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Home My WebLink About2019-12-05_319-552STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 DEC - 5 2019 AOG CG 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program El Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Flow Test 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Oil Search Alaska Exploratory ❑✓ Development ❑ SireOgraphic ❑ Service ❑ 3. Address: 900 E Benson Boulevard 6. API Number: Anchorage, AK Bat 50- 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? INA Stirrup 1 Will planned perforations require a spacing exception? Yes ❑ No ❑+ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 392044 Jun deflned 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): Casing Length Size MD TVD Bunt Collapse Structural Conductor 16" 3060 1450 Surface 915/8" 7930 4760 Intermediate Production 7" 7240 7800 Liner Perforation Depth MD (ft): Perforetion Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3-1/2", 9.2# L-80, Vamtop 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 0 BOP Sketch ❑ Exploratory ❑� Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3!7/2020 OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Marc Kuck Contact Name: Marc Kuck Authorized Title: Senior Engineering Manager Contact Email: marcAuck@oilsearch.com Contact Phone: 907,375-4600 L/ Authorized SignaDate: % COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other. Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Data: Submit Form and Farm 10-403 Revised 4Y2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate NW Oil Search Stirrup 1 Sundry Application Requirements 1. Affidavit of Notice — Attachment A 2. Plat showing well location, as well as''/: mile radius around well with all well penetrations, fractures, and faults within that radius —Attachments B and F 3. Identification of freshwater aquifers within % mile radius —There are no known underground sources of drinking water within a half mile radius of the current proposed well bore trajectory for Stirrup -1. At the Stirrup -1 location, the Permafrost interval extends down to approximately 630-850 ft and therefore, no known shallow aquifers (typically found down to 400ft depth) are located at the Stirrup -1 location. 4. Plan for freshwater sampling —There are no known freshwater wells proximal to the proposed operations, therefore no water sampling is planned. 5. Detailed casing and cementing information —Attachment C 6. Assessment of casing and cementing operations — Assessment of casing and cementing operations will be performed after cementing operations are complete. 7. Casing and tubing pressure test information — Pressure testing will be performed upon completion of the well's lateral section. 8. Pressure ratings for wellbore, wellhead, BOPE and treating head — Attachment D 9. a -d Lithological and geological descriptions of each zone — Attachment E and below e. Estimated fracture pressure for each zone listed below: Treatment IA IA PRV (psi) GORV (psi) Pump Trip THeld Pressure Maz Pressure (Psi) Depth (ft) (psi) Job 2,600 2,900 5,400 5,000 Treatment MD Pert TVD Perf Max Frac Frac % Max Rate Maz Max Prop Depth (ft) Depth (ft) Height (ft) Length (ft) (bpm) Pressure Conc. (psi) (PPA) lob Max 10. Mechanical condition of wells transecting the confining zones — No wells within 1/2 - mile radius of Stirrup 1. Please see attachment B as reference. 11. Location of faults and fractures in wellbore % mile radius — Based on the seismic and well data covering the Stirrup -1 location, there are no known faults or fracture zones Oil Search does not expect that any hydraulic fractures during the stimulation of Stirrup - 1 will intersect any faults near the wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, Oil Search will flush and terminate the stage immediately. 