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Home My WebLink About2019-08-08_319-368STATE OF ALASKA AUG 0 8 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development o 219-059 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20803-00-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 CRU CD5-98 9. Property Designation (Lease Number): 10. Field/Pool(s): ASRC-NPR4, ASRC-AA092344, ASRC-NPR2, ASRC-NPR3 I Colville River Field I Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total DepliaMID (ft) Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 32;4 V 7,76T 31,468 7,716 7,500 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 74' 20" 115, 115, Surface 2,245' 10 314 2,286' 2,177' Intermediate 14,321' 7 6M 14,362' 7,640' Liner 17,268' 4112 31,468' 7,716' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 41/2" & 3 1/2" L-80 est 14,223 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Halliburton TNT Packer no SSV est 13,945 & 14,169 MD no SSSV 12. Attachments: Proposal Summary ❑ Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development p Service ❑ 14. Estimated Date for 8/12/2019 15. Well Status after proposed work: Commencing Operations: OIL p WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 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: Adam Klem Contact Name: Adam Klem Authorized Title: Sr. Completions Engineer Contact Email: adam.klem.@cop.com Authorized Signature: Date: Contact Phone: (9D7) 2634529 � � G� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test r] Mechanical Integrity Test ❑ Location Clearance ❑ Other. (Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY by: COMMISSIONER THE COMMISSION Date: ORIGINAL Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate CD5 - 98 Alpine A/C Dual Lateral Producer Proposed Schematic 20" 94# H-40 Welded Conductor to 115' MD 10-3/4" 45.5# L-80 TXP x BTC Surface Casing at 2,286' MD 4-%" x 1" GLM 4-1/2" 12.6# L-80 Hyd563 4-'/2" x 1" GLM 7 5/8" 29.7# L-80 TXP Intermediate Casing at 14,362' MD 4-'/" x 1" GLM Upper Completion: 1) 4 %"-12.6# Hyd563 tubing 2) Shallow nipple profile 3.813" ID 3) 4-%" x 1" Camco KBMG GLM (xx°) w/DCK2 pinned for 2500 psi casing to tbg shear 4) SLB DHG 5)TNT Packer 6) X Nipple profile, 2.813" 7) TNT Packer 8) XN Nipple profife, 2.813" Lower Completion: 8) Plop and drop liner in C sand - no junction -4.5" 12.6# L-80 w/ perf pups 9) ZXP liner top packer & Flexlock Liner Hanger XO 5" Hydril 521 Box X 4-1/2" H563 pin -4.5" Hydril563 12.6# L-80 w/ Frac Ports C sand Lateral 6 1/2" Hole TD 14,134'- 29,480' MD ----------------------------------------------------------- 4-'/2" 12.6# L-80 Hyd563 Liner w/ perf pups 0 0 0 0 0 0 0 0 TNT Production PE at 13,945' MD 4=/2" 12.60 L-80 Hyd563 Liner w/ frac ports to 31,468' HP Sliding sleeve for Selectivity 14,000' MD 3-1/2" 9.3# TN110SS TNT Production Packer A sand Lateral at 6 1/2" Hole TD 14,169' MD ZXP liner top packer 14,341' — 32,468' MD at 14,200' MD 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). TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation } Commission in the Matter of the ) AFFIDAVIT OF Jason C. Parker Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the CD5-98 Well ) under the Provisions ) of 20 AAC 25.280 STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) H Jason C. Parker, being first duly sworn, upon oath, deposes and states as follows: My name is Jason C. Parker. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. 1 am a Senior Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On August 5, 2019, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 5th day of August, 2019. C a C rker STATE OF ALASKA ) H THIRD JUDICIAL DISTRICT This instrument was acknowledged before me this 5th day of August, 2019, by Jason C. Parker. 