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Home My WebLink About2018-12-21_318_578DnL�ED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAr. ?5 ?Rn r.,.-.. '1 a r. .r: •s 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate Q Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Oil Search Alaska Exploratory Q Development ❑ Sira[igraphic Service El 218-163 3. Address: 6. API Number: 510 L Street, Suite 310, Anchorage, Alaska 99501 50-103-20793-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require a spacing exception? Yes ❑ No Pikka C ST1 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 393006 / 392999 / 393002 1 Wildcat 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 Burst Collapse Structural Conductor 20" 3060 psi 1450 psi Surface 10 3/4" 4800 psi 2470 psi Intermediate Production 7 5/8" 6890 psi 4790 psi Liner 4 i/2" 8430 psi 7500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 41/2" L80 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary LiWellbore schematic Fal 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory Q Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8 -Mar -19 OIL Q 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: marg.kUCk(doilsearch.COm Contact Phone: 907-375-4600 Authorized Signature: Date: /' I� 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 Date DUPLICATE -403 Revised 4/2017 A Submit Form and Form 10 Approved application is valid for 12 months from the date of approval. Attachments it Duplicate 0) Oil Search Pikka C ST1 Sundry Application Requirement 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, E, and F 3. Identification of freshwater aquifers within''/: 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 Pikka C and Pikka C ST1. At the Pikka C location, the Permafrost interval extends down to approximately 1000-1200ft and therefore, no shallow aquifers (typically found down to 400ft depth) are located at the Pikka C 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 — e. Estimated fracture pressure for each zone listed below: 10. Mechanical condition of wells transecting the confining zones —As noted in Attachment B, the Qugruk 7 (PTD 213-204) well is within 0.5 -mile radius of the Pikka C ST1 wellbore. However, this well is currently plugged & abandoned. No public data is available as this is an exploratory well. 11. Location of faults and fractures in wellbore % mile radius — Based on the seismic and well data covering the Pikka C location, there are no known faults or fracture zones interpreted to be located within a half mile radius of the Pikka C and Pikka C ST1 wellbore trajectories. Seismic interpretation of the Nanushuk 3 reservoir and internal interpretation surfaces has determined that there are no faults of seismic resolution within the half mile radius (Attachment E). Furthermore, the use of seismic attribute analysis supports the structural interpretation. The coherency attribute which identifies structural fabric that is associated with faults and fractures suggests that there are no faults located within a half mile radius of the Pikka C and Pikka C ST1 wellbore trajectories (Attachment F). Oil Search does not expect that any hydraulic fractures during the stimulation of Pikka C STI 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 Pump Held IA Trip Pressure IA PRV GORV Pressure (psi) si (psi) (psi) Stages 1- 6 2500 2750 5000 4500 10. Mechanical condition of wells transecting the confining zones —As noted in Attachment B, the Qugruk 7 (PTD 213-204) well is within 0.5 -mile radius of the Pikka C ST1 wellbore. However, this well is currently plugged & abandoned. No public data is available as this is an exploratory well. 11. Location of faults and fractures in wellbore % mile radius — Based on the seismic and well data covering the Pikka C location, there are no known faults or fracture zones interpreted to be located within a half mile radius of the Pikka C and Pikka C ST1 wellbore trajectories. Seismic interpretation of the Nanushuk 3 reservoir and internal interpretation surfaces has determined that there are no faults of seismic