12. Detailed proposed fracturing program—Attachments G & H 13. Flowback procedure — Attachment I Section (b) Casing Pressure Test — We will not be treating through production or intermediate casing strings. Section (c) Fracture String Pressure Test — Attachment J Section (d) Pressure Relieve Valve—Attachment K Proposed Wellbore Schematic—Attachment L Oil Search December 4, 2019 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 Stirrup 1 Well 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 Stirrup 1 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 PO Box 240927 Anchorage, AK 99524 Direct: 907-375-4624 tim.ionesCdoilsearch.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 Y. mile of the proposed Stirrup 1 well trajectory and fracture stimulation. Please contact me should you require additional Tim JonA Land Ma Oil Search Alaska, LLC Anchorage oMlca Tel .+ 1 907 375 4600 PO Bax 240927 Fax +1907 375 4630 Anchorage, AK 99524-0927 v cilsearch mm Attachment A Distribution List: Alaska Division of Oil and Gas Oil Search (Alaska), LLC Repsol E&P USA Inc. a Oil Search Attachment A Contact Information: State of Alaska Department of Natural Resources Alaska Division of Oil and Gas 550 W 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Oil Search (Alaska), LLC 510 L Street, Suite 310 Anchorage, AK 99501 Repsol E&P USA Inc. Attn: Dennis Henderson 2455 Technology Forest Blvd. The Woodlands, TX 77381 Oil Search Alaska, LLC Anchorage office PO Box 240927 Anchorage, AK 99524-0927 (0) Oil Search Tel: +1907 375 4600 Fax: +1907 375 4630 w .oilsearoh.com CERTIFIED MAIL CERTIFIED MAIL CERTIFIED MAIL Attachment A Affidavit State of Alaska, Third Judicial District Personally appeared before me, Timothy Jones, who, being duly sworn according to law, deposes and says: 1. 1, Timothy Jones, am the Land Manager for Oil Search (Alaska), LLC and a Registered Professional Landman #84167. 2. The Owners, Landowners, Surface Owners and Operators, as defined in relevant state statutes and regulations, identified in the attached Notice of Operations are correct to the best of my knowledge. 3. The well location in the attached Exhibit A was taken from Oil Search (Alaska), LLC's Permit to Drill submitted to AOGCC. 4. The attached Notice of Operations was sent to the identified Owners, Landowners, Surface Owners and Operators by certified mail. Further the affia% sayeth naught Timothy Jon4sj f RPL #84167 V U UNITED STATES OF AMERICA § STATE OF ALASKA STEPH LIRETTE Notary Public State of Alaska My Commission Expires Jul 21. 2023 _��'"'� Date ly Subscribed and sworn to before me on the day of December, 2019. /� ��1 Notary Public My commission expires: I' L ( • ? 3 Attachment A ` • { w�, !!! ! JIM— moo , 2 ®!` � / ! � � / \ 10 ) 0 ;■/ \}),! . � � § ] { } § u cu �EA ! Ingo � , O 7" Production Casing Section Overview 7" 26# L80 Vam Top HC Casing Burst Collapse Tensile ID Drik ID Connection Optimal Make- Make -Up (Psi) (Psi) (klbs) (in) (in) OD up Torque Loss (in) (k-Ibs) (in) 7240 5410 604 6.276 6.151 7.000 11950 4.776 Production Casing Cement —STAGE 1 Casing 7" 26# L80 Vam Top HC Casing Basis Total Cement Volume Notes Job will be mixed on the fly Two stage cement job, first stage pumped with top and bottom plugs Production Casing Cement—STAGE 2 Casing 7" 26# L80 Vam Top HC Casing Basis Total Cement Volume Notes Job will be mixed on the fly Two stage cement job, second stage pumped with top plug only Attachment C Production Casing Proposed Cementing Program 1. Pump the first stage cement job as per Halliburton Cementing Program. a) Stage 1 is planned to be pumped as follows: ii. Drop Bypass Plug A. Land Shut Off Plug on Baffle Adapter, bump plug with 500psi over final circulating pressure. Shut down pumps, bleed off pressure and verify floats are holding. xii. Reload Cement Head with Second Stage Top Cement Plug only. DO NOT load Second Stage Bottom Plug as this will not be dropped. xiii. Pressure up to 3,300 psi (+/-250psi) to shift open ES -Cementer (pressure up against shut off plug landed on baffle adaptor in the shoe track). b) Final volumes will be detailed in the Halliburton Cement Program based on actual well