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Home My WebLink About2025_11_05_325-6801. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Well Clean Up 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 22,871'N/A Casing Collapse Conductor Surface 2,260 Intermediate 4,750 Tieback 4,750 Intermediate 2 5,410 Production 9,210 Liner 9,210 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:scott.leahy@santos.com Contact Phone: 907-330-4595 Authorized Title: Completions Specialist Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. 14,921 Perforation Depth MD (ft): 9,995 5,071 4-1/2" 22,8548,139 4-1/2" 12.6ppf 4,1117" 20"x34" 13-3/8" 128' 9-5/8"7,128 3,058 3,279 2,309 MD 6,870 5,020 128 2,389 128 3,058 Length Size Proposed Pools: P110S TVD Burst 14,715 7,240 Pikka Nanushuk Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 392984, 391445, 393023, 393022, 392977, 392958 225-084 601 W 5th Avenue, Suite 600, Anchorage, AK 99501 50-103-20924-00-00 Oil Search Alaska, LLC Pikka NDB-040 AOGCC USE ONLY 11,590 Tubing Grade: Tubing MD (ft): See attached packer report Perforation Depth TVD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Leahy 14,715 4-1/2" 14,715 4,066 11,590 11/20/2025 4,09 See attached packer report N/A 2,800 Tieback 2,800 6,870 4,093 22,852 4,09 P ell Cla Well Stat oposed wor dedd t edeeedeedn CtP W No Comm.Form 10-403 Revised 06/2023 Sr Pet Eng Approved application valid Sr Pet Geo for 12 months from date of approval.oaSr Rogescc. EnpergSubmit PDF t mitting@alaska.gov e foregoing is true and the 11/04/2025 325-680 By Grace Christianson at 7:52 am, Nov 05, 2025 Item Description Top (ftKB)Top (TVD) (ft KB) ZXP Liner Top Hanger Packer W/HRD-E Profile 14,715 4,060 HES Zoneguard OH Packer #16 14,999 4,125 HES Zoneguard OH Packer #15 15,064 4,140 HES Zoneguard OH Packer #14 15,609 4,165 HES Zoneguard OH Packer #13 16,071 4,160 HES Zoneguard OH Packer #12 16,739 4,154 HES Zoneguard OH Packer #11 17,282 4,150 HES Zoneguard OH Packer #10 17,866 4,144 HES Zoneguard OH Packer #9 18,410 4,138 HES Zoneguard OH Packer #8 18,956 4,132 HES Zoneguard OH Packer #7 19,543 4,127 HES Zoneguard OH Packer #6 20,082 4,122 HES Zoneguard OH Packer #5 20,665 4,116 HES Zoneguard OH Packer #4 21,210 4,111 HES Zoneguard OH Packer #3 21,796 4,105 HES Zoneguard OH Packer #2 22,341 4,099 HES Zoneguard OH Packer #1 22,719 4,095 Packer Set Depths - NDB-040 Page 1 of 20 NDB-040 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-040. At the NDB-040 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-040 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 965 feet (ft) total vertical depth subsea (TVDSS)/ 965 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: 965 to 2,387 ft TVDSS/1,422 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: 2,387 to 3,289 ft TVDSS/ 902 ft thick Hydrocarbon Zone: 2,756 to 3,289 ft TVDSS Lithological Description: The Tuluvak Fm in the Pikka Unit area consists predominantly of claystone, siltstone, and thinly interbedded sandstones deposited in a prograding, shallow marine setting, grading with depth to the deep marine shales of the Seabee Fm. Sandstones. Upper Confining Zone Name Seabee Formation Depth/Thickness: 3,289 to 3,736 ft TVDSS/ 447 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: 3,737 to 4,691 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: 4,691 to 5,590 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 1-14 3,800 4,100 8,500 8,100 9,200 8,800 Note: GORV and pump trips to be set to 8700 psi to open Toe Sleeve Fracture gradient values for each stage are listed in detail within Attachment K. In general, the fracture gradient values for the confining zones and pay zone are listed below: Upper confining: Shale gradient – 0.71 psi/ft Fracturing: Sand gradient- 0.61 psi/ft Lower confining: Shale gradient- 0.69 psi/ft Mechanical condition of wells transecting the confining zones –NDBi-049, NDBi- 036, NDBi-050, NDBi-050PB1 NDB-048, and NDBi-046/NDBi-046L1. Please see Attachment B as reference. Stage MD Perf Depth (ft) TVD Perf Depth (ft) Max Frac Height (ft) Frac ½ Length (ft) Max Rate (bpm) Est. Max Pressure (psi) Max Prop Conc. (PPA) 1 22,613 4,096 239 498 40 6,604 8 2 22,070 4,102 241 499 40 6,564 8 3 21,483 4,108 244 521 40 6,899 10 4 20,937 4,113 250 422 40 6,695 10 5 20,395 4,118 249 420 40 6,545 10 6 19,816 4,124 248 414 40 6,381 10 7 19,271 4,129 245 387 40 6,485 11 8 18,684 4,135 247 406 40 6,595 12 9 18,055 4,141 245 387 40 6,112 11 10 17,554 4,146 250 414 45 7,313 12 11 17,012 4,151 251 430 45 7,141 12 12 16,466 4,157 251 440 45 6,313 10 13 15,882 4,164 252 450 45 6,127 10 14 15,296 4,162 248 410 45 5,934 10 A cross-section map of NDB-040 is presented in Attachment B. NDBi-050 is shown to sail over NDB-040 by approximately 112 feet. Per the fracture model for Stages 12-14 on NDB-040, the stages closest in proximity to the lateral of NDBi- 050, the fracture height growth is approximately 85-90 feet above the lateral where the fracture is initiated and would not intersect the NDBi-050 wellbore. Additionally, the NDB-040 lateral is 708 feet away from NDB-048 when considering the 330-degree plane that both wells have the lateral drilled. Note that the induced fractures are thought to propagate at 330 degrees which would provide sufficient offset given that the modelled half length is estimated at 410 feet for Stage 14 on NDB-040. Santos will monitor the BHP on wells NDBi-050 and NDB-048. If a pressure increase is observed in either of the wells being monitored, the stage will not continue to completion and will be flushed to depth. 11.Suspected fault or fracture that may transect the confining zones: There are no known faults within the ½ mile radius of NDB-040. Please See Attachment B. Note: Fractures are estimated to propagate along wellbore longitudinally at ~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( 8 1 ( 8 1 ( 81( 81( 81( 81( 81( 81( 81( 81( 8 1 ( 81( 81( 81( 81( 8 1 ( 81(81( 81( 81( 81( 81( 81( ADL 392977 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 17.22% DNR - 82.78% ADL 392991 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 41.58% DNR - 58.42% ADL 392959 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 22.52% DNR - 77.48%pik ADL 392965 Surface Owners: Kuu OIL SEARCH - 51%, RE SUBS.OWNERS: ASRC - 50% DNR - 50% AD L 3 9 2 9 8 5 Su r f a c e O w n e r s : K u u k p i k OI L S E A R C H - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 4 9 . 8 4 % D N R - 5 0 . 1 6 % AD L 3 9 2 9 8 4 Su r f a c e O w n e r s : K u u k p i k OI L S E A R C H - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 5 0 % D N R - 5 0 % AD L 3 9 2 9 5 8 Su r f a c e O w n e r s : K u u k p i k OI L S E A R C H - 5 1 % , R E P S O L - 4 9 % SU B S . O W N E R S : AS R C - 3 6 . 3 1 % D N R - 6 3 . 6 9 % ADL 392970 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 40.29% DNR - 59.71% ADL 393024 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 45.77% DNR - 54.23% ADL 393022 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 39.48% DNR - 60.52% ADL 393021 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 19.22% DNR - 80.78% ADL 393023 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 44.08% DNR - 55.92% 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 393016 Surface Owners: Ku OIL SEARCH - 51%, R SUBS.OWNERS: ASRC - 33.17% DNR ADL 391320 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 44.93% DNR - 55.07% ADL 391445 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 41.98% DNR - 58.02% ADL 391455 Surface Owners: Kuukpik OIL SEARCH - 51%, REPSOL - 49% SUBS.OWNERS: ASRC - 46.4% DNR - 53.6% OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD NDB-040 SURFACE LOCATION NDB-040 TRAJECTORY 0.5-MILE BUFFER NDB-040 BOTTOM HOLE PRODUCTION INTERVAL SECTIONS SANTOS LEASES DATE: 9/29/2025. By: JB 00.10.2 MilesProject: AP-DRL-GEN_assorted Layout: AP-DRL-PE_NDB40_well_ownership Map Frame: AP-DRL-PE-M_NDB-040_well_ownership GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 00.20.4 Kilometers PIKKA DEVELOPMENT NDB-040 WELL AREA Attachment B ADL 392977 ADL 392991 ADL 392959ADL 392978 ADL 392965 ADL 392985 ADL 392984 ADL 392958 ADL 392992 ADL 392970 ADL 393024 ADL 393022 ADL 393021 ADL 393023 ADL 393019 ADL 393018 ADL 393020 ADL 393015 ADL 393016 ADL 393007 ADL 391320 ADL 391445 ADL 391455 ADL 393011 81( 81( 8 1 ( 81( 81( 81( 81( 81( 81( 81( 81( 81( 81( 8 1 ( 81(81(81( 81( 8 1 ( 81( 81( 81( 81( 81( 81( 81( COLVILLE RIVER 1 FIORD 3A FIORD 3 QUGRUK 3 QUGRUK 301 QUGRUK 3A COLVILLE RIV UNIT CD1-15 QUGRUK 8 CD1-15PB1 Colville River Unit CD1-15PB2 DW-02 NDB-011 NDB-024 NDB-025 NDB-031 NDB-032 NDB-037 NDB-051 NDBi-014 NDBi-018 NDBi-030 NDBi-036 NDBi-043A NDBi-044 NDBi-046 NDBi-049 OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD NDB-040 SURFACE LOCATION NDB-040 TRAJECTORY OTHER DRILLED NDB WELLS 0.25-MILE BUFFER 0.5-MILE BUFFER NDB-040 BOTTOM HOLE NDB DRILLED WELLS BOTTOM HOLES DEVELOPMENT WELLS EXPLORATION WELLS BOTTOM HOLES OTHER WELL TRAJECTORIES BY OTHERS PRODUCTION INTERVAL SANTOS LEASES SECTIONS FAULT LINE DATE: 9/29/2025. By: JB 00.10.2 Miles Project: AP-DRL-GEN_assorted Layout: AP-DRL-GEN-M_NDB40_buffers GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 00.20.4 Kilometers PIKKA DEVELOPMENT NDB-040 WELL NDBi-046L1 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 4 6 / N D B i - 0 4 6 L 1 A C T I V E 9 - 5 / 8 " 4 7 p p f 1 1 , 1 6 6 ' ( N a n u s h u k ) 3 , 7 3 3 ' ( N a n u s h u k ) 1 0 2 5 5 3 , 6 1 5 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 1 0 , 2 5 5 ' & p a c k e r @ 12 , 5 7 2 ' 9- 5 / 8 ” x 1 3 - 3 / 8 ” P r i m a r y c e m e n t j o b - P u m p 8 0 b b l 1 2 . 5 p p g T u n e d S p a c e r w i t h S u r f a c t a n t B a n d M u s o l a t 3 . 7 - 4 b p m , r e l e a s e b o t t o m p u m p d o w n p l u g f o r b o t t o m p l u g , c h as e w i t h 1 5 . 3 p p g Ve r s a c e m T a i l C e m e n t T y p e I / I I , p u m p t o t a l o f 1 9 7 b b l s a t 4 b p m , r e l e a s e t o p p u m p d o w n p l u g , c h a s e w i t h 2 0 b b l s o f w a t e r f r o m H al l i b u r t o n . P e r f o r m di s p l a c e m e n t w i t h r i g p u m p s , d i s p l a c e w i t h 1 1 . 8 p p g O B M a t 4 b p m , I C P 3 9 5 p s i 8 % f l o w , F C P 5 9 6 p s i , 2 % r e t u r n f l o w , r e d u c e r a t e t o 3 b p m p r i o r t o p l u g bu m p : F i n a l c i r c u l a t i n g p r e s s u r e 5 9 6 p s i . p r e s s u r e d u p 5 0 0 p s i o v e r F C P 1 , 0 8 0 p s i . H e l d 5 m i n , b l e d o f f c h e c k e d f l o a t s . F l o a t s he l d . C I P @ 1 2 : 4 5 h r s . - T o t a l l o s s e s f r o m c e m e n t e x i t s h o e t o c e m e n t i n p l a c e : 4 3 b b l s . Ce m e n t E v a l u a t i o n R e s u l t s : T O C w a s f o u n d t o b e 91 1 ’ a b o v e t h e T o p o f t h e N a n u s h u k P o o l ( 1 1 , 1 6 6 ’ M D ) a t 1 0 , 2 5 5 ’ M D . C e m e n t i s o l a t i o n f r o m t h e T O C d o w n to t h e c a s i n g s h o w w a s f o u n d t o b e i n g o o d q u a l i t y r a n g i n g d o w n t o p a r t i a l c o v e r a g e i n l i m i t e d a r e a s . 07 / 1 1 / 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 3 , 6 6 7 p s i fo r 3 0 m i n u t e s ND B - 0 4 8 A C T I V E 9 - 5 / 8 " 4 7 p p f 1 2 , 0 4 4 ' ( N a n u s h u k ) 3 , 7 3 3 ' ( N a n u s h u k ) 1 0 , 9 0 8 ' 3, 5 7 4 ' Lo 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 1 2 , 0 4 4 M D ' & P a c k e r @ 1 1 , 9 8 9 M D ' Fi r s t s t a g e o f c e m e n t j o b : P u m p 8 2 b b l 1 2 . 5 p p g T u n e d S p a c e r w i t h S u r f a c t a n t B a n d M u s o l A d o w n h o l e a t 3 b p m , ~ 0 % r e t u r n s . Re l e a s e b o t t o m p u m p d o w n p l u g f o r b o t t o m p l u g , p u m p 1 5 3 b b l s 1 5 . 3 p p g V e r s a c e m T a i l C e m e n t T y p e I / I I ( 6 8 1 s a c k s , y i e l d 1 . 2 3 7 c u f t / s k – 1 s t 2 0 b b l s N e a t an d l a s t 4 0 b b l s N e a t w i t h o u t B r i d g e m a k e r I I L C M ) , e x c e s s v o l u m e 3 0 % , a t 3 . 5 b p m , a v e r a g e c i r c u l a t i n g p r e s s u r e 3 3 0 p s i . ~ 5 % r e t ur n s t h r o u g h o u t c e m e n t pu m p i n g . Re l e a s e t o p p u m p d o w n p l u g , c h a s e p l u g w i t h d i s p l a c e m e n t b y r i g p u m p s , d i s p l a c e w i t h 1 1 . 5 p p g O B M a t 3 . 5 b p m , I C P 2 0 0 p s i . A v e r ag e ~ 0 % r e t u r n s d u r i n g di s p l a c e m e n t . B o t t o m p l u g l a n d e d o n c a l c u l a t e d s t r o k e s at 3 . 5 b p m , 5 2 0 p s i c i r c p r e s s u r e , s h e a r w i t h d r o p i n c i r c u l a t i n g p r e s s u r e t o 4 9 3 p s i a n d m a i n t a i n 3 . 5 b p m a s c e m e n e x i t s s h o e . C i r c u l a t i n g p r e s s u r e w i t h ce m e n t t u r n i n g s h o e 4 9 3 I C P a t 3 . 5 b p m . R e d u c e ra t e t o 3 . 0 b p m , 4 5 5 p s i c i r c . p r e s s u r e t o r e d u c e E C D . M a i n t a i n 3 b p m t o p l u g b u m p , F C P 5 0 0 p s i ; ~ 0 % r e t u r n s w i t h c e m e n t a r o u n d s h o e . B u m p p l u g , h o l d f o r 5 mi n u t e s , t o c h e c k f l o a t s , f l o a t s h e l d , O b s e r v a t i o n s f o 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 : T h e r e i s ad e q u a t e i s o l a t i o n o f t h e 9 - 5 / 8 ” s h o e i n t h e T o p N a n u s h u k a n d g o o d i s o l a t i o n i n t h e l o w e r S e a b e e f o r m a t i o n b a s e d o n t h e C B L l o g. W h i l e l o s s e s w e r e en c o u n t e r e d d u r i n g t h e l i n e r r u n a n d s u b s e q u e n t c e m e n t j o b , t h e C B L l o g i n d i c a t e s g o o d c e m e n t i s o l a t i o n t o t h e p i c k e d T O C a t 1 0 ,9 0 8 ’ M D . T h e C B L i n d i c a t e s go o d q u a l i t y c e m e n t f r o m 1 2 , 0 6 6 ’ t o 1 0 , 9 0 8 ’ , w i t h p o o r t o n o c e m e n t f r o m 1 0 , 9 0 8 ’ t o 9 , 8 2 5 ’ M D . 12 / 3 1 / 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 3 , 7 5 5 p s i fo r 3 0 m i n u t e s ND B i - 0 4 9 A C T I V E 9 - 5 / 8 " 4 7 p p f 1 1 , 5 6 0 ' ( N a n u s h u k ) 3 , 7 4 3 ' ( N a n u s h u k ) 1 0 , 4 7 7 ' 3 , 5 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 1 0 , 4 7 7 ' & p a c k e r @ 11 , 4 3 8 ' Ce m e n t J o b E x e c u t i o n : - 1 s t S t a g e o f c e m e n t j o b p l a n n e d w i t h a f u l l 1 5 . 3 p p g t a i l s l u r r y a t 3 0 % e x c e s s , t a r g e t i n g T O C 2 5 0 ’ T V D a b o v e t o p o f N a n u s h u k t o 10 , 2 0 0 ’ M D . -D u r i n g e x e c u t i o n o f t h e 1 s t s t a g e c e m e n t j o b , l o s t a r e p o r t e d 8 8 b b l s a f t e r c e m e n t t u r n e d t h e c o r n e r , a l t h o u g h l i f t p r e s s u r e c on t i n u e d t o i n c r e a s e d u r i n g t h e di s p l a c e m e n t ( I C P 2 8 0 p s i , F C P 4 0 7 p s i ) . -2 n d S t a g e o f c e m e n t j o b p l a n n e d w i t h C F L E X ~ 1 0 3 ’ b e l o w t h e T S 7 9 0 . A l s o p l a n n e d w i t h a f u l l 1 5 . 3 p p g t a i l s l u r r y a t 1 0 0 % e x c e s s, t a r g e t i n g T O C a t t h e 9 - 5 / 8 ” li n e r t o p . -D u r i n g e x e c u t i o n o f t h e 2 n d s t a g e c e m e n t j o b , ~ 6 b b l s o f l o s s e s w e r e r e p o r t e d a n d g o o d l i f t p r e s s u r e s n o t e d . A n e s t i m a t e d 1 4 0 bb l s S p a c e r , 3 5 b b l s co n t a m i n a t e d c e m e n t , a n d 6 5 b b l s p u r e c e m e n t o b s e r v e d a t s u r f a c e o f f t h e t o p o f l i n e r . Ob s e r v a t i o n s / Co n c l u s i o n s : - F o 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 a b o v e t h e t o p o f t h e N a n u s h u k f o r m a t i o n . T h i s i s s u p p o r t e d by t h e C B L l o g , wh 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 w i t h a T O C a t 1 0 , 4 7 7 ’ M D ( 1 0 8 3 ’ M D / 1 4 2 ’ T V D a b o v e t o p N a n u s h u k ) . -F o 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 oc a 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 . -O u 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 t h e t o p o f t h e N a n u s h u k f o r m a t i o n f o r f r 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 is 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 . 12 / 1 0 / 2 4 , 9 - 5 / 8 " c a s i n g p r e s s u r e t e s t e d t o 4 , 0 2 0 p s i fo r 3 0 m i n u t e s ND B i - 0 5 0 P B 1 A b a n d o n d e d 9 - 5 / 8 " 4 7 p p f 1 3 , 2 2 8 ' ( N a n u s h u k ) 3 , 7 2 7 ' ( N a n u s h u k ) Ab a n d o n e d w i t h C a s e d h o l e ce m e n t p l u g s Ce m e n t r e t a i n e r @ 13 , 0 0 9 ' M D w i t h 4 5 b b l s be n e a t h r e t a i n e r a n d 5 bb l s a b o v e . Th e 1 2 - 1 / 4 ” i n t e r m e d i a t e h o l e w a s d r i l l e d t o a d e p t h o f 1 3 , 3 7 2 ’ M D ( t o p o f N a n u s h u k f o r m a t i o n ) . 9 - 5 / 8 ” l i n e r w a s r u n t o a d e p t h o f 1 3 , 3 6 7 ’ M D . 