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Home My WebLink About2018-12-21_318_577STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS RECEIVED DEC 21 2,3t8 AOGCC 1. 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 n Re-enter Susn well n Altar r—inn n r)fh.,. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: RAK4 Oil Search Alaska, LLC Exploratory Q Development ❑ Stretigrephic ❑ Service ❑ 3. Address: 6. API Number: 51 D L Street, Suite 310, Anchorage, Alaska 99501 50- 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Pikka B STA Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number):Pool(s): 10. Fiefdl ADL 3929751 ADL393028 Pikka Unit 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 16" 3060 1450 Surface 9-518" 7930 4760 Intermediate Production 7" 7240 7800 Liner Perforation Depth MD 01): pwruraillori D apth TVD (ft): ITubing Size: Tubing Grade: Tubing MD (ft): :I-11211, 9.2# L-80, TCII rockers ane SSSv Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program Q DOP Sketch ❑ Exploratory Q Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 20 -Feb -19 Commencing Operations: OIL WINJ ❑ F]WDSPL GAS ❑ WAG ❑ ❑ GSTOR ❑ Suspended ❑ 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 M er Contact Email: marc.kUCk oilsearch.corn BContact Phone: 907-375-4600 Authorized Signature: Date, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 11- -r+ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ❑ Subsequent Farm Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: DUPLICATE Submit Form and Form 10403 Revised 4/2017 Approved application Is valid for 12 months from the data of approval. Attachments in Duplicate (r Oil Search Pikka B STA 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 half mile radius of the current proposed well bore trajectory for Pikka B and Pikka B STA. At the Pikka B location, the Permafrost interval extends down to approximately 1000-1200ft and therefore, no known shallow aquifers (typically found down to 400ft depth) are located at the Pikka B 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. S. Pressure ratings for wellbore, wellhead, BOPE and treating head — Attachment D 9. a -d I-ithological and geological descriptions of each zone — e. Estimated fracture pressure for each zone listed below: Pump Held IA Trip Pressure !A PRV GQRV Pressure (Psij (PSI)(psi) pal} !ab 3000 3300 6400 6000 10. Mechanical condition of wells transecting the confining zones — No wells within 1/2 - mile radius of Pikka B STA. Please see attachment B as reference. El.ocation of faults and fractures in wellbore Y2. mile radius — Based on the seismic and well data covering the Pikka B location, there are no known faults or fracture zones interpreted to be located within a half mile radius of the Pikka B and Pikka B STA Oil Search does not expect that any hydraulic fractures during the stimulation of Pikka B STA 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) — 1. Rig up pumpto set PHL Packer. Testsurface linesto 5,000 psi. Bleed off pressure. 2. Slowlypressure up the tubing in 500 psi incrementsto 3,500 psi forthe packerto setand hold for 30 min. Chart as inner integrity test. 3. Reduce tubingpressure to 2,000 psi 4. Increase IA pressure to 3,300 psi and hold for30 min. Chart as IA pressure test. 5. Bleed off IA pressure to 0 psi. 6. Increase tubing pressure to expe nd the mirage plug. a. Estimated expend: 4480-4900 psi 7. Once expended pressure will reduce, bleed off tubing pressureto0 psi. Section (d) — Attachment J Proposed 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: 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 affiant ayeth naught. Ai z/18116 Timothy Jone Date RPL #84167 UNITED STATES OF AMERICA § STATE OF ALASKA Subscribed and sworn to before me on the day of December. 