depths. c) Do not pump over the calculated displacement plus half of the three joint shoe volume plus 0.2bbs for mud compressibility (" 2.3bbls Y. shoe +0.2bbls mud compressibility= —2.5bbls total). If plug does not bump refer to contingency cement procedures. d) Verify floats are holding. If floats have failed refer to contingency cement procedures. Attachment C 2. Once the ES -Cementer stage tool has been opened circulate minimum of 1.Sx BU from stage tool depth. Initiate circulation through step rate method. Target 8bpm but limit pump rate if losses are observed. Monitor returns for cement and spacer and attempt to estimate volumes. 3. Wait on first stage tail cement to reach 50psi compressive strength (" 5hrs). 4. Proceed to pump the second stage cement job as per Halliburton Cementing Program. a) Stage 2 is planned to be pumped as follows: iv. Drop Second Stage Top Plug b) DO NOT DROP Second Stage Bottom Plug. Lesson Learned 2019: 2nd stage bottom plug prematurely closed the ES -cementer and filled the casing with cement. c) Final volumes will be detailed in the Halliburton Cement Program based on actual well depths. d) When Second Stage Top Plug lands hold pressure for 2 mins then release pressure and observe for flow back. If no excessive flowback is observed, then tool is closed. If tool is not closed refer to contingency procedures. e) Monitor for cement returns at surface and verify a plan is in place to segregate cement contaminated returns. 5. Rig down Halliburton cement head and lines. 6. Backout and retrieve the casing hanger running tool. Attachment C M T FEMALE O . �'[` 16"x 9-5/8"x 7"x 4-1/2 x 3-1/2" 5/10M MB -230 Multibml Assembly, BA17UGHES With MB -230 Upper Head and MB -230 Tubing Hanger and K Tubing Bonnet 1 aGEmmparry MtWU1111C111 U 9-lQ-(4ACME)OTIS 4-1116-W 41/16.10M c ƒ22 uj c / / / / § / u / ( \ § 0 / � E 7 fu@ o c� 3— L 2 0 5>_) ) °== c ° g uƒ u u= 4- 7 0 5 c 3$ E t a f u\/�ƒ > ® @ / 3 /Ln — \ / ( / f m ° 3 � \ 0 = ®� § m r £ + G$&\ c$ m e s e V)¥ = » k b® E 0tW c% \ ± t u M \ ) ƒ m / \ 5 R # / a e 2 § = c — E-0 a) � � -0 / a) > % m m-0« E o m Ln o T L cu L� r "a Ul a) t— Q ru 1� 1 N L Q m C Schlumberger FracCADE" STIMULATION PROPOSAL Operator Oil Search Well Stirrup Field Pikka Formation Well Location County State Alaska Country United States Prepared for Scott Leahy Service Point Prudhoe Bay, Alaska Business Phone 1907 659 2434 Date Prepared 11 21 2019 FAX No. 1907 659 2538 Prepared by Mike Hyatt Phone 9072734748 E Mail Address MHyatt@slb.com • Mal, M Schlumberger Dachoimar Notice' This information is presented in goad with, but no warranty is given by antl Schlumberger assumes no liability for advice or recommmulations made cuncemin9 results te be obtained from the use of any product a, write. The resume given are connotes based an calculations produced by a computer model including enforce assumptions an Ilse well, ressrsor r and l eam ent The results depend on Input dab provided by Isle Operster and manatee as to aalmaw a data and Can be no more accepts, than me medal. Me assumptions; and each Input deal. The Information preiemed IS SChlumllef C best estimate of the acted results that may be acmMVed and Should be used for Comparison purposes ramerthen absolute velue5. The quality of input data, and hence pouts, may be improved@rough the use of certain tests antl procedures which ScMumbergerom assist in ;awning, The Operator has superior knowledge of the will, to reserveir,1116 field and candlhon5 affecting Nem, t*a Options is mare of any conditions Wfiemby a neighboring well or wells might be affected by Ole IreaMent opposed herein RIS Me Operator a responsibility moble Me owner or owners of Me Well or welle accordingly. Prices quoted are estimates only and are good for 30 days from Me date of issue. Actual Charges may were depending upon time, equipment and material uhimllely required b ,mere these sevic65. Attachment G 5 ch I u m be rge r -Private Client Oil Search Well Oil Se Schlumhergcr W Formation District Prudhoe Bay, Alaska Section 1: Zone Data Attachment Schlumberger -Private Client Oil Search Well Schlumherger O......