9 - 5 / 8 ” l i n e r wa s s e t a t t h e v e r y t o p o f t h e N a n u s h u k f o r m a t i o n . U p p e r 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 i s t h e N T 8 M F S . N D B i - 0 5 0 P B 1 we l l b o r e w a s d r i l l e d t o 30 2 ’ M D ( 3 7 ’ T V D ) a b o v e t h e p r o g n o s e d t o p o f t h e N T 8 M F S . D u r i n g t h e 1 s t s t a g e c e m e n t j o b , b o t h l i n e r w i p e r p l u g s w e r e i n a d v e r te n t l y l a u n c h e d a h e a d o f ce m e n t . W h e n t h e p l u g s l a n d e d o n t h e l a n d i n g c o l l a r , a l l c e m e n t w a s l e f t i n s i d e t h e 9 - 5 / 8 ” c a s i n g , w i t h t h e 8 0 b b l s o f w a t e r - b as e d s p a c e r i n t h e 1 2 - 1 / 4 ” x 9 - 5/ 8 ” a n n u l u s . -L o w e r L i n e r S e c t i o n : C e m e n t w a s d r i l l e d o u t , a n d a r e m e d i a l c e m e n t j o b w i t h 5 0 b b l s o f c e m e n t w a s a t t e m p t e d w i t h a c e m e n t r e t a in e r i n t h e 9 - 5 / 8 ” s h o e tr a c k . T h e 9 - 5 / 8 ” c a s i n g w a s l a t e r f o u n d t o b e p a r t e d a t 1 3 , 11 1 ’ M D ( a b o v e c e m e n t r e t a i n e r s e t d e p t h ) . A s e c o n d c e m e n t r e t a i n e r w a s s e t a t 1 3 , 0 0 9 ’ M D , a n d th e 9 - 5 / 8 ” l i n e r a p p e a r e d t o b e p a r t e d i n a n o t h e r l o c a t i o n a b o v e t h e 2 n d c e m e n t r e t a i n e r . A n o t h e r 5 0 b b l s o f c e m e n t w a s p u m p e d t o P & A t h e l o w e r l i n e r se c t i o n . 4 5 b b l s o f c e m e n t w a s s q u e e z e d b e l o w t h e c e m e n t r e t a i n e r , a n d 5 b b l s w e r e p l a c e d o n t o p o f t h e r e t a i n e r . -U p p e r L i n e r S e c t i o n : 2 n d s t a g e 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 A r c h e r C - F l e x s t a g e t o o l p e r p l a n ( 3 2 5 b b l s 1 5 . 3 p p g c e m e n t ) t o i s o l a t e t h e T u l u v a k s a n d . No l o s s e s w e r e o b s e r v e d d u r i n g t h e c e m e n t j o b a n d 5 0 b b l s o f c e m e n t w e r e c i r c u l a t e d o f f t h e l i n e r t o p . Se t 9 - 5 / 8 ” b r i d g e p l u g a t 3 1 5 0 ’ M D . S e t 2 5 K l b s t o c o n f i r m s e t . L a y i n 3 0 b b l s 1 5 . 3 p p g c e m e n t p l u g o n t o p o f b r i d g e p l u g , t a r ge t i n g T O C 5 0 ’ a b o v e s u r f a c e ca s i n g s h o e . P r e s s u r e t e s t c e m e n t p l u g t o 2 0 0 0 p s i f o r 3 0 m i n . . We l l i s f u l l y a b a n d o n e d . ND B i - 0 5 0 A C T I V E Li n e r 1 - 9 - 5 / 8 " 47 p p f t o 9 , 9 9 0 ' . Li n e r 2 - 7 " 2 6 p p t t o 15 , 1 3 7 ' . 12 , 1 0 5 ' ( N a n u s h u k ) 3 , 7 3 8 ' ( N a n u s h u k ) 1 1 , 5 4 5 ' 3 , 6 7 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 1 1 , 5 4 5 ' & p a c k e r @ 15 , 1 3 7 ' Ce m e n t J o b E x e c u t i o n : 9- 5 / 8 ” I n t e r m e d i a t e 1 L i n e r -2 n d S t a g e o f c e m e n t j o b p l a n n e d w i t h C F L E X ~ 9 6 ’ b e l o w t h e T S 7 9 0 . A l s o p l a n n e d w i t h a f u l l 1 5 . 3 p p g t a i l s l u r r y a t 1 6 5 % e x c e s s , t a r g e t i n g T O C a t t h e 9 - 5 / 8 ” li n e r t o p . -D u r i n g e x e c u t i o n o f t h e 2 n d s t a g e c e m e n t , n o l o s s e s w e r e e n c o u n t e r e d a n d w e s a w g o o d l i f t p r e s s u r e . A n e s t i m a t e d 1 1 0 b b l s o f s pa c e r a n d 1 2 0 b b l s o f c e m e n t ob s e r v e d a t s u r f a c e o f f t h e t o p o f l i n e r . 7” I n t e r m e d i a t e 2 L i n e r - 7 ” L i n e r c e m e n t j o b p l a n n e d w i t h a f u l l 1 5 . 3 p p g t a i l s l u r r y a t 3 0 % e x c e s s , t a r g e t i n g T O C 1 0 0 ’ T V D a b o ve t o p o f N a n u s h u k t o 1 1 , 2 0 0 ’ MD . -D u r i n g e x e c u t i o n o f t h e 1 s t s t a g e c e m e n t , w e l o s t a r e p o r t e d 1 1 9 b b l s d u r i n g t h e c e m e n t j o b , a l t h o u g h l i f t p r e s s u r e c o n t i n u e d to i n c r e a s e d u r i n g t h e di s p l a c e m e n t ( I C P 5 6 1 p s i , F C P 8 7 8 p s i ) . M a j o r i t y o f l o s s e s o c c u r r e d du r i n g t h e l a s t 1 0 0 b b l s o f d i s p l a c e m e n t . 'O b s e r v a t i o n / C o n c l u s i o n s : 9- 5 / 8 ” I n t e r m e d i a t e 1 L i n e r - F o 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 hy d r o c a r b o n z o n e w i t h i n t h e u p p e r T u l u v a k f o r m a t i o n . 7” I n t e r m e d i a t e 2 L i n e r - F o r t h e 7 ” l i n e r 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 yd r o c a r b o n - b e a r i n g fo r m a t i o n s ( t o p h y 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 1 2 , 5 4 7 ’ 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 N a n u s h u k (t o p o f g o o d c e m e n t a t ~ 1 2 , 3 2 2 ’ ) a n d a n o v e r a l l T O C a t 1 1 , 5 4 5 ’ M D . O u 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 ro c a r b o n - b e a r i n g f o r m a t i o n s in 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 l l a s a d e q u a t e i s o l a t i o n f o r f r 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 ab 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 . 3/ 2 3 / 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 ps i f o r 3 0 m i n . 3, 9 2 5 ' l o g op 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 1 5 , 3 3 2 ' & p a c k e r @ 16 , 8 2 0 ' Ce m e n t J o b E x e c u t i o n : 9- 5 / 8 ” I n t e r m e d i a t e 1 L i n e r : •1 s t s t a g e o f t h e c e m e n t j o b p l a n n e d w i t h 1 5 . 3 p p g t a i l s l u r r y a t 3 0 % e x c e s s , t a r g e t i n g T O C 1 0 0 0 ’ M D a b o v e t h e 9 - 5 / 8 ” s h o e . •D u r i n g e x e c u t i o n o f t h e 1 s t s t a g e c e m e n t , ~ 1 6 3 b b l s o f l o s s e s w e r e s e e n d u r i n g t h e c e m e n t j o b w i t h o n l y ~ 1 4 b b l s l o s t a f t e r c e m e nt e x i t e d t h e s h o e ( g o o d l i f t pr e s s u r e s n o t e d ) . A f t e r d r i l l i n g o u t t h e 9 - 5 / 8 ” s h o e a L O T w a s c o nd u c t e d t o 1 3 . 4 3 p p g . •2 n d S t a g e o f c e m e n t j o b p l a n n e d w i t h C F L E X ~ 5 3 ’ b e l o w t h e T S 7 9 0 . A l s o p l a n n e d w i t h a f u l l 1 5 . 3 p p g t a i l s l u r r y a t 1 0 0 % e x c e s s , t a r g e t i n g T O C a t t h e 9 - 5 / 8 ” li n e r t o p . •D u r i n g e x e c u t i o n o f t h e 2 n d s t a g e c e m e n t , n o l o s s e s w e r e e n c o u n t e r e d a n d w e s a w g o o d l i f t p r e s s u r e . A n e s t i m a t e d 1 0 1 b b l s o f c em e n t w a s o b s e r v e d a t su r f a c e o f f t h e t o p o f l i n e r . 7” I n t e r m e d i a t e 2 L i n e r : •7 ” L i n e r c e m e n t j o b p l a n n e d w i t h a f u l l 1 5 . 3 p p g t a i l s l u r r y a t 3 0 % e x c e s s , t a r g e t i n g T O C 1 0 0 ’ T V D a b o v e t o p o f N a n u s h u k t o 1 3 ,3 0 0 ’ M D . •D u r i n g e x e c u t i o n o f t h e j o b , a t o t a l o f 2 9 0 b b l s o f l o s s e s w e r e n o t e d , w i t h ~ 1 5 0 b b l s a f t e r t h e c e m e n t e x i t e d t h e s h o e . W i t h t h e n e a r - h o r i z o n t a l i n c l i n a t i o n , lo s s e s , a n d c h a n g e s i n d i s p l a c e m e n t r a t e i t w a s d i f f i c u l t t o i d e n t i f y a n y s i g n i f i c a n t i n c r e a s e i n t h e l i f t p r e s s u r e s . A f t e r d r i ll i n g o u t t h e 7 ” s h o e a L O T w a s co n d u c t e d t o 1 3 . 7 8 p p g . Ob s e r v a t i o n s / C o n c l u s i o n s 9- 5 / 8 ” I n t e r m e d i a t e 1 L i n e r : •F o r t h e 1 s t s t a g e o f t h e c e m e n t j o b , b a s e d o n j o b e x e c u t i o n r e s u l t s , c e m e n t i s o l a t i o n w a s a c h i e v e d a c r o s s t h e 9 - 5 / 8 ” s h o e . •F o 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 oc a r b o n z o n e w i t h i n t h e u p p e r Tu l u v a k f o r m a t i o n . 7” I n t e r m e d i a t e 2 L i n e r : •T h e S L B T O C l o g i n d i c a t e s n o c e m e n t d o w n t o 1 5 , 1 4 0 ’ M D w i t h a t r a n s i t i o n t o t h e T O C a t 1 5 , 3 3 2 ’ M D ( 3 , 9 2 5 ’ T V D ) , a n d g o o d c e m e n t b o n d b e l o w t h i s d e p t h do w n t o t h e 7 ” s h o e . 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 ( w i t h i n N T 8 ) h a v e n o t b e e n f u l l y c ov e r e d b y c e m e n t b a s e d o n th e m e a s u r e d T O C a t 1 5 , 3 3 2 ’ M D . 6/ 2 7 / 2 0 2 5 , 9 - 5 / 8 " c a s i n g p r e s s u r e t e s t e d t o 4 , 3 0 0 ps i f o r 3 0 m i n . ND B i - 0 3 6 A C T I V E Li n e r 1 - 9 - 5 / 8 " 47 p p f t o 1 0 , 9 9 5 ' . Li n e r 2 - 7 " 2 6 p p t t o 16 , 8 2 0 ' . 14 , 3 3 1 ' ( N a n u s h u k ) 3 , 7 4 1 ' ( N a n u s h u k ) 1 5 , 3 3 2 ' 1 &Ž ƌ / Ŷ ƚ Ğ ƌ Ŷ Ă ů h Ɛ Ğ Ž Ŷ ů Ǉ ND B - 0 4 0 i s 1 1 2 f t b e l o w N D B i - 0 5 0 ND B - 0 4 0 i s 7 0 8 f t a w a y f r o m N D B - 0 4 8 ND B - 0 4 0 V e r t i c a l S e p a r a t i o 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 2,867” MD x 13-3/8” Casing Shoe at 3,058’ MD x 9-5/8” Archer Cflex Mechanical Stage tool: 6,377’ MD x 9-5/8” Shoe at 9,995’ MD 7” Intermediate 2 Liner x 7” Liner Top at 9,850’ MD x Shoe at 14,921’ MD Geology x Top of Tuluvak Sand Top at 3,793’ MD x Top of Tuluvak TS 790 formation at 6,327’ MD. x Top of the Nanushuk picked at 13,593’ MD. Cement Job Planning/Execution A summary is provided below. See attached cementing reports for additional information. 9-5/8” INT1 Liner 1st Stage Cement Job -1st Stage of cement job planned with a full 15.3 ppg tail slurry at 30% excess, targeting 1,000’ MD above 9-5/8” shoe to ~9,000’ MD. This cement job is not isolating any permeable or hydrocarbon zones. -No issues or losses were encountered running liner and cementing the 1st stage cement job. -A good FIT to 14.0ppg was achieved at the 9-5/8” shoe. -All indications of a successful 1st stage job. 9-5/8” INT1 Liner 2nd Stage Cement Job -2nd Stage of cement job planned with CFLEX ~50’ below the TS790. Also planned with a full 15.3 ppg tail slurry at 100% excess, targeting TOC at the 9-5/8” liner top. This cement job is isolating the hydrocarbon zone within the upper Tuluvak formation. -Opened the CFLEX stage tool at ~6377’ MD and established circulation up to 8 bpm. Pumped the 2 nd stage cement job (~381 bbls). We did lose an estimated 80 bbls during the cement job (toward the end of the job), but observed lift pressure during the job. Closed the CFLEX and set the LTP, then circulated ~50 bbls cement back to surface. -Overall, the cement job met objectives based on job parameters and cement above the liner top. 7” INT2 Liner Cement Job -1st Stage of cement job planned with a full 15.3 ppg tail slurry at 30% excess, targeting 200’ TVD above Top Nanushuk to ~12,590’ MD. Additionally, this well was planned with 160 bbl LVT spacer to be pumped ahead of the cement spacer to further lower cementing ECD. This cement job is isolating hydrocarbons in the Upper Nanushuk. -No issues or losses were encountered running liner and cementing the 1st stage cement job. -An LOT of ~13.1ppg was achieved at the 7” shoe. A SLB Sonic CBL was run on the 6-1/8” drilling BHA – results are discussed below and report is attached. Observations 9-5/8” Intermediate 1 Liner: -For the 1st stage of the cement job, based on job execution results, cement isolation was achieved across the 9-5/8” shoe. -For the 2nd stage of the cement job, based on job execution results, cement isolation was achieved across the hydrocarbon zone within the upper Tuluvak formation. 7” Intermediate 2 Liner: -The SLB Sonic TOC Log indicates there is good cement coverage across and above the Upper Nanushuk formations. Summary as follows: o Top of Partial Cement is 11,667' MD / 3,489' TVD - 1926' MD / 316' TVD above TNAN o Top of Good Cement is 12,486' MD / 3,592' TVD - 1107' MD / 213' TVD above TNAN o Top of Nanushuk is 13,593’ MD / 3,805’ TVD Page 1 of 1 Cement - NDB-040 Surface Casing Cement Surface Casing Cement, Casing, 10/4/2025 06:00 Type Casing Cementing Start Date 10/4/2025 Cementing End Date 10/4/2025 Wellbore Original Hole String Surface Casing, 3,058.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Returns to Surface Cement Evaluation Results Good lift pressure observed. 42 bbls of interface (contaminated) returns and 33 bbls of clean cement returns to surface. 25 bbls losses after cement exited the shoe. Comment Cement 13-3/8” Surface Casing as follows: -Fill lines with 5 water and pressure test to 2,500 psi for 5 minutes: Good test. -Drop 1st Bottom Plug. -Pump 120 bbls of 10.5 ppg Tuned Spacer at 5.0 bpm, 320 psi. -Release 2nd Bottom Plug. -Pump 391 bbls of 11.0 ppg ArcticCem lead cement at 5 bpm, Excess Volume 150% (866 sacks, yield 2.535 cu.ft/sk). -Pump 69 bbls of 15.3 ppg Type I/II tail at 5 bpm, Excess Volume 50% (312 sacks, yield 1.24 cu.ft/sk). -Drop top plug and followed by 20 bbls wash water. -Perform displacement with rig pumps and 9.5 ppg mud. -425 bbls displaced at 2.5-6 bpm: ICP 475 psi 11% return flow, FCP 1,220 psi. -Reduce rate to 2.5 bpm prior to plug bump: Final circulating pressure 1,500 psi prior to plug bump. -Observed cement to surface at 350 bbls into displacement and swapped to take returns down bypass line to cuttings box. After swapping to bypass line, packed off at surface and opened 4" side outlet valve on conductor to take returns to cellar. -Bump plug and increase pressure to 2,000 psi, check floats: Good. -Total displacement volume 425 bbls (measured by strokes at 96% pump efficiency). -42 bbls of interface (contaminated) returns and 33 bbls of clean cement returns to surface. -Total losses from cement exit shoe to cement in place: 25 bbls. -CIP at 11:27 hrs. 1, 0.0-3,058.0ftKB Top Depth (ftKB) 0.0 Bottom Depth (ftKB) 3,058.0 Full Return? No Vol Cement Ret (bbl) 75.0 Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 5 Final Pump Rate (bbl/min) 5 Avg Pump Rate (bbl/min) 5 Final Pump Pressure (psi) 1,500.0 Plug Bump Pressure (psi) 2,000.0 Pipe Reciprocated? No Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Spacer Fluid Type Spacer Fluid Description Tuned Spacer (Add 8lb RED DYE to first 20 bbl) Amount (sacks) Class Volume Pumped (bbl) 120.0 Estimated Top (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 1.82 Mix H20 Ratio (gal/sack) 12.17 Free Water (%) Density (lb/gal) 10.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) CmprStr Time 1 (hr) Lead Fluid Type Lead Fluid Description ArcticCem Lead Amount (sacks) 866 Class Volume Pumped (bbl) 391.0 Estimated Top (ftKB) Percent Excess Pumped (%) 150.0 Yield (ft³/sack) 2.54 Mix H20 Ratio (gal/sack) 12.21 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 23.3 Thickening Time (hr) 13.48 1st Compressive Strength (psi) 500.0 CmprStr Time 1 (hr) 35.98 Tail Fluid Type Tail Fluid Description 15.3ppg Tail Amount (sacks) 312 Class Volume Pumped (bbl) 69.0 Estimated Top (ftKB) Percent Excess Pumped (%) 50.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.66 Free Water (%) Density (lb/gal) 15.30 Plastic Viscosity (cP) 69.8 Thickening Time (hr) 3.78 1st Compressive Strength (psi) 500.0 CmprStr Time 1 (hr) 14.67 Page 1 of 1 Cement - NDB-040 Intermediate #1 1st StageCasing Cement Intermediate #1 1st StageCasing Cement, Casing, 10/11/2025 01:00 Type Casing Cementing Start Date 10/11/2025 Cementing End Date 10/11/2025 Wellbore Original Hole String Intermediate Liner, 9,995.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Cement job parameters / FIT Cement Evaluation Results No losses during cement job and good lift pressure. FIT to 14.0ppg EMW at 9-5/8" shoe. Comment Cement 1st stage 9-5/8" Intermediate liner. -Pump 5 bbls water and Pressure test cement lines to 1,000 psi low 4,000 psi high. -Pump 80 bbl 12.5 ppg Tuned Spacer with Surfactant B and Musol A - (65 gallons each) downhole at 4 bpm with 600-500 psi. -Release bottom pump down dart, chase with 80 bbls of 15.3 ppg Versacem tail cement Type I/II at 4 bpm, initial circulating pressure 675 psi. FCP 530 psi. -Open hole excess volume 30%. -Flush lines with 20 bbl. water to cuttings box. -Release top pump down dart. -Perform displacement with rig pumps and 11.5 ppg MOBM as follows: -572 bbls 11.5 ppg OBM at 4 bpm, ICP 375 psi, FCP 555 psi. (Bottom pump down dart latch up confirmed at 53 bbls displaced). -Pressured up 500 psi over FCP (1,000 psi) and held 5 min, bled off, checked floats. Floats held. -Total displacement volume 570 bbls (measured by strokes at 96% pump efficiency). -CIP at 05:35 hrs. -No losses during cement job and displacement. 1, 8,566.3-10,000.0ftKB Top Depth (ftKB) 8,566.3 Bottom Depth (ftKB) 10,000.0 Full Return? Yes Vol Cement Ret (bbl) 0.0 Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 4 Final Pump Rate (bbl/min) 3 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 500.0 Plug Bump Pressure (psi) 1,000.0 Pipe Reciprocated? No Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Spacer Fluid Type Spacer Fluid Description Mud Flush Spacer with 8# Red Dye, 65 gal Surf B & Musol A Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 2.24 Mix H20 Ratio (gal/sack) 13.09 Free Water (%) Density (lb/gal) 12.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) CmprStr Time 1 (hr) Tail Fluid Type Tail Fluid Description Versacem Amount (sacks) 363 Class I/II Volume Pumped (bbl) 80.0 Estimated Top (ftKB) 9,000.0 Percent Excess Pumped (%) 30.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.56 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) 129.0 Thickening Time (hr) 7.00 1st Compressive Strength (psi) 500.0 CmprStr Time 1 (hr) 12.50 Page 1 of 1 Cement - NDB-040 Intermediate #1 2nd Stage Casing Cement Intermediate #1 2nd Stage Casing Cement, Casing, 10/12/2025 00:30 Type Casing Cementing Start Date 10/12/2025 Cementing End Date 10/12/2025 Wellbore Original Hole String Intermediate Liner, 9,995.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Cement returns circulating off top of liner Cement Evaluation Results Lift pressure observed when pumping cement. 