201 S. Notary Public No" PWO Sy" UNIM My commission expires:, noof man ttOWMOsslan 1WMI Jul 21, 2018 Attachment A f 4 P Oil Search 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 B STI Sidetrack Well Dear Owner, Landowner, Surface Owner and/or Operator, Oil Search (Alaska), LLC (OSA) is applying for a Sundry Application under 20 RAC 25.283 to perform a fracture stimulation of the proposed Pikka B STI 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)(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 Janes Land Manager Oil Search (Alaska), LLC 510 L Street, Suite 310 Anchorage, AK 99501 Direct: 907-375-4624 tim.ionesPolIs;,arch.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 B STI sidetrack well trajectory and fracture stimulation. Please contact me should you require additional information. Sincerdly, I h^rs Tim Jo s Land M naf;er 09 Search Alaska, LLC Anchorage office Tel. +1907 275 6800 510 L Sheaf, Suft 310 Fax. +1907 275 6930 Anchorage. www *isosrch.corn AK 99501 Attachment A 0) Oil Search 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 ConocoPhlllips Alaska, Inc. Attachment A [C t c mo L Ln x v 0 N l/] v C 3 0 Ln m m Y Y d o M •`• cc Y Y 4- 0 Q m m U J " m 4, c v U f4 a ��°'� � lr; ��;C Vc�r„�:• � 'xar� mm3 s o i I °` U cz H ` ap�Y [7a Qj I yy �jri n .n. f l f f f m 7 . 4 i i i_ r° rl � x, a Y' � j F „•' O w a r= � F d I and a O [C t c mo L Ln x v 0 N l/] v C 3 0 Ln m m Y Y d o M •`• cc Y Y 4- 0 Q m m U J " m 4, c v U f4 a 7" Production Casing Section Overview 7" 26# L80 DWCIC-SR Casing Burst Collapse Tensile ID Drift ID Connection Make-up Make -Up (Psi) (Psi) (Klbs) (in) (in) CID Torque Loss (in) (ft -lbs) (in) 7240 5410 604 6.276 6.151 7.875 Min 18,300 4.50 Max 21,100 Production Casing Cement—STAGE 1 Casing 17" 26# 1.80 DWC/C Casing Basis Total Cement Volume Notes I Job will be mixed on the Production Casing Cement —STAGE 2 Casing 7" 26# L80 DWC/C Casing Basis Total Cement Volume - (votes I Job will be mixed on the fly Attachment C Production Casing Proposed Cementing Program 1. Pump the 1st stage cement job as per HAL Cementing Program. a. Cement job is planned to be pumped as follows: U. Drop Bypass Plug ix. Land Shut Off Plug on Baffle Adapter and verify floats are holding x. Pressure up to 3,300 psi to shift open ES cementer b. Do not pump over the calculated displacement plus half of the shoe track volume (-y2.4 bbls). If plug does not bump refer to contingency cement procedures. <account for compressibility of MOBM> c. Verify floats are holding. If floats have failed refer to contingency procedures. d. Record type, volume, density, if there were any losses or cementing problems, and volume of cement returns at surface in detail in the morning report. 2. Circulate 1-2X BU with MOBM through ES -Cementer and prepare for 2m stage cement job. Modeling indicates it is not necessary to WOC between stages. a. Be prepared to handle any cement returns at surface that were above the stage tool from the first stage cement job. 3. Prior to commencing second stage cementing operations, reload Halliburton cement head. 4. Pump the 2nd stage cement job as per HAL Cementing Program. a. Cement job is planned to be pumped as follows: ii. Drop Second Stage Bottom Plug b. When Second Stage Closing Plug lands hold pressure for 2 minutes then release pressure and observe for flow back. If no flowback is observed, then tool is closed. If tool is not closed, refer to contingency procedures. c. Monitor for cement returns at surface and ensure a plan is in place to handle cement contaminated returns. Attachment C d. Record type, volume, density, if there were any losses or cementing problems, and volume of cement returns at surface in detail in the morning report. 