4)__Q&Z,1S4 Y.0&e., Notary Public, State of Alaska My Commission Expires: STATE OF ALASICA NOXARY ?PUB] IC REBECCA WENSEN M CmwnW iort Ex A . 27, 2OX Alaska August 5, 2019 To: Operator and Owners (shown on Exhibit 2) Jason C.Parker Senior Landman Land & Business Development ConocoPhillips Company 700 G Street Anchorage, AK 99501 Office: 907-265-6297 Fax: 907-263-4966 jason.c.parker@cop.com VIA CERTIFIED MAIL Re: Notice of Operations pursuant to 20 AAC 25.283 (1) for CD5-98 Well AA-92344 (ASRC), ASRC-NPR2, ASRC-NPR3, and ASRC-NPR4 Colville River Unit, Alaska CPAI Contract No. 203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Colville River Unit ("CRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the CD5-98 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about August 5, 2019. This Notice is being provided pursuant to subsection of 20 AAC 25.283. The Well is currently planned to be drilled as a directional horizontal well on leases, AA-92344 (ASRC), ASRC-NPR2, ASRC-NPR3, and ASRC-NPR4 as depicted on Exhibit 1 and has locations as follows: Location FNL FEL Township Ran a Section Meridian Surface 281' 2401' T11 N R4E 18 Umiat Top Open Interval 582' 2555' T11 N RK 12 Umiat Bottomhole 1 471' 4315' 1 T11 N I R4E 1 29 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information, please contact the undersigned. Sincerely, Jaso . Parker Senior Landman Attachments: Exhibits 1 & 2 Exhibit 1 Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator & Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attn: Misty Alexa, NS Development Manager Owner (Non -Operator): None Landowners: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage, Alaska 99503-5963 Attn: Teresa Imm, Executive VP, Regional and Resource Development Surface Owner: Kuukpik Corporation P.O. Box 89187 Nuiqsut, AK 99789-0187 Attn: Joe Nukapigak, President Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within .5 miles Table 1: Wells within .5 miles APE Well Name Well Type 501032073600 CD5-01 INJ 501032073700 CD5-02 SVC 501032073701 CD5-02A INJ 501032071800 CD5-03 PROD 501032071100 CD5-04 PROD 501032071200 CD5-05 PROD 501032074400 CD5-06 ]NJ 501032074460 CD5-06L1 INJ 501032073400 CD5-07 INJ 501032074100 CD5-08 INJ 501032072300 CD5-09 PROD 501032072400 CD5-10 PROD 501032072600 CD5-11 PROD 501032074200 CD5-12 INJ 501032075400 CD5-17 INJ 501032075460 CD5-17L1 INJ 501032075000 CD5-18 PROD 501032075060 CD5-18L1 PROD 501032076000 CD5-19 ]NJ 501032076060 CD5-19L1 INJ 501032075260 CD5-20L1 PROD 501032073800 CD5-21 PROD 501032075900 CD5-22 PROD 501032076100 CD5-23 INJ 501032079900 CD5-24 PROD 501032079960 CD5-24L1 PROD 501032079970 CD5-24L1PB1 EXPEND 501032076500 CD5-25 INJ 501032076560 CD5-25L1 INJ 501032071400 CD5-313 PROD 501032071470 CD5-313PB1 EXPEND 501032070700 CD5-314 PROD 501032075500 CD5-314X PROD 501032071600 CD5-315 INJ 501032071670 CD5-315PB1 EXPEND 501032075600 CD5-316 INJ 501032075670 CD5-316PB1 EXPEND 501032074800 CD5-99 PROD 501032074801 CD5-99A PROD 501032074861 CD5-99AL1 PROD SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, Alpine Oil Pool: Enhanced Recovery Project, which states "No underground sources of drinking water ("USDWs") exist beneath the permafrost in the Colville River Unit area." 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 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. 