50 bbls of good cement returned to surface when circulating above the liner top after cement job. 80 bbls lost during cement job. Comment Conduct 2nd stage cementing of 9-5/8” 47# Intermediate casing by open hole annulus through Archer cementing tool as follows: -Fill lines with water and test 1,000 psi low, 4,000 psi high. -Mix and pump 80 bbls of 12.5 ppg Mud Flush at bpm, ICP 453 psi, FCP 303 psi. -Mix and pump 80 bbls of 13.5 ppg Tuned Spacer at 4 bpm, ICP 258 psi. FCP 266 psi, 0 bbls lost during spacer pumping. -Mix and pump 381 bbls of 15.3 ppg Versacem Type I-II Tail cement at 4 bpm, ICP 509 psi, Final pump rate 4 bpm, FCP 539 psi. No losses observed. -Excess Volume 100% (1772 sacks, yield 1.236 cu ft/sk) Total volume pumped 381 bbls cement. -Displace with calculated volume of 145 bbls 11.5 ppg OBM using rig pumps to Archer stage collar. -Displace cement with 62 bbls at 4 bpm, 433 psi ICP, 530 psi FCP with full returns. At 668 strokes, began losing returns, slowed to 3 bpm, then 2 bpm with 370 psi and no returns. Maintained 2 bpm to calculated 1,567 calculated strokes, with no returns, 145 bbls total displacement to Archer tool. -80 bbls total losses during cement job. -CIP at 04:45 hrs. - Circulate 50 bbls clean cement off liner top. 2, 2,856.0-6,377.0ftKB Top Depth (ftKB) 2,856.0 Bottom Depth (ftKB) 6,377.0 Full Return? Yes Vol Cement Ret (bbl) 50.0 Top Plug? No Bottom Plug? No Initial Pump Rate (bbl/min) 4 Final Pump Rate (bbl/min) 4 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 525.0 Plug Bump Pressure (psi) Pipe Reciprocated? No Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Mud Flush Spacer Fluid Type Mud Flush Spacer Fluid Description Mud Flush Spacer 8# Red Dye, 65 gal Surf B & Musol A Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 2.22 Mix H20 Ratio (gal/sack) 12.89 Free Water (%) Density (lb/gal) 12.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) CmprStr Time 1 (hr) Tuned Spacer Fluid Type Tuned Spacer Fluid Description Tuned Spacer 4# Red Dye, 65 gal Surf B & Musol A Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 1.91 Mix H20 Ratio (gal/sack) 10.72 Free Water (%) Density (lb/gal) 13.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) CmprStr Time 1 (hr) Tail Fluid Type Tail Fluid Description Versacem Amount (sacks) 1,772 Class I/II Volume Pumped (bbl) 381.0 Estimated Top (ftKB) 2,867.0 Percent Excess Pumped (%) 100.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.57 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) 121.0 Thickening Time (hr) 6.50 1st Compressive Strength (psi) 500.0 CmprStr Time 1 (hr) 18.50 Page 1 of 1 Cement - NDB-040 Intermediate #2 Casing Cement Intermediate #2 Casing Cement, Casing, 10/18/2025 13:30 Type Casing Cementing Start Date 10/18/2025 Cementing End Date 10/18/2025 Wellbore Original Hole String Intermediate 2 Liner, 14,921.0ftKB Cementing Company Halliburton Energy Services Evaluation Method Cement Bond Log Cement Evaluation Results SLB SonicScope TOC Log: - Top of Partial Cement is 11,667' MD / 3,489' TVD - 1926' MD / 316' TVD above TNAN. - Top of Good Cement is 12,486' MD / 3,592' TVD - 1107' MD / 213' TVD above TNAN. - Top of Nanushuk is 13,593' MD / 3,805' TVD. Comment PJSM, Cement 7” Intermediate #2 liner. - Fill lines with water and pressure test to 4,000 psi for 5 min. - Pump 160 bbls LVT at 4 bpm, 540 psi. - Pump 80 bbls of 12.5 ppg Tuned Spacer at 3.8 bpm, 625 psi. - Release bottom Pump down plug. - Pump 148 bbls of 15.3 ppg Type I/II Versacem tail at 3.7 bpm, Excess Volume 30% (998 sacks, yield 1.238 cu.ft/sk). - Wash up lines to cuttings box with 20 bbls water. - Release top pump down plug. - Perform displacement with rig pumps at 4 bpm. ICP 269 psi. FCP 950 psi with 330 bbls away. Reduce rate to 3 bpm, 718 psi to land plug at 346 bbls displacement. - Bump plug with 1,150 psi and hold for 5 mins. - Both pump down darts and liner wiper plugs landed on calculated strokes. - CIP at 17:11 hrs. - Floats held, 3.1 bbls bled back - 0 bbls lost during cement job. 1, 12,590.0-9,871.0ftKB Top Depth (ftKB) 12,590.0 Bottom Depth (ftKB) 9,871.0 Full Return? No Vol Cement Ret (bbl) 0.0 Top Plug? Yes Bottom Plug? Yes Initial Pump Rate (bbl/min) 4 Final Pump Rate (bbl/min) 3 Avg Pump Rate (bbl/min) 4 Final Pump Pressure (psi) 718.0 Plug Bump Pressure (psi) 1,150.0 Pipe Reciprocated? No Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Tuned Spacer Fluid Type Tuned Spacer Fluid Description Tuned Spacer 4# Red Dye, 65 gal Surf B & Musol A Amount (sacks) Class Volume Pumped (bbl) 80.0 Estimated Top (ftKB) Percent Excess Pumped (%) Yield (ft³/sack) 2.24 Mix H20 Ratio (gal/sack) 13.09 Free Water (%) Density (lb/gal) 12.50 Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi) CmprStr Time 1 (hr) Tail Fluid Type Tail Fluid Description Versacem (Type I/II ) Amount (sacks) 998 Class I/II Volume Pumped (bbl) 148.0 Estimated Top (ftKB) 13,991.0 Percent Excess Pumped (%) 30.0 Yield (ft³/sack) 1.24 Mix H20 Ratio (gal/sack) 5.57 Free Water (%) 0.00 Density (lb/gal) 15.30 Plastic Viscosity (cP) 117.8 Thickening Time (hr) 8.00 1st Compressive Strength (psi) 500.0 CmprStr Time 1 (hr) 14.00 Attachment D Attachment E Attachment F We l l N a m e ND B - 0 4 0 10 / 3 1 / 2 5 D r a f t 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 U s a b l e J 7 5 3 En c a p s . # 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 W a t e r B r e a k e r Br e a k e r 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 ) 1 3 4 1 0 ( g / M g a l ) ( # / M g a l ) a FP b FP 13 4 1 0 26 c WF 2 6 3. 5 40 40 16 8 0 16 8 0 40 40 1 3 3 7 0 d P u m p C h e c k WF 26 4 0 40 0 44 0 16 8 0 0 18 4 8 0 40 0 44 0 1 2 9 7 0 36 0 44 0 1 2 9 7 0 0 0 eD F I T XL 26 4 0 25 0 69 0 1 0 5 0 0 2 8 9 8 0 2 5 0 6 9 0 1 2 7 2 0 2 6 f WF 26 4 0 35 0 10 4 0 1 4 7 0 0 4 3 6 8 0 3 5 0 1 0 4 0 1 2 3 7 0 2 6 0 1 0 4 0 1 2 3 7 0 0 0 0 1 0 4 0 1 2 3 7 0 0 0 FL U I D Ne a t W a t e r SD m o n i t o r 2 0 m i n 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 - I n i t i a t e P - S l e e v e Di s p l a c e P T - S h u t d o w n 5 m i n SD m o n i t o r 2 H , l i n e u p f o r F P w i t h L R S Pa d t o 4 p p a Gr e a t e r t h a n 4 p p a DF I T D i s p a c e m e n t t o P s l e e v e We l l N a m e ND B - 0 4 0 10 / 3 0 / 2 5 D r a f t 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 25 0 30 0 10 5 0 0 12 6 0 0 25 0 30 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 0 16 8 0 1 6 8 0 0 0 4 0 3 4 0 2 0 Dr o p S t a g e 1 B a l l / C o l l e t F P 0 18 3 43 4 3 12 6 1 8 0 6 00 CS G - I V 3 3 4 3 3 0 St a g e 1 P A D XL 2 6 40 3 1 5 35 8 3 5 8 13 2 3 0 1 5 0 3 6 0 0 3 1 5 6 5 8 4 0 Sl o w f o r S e a t X L 2 6 18 50 40 8 4 0 8 21 0 0 1 7 1 3 6 0 0 5 0 7 0 8 5 0 Re s u m e P a d XL 2 6 40 6 0 46 8 4 6 8 25 2 0 1 9 6 5 6 0 0 6 0 7 6 8 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 3 5 9 3 52 5 0 2 4 9 0 6 50 2 7 5 0 2 7 CS G - I V 12 0 8 8 8 7 2 Fl a t XL 2 6 40 1 4 0 73 3 7 3 3 58 8 0 3 0 7 8 6 10 8 0 1 1 5 8 2 8 CS G - I V 12 9 1 0 1 6 8 3 Fl a t XL 2 6 40 1 7 0 90 3 9 0 3 71 4 0 3 7 9 2 6 18 9 0 2 3 4 7 3 0 CS G - I V 15 0 1 1 6 6 9 4 Fl a t XL 2 6 40 1 7 0 10 7 3 1 0 7 3 71 4 0 4 5 0 6 6 24 2 5 2 5 8 9 8 2 CS G - I V 14 4 1 3 1 1 10 5 Fl a t XL 2 6 40 1 7 0 12 4 3 1 2 4 3 71 4 0 5 2 2 0 6 29 2 1 4 8 8 1 9 6 CS G - I V 13 9 1 4 5 0 11 6 Fl a t XL 2 6 40 1 7 0 14 1 3 1 4 1 3 71 4 0 5 9 3 4 6 33 8 2 7 1 2 2 0 2 3 CS G - I V 13 4 1 5 8 4 12 7 Fl a t XL 2 6 40 1 4 0 15 5 3 1 5 5 3 58 8 0 6 5 2 2 6 31 4 0 0 1 5 3 4 2 3 CS G - I V 10 7 1 6 9 1 13 8 Fl a t XL 2 6 40 1 2 5 16 7 8 1 6 7 8 52 5 0 7 0 4 7 6 30 9 9 1 1 8 4 4 1 4 CS G - I V 92 1 7 8 3 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 3 1 6 9 3 63 0 7 1 1 0 6 0 1 8 4 4 1 4 1 5 1 7 9 8 15 0 Sp a c e r X L 2 6 40 15 17 0 8 1 7 0 8 63 0 7 1 7 3 6 0 1 8 4 4 1 4 1 5 1 8 1 3 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 1 1 7 1 1 12 6 7 1 8 6 2 0 1 8 4 4 1 4 3 1 8 1 6 17 0 St a g e 2 P A D XL 2 6 40 3 0 6 20 1 7 2 0 1 7 12 8 5 2 8 4 7 1 4 0 1 8 4 4 1 4 3 0 6 2 1 2 2 18 0 Sl o w f o r S e a t X L 2 6 18 50 20 6 7 2 0 6 7 21 0 0 8 6 8 1 4 0 1 8 4 4 1 4 5 0 2 1 7 2 19 0 Re s u m e P a d XL 2 6 40 9 4 21 6 1 2 1 6 1 39 4 8 9 0 7 6 2 0 1 8 4 4 1 4 9 4 2 2 6 6 20 1 Fl a t XL 2 6 40 1 6 5 23 2 6 2 3 2 6 69 3 0 9 7 6 9 2 66 3 5 1 9 1 0 4 9 CS G - I V 15 8 2 4 2 4 21 2 Fl a t XL 2 6 40 1 8 0 25 0 6 2 5 0 6 75 6 0 1 0 5 2 5 2 13 8 8 7 2 0 4 9 3 6 CS G - I V 16 5 2 5 8 9 22 3 Fl a t XL 2 6 40 1 9 5 27 0 1 2 7 0 1 81 9 0 1 1 3 4 4 2 21 6 8 2 2 2 6 6 1 7 CS G - I V 17 2 2 7 6 1 23 4 Fl a t XL 2 6 40 1 9 5 28 9 6 2 8 9 6 81 9 0 1 2 1 6 3 2 27 8 1 9 2 5 4 4 3 6 CS G - I V 16 6 2 9 2 7 24 5 Fl a t XL 2 6 40 1 9 5 30 9 1 3 0 9 1 81 9 0 1 2 9 8 2 2 33 5 1 0 2 8 7 9 4 6 CS G - I V 16 0 3 0 8 7 25 6 Fl a t XL 2 6 40 1 9 5 32 8 6 3 2 8 6 81 9 0 1 3 8 0 1 2 38 8 0 2 3 2 6 7 4 8 CS G - I V 15 4 3 2 4 1 26 7 Fl a t XL 2 6 40 1 8 5 34 7 1 3 4 7 1 77 7 0 1 4 5 7 8 2 41 4 9 3 3 6 8 2 4 1 CS G - I V 14 1 3 3 8 2 27 8 Fl a t XL 2 6 40 1 7 0 36 4 1 3 6 4 1 71 4 0 1 5 2 9 2 2 42 1 4 8 4 1 0 3 8 8 CS G - I V 12 5 3 5 0 7 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 6 3 6 5 6 63 0 1 5 3 5 5 2 0 4 1 0 3 8 8 1 5 3 5 2 2 29 0 Sp a c e r X L 2 6 40 15 36 7 1 3 6 7 1 63 0 1 5 4 1 8 2 0 4 1 0 3 8 8 1 5 3 5 3 7 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 4 3 6 7 4 12 6 1 5 4 3 0 8 0 4 1 0 3 8 8 3 3 5 4 0 31 0 St a g e 3 P A D XL 2 6 40 2 9 5 39 6 9 3 9 6 9 12 3 9 0 1 6 6 6 9 8 0 4 1 0 3 8 8 2 9 5 3 8 3 5 32 0 Sl o w f o r S e a t X L 2 6 18 50 40 1 9 4 0 1 9 21 0 0 1 6 8 7 9 8 0 4 1 0 3 8 8 5 0 3 8 8 5 33 0 Re s u m e P a d XL 2 6 40 1 40 2 0 4 0 2 0 42 1 6 8 8 4 0 0 4 1 0 3 8 8 1 3 8 8 6 34 1 Sc o u r XL 2 6 40 6 0 40 8 0 4 0 8 0 25 2 0 1 7 1 3 6 0 24 1 3 4 1 2 8 0 2 40 / 7 0 - C L 57 3 9 4 4 35 3 Sc o u r XL 2 6 40 1 2 0 42 0 0 4 2 0 0 50 4 0 1 7 6 4 0 0 13 3 4 8 4 2 6 1 5 0 40 / 7 0 - C L 10 6 4 0 5 0 FL U I D Ne a t W a t e r CO M M E N T S En s u r e S t a g e 1 b a l l / c o l l e t i s l o a d e d Pr i m e a n d P r e s s u r e T e s t Op e n w e l l - D i s p l a c e P T We l l N a m e ND B - 0 4 0 10 / 3 0 / 2 5 D r a f t 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 36 0 Re s u m e P a d XL 2 6 40 5 0 42 5 0 4 2 5 0 21 0 0 1 7 8 5 0 0 0 4 2 6 1 5 0 5 0 4 1 0 0 37 1 Fl a t XL 2 6 40 2 0 0 44 5 0 4 4 5 0 84 0 0 1 8 6 9 0 0 80 4 3 4 3 4 1 9 3 CS G - I V 19 1 4 2 9 1 38 2 Fl a t XL 2 6 40 2 2 5 46 7 5 4 6 7 5 94 5 0 1 9 6 3 5 0 17 3 5 8 4 5 1 5 5 1 CS G - I V 20 7 4 4 9 8 39 4 Fl a t XL 2 6 40 2 7 5 49 5 0 4 9 5 0 11 5 5 0 2 0 7 9 0 0 39 2 3 2 4 9 0 7 8 3 CS G - I V 23 4 4 7 3 1 40 6 Fl a t XL 2 6 40 2 6 0 52 1 0 5 2 1 0 10 9 2 0 2 1 8 8 2 0 51 7 3 6 5 4 2 5 1 9 CS G - I V 20 5 4 9 3 6 41 8 Fl a t XL 2 6 40 2 4 0 54 5 0 5 4 5 0 10 0 8 0 2 2 8 9 0 0 59 5 0 2 6 0 2 0 2 1 CS G - I V 17 7 5 1 1 4 42 10 Fl a t XL 2 6 40 2 0 0 56 5 0 5 6 5 0 84 0 0 2 3 7 3 0 0 58 1 7 0 6 6 0 1 9 1 CS G - I V 13 8 5 2 5 2 43 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 56 6 5 5 6 6 5 63 0 2 3 7 9 3 0 0 6 6 0 1 9 1 1 5 5 2 6 7 44 0 Sp a c e r X L 2 6 40 15 56 8 0 5 6 8 0 63 0 2 3 8 5 6 0 0 6 6 0 1 9 1 1 5 5 2 8 2 45 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 8 3 5 6 8 3 12 6 2 3 8 6 8 6 0 6 6 0 1 9 1 3 5 2 8 5 46 0 St a g e 4 P A D XL 2 6 40 2 9 0 59 7 3 5 9 7 3 12 1 8 0 2 5 0 8 6 6 0 6 6 0 1 9 1 2 9 0 5 5 7 5 47 0 Sl o w f o r S e a t X L 2 6 18 50 60 2 3 6 0 2 3 21 0 0 2 5 2 9 6 6 0 6 6 0 1 9 1 5 0 5 6 2 5 48 0 Re s u m e P a d XL 2 6 40 1 60 2 4 6 0 2 4 42 2 5 3 0 0 8 0 6 6 0 1 9 1 1 5 6 2 6 49 1 Sc o u r XL 2 6 40 6 0 60 8 4 6 0 8 4 25 2 0 2 5 5 5 2 8 24 1 3 6 6 2 6 0 4 40 / 7 0 - C L 57 5 6 8 4 50 3 Sc o u r XL 2 6 40 1 2 0 62 0 4 6 2 0 4 50 4 0 2 6 0 5 6 8 13 3 4 8 6 7 5 9 5 2 40 / 7 0 - C L 10 6 5 7 8 9 51 0 Re s u m e P a d XL 2 6 40 5 0 62 5 4 6 2 5 4 21 0 0 2 6 2 6 6 8 0 6 7 5 9 5 2 5 0 5 8 3 9 52 1 Fl a t XL 2 6 40 2 0 0 64 5 4 6 4 5 4 84 0 0 2 7 1 0 6 8 80 4 3 6 8 3 9 9 5 CS G - I V 19 1 6 0 3 1 53 2 Fl a t XL 2 6 40 2 2 5 66 7 9 6 6 7 9 94 5 0 2 8 0 5 1 8 17 3 5 8 7 0 1 3 5 3 CS G - I V 20 7 6 2 3 8 54 4 Fl a t XL 2 6 40 2 7 5 69 5 4 6 9 5 4 11 5 5 0 2 9 2 0 6 8 39 2 3 2 7 4 0 5 8 5 CS G - I V 23 4 6 4 7 1 55 6 Fl a t XL 2 6 40 2 6 0 72 1 4 7 2 1 4 10 9 2 0 3 0 2 9 8 8 51 7 3 6 7 9 2 3 2 1 CS G - I V 20 5 6 6 7 6 56 8 Fl a t XL 2 6 40 2 4 0 74 5 4 7 4 5 4 10 0 8 0 3 1 3 0 6 8 59 5 0 2 8 5 1 8 2 3 CS G - I V 17 7 6 8 5 4 57 10 Fl a t XL 2 6 40 2 0 0 76 5 4 7 6 5 4 84 0 0 3 2 1 4 6 8 58 1 7 0 9 0 9 9 9 3 CS G - I V 13 8 6 9 9 2 58 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 76 6 9 7 6 6 9 63 0 3 2 2 0 9 8 0 9 0 9 9 9 3 1 5 7 0 0 7 59 0 Sp a c e r X L 2 6 40 15 76 8 4 7 6 8 4 63 0 3 2 2 7 2 8 0 9 0 9 9 9 3 1 5 7 0 2 2 60 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 8 7 7 6 8 7 12 6 3 2 2 8 5 4 0 9 0 9 9 9 3 3 7 0 2 5 61 0 St a g e 5 P A D XL 2 6 40 2 8 1 79 6 8 7 9 6 8 11 8 0 2 3 3 4 6 5 6 0 9 0 9 9 9 3 2 8 1 7 3 0 6 62 0 Sl o w f o r S e a t X L 2 6 18 50 80 1 8 8 0 1 8 21 0 0 3 3 6 7 5 6 0 9 0 9 9 9 3 5 0 7 3 5 6 63 0 Re s u m e P a d XL 2 6 40 1 80 1 9 8 0 1 9 42 3 3 6 7 9 8 0 9 0 9 9 9 3 1 7 3 5 7 64 1 Sc o u r XL 2 6 40 6 0 80 7 9 8 0 7 9 25 2 0 3 3 9 3 1 8 24 1 3 9 1 2 4 0 6 40 / 7 0 - C L 57 7 4 1 4 65 3 Sc o u r XL 2 6 40 1 2 0 81 9 9 8 1 9 9 50 4 0 3 4 4 3 5 8 13 3 4 8 9 2 5 7 5 5 40 / 7 0 - C L 10 6 7 5 2 0 66 0 Fl a t XL 2 6 40 5 0 82 4 9 8 2 4 9 21 0 0 3 4 6 4 5 8 0 9 2 5 7 5 5 5 0 7 5 7 0 67 1 Fl a t XL 2 6 40 2 0 0 84 4 9 8 4 4 9 84 0 0 3 5 4 8 5 8 80 4 3 9 3 3 7 9 7 CS G - I V 19 1 7 7 6 2 68 2 Fl a t XL 2 6 40 2 2 5 86 7 4 8 6 7 4 94 5 0 3 6 4 3 0 8 17 3 5 8 9 5 1 1 5 6 CS G - I V 20 7 7 9 6 9 69 4 Fl a t XL 2 6 40 2 7 5 89 4 9 8 9 4 9 11 5 5 0 3 7 5 8 5 8 39 2 3 2 9 9 0 3 8 7 CS G - I V 23 4 8 2 0 2 70 6 Fl a t XL 2 6 40 2 6 0 92 0 9 9 2 0 9 10 9 2 0 3 8 6 7 7 8 51 7 3 6 1 0 4 2 1 2 3 CS G - I V 20 5 8 4 0 7 71 8 Fl a t XL 2 6 40 2 4 0 94 4 9 9 4 4 9 10 0 8 0 3 9 6 8 5 8 59 5 0 2 1 1 0 1 6 2 6 CS G - I V 17 7 8 5 8 4 72 10 Fl a t XL 2 6 40 2 0 0 96 4 9 9 6 4 9 84 0 0 4 0 5 2 5 8 58 1 7 0 1 1 5 9 7 9 6 CS G - I V 13 8 8 7 2 3 73 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 96 6 4 9 6 6 4 63 0 4 0 5 8 8 8 0 1 1 5 9 7 9 6 1 5 8 7 3 8 74 0 Sp a c e r X L 2 6 40 15 96 7 9 9 6 7 9 63 0 4 0 6 5 1 8 0 1 1 5 9 7 9 6 1 5 8 7 5 3 75 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 8 2 9 6 8 2 12 6 4 0 6 6 4 4 0 1 1 5 9 7 9 6 3 8 7 5 6 76 0 St a g e 6 P A D XL 2 6 40 2 7 2 99 5 4 9 9 5 4 11 4 2 4 4 1 8 0 6 8 0 1 1 5 9 7 9 6 2 7 2 9 0 2 8 77 0 Sl o w f o r S e a t X L 2 6 18 50 10 0 0 4 1 0 0 0 4 21 0 0 4 2 0 1 6 8 0 1 1 5 9 7 9 6 5 0 9 0 7 8 78 0 Re s u m e P a d XL 2 6 40 1 10 0 0 5 1 0 0 0 5 42 4 2 0 2 1 0 0 1 1 5 9 7 9 6 1 9 0 7 9 We l l N a m e ND B - 0 4 0 10 / 3 0 / 2 5 D r a f t 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 79 1 Sc o u r XL 2 6 40 6 0 10 0 6 5 1 0 0 6 5 25 2 0 4 2 2 7 3 0 24 1 3 1 1 6 2 2 0 9 40 / 7 0 - C L 57 9 1 3 6 80 3 Sc o u r XL 2 6 40 1 2 0 10 1 8 5 1 0 1 8 5 50 4 0 4 2 7 7 7 0 13 3 4 8 1 1 7 5 5 5 7 40 / 7 0 - C L 10 6 92 4 2 81 0 Fl a t XL 2 6 40 5 0 10 2 3 5 1 0 2 3 5 21 0 0 4 2 9 8 7 0 0 1 1 7 5 5 5 7 5 0 92 9 2 71 1 Fl a t XL 2 6 40 2 0 0 94 0 9 9 4 0 9 84 0 0 3 9 5 1 7 8 80 4 3 1 0 5 0 1 6 6 CS G - I V 19 1 94 8 4 72 2 Fl a t XL 2 6 40 2 2 5 96 3 4 9 6 3 4 94 5 0 4 0 4 6 2 8 17 3 5 8 1 0 6 7 5 2 5 CS G - I V 20 7 96 9 1 73 4 Fl a t XL 2 6 40 2 7 5 99 0 9 9 9 0 9 11 5 5 0 4 1 6 1 7 8 39 2 3 2 1 1 0 6 7 5 6 CS G - I V 23 4 99 2 4 74 6 Fl a t XL 2 6 40 2 6 0 10 1 6 9 1 0 1 6 9 10 9 2 0 4 2 7 0 9 8 51 7 3 6 1 1 5 8 4 9 2 CS G - I V 20 5 10 1 2 9 75 8 Fl a t XL 2 6 40 2 4 0 10 4 0 9 1 0 4 0 9 10 0 8 0 4 3 7 1 7 8 59 5 0 2 1 2 1 7 9 9 5 CS G - I V 17 7 10 3 0 6 76 10 Fl a t XL 2 6 40 2 0 0 10 6 0 9 1 0 6 0 9 84 0 0 4 4 5 5 7 8 58 1 7 0 1 2 7 6 1 6 4 CS G - I V 13 8 10 4 4 5 77 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 10 6 2 4 1 0 6 2 4 63 0 4 4 6 2 0 8 0 1 2 7 6 1 6 4 1 5 10 4 6 0 78 0 Sp a c e r X L 2 6 40 15 10 6 3 9 1 0 6 3 9 63 0 4 4 6 8 3 8 0 1 2 7 6 1 6 4 1 5 10 4 7 5 79 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 10 6 4 2 1 0 6 4 2 12 6 4 4 6 9 6 4 0 1 2 7 6 1 6 4 3 10 4 7 8 80 0 St a g e 7 P A D XL 2 6 40 2 9 4 10 9 3 6 1 0 9 3 6 12 3 4 8 4 5 9 3 1 2 0 1 2 7 6 1 6 4 2 9 4 10 7 7 2 81 0 Sl o w f o r s e a t ( X L D F I T ) XL 26 18 50 10 9 8 6 1 0 9 8 6 21 0 0 4 6 1 4 1 2 0 1 2 7 6 1 6 4 5 0 10 8 2 2 82 0 Re s u m e P a d XL 2 6 40 5 4 10 2 8 9 1 0 2 8 9 22 6 8 4 3 2 1 3 8 0 1 1 7 5 5 5 7 5 4 10 8 7 6 83 1 Fl a t XL 2 6 40 1 9 0 10 4 7 9 1 0 4 7 9 79 8 0 4 4 0 1 1 8 76 4 1 1 1 8 3 1 9 8 CS G - I V 18 2 11 0 5 8 84 3 Fl a t XL 2 6 40 2 1 5 10 6 9 4 1 0 6 9 4 90 3 0 4 4 9 1 4 8 23 9 0 5 1 2 0 7 1 0 3 CS G - I V 19 0 11 2 4 8 85 5 Fl a t XL 2 6 40 2 4 0 10 9 3 4 1 0 9 3 4 10 0 8 0 4 5 9 2 2 8 41 2 4 3 1 2 4 8 3 4 6 CS G - I V 19 6 11 4 4 4 86 7 Fl a t XL 2 6 40 2 4 0 11 1 7 4 1 1 1 7 4 10 0 8 0 4 6 9 3 0 8 53 8 2 8 1 3 0 2 1 7 4 CS G - I V 18 3 11 6 2 7 87 9 Fl a t XL 2 6 40 2 2 0 11 3 9 4 1 1 3 9 4 92 4 0 4 7 8 5 4 8 59 4 1 5 1 3 6 1 5 8 9 CS G - I V 15 7 11 7 8 4 88 11 Fl a t XL 2 6 40 1 9 0 11 5 8 4 1 1 5 8 4 79 8 0 4 8 6 5 2 8 58 9 7 4 1 4 2 0 5 6 3 CS G - I V 12 8 11 9 1 2 89 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 11 5 9 9 1 1 5 9 9 63 0 4 8 7 1 5 8 0 1 4 2 0 5 6 3 1 5 11 9 2 7 90 0 Sp a c e r X L 2 6 40 15 11 6 1 4 1 1 6 1 4 63 0 4 8 7 7 8 8 0 1 4 2 0 5 6 3 1 5 11 9 4 2 91 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 11 6 1 7 1 1 6 1 7 12 6 4 8 7 9 1 4 0 1 4 2 0 5 6 3 3 11 9 4 5 92 0 XL F l u s h ( D F I T ) XL 2 6 40 2 6 4 11 8 8 1 1 1 8 8 1 11 0 8 8 4 9 9 0 0 2 0 1 4 2 0 5 6 3 2 6 4 12 2 0 9 93 0 Sl o w f o r s e a t ( X L D F I T ) XL 26 18 50 11 9 3 1 1 1 9 3 1 21 0 0 5 0 1 1 0 2 0 1 4 2 0 5 6 3 5 0 1 2 2 5 9 94 DF I T F l u s h WF 2 6 40 23 0 1 3 9 3 8 1 2 1 6 1 96 6 0 5 9 7 9 9 6 23 0 1 2 4 8 9 95 30 0 0 f e e t M D + S u r f a c e E q m t FP 20 7 0 14 0 0 8 1 2 2 3 1 29 4 9 6 0 0 9 4 5 TO T A L S 14 3 0 8 60 0 9 4 5 16 5 4 6 0 4 We l l N a m e ND B - 0 4 0 10 / 3 0 / 2 5 D r a f t 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 40 40 c WF 2 6 1. 