2665000.7 0.23 2500 Nan DS 4243.57 2 0.65 2763.26 1242000.3 0.26 1500 Shale 4245.57 8 0.69 2927.88 2665000.7 0.23 2500 Nan DS 4253.58 2 0.64 2723.23 932500.2 0.27 1500 Shale 4255.58 4 0.7 2967.47 2665000.7 0.23 2500 Nan DS 4259.58 6 0.65 2753.54 1427000.4 0.26 1500 Shale 4265.58 8 0.7 2975.88 2665000.7 0.23 2500 Nan DS 4273.59 6.5 0.65 2800.1 1469000.4 0.26 1500 Shale 4280.09 6 0.69 2951.08 2665000.7 0.23 2500 Attachment K- NDB-027 Page 99 of 113 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 4286.09 2 0.64 2759.49 838400.2 0.27 1000 Shale 4288.09 2 0.7 2989.52 2665000.7 0.23 2500 Nan DS 4290.06 4 0.65 2789.95 1469000.4 0.26 1500 Shale 4294.06 2 0.7 2993.58 2665000.7 0.23 2500 Nan DS 4296.06 6 0.67 2883.93 1545000.4 0.26 1500 Shale 4302.07 12 0.7 3002.72 2665000.7 0.23 2500 Nan DS 4314.07 2.5 0.65 2787.63 1214000.3 0.27 1500 Shale 4316.57 20 0.69 2980.96 2665000.7 0.23 2500 Attachment K- NDB-027 Page 100 of 113 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 16800 400 10 2 1 PPA 40 YF126ST 7238.8 180 CarboLite 16/20- SG 1 7238.8 4.5 3 2 PPA 40 YF126ST 7715.2 200 CarboLite 16/20- SG 2 15430.4 5 4 4 PPA 40 YF126ST 7846.9 220 CarboLite 16/20- SG 4 31387.6 5.5 5 6 PPA 40 YF126ST 7296.9 220 CarboLite 16/20- SG 6 43781.4 5.5 6 8 PPA 40 YF126ST 6818.9 220 CarboLite 16/20- SG 8 54551.2 5.5 7 10 PPA 40 YF126ST 5818 200 CarboLite 16/20- SG 10 58180 5 8 12 PPA 40 YF126ST 4932.9 180 CarboLite 16/20- SG 12 59194.8 4.5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.06 21.98 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 64467.6 269764.2 1819.99 45.5 Attachment K- NDB-027 Page 101 of 113 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 16 MD: [18678, 18684] 6659.9 214.96 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4068.97 4283.93 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 16 MD: [18678, 18684] 853.2 167.27 0.51 Attachment K- NDB-027 Page 102 of 113 Stage 17 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 17 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6479.7 psi ǣ Zoneset name: Stage 17 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 4060.76 10 0.73 2974.87 1461000.3 0.22 2500 Shale 4070.77 15 0.7 2834.47 1762000.5 0.22 2500 Nanushuk 3 SS 4085.76 15.3 0.68 2775.3 1898000.5 0.22 2000 Top Nan 4101.08 6 0.65 2663.76 838900.2 0.27 1000 Shale 4107.09 2 0.7 2894.66 2665000.7 0.23 2500 Nan DS 4109.09 1.5 0.64 2617.06 819400.2 0.27 1500 Nan DS 4110.56 2 0.64 2648.53 1222000.3 0.26 1500 Nan CS 4112.57 13 0.63 2594.73 869100.2 0.27 1000 Nan CS 4125.59 1.5 0.61 2529.46 1002000.3 0.27 1000 Attachment K- NDB-027 Page 103 of 113 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 4127.07 4 0.65 2663.47 706600.2 0.28 1000 Nan CS 4131.07 9 0.61 2510.31 1166000.3 0.27 1000 Nan CS 4140.06 7 0.65 2692.77 769000.2 0.27 1000 Nan CS 4147.08 5.5 0.62 2575.29 1278000.4 0.26 1000 Nan CS 4152.56 13 0.65 2698.72 691700.2 0.28 1000 Nan DS 4165.58 2.5 0.68 2852.6 1748000.4 0.26 1500 Nan DS 4168.08 12.5 0.64 2654.92 1111000.3 0.27 1500 Nan DS 4180.58 4 0.7 2927.44 1692000.4 0.26 1500 Nan DS 4184.58 2.5 0.65 2708.58 822100.2 0.27 1500 Shale 4187.07 2 0.7 2919.17 2665000.7 0.23 2500 Nan DS 4189.07 4 0.65 2715.83 1159000.3 0.27 1500 Nan DS 4193.08 4 0.63 2630.26 838300.2 0.27 1000 Shale 4197.08 4 0.7 2957.61 