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Home My WebLink About2018-02-22_318-076STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑ 217-169 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20766-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A 7 Will planned perforations require a spacing exception? Yes ❑ No [21Tinmiaq 9. Property Designation (Lease Number): 10. Field/Pool(s): EXPLORATORY 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (all Casing Length Size MD TVD Burst Collapse Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 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 EI Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 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: Sandeep Pedam Contact Name: Sandeep Pedam Authorized Title: ff Completions Engineer Contact Email: Sandeep.Pedam@cop.cem I g. Contact Phone: (907) 263-4724 Authorized Signature:Date: 2 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 11 Q n 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: Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Dupliate From, Sandeep Pedam ConocoPhillips Alaska 700 G St, Anchorage, AK, 99502 To, Guy Schwartz Alaska Oil & Gas Conservation Commission 333 W 7`^ Ave #100, Anchorage, AK 99501 Under cover of this letter, ConocoPhillips Alaska, Inc., ("CPAI") is submitting an application for sundry approval to hydraulically fracture the Tinmiaq 7 exploration well recently drilled on federal lands in the National Petroleum Reserve—Alaska ("NPR -A"). Some information in the application reveals well data that is protected, confidential information under federal law, and also under state law (to the extent it is not preempted by federal law). To preserve confidentiality, CPAI is including a copy of the application that has confidential information redacted. Only this redacted copy may be posted on the AOGCC's public Internet website, as provided in 20 AAC 25.280(f). Regards, Sandeep Pedam Staff Completion Engineer Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Date 20184141 state: Alaska County: Harrism. Be API Number. 5010320786 --- d51TdU5PRl1DP§ NORTH SLOPE - OperatorName: EBUS Well Nem. and Number Til 7 Longitude: -152.25 laldird.: 70.22 Longue% Projection: Fill liniaNFetlam- none ProdubtlorTir i Oil Time Vertical Depth (TVO): 0 Total Water Volume all`: 30,221 Hydraulic Fmctudng Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration In Additive Concentration In Ingredient Mass Comments Company First Name Lest Name Email Phone Number (CAS (% by mass)" HF Fluid (%by ibs #) mass'" sea Water Operator Base Fluid Water 7732-18-5 96.00% 60.102569 24]]64 Density=8540 BE-6 Halliburton Biocide Listed Below listed Below MICROBIOCIDE 0 NA CAT4WB Halliburton Activator Listed Below Listed Below 0 NA CL-31 Halsburton Crosslinker Listed Below Listed Below C RO NKER 0 W` LMURF-3001 Halliburton Nonionic Surmount Listed Below Listed Below 121NA SP BREAKER Halliburton Breaker Listed Below Listed Below 0 NA WG-36GELLING Halliburton Gelling Agent Listed Below Listed Below 0 NA AGENT Carbo C.m.NRT 20140 Additive Listed Below Listed Below Ceramms 0 NA MBDS dndNonW SDS9ngredlenls a relisled belawthe greCpaf, '- In retlrents Listed Above 1,24 Tdme1M1 Ibenxene 95636 0.000934 3 2-Bromo-2-nitro-1,3- roenediol 52-514 too.0ox m. mm145r 5 Cloudi. materials and wereH 66402681 100.00% 16.16516% 500W Denise Tuck, Halliburton, 3000 EDTAICopper chalet. Proprietary 30.00% 0.00806% 25 N. Sam Houston Harmon. Denise.TuckQ Denise Tuck Hallibunon.co 281-871-6228 Pkwy E., Houston, TX 281- m 8]1-82W2826 Ethanol 6417-5 60.00% 0.04405% 137 Guar um 900040-0 100.00% 0.19528% 605 Heavy aromatic Ficrolatim naphtha 64742-94-5 30.00% 0.02203% 68 Methanol 67-56-1 30.00% 0.00806% 25 Naphthalene 91-20.3 5.00% 0.00367% 12 Deniii.T.cl Oxylated phenolic resin Proprietary 30.00% 0.02939% 92 Hellieston Denise Tuck Hallibunon.co 281-871-6226 in Poly(oxy-1,2etminedlyll, alpha-(4- nonylpheml)-omega-hydroxy-, 12]08]-87-0 5.00% 0.00367% 12 branched Potassium hydroxide 1310-58-3 5.001 0.004439 14 Potassium meteborate 13719-94-9 60.00% 0.05312% 165 Sodium chladde 7647-14-5 4.00% 3.33761% 10324 Sodium perattlate T/]5-2]-1 100-00%1 0.009128 129 sodium sulfate ]]5]62-6 0.10% 0.000019 1 Water 7]32-18-5 100.00% 0.07999% 240 Total Water Volume sources may include fresh water, produced water, and/or recycled water " Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. All component information listed was obtained from Me supplier's Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration's (OSHA) regulations govern the criteria for the disclosure of this information. Please nota that Federal Law Protects "proprietary', "trade secret", and "confidential business information" and the criteria for how this information is reported on an MSDS is sub act to 29 CFR 1910.1200 and Appendix D. Section 1- Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one- half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1) This information is confidential and is therefore redacted Section 2 - Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within 0.5 mile Table 1: Wells