5. Rig down Halliburton cement head and lines. LI] casing hanger running tool. Attachment C 188.6' B111d 77.7' 43.0" 43.0' 41!16' 10M 4'1602 R. i yy Lei �i f f r... 41118' 10M � 4-1119'10M 41!18" 10M3"1502 � �� = 4'1!18' 10M 3'Y502 41!16' 10M S f4-1116•1sM r- - J 4 N7 -- 3-116'5M 3.116"5M n10 - 11.5M 22.0' \«J_lfl1� L� I I I sit 40 or 2-1116' SM 41118" SM 4-1118-10M UEM od E Pressure Control 16"x 9-5/&'x 7" x 3-112" 5/10M MB -230 Multibawl Assembly, uGRI IES With MB -230 Upper Head and MB -230 Tubing Hanger and K Tubing Bonnet a GE company coyYNwWRaPPOPIYETMYNoi10E DRAWN BY: 6RAWIN6 NO.: �spnxjja]Mi BYrIWd+SaePmnWM.ue[ub+e��9"Md.lp-hM iww�etl. TheYMn�knawYY"d htlh tloo�wa umnPtlmEtl"W .tl rR AAZ49E� a �rameas +P,w�`n.aN ew�.n R�aaa rw�,pwm�.nder..xypw.�e.a�se.ane.e.v.rwara �L aye REYIPWED EY: Rei. S2 OF NC I I "uoukTgoRBhREAPHiORIMA NOf FOR A9WIIFlLT1PlY0 V8E -: 190=48 PIKKA B Attachment D OIL SEARCH ALASKA W C N E t U m a LL C N E .r - u Q Prepared for Date Prepared *Mork of Schlumberger schlumbeflep FracCAUE* STIMULATION PROPOSAL Operator Oil Search Well Pikka B Field Pikka Formation Well Location County North Slope State Alaska Country united States Mike Martin Service Point Business Phone 12-18-2018 FAX No. Prepared by Scott Leahy Phone 907-330-4595 E -Mail Address SLeahy®slb.com Prudhoe Other 1907 659 2434 1907 659 2538 giaclatmer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no lability for advice or recommendations made concerning results to he obtained from the use of any product or service. The results given are astirretes based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment Thu results depend an input dam provided by the Operator and oegmatoa as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual moults that may he achieved and should be used for comparison purposes ratherthan absolute values. The quality of input date, and Was resultsr may he Improved through the use cf certain mate and procedures which Schlumberger can assist in sskecting. The Opermar has sup Her knowledge of the welL the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby d neighboring well or wags mightba affects: by the treshnentproposed herein Moth* Opmamr'e responsibility to naft the owner or owners oftha well or wells accordingly. Pdaa9 quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infdngemslrt of patents of Schlumberger or others is natio be inferred. Schlumberger -Private Attachment G Client Oil Search schw0hplop well Pikka B Formation District Prudhoe Bay, AK Section 1: Zone Data Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio {psi.inll.5} (ft} I (psi/ft) I (psi) I (psi) Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. {ft} Height (md) {%} Pressure Vo 1psil 2 Schlumberger -Private Attachment G Client Oil Search Wall Pikka s Formation Stop Slurry Volume (bbl) District Prudhoe Bay, AK AaL atiloMpgr Section 2; Propped Fracture Schedule Pumping Schedule Please note that this pumping schedule is under -displaced by 5.0 bbl. Fluid Totals 53718 gal of YF125ST 2458 gal of WF125 