0 0 0 16 8 0 0 40 d WF 26 3 . 5 28 5 32 5 1 1 9 7 0 1 3 6 5 0 2 8 5 3 2 5 e P u m p C h e c k WF 26 4 0 50 37 5 2 1 0 0 1 5 7 5 0 5 0 3 7 5 0 3 7 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 1 5 16 8 0 1 7 4 3 0 0 0 4 0 4 1 5 2 0 St a g e 8 P A D XL 2 6 40 4 0 0 44 0 8 1 5 16 8 0 0 3 4 2 3 0 00 CS G - I V 40 0 8 1 5 3 1 Fl a t XL 2 6 40 1 8 0 62 0 9 9 5 75 6 0 4 1 7 9 0 72 3 9 7 2 3 9 CS G - I V 17 2 9 8 7 4 2 Fl a t XL 2 6 40 1 8 0 80 0 1 1 7 5 75 6 0 4 9 3 5 0 13 8 8 7 2 1 1 2 5 CS G - I V 16 5 1 1 5 3 5 4 Fl a t XL 2 6 40 2 0 0 10 0 0 1 3 7 5 84 0 0 5 7 7 5 0 28 5 3 2 4 9 6 5 7 CS G - I V 17 0 1 3 2 2 6 6 Fl a t XL 2 6 40 2 0 0 12 0 0 1 5 7 5 84 0 0 6 6 1 5 0 39 7 9 7 8 9 4 5 4 CS G - I V 15 8 1 4 8 0 7 8 Fl a t XL 2 6 40 2 0 0 14 0 0 1 7 7 5 84 0 0 7 4 5 5 0 49 5 8 5 1 3 9 0 4 0 CS G - I V 14 8 1 6 2 8 8 10 Fl a t XL 2 6 40 2 0 0 16 0 0 1 9 7 5 84 0 0 8 2 9 5 0 58 1 7 0 1 9 7 2 0 9 CS G - I V 13 8 1 7 6 6 9 12 Fl a t XL 2 6 40 1 7 5 17 7 5 2 1 5 0 73 5 0 9 0 3 0 0 57 5 4 0 2 5 4 7 4 9 CS G - I V 11 4 1 8 8 1 10 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 17 9 0 2 1 6 5 63 0 9 0 9 3 0 0 2 5 4 7 4 9 1 5 1 8 9 6 11 0 Sp a c e r X L 2 6 40 15 18 0 5 2 1 8 0 63 0 9 1 5 6 0 0 2 5 4 7 4 9 1 5 1 9 1 1 12 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 18 0 8 2 1 8 3 12 6 9 1 6 8 6 0 2 5 4 7 4 9 3 1 9 1 4 13 0 St a g e 9 P A D XL 2 6 40 2 4 5 20 5 3 2 4 2 8 10 2 9 0 1 0 1 9 7 6 0 2 5 4 7 4 9 2 4 5 2 1 5 9 14 0 Sl o w f o r S e a t X L 2 6 18 50 21 0 3 2 4 7 8 21 0 0 1 0 4 0 7 6 0 2 5 4 7 4 9 5 0 2 2 0 9 15 0 Re s u m e P a d XL 2 6 40 9 0 21 9 3 2 5 6 8 37 8 0 1 0 7 8 5 6 0 2 5 4 7 4 9 9 0 2 2 9 9 16 1 Fl a t XL 2 6 40 1 9 0 23 8 3 2 7 5 8 79 8 0 1 1 5 8 3 6 76 4 1 2 6 2 3 9 0 CS G - I V 18 2 2 4 8 1 17 3 Fl a t XL 2 6 40 2 1 5 25 9 8 2 9 7 3 90 3 0 1 2 4 8 6 6 23 9 0 5 2 8 6 2 9 5 CS G - I V 19 0 2 6 7 0 18 5 Fl a t XL 2 6 40 2 4 0 28 3 8 3 2 1 3 10 0 8 0 1 3 4 9 4 6 41 2 4 3 3 2 7 5 3 8 CS G - I V 19 6 2 8 6 7 19 7 Fl a t XL 2 6 40 2 4 0 30 7 8 3 4 5 3 10 0 8 0 1 4 5 0 2 6 53 8 2 8 3 8 1 3 6 6 CS G - I V 18 3 3 0 5 0 20 9 Fl a t XL 2 6 40 2 2 0 32 9 8 3 6 7 3 92 4 0 1 5 4 2 6 6 59 4 1 5 4 4 0 7 8 1 CS G - I V 15 7 3 2 0 7 21 11 Fl a t XL 2 6 40 1 9 0 34 8 8 3 8 6 3 79 8 0 1 6 2 2 4 6 58 9 7 4 4 9 9 7 5 5 CS G - I V 12 8 3 3 3 5 22 0 Cl e a r S u r f a c e L i n e s XL 2 6 40 1 5 35 0 3 3 8 7 8 63 0 1 6 2 8 7 6 0 4 9 9 7 5 5 1 5 3 3 5 0 23 0 Sp a c e r X L 2 6 40 15 35 1 8 3 8 9 3 63 0 1 6 3 5 0 6 0 4 9 9 7 5 5 1 5 3 3 6 5 24 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 35 2 1 3 8 9 6 12 6 1 6 3 6 3 2 0 4 9 9 7 5 5 3 3 3 6 8 25 0 St a g e 1 0 P A D XL 2 6 40 2 3 7 37 5 8 4 1 3 3 99 5 4 1 7 3 5 8 6 0 4 9 9 7 5 5 2 3 7 3 6 0 5 26 0 Sl o w f o r S e a t X L 2 6 18 50 38 0 8 4 1 8 3 21 0 0 1 7 5 6 8 6 0 4 9 9 7 5 5 5 0 3 6 5 5 27 0 Re s u m e P a d XL 2 6 45 1 1 3 39 2 1 4 2 9 6 47 4 6 1 8 0 4 3 2 0 4 9 9 7 5 5 1 1 3 3 7 6 8 28 1 Fl a t XL 2 6 45 1 8 0 41 0 1 4 4 7 6 75 6 0 1 8 7 9 9 2 72 3 9 5 0 6 9 9 4 CS G - I V 17 2 3 9 4 0 29 2 Fl a t XL 2 6 45 1 8 0 42 8 1 4 6 5 6 75 6 0 1 9 5 5 5 2 13 8 8 7 5 2 0 8 8 1 CS G - I V 16 5 4 1 0 5 30 4 Fl a t XL 2 6 45 2 0 0 44 8 1 4 8 5 6 84 0 0 2 0 3 9 5 2 28 5 3 2 5 4 9 4 1 3 CS G - I V 17 0 4 2 7 5 31 6 Fl a t XL 2 6 45 2 0 0 46 8 1 5 0 5 6 84 0 0 2 1 2 3 5 2 39 7 9 7 5 8 9 2 1 0 CS G - I V 15 8 4 4 3 3 32 8 Fl a t XL 2 6 45 2 0 0 48 8 1 5 2 5 6 84 0 0 2 2 0 7 5 2 49 5 8 5 6 3 8 7 9 5 CS G - I V 14 8 4 5 8 1 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 4 0 10 / 3 0 / 2 5 D r a f t 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 10 Fl a t XL 2 6 45 2 0 0 50 8 1 5 4 5 6 84 0 0 2 2 9 1 5 2 58 1 7 0 6 9 6 9 6 5 CS G - I V 13 8 4 7 1 9 34 12 Fl a t XL 2 6 45 1 7 5 52 5 6 5 6 3 1 73 5 0 2 3 6 5 0 2 57 5 4 0 7 5 4 5 0 4 CS G - I V 11 4 4 8 3 3 35 0 Cl e a r S u r f a c e L i n e s XL 2 6 45 1 5 52 7 1 5 6 4 6 63 0 2 3 7 1 3 2 0 7 5 4 5 0 4 1 5 4 8 4 8 36 0 Sp a c e r X L 2 6 45 15 52 8 6 5 6 6 1 63 0 2 3 7 7 6 2 0 7 5 4 5 0 4 1 5 4 8 6 3 37 0 Dr o p S t a g e 1 1 B a l l / C o l l e t F P 0 45 3 52 8 9 5 6 6 4 12 6 2 3 7 8 8 8 0 7 5 4 5 0 4 3 4 8 6 6 38 0 St a g e 1 1 P A D XL 2 6 45 2 2 9 55 1 8 5 8 9 3 96 1 8 2 4 7 5 0 6 0 7 5 4 5 0 4 2 2 9 5 0 9 5 39 0 Sl o w f o r S e a t X L 2 6 18 50 55 6 8 5 9 4 3 21 0 0 2 4 9 6 0 6 0 7 5 4 5 0 4 5 0 5 1 4 5 40 0 Re s u m e P a d XL 2 6 45 1 4 6 57 1 4 6 0 8 9 61 3 2 2 5 5 7 3 8 0 7 5 4 5 0 4 1 4 6 5 2 9 1 41 1 Fl a t XL 2 6 45 1 9 0 59 0 4 6 2 7 9 79 8 0 2 6 3 7 1 8 76 4 1 7 6 2 1 4 5 CS G - I V 18 2 5 4 7 3 42 2 Fl a t XL 2 6 45 2 1 0 61 1 4 6 4 8 9 88 2 0 2 7 2 5 3 8 16 2 0 1 7 7 8 3 4 6 CS G - I V 19 3 5 6 6 6 43 4 Fl a t XL 2 6 45 2 2 5 63 3 9 6 7 1 4 94 5 0 0 32 0 9 9 8 1 0 4 4 5 CS G - I V 19 1 5 8 5 7 44 6 Fl a t XL 2 6 45 2 2 5 65 6 4 6 9 3 9 94 5 0 9 4 5 0 44 7 7 2 8 5 5 2 1 6 CS G - I V 17 8 6 0 3 5 45 8 Fl a t XL 2 6 45 2 2 5 67 8 9 7 1 6 4 94 5 0 1 8 9 0 0 55 7 8 3 9 1 1 0 0 0 CS G - I V 16 6 6 2 0 1 46 10 Fl a t XL 2 6 45 2 1 0 69 9 9 7 3 7 4 88 2 0 2 7 7 2 0 61 0 7 8 9 7 2 0 7 8 CS G - I V 14 5 6 3 4 6 47 12 Fl a t XL 2 6 45 1 8 5 71 8 4 7 5 5 9 77 7 0 3 5 4 9 0 60 8 2 7 1 0 3 2 9 0 6 CS G - I V 12 1 6 4 6 7 48 0 Cl e a r S u r f a c e L i n e s XL 2 6 45 1 5 71 9 9 7 5 7 4 63 0 0 0 1 0 3 2 9 0 6 1 5 6 4 8 2 49 0 Sp a c e r X L 2 6 45 15 72 1 4 7 5 8 9 63 0 6 3 0 0 1 0 3 2 9 0 6 1 5 6 4 9 7 50 0 Dr o p S t a g e 1 2 B a l l / C o l l e t F P 0 45 3 72 1 7 7 5 9 2 12 6 7 5 6 0 1 0 3 2 9 0 6 3 6 5 0 0 51 0 St a g e 1 2 P A D XL 2 6 45 2 2 1 74 3 8 7 8 1 3 92 8 2 1 0 0 3 8 0 1 0 3 2 9 0 6 2 2 1 6 7 2 1 52 0 Sl o w f o r S e a t X L 2 6 18 50 74 8 8 7 8 6 3 21 0 0 1 2 1 3 8 0 1 0 3 2 9 0 6 5 0 6 7 7 1 53 0 Re s u m e P a d XL 2 6 45 1 5 4 76 4 2 8 0 1 7 64 6 8 1 8 6 0 6 0 1 0 3 2 9 0 6 1 5 4 6 9 2 5 54 1 Fl a t XL 2 6 45 2 2 5 78 6 7 8 2 4 2 94 5 0 2 8 0 5 6 90 4 8 1 0 4 1 9 5 4 CS G - I V 21 5 7 1 4 0 55 2 Fl a t XL 2 6 45 2 4 0 81 0 7 8 4 8 2 10 0 8 0 3 8 1 3 6 18 5 1 6 1 0 6 0 4 6 9 CS G - I V 22 0 7 3 6 1 56 4 Fl a t XL 2 6 45 2 6 0 83 6 7 8 7 4 2 10 9 2 0 4 9 0 5 6 37 0 9 2 1 0 9 7 5 6 1 CS G - I V 22 1 7 5 8 2 57 6 Fl a t XL 2 6 45 2 6 0 86 2 7 9 0 0 2 10 9 2 0 5 9 9 7 6 51 7 3 6 1 1 4 9 2 9 7 CS G - I V 20 5 7 7 8 7 58 8 Fl a t XL 2 6 45 2 1 0 88 3 7 9 2 1 2 88 2 0 6 8 7 9 6 52 0 6 5 1 2 0 1 3 6 2 CS G - I V 15 5 7 9 4 2 59 8 Fl a t XL 2 6 45 4 0 88 7 7 9 2 5 2 16 8 0 7 0 4 7 6 99 2 6 1 2 1 1 2 8 8 12 / 1 8 - C L 30 7 9 7 1 60 10 Fl a t XL 2 6 45 2 1 0 90 8 7 9 4 6 2 88 2 0 7 9 2 9 6 61 1 4 5 1 2 7 2 4 3 3 12 / 1 8 - C L 14 6 8 1 1 7 61 0 Cl e a r S u r f a c e L i n e s XL 2 6 45 1 5 91 0 2 9 4 7 7 63 0 7 9 9 2 6 0 1 2 7 2 4 3 3 1 5 8 1 3 2 62 0 Sp a c e r X L 2 6 45 15 91 1 7 9 4 9 2 63 0 8 0 5 5 6 0 1 2 7 2 4 3 3 1 5 8 1 4 7 63 0 Dr o p S t a g e 1 3 B a l l / C o l l e t F P 0 45 3 91 2 0 9 4 9 5 12 6 8 0 6 8 2 0 1 2 7 2 4 3 3 3 8 1 5 0 64 0 St a g e 1 3 P A D XL 2 6 45 2 1 2 93 3 2 9 7 0 7 89 0 4 8 9 5 8 6 0 1 2 7 2 4 3 3 2 1 2 8 3 6 2 65 0 Sl o w f o r S e a t X L 2 6 18 50 93 8 2 9 7 5 7 21 0 0 9 1 6 8 6 0 1 2 7 2 4 3 3 5 0 8 4 1 2 66 0 Re s u m e P a d XL 2 6 45 1 8 8 95 7 0 9 9 4 5 78 9 6 9 9 5 8 2 0 1 2 7 2 4 3 3 1 8 8 8 6 0 0 67 1 Fl a t XL 2 6 45 2 5 0 98 2 0 1 0 1 9 5 10 5 0 0 1 1 0 0 8 2 10 0 5 4 1 2 8 2 4 8 6 CS G - I V 23 9 8 8 3 9 68 2 Fl a t XL 2 6 45 2 8 0 10 1 0 0 1 0 4 7 5 11 7 6 0 1 2 1 8 4 2 21 6 0 2 1 3 0 4 0 8 8 CS G - I V 25 7 9 0 9 7 69 4 Fl a t XL 2 6 45 2 8 0 10 3 8 0 1 0 7 5 5 11 7 6 0 1 3 3 6 0 2 39 9 4 5 1 3 4 4 0 3 3 CS G - I V 23 8 9 3 3 4 70 6 Fl a t XL 2 6 45 2 8 0 10 6 6 0 1 1 0 3 5 11 7 6 0 1 4 5 3 6 2 55 7 1 6 1 3 9 9 7 4 9 CS G - I V 22 1 9 5 5 5 71 8 Fl a t XL 2 6 45 2 2 0 10 8 8 0 1 1 2 5 5 92 4 0 1 5 4 6 0 2 54 5 4 4 1 4 5 4 2 9 2 CS G - I V 16 2 9 7 1 8 72 8 Fl a t XL 2 6 45 4 0 10 9 2 0 1 1 2 9 5 16 8 0 1 5 6 2 8 2 99 2 6 1 4 6 4 2 1 9 12 / 1 8 - C L 30 9 7 4 7 73 10 Fl a t XL 2 6 45 2 2 0 11 1 4 0 1 1 5 1 5 92 4 0 1 6 5 5 2 2 64 0 5 6 1 5 2 8 2 7 5 12 / 1 8 - C L 15 3 9 9 0 0 74 0 Cl e a r S u r f a c e L i n e s XL 2 6 45 1 5 11 1 5 5 1 1 5 3 0 63 0 1 6 6 1 5 2 0 1 5 2 8 2 7 5 1 5 9 9 1 5 75 0 Sp a c e r X L 2 6 45 15 11 1 7 0 1 1 5 4 5 63 0 1 6 6 7 8 2 0 1 5 2 8 2 7 5 1 5 9 9 3 0 We l l N a m e ND B - 0 4 0 10 / 3 0 / 2 5 D r a f t 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 Dr o p S t a g e 1 4 B a l l / C o l l e t F P 0 45 3 11 1 7 3 1 1 5 4 8 12 6 1 6 6 9 0 8 0 1 5 2 8 2 7 5 3 9 9 3 3 77 0 St a g e 1 4 P A D XL 2 6 45 2 0 3 11 3 7 6 1 1 7 5 1 85 2 6 1 7 5 4 3 4 0 1 5 2 8 2 7 5 2 0 3 10 1 3 6 78 0 Sl o w f o r S e a t X L 2 6 18 50 11 4 2 6 1 1 8 0 1 21 0 0 1 7 7 5 3 4 0 1 5 2 8 2 7 5 5 0 10 1 8 6 79 0 Re s u m e P a d XL 2 6 45 1 4 7 11 5 7 3 1 1 9 4 8 61 7 4 1 8 3 7 0 8 0 1 5 2 8 2 7 5 1 4 7 10 3 3 3 80 1 Fl a t XL 2 6 45 2 0 5 11 7 7 8 1 2 1 5 3 86 1 0 1 9 2 3 1 8 82 4 4 1 5 3 6 5 1 9 CS G - I V 19 6 10 5 2 9 81 3 Fl a t XL 2 6 45 2 0 5 11 9 8 3 1 2 3 5 8 86 1 0 2 0 0 9 2 8 22 7 9 4 1 5 5 9 3 1 3 CS G - I V 18 1 10 7 1 0 82 5 Fl a t XL 2 6 45 2 8 0 12 2 6 3 1 2 6 3 8 11 7 6 0 2 1 2 6 8 8 48 1 1 7 1 6 0 7 4 2 9 CS G - I V 22 9 10 9 3 9 83 7 Fl a t XL 2 6 45 2 5 5 12 5 1 8 1 2 8 9 3 10 7 1 0 2 2 3 3 9 8 57 1 9 3 1 6 6 4 6 2 2 CS G - I V 19 5 11 1 3 4 84 9 Fl a t XL 2 6 45 2 5 5 12 7 7 3 1 3 1 4 8 10 7 1 0 2 3 4 1 0 8 68 8 6 7 1 7 3 3 4 9 0 CS G - I V 18 2 11 3 1 6 85 10 Fl a t XL 2 6 45 2 2 5 12 9 9 8 1 3 3 7 3 94 5 0 2 4 3 5 5 8 65 5 1 2 1 7 9 9 0 0 2 12 / 1 8 - C L 15 6 1 1 4 7 2 86 XL F l u s h XL 2 6 45 20 1 3 0 1 8 1 3 3 9 3 84 0 5 6 0 8 2 6 20 1 1 4 9 2 87 LG F l u s h WF 2 6 45 16 0 1 3 1 7 8 1 3 5 5 3 67 2 0 5 6 7 5 4 6 16 0 1 1 6 5 2 88 30 0 0 f e e t M D + S u r f a c e E q m t FP 20 7 0 13 2 4 8 1 3 6 2 3 29 4 9 5 7 0 4 9 5 TO T A L S 13 5 8 3 57 0 4 9 5 17 9 9 0 0 2 Additive Additive Description D206 Antifoam Agent 0.0 Gal/mGal 5.0 gal F103 Surfactant 1.0 Gal/mGal 1,014.0 gal J450 Stabilizing Agent 0.5 Gal/mGal 485.0 gal J475 Breaker J475 6.0 lb/mGal 6,084.0 lbm J511 Stabilizing Agent 1.9 lb/mGal 1,938.0 lbm J532 Crosslinker 2.4 Gal/mGal 2,423.0 gal J580 Gel J580 26.0 lb/mGal 26,362.0 lbm J753 Enzyme Breaker J753 0.1 Gal/mGal 73.0 gal M002 Additive 0.0 lb/mGal 1.0 lbm M117 Clay Control Agent 338.9 lb/mGal 343,649.0 lbm M275 Bactericide 0.3 lb/mGal 304.0 lbm S522-1620 Propping Agent varied concentrations 2,989,200.0 lbm S522-4070 Propping Agent varied concentrations 63,044.0 lbm S522-1218 Propping Agent varied concentrations 210,565.0 lbm S901-1620 Proppant with Scale Inhibitor S901- 1620 varied concentrations 133,560.0 lbm S902-1620 Proppant with Scale Inhibitor S902- 16/20 varied concentrations 57,240.0 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 % State: Alaska County/Parish: North Slope Borough Case: Client: Oil Search Alaska Well: PIKKA NDB-040 Basin/Field: Pikka Fluid Name & Volume Concentration Volume Disclosure Type: Pre-Job Well Completed: Date Prepared: 11/3/2025 CAS Number Chemical Name Mass Fraction - Water (Including Mix Water Supplied by Client)* YF126ST:WF126 1,013,922 gal † Proprietary Technology The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. 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 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 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 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 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 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 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 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 # SLB-Private Page: 1 / 1 Up d a t e d 1 0 / 3 0 / 2 0 2 5 10 / 3 0 / 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 T r a c e r c o C a r r i e r F l u i d S o y M e th y l E s t e r 6 7 7 8 4 - 8 0 - 9 1 0 0 # V A L U E ! 1 4 8 . 5 9 1 3 8 8 0 0 0 0 T- 1 6 0 B T r a c e r c o C h e m i c a l T r a c e r 3 , 5 - D i b r o m o to l u e n e 1 6 1 1 - 9 2 - 3 1 0 0 # V A L U E ! 1 . 1 0 2 3 1 0 0 0 0 0 T- 1 6 0 C T r a c e r c o C h e m i c a l T r a c e r 2 ,4 , 6 - T r i b r o m o t o l ue n e 6 3 2 0 - 4 0 - 7 1 0 0 #V A L U E ! 0 . 44 0 9 2 4 0 0 0 0 T- 1 6 1 B T r a c e r c o C h e m i c a l T r a c e r 4 - I o d ot o l u e n e 6 2 4 - 3 1 - 7 10 0 # V A L U E ! 0. 4 4 0 9 2 4 0 0 0 0 T- 1 6 2 A T r a c e r c o C h e m i c a l T r a c e r 1 , 4- D i b r o m o b e n z e n e 1 0 6 - 3 7 - 6 1 0 0 # V A L U E ! 1 . 1 0 2 3 1 0 0 0 0 0 T- 1 6 4 B T r a c e r c o C h e m i c a l T r a c e r 2 - B r o m o n a p h th a l e n e 5 8 0 - 1 3 - 2 10 0 # V A L U E ! 1. 1 0 2 3 1 0 0 0 0 0 T- 1 6 4 C T r a c e r c o C h e m i c a l T r a c e r 1 - I o d o n a p h t ha l e n e 9 0 - 1 4 - 2 1 0 0 # V A L U E ! 0 . 4 4 0 9 2 4 0 0 0 0 T- 1 6 5 B T r a c e r c o C h e m i c a l T r a c e r 2 - I o d o b i ph e n y l 2 1 1 3 - 5 1 - 1 1 0 0 # V A L U E ! 0 . 4 4 0 9 2 4 0 0 0 0 T- 1 6 5 C T r a c e r c o C h e m i c a l T r a c e r 9 - B r o m o p h en a n t h r e n e 5 7 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 6 C T r a c e r c o C h e m i c a l T r a c e r 1 - I o d o - 3 , 4 - di m e t h y l b e n z e n e 31 5 9 9 - 6 1 - 8 1 0 0 # V A L U E ! 1 . 1 0 2 3 1 0 0 0 0 0 T- 7 1 6 T r a c e r c o C h e m i c a l T r a c e r 1 , 3 , 5 - T r ib r o m o b e n z e n e 6 2 6 - 3 9 - 1 1 0 0 # V A L U E ! 0 . 4 4 0 9 2 4 0 0 0 0 T- 7 3 1 T r a c e r c o C h 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 ne 1 9 7 5 2 - 5 5 - 7 1 0 0 #V A L U E ! 0 . 44 0 9 2 4 0 0 0 0 T- 7 3 4 T r a c e r c o C h e m i c a l T r a c e r 1 - B r o m o - 2 - (t r i f l u o r o m e t h y l ) b e n z e n e 39 2 - 8 3 - 6 1 0 0 #V A L U E ! 0. 6 6 1 3 8 6 0 0 0 0 T- 1 6 8 C T r a c e r c o C h e m i c a l T r a c e r 1 - B r o m o - 4 - i o d ob e n z e n e 5 8 9 - 8 7 - 7 1 0 0 # V A L U E ! 0 . 4 4 0 9 2 4 0 0 0 0 T- 7 5 0 T r a c e r c o C h e m i c a l T r a c e r 1 , 4 - D i b r o m o - 2 -f l u o r o b e n z e n e 1 4 3 5 - 5 2 - 5 1 0 0 # V A L U E ! 0 . 4 4 0 9 2 4 0 0 0 0 T- 7 2 1 T r a c e r c o S o l i d 4 , 4 ' - D i c h l o r o b e n z o p h e n o n e 9 0 - 9 8 - 2 1 0 0 # V A L U E ! 0 . 4 4 0 9 2 4 0 0 0 0 T- 7 2 9 T r a c e r c o S o 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 ne 1 0 7 4 - 2 4 - 4 1 0 0 # V A L U E ! 2 . 2 0 4 6 2 0 0 0 0 0 T- 7 5 1 T r a c e r c o S o l i d B i s ( 4 - b r o m o ph e n y l ) e t h e r 2 0 5 0 - 4 7 - 7 10 0 # V A L U E ! 1 . 5 4 3 2 3 4 0 0 0 0 Wa t e r T r a c e r c o C a r r i e r F l u i d W at e r 7 7 3 2 - 1 8 - 5 1 0 0 #V A L U E ! 1 13 . 5 6 1 0 4 8 8 6 0 0 T- 9 4 3 T r a c e r c o C h 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 - me t h y l b e n z o a t e 17 0 8 9 4 2 - 1 7 - 9 10 0 # V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 4 0 C T r a c e r c o C h e m i c a l T r a c e r S o d i u m - 4 - F l u o ro b e n z o a t e 4 9 9 - 9 0 - 1 1 0 0 # V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 1 5 8 B T r a c e r c o C h e m i c a l T r a c e r S o d i um - 2 , 5 - D i f l u o r o b e n z o a t e 5 2 2 6 5 1 - 4 2 - 9 1 0 0 # V A L U E ! 0 . 7 7 1 6 1 7 0 0 0 0 T- 1 5 8 F T r a c e r c o C h e m i c a l Tr a c e r S o d i u m - 2 , 3 - D if l u o r o b e n z o at e 1 6 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 4 5 T r a c e r c o C h e m i c a l T r a c e r So d i u m - 4 - c h l o r o - 2 - me t h y l b e n z o a t e 20 3 2 6 1 - 4 2 - 1 10 0 # V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 1 0 T r a c e r c o C h e m i c a l T r a c e r S o di u m - 2 - c h l o r o - 3 - f l u o r o b e n z o at e 1 3 8 2 1 0 6 - 8 3 - 3 1 0 0 # V A L U E ! 0 . 7 7 1 6 1 7 0 0 0 0 T- 9 1 4 T r a c e r c o C h e m i c a l T r a c e r S o 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 1 4 2 1 7 6 1 - 1 6 - 1 1 0 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 1 6 T r a c e r c o C h e m i c a l T r a c e r S o 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 1 3 9 6 7 6 2 - 3 4 - 7 1 0 0 #V A L U E ! 0. 7 7 1 6 1 7 0 0 0 0 T- 9 1 9 T r a c e r c o C h e m i c a l T r a c e r S o di u m - 4 - c h l o r o - 3 - f l u o r o b e n z o at e 1 4 2 1 0 2 9 - 8 8 - 0 1 0 0 # V A L U E ! 0 . 7 7 3 8 2 1 6 2 0 0 T- 9 2 0 T r a c e r c o C h e m i c a l T r a c e r S o di u m - 5 - c h l o r o - 2 - f l u o r o b e n z o at e 1 3 8 2 1 0 6 - 7 8 - 6 1 0 0 # V A L U E ! 0 . 7 7 6 0 2 6 2 4 0 0 T- 9 2 7 T r a c e r c o C h e m i c a l T r a c e r S o di u m - 2 - f l u o r o - 3 - m e t h y l b e n z o a te 1 7 0 8 9 4 2 - 1 8 - 0 1 0 0 # V A L U E ! 0 . 7 7 8 2 3 0 8 6 0 0 T- 9 2 9 T r a c e r c o C h e m i c a l T r a c e r S o di u m - 3 - f l u o r o - 2 - m e t h y l b e n z o a te 1 7 0 8 9 4 2 - 2 4 - 8 1 0 0 # V A L U E ! 0 . 7 8 0 4 3 5 4 8 0 0 T- 1 5 8 A T r a c e r c o C h e m i c a l Tr a c e r S o d i u m - 2 , 4 - D if l u o r o b e n z o at e 1 7 6 5 - 0 8 - 8 10 0 # V A L U E ! 0. 7 8 2 6 4 0 1 0 0 0 T- 9 5 0 T r a c e r c o C h e m i c a l T r a c e r S o d i um - 2 - f l u o r o - 3 - ( T r i f lu o r o m e t h y l ) - b e n z oa t e 1 7 0 1 4 4 6 - 4 1 - 4 1 0 0 #V A L U E ! 0 . 