2665000.7 0.23 2500 Nan DS 4201.08 6 0.65 2715.54 1133000.3 0.27 1500 Shale 4207.09 2 0.7 2933.1 2665000.7 0.23 2500 Nan DS 4209.09 2 0.63 2646.65 1078000.3 0.27 1500 Attachment K- NDB-027 Page 104 of 113 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 4211.09 6.5 0.67 2815.76 1694000.4 0.26 1500 Nan DS 4217.59 4 0.62 2608.07 898500.2 0.27 1500 Nan DS 4221.59 3.5 0.65 2744.84 929100.3 0.27 1500 Shale 4225.07 2 0.7 2945.57 2665000.7 0.23 2500 Nan DS 4227.07 12.5 0.65 2731.5 1562000.4 0.26 1500 Nan DS 4239.57 2 0.66 2781.1 1397000.4 0.26 1500 Shale 4241.57 2 0.7 2957.03 2665000.7 0.23 2500 Nan DS 4243.57 2 0.65 2763.26 1242000.3 0.26 1500 Shale 4245.57 8 0.69 2927.88 2665000.7 0.23 2500 Nan DS 4253.58 2 0.64 2723.23 932500.2 0.27 1500 Shale 4255.58 4 0.7 2967.47 2665000.7 0.23 2500 Nan DS 4259.58 6 0.65 2753.54 1427000.4 0.26 1500 Shale 4265.58 8 0.7 2975.88 2665000.7 0.23 2500 Nan DS 4273.59 6.5 0.65 2800.1 1469000.4 0.26 1500 Shale 4280.09 6 0.69 2951.08 2665000.7 0.23 2500 Nan DS 4286.09 2 0.64 2759.49 838400.2 0.27 1000 Attachment K- NDB-027 Page 105 of 113 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 4288.09 2 0.7 2989.52 2665000.7 0.23 2500 Nan DS 4290.06 4 0.65 2789.95 1469000.4 0.26 1500 Shale 4294.06 2 0.7 2993.58 2665000.7 0.23 2500 Nan DS 4296.06 6 0.67 2883.93 1545000.4 0.26 1500 Shale 4302.07 12 0.7 3002.72 2665000.7 0.23 2500 Nan DS 4314.07 2.5 0.65 2787.63 1214000.3 0.27 1500 Shale 4316.57 20 0.69 2980.96 2665000.7 0.23 2500 Attachment K- NDB-027 Page 106 of 113 ǣ Name: Stage 17 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 17 PAD 40 YF126ST 16800 400 10 2 1 PPA 40 YF126ST 7238.8 180 CarboLite 16/20- SG 1 7238.8 4.5 3 2 PPA 40 YF126ST 7715.2 200 CarboLite 16/20- SG 2 15430.4 5 4 4 PPA 40 YF126ST 7846.9 220 CarboLite 16/20- SG 4 31387.6 5.5 5 6 PPA 40 YF126ST 7296.9 220 CarboLite 16/20- SG 6 43781.4 5.5 6 8 PPA 40 YF126ST 6818.9 220 CarboLite 16/20- SG 8 54551.2 5.5 7 10 PPA 40 YF126ST 5818 200 CarboLite 16/20- SG 10 58180 5 8 12 PPA 40 YF126ST 4932.9 180 CarboLite 16/20- SG 12 59194.8 4.5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.06 21.98 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 64467.6 269764.2 1819.99 45.5 Attachment K- NDB-027 Page 107 of 113 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 17 MD: [18137, 18143] 6479.7 240.5 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4064.65 4305.15 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 17 MD: [18137, 18143] 775.31 194.29 0.53 Attachment K- NDB-027 Page 108 of 113 Stage 18 The following are the results of the computer simulation which was run for the following combination of inputs: Stage ID: 18 Simulator Settings: Simulator type: p3dmp1 Shut-in time (s): 6000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6315.8 psi ǣ Zoneset name: Stage 18 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 4038.78 10 0.73 2958.77 1461000.3 0.22 2500 Shale 4048.79 15 0.7 2819.1 1762000.5 0.22 2500 Nanushuk 3 SS 4063.78 15.3 0.68 2760.5 1898000.5 0.22 2000 Top Nan 4079.1 6 0.65 2649.4 838900.2 0.27 1000 Shale 4085.1 2 0.7 2879.14 2665000.7 0.23 2500 Nan DS 4087.11 1.5 0.64 2603.14 819400.2 0.27 1500 Nan DS 4088.58 2 0.64 2634.32 1222000.3 0.26 1500 Nan CS 4090.58 13 0.63 2580.95 869100.2 0.27 1000 Attachment