Proppent Totals 190900 lb of CarboLite 16/20 Pad Percentages % PAD Clean 27,4 % PAD Dirty 23.5 Job Execution Step Name Jab Description Cum. Fluid Volume (gal) Stop Slurry Volume (bbl) Stop Name Pump Rate (bbUmin) Fluid Name Step Fluid Volume (gal) Gel Conc. (lb/mgal) Prop. Type and Mesh Prop. Conc. (PPA) PAD 30.0 YF125ST 14700 25.0 0 0.00 1.0 PPA 25.0 YF125ST 3620 25.0 CarboLite 16/20 1.00 2.0 PPA 25.0 YF125ST 3473 25.0 CarboLite 16120 2.00 3.0 PPA 25.0 YF125ST 4450 25.0 CarboLite 16/20 3.00 4.0 PPA 25.0 YF125ST 4996 25.0 CarboLite 16/2D 4.00 5.0 PPA 25.0 YF125ST 5847 25.0 CarbDLita 16120 5.00 6.0 PPA 25.0 YF125ST 5975 25.0 CarboUte 16/20 6.00 7.0 PPA 25.0 YFI25ST 4811 25.0 CarboUte 16/20 7.00 8.0 PPA 25.0 YF125ST 4344 25.0 CarboLite IWD 8.00 9.0 PPA 25.0 YF125ST 1502 25.0 CarbaLite 16120 9.00 FLUSH 25.0 WF125 2458 25.0 0.00 Please note that this pumping schedule is under -displaced by 5.0 bbl. Fluid Totals 53718 gal of YF125ST 2458 gal of WF125 Proppent Totals 190900 lb of CarboLite 16/20 Pad Percentages % PAD Clean 27,4 % PAD Dirty 23.5 Job Execution Step Name Step Ruid Volume (gal) Cum. Fluid Volume (gal) Stop Slurry Volume (bbl) Cum. Slurry Volume (bbl) Step Prop (Ib) Cum. Prop. (Ib) Avg. Surface Pressure (psi) Stop Time (min) Cum. Time (min) PAD 14700 14700 330.0 350.0 0 0 17.7 3.6 3.6 4.6 11.7 15.3 18.9 23.7 1.0 PPA 3620 18320 90.0 440.0 3620 3620 2.0 PPA 3473 1 21793 1 90.0 530.0 6946 10566 3.0 PPA 4460 1 26243 1 120.0 650.0 1 13349 1 23915 Schlumberger -Private Attachment G Client Oil Search well Pikka B Formation District Prudhoe Bay, AK Sr> Mpoer 4 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) {Ib) Pressure (min) (min) (gal) (bbl) {bbl) {psi) 4.0 PPA 4996 31239 140.0 790.0 19985 43900 5.6 29.3 5.0 PPA 5847 37086 170.0 960.0 29236 73137 6.8 36.1 6.0 PPA 5975 43061 180.0 1140.0 35849 108986 7.2 1 43.3 7.0 PPA 4811 47872 150.0 1290.0 33677 142662 6.0 49.3 8.0 PPA 4344 52216 140.0 1430.0 34748 177411 5.6 54.9 9.0 PPA 1502 53718 50.0 1480.0 13520 190931 2.0 56.9 FLUSH 2458 56175 58.5 1538.5 0 190931 2.3 59.2 4 Schlumberger -Private Attachment G Client : Oil Search SchInhPlor well Pikka B Formation : Nanushuk District Prudhoe Bay, AK Section 3: 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 Fed are calculated based on perforated intervals with positive net heights. 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_______________ 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 (in) (ft} Cone. (Ib/mgal) (md.ft) (PPA) flb/ft2) 5ch lum berger-Private Attachment G chi plep Client: DII Search Alaska Well: Pfkka B Basin/Ffeld: Pikka State: Alaska County/Parish: North Slope Borough Case: 7280890 Disclosure Type: Pre -Job Well Completed: 2/22/2019 Date Prepared: 12/14/2018 1:11 PM Report ID, RPT -59132 yr325R�T-WFI�5 ?3.674 Gal Contains Water, 5urfactanty Jiresker, Breaker Aid, Crum'If1krt. GuBing Agahl, LlayCurtraiAoem, Mnr ricfdr_ PfUV;15Agant rbcs w,4ME 411MAil�mnik,a wan WMMP +nn 4t+ trrsnA R*Il+er yhilc7sviv4eu7vcRent `.rveuwv—pµreuuy— 3—warp o—i y—na MMYXB or me wnwrvrmcvnrmrprvvmea weawvwn w eamponenm mvcmvy neve been avuea M me warervy mrm-parses. • the evahmdan of attvcheddocumealsPerhaned based an the campasldan of rhe identrykdpmductc to the extent Mot such camPasMonal f & marWn was Anvum to GRC-Memkars as bf the date of the dacumem was produced. Anynew updates wM=t be rcjiectedin this docbmewt. Attachment H 0 Schlumberger201a Used by Oil Search Alaska by permission. Page- 1 / 1 v'vaier'IlFicluding Mix Water SupplieabyCrienij- —77 % 56402-68-4 