77 6 0 2 6 2 4 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 4 0 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 Attachment G NDB-040 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-040 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-040 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-040 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 (planned). (Post rig move, pressure test to 4,300 psi for 30 minutes (Planned)) 15.MIT-T to 3,500 psi for 30 minutes on rig (Planned). (Post rig move, pressure test to 5,500 psi for 30 minutes (Planned)) a. Post rig more pressure test criteria: (8,800 psi MAWP – 3,800 psi IA hold) * 1.1 = 5,500 psi tubing 16.Nipple down BOP stack and install 10k frac tree. 17.RDMO Attachment I Attachment J Tuluvak Sand @ 3,793' MD Top Nan 3.2 @14,979' MD Top Nanushuk @13,593' NDB-040 Well Schematic As-Built 20" Insulated Conductor128' MD 20" Insulated Conductor128' MD 9-5/8" Liner Hanger and Liner Top Packer 2,867' MD 9-5/8" Liner Hanger and Liner Top Packer 2,867' MD 13-3/8" 68 ppf L-80 Surface Casing 3,058' MD 13-3/8" 68 ppf L-80 Surface Casing 3,058' MD 4-½”, 12.6ppf P-110S Production Liner22,854' MD 4-½”, 12.6ppf P-110S Production Liner22,854' MD 4-½” Liner Hanger/Top Packer14,715' MD 4-½” Liner Hanger/Top Packer14,715' MD GL 69.8' RKB – Bottom Flange 11/04/2025 7" Tieback9,850' MD 7" Tieback9,850' MD 9-5/8" Cflex Stage Tool (50' MD below TS790)6,377' MD 9-5/8" Cflex Stage Tool (50' MD below TS790)6,377' MD 7" TOC (Sonic CBL)12,486' MD 7" TOC (Sonic CBL)12,486' MD 7", 26ppf L-80 Production Liner14,921' MD 7", 26ppf L-80 Production Liner14,921' MD 9-5/8", 47ppf L-80 Intermediate Liner 9,995' MD 9-5/8", 47ppf L-80 Intermediate Liner 9,995' MD 9-5/8" Primary TOC (1000' MD above shoe) 8,995' MD 9-5/8" Primary TOC (1000' MD above shoe) 8,995' MD 7" Liner Hanger and Liner Top Packer 9,850' MD 7" Liner Hanger and Liner Top Packer 9,850' MD 13 67 68 8-½” Openhole TD22,871' MD 8-½” Openhole TD22,871' MD 6664 17 21 25 29 33 37 41 45 49 53 57 61 65 9 7 6 5 4 3 2 1 6362605958565554525150484746444342403938363534323130282726242322201918161514 1211 10 7" x 9-5/8" Tieback X-over2,800' MD 7" x 9-5/8" Tieback X-over2,800' MD # Completion Item Top Depth (MD') Depth (TVD') Inc ID" OD" 1 X Landing Nipple 1388 1350 24 3.813 5.201 2 Gaslift Mandrel 1.5" 2277 2050 52 3.865 7.640 3 X Landing Nipple 2348 2100 54 3.813 5.201 4 D/H Psi-Temp Gauge 14460 4012 77 3.864 5.830 5 EGL Valve 14565 4035 77 3.958 5.900 6 Tieback Seal Assy (No-Go) 14715 4060 77 3.860 5.190 7 7" x 4.5" LH/Packer 14715 4060 77 5.000 5.960 8 #16 Openhole Packer 14999 4125 79 3.898 5.750 9 #15 Openhole Packer 15064 4140 81 3.898 5.750 10 #28 Tracer Carrier 15244 4160 86 3.958 5.875 11 Stg 14 - Collet Sleeve 14 15296 4162 86 3.735 5.634 12 #27 Tracer Carrier 15310 4164 87 3.958 5.875 13 #14 Openhole Packer 15609 4165 90 3.898 5.750 14 #26 Tracer Carrier 15831 4164 90 3.958 5.875 15 Stg 13 - Collet Sleeve 13 15882 4164 90 3.735 5.634 16 #25 Tracer Carrier 15896 4163 91 3.958 5.875 17 #13 Openhole Packer 16071 4160 91 3.898 5.750 18 #24 Tracer Carrier 16416 4157 91 3.958 5.875 19 Stg 12 - Collet Sleeve 12 16466 4157 91 3.735 5.634 20 #23 Tracer Carrier 16481 4157 91 3.958 5.875 21 #12 Openhole Packer 16739 4154 91 3.898 5.750 22 #22 Tracer Carrier 16961 4151 91 3.958 5.875 23 Stg 11 - Collet Sleeve 11 17012 4151 91 3.735 5.634 24 #21 Tracer Carrier 17026 4151 91 3.958 5.875 25 #11 Openhole Packer 17282 4150 91 3.898 5.750 26 #20 Tracer Carrier 17503 4146 91 3.958 5.875 27 Stg 10 - Collet Sleeve 10 17554 4146 91 3.735 5.634 28 #19 Tracer Carrier 17568 4146 91 3.958 5.875 29 #10 Openhole Packer 17866 4144 91 3.898 5.750 30 #18 Tracer Carrier 18004 4141 90 3.958 5.875 31 Stg 9 - Collet Sleeve 9 18055 4141 90 3.735 5.634 32 #17 Tracer Carrier 18069 4141 90 3.958 5.875 33 #9 Openhole Packer 18410 4138 91 3.898 5.750 34 #16 Tracer Carrier 18633 4136 91 3.958 5.875 35 Stg 8- Collet Sleeve 8 18684 4135 91 3.735 5.634 36 #15 Tracer Carrier 18698 4135 91 3.958 5.875 37 #8 Openhole Packer 18956 4132 91 3.898 5.750 38 #14 Tracer Carrier 19219 4130 91 3.958 5.875 39 Stg 7 - Collet Sleeve 7 19271 4129 91 3.735 5.634 40 #13 Tracer Carrier 19285 4129 91 3.958 5.875 41 #7 Openhole Packer 19543 4127 91 3.898 5.750 42 #12 Tracer Carrier 19765 4125 91 3.958 5.875 43 Stg 6- Collet Sleeve 6 19816 4124 91 3.735 5.634 44 #11 Tracer Carrier 19830 4124 91 3.958 5.875 45 #6 Openhole Packer 20082 4122 91 3.898 5.750 46 #10 Tracer Carrier 20343 4119 90 3.958 5.875 47 Stg 5 - Collet Sleeve 5 20395 4118 90 3.735 5.634 48 #9 Tracer Carrier 20408 4118 90 3.958 5.875 49 #5 Openhole Packer 20665 4116 91 3.898 5.750 50 #8 Tracer Carrier 20886 4114 91 3.958 5.875 51 Stg 4 - Collet Sleeve 4 20937 4113 91 3.735 5.634 52 #7 Tracer Carrier 20951 4113 91 3.958 5.875 53 #4 Openhole Packer 21210 4111 91 3.898 5.750 54 #6 Tracer Carrier 21431 4108 91 3.958 5.875 55 Stg 3 - Collet Sleeve 3 21483 4108 91 3.735 5.634 56 #5 Tracer Carrier 21497 4107 91 3.958 5.875 57 #3 Openhole Packer 21796 4105 91 3.898 5.750 58 #4 Tracer Carrier 22018 4102 91 3.958 5.875 59 Stg 2 - Collet Sleeve 2 22070 4102 91 3.735 5.634 60 #3 Tracer Carrier 22083 4102 91 3.958 5.875 61 #2 Openhole Packer 22341 4099 91 3.898 5.750 62 #2 Tracer Carrier 22562 4097 91 3.958 5.875 63 Stg 1 - Collet Sleeve 1 22613 4096 91 3.735 5.634 64 #1 Tracer Carrier 22627 4096 91 3.958 5.875 65 #1 Openhole Packer 22719 4095 91 3.898 5.750 66 Toe Sleeve 22826 4094 91 3.500 5.750 67 WIV Collar 22839 4093 91 0.875 5.620 68 Eccentric shoe 22852 4093 91 3.840 5.200 8 Tuluvak Sand @ 3,793' MD Top Nan 3.2 @14,979' MD Top Nanushuk @13,593' NDB-040 Well Schematic As-Built 20" Insulated Conductor128' MD 20" Insulated Conductor128' MD 9-5/8" Liner Hanger and Liner Top Packer 2,867' MD 9-5/8" Liner Hanger and Liner Top Packer 2,867' MD 13-3/8" 68 ppf L-80 Surface Casing 3,058' MD 13-3/8" 68 ppf L-80 Surface Casing 3,058' MD 4-½”, 12.6ppf P-110S Production Liner22,854' MD 4-½”, 12.6ppf P-110S Production Liner22,854' MD 4-½” Liner Hanger/Top Packer14,715' MD 4-½” Liner Hanger/Top Packer14,715' MD GL 69.8' RKB – Bottom Flange 11/04/2025 7" Tieback9,850' MD 7" Tieback9,850' MD 9-5/8" Cflex Stage Tool (50' MD below TS790)6,377' MD 9-5/8" Cflex Stage Tool (50' MD below TS790)6,377' MD 7" TOC (Sonic CBL)12,486' MD 7" TOC (Sonic CBL)12,486' MD 7", 26ppf L-80 Production Liner14,921' MD 7", 26ppf L-80 Production Liner14,921' MD 9-5/8", 47ppf L-80 Intermediate Liner 9,995' MD 9-5/8", 47ppf L-80 Intermediate Liner 9,995' MD 9-5/8" Primary TOC (1000' MD above shoe) 8,995' MD 9-5/8" Primary TOC (1000' MD above shoe) 8,995' MD 7" Liner Hanger and Liner Top Packer 9,850' MD 7" Liner Hanger and Liner Top Packer 9,850' MD 13 67 68 8-½” Openhole TD22,871' MD 8-½” Openhole TD22,871' MD 6664 17 21 25 29 33 37 41 45 49 53 57 61 65 9 7 6 5 4 3 2 1 6362605958565554525150484746444342403938363534323130282726242322201918161514 1211 10 7" x 9-5/8" Tieback X-over2,800' MD 7" x 9-5/8" Tieback X-over2,800' MD # Completion Item Top Depth (MD') Depth (TVD') Inc ID" OD" 1 X Landing Nipple 1388 1350 24 3.813 5.201 2 Gaslift Mandrel 1.5" 2277 2050 52 3.865 7.640 3 X Landing Nipple 2348 2100 54 3.813 5.201 4 D/H Psi-Temp Gauge 14460 4012 77 3.864 5.830 5 EGL Valve 14565 4035 77 3.958 5.900 6 Tieback Seal Assy (No-Go) 14715 4060 77 3.860 5.190 7 7" x 4.5" LH/Packer 14715 4060 77 5.000 5.960 8 #16 Openhole Packer 14999 4125 79 3.898 5.750 9 #15 Openhole Packer 15064 4140 81 3.898 5.750 10 #28 Tracer Carrier 15244 4160 86 3.958 5.875 11 Stg 14 - Collet Sleeve 14 15296 4162 86 3.735 5.634 12 #27 Tracer Carrier 15310 4164 87 3.958 5.875 13 #14 Openhole Packer 15609 4165 90 3.898 5.750 14 #26 Tracer Carrier 15831 4164 90 3.958 5.875 15 Stg 13 - Collet Sleeve 13 15882 4164 90 3.735 5.634 16 #25 Tracer Carrier 15896 4163 91 3.958 5.875 17 #13 Openhole Packer 16071 4160 91 3.898 5.750 18 #24 Tracer Carrier 16416 4157 91 3.958 5.875 19 Stg 12 - Collet Sleeve 12 16466 4157 91 3.735 5.634 20 #23 Tracer Carrier 16481 4157 91 3.958 5.875 21 #12 Openhole Packer 16739 4154 91 3.898 5.750 22 #22 Tracer Carrier 16961 4151 91 3.958 5.875 23 Stg 11 - Collet Sleeve 11 17012 4151 91 3.735 5.634 24 #21 Tracer Carrier 17026 4151 91 3.958 5.875 25 #11 Openhole Packer 17282 4150 91 3.898 5.750 26 #20 Tracer Carrier 17503 4146 91 3.958 5.875 27 Stg 10 - Collet Sleeve 10 17554 4146 91 3.735 5.634 28 #19 Tracer Carrier 17568 4146 91 3.958 5.875 29 #10 Openhole Packer 17866 4144 91 3.898 5.750 30 #18 Tracer Carrier 18004 4141 90 3.958 5.875 31 Stg 9 - Collet Sleeve 9 18055 4141 90 3.735 5.634 32 #17 Tracer Carrier 18069 4141 90 3.958 5.875 33 #9 Openhole Packer 18410 4138 91 3.898 5.750 34 #16 Tracer Carrier 18633 4136 91 3.958 5.875 35 Stg 8- Collet Sleeve 8 18684 4135 91 3.735 5.634 36 #15 Tracer Carrier 18698 4135 91 3.958 5.875 37 #8 Openhole Packer 18956 4132 91 3.898 5.750 38 #14 Tracer Carrier 19219 4130 91 3.958 5.875 39 Stg 7 - Collet Sleeve 7 19271 4129 91 3.735 5.634 40 #13 Tracer Carrier 19285 4129 91 3.958 5.875 41 #7 Openhole Packer 19543 4127 91 3.898 5.750 42 #12 Tracer Carrier 19765 4125 91 3.958 5.875 43 Stg 6- Collet Sleeve 6 19816 4124 91 3.735 5.634 44 #11 Tracer Carrier 19830 4124 91 3.958 5.875 45 #6 Openhole Packer 20082 4122 91 3.898 5.750 46 #10 Tracer Carrier 20343 4119 90 3.958 5.875 47 Stg 5 - Collet Sleeve 5 20395 4118 90 3.735 5.634 48 #9 Tracer Carrier 20408 4118 90 3.958 5.875 49 #5 Openhole Packer 20665 4116 91 3.898 5.750 50 #8 Tracer Carrier 20886 4114 91 3.958 5.875 51 Stg 4 - Collet Sleeve 4 20937 4113 91 3.735 5.634 52 #7 Tracer Carrier 20951 4113 91 3.958 5.875 53 #4 Openhole Packer 21210 4111 91 3.898 5.750 54 #6 Tracer Carrier 21431 4108 91 3.958 5.875 55 Stg 3 - Collet Sleeve 3 21483 4108 91 3.735 5.634 56 #5 Tracer Carrier 21497 4107 91 3.958 5.875 57 #3 Openhole Packer 21796 4105 91 3.898 5.750 58 #4 Tracer Carrier 22018 4102 91 3.958 5.875 59 Stg 2 - Collet Sleeve 2 22070 4102 91 3.735 5.634 60 #3 Tracer Carrier 22083 4102 91 3.958 5.875 61 #2 Openhole Packer 22341 4099 91 3.898 5.750 62 #2 Tracer Carrier 22562 4097 91 3.958 5.875 63 Stg 1 - Collet Sleeve 1 22613 4096 91 3.735 5.634 64 #1 Tracer Carrier 22627 4096 91 3.958 5.875 65 #1 Openhole Packer 22719 4095 91 3.898 5.750 66 Toe Sleeve 22826 4094 91 3.500 5.750 67 WIV Collar 22839 4093 91 0.875 5.620 68 Eccentric shoe 22852 4093 91 3.840 5.200 8 Attachment K Kinetix-Frac Completion Report Santos Country:United States Well Name:NDB-040 Operator:Santos Field:Pikka Formation:Nanushuk Prepared By: Javier M. Del Real Report Date:November 3, 2025 Table of Contents Well Description ......................................................................................................................................................................................... 4 Stage 1 ....................................................................................................................................................................................................... 5 Zoneset Simulated: ................................................................................................................................................................................ 5 Pumping Schedule Simulated: ............................................................................................................................................................... 8 Simulation Summary: ........................................................................................................................................................................... 10 Stage 2 ..................................................................................................................................................................................................... 11 Zoneset Simulated: .............................................................................................................................................................................. 11 Pumping Schedule Simulated: ............................................................................................................................................................. 15 Simulation Summary: ........................................................................................................................................................................... 16 Stage 3 ..................................................................................................................................................................................................... 17 Zoneset Simulated: .............................................................................................................................................................................. 17 Pumping Schedule Simulated: ............................................................................................................................................................. 20 Simulation Summary: ........................................................................................................................................................................... 22 Stage 4 ..................................................................................................................................................................................................... 23 Zoneset Simulated: .............................................................................................................................................................................. 23 Pumping Schedule Simulated: ............................................................................................................................................................. 27 Simulation Summary: ........................................................................................................................................................................... 29 Stage 5 ..................................................................................................................................................................................................... 30 Zoneset Simulated: .............................................................................................................................................................................. 30 Pumping Schedule Simulated: ............................................................................................................................................................. 34 Simulation Summary: ........................................................................................................................................................................... 36 Stage 6 ..................................................................................................................................................................................................... 37 Zoneset Simulated: .............................................................................................................................................................................. 37 Pumping Schedule Simulated: ............................................................................................................................................................. 41 Simulation Summary: ........................................................................................................................................................................... 43 Stage 7 ..................................................................................................................................................................................................... 44 Zoneset Simulated: .............................................................................................................................................................................. 44 Pumping Schedule Simulated: ............................................................................................................................................................. 48 Simulation Summary: ........................................................................................................................................................................... 49 Stage 8 ..................................................................................................................................................................................................... 50 Zoneset Simulated: .............................................................................................................................................................................. 50 Pumping Schedule Simulated: ............................................................................................................................................................. 54 Simulation Summary: ........................................................................................................................................................................... 55 NDB-040 (Attachment K) Stage 9 ..................................................................................................................................................................................................... 56 Zoneset Simulated: .............................................................................................................................................................................. 56 Pumping Schedule Simulated: ............................................................................................................................................................. 60 Simulation Summary: ........................................................................................................................................................................... 61 Stage 10 ................................................................................................................................................................................................... 62 Zoneset Simulated: .............................................................................................................................................................................. 