resolution within the half mile radius (Attachment E). Furthermore, the use of seismic attribute analysis supports the structural interpretation. The coherency attribute which identifies structural fabric that is associated with faults and fractures suggests that there are no faults located within a half mile radius of the Pikka C and Pikka C ST1 wellbore trajectories (Attachment F). Oil Search does not expect that any hydraulic fractures during the stimulation of Pikka C STI 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) — We will not be treating through production or intermediate casing strings. Section (c) — PikkaC Liner (Pressure test of Iinerbetween Baker Liner hanger and first Zoneguard packer) 1. Rig up pump to set I inerequipment. Test surface I ine to 5,0D0 psi. Bleed off pressure. 2. Drop 1" bat If or the shut off col I a rand pump —3-6 bpm.Shut off col I arwi I I shut at 1,630 psi. 3. Increase drill pipe pressure to 2,500 psi and hole for min to activate the SLZXP Hanger. 4. Continue pressuring up the dri I I pipe in 500 psi increment hold for 2 mine ach up to to 3,500 psi and hold for min to set the zoneguard openhole packers. 5. Continue pressure up to 4,000 psi tore I ease the HRDE and neutralize hydraulic pusher tool. 6. Bleed off tubing pressure. 7. Whi I e stabbed in with the running tool, pressure test the IA to 1, 500 psi for 10 min. 8. Bleed off lApressure. Pikka C UpperCompletion 1. Once upper completion is stabbed into the hangerpolish bore. 2. Increase the IAto 2,200 psi to shearthe DCK-2 Valve. 3. Circulate freeze protect. 4. N/D BOP, N/U Frac Tree. S. Swap the DCK-2Valve with Dummy valve with Slickline. 6. Increase and pressure test the tubingto 3,000 psi for 30 min. Chart as inner integrity test. 7. Reduce tubingto0psi. 8. Increase and pressure test the IA to 2,200 psi for 30 min. Chart as IA pressure test. 9. Reduce tubingto0psi. Section (d) — Attachment 1 Final Wellbore Schematic—Attachment K Affidavit State of Alaska, Third Judicial District Personally appeared before me, Timothy Jones, who, being duly sworn according to law, deposes and says: I. 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 affiansayeth naught. RPL #84167 UNITED STATES OF AMERICA § STATE OF ALASKA NOUtY Publit STEPN LIRETTE State of Alaska MY Cammhabn ExPkas JW Pt, 2019 12/18/!8 Date Subscribed and sworn to before me on the' 8l d11 -ay of December, 2018. �j Notary Public My commission expires: `' ( I . Attachment A December 18, 2018 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 Pikka C STI Sidetrack 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 Pikka C ST3 sidetrack 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)(8)• 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 510 L Street, Suite 310 Anchorage, AK 99501 Direct: 907-375-4624 tlm.ion es@oilsearch.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 % mile of the proposed Pikka C STI sidetrack well trajectory and fracture stimulation. Please contact me should you require additional information. Oil Search Alaska, LLC Anchorage office Te" +1 907 276 6900 610 L Sheat, Suae 310 Fax +1 907 275 6930 Anchorage, www.¢isearch,corn AK 99501 Attachment A Distribution List: Alaska Division of Oil and Gas Arctic Slope Regional Corp. Kuukpik Corp. Oil Search (Alaska(, LLC Repsol E&P USA Inc. Armstrong Energy, LLC GMT Exploration Company LLC Attachment A m r g u„a s e aoHog z I �=v:5 c6 lo ul KR / y "F o 8qa l�o -_•_ �..�..–��.->- __ __— --mac- gp � I; y bg nfl / / 1 s / a p 0DFJ \ / oe�� na ” 6< y 3 W RRgg i6dK U t §s of r V ��iVi i 3 vi 11 O m 7-5/8" Production Casing Section Overview Section Overview 7-5/8" 29.7# L80 BTC Casing Burst Collapse Tensile ID Drift ID Connection Make-up Make -Up (Psi) (Psi) (kibs) (in) (in) OD Torque Loss Cement Cement Volume Tail Tail (in) (ft -lbs) (in) 6,880 4,790 683 6.875 6.750 8.500 As per BTC A 4.69 (-7,630) Production Casing Cement—STAGE 1 Casing 7-5/8" 29.7# L80 BTC Casing Lead Lead TOC Basis Tail Tail TOC Spacer Total Total Lead Cement Cement Volume Tail Tail Temp Verification Method Notes Job will be mixed on the fly Production