K- NDB-027 Page 109 of 113 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 4103.61 1.5 0.61 2515.97 1002000.3 0.27 1000 Nan CS 4105.09 4 0.65 2649.4 706600.2 0.28 1000 Nan CS 4109.09 9 0.61 2496.97 1166000.3 0.27 1000 Nan CS 4118.08 7 0.65 2678.56 769000.2 0.27 1000 Nan CS 4125.1 5.5 0.62 2561.66 1278000.4 0.26 1000 Nan CS 4130.58 13 0.65 2684.5 691700.2 0.28 1000 Nan DS 4143.6 2.5 0.68 2837.52 1748000.4 0.26 1500 Nan DS 4146.1 12.5 0.64 2640.85 1111000.3 0.27 1500 Nan DS 4158.6 4 0.7 2911.92 1692000.4 0.26 1500 Nan DS 4162.6 2.5 0.65 2694.37 822100.2 0.27 1500 Shale 4165.09 2 0.7 2903.8 2665000.7 0.23 2500 Nan DS 4167.09 4 0.65 2701.47 1159000.3 0.27 1500 Nan DS 4171.1 4 0.63 2616.48 838300.2 0.27 1000 Shale 4175.1 4 0.7 2942.09 2665000.7 0.23 2500 Nan DS 4179.1 6 0.65 2701.33 1133000.3 0.27 1500 Shale 4185.1 2 0.7 2917.72 2665000.7 0.23 2500 Attachment K- NDB-027 Page 110 of 113 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 4187.11 2 0.63 2632.87 1078000.3 0.27 1500 Nan DS 4189.11 6.5 0.67 2801.11 1694000.4 0.26 1500 Nan DS 4195.6 4 0.62 2594.58 898500.2 0.27 1500 Nan DS 4199.61 3.5 0.65 2730.48 929100.3 0.27 1500 Shale 4203.08 2 0.7 2930.2 2665000.7 0.23 2500 Nan DS 4205.09 12.5 0.65 2717.28 1562000.4 0.26 1500 Nan DS 4217.59 2 0.66 2766.59 1397000.4 0.26 1500 Shale 4219.59 2 0.7 2941.66 2665000.7 0.23 2500 Nan DS 4221.59 2 0.65 2748.9 1242000.3 0.26 1500 Shale 4223.59 8 0.69 2912.79 2665000.7 0.23 2500 Nan DS 4231.59 2 0.64 2709.16 932500.2 0.27 1500 Shale 4233.6 4 0.7 2952.24 2665000.7 0.23 2500 Nan DS 4237.6 6 0.65 2739.33 1427000.4 0.26 1500 Shale 4243.6 8 0.7 2960.66 2665000.7 0.23 2500 Nan DS 4251.61 6.5 0.65 2785.59 1469000.4 0.26 1500 Shale 4258.1 6 0.69 2935.85 2665000.7 0.23 2500 Attachment K- NDB-027 Page 111 of 113 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 4264.11 2 0.64 2745.27 838400.2 0.27 1000 Shale 4266.11 2 0.7 2974.14 2665000.7 0.23 2500 Nan DS 4268.08 4 0.65 2775.59 1469000.4 0.26 1500 Shale 4272.08 2 0.7 2978.35 2665000.7 0.23 2500 Nan DS 4274.08 6 0.67 2869.14 1545000.4 0.26 1500 Shale 4280.09 12 0.7 2987.34 2665000.7 0.23 2500 Nan DS 4292.09 2.5 0.65 2773.41 1214000.3 0.27 1500 Shale 4294.59 20 0.69 2965.88 2665000.7 0.23 2500 Attachment K- NDB-027 Page 112 of 113 ǣ Name: Stage 18 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 18 PAD 40 YF126ST 16800 400 10 2 1 PPA 40 YF126ST 7238.8 180 CarboLite 16/20- SG 1 7238.8 4.5 3 2 PPA 40 YF126ST 7715.2 200 CarboLite 16/20- SG 2 15430.4 5 4 4 PPA 40 YF126ST 7846.9 220 CarboLite 16/20- SG 4 31387.6 5.5 5 6 PPA 40 YF126ST 7296.9 220 CarboLite 16/20- SG 6 43781.4 5.5 6 8 PPA 40 YF126ST 6818.9 220 CarboLite 16/20- SG 8 54551.2 5.5 7 10 PPA 40 YF126ST 5818 200 CarboLite 16/20- SG 10 58180 5 8 12 PPA 40 YF126ST 4932.9 180 CarboLite 16/20- SG 12 59194.8 4.5 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.06 21.98 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 64467.6 269764.2 1819.99 45.5 Attachment K- NDB-027 Page 113 of 113 ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Perf 18 MD: [17634, 17640] 6315.8 217.59 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4045.61 4263.2 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length Height Avg Wellbore Width (ft) (ft) (in) Perf 18 MD: [17634, 17640] 823.72 173.25 0.59