_ Formation District rruonoe nay, Alaska Attachment Schlumberger -Private Client Oil Search Well Oil Schlumberger l• Formation District Prudhoe Bay, Alaska Section 2: Propped Fracture Schedule Pumping Schedule Please note thatthis pumping schedule is under -displaced by5.0 bbl. Fluid Totals 1081 bbl of YF120ST 37 bbl of WFI20 Proppant Totals 1581DO lb of CarboLite 16/20 400DO lb of 16/20 CarboBond Lite Pad Percentages % PAD Clean 16.2 %PAD Dirty 13.6 Attachment Schlumberger -Private Job Description Step Name Pump Rate (bbl/min) Fluid Name Step Fluid Volume (bbl) Gel Conic. (Ib/mgal) Prop. Type and Mesh Prop. Conc. (PPA) PAD 25.0 YF120ST 175 20.0 0.00 1.0 PPA 25.0 YF120ST 120 20.0 CarboLite 16/20 1.00 2.0 PPA 25.0 YF120ST 129 20.0 CarboLite 16/20 2.00 4.0 PPA 25.0 YF120ST 191 20.0 CarboLite 16720 4.00 6.0 PPA 25.0 YF120ST 178 20.0 CarboLite 16/20 8.0 PPA 25.0 YF120ST 185 20.0 CarboLite 16/20 PPA25.0YF120ST103 20.0 16/20 CarbaBond Lite V1000 FLUSH 25.0 WF120 37 30.0 Please note thatthis pumping schedule is under -displaced by5.0 bbl. Fluid Totals 1081 bbl of YF120ST 37 bbl of WFI20 Proppant Totals 1581DO lb of CarboLite 16/20 400DO lb of 16/20 CarboBond Lite Pad Percentages % PAD Clean 16.2 %PAD Dirty 13.6 Attachment Schlumberger -Private Client Well Oil Search ^•-��- Schlumberger Formation District Prudhoe Bay, Alaska Job Execution Step Step Cum. Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (lb) (lb) Pressure )min) (min) (bbl) (bbl) (bbl) )psi) PAD 175 175 175 175.0 0 0 7.0 7.0 1.0 PPA 120 295 125 300.0 5029 .rro9 F n to n ( IO.OPPA 1 103 1 1081 1 150 1 1289.3 1 40000 1 198170 1 Attachment G Schlumberger -Private WClient OilSearch Schlumberger ell •—��• Formation District Prudhoe Bay, Alaska Section 3: Propped Fracture Simulation The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Initial Fracture Top TVD -------------- ......... Initial Fracture Bottom TVD Propped Fracture Fracture Half -Length EOJ Hyd Height at Well------------------------- Average Propped Width ----------------------- Net Pressure --------------- Max Surface Pressure„ Attachment Schlumberger -Private Schlumberger Client: Oil Search Alaska Well: Stirrup Basin/Field: Pikka State: Alaska County/Parish: North Slope Borough Case: <0.1 % Disclosure Type: PreJob Well Completed: 3/14/2020 Date Prepared: 11/19/2019 2:19 PM Report ID: RPT -64248 rte wrwwwmeaaeom she Narcs abort rcoresennmesvmmolion o)wotnaMaddinres. Warcrk eupplkdbytlienr. - Water(including Mix Water Supplied bClient)- ^72% 66402-684 Ceramic materials and wares, chemicals —27% 9000-30-0 Guar um <1 % 56-81-5 1,2,3 -Pro anetriol <0.1 % 1303-96-4 Sodium tetraborate decah drate <0.1 % 102-71-6 2,2',2"-nitrilotriethanol <0.1 % 107-21-1 Ethylene glycol <0.1 % 129898-01-7 2-Propenoic acid, polymer with sodium phosphinate <0.1% 67-63-0 Propan-2-ol <0.1 % 50-70-0 Sorbitol <0.1 % 7727-54-0Diammonium peroxodisulphate <0.1 % 68131-40-8 Alcohols, cl1-15-secunda , ethoxylated <0.1 % 111-76-2 2-butoxyethanol <0.1 % 34398-01-1 Ethoxylated CII Alcohol <0.1 % 68131-39-5 Ethoxylated Alcohol <0.01 % 7647-14-5 Sodium chloride <0.01 % 25038-72-6 Vin lidene chloride/meth acrylate coipomer <0.01 % 1310-73-2 Sodium hydroxide <0.01 % 10043-52-4 Calcium Chloride < 0.01 % 91053-39-3 Diatomaceous earth, calcined < 0.01 % 11242-5 Undecanol <0.01 % 7631-86-9 Nan -crystalline silica (impurity) <0.001 % 111-46-6 2,2"-olrydiethanol (impurity) <0.001 % 10377-60-3 Magnesium nitrate <0.001 % 14807-96-6 Magnesium silicate hydrate talc <0.001 % 26172-55-4 5 -chloro -2 -meth I-2h-isothiazolol-3-one <0.001 % 7786-30-3 Magnesium chloride <0.001 % 7447.40-7 Potassium chloride (impurity) <0.001 % 9002-84-0 ly(tetra8uoroeth leve) <0.0001 % 2682-20-4 2 -meth I-2h-isothiazol-3-one <0.0001 % 127-08-2 Acetic acid, potassium salt <0.0001 % 68-04-2 Sodium citrate <0.0001 % 14808-60-7 Quartz, Crystalline silica <0.0001 % 14464-46-1 