Casing Cement—STAGE 2 Casing 7-5/8" 29.7# LBO BTC Casing Lead Lead TOC Basis Tail Tail TOC Spacer Total Lead Cement Tail Volume Temp Verification Method Notes I Job will be mixed on the fly 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 v. Drop Shut Off Plug (opens ES -Cementer upon plug bump) vi. 5-10bbls water to clean cementing lines x. Land Shut Off Plug on Baffle Adapter and verify floats are holding A. Pressure up to 3,300 psi to shift open ES -Cementer. b) Final volumes will be detailed in the Halliburton Cement Program. c) Do not pump over the calculated displacement plus half of the two joint shoe volume plus mud compressibility (-2.7bbls + XXXXbIs = XXXX 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. 2. Can likely go straight into second stage cement job, however actual ECD on the hole will depend on final slurry design. 3. Prior to commencing second stage cementing operations reload Halliburton cement head. 4. Pump the second stage cement job as per Halliburton Cementing Program. a) Stage 2 is planned to be pumped as follows: ii. Drop Second Stage Bottom Plug Attachment C b) Final volumes will be detailed in the Halliburton Cement Program. c) 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. d) 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. Back out and retrieve the casing hanger running tool. Attachment C M 3"1502 I :-1116' SM X2 1502 PIKKAC Attachment CIL SEARCH ALASKA Pressure Control BV 20"x 10 -3/4"x7 -5/8"x4 -105/10M MB-222/MB-242 Mullibowl Assembly, IVER With MB -242 Tubing Hanger and K Tubing Bonnet GEcompany Dwwx Bv: DwRvnxD NO.: wmm�wR REVIEWED BY: RN. SM. d XG f f ppsipgeq�wa�xy�w,wuxymaw�n ux� qww amdx,lW �I "+:iwwM1bwu.""wx�•�WwiWN xv}a PV%IDVEO BY: DAA' 1]OCT1B PIKKAC Attachment CIL SEARCH ALASKA w Y C v E 06 m U Y a Y Y_ O. C O U1 v Y L L }J M N � •— C C a L tjo N cuY �L Q� L Y v c O .0 Q N m C }' C (6 Q1 � N O (6 C 41 41 L L � Q/ L t -i v F L N � U t6 L Y Y N a 3 06 O L U '^ m u Y Y N CL v N N L N m L 00 �— C 3 O u V L w N L C N O y Y L V OJ a0+ N U N � N L N u L u a w C L .!2 a O W Y L V) L GJ LU N 3 M H Z Z U { £ C) E E u \ \ / m � / z k u � a � G \ ° \ 2 k 2OJ /0\ , { £ Prepared for Date Prepared • Mark of Schlumberger Schlumberger FraCCADE% STIMULATION PROPOSAL Operator Oil Search Alaska Well Pikka C Field Pikka Unit Formation Well Location County North Slope State Alaska Country United States Mike Martin Service Point Prudhoe Bay, AK Business Phone 1907 659 2434 12-17-2018 FAX No. 1 907 659 2538 Prepared by ScottLeahy Phone 907-330-4595 E -Mail Address SLeahy@slb.com gistlaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger comedy no gentler for advice or recommendations made concerning once an be Obtained from Me use at any product Or service, "a results given are esGmame band an calculations produced by a computer model Including various assumptions On to vial, maiman and treatment The results dennd on Input date provided by Me Operator and a0timates as to unknown dela and can be no mom accused Man Me model, Me smoulders end such input data. The information presented is Schlemm ger's beat estimate of the actual resugs Met may be achieved and should be and for compadnn purposes ratio Man absolute values. The quality of input data, and hence mask, a, an improved Mrough Meuse of arida testi and procedures which Schlumberger can assist in nlochn, The Operator has ..,ad., knowledge of to well, Me reservoir, Me field and conditions affecting Mem If to Operator is aware of any conditions whereby a neighboring wall or walls might be affected by Me sediment proposed herein it is Me Oper alor's responsibility to Athol owner or owners of the wall or wells accordingly. Prices quoted am sy metry any and are good far 30 days from to date of issue. Actual charges may vary depending upontime, equipment, and malarial uldmom y minimal in ,dorm Maseserviaes. belabored Schlumberger -Private Attachment G Client Oil Search Alaska Well Formation : District : Prudhoe Bay,AK Schlumberger Schlumberger -Private Attachment G Client Oil Search Alaska Well Pikka C Formation District Prudhoe Bay,AK Section 2: Propped