within 0.5 mile Section 3 - Freshwater Aquifers 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within one-half mile radius of the current or proposed wellbore trajectory. Section 4 - Plan for Baseline Water Sampling for Water Wells 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. Section 5 - Detailed Cementing and casing information 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.030(b) and tested in accordance with 20 AAC 25.030 (e) when completed. This information is confidential and is therefore redacted Section 6 - Assessment of each casing and cementing operation to be performed to construct or repair the well 20 AAC 25.283(a)(6) Casing & Cement Assessments: This information is confidential and is therefore redacted Section 7 - Pressure test information and plans to pressure test casing and tubings installed in the well 20 AAC 25.283 (a)(7) 20 AAC 25.253. Hydraulic fracturing This information is confidential and is therefore redacted Section 8 - Pressure ratings and schematics for the Wellbore, Wellhead, BOPE and Treating head 20 AAC 25.283(a)(8) 20 AAC 25.283. Hydraulic fracturing (a) Before hydraulic fracturing, the operator must submit an Application for Sundry Approvals (Form 10- 403) under 20 AAC 25.280. Unless modified or altered by pool rules established under 20 AAC 25.520, the application must include (8) accurate pressure ratings and schematics for the wellbore, wellhead, BOPE, and treating head; This information is confidential and is therefore redacted Stimulation Surface Rig -Up m a BT.I. Talae Tele Ta k 3� m; J c d� a`@ r v i a Mmi dwnd U d e 0 Pop -0a Tank • Min. press. Rating on all surface treating lines 10,000 psi • Main treating line PRV set to 95% of max. treating pressure • IA parallel PRV set to 3600 psi • Frac pump trip pressure setting staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi Pc"ff Tard, Pump hock Tree Saver With Wellhead ►� OIL STATES Energy Services (Canada) Inc. QUOTE#: Maximurn Allowable Pumping Rates DATE: PROPOSAL: : SIZE CSG ID 2.260--1 .D 3.750 RATE tr'lmin 1 10 m'lmin 3112" Big Bore 1.750 2.750 6 m'lmin -17/8" & 3112" 1.438 2.360 4 m'lmin 2 318" 1.000 1.900 2 m'/min 31/16 & 41116 with tapered mandrel 2.750 4.000 15 m'lmIn 41116 X Tool Mandrel 3.610 4.760 24 m'lmin CLOSED POSITION I OPEN POSITION u111 .. .. u. eel,... Y. y I no � : uvviiiw..i i I Di 1.� W wumra / vino. \ m.o � se CLOSED POSITION I Pressure rating: 15,000psi www.osescanada.com owun.�. u111 .. .. u. eel,... Pressure rating: 15,000psi www.osescanada.com Wellhead #NCTechnologles r�n." GENERA'T'ION 5 WELLHEAD 1 III(, -'_COD IRU mi 4 1115 -SOC. Alai; on CY Section 9 - Data for Fracturing zone and confining zones 20 AAC 25.283(a)(9) This information is confidential and is therefore redacted Section 10 - Location, Orientation and a Report on Mechanical Condition of Each Well that may Transect Confining Zone 20 AAC 25.283(a)(10) This information is confidential and is therefore redacted Section 11- Location of, Orientation of and Geological Data for Faults and Fractures that may Transect the Confining Zones 20 AAC 25.283(a)(11) This information is confidential and is therefore redacted Section 12 - Proposed Hydraulic Fracturing Program 20 AAC 25.283(a)(12) This information is confidential and is therefore redacted Section 13 - Post -Fracture Wellbore Cleanup and Fluid Recovery Plan 20 AAC 25.283(a)(13) Little Red Services with be the Well Testing company for Tinmiaq 7. The base case for the flow test consists of four periods: Period Duration (hrs) 1 Post frac high draw down clean up flow 72 2 Shut-in pressure build up period 72 3 Main flow - low drawdown period 240 4 Main shut-in period 240 The "post -frac high draw down clean up flow" period is intended to produce the frac fluid back as quickly as possible until the well is producing at less than 10% water cut. We will likely need N2 to kick the well off and will have it on location to sustain flow if needed. The "shut-in pressure build up period" will be equal to the time of the first flow. The "main flow period" will impose minimal drawdown while maintaining stable flow for the duration. We will collect downhole samples, pressurized gas and oil samples, and stock tank oil. We will flare the produced gas through Little Red Services flare stack with a continuous pilot. During the "main shut-in period" we will monitor the pressure buildup. There will be a tank farm on location with —4,000 BBL capacity. Fluid will be trucked to either Alpine or Kuparuk (depending on what fluid) with appropriate North Slope Manifests and volumes for each transport. We will take tank straps before and after transport loading to calculate total fluid leaving location. During the testing operations, we will be taking 30 min tank straps to confirm volumes. Shakeouts will be taken on 30 min intervals for water cut and BS&W. A Micromotion and Phase Dynamics will also be installed for continuous flow rate monitoring. Once the flow test is complete we will suspend the well with permanent downhole gauge for pressure monitoring. Proposed Well Testing Layout r R -.LE I, FEET 00�� E -ILI Little Red Services MID