Cristobalite <0.0001 % 9012-54-8 64-19-7 _ Hemicellulase enzyme Acetic acid (impurity) <0.0001 % <0.0001 % 2634-33-5 1,2-benzisothiazolin-3-une <0,00001 % sr Attachment H 0 Schlumberger 2019. Used by Oil Search Alaska by permission. Page: 1 / 2 Schlumberger Client: Oil Search Alaska Well: Stirrup Basin/Field: Pikka State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre -lob Well Completed: 3/14/2020 Date Prepared: 11/19/2019 2:19 PM Report ID: RPT -64248 • Mix wooer is supplkd by Me client 5ehfUonw gerhasper{armed no arulysb olthe woterwMconnotprovide a breakdown o/eewroneen Motmayhm been added to the waterby Mirdponres 'fie emloodon ofenached dnwmeotlspedormedbosed on Me wmposlMoo of he 0.*ed prodwc to he Mon,motsu.F rompwlaond InJormaaon ww known M 6R6Gemlwls w o/Medote a/the document was ProduwJ. Any new updates will not be w/le In Mu document. 0 Schlumberger2019. Used by Oil Search Alasko by Permission. Attachment H Page: 2 / 2 Stirrup 1 ST -1 Clean-up and Test Summary TABLE OF FLOW PERIODS Duration Flow / Build Up Table Bring well on slowly (16/64th) via adjustable choke, adjust as necessary to achive stable flow. Monitor returns for proppant and adjust choke asnecessay Clean -Up & Initial Flow to avoid damage to proppant pack and to minimize errosion to surface equipment. The OS Resevoir Engineerwill determine when the well is clean and advise choke changes/rates for initial flow period. Initial Pressure Build Up Shut in for Build-up/Analysis Well Test (Main Flow) Conduct 6 day flow test as pertable below or as 3 rd Party Oil & Gas Samples for Clean-up PVT, EOR, & SCAL Initial Flow will be taken at the Separator as per Main Flow Reservoir Engineer's direction Max Rate NOTE: Main flow period Rates and periods are indicative and will depend on may be extended (TBC) clean-up, drawdown, and reservoir properties Final Build -Up Period Shut in for Build-up/Analysis MaxFlow (if timeallows) Conduct Max Flow Test as directed by OS Reservoir Per regulation 10AAC25.235 (d) 6, Oil Search is requesting AOGCC permission to flare the produced gas for the duration of the exploration well production test. Attachment I Well Cleanup - Operational Summary: • Estimates Time: -or as dictated by Oil Search Reservoir Engineer. • Target Clean-up Flow Rate: • Target Post Clean-up Flow Rate: • 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 OSA Reservoir Engineer or OSA Well Test Supervisor will advise choke changes based on well performance and solids production. • Proppant Production: Proppant production is expected and will managed by bringing on the well slowly and beaning up choke based on well performance and bottoms up solids production. • 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. • N2 Injection Rate: As per contingency N2 well kick-off procedures if required. • Methanol Injection Rate: McOH will be injected into the well via the inner annulus to prevent the formation of hydrates. Injection rates will vary based on produced water volumes. • Sampling: Asper sampling table below. Attachment I Main Flow- Operational Summary: • Estimates Time: - as directed by OS Reservoir Engineer. • Main Flow Period: • Choke Setting: Bring the well on slowly using the PTS adjustable choke, OSA Engineer will advise drawdown targets based on observation from initial flow. Step open choke until desired flow rate is achieved, then switch to a positive choke. The OSA Reservoir Engineer & OSA Well Test Supervisor will advise target rates and choke changes. • Proppant Production: Minimal proppant production is expected. • Annulus Pressure: The annulus pressure is expected to increase due to thermal expansion. The maximum annular pressure will be 2,000 psi., bleed as required. • Downhole Shut-in Valve: A programable down -hole shut-in valve has been installed. • Sampling: As per sampling table below 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 Daniels differential pressure Flow meter. Attachment I Stirrup 1 Completion Procedure 1. 