Fracture Schedule ( Pumping Schedule 3chlutopger Fluid Totals 40022 gal of YF125ST Proppant Totals 129900 lb of CarboLhe 16/20 Pad Percentages %PAD Clean 29.1 Job Description 25.5 Job Execution Step Name Pump Hate (bbl/min) Fluid Name Step Fluid Volume (gal) Gel Cone. (lb/mgal) Prop. Type and Mesh Prop. Cone. (PPA) PAD 40.0 YF125ST 11760 25.0 Cum. 0.00 1.0 PPA 30.0 YF125ST 3620 25.0 Carbo Lite 16/20 1.00 2.0 PPA 30.0 YF125ST 3473 25.0 Carbo Lite 16/20 2.00 3.0 PPA 30.0 YF125ST 3337 25.0 CarboLhe 16/20 3.00 4.0 PPA 30.0 YF125ST 3569 25.0 CarboLhe 16/20 4.00 5.0 PPA 30.0 YF125ST 1 3764 25.0 CarboLhe 16/20 5.00 6.0 PPA 30.0 VF125ST 3651 25.0 Car62Lte 16/20 6.00 7.0 PPA 30.0 YF1255T 3849 25.0 CarbaLite 16/20 7.00 8.0 PPA 30.0 YF125ST 3413 25.0 1 CarboLite 16/20 8.00 Flush 30.0 YF125ST 5566 25.0 1 22190 0.00 Fluid Totals 40022 gal of YF125ST Proppant Totals 129900 lb of CarboLhe 16/20 Pad Percentages %PAD Clean 29.1 % PAD Dirty 25.5 Job Execution 3 Schlumberger -Private Attachment G Job Execution Step Step Cum. Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (gal) Volume Volume 013) (lb) Pressure (min) (min) (gall (bbl) (bbl) (psi) PAD 11760 11760 280.0 280.0 0 0 7.0 7.0 1.0 PPA 3620 15380 90.0 370.0 3620 3620 3.0 10.0 2.0 PPA 3473 18853 90.0 460.0 6946 10566 3.0 13.0 3.0 PPA 3337 22190 90,0 550.0 10012 20578 3.0 16.0 4.0 PPA 3569 25759 1 100.0 1 650.0 1 14275 34853 3.3 19.3 5.0 PPA 3784 29542 110.0 760.0 18918 53770 3.7 23.0 6.0 PPA 3651 33194 110.0 870.0 21908 15618 3.7 26.7 7.0 PPA 3849 37043 120.0 1 990.0 1 26941 102620 4.0 30.7 8.0 PPA 3413 40455 110.0 1 1100.0 1 27302 129922 3.7 34.3 3 Schlumberger -Private Attachment G Client Oil Search Alaska Well Pikka C Formation : District : Prudhoe Bay,AK S010m6ergor Section 3: Schlumberger -Private Attachment G Client Oil Search Alaska Well Pikka C Farmatian District Section 4: Zone Data 3chlumherger Schlumberger -Private Attachment G Client Oil Search Alaska well Pikka C Formation Cum. District Prudhoe Bay, AK s luderger Section 5: Propped Fracture Schedule Pumping Schedule Fluid Totals 45636 gal of YF125ST Pro ant Totals 129900 lb of CarboLite 16/20 Pad Percentages % PAD Clean 29.1 % PAD Dirty 25.5 Step Step Cum. Fluid Step Job Description Step Cum. Step Name Pump Nate (bbl/min) Fluid Name Step Fluid Volume I all Gel Conc. (Ib/mgal) Prop. Type and Mesh Prop. Conc. (PPA) PAD 40.0 YF125ST 11760 25.0 Volume 0.00 1.0 PPA 30.0 YF125ST 3620 25.0 CarboLite 16120 1.00 2.0 PPA 30.0 YF125ST 3473 25.0 CarboLite 16/20 2.00 3.0 PPA 30.0 YF125ST 3337 25.0 CarboLite 16/20 3.00 4.0 PPA 30.0 YF125ST 3569 25.0 CarboLite 16/20 4.00 5.0 PPA 30.0 YF125ST 3784 25.0 CarboLite 16120 5.00 6.0 PPA 30.0 YF125ST 3651 25.0 CarboLite 16/20 6.00 7.0 PPA 30.0 YF125ST 3849 25.0 CarboLite 16/20 1.00 8.0 PPA 30.0 YF125ST 3413 25.0 CarboLite 16/20 8A0 Flush 30.0 YF125ST 5182 25.0 0 Fluid Totals 45636 gal of YF125ST Pro ant Totals 129900 lb of CarboLite 16/20 Pad Percentages % PAD Clean 29.1 % PAD Dirty 25.5 Step Step Cum. Fluid Step Cum. Step Cum. Avg.Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (gal) Volume Volume Ilb) Ilb) Pressure (min) (min) (gal) (bbl) (bbl) (psi) PAn 11760 71760 290.0 280.0 0 D 7.0 7.0 KUK 3651 iDIIIPiM411.11-*i 6 Schlumberger -Private 19.3 Attachment G Client Oil Search Alaska Well Pikka C Formation Cum. District Prudhoe Bay,AK Schlumberger Job Execution Step Step Cum. Fluid Step Cum. Step Cum. Avg. Step Cum. Name FluidVolume Slurry Slurry Prop Prop. Surface Time Time Volume (gal) Volume Volume (lb) (Ib) Pressure (min) (min) (gal) (bbl) (bbl) (psi) 8.0 PPA 3413 40455 170.0 1700.0 27302 129922 3.7 34.3 Flush 5182 45638 123.4 1223.4 0 129922 4.1 36.4 Schlumberger -Private Attachment G Client Oil Search Alaska Schlumberger well Pikka C Formation District Section 6: Propped Fracture Simulation The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-13 Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 2 MD ........................ .....— Initial Fracture Top TVO......................... Initial Fracture Bottom TVD Propped Fracture Half -Length EOJ Hyd Height at Well------------------------- Average Propped Width------------------------ Net Pressure – Max Surface Pressure Simulation Results by fracture Segment From To Prop. Cone. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Cone. Conductivity Pumping lin) Iftl Conc. (Ib/mgal) (md.ft) (PPA) (lb/ft2) a Schlumberger Private Attachment G Client Oil Search Alaska SnIumh8rgcr Well Pikka C Formation District Pmdhoeaay,AK Section 7: Zone Data B _N N N N N N N N N N N Formation Mechanical Properties 9 Schlumberger -Private Attachment G Client Oil Search Alaska Well Pikka C Formation : District : Prudhoe Bay,AK Schlumberger Section 8: Propped Fracture Schedule ( Pumping Schedule Fluid Totals 50841 gal of YF125ST Pro pant Totals 160300 lb of CarboLite 16/20 Ped Percentages % PAD Clean 31.0 % PAD Dirty 126.9 Job Description Job Execution Step Name Pump Hate (bbl/min) Fluid Name Step Fluid Volume (gal) Gel Cone. (Ib/mgap Prop. Type and Mesh Prop. Cone. (PPA) PAD 40.0 YF125ST 14280 25.0 Cum. Time (min) 0.00 1.0 PPA 30.0 YF125ST 3218 25.0 CarbaLite 16/20 1.00 2.0 PPA 30.0 YF125ST 3087 25.0 CarbaLite 16/20 2.00 3.0 PPA 30.0 YF125ST 3337 25.0 CarboL'ae 16/20 3.110 4.0 PPA 30.0 YF125ST 3569 25.0 CarboLhe 16/20 4.00 5.0 PPA 30.0 YF125ST 4127 25.0 CarboLhe 16/20 5.00 6.0 PPA 30.0 YF125ST 3983 25.0 CarboLhe 16/20 6.00 7.0 PPA 30.0 YF125ST 3849 25.0 CarboLite 16/20 7.00 8.0 PPA 30.0 YF125ST 4188 25.0 CarboLite 16/20 8.00 9.0 PPA 30.0 YF125ST 2404 25.0 CarboLite 16/20 9.00 Flush 30.0 YF125ST 4799 25.0 28.2 0.00 Fluid Totals 50841 gal of YF125ST Pro pant Totals 160300 lb of CarboLite 16/20 Ped Percentages % PAD Clean 31.0 % PAD Dirty 126.9 10 Sch I u m be rg er-Private Attachment G Job Execution Step Name Step Fluid Volume (gall Cum. Fluid Volume (gal) Step Slurry Volume (bbl) Cum. Slurry Volume (bbl) Step Prop (lb) Cum. Prop. (lb) Avg. Surface Pressure Step Time (mini Cum. Time (min) PAD 14280 14280 340.0 340.0 0 0 8.5 8.5 1.0 PPA 3218 17498 80.0 420.0 3218 3218 2.7 11.2 2.0 PPA 3087 20585 80.0 500.0 6174 9392 2.7 13.8 3.0 PPA 3337 23922 90.0 590.0 10012 19404 3.0 16.8 4.0 PPA 3569 27491 100.0 690.0 14275 33679 3.3 20.2 5.0 PPA 4127 31618 120.0 810.0 20637 54316 4.0 24.2 6.0 PPA 3983 35602 120.0 1 930.0 1 23899 1 78216 1 4.0 28.2 10 Sch I u m be rg er-Private Attachment G Client Oil Search Alaska Well Pikka C Formation District 3chlumtopp Job Execution Step Name Step Fluid Volume (gal) Cum. Fluid Volume Igal) Step Slurry Volume (bbl) Cum. Slurry Volume (bbl) Step Prop (lb) Cum. Prop. (Ib) Avg. Surface Pressure Step Time (min) Cum. Time (min) 7.0 PPA 3849 39450 120.0 1050.0 26941 105157 4.0 32.2 8.0 PPA 4188 43639 135.0 1185.0 33507 138664 4.5 36.7 9.0 PPA 2404 46042 80.0 1265.0 21632 160296 2.7 39.3 Flush 4799 50841 114.3 1379.3 0 160296 3.8 43.1 11 Schlumberger -Private Attachment G Client Oil Search Alaska Well Pikka C Formation District Prudhoe Bay,AK Section 9: Propped Fracture Simulation Seklmhrger 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. Stage3 MD---------------------- - ------------ Initial Fracture Top TVD----------------------- Initial Fracture Bottom TVD Propped Fracture Half•Length-------------- EOJ Hyd Height at Well ------------------------ Average Propped Width ---------------------- Net Pressure -------------------------------------- Max Surface Pressure Results by Fracture 12 Sch lum berge r -Private Attachment G Client Oil Search Alaska Well Pikka C Formation District Prudhoe Bay, AK Section 10: Zone Data Schlumberger 13 Schlumberger -Private Attachment G client Oil Search Alaska Well Formation District Prudhoe Bay,AK 3chIUMBPgcr Section 11: Propped Fracture Schedule ( 1 Pumping Schedule Fluid Totals 48601 gal of YF125ST Proppant Totals 1595001b of CarboLite 16/20 Pad Percentages % PAD Clean 30.4 % PAD Dirty 126.2 Job Description Job Execution Step Name Pump Rate (bbl/min) Fluid Name Step Fluid Volume (gall Gel Cone. (lb/mgal) Prop. Type and Mesh Prop. Cone. (PPA) PAD 40.0 YF125ST 13440 25.0 Cum. 0.00 1.0 PPA 30.0 YF125ST 3218 25.0 CarboUte 16/20 1.00 2.0 PPA 30.0 YF125ST 4631 25.0 CarboLite 16/20 2.00 4.0 PPA 30.0 YF125ST 6761 25.0 CarboLite 16/20 4.00 6.0 PPA 30.0 YF125ST 6307 25.0 CarboLite 16/20 6.00 8.0 PPA 30.0 YF125ST 6205 25.0 CarboLite 16/20 8.00 9.0 PPA 30.0 YF125ST 3605 25.0 CarboLite 16/20 9.00 Flush 30.0 YF125ST 1 4415 1 25.0 1 2.7 0.00 Fluid Totals 48601 gal of YF125ST Proppant Totals 1595001b of CarboLite 16/20 Pad Percentages % PAD Clean 30.4 % PAD Dirty 126.2 14 Schlumberger -Private Attachment G Job Execution Step Step Cum. Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (gal) Volume Volume (1151 (lb) Pressure (min) (min) (gal) (bbl) (bbll PAD 13440 13440 320.0 320.0 0 0 8.0 8.0 1.0 PPA 3218 16658 80.0 400.0 3218 3218 2.7 10.7 2.0 PPA 4631 21288 120.0 520.0 9261 12479 4.0 14.7 4.0 PPA 6781 28069 190.0 710.0 27123 39602 6.3 21.0 PPA 6307 34376 190.0 900.0 37841 77442 6.3 27.3 N6.0 . PPA 6205 40581 200.0 1100.0 1 49641 127083 6.7 34.0 9.0 PPA 3605 1 44186 1 120.0 1 1220.0 1 32448 159531 4.0 38.0 Flush 4415 1 48601 1 105.1 1 1325.1 1 0 159531 3.5 41.5 14 Schlumberger -Private Attachment G Client Oil Search Alaska 3chlumherger well Pikka C Formation District Section 12: Propped Fracture Simulation ( The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-0 Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 4 MD Initial Fracture Top TVD ------------------------ Initial Fracture Bottom TVD Propped Fracture Half-Length-.--_------_-- EOJ Hyd Height at Well ------------------------- Average Propped Width Net Pressure Max Surface Pressure. I Simulation Results by Fracture Seament I 15 Schlumberger -Private Attachment G Client Oil Search Alaska Well Pikka C Formation : Nanushuk District Prudhoe Bay, AK Section 13: Zone Data ( Schlumberger I Formation Transmissibilitv Prooerties I 16 Schlumberger -Private Attachment G Client Oil Search Alaska Well Pikka C Formation Distriet Schlumberger Section 14: Propped Fracture Schedule Pumping Schedule Fluid Totals 48217 gal of YF125ST Pro ant Totals 159500 lb of CarboLite 16/20 Pad Percentages %PAD Clean 30.4 % PAD Dirty 26.2 Job Description Job Execution Step Name Pump Rete (bbl/min) Fluid Name Step Fluid Volume (a0 Gel Conc. (lb/mgal) Prop. Type and Mesh Prop. Conc. (PPA) PAD 40.0 YF125ST 13440 25.0 Cum. Time (min) 8.0 10.7 14.7 21.0 27.3 34.0 38.0 41.2 0.00 1.0 PPA 30.0 YF125ST 3218 25.0 CarboLite 16/20 1.00 2.0 PPA 30.0 YF125ST 4631 25.0 CarboLite 16/20 2.00 4.0 PPA 30.0 YF125ST 6781 25.0 CarboLite 16/20 4.00 6.0 PPA 30.0 YF125ST 6307 25.0 CarboLite 16/20 6.00 8.0 PPA 30.0 YF125ST 6205 25.1 CarboLite 16/20 8.00 9.0 PPA 30.o YF725ST 3605 25.0 CarboLite 16/20 9.00 Flush 30.0 YF125ST 4031 25.0 0.00 Fluid Totals 48217 gal of YF125ST Pro ant Totals 159500 lb of CarboLite 16/20 Pad Percentages %PAD Clean 30.4 % PAD Dirty 26.2 17 Schlumberger -Private Attachment G Job Execution Step Name Step Fluid Volume (gal) Cum. Fluid Volume (gal) Step Slurry Volume (bbl) Cum. Slurry Volume (bbl) Step Prop (lb) Cum. Prop. (lb) 0 3218 12479 39602 77442 127083 159531 159531 Avg. Surface Pressure Step Time (min) 8.0 2.7 4.0 6.3 6.3 6.7 4.0 1 3.2 1 Cum. Time (min) 8.0 10.7 14.7 21.0 27.3 34.0 38.0 41.2 PAD 13440 13440 320.0 320.0 0 1.0 PPA 3218 16658 80.0 400.0 3218 2.0 PPA 4631 21266 120.0 520.0 9261 4.0 PPA 6761 28069 190.0 710.0 27123 6.0 PPA 6307 34376 190.0 900.0 37841 8.0 PPA 6205 40581 200.0 1100.0 49641 9.0 PPA 3605 1 44186 120.0 1220.0 32448 Flush 4031 1 48217 96.0 1316.0 0 17 Schlumberger -Private Attachment G Client Oil Search Alaska Schlumberger Well Formation District Prudhoe Bay,AK Section 15: Propped Fracture Simulation ( The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-1) Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 5 MD Initial Fracture Top TVD ...................... Initial Fracture Bottom TVD Propped Fracture Half -Length ------------ _ EOJ Hyd Height at Well_. -._---___.