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: 10 & %" casing cement pump report on 6/9/2019 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg LiteCrete lead and 15.8ppg class G cement, displaced with 10ppg mud. Full returns were seen throughout the job. The plug bumped at 500 psi and the floats were checked and they held. The 7 & 5/8" casing cement report on 6/23/2019 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 15.8ppg Class G tail. The plug bumped at 1600 psi, and the floats were checked and they held. Partial losses were observed during cement operations, however the cement was logged and TOC was determined to be at 12,850' MD. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 6/11/2019 the 10-3/4" casing was pressure tested to 3,500 psi for 30 mins. On 6/25/2019 the 7-5/8" casing was pressure tested to 3,500 psi for 30 mins. The 3.5" and 4.5" tubing will be pressure tested to 5,200 psi prior to frac'ing. The 7-5/8" casing will be pressure tested to 3,850 psi prior to frac'ing. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 6,000 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 7 5/8" Annulus pressure test 3,600 3,850 4.5" & 3 1/2" Tubing pressure Test 5,200 Nitrogen PRV 7,600 Highest pump trip 7 400 SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & %11 45.5 L-80 2,090 psi 3,580 psi 7 & 518" 29.7 L-80 6,890 psi 4,790 psi 4.5" 12.6 L-80 8,430 psi 7,500 psi 3.5" 9.3 TN-110 13,970 psi 12,620 psi Table 2: Wellbore pressure ratings Stimulation Surface Rig -Up a til d.�tl� in ru E �C 00 F 40-:71f 1 WA F ra_ Vwly FTg„, hunk ■0 v�� rLa 0 ■ • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Nnp Teua( HN:: P .0 f:'JI C'ur-1p Alpine 1 OK Frac_= Tree I SECTION 9 - DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Alpine A interval is approximately 30' TVD thick at the heel of the lateral and generally maintaining the same thickness to the toe. The Alpine A sandstone is very fine grained and quartz rich, with a coarsening upward log profile. Top Alpine A is estimated to beat 14,559' MDI-7,434' TVDSS. The estimated fracture gradient for the Alpine A sandstone is 12.5 ppg. The overlying confining zone consists of greater than 500' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ was encountered at 13,002'MDI-6,785 TVDSS. The underlying confining zone consists of approximately 1800' TVD of Kingak shales. The estimated fracture gradient for the Kingak interval ranges from 15-18 ppg. Fracture gradient increases down section. The top of the Kingak shale interval ranges from --7,460' TVDSS at the heel to --7,695' TVDSS at the toe of the well (no MD as the Kingak interval was not penetrated in the CD5-98 wellbore). SECTION 10 -- LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casino & Cement assessments for all wells that transect the confinin zone: C135-25 and CD5-25L1: The 7-5/8" casing cement pump report on 7/25/2015. Full returns were not seen throughout the job. The cement job was pumped with 12.2ppg lead cement and 15.8 ppg Class G tail cement, displaced with 10.6 ppg WBM. The plug bumped at 1,000 psi and the floats held. CD5-23: The 7-5/8" casing cement pump report on 1/712018. Full returns were seen throughout the job. The cement job was pumped with 15.8 ppg Class G cement, displaced with 10.8 ppg WBM. The plug bumped at 1,100 psi and the floats held. CD5-315: The 7-5/8" casing cement pump report on 1013/2015. Full returns were seen throughout the job. The cement job was pumped with 15.8 ppg Class G cement, displaced with 11.1 ppg WBM. The plug did not bump but the floats were checked and they held. � > $ � 0 m � Q c 0 +j � E .P � 2 u � � co Ln 0 J�! . > K■! ki k2 }2;Ew i`§ ■! � w k R m| } \ § _ & Ln $ % § o F- / k ! ! ! ! � � k� - om.