62 Pumping Schedule Simulated: ............................................................................................................................................................. 66 Simulation Summary: ........................................................................................................................................................................... 67 Stage 11 ................................................................................................................................................................................................... 68 Zoneset Simulated: .............................................................................................................................................................................. 68 Pumping Schedule Simulated: ............................................................................................................................................................. 71 Simulation Summary: ........................................................................................................................................................................... 73 Stage 12 ................................................................................................................................................................................................... 74 Zoneset Simulated: .............................................................................................................................................................................. 74 Pumping Schedule Simulated: ............................................................................................................................................................. 78 Simulation Summary: ........................................................................................................................................................................... 79 Stage 13 ................................................................................................................................................................................................... 80 Zoneset Simulated: .............................................................................................................................................................................. 80 Pumping Schedule Simulated: ............................................................................................................................................................. 84 Simulation Summary: ........................................................................................................................................................................... 85 Stage 14 ................................................................................................................................................................................................... 86 Zoneset Simulated: .............................................................................................................................................................................. 86 Pumping Schedule Simulated: ............................................................................................................................................................. 90 Simulation Summary: ........................................................................................................................................................................... 91 NDB-040 (Attachment K) Well Description Completion Stages and Perforations Stage Perforation Top MD (ft) Perforation Top TVD (ft) 14 15296 4162 13 15882 4164 12 16466 4157 11 17012 4151 10 17554 4146 9 18055 4141 8 18684 4135 7 19271 4129 6 19816 4124 5 20395 4118 4 20937 4113 3 21483 4108 2 22070 4102 1 22613 4096 NDB-040 (Attachment K) 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): 15000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6603.8 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 4008.8 10 0.73 2936.91 1461000.32 0.22 2500 Shale 4018.8 15 0.69 2798.28 1762000.53 0.22 2500 Nanushuk 3 SS 4033.8 15.3 0.68 2740.1 1898000.54 0.22 2000 Top Nan 4049.1 6 0.65 2630 838900.21 0.27 1000 Shale 4055.1 2 0.7 2858 2665000.72 0.23 2500 Nan DS 4057.1 1.5 0.64 2584 819400.23 0.27 1500 Nan DS 4058.6 2 0.64 2615 1222000.33 0.26 1500 Nan CS 4060.6 13 0.63 2562 869100.21 0.27 1000 Nan CS 4073.6 1.5 0.61 2497.58 1002000.26 0.27 1000 NDB-040 (Attachment K) 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 4075.1 4 0.65 2630 706600.17 0.28 1000 Nan CS 4079.1 9 0.61 2478.74 1166000.34 0.27 1000 Nan CS 4088.1 7 0.65 2659 769000.2 0.27 1000 Nan CS 4095.1 5.5 0.62 2543 1278000.4 0.26 1000 Nan CS 4100.6 13 0.65 2665 691700.19 0.28 1000 Nan DS 4113.6 2.5 0.68 2817 1748000.42 0.26 1500 Nan DS 4116.1 12.5 0.64 2621.81 1111000.32 0.27 1500 Nan DS 4128.6 4 0.7 2891 1692000.43 0.26 1500 Nan DS 4132.6 2.5 0.65 2675 822100.22 0.27 1500 Shale 4135.1 2 0.7 2882.86 2665000.72 0.23 2500 Nan DS 4137.1 4 0.65 2682.14 1159000.28 0.27 1500 Nan DS 4141.1 4 0.63 2597.72 838300.19 0.27 1000 Shale 4145.1 4 0.7 2921 2665000.72 0.23 2500 Nan DS 4149.1 6 0.65 2682 1133000.31 0.27 1500 Shale 4155.1 2 0.7 2896.8 2665000.72 0.23 2500 Nan DS 4157.1 2 0.63 2614 1078000.3 0.27 1500 NDB-040 (Attachment K) 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 4159.1 6.5 0.67 2781 1694000.38 0.26 1500 Nan DS 4165.6 4 0.62 2576 898500.22 0.27 1500 Nan DS 4169.6 3.5 0.65 2711 929100.26 0.27 1500 Shale 4173.1 2 0.7 2909.35 2665000.72 0.23 2500 Nan DS 4175.1 12.5 0.65 2698 1562000.43 0.26 1500 Nan DS 4187.6 2 0.66 2747 1397000.37 0.26 1500 Shale 4189.6 2 0.7 2920.85 2665000.72 0.23 2500 Nan DS 4191.6 2 0.65 2729.38 1242000.3 0.26 1500 Shale 4193.6 8 0.69 2892.15 2665000.72 0.23 2500 Nan DS 4201.6 2 0.64 2690 932500.22 0.27 1500 Shale 4203.6 4 0.7 2931.3 2665000.72 0.23 2500 Nan DS 4207.6 6 0.65 2720.05 1427000.39 0.26 1500 Shale 4213.6 8 0.7 2939.67 2665000.72 0.23 2500 Nan DS 4221.6 6.5 0.65 2766 1469000.43 0.26 1500 Shale 4228.1 6 0.69 2915.23 2665000.72 0.23 2500 Nan DS 4234.1 2 0.64 2726 838400.22 0.27 1000 NDB-040 (Attachment K) 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 4236.1 2 0.7 2953.26 2665000.72 0.23 2500 Nan DS 4238.1 4 0.65 2756.06 1469000.43 0.26 1500 Shale 4242.1 2 0.7 2957.44 2665000.72 0.23 2500 Nan DS 4244.1 6 0.67 2849 1545000.39 0.26 1500 Shale 4250.1 12 0.7 2966.5 2665000.72 0.23 2500 Nan DS 4262.1 2.5 0.65 2754 1214000.3 0.27 1500 Shale 4264.6 20 0.69 2945.2 2665000.72 0.23 2500 ǣ Name: Stage 1 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 1 PAD 40 YF126ST 17850 425 10.63 2 1.0 PPA 40 YF126ST 5027.69 125.02 CarboLite 16/20 + SG 1 5027.69 3.13 3 2.0 PPA 40 YF126ST 5402.26 140.04 CarboLite 16/20 + SG 2 10804.53 3.5 4 3.0 PPA 40 YF126ST 6301.07 170 CarboLite 16/20 + SG 3 18903.22 4.25 5 4.0 PPA 40 YF126ST 6063.59 170 CarboLite 16/20 + SG 4 24254.35 4.25 NDB-040 (Attachment K) 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) 6 5.0 PPA 40 YF126ST 5843.36 170 CarboLite 16/20 + SG 5 29216.78 4.25 7 6.0 PPA 40 YF126ST 5638.56 170 CarboLite 16/20 + SG 6 33831.36 4.25 8 7.0 PPA 40 YF126ST 4486.29 140 CarboLite 16/20 + SG 7 31404 3.5 9 8.0 PPA 40 YF126ST 3874.4 125 CarboLite 16/20 + SG 8 30995.2 3.12 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 29.51 25.99 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 60487.22 184437.13 1635.06 40.88 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 1 6603.8 238.66 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4014 4252.66 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 1 996.56 178.94 0.28 NDB-040 (Attachment K) 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): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6564 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 4014.8 10 0.73 2936.9 1461000.32 0.22 2500 Shale 4024.8 15 0.69 2802.4 1762000.53 0.22 2500 Nanushuk 3 SS 4039.8 15.3 0.68 2744.2 1898000.54 0.22 2000 Top Nan 4055.12 6 0.65 2630 838900.21 0.27 1000 Shale 4061.09 2 0.7 2858 2665000.72 0.23 2500 Nan DS 4063.09 1.5 0.64 2584 819400.23 0.27 1500 Nan DS 4064.6 2 0.64 2615 1222000.33 0.26 1500 Nan CS 4066.6 13 0.63 2562 869100.21 0.27 1000 Nan CS 4079.59 1.5 0.61 2501.3 1002000.26 0.27 1000 NDB-040 (Attachment K) 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 4081.1 4 0.64 2630 706600.17 0.28 1000 Nan CS 4085.1 9 0.61 2482.4 1166000.34 0.27 1000 Nan CS 4094.09 7 0.65 2659 769000.2 0.27 1000 Nan CS 4101.12 5.5 0.62 2543 1278000.4 0.26 1000 Nan CS 4106.59 13 0.65 2665 691700.19 0.28 1000 Nan DS 4119.62 2.5 0.68 2817 1748000.42 0.26 1500 Nan DS 4122.11 12.5 0.64 2625.6 1111000.32 0.27 1500 Nan DS 4134.61 4 0.7 2891 1692000.43 0.26 1500 Nan DS 4138.62 2.5 0.65 2675 822100.22 0.27 1500 Shale 4141.11 2 0.7 2887 2665000.72 0.23 2500 Nan DS 4143.11 4 0.65 2686 1159000.28 0.27 1500 Nan DS 4147.11 4 0.63 2601.5 838300.19 0.27 1000 Shale 4151.12 4 0.7 2921 2665000.72 0.23 2500 Nan DS 4155.12 6 0.65 2682 1133000.31 0.27 1500 Shale 4161.09 2 0.7 2901 2665000.72 0.23 2500 Nan DS 4163.09 2 0.63 2614 1078000.3 0.27 1500 NDB-040 (Attachment K) 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 4165.09 6.5 0.67 2781 1694000.38 0.26 1500 Nan DS 4171.59 4 0.62 2576 898500.22 0.27 1500 Nan DS 4175.59 3.5 0.65 2711 929100.26 0.27 1500 Shale 4179.1 2 0.7 2913.5 2665000.72 0.23 2500 Nan DS 4181.1 12.5 0.64 2698 1562000.43 0.26 1500 Nan DS 4193.6 2 0.65 2747 1397000.37 0.26 1500 Shale 4195.6 2 0.7 2925 2665000.72 0.23 2500 Nan DS 4197.6 2 0.65 2733.3 1242000.3 0.26 1500 Shale 4199.61 8 0.69 2896.3 2665000.72 0.23 2500 Nan DS 4207.61 2 0.64 2690 932500.22 0.27 1500 Shale 4209.61 4 0.7 2935.5 2665000.72 0.23 2500 Nan DS 4213.62 6 0.65 2723.9 1427000.39 0.26 1500 Shale 4219.62 8 0.7 2943.8 2665000.72 0.23 2500 Nan DS 4227.59 6.5 0.65 2766 1469000.43 0.26 1500 Shale 4234.09 6 0.69 2919.4 2665000.72 0.23 2500 Nan DS 4240.09 2 0.64 2726 838400.22 0.27 1000 NDB-040 (Attachment K) 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 4242.09 2 0.7 2957.4 2665000.72 0.23 2500 Nan DS 4244.09 4 0.65 2760 1469000.43 0.26 1500 Shale 4248.1 2 0.7 2961.6 2665000.72 0.23 2500 Nan DS 4250.1 6 0.67 2849 1545000.39 0.26 1500 Shale 4256.1 12 0.7 2970.7 2665000.72 0.23 2500 Nan DS 4268.11 2.5 0.65 2754 1214000.3 0.27 1500 Shale 4270.6 20 0.69 2949.3 2665000.72 0.23 2500 NDB-040 (Attachment K) 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 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 2 6564 240.65 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4019 4259.65 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 2 997.48 186.17 0.35 NDB-040 (Attachment K) 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 6898.6 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 4034.81 10 0.73 2944.99 1461000.32 0.22 2500 Shale 4044.82 15 0.69 2816.34 1762000.53 0.22 2500 Nanushuk 3 SS 4059.81 15.3 0.68 2757.75 1898000.54 0.22 2000 Top Nan 4075.1 6 0.65 2637.08 838900.21 0.27 1000 Shale 4081.1 2 0.7 2865.66 2665000.72 0.23 2500 Nan DS 4083.1 1.5 0.63 2590.95 819400.23 0.27 1500 Nan DS 4084.61 2 0.64 2622.14 1222000.33 0.26 1500 Nan CS 4086.61 13 0.63 2568.91 869100.21 0.27 1000 Nan CS 4099.61 1.5 0.61 2513.5 1002000.26 0.27 1000 NDB-040 (Attachment K) 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 4101.12 4 0.64 2637.08 706600.17 0.28 1000 Nan CS 4105.09 9 0.61 2494.5 1166000.34 0.27 1000 Nan CS 4114.11 7 0.65 2666.08 769000.2 0.27 1000 Nan CS 4121.1 5.5 0.62 2549.76 1278000.4 0.26 1000 Nan CS 4126.61 13 0.65 2672.18 691700.19 0.28 1000 Nan DS 4139.6 2.5 0.68 2824.46 1748000.42 0.26 1500 Nan DS 4142.09 12.5 0.64 2638.38 1111000.32 0.27 1500 Nan DS 4154.59 4 0.7 2898.72 1692000.43 0.26 1500 Nan DS 4158.6 2.5 0.64 2682.04 822100.22 0.27 1500 Shale 4161.09 2 0.7 2900.9 2665000.72 0.23 2500 Nan DS 4163.09 4 0.65 2699.01 1159000.28 0.27 1500 Nan DS 4167.09 4 0.63 2614.02 838300.19 0.27 1000 Shale 4171.1 4 0.7 2928.75 2665000.72 0.23 2500 Nan DS 4175.1 6 0.64 2689.14 1133000.31 0.27 1500 Shale 4181.1 2 0.7 2914.97 2665000.72 0.23 2500 Nan DS 4183.1 2 0.63 2620.83 1078000.3 0.27 1500 NDB-040 (Attachment K) 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 4185.1 6.5 0.67 2788.35 1694000.38 0.26 1500 Nan DS 4191.6 4 0.62 2582.83 898500.22 0.27 1500 Nan DS 4195.6 3.5 0.65 2718.15 929100.26 0.27 1500 Shale 4199.11 2 0.7 2927.44 2665000.72 0.23 2500 Nan DS 4201.12 12.5 0.64 2705.1 1562000.43 0.26 1500 Nan DS 4213.62 2 0.65 2754.12 1397000.37 0.26 1500 Shale 4215.58 2 0.7 2938.9 2665000.72 0.23 2500 Nan DS 4217.59 2 0.65 2746.29 1242000.3 0.26 1500 Shale 4219.59 8 0.69 2910.04 2665000.72 0.23 2500 Nan DS 4227.59 2 0.64 2696.98 932500.22 0.27 1500 Shale 4229.59 4 0.7 2949.49 2665000.72 0.23 2500 Nan DS 4233.6 6 0.65 2736.86 1427000.39 0.26 1500 Shale 4239.6 8 0.7 2957.75 2665000.72 0.23 2500 Nan DS 4247.6 6.5 0.65 2773.12 1469000.43 0.26 1500 Shale 4254.1 6 0.69 2933.24 2665000.72 0.23 2500 Nan DS 4260.1 2 0.64 2733.09 838400.22 0.27 1000 NDB-040 (Attachment K) 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 4262.11 2 0.7 2971.39 2665000.72 0.23 2500 Nan DS 4264.11 4 0.65 2772.98 1469000.43 0.26 1500 Shale 4268.11 2 0.7 2975.59 2665000.72 0.23 2500 Nan DS 4270.11 6 0.67 2856.37 1545000.39 0.26 1500 Shale 4276.12 12 0.7 2984.73 2665000.72 0.23 2500 Nan DS 4288.09 2.5 0.64 2761.08 1214000.3 0.27 1500 Shale 4290.58 20 0.69 2963.12 2665000.72 0.23 2500 ǣ Name: Stage 3 Pumping Steps Step # Step Name Pump Rate (bbl/min) Fluid Name CFLD Vol (gal) Slurry Volume (bbl) Prop Name Prop Conc (PPA) Prop Mass (lbm) Pump Time (min) 1 Stage 3 PAD 40 YF126ST 14280 340 8.5 2 1 PPA Scour 40 YF126ST 2414.7 60.03 CarboLite 40/70 1 2414.7 1.5 3 3 PPA Scour 40 YF126ST 4457.5 120.21 CarboLite 40/70 3 13372.5 3.01 4 Resume PAD 40 YF126ST 2100 50 1.25 5 1 PPA 40 YF126ST 8043 200 CarboLite 16/20 + SG 1 8043 5 NDB-040 (Attachment K) 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) 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 (%) 32.45 28.1 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 71664 249856.8 1970.24 49.26 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 3 6898.6 244.03 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4038.38 4282.41 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 3 1042.55 192.35 0.38 NDB-040 (Attachment K) 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): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6694.5 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 4024.11 10 0.73 2931.79 1461000.3 0.22 1000 Shale 4034.09 15 0.7 2808.95 1762000.5 0.22 1000 Nanushuk 3 SS 4049.11 15.3 0.68 2750.5 1898000.5 0.22 1000 Top Nan 4064.4 19.5 0.63 2566.73 900400.2 0.27 1000 Shale 4083.89 2 0.69 2822.72 2665000.7 0.23 2500 Nan DS 4085.89 1.5 0.65 2650.42 1292000.4 0.26 1000 Nan DS 4087.4 4.5 0.62 2519.16 643500.2 0.28 1000 Nan CS 4091.9 3.5 0.69 2828.67 1774000.4 0.26 1500 Nan CS 4095.41 14.5 0.66 2721.34 1388000.3 0.26 1500 NDB-040 (Attachment K) 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 4109.91 1.5 0.66 2701.33 1145000.3 0.27 1000 Nan CS 4111.38 12.5 0.64 2636.5 882100.2 0.27 1000 Nan CS 4123.88 2 0.65 2677.11 1402000.4 0.26 1500 Nan CS 4125.89 9 0.61 2507.12 853600.2 0.27 1000 Nan CS 4134.91 7 0.66 2750.35 1397000.4 0.26 1500 Nan DS 4141.9 9 0.65 2700.46 1132000.3 0.27 1500 Nan DS 4150.89 3.5 0.64 2665.94 1688000.4 0.26 1500 Nan DS 4154.4 5 0.64 2660.43 757000.2 0.27 1000 Nan DS 4159.42 2 0.7 2920.04 1795000.5 0.25 1500 Shale 4161.38 10.5 0.62 2579.21 735600.2 0.27 1000 Nan DS 4171.92 3.5 0.65 2700.31 1098000.3 0.27 1000 Nan DS 4175.39 2 0.62 2609.66 670200.2 0.28 1000 Shale 4177.4 5.5 0.66 2763.11 1300000.3 0.26 1000 Nan DS 4182.91 3.5 0.7 2908.3 1531000.4 0.26 1500 Shale 4186.38 3.5 0.64 2696.54 1193000.3 0.27 1500 Nan DS 4189.9 5.5 0.69 2897.13 1416000.4 0.26 1500 NDB-040 (Attachment K) 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 4195.41 10.5 0.64 2688.42 1171000.3 0.27 1000 Nan DS 4205.91 1.5 0.67 2805.9 1376000.4 0.26 1500 Nan DS 4207.41 5 0.62 2618.51 1139000.3 0.27 1500 Shale 4212.4 2 0.67 2804.3 1560000.5 0.26 1500 Nan DS 4214.4 4 0.64 2683.49 896400.2 0.27 1500 Nan DS 4218.41 2 0.68 2871.31 1656000.4 0.26 1500 Shale 4220.41 10 0.63 2649.26 981000.2 0.27 1500 Nan DS 4230.41 4 0.65 2768.05 1633000.4 0.26 1500 Shale 4234.42 4 0.7 2969.07 1749000.4 0.26 1500 Nan DS 4238.39 9.5 0.65 2779.21 1327000.4 0.26 1500 Shale 4247.9 2 0.62 2621.56 781500.2 0.27 1000 Nan DS 4249.9 9.5 0.69 2944.27 1692000.4 0.26 1500 Shale 4259.42 2 0.66 2807.64 1365000.4 0.26 1500 Nan DS 4261.38 2 0.7 2970.95 2665000.7 0.23 2500 Shale 4263.39 2 0.64 2712.21 1088000.3 0.27 1500 Nan DS 4265.39 2 0.7 2973.71 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 4267.39 4 0.66 2839.11 1287000.3 0.26 1500 Nan DS 4271.39 19.5 0.7 2983.86 2665000.7 0.23 2500 Shale 4290.91 2 0.66 2815.47 1356000.3 0.26 1500 Nan DS 4292.91 2 0.7 2992.85 2665000.7 0.23 2500 Shale 4294.91 8 0.66 2850.14 1373000.4 0.26 1500 Nan DS 4302.89 8 0.65 2786.61 1558000.4 0.26 1500 Shale 4310.89 20 0.7 3037.09 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 13860 330 8.25 2 1 PPA Scour 40 YF126ST 2414.7 60.03 CarboLite 40/70 1 2414.7 1.5 3 3 PPA Scour 40 YF126ST 4457.5 120.21 CarboLite 40/70 3 13372.5 3.01 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 (%) 32.05 27.73 NDB-040 (Attachment K) Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 71244 249856.8 1960.24 49.01 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 4 6694.5 249.57 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4029.61 