7" 26# casing tested to 3,500 psi 2. USIT and VSP log has been completed and USIT results has been forward to AOGCC. 3. RIH with 4. RIH with 3-1/2" 9.2# completion and jewelry. 5. Landing tubing hanger and test upper and lower seals to 250 psi/5min and 5,000 psi/30 min. Chart pressure test. 6. Bull head freeze protect into annulus —1,500' TVD. 7. Drop ball and rod to set the retrievable packer. 8. Increase pressure to 3,500 psi to set the packer and hold for 30 minutes. Chart pressure test. MIT -T, tubing integrity test per AOGCC. (5,700 psi MAWP — 2,600 psi IA)*1.1= 3,410 psi (Testing tubing to 3,500 psi) 9. Slowly increase IA pressure to 3,100 psi and hold for 30 min. Chart pressure test. MIT -IA, annulus integrity test per AOGCC. 10. Rig up slickline to two TIW valves to pull ball and rod/RHCM plug and run XX plugs. 11. RIH to retrieve the ball and rod/RHCM plug 12. Shut in annulus, open tubing and bull head freeze protect to `1,500' TVD. 13. RIH and set #1 XN plug and pressure test plug to 2,500 psi and chart for 30 min. 14. RIH and set #2 X plug @ and pressure test plug to 2,500 psi and chart for 30 min. 15. Rig down slickline 16. Set TWCV into tubing hanger 17. N/D BOPE Stack and N/U Tree. 18. Fill tree with diesel, Rig up LRS to test tree, test surface lines to 7,500 psi. 19. Test tree and chart to 500 psi for 5 min and 7,000 psi for 15 min. 20. Drilling Rig demob. 21. Pull TWCV 22. Rig up sickline to retrieve X/XN plugs. 23. Rig down slickline 24. Shut in well and rig down lines. 25. Secure well, prepare for frac operations. Attachment J Stirrup 1 Fracturing Procedure Held IA IA PRV (psi) GORV (psi) Pump Trip Li Pressure Maz Rate Max Pressure (psi) Depth (ft) Depth (ft) (psi) Job 1 2,600 2,900 5,400 5,000 Treatment MD Perf TVD Pert Max Frac Frac A Maz Rate Max Max Prop Depth (ft) Depth (ft) Height (ft) Length (ft) (bpm) Pressure Conc. (psi) (PPA) Job Max MAWP = 5,700 psi, GORV = 5,400 psi, IA Pressure Max psi = 2,600 psi, IA PRV = 2,900 psi 1. MIRU Schlumberger frac equipment and treating line to the frac tree. 2. R/U to the annulus valve and isolate the pressure relief valve. 3. Pressure test IA line to 3,100 psi. 4. Open line to annular PRV and verify relief at 2,900psi. 5. Open the casing valve and proceed to pressure up the 7" x 3 g annulus to 2,600 psi. 6. Prime up the frac pumps. 7. Isolate the GORV on the treating line and pressure test the treating line to 6,500 psi. B. Upon successful pressure test, bleed off pressure and open the GORV on the treating line. 9. Open well head and pump Data FRAC. 10. Shut down and isolate the wellhead pressure gauge from the pumps if necessary. 11. Monitor the bottom hole, wellhead, and annulus pressures until closure is observed. 12. Modify PAD volume and/or schedule if necessary. 13. Pump frac treatment as referenced in attachment G. 14. Upon completion of frac, isolate well head, bleed off line pressure, rig down frac equipment, and demobilize frac equipment from wellsite. Stirrup 1 Flow Test Procedure I. Move in and rig up Well Test 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 5,000 psi and hold 15 minutes. Pressure test all downstream flow iron (with exception of flare) to 1000 psi and hold 15 minutes. Cap the gas line to the flare/incinerator and test line with air to 120 psi for 15 minutes. (N2 will be used if hydrocarbons are present) 4. Perform Clean Up Flowback as per procedures S. Perform Flow Test, Shut In, and Sampling as per procedures 6. Rig down and demobilize equipment. Attachment J N C J Stirrup 1 Nanushuk Oil Search Draft V4 11.13.19 3-1/2" 9.2 ppf L80 R3 Vamtop Tubing Surf. Casin 9-5/8" 40# L80 R Planned Perforal 20', 6spf, 60 degree 2.813" Polish Bore'X' Landing Nipple cable clamps: 0.433" (1/,") Encap gauge line A, 3-%' x 1", 1" Dummy Valve 2.813" Polish Bore 'X' Landing Nipple - Tubing PIT Gauges - Tubing P/T Gauges - X 7" PHL Retrievable Packer - ', 2.813" Polish Bore, 2.75" No -Go 'XN' ling Nipple - =G t L80 R3 Vamtop HC 3 1/2" Open Hole 0° Inc Confidential Attachment L