---_- Average Propped Width ---------------------- Not Pressure... - - - - Max Surface Pressure Simulation Results by Fracture Segment 18 Schlumberger -Private Attachment G Chem Oil Search Alaska Well Pikka C Formation : District : Prudhoe Bay,AK Section 16: Zone Data ( 3chlumdergcr, 1s Schlumberger -Private Attachment G Client Oil Search Alaska Wan Pikka C Formation District Prudhoe Bay,AK Section 17: Propped Fracture Schedule ( Pumping Schedule Schlumberger Please note thatthis pumping schedule is under -displaced by 5.0 bbl. Fluid Totals 47259 Bal of YF125ST 3437 gal of WF125 Pro ant Totals 180300 lb of CarboLite 16/20 Pad Percentages % PAD Clean 28.4 % PAD Dirty 124.3 Job Description Job Execution Step Name Pump Rate )bbl/min) Fluid Name Step Fluid Volume (gal) Gel Cont. (Ib/mgal) Prop. Type and Mesh Prop. Conc. (PPA) PAD 40.0 YF125ST 13440 25.0 Cum. 0.00 1.0 PPA 30.0 YF125ST 3218 25.0 CarboLite 16/20 1.00 2.0 PPA 30.0 YF125ST 5016 25.0 CarboLite 16/20 2.00 4.0 PPA 30.0 YF125ST 7138 25.0 CarboLite 16/20 4.00 6.0 PPA 30.0 YF125ST 6805 25.0 CarboLite 16/20 6.00 8.0 PPA 30.0 YF725ST 7136 25.0 CerboLhe 16120 8.00 9.0 PPA 30.0 YF725ST 4507 25.0 CarboLite 16/20 9.00 Flush 30.0 WF125 1 3437 25.0 2.7 0.00 Please note thatthis pumping schedule is under -displaced by 5.0 bbl. Fluid Totals 47259 Bal of YF125ST 3437 gal of WF125 Pro ant Totals 180300 lb of CarboLite 16/20 Pad Percentages % PAD Clean 28.4 % PAD Dirty 124.3 20 Schlumberger -Private Attachment G Job Execution Step Step Cum. Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (gal) Volume Volume (lb) (lb) Pressure (min) (min) (gal) (bbll (bbl) PAD 13440 13440 320.0 320.0 0 0 8.0 8.0 1.0 PPA 3218 16658 80.0 400.0 3218 3218 2.7 10.7 2.0 PPA 5016 21674 130.0 530.0 10033 13250 4.3 15.0 4.0 PPA 7138 28812 200.0 730.0 28550 41801 6.7 21.7 6.0 PPA 6805 35616 205.0 935.0 40828 82629 6.8 28.5 8.0 PPA 7136 42752 230.0 1 1165.0 1 57087 139716 7.7 36.2 9.0 PPA 4507 1 47259 150.0 1 1315.0 1 40559 1 180275 5.0 41.2 Flush 3437 50696 81.8 1396.8 0 180275 2.7 43.9 20 Schlumberger -Private Attachment G Client Oil Search Alaska Schlumberger Well Formation District Section 18: Propped Fracture Simulation (Stage 6; 5700' MD) The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-1) Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 6 MD_________ -. Initial Fracture Top TVD Initial Fracture Bottom TVD Propped Fracture Half -Length______ E0J Hyd Height at Well________.__ Average Propped Width______________________ Net Pressure Max Surface Pressure- _„................. ation Results el Schlumberger -Private Attachment G Schlumberger Client: Oil Search Alaska Well: PikkaC Basin/Field: Pikka State: Alaska County/Parish: North Slope Borough Case: < 1 % Disclosure Type: Pre -Job Well Completed: 3/16/2019 Date Prepared: 12/14/20181:10 PM Report ID: RPT -59131 Fluid Description(s) YF125 ST:WF125 298,830 Gal Contains: Water, Surfactant, Breaker, Breaker Aid, Crosslinkep Gelling Agent, Clay Control Agent, Bactericide, Propping Agent rnemew ro,umerurm x,v,e morcsowve reprcsenrsmesvmmanan o)worer ana aaamves. worer n supp.,eaoy[rvmr. ezao- ware.is wppree Mure dar. swamberxr msper)wmedpp ofmlysa of rhe wattrpndmrmpeprpwdea breakdpwn p)rompmenn marmay M1ovebempdEeErome wpnrby mire -games. woo booaNatlmynewupo Eo[umm[ispeQarmetl basetl unmet'omposlXon aJ rl,e gentlfMpmdu[rt to the nten[mp[su[M1 [omposMunal Mf atlon wai knewnbGflC-CM1emlml[os ojme tlote o)me tlo[umeat was prcdattd. Mynewupdptts will not be rejleaedin this ao[ammc Attachment H 0 Schlumberger 1018. Usedby OBSearch Alosko bypermission. Page: I / 1 LAS Number Chemical Name Water(including Mix Water Supplied b Client)" Mass Fracti.o, 77= 66402-68-4 Ceramic materials and wares, chemicals —27% 67-48-1 2-hydroxy-N,N,N-trimethylethanaminium chloride < 1 % 9000-30-0 Guargum <1 % 56-81-5 1, 2,3 - Propanetriol <0.1 % 7727-54-0 Diammonium peroxidisulphate <0.2 % 1303-96-4 Sodium tetraborate decahydrate <0.1 % 102-71-6 2,2',2"-nitrilotriethanol <0.1 % 111-76-2 2-butoxyethanol <0.1 % 67-63-0 Propan-2-ol <0.1 % 34399-01-1 Ethoxylated C11 Alcohol <0.1 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer .0.01 % 63-02-3 Lactose .0.01 % 68131-39-5 Ethoxylated Alcohol <0.01 % 91053-39-3 Diatomaceous earth, calcined <0.01 % 112-42-5 Undecanol <0.01 % 7631-86-9 _ Non -crystalline silica (impurity) <0.001% 14807-96-6 Magnesium silicate hydrate (talc) .0.001 % 10377-60-3 Magnesium nitrate .0.001 % 26172-55-0 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001 % 7786-30-3 