4279.18 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 4 843.18 216.58 0.27 NDB-040 (Attachment K) 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): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6545 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 4028.08 10 0.73 2931.07 1461000.3 0.22 1000 Shale 4038.09 15 0.7 2811.7 1762000.5 0.22 1000 Nanushuk 3 SS 4053.08 15.3 0.68 2753.11 1898000.5 0.22 1000 Top Nan 4068.41 19.5 0.63 2569.2 900400.2 0.27 1000 Shale 4087.89 2 0.69 2825.48 2665000.7 0.23 2500 Nan DS 4089.9 1.5 0.65 2649.84 1292000.4 0.26 1000 Nan DS 4091.4 4.5 0.62 2521.63 643500.2 0.28 1000 Nan CS 4095.9 3.5 0.69 2831.43 1774000.4 0.26 1500 Nan CS 4099.41 14.5 0.66 2720.76 1388000.3 0.26 1500 NDB-040 (Attachment K) 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 4113.91 1.5 0.66 2700.75 1145000.3 0.27 1000 Nan CS 4115.39 12.5 0.64 2635.92 882100.2 0.27 1000 Nan CS 4127.89 2 0.65 2679.57 1402000.4 0.26 1500 Nan CS 4129.89 9 0.61 2509.59 853600.2 0.27 1000 Nan CS 4138.91 7 0.66 2749.63 1397000.4 0.26 1500 Nan DS 4145.9 9 0.65 2699.73 1132000.3 0.27 1500 Nan DS 4154.89 3.5 0.64 2668.55 1688000.4 0.26 1500 Nan DS 4158.4 5 0.64 2663.04 757000.2 0.27 1000 Nan DS 4163.39 2 0.7 2919.32 1795000.5 0.25 1500 Shale 4165.39 10.5 0.62 2581.67 735600.2 0.27 1000 Nan DS 4175.89 3.5 0.65 2702.92 1098000.3 0.27 1000 Nan DS 4179.4 2 0.62 2608.94 670200.2 0.28 1000 Shale 4181.4 5.5 0.66 2765.72 1300000.3 0.26 1000 Nan DS 4186.91 3.5 0.7 2911.2 1531000.4 0.26 1500 Shale 4190.39 3.5 0.64 2695.82 1193000.3 0.27 1500 Nan DS 4193.9 5.5 0.69 2899.88 1416000.4 0.26 1500 NDB-040 (Attachment K) 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 4199.41 10.5 0.64 2691.03 1171000.3 0.27 1000 Nan DS 4209.91 1.5 0.67 2808.51 1376000.4 0.26 1500 Nan DS 4211.38 5 0.62 2620.98 1139000.3 0.27 1500 Shale 4216.4 2 0.66 2803.72 1560000.5 0.26 1500 Nan DS 4218.41 4 0.64 2682.91 896400.2 0.27 1500 Nan DS 4222.41 2 0.68 2870.59 1656000.4 0.26 1500 Shale 4224.41 10 0.63 2651.72 981000.2 0.27 1500 Nan DS 4234.42 4 0.65 2770.51 1633000.4 0.26 1500 Shale 4238.39 4 0.7 2968.34 1749000.4 0.26 1500 Nan DS 4242.39 9.5 0.65 2781.82 1327000.4 0.26 1500 Shale 4251.9 2 0.62 2624.02 781500.2 0.27 1000 Nan DS 4253.9 9.5 0.69 2947.02 1692000.4 0.26 1500 Shale 4263.39 2 0.66 2810.25 1365000.4 0.26 1500 Nan DS 4265.39 2 0.7 2973.71 2665000.7 0.23 2500 Shale 4267.39 2 0.64 2714.67 1088000.3 0.27 1500 Nan DS 4269.39 2 0.7 2976.46 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 4271.39 4 0.66 2841.72 1287000.3 0.26 1500 Nan DS 4275.39 19.5 0.7 2986.76 2665000.7 0.23 2500 Shale 4294.91 2 0.66 2818.23 1356000.3 0.26 1500 Nan DS 4296.92 2 0.7 2995.61 2665000.7 0.23 2500 Shale 4298.88 8 0.66 2852.75 1373000.4 0.26 1500 Nan DS 4306.89 8 0.65 2789.08 1558000.4 0.26 1500 Shale 4314.9 20 0.7 3036.37 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 13440 320 8 2 1 PPA Scour 40 YF126ST 2414.7 60.03 CarboLite 40/70 1 2414.7 1.5 3 3 PPA Scour 40 YF126ST 4457.5 120.21 CarboLite 40/70 3 13372.5 3.01 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 27.36 NDB-040 (Attachment K) Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 70824 249856.8 1950.24 48.76 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 5 6545 249.12 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4033 4282.12 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 5 839.25 213.71 0.28 NDB-040 (Attachment K) 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 6380.6 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 4032.09 10 0.73 2933.24 1461000.3 0.22 1000 Shale 4042.09 15 0.69 2814.46 1762000.5 0.22 1000 Nanushuk 3 SS 4057.09 15.3 0.68 2755.86 1898000.5 0.22 1000 Top Nan 4072.41 19.5 0.63 2571.81 900400.2 0.27 1000 Shale 4091.9 2 0.69 2828.09 2665000.7 0.23 2500 Nan DS 4093.9 1.5 0.65 2651.72 1292000.4 0.26 1000 Nan DS 4095.41 4.5 0.62 2524.09 643500.2 0.28 1000 Nan CS 4099.9 3.5 0.69 2834.18 1774000.4 0.26 1500 NDB-040 (Attachment K) 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 4103.41 14.5 0.66 2722.65 1388000.3 0.26 1500 Nan CS 4117.91 1.5 0.66 2702.78 1145000.3 0.27 1000 Nan CS 4119.39 12.5 0.64 2637.8 882100.2 0.27 1000 Nan CS 4131.89 2 0.65 2682.18 1402000.4 0.26 1500 Nan CS 4133.89 9 0.61 2511.91 853600.2 0.27 1000 Nan CS 4142.91 7 0.66 2751.66 1397000.4 0.26 1500 Nan DS 4149.9 9 0.65 2701.76 1132000.3 0.27 1500 Nan DS 4158.89 3.5 0.64 2671.16 1688000.4 0.26 1500 Nan DS 4162.4 5 0.64 2665.5 757000.2 0.27 1000 Nan DS 4167.39 2 0.7 2921.5 1795000.5 0.25 1500 Shale 4169.39 10.5 0.62 2584.14 735600.2 0.27 1000 Nan DS 4179.89 3.5 0.65 2705.53 1098000.3 0.27 1000 Nan DS 4183.4 2 0.62 2610.82 670200.2 0.28 1000 Shale 4185.4 5.5 0.66 2768.34 1300000.3 0.26 1000 Nan DS 4190.91 3.5 0.7 2913.95 1531000.4 0.26 1500 Shale 4194.39 3.5 0.64 2697.85 1193000.3 0.27 1500 NDB-040 (Attachment K) 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 4197.9 5.5 0.69 2902.64 1416000.4 0.26 1500 Nan DS 4203.41 10.5 0.64 2693.5 1171000.3 0.27 1000 Nan DS 4213.91 1.5 0.67 2811.12 1376000.4 0.26 1500 Nan DS 4215.39 5 0.62 2623.44 1139000.3 0.27 1500 Shale 4220.41 2 0.66 2805.61 1560000.5 0.26 1500 Nan DS 4222.41 4 0.64 2684.79 896400.2 0.27 1500 Nan DS 4226.41 2 0.68 2872.62 1656000.4 0.26 1500 Shale 4228.41 10 0.63 2654.34 981000.2 0.27 1500 Nan DS 4238.39 4 0.65 2773.27 1633000.4 0.26 1500 Shale 4242.39 4 0.7 2970.52 1749000.4 0.26 1500 Nan DS 4246.39 9.5 0.66 2784.58 1327000.4 0.26 1500 Shale 4255.91 2 0.62 2626.49 781500.2 0.27 1000 Nan DS 4257.91 9.5 0.69 2949.78 1692000.4 0.26 1500 Shale 4267.39 2 0.66 2812.86 1365000.4 0.26 1500 Nan DS 4269.39 2 0.7 2976.46 2665000.7 0.23 2500 Shale 4271.39 2 0.64 2717.28 1088000.3 0.27 1500 NDB-040 (Attachment K) 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 4273.39 2 0.7 2979.22 2665000.7 0.23 2500 Shale 4275.39 4 0.67 2844.48 1287000.3 0.26 1500 Nan DS 4279.4 19.5 0.7 2989.52 2665000.7 0.23 2500 Shale 4298.88 2 0.66 2820.69 1356000.3 0.26 1500 Nan DS 4300.89 2 0.7 2998.37 2665000.7 0.23 2500 Shale 4302.89 8 0.66 2855.5 1373000.4 0.26 1500 Nan DS 4310.89 8 0.65 2791.83 1558000.4 0.26 1500 Shale 4318.9 20 0.7 3038.54 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 13020 310 7.75 2 1 PPA Scour 40 YF126ST 2414.7 60.03 CarboLite 40/70 1 2414.7 1.5 3 3 PPA Scour 40 YF126ST 4457.5 120.21 CarboLite 40/70 3 13372.5 3.01 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 (%) 31.24 26.99 NDB-040 (Attachment K) Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 70404 249856.8 1940.24 48.51 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 6 6380.6 247.79 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4038.24 4286.03 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 6 826.99 212.81 0.28 NDB-040 (Attachment K) 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 6485.2 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 4036.09 10 0.72 2918.88 1461000.3 0.22 1000 Shale 4046.1 15 0.69 2817.21 1762000.5 0.22 1000 Nanushuk 3 SS 4061.09 15.3 0.68 2758.62 1898000.5 0.22 1000 Top Nan CS 4076.41 19.5 0.63 2574.27 900400.2 0.27 1000 Nan SS 4095.9 2 0.69 2830.99 2665000.7 0.23 2500 Nan CS 4097.9 1.5 0.64 2638.96 1292000.4 0.26 1000 Nan CS 4099.41 4.5 0.62 2526.56 643500.2 0.28 1000 Nan DS 4103.9 3.5 0.69 2837.08 1774000.4 0.26 1500 Nan DS 4107.41 14.5 0.66 2709.6 1388000.3 0.26 1500 NDB-040 (Attachment K) 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 4121.92 1.5 0.65 2689.72 1145000.3 0.27 1000 Nan CS 4123.39 12.5 0.64 2625.04 882100.2 0.27 1000 Nan DS 4135.89 2 0.65 2684.94 1402000.4 0.26 1500 Nan CS 4137.89 9 0.61 2514.37 853600.2 0.27 1000 Nan DS 4146.92 7 0.66 2738.46 1397000.4 0.26 1500 Nan DS 4153.9 9 0.65 2688.85 1132000.3 0.27 1500 Nan DS 4162.89 3.5 0.64 2673.77 1688000.4 0.26 1500 Nan DS 4166.4 5 0.64 2668.11 757000.2 0.27 1000 Nan DS 4171.39 2 0.7 2907.57 1795000.5 0.25 1500 Nan CS 4173.39 10.5 0.62 2586.6 735600.2 0.27 1000 Nan CS 4183.89 3.5 0.65 2708.14 1098000.3 0.27 1000 Nan CS 4187.4 2 0.62 2598.5 670200.2 0.28 1000 Nan CS 4189.4 5.5 0.66 2770.95 1300000.3 0.26 1000 Nan DS 4194.91 3.5 0.69 2916.56 1531000.4 0.26 1500 Nan DS 4198.39 3.5 0.64 2685.08 1193000.3 0.27 1500 Nan DS 4201.9 5.5 0.69 2905.4 1416000.4 0.26 1500 NDB-040 (Attachment K) 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 4207.41 10.5 0.64 2696.11 1171000.3 0.27 1000 Nan DS 4217.91 1.5 0.67 2813.88 1376000.4 0.26 1500 Nan DS 4219.39 5 0.62 2626.05 1139000.3 0.27 1500 Nan DS 4224.41 2 0.66 2792.56 1560000.5 0.26 1500 Nan DS 4226.41 4 0.63 2672.18 896400.2 0.27 1500 Nan DS 4230.41 2 0.68 2859.13 1656000.4 0.26 1500 Nan DS 4232.41 10 0.63 2656.8 981000.2 0.27 1500 Nan DS 4242.39 4 0.65 2775.88 1633000.4 0.26 1500 Nan DS 4246.39 4 0.7 2956.59 1749000.4 0.26 1500 Nan DS 4250.39 9.5 0.66 2787.19 1327000.4 0.26 1500 Nan DS 4259.91 2 0.62 2628.95 781500.2 0.27 1000 Nan DS 4261.91 9.5 0.69 2952.53 1692000.4 0.26 1500 Nan DS 4271.39 2 0.66 2815.47 1365000.4 0.26 1500 Shale 4273.39 2 0.7 2979.22 2665000.7 0.23 2500 Nan DS 4275.39 2 0.64 2719.75 1088000.3 0.27 1500 Shale 4277.4 2 0.7 2982.12 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 4279.4 4 0.67 2847.24 1287000.3 0.26 1500 Shale 4283.4 19.5 0.7 2992.42 2665000.7 0.23 2500 Nan DS 4302.89 2 0.66 2823.45 1356000.3 0.26 1500 Shale 4304.89 2 0.7 3001.12 2665000.7 0.23 2500 Nan DS 4306.89 8 0.66 2858.11 1373000.4 0.26 1500 Nan DS 4314.9 8 0.65 2794.3 1558000.4 0.26 1500 Shale 4322.9 20 0.7 3024.62 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 16800 400 CarboLite 16/20 + SG 0 0 10 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 (%) 27.84 23.59 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 60339.4 245217 1695.77 42.39 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 7 6485.2 244.84 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4042.78 4287.62 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 7 773.22 207.26 0.37 NDB-040 (Attachment K) 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 6595 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 4041.11 10 0.72 2922.51 1461000.3 0.22 1000 Shale 4051.12 15 0.69 2820.69 1762000.5 0.22 1000 Nanushuk 3 SS 4066.11 15.3 0.68 2762.1 1898000.5 0.22 1000 Top Nan CS 4081.4 19.5 0.63 2577.47 900400.2 0.27 1000 Nan SS 4100.89 2 0.69 2834.33 2665000.7 0.23 2500 Nan CS 4102.89 1.5 0.64 2642.15 1292000.4 0.26 1000 Nan CS 4104.4 4.5 0.62 2529.75 643500.2 0.28 1000 Nan DS 4108.89 3.5 0.69 2840.42 1774000.4 0.26 1500 Nan DS 4112.4 14.5 0.66 2712.79 1388000.3 0.26 1500 NDB-040 (Attachment K) 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 4126.9 1.5 0.65 2692.92 1145000.3 0.27 1000 Nan CS 4128.41 12.5 0.64 2628.23 882100.2 0.27 1000 Nan DS 4140.91 2 0.65 2688.13 1402000.4 0.26 1500 Nan CS 4142.91 9 0.61 2517.42 853600.2 0.27 1000 Nan DS 4151.9 7 0.66 2741.79 1397000.4 0.26 1500 Nan DS 4158.89 9 0.65 2692.05 1132000.3 0.27 1500 Nan DS 4167.91 3.5 0.64 2676.96 1688000.4 0.26 1500 Nan DS 4171.39 5 0.64 2671.31 757000.2 0.27 1000 Nan DS 4176.41 2 0.7 2911.05 1795000.5 0.25 1500 Nan CS 4178.41 10.5 0.62 2589.79 735600.2 0.27 1000 Nan CS 4188.91 3.5 0.65 2711.34 1098000.3 0.27 1000 Nan CS 4192.39 2 0.62 2601.54 670200.2 0.28 1000 Nan CS 4194.39 5.5 0.66 2774.28 1300000.3 0.26 1000 Nan DS 4199.9 3.5 0.69 2920.04 1531000.4 0.26 1500 Nan DS 4203.41 3.5 0.64 2688.27 1193000.3 0.27 1500 Nan DS 4206.89 5.5 0.69 2908.88 1416000.4 0.26 1500 NDB-040 (Attachment K) 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 4212.4 10.5 0.64 2699.3 1171000.3 0.27 1000 Nan DS 4222.9 1.5 0.67 2817.21 1376000.4 0.26 1500 Nan DS 4224.41 5 0.62 2629.1 1139000.3 0.27 1500 Nan DS 4229.4 2 0.66 2795.75 1560000.5 0.26 1500 Nan DS 4231.4 4 0.63 2675.37 896400.2 0.27 1500 Nan DS 4235.4 2 0.68 2862.46 1656000.4 0.26 1500 Nan DS 4237.4 10 0.63 2659.99 981000.2 0.27 1500 Nan DS 4247.41 4 0.65 2779.07 1633000.4 0.26 1500 Nan DS 4251.41 4 0.7 2960.08 1749000.4 0.26 1500 Nan DS 4255.41 9.5 0.66 2790.38 1327000.4 0.26 1500 Nan DS 4264.9 2 0.62 2632 781500.2 0.27 1000 Nan DS 4266.9 9.5 0.69 2956.01 1692000.4 0.26 1500 Nan DS 4276.41 2 0.66 2818.81 1365000.4 0.26 1500 Shale 4278.41 2 0.7 2982.7 2665000.7 0.23 2500 Nan DS 4280.41 2 0.64 2722.94 1088000.3 0.27 1500 Shale 4282.41 2 0.7 2985.6 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 4284.42 4 0.67 2850.57 1287000.3 0.26 1500 Shale 4288.39 19.5 0.7 2995.9 2665000.7 0.23 2500 Nan DS 4307.91 2 0.66 2826.64 1356000.3 0.26 1500 Shale 4309.91 2 0.7 3004.6 2665000.7 0.23 2500 Nan DS 4311.91 8 0.66 2861.45 1373000.4 0.26 1500 Nan DS 4319.91 8 0.65 2797.63 1558000.4 0.26 1500 Shale 4327.89 20 0.7 3028.1 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 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 6943.6 180 CarboLite 16/20 + SG 2 13887.2 4.5 4 4 PPA 40 YF126ST 7133.8 200 CarboLite 16/20 + SG 4 28535.2 5 5 6 PPA 40 YF126ST 6633.6 200 CarboLite 16/20 + SG 6 39801.6 5 6 8 PPA 40 YF126ST 6199.2 200 CarboLite 16/20 + SG 8 49593.6 5 7 10 PPA 40 YF126ST 5818 200 CarboLite 16/20 + SG 10 58180 5 8 12 PPA 40 YF126ST 4796 175 CarboLite 16/20 + SG 12 57552 4.38 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 27.29 23.05 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 61563 254788.4 1735.01 43.38 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 8 6595 246.7 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4047.05 4293.75 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 8 812.44 209.38 0.38 NDB-040 (Attachment K) 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): 12000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6111.5 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 4047.11 10 0.72 2926.72 1461000.3 0.22 1000 Shale 4057.09 15 0.69 2824.9 1762000.5 0.22 1000 Nanushuk 3 SS 4072.11 15.3 0.68 2766.16 1898000.5 0.22 1000 Top Nan CS 4087.4 19.5 0.63 2581.24 900400.2 0.27 1000 Nan SS 4106.89 2 0.69 2838.53 2665000.7 0.23 2500 Nan CS 4108.89 1.5 0.64 2645.92 1292000.4 0.26 1000 Nan CS 4110.4 4.5 0.62 2533.37 643500.2 0.28 1000 Nan DS 4114.9 3.5 0.69 2844.63 1774000.4 0.26 1500 NDB-040 (Attachment K) 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 4118.41 14.5 0.66 2716.85 1388000.3 0.26 1500 Nan CS 4132.91 1.5 0.65 2696.83 1145000.3 0.27 1000 Nan CS 4134.42 12.5 0.64 2632.14 882100.2 0.27 1000 Nan DS 4146.92 2 0.65 2692.05 1402000.4 0.26 1500 Nan CS 4148.88 9 0.61 2521.05 853600.2 0.27 1000 Nan DS 4157.91 7 0.66 2745.71 1397000.4 0.26 1500 Nan DS 4164.9 9 0.65 2695.96 1132000.3 0.27 1500 Nan DS 4173.88 3.5 0.64 2680.88 1688000.4 0.26 1500 Nan DS 4177.4 5 0.64 2675.08 757000.2 0.27 1000 Nan DS 4182.41 2 0.7 2915.26 1795000.5 0.25 1500 Nan CS 4184.42 10.5 0.62 2593.42 735600.2 0.27 1000 Nan CS 4194.91 3.5 0.65 2715.25 1098000.3 0.27 1000 Nan CS 4198.39 2 0.62 2605.31 670200.2 0.28 1000 Nan CS 4200.39 5.5 0.66 2778.2 1300000.3 0.26 1000 Nan DS 4205.91 3.5 0.69 2924.25 1531000.4 0.26 1500 Nan DS 4209.42 3.5 0.64 2692.05 1193000.3 0.27 1500 NDB-040 (Attachment K) 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 4212.89 5.5 0.69 2913.08 1416000.4 0.26 1500 Nan CS 4218.41 10.5 0.64 2703.21 1171000.3 0.27 1000 Nan DS 4228.9 1.5 0.67 2821.13 1376000.4 0.26 1500 Nan DS 4230.41 5 0.62 2632.87 1139000.3 0.27 1500 Nan DS 4235.4 2 0.66 2799.81 1560000.5 0.26 1500 Nan DS 4237.4 4 0.63 2679.14 896400.2 0.27 1500 Nan DS 4241.4 2 0.68 2866.53 1656000.4 0.26 1500 Nan DS 4243.41 10 0.63 2663.76 981000.2 0.27 1500 Nan DS 4253.41 4 0.65 2782.98 1633000.4 0.26 1500 Nan DS 4257.41 4 0.7 2964.28 1749000.4 0.26 1500 Nan DS 4261.38 9.5 0.66 2794.3 1327000.4 0.26 1500 Nan DS 4270.9 2 0.62 2635.77 781500.2 0.27 1000 Nan DS 4272.9 9.5 0.69 2960.08 1692000.4 0.26 1500 Nan DS 4282.41 2 0.66 2822.72 1365000.4 0.26 1500 Shale 4284.42 2 0.7 2986.91 2665000.7 0.23 2500 Nan DS 4286.38 2 0.64 2726.85 1088000.3 0.27 1500 NDB-040 (Attachment K) 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 4288.39 2 0.7 2989.66 2665000.7 0.23 2500 Nan DS 4290.39 4 0.67 2854.49 1287000.3 0.26 1500 Shale 4294.39 19.5 0.7 3000.11 2665000.7 0.23 2500 Nan DS 4313.91 2 0.66 2830.56 1356000.3 0.26 1500 Shale 4315.91 2 0.7 3008.81 2665000.7 0.23 2500 Nan DS 4317.91 8 0.66 2865.37 1373000.4 0.26 1500 Nan DS 4325.89 8 0.65 2801.4 1558000.4 0.26 1500 Shale 4333.89 20 0.7 3032.16 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 16170 385 9.62 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 (%) 27.08 22.91 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 59709.4 245217 1680.77 42.02 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 9 6111.5 244.68 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4053.84 4298.52 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 9 774.3 206.76 0.39 NDB-040 (Attachment K) 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 7312.6 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 4053.12 10 0.72 2931.07 1461000.3 0.22 1000 Shale 4063.09 15 0.69 2829.11 1762000.5 0.22 1000 Nanushuk 3 SS 4078.12 15.3 0.68 2770.22 1898000.5 0.22 1000 Top Nan CS 4093.41 19.5 0.63 2585.01 900400.2 0.27 1000 Nan SS 4112.89 2 0.69 2842.74 2665000.7 0.23 2500 Nan CS 4114.9 1.5 0.64 2649.84 1292000.4 0.26 1000 Nan CS 4116.4 4.5 0.62 2537.15 643500.2 0.28 1000 Nan DS 4120.9 3.5 0.69 2848.83 1774000.4 0.26 1500 Nan DS 4124.41 14.5 0.66 2720.76 1388000.3 0.26 1500 NDB-040 (Attachment K) 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 4138.91 1.5 0.65 2700.75 1145000.3 0.27 1000 Nan CS 4140.39 12.5 0.64 2635.92 882100.2 0.27 1000 Nan DS 4152.89 2 0.65 2695.96 1402000.4 0.26 1500 Nan CS 4154.89 9 0.61 2524.67 853600.2 0.27 1000 Nan DS 4163.91 7 0.66 2749.77 1397000.4 0.26 1500 Nan DS 4170.9 9 0.65 2699.88 1132000.3 0.27 1500 Nan DS 4179.89 3.5 