Ceramic materials and wares, chemicals —22% 57-48-1 2-hydroxy-N,N,N-trimet ethanaminium chloride <1 % 9000-30-0 Guargurn <1% 7727-54-0 Diammonfumperoxidisul hate <0.1 % 56-81-5 1, 2,3 - Propanetrior < 0.1 % 1303-96-4 Sodium tetraborate decahydrate < 0.1 % 102-71-0 2,2',2"-nitrllotrlethanol <0.1 % 111-76-2 2-buto ethanol <0.1 % 67-63-0 P►a an-2-ol <0.1 % 34398.03.1 EthaxyratedC11Alcohol <0.1 % 25038-72-6 Vinylidene chloride/methylac late copolymer <0.1 % 63-42-3 Lactase <0.01 % 68131-39-5 Ethoxylated Alcohol < 0.01 % 91053-39-3 Diatomaceous earth, calcined < 0.01 % 112-02-5 Undecanol <0.01 % 7631-86-9 Nan -crystalline silica (impurity) <0.001 % 14807-96-6 Magnesium silicate hydrate talc < 0.001 % 10377-60-3 Magnesium nitrate <0.001 % 26172-55-4 5 -chloro -2 -meth I-2h-isothiatolal-3-one <0.001 % 7786-30-3 Magnesium chloride <0.001 % 9002.840 of jtetraflucroeth ene < 0,001 % 9050.36.6 Maltodext►fn <0.001 % 2682-20,4 2-methyl-2h-iscthiazol-3-one <0.0001 % 127-08-2 14808-60-7 14464-46-1 6419-7 9004-53-9 9[172 -SA -R Acetic acid, potassium salt Quartz, Crystalline silica Cristobalite Acetic acid (impurity) Dextrin N4mIL@nl�la5@ 4nFyrno <0.0001 % <0.0001 % < 0.0001 % < 0.0001 % _ < 0.0001 % A nnl n, yrF `.rveuwv—pµreuuy— 3—warp o—i y—na MMYXB or me wnwrvrmcvnrmrprvvmea weawvwn w eamponenm mvcmvy neve been avuea M me warervy mrm-parses. • the evahmdan of attvcheddocumealsPerhaned based an the campasldan of rhe identrykdpmductc to the extent Mot such camPasMonal f & marWn was Anvum to GRC-Memkars as bf the date of the dacumem was produced. Anynew updates wM=t be rcjiectedin this docbmewt. Attachment H 0 Schlumberger201a Used by Oil Search Alaska by permission. Page- 1 / 1 Pikka Bst1 Clean-up and Test Summary PIKKA B 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 test Attachment I Duration I Build Up Table (hours) PurposeFlow A Bring well 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 Flow to avoid damage to proppant pack and minimize errosion to surface equipment. The OS Resevoir Engineer will determine when the well is clean and advise choke changes/rates for initial flow period. Shut in well to obtain reservoir pressure Initial Pressure Build Up 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 initial Flow will betaken at the J Separator as per Multi -Rate 1 Reservoir Engineer's Multi -Rate 2 direction Multi -Rate 3 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 forvarious reservoir 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 test Attachment I Well Cleanup - Operational Summary: • Estimates Time; -is directed by Oil Search Reservoir Engineer. • Target Clean-up Flow Rate- 07'arget Post Clean-up Flow Rate: • Choke Setting: Use adjustable choke to make the adjustments needed to achieve 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. ErAulti-Rate 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 DL J 3-'N'9.2 ppf L80 TCII Tubing Wellhead, 9-518" x 3 -IN', 5K psi, 10 K XT Conductor, 20" Uninsulated set at 80 ft Surf. Casing 9-&8" 47# L80 R3 BTC -M le Pikka B ST1 2.813"'X' landing Nipple KBMG with Dummy Vale Mandrel, 318" SS line Wl' Oil Search Plsran�d V��' y . GLM, 3-1/p." x 1 ", Chem Injection 344 cable clamps: 0.433" (W) Encap gauge line, 0.433" (1✓W') Encap SSSV line, 318"' Chem Inj Line - 2.813"X' Landing Nipple ,3-1/FNE TRSSSV, 2.813"'X' Profile, 0.433"(1/4") SSSV Encapsulated Une Confidential 3-1/2' SRO HAL ROC Tubing P/T Gauges Mirage Plug & AutoFili Sub 2:75"'XN' Landing Nipple .` Production Liner, 7" 26# LBO R3 DWC Attachment K