Magnesium chloride <0.001 % 9002-84-0 poly(tetra8uorcethylene) <0.001 % 9050-36-6 Maltodestrin <0.0001 % 2682-20-4 2 -methyl -2h -i sothiazol-3-one .0.0001 % 127-08-2 Acetic acid, potassium salt <0.0002 % 14808-60-7 Quartz, Crystalline silica <0.0001 % 14464-46-1 Cristobalite <0.0001 % 64-19-7 Acetic acid (impurity) <0.0001 % 9004-53-9 Degrin <0.0001 % 9012-54-8 Hemicellulase enzyme < 0.00001 % I ezao- ware.is wppree Mure dar. swamberxr msper)wmedpp ofmlysa of rhe wattrpndmrmpeprpwdea breakdpwn p)rompmenn marmay M1ovebempdEeErome wpnrby mire -games. woo booaNatlmynewupo Eo[umm[ispeQarmetl basetl unmet'omposlXon aJ rl,e gentlfMpmdu[rt to the nten[mp[su[M1 [omposMunal Mf atlon wai knewnbGflC-CM1emlml[os ojme tlote o)me tlo[umeat was prcdattd. Mynewupdptts will not be rejleaedin this ao[ammc Attachment H 0 Schlumberger 1018. Usedby OBSearch Alosko bypermission. Page: I / 1 Pikka C, Clean-up and Test Summary P/KKA C TABLE OF FLOW PERIODS - Per regulation 20AAC25.235 (d) 6, Oil Search is requesting AOGCC permission to flare the produced gas for the duration of the exploration well production tes Attachment I Duration Flow / Build Up Table Purpose / Remarks Bringwell on slowly (16/64th) via adjustable choke, adjust as necessary to achive stable flow. Monitor returns for proppant and adjust choke as necessay Clean -Up & Initial Flowto avoid damage to proppant pack and minimize errosion to surface equipment. The OS Resevoir Engineerwill determine when the well is clean and advise choke changes/rates forinitial flow period. Initial Pressure Build Up Shut in well to obtain reservoir pressure Conduct Multi -Rate flow testas per Table below or as directed by Onsite Reservoir Engineer Multi -Rate Well Test Collect Surface Samples as directed by OS Reservoir Engineer 3 rd Party Oil & Gas Samples for clean-up PVT, EOR, & SCAL Clean-up will be taken at the Initial Flow Separator as per Reservoir Engineer's Multi -Rate t direction Multi -Rate 2 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-UpPeriod TBC ShutInforvariousreservoir analysis Per regulation 20AAC25.235 (d) 6, Oil Search is requesting AOGCC permission to flare the produced gas for the duration of the exploration well production tes Attachment I Well Cleanup - Operational Summary: • Estimates Time- as directed by Oil Search Reservoir Engineer. • Target Clean-up Flow Rate: • Target Post Clean-up Flow Rate: • Choke Setting: Use adjustable choke to make the adjustments needed to achieve a stable liquid flow rate. The OS Reservoir Engineer & OS 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 base on well performance and bottoms up solids production. • Annulus Pressure: The annulus pressure is expected to increase due to thermal expansion. • Nz Injection Rate: As per contingency Nz well kick-off procedures. • Methanol Injection Rate: McOH will be injected into the well via the chemical injection line to prevent the formation of hydrates. Injection rate TBD • 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, Once at targeted rate switch to a positive choke for the specified flow period. The OS Reservoir Engineer & OS 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. • Methanol Injection Rate: McOH will be injected into the well via the chemical injection line to prevent the formation of hydrates. Injection rate TBC • 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 Pikka C ST1 4-1/2",12.6 ppf, TC 11, Production Tubing 3.81" X -nipple - 4-1/2" x 1" KBMG GLM, 2,100 psi A to T shear valve (A Oil Search As Planned Version 3 12/14/2018 — 4-1/' DCIN-11 Chem Injection Mandrel, dual check valve SCSSV, 4-1/2" TRM-4PE-CF, 3.813" X profile, 6" OD, 5K psi 4-'/z' cable clamps: 0.433" (1/4!') Encap gauge line, 0.433" (Y4") Encap SSSV line, 3/8" Chem Inj Line 10-3/4" 45.5 ppf LBO BTC Surface Casing, Bottom of entry guide SRO HAL ROC Tubing P/7 Gauge 4-1/2" Ecc-Nose SRO HAL ROC Tubing P/T Gauge Guide Shoe Top of SLZXP Liner Hanger/Packer Zonal Isolation Packers Frac Sleeves Initiator Sleeve Shutoff 7-5/8" 29.7 ppf L80 BTC Intermediate Casing, 4-'/2" 12.6 ppf, L80 TSH563 6 a/4" Ok TD, Production Liner