0.64 2684.65 1688000.4 0.26 1500 Nan DS 4183.4 5 0.64 2678.99 757000.2 0.27 1000 Nan DS 4188.39 2 0.7 2919.46 1795000.5 0.25 1500 Nan CS 4190.39 10.5 0.62 2597.19 735600.2 0.27 1000 Nan CS 4200.89 3.5 0.65 2719.17 1098000.3 0.27 1000 Nan CS 4204.4 2 0.62 2609.08 670200.2 0.28 1000 Nan CS 4206.4 5.5 0.66 2782.26 1300000.3 0.26 1000 Nan DS 4211.91 3.5 0.69 2928.46 1531000.4 0.26 1500 Nan DS 4215.39 3.5 0.64 2695.82 1193000.3 0.27 1500 Nan DS 4218.9 5.5 0.69 2917.14 1416000.4 0.26 1500 NDB-040 (Attachment K) 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 4224.41 10.5 0.64 2706.98 1171000.3 0.27 1000 Nan DS 4234.91 1.5 0.67 2825.19 1376000.4 0.26 1500 Nan DS 4236.42 5 0.62 2636.64 1139000.3 0.27 1500 Nan DS 4241.4 2 0.66 2803.72 1560000.5 0.26 1500 Nan DS 4243.41 4 0.63 2682.91 896400.2 0.27 1500 Nan DS 4247.41 2 0.68 2870.59 1656000.4 0.26 1500 Nan DS 4249.41 10 0.63 2667.53 981000.2 0.27 1500 Nan DS 4259.42 4 0.65 2786.9 1633000.4 0.26 1500 Nan DS 4263.39 4 0.7 2968.49 1749000.4 0.26 1500 Nan DS 4267.39 9.5 0.66 2798.21 1327000.4 0.26 1500 Nan DS 4276.9 2 0.62 2639.4 781500.2 0.27 1000 Nan DS 4278.9 9.5 0.69 2964.28 1692000.4 0.26 1500 Nan DS 4288.39 2 0.66 2826.79 1365000.4 0.26 1500 Shale 4290.39 2 0.7 2991.11 2665000.7 0.23 2500 Nan DS 4292.39 2 0.64 2730.63 1088000.3 0.27 1500 Shale 4294.39 2 0.7 2993.87 2665000.7 0.23 2500 NDB-040 (Attachment K) Zone Mechanical Properties Zone Name Top TVD (ft) Zone Height (ft) Frac Gradient (psi/ft) Min. Stress (psi) Young’s Modulus (psi) Poisson’s Ratio Toughness (psi.in0.5) Nan DS 4296.39 4 0.67 2858.4 1287000.3 0.26 1500 Shale 4300.39 19.5 0.7 3004.17 2665000.7 0.23 2500 Nan DS 4319.91 2 0.66 2834.62 1356000.3 0.26 1500 Shale 4321.92 2 0.7 3013.01 2665000.7 0.23 2500 Nan DS 4323.92 8 0.66 2869.43 1373000.4 0.26 1500 Nan DS 4331.89 8 0.65 2805.32 1558000.4 0.26 1500 Shale 4339.9 20 0.7 3036.37 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 45 YF126ST 16800 400 8.89 2 1 PPA 45 YF126ST 7238.8 180 CarboLite 16/20 + SG 1 7238.8 4 3 2 PPA 45 YF126ST 6943.6 180 CarboLite 16/20 + SG 2 13887.2 4 4 4 PPA 45 YF126ST 7133.8 200 CarboLite 16/20 + SG 4 28535.2 4.44 5 6 PPA 45 YF126ST 6633.6 200 CarboLite 16/20 + SG 6 39801.6 4.44 6 8 PPA 45 YF126ST 6199.2 200 CarboLite 16/20 + SG 8 49593.6 4.44 7 10 PPA 45 YF126ST 5818 200 CarboLite 16/20 + SG 10 58180 4.44 8 12 PPA 45 YF126ST 4796 175 CarboLite 16/20 + SG 12 57552 3.89 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 27.29 23.05 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 61563 254788.4 1735.01 38.56 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 10 7312.6 250.27 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4058.03 4308.3 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 10 830.89 211.3 0.42 NDB-040 (Attachment K) 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): 6000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 7141.4 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 4061.1 10 0.72 2936.9 1461000.3 0.22 1000 Shale 4071.1 15 0.69 2834.6 1762000.5 0.22 1000 Nanushuk 3 SS 4086.1 15.3 0.68 2775.6 1898000.5 0.22 1000 Top Nan CS 4101.4 19.5 0.63 2590 900400.2 0.27 1000 Nan SS 4120.9 2 0.69 2848.2 2665000.7 0.23 2500 Nan CS 4122.9 1.5 0.64 2655 1292000.4 0.26 1000 Nan CS 4124.4 4.5 0.62 2542 643500.2 0.28 1000 Nan DS 4128.9 3.5 0.69 2854.3 1774000.4 0.26 1500 Nan DS 4132.4 14.5 0.66 2726 1388000.3 0.26 1500 NDB-040 (Attachment K) 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 4146.9 1.5 0.65 2706 1145000.3 0.27 1000 Nan CS 4148.4 12.5 0.64 2641 882100.2 0.27 1000 Nan DS 4160.9 2 0.65 2701.1 1402000.4 0.26 1500 Nan CS 4162.9 9 0.61 2529.6 853600.2 0.27 1000 Nan DS 4171.9 7 0.66 2755 1397000.4 0.26 1500 Nan DS 4178.9 9 0.65 2705 1132000.3 0.27 1500 Nan DS 4187.9 3.5 0.64 2689.8 1688000.4 0.26 1500 Nan DS 4191.4 5 0.64 2684.1 757000.2 0.27 1000 Nan DS 4196.4 2 0.7 2925 1795000.5 0.25 1500 Nan CS 4198.4 10.5 0.62 2602.1 735600.2 0.27 1000 Nan CS 4208.9 3.5 0.65 2724.3 1098000.3 0.27 1000 Nan CS 4212.4 2 0.62 2614 670200.2 0.28 1000 Nan CS 4214.4 5.5 0.66 2787.5 1300000.3 0.26 1000 Nan DS 4219.9 3.5 0.69 2934 1531000.4 0.26 1500 Nan DS 4223.4 3.5 0.64 2701 1193000.3 0.27 1500 Nan DS 4226.9 5.5 0.69 2922.7 1416000.4 0.26 1500 NDB-040 (Attachment K) 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 4232.4 10.5 0.64 2712.1 1171000.3 0.27 1000 Nan DS 4242.9 1.5 0.67 2830.5 1376000.4 0.26 1500 Nan DS 4244.4 5 0.62 2641.6 1139000.3 0.27 1500 Nan DS 4249.4 2 0.66 2809 1560000.5 0.26 1500 Nan DS 4251.4 4 0.63 2688 896400.2 0.27 1500 Nan DS 4255.4 2 0.68 2876 1656000.4 0.26 1500 Nan DS 4257.4 10 0.63 2672.5 981000.2 0.27 1500 Nan DS 4267.4 4 0.65 2792.2 1633000.4 0.26 1500 Nan DS 4271.4 4 0.7 2974 1749000.4 0.26 1500 Nan DS 4275.4 9.5 0.66 2803.5 1327000.4 0.26 1500 Nan DS 4284.9 2 0.62 2644.4 781500.2 0.27 1000 Nan DS 4286.9 9.5 0.69 2969.8 1692000.4 0.26 1500 Nan DS 4296.4 2 0.66 2832 1365000.4 0.26 1500 Shale 4298.4 2 0.7 2996.7 2665000.7 0.23 2500 Nan DS 4300.4 2 0.64 2735.7 1088000.3 0.27 1500 Shale 4302.4 2 0.7 2999.5 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 4304.4 4 0.67 2863.8 1287000.3 0.26 1500 Shale 4308.4 19.5 0.7 3009.8 2665000.7 0.23 2500 Nan DS 4327.9 2 0.66 2839.8 1356000.3 0.26 1500 Shale 4329.9 2 0.7 3018.6 2665000.7 0.23 2500 Nan DS 4331.9 8 0.66 2874.7 1373000.4 0.26 1500 Nan DS 4339.9 8 0.65 2810.5 1558000.4 0.26 1500 Shale 4347.9 20 0.7 3042 2665000.7 0.23 2500 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 10 PAD 45 YF126ST 17850 425 9.44 2 1 PPA 45 YF126ST 7640.7 190 CarboLite 16/20 + SG 1 7640.7 4.22 3 2 PPA 45 YF126ST 8100.8 210 CarboLite 16/20 + SG 2 16201.6 4.67 4 4 PPA 45 YF126ST 8025.2 225 CarboLite 16/20 + SG 4 32100.8 5 5 6 PPA 45 YF126ST 7462.7 225 CarboLite 16/20 + SG 6 44776.2 5 NDB-040 (Attachment K) 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) 6 8 PPA 45 YF126ST 6974 225 CarboLite 16/20 + SG 8 55792 5 7 10 PPA 45 YF126ST 6109 210 CarboLite 16/20 + SG 10 61090 4.67 8 12 PPA 45 YF126ST 5070 185 CarboLite 16/20 + SG 12 60840 4.11 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.55 22.43 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 67232.4 278441.3 1894.99 42.11 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max SurfacePressure (psi) Max Height (ft) Stage 11 7141.4 250.77 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4064.84 4315.61 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 11 859.45 210.24 0.42 NDB-040 (Attachment K) 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 6312.8 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 4066.11 10 0.72 2940.5 1461000.3 0.22 1000 Shale 4076.12 15 0.69 2838.1 1762000.5 0.22 1000 Nanushuk 3 SS 4091.11 15.3 0.68 2778.92 1898000.5 0.22 1000 Top Nan CS 4106.4 19.5 0.63 2593.13 900400.2 0.27 1000 Nan SS 4125.89 2 0.69 2851.59 2665000.7 0.23 2500 Nan CS 4127.89 1.5 0.64 2658.25 1292000.4 0.26 1000 Nan CS 4129.4 4.5 0.62 2545.12 643500.2 0.28 1000 Nan DS 4133.89 3.5 0.69 2857.82 1774000.4 0.26 1500 Nan DS 4137.4 14.5 0.66 2729.32 1388000.3 0.26 1500 NDB-040 (Attachment K) 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 4151.9 1.5 0.65 2709.3 1145000.3 0.27 1000 Nan CS 4153.41 12.5 0.64 2644.18 882100.2 0.27 1000 Nan DS 4165.91 2 0.65 2704.37 1402000.4 0.26 1500 Nan CS 4167.91 9 0.61 2532.65 853600.2 0.27 1000 Nan DS 4176.9 7 0.66 2758.33 1397000.4 0.26 1500 Nan DS 4183.89 9 0.65 2708.29 1132000.3 0.27 1500 Nan DS 4192.91 3.5 0.64 2693.06 1688000.4 0.26 1500 Nan DS 4196.39 5 0.64 2687.26 757000.2 0.27 1000 Nan DS 4201.41 2 0.7 2928.46 1795000.5 0.25 1500 Nan CS 4203.41 10.5 0.62 2605.17 735600.2 0.27 1000 Nan CS 4213.91 3.5 0.65 2727.58 1098000.3 0.27 1000 Nan CS 4217.39 2 0.62 2617.06 670200.2 0.28 1000 Nan CS 4219.39 5.5 0.66 2790.82 1300000.3 0.26 1000 Nan DS 4224.9 3.5 0.69 2937.45 1531000.4 0.26 1500 Nan DS 4228.41 3.5 0.64 2704.23 1193000.3 0.27 1500 Nan DS 4231.89 5.5 0.69 2926.14 1416000.4 0.26 1500 NDB-040 (Attachment K) 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 4237.4 10.5 0.64 2715.25 1171000.3 0.27 1000 Nan DS 4247.9 1.5 0.67 2833.89 1376000.4 0.26 1500 Nan DS 4249.41 5 0.62 2644.76 1139000.3 0.27 1500 Nan DS 4254.4 2 0.66 2812.28 1560000.5 0.26 1500 Nan DS 4256.4 4 0.63 2691.18 896400.2 0.27 1500 Nan DS 4260.4 2 0.68 2879.43 1656000.4 0.26 1500 Nan DS 4262.4 10 0.63 2675.66 981000.2 0.27 1500 Nan DS 4272.41 4 0.65 2795.46 1633000.4 0.26 1500 Nan DS 4276.41 4 0.7 2977.48 1749000.4 0.26 1500 Nan DS 4280.41 9.5 0.66 2806.77 1327000.4 0.26 1500 Nan DS 4289.9 2 0.62 2647.52 781500.2 0.27 1000 Nan DS 4291.9 9.5 0.69 2973.27 1692000.4 0.26 1500 Nan DS 4301.41 2 0.66 2835.34 1365000.4 0.26 1500 Shale 4303.41 2 0.7 3000.25 2665000.7 0.23 2500 Nan DS 4305.41 2 0.64 2738.89 1088000.3 0.27 1500 Shale 4307.41 2 0.7 3003.01 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 4309.42 4 0.67 2867.11 1287000.3 0.26 1500 Shale 4313.39 19.5 0.7 3013.3 2665000.7 0.23 2500 Nan DS 4332.91 2 0.66 2843.03 1356000.3 0.26 1500 Shale 4334.91 2 0.7 3022.15 2665000.7 0.23 2500 Nan DS 4336.91 8 0.66 2877.98 1373000.4 0.26 1500 Nan DS 4344.91 8 0.65 2813.73 1558000.4 0.26 1500 Shale 4352.89 20 0.7 3045.5 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 10 PAD 45 YF126ST 17850 425 9.44 2 1 PPA 45 YF126ST 9048.5 225 CarboLite 16/20 + SG 1 9048.5 5 3 2 PPA 45 YF126ST 9258.2 240 CarboLite 16/20 + SG 2 18516.4 5.33 4 4 PPA 45 YF126ST 9273.7 260 CarboLite 16/20 + SG 4 37094.8 5.78 5 6 PPA 45 YF126ST 8623.8 260 CarboLite 16/20 + SG 6 51742.8 5.78 6 8 PPA 45 YF126ST 6508.9 210 CarboLite 16/20 + SG 8 52071.2 4.67 7 8 PPA 45 YF126ST 1244.6 40 CarboLite 12/18 8 9956.8 0.89 8 10 PPA 45 YF126ST 6136.5 210 CarboLite 12/18 10 61365 4.67 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 26.27 22.73 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 67944.2 239795.5 1870 41.56 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 12 6312.8 251.2 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4070.2 4321.4 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 12 879 213.13 0.28 NDB-040 (Attachment K) 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): 6000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 6126.9 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 4073.1 10 0.72 2945.57 1461000.3 0.22 1000 Shale 4083.1 15 0.69 2842.88 1762000.5 0.22 1000 Nanushuk 3 SS 4098.1 15.3 0.68 2783.71 1898000.5 0.22 1000 Top Nan CS 4113.39 19.5 0.63 2597.63 900400.2 0.27 1000 Nan SS 4132.91 2 0.69 2856.52 2665000.7 0.23 2500 Nan CS 4134.91 1.5 0.64 2662.75 1292000.4 0.26 1000 Nan CS 4136.38 4.5 0.62 2549.33 643500.2 0.28 1000 Nan DS 4140.91 3.5 0.69 2862.61 1774000.4 0.26 1500 Nan DS 4144.39 14.5 0.66 2733.96 1388000.3 0.26 1500 NDB-040 (Attachment K) 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 4158.89 1.5 0.65 2713.8 1145000.3 0.27 1000 Nan CS 4160.4 12.5 0.64 2648.68 882100.2 0.27 1000 Nan DS 4172.9 2 0.65 2708.87 1402000.4 0.26 1500 Nan CS 4174.9 9 0.61 2536.86 853600.2 0.27 1000 Nan DS 4183.89 7 0.66 2762.97 1397000.4 0.26 1500 Nan DS 4190.91 9 0.65 2712.79 1132000.3 0.27 1500 Nan DS 4199.9 3.5 0.64 2697.56 1688000.4 0.26 1500 Nan DS 4203.41 5 0.64 2691.76 757000.2 0.27 1000 Nan DS 4208.4 2 0.7 2933.39 1795000.5 0.25 1500 Nan CS 4210.4 10.5 0.62 2609.52 735600.2 0.27 1000 Nan CS 4220.9 3.5 0.65 2732.08 1098000.3 0.27 1000 Nan CS 4224.41 2 0.62 2621.41 670200.2 0.28 1000 Nan CS 4226.41 5.5 0.66 2795.46 1300000.3 0.26 1000 Nan DS 4231.89 3.5 0.69 2942.38 1531000.4 0.26 1500 Nan DS 4235.4 3.5 0.64 2708.72 1193000.3 0.27 1500 Nan DS 4238.91 5.5 0.69 2930.92 1416000.4 0.26 1500 NDB-040 (Attachment K) 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 4244.39 10.5 0.64 2719.75 1171000.3 0.27 1000 Nan DS 4254.89 1.5 0.67 2838.53 1376000.4 0.26 1500 Nan DS 4256.4 5 0.62 2649.11 1139000.3 0.27 1500 Nan DS 4261.38 2 0.66 2816.92 1560000.5 0.26 1500 Nan DS 4263.39 4 0.63 2695.53 896400.2 0.27 1500 Nan DS 4267.39 2 0.68 2884.08 1656000.4 0.26 1500 Nan DS 4269.39 10 0.63 2680.01 981000.2 0.27 1500 Nan DS 4279.4 4 0.65 2800.1 1633000.4 0.26 1500 Nan DS 4283.4 4 0.7 2982.41 1749000.4 0.26 1500 Nan DS 4287.4 9.5 0.66 2811.41 1327000.4 0.26 1500 Nan DS 4296.92 2 0.62 2651.87 781500.2 0.27 1000 Nan DS 4298.88 9.5 0.69 2978.06 1692000.4 0.26 1500 Nan DS 4308.4 2 0.66 2839.84 1365000.4 0.26 1500 Shale 4310.4 2 0.7 3005.04 2665000.7 0.23 2500 Nan DS 4312.4 2 0.64 2743.39 1088000.3 0.27 1500 Shale 4314.4 2 0.7 3007.94 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 4316.4 4 0.67 2871.75 1287000.3 0.26 1500 Shale 4320.41 19.5 0.7 3018.24 2665000.7 0.23 2500 Nan DS 4339.9 2 0.66 2847.67 1356000.3 0.26 1500 Shale 4341.9 2 0.7 3026.94 2665000.7 0.23 2500 Nan DS 4343.9 8 0.66 2882.63 1373000.4 0.26 1500 Nan DS 4351.9 8 0.65 2818.23 1558000.4 0.26 1500 Shale 4359.91 20 0.7 3050.43 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 10 PAD 45 YF126ST 18900 450 10 2 1 PPA 45 YF126ST 10053.8 250 CarboLite 16/20 + SG 1 10053.8 5.56 3 2 PPA 45 YF126ST 10801.2 280 CarboLite 16/20 + SG 2 21602.4 6.22 4 4 PPA 45 YF126ST 9987 280 CarboLite 16/20 + SG 4 39948 6.22 5 6 PPA 45 YF126ST 9287 280 CarboLite 16/20 + SG 6 55722 6.22 6 8 PPA 45 YF126ST 6819 220 CarboLite 16/20 + SG 8 54552 4.89 7 8 PPA 45 YF126ST 1244.7 40 CarboLite 12/18 8 9957.6 0.89 8 10 PPA 45 YF126ST 6428.6 220 CarboLite 12/18 10 64286 4.89 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 25.71 22.28 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 73521.3 256121.8 2020 44.89 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 13 6126.9 252.05 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4076.85 4328.9 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 13 900.15 210.14 0.34 NDB-040 (Attachment K) 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): 6000 Element Size (m): Vertical: 6.1 Horizontal: 24.38 A maximum surface pressure was simulated as 5934.2 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 4076.12 10 0.72 2947.75 1461000.3 0.22 1000 Shale 4086.09 15 0.69 2845.06 1762000.5 0.22 1000 Nanushuk 3 SS 4101.12 15.3 0.68 2785.74 1898000.5 0.22 1000 Top Nan CS 4116.4 19.5 0.63 2599.51 900400.2 0.27 1000 Nan SS 4135.89 2 0.69 2858.55 2665000.7 0.23 2500 Nan CS 4137.89 1.5 0.64 2664.63 1292000.4 0.26 1000 Nan CS 4139.4 4.5 0.62 2551.21 643500.2 0.28 1000 Nan DS 4143.9 3.5 0.69 2864.64 1774000.4 0.26 1500 NDB-040 (Attachment K) 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 4147.41 14.5 0.66 2735.85 1388000.3 0.26 1500 Nan CS 4161.91 1.5 0.65 2715.83 1145000.3 0.27 1000 Nan CS 4163.39 12.5 0.64 2650.56 882100.2 0.27 1000 Nan DS 4175.89 2 0.65 2710.76 1402000.4 0.26 1500 Nan CS 4177.89 9 0.61 2538.74 853600.2 0.27 1000 Nan DS 4186.91 7 0.66 2764.85 1397000.4 0.26 1500 Nan DS 4193.9 9 0.65 2714.67 1132000.3 0.27 1500 Nan DS 4202.89 3.5 0.64 2699.44 1688000.4 0.26 1500 Nan DS 4206.4 5 0.64 2693.64 757000.2 0.27 1000 Nan DS 4211.38 2 0.7 2935.42 1795000.5 0.25 1500 Nan CS 4213.39 10.5 0.62 2611.4 735600.2 0.27 1000 Nan CS 4223.88 3.5 0.65 2733.96 1098000.3 0.27 1000 Nan CS 4227.4 2 0.62 2623.3 670200.2 0.28 1000 Nan CS 4229.4 5.5 0.66 2797.49 1300000.3 0.26 1000 Nan DS 4234.91 3.5 0.69 2944.41 1531000.4 0.26 1500 Nan DS 4238.39 3.5 0.64 2710.61 1193000.3 0.27 1500 NDB-040 (Attachment K) 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 4241.9 5.5 0.69 2933.1 1416000.4 0.26 1500 Nan CS 4247.41 10.5 0.64 2721.63 1171000.3 0.27 1000 Nan DS 4257.91 1.5 0.67 2840.56 1376000.4 0.26 1500 Nan DS 4259.42 5 0.62 2651 1139000.3 0.27 1500 Nan DS 4264.4 2 0.66 2818.95 1560000.5 0.26 1500 Nan DS 4266.4 4 0.63 2697.41 896400.2 0.27 1500 Nan DS 4270.41 2 0.68 2886.11 1656000.4 0.26 1500 Nan DS 4272.41 10 0.63 2681.89 981000.2 0.27 1500 Nan DS 4282.41 4 0.65 2801.98 1633000.4 0.26 1500 Nan DS 4286.38 4 0.7 2984.44 1749000.4 0.26 1500 Nan DS 4290.39 9.5 0.66 2813.3 1327000.4 0.26 1500 Nan DS 4299.9 2 0.62 2653.61 781500.2 0.27 1000 Nan DS 4301.9 9.5 0.69 2980.24 1692000.4 0.26 1500 Nan DS 4311.38 2 0.66 2841.87 1365000.4 0.26 1500 Shale 4313.39 2 0.7 3007.21 2665000.7 0.23 2500 Nan DS 4315.39 2 0.64 2745.27 1088000.3 0.27 1500 NDB-040 (Attachment K) 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 4317.39 2 0.7 3009.97 2665000.7 0.23 2500 Nan DS 4319.39 4 0.67 2873.78 1287000.3 0.26 1500 Shale 4323.39 19.5 0.7 3020.27 2665000.7 0.23 2500 Nan DS 4342.91 2 0.66 2849.7 1356000.3 0.26 1500 Shale 4344.91 2 0.7 3029.11 2665000.7 0.23 2500 Nan DS 4346.92 8 0.66 2884.66 1373000.4 0.26 1500 Nan DS 4354.89 8 0.65 2820.26 1558000.4 0.26 1500 Shale 4362.89 20 0.7 3052.46 2665000.7 0.23 2500 NDB-040 (Attachment K) 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 10 PAD 45 YF126ST 16800 400 8.89 2 1 PPA 45 YF126ST 8244.2 205 CarboLite 16/20 + SG 1 8244.2 4.56 3 3 PPA 45 YF126ST 7601.9 205.1 CarboLite 16/20 + SG 3 22805.7 4.56 4 5 PPA 45 YF126ST 9624.2 280 CarboLite 16/20 + SG 5 48121 6.22 5 7 PPA 45 YF126ST 8171.3 255 CarboLite 16/20 + SG 7 57199.1 5.67 6 9 PPA 45 YF126ST 7653.3 255 CarboLite 16/20 + SG 9 68879.7 5.67 7 10 PPA 45 YF126ST 6545.4 224 CarboLite 12/18 10 65454 4.98 Pad Percentage Clean Pad Percentage (%) Dirty Pad Percentage (%) 25.99 21.93 Totals Fluid Vol (gal) Proppant mass (lbm) Slurry Vol (bbl) Pump Time (min) 64640.3 270703.7 1824.09 40.54 NDB-040 (Attachment K) ǣ Summary Table: Maximum Pressures Case Max Parameters Perforation Max Surface Pressure (psi) Max Height (ft) Stage 14 5934.2 248.19 Summary Table: Height TVDs Max Fracture Top TVD (ft) Max Fracture Bottom TVD (ft) 4081.54 4329.73 Summary Table: Propped Fracture Results Case Closed Fracture Parameters Perforation Length (ft) Height (ft) Avg Wellbore Width (in) Stage 14 820.93 207.21 0.35