■ BE c - } - § § |_ $ § - \ _ q } }�� \ / £§ ! _ o a \ 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) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that five faults or fracture systems transect the Alpine A formation or enter the confining zone within one half mile radius of the wellbore trajectory for C05-98. The first fault the CD5-98 weilpath intersected occurred at 14,559' MD and had a throw of 3'. This fault was not interpreted in the seismic. The second fault, at 18,263' MD, was interpreted from seismic data prior to drilling and confirmed with log data (throw of 24'). CD5-98 next intersected a fault zone of two faults that were mapped as one fault on the seismic. This zone consisted of a fault at 26,045' MD and one at 26,198'MD with a combined throw of 27' The fourth and fifth faults was mapped with seismic data as one fault and intersected the wellbore at 32,072' MD and 32,102' MD with a combined throw of 35'. Any faults that are within the half mile radius of the wellbore do not extend up through the confining interval, and fracture gradients within the top seal intervals would not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. Based on our knowledge of the principle stress direction in the Alpine A formation, along with the well path, all of the fractures will be longitudinal, running parallel to the wellbore. Because of this the fractures will only intersect faults that intersect the wellbore. We do not expect any of our hydraulic fractures to intersect faults seen in this wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. Well Name Depth MD (ft) Depth TVDSS (ft) Vertical Displacement Loss (bbls/hr) CD5-98 15919' -7,45 P 3' 0 CD5-98 18264' -7,462' 24' 25 C135-98 26,045 -7,568' 10' 35 C135-98 26,198' -7,567 17' 40 CD5-98 32,072 -7,643' 20' 15 C135-98 32,102 -7,643' 15, 15 Plat 2: CD5-98 Fault Analysis SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD5-98 was completed in 2019 as a horizontal producer in the Alpine A and C formation. The well was completed with 4.5" tubing, with 3.5" tubing isolating the C lateral. In the A sand is a 4.5" liner with ball actuated sliding sleeves. After the 1 st stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2"d stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Alpine A Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 25 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 1000 F seawater (approx. 26,991 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU HES Frac Equipment. 6. PT Surface lines to 9,500 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Bring up pumps and increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. 9. Pump the 100 bbl breakdown stage (25# Hybor G) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 35 BPM as quick as possible, pressure permitting. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following attached HES schedule @ 35bpm with a maximum expected treating pressure of 6,000 psi. 12. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 13. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 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IBN��s•R�I•tW� B gp. s� r i s ^$Bi 25X tl � �„� � tlK tl ^� � $$z 25a ��an � �75 � S iG tl 0 ma ��• a� $88�� $888 .8$8� 86ad 88$8�8� 888 $$$888 a smm SSSS SSH S9SSS9 S S S R R 8n R 3�333 �3' 3 °3�53 atl3'3 <<<_-a� 333�333 �3?3 333333 s3?3. __ 99 `gym ��d8� g9a�9� �9E:��m �� oLLvaccvm 5E �i �9aaaa99$ _` " c c. 9 e$= a399�99 a c c c c E a E & P c -s�99� a aand $ ao aan eeea" ggd " 2: �BeV ddd LL t xxx xx x xx x xx m. �zxx by _ !�!f � MAE g �. u • u•# d. u a. u i a. a• f a a. u ,.-m • s @ C UIRM"I 9L 1"" LLPNaIul BI PARM BLP+-W°I OL reumf I LdPmmmI iZ W-" C I1B a c c m a 8 4 m o t5 v Ln N N Q o Hydraulic Fracturing Fluid Product Component Information DIsclosure FI.-hers, DOU M84&13 apse OWITY R.rdwn Am Hpmerr 491132DO t wMaLOPE- cow fr Numas Bats VAM them and Nmular emu Lam151-U L+ebgl: 7M tamiiilg Prate Loa: NRD17 ge.rff.d.Lsk --2202 Frmpdwkm oil Tm. ikrlktl Depk 6>mlBDO Td.l UWh 100 0 Hydraulic Fracturing Fluid Cemlwalli m: GirallL� A6s9aet MWvratm lnsredient Ilglradieelt . Tmd. 14sme 813p Puq— htgredrnets 3arviva Coneeltbabas in Addub" Concerlhabmr an, inp �S Mae, Cgrwmants Cneupany Final Npmn Lsst Nsnw ERIer7 phone reeae HumbrK (QU PA by rricur HF Fluid (%by S.aWaler C Fkdd Wder 773&1&5 M.noe 9us)8 88640LrB Density -MM Bse MCRC61OCIDE "I Bl de Lewd Bd., Lewd Bah- o NA CL-22UC HabuRm Cmealinker LW d New Listed BNow C ryp, CL31 CRC6tgJNKER Hallbuion CamLMw Llewd Below Laaad Sul- 0 NA LOMJRF 7000 HBUburt n Sufacbre u.M Bdae Lhletl Bd_ p NA M0.67 rldLarwrr ph Carml Addiiw listed Behr lived Bala. 0 NA CPTIFLO-kl ELE RELEASE Hbu.n t Brmmr UseUsed!Belo, dated Bekaf 0 NA BREAKER SP BREAKER I-b lhutem Breaker Listed Bdb Lipwd Bela, 0 14A WG38 GELLIHG Hebu, GNkrg Agent L.k.ed Benin Listed Bel= AGENT 0 NA Wr400 Par— Finam-Pnxadt Leted Ed- Ustedawar 0 NA W.di 3y4O War. Prq*.M Can Addi W d.led 8.6— L.Ialtl Bah- 0 NA lea I�wrp l.detl Mole l.bltl Ab,a 124 T1mer hamarre 95-634 � 1..O S§ a. C00]5: 2-Braau LOW 5231-7 1110 -.08 0.0015a'- 165 Dalh.Ttak, He4bul(ar, 3000 D-i..Tuck® "Me P*.. Pmprwry 1..- 1.00112- 112 N. Sem Halmbn Play E. 1{.{i5ttm Hall.- Dslee T_k Fedkbrdam.o. 2B13M-®B TA 77032,201- 8714ME A...rb— purdrMba 7727-540 1TP.409 ).52000 2194 Derrlae.Tndt® �'de ads P ropri.lvy GJ. SJY a.JEJo1g 8873 Hlallbur[m curb. Mk lWlbrawn.a0 re 291-B71-0726 Carsdun t8�746 a5.00. c.6n26e 1053000 Iba d' 14906$D7 ?a.JJa p.3701x: 670 Dien s. Tull@ Cu1d.Rykc reen pl%aaery _i.009 a COhuI'. 658 HWObLrlm D... T k Fsrb—ca an 28T-M-MM Emerral 04-176 cn,.C. 4948 Gus rm 8D0&3&0 1 a. 3o_ n. e5.52. 27415 iumda pekIXevmnaphlive 64742-94-5 ?O. o08 u.rl.'.:fils 2474 Mreetad DUW light 64742-41-B lay .110% 0m2�5Ne 30121 Mube 1302-M-8 [0.3ca 6..M61 72M Wifthudure 81-70-3 5 Jag 3.0037'1 413 O.d—Tud,® mrylel M phaoke reern P-pdNOry -e.cpx 0. 0501fe iruibudan Dare. Tuck Aalburhm- 20149142M Poy(auq-1 2eth madlyl), Wo. 4+ rvMylPharr*_-ss4lldrory-. 127W437-0 041 a.anal•.. 413 bren.hud Pubaakanlormaw 59&2¢4 EO. JaB c.OFJg39 �77 P.1-1t. 1310.5&3 ..6 a 11. 0.1236+ 259 Pcrosaiun mdaborata 13708,949 Ca. n09 n. 3]011R 3088 Scdian ad drum 900442-4 1�C-e 6.00102% 112 SWkrn chlarld. 7647--145 4. C.k a. 76raa 389502 Gwk" nwkft 2838820 1-301 0.00132-. 112 $odium hydraWde, 1310-7.2 .c0; n,O1, lI- IRS a.dlrlm parsulan. 7i75-27-1 lab.00S n.a002C' 31 $odium arlane 7767$2-6 I 1 Ware 9 Total 1Nater Vof ume s.ueea may Includeflesh rater, produced water, endlor recycled !rider "information is belled an the madmum potential for cnneelmagon and thmths told maybewar 1D0% Nate: For Field De slopmem Produda (pmdmW tlmt begin with FDP), MBDS imr l my If rDrmafion has been provided Aa mmpmertinformatlan Ilded was ahwinetl fmm the eupplier'a fddedal salary Da♦a 5heew (M5O5). As such, the Operator h not mprxrelHe for Ihacclaste andlorinmmpldeinhurmadon. Any quaefiens regarding the content of the MSDS should be directed to the supplier who XWdsd R The Occupational Safety and Health AtIninistraBenl. (OSH4) rpDagana go -ern the criteria for the dtadnawe orthis hAannatlon. Flame note that Federal Law pdecw "praprieta y', Tmde acme', and'bonedurdal business lnformarfiarf' and the criteria for hmr this Irdormatnn ill remdod anon MSDS is au 'ectta 29 CFR IRIG.12ODfil and Awandix D. N 00 dl 0 u (D �► V li 4, U70- V, cV o V1 � N 0 VI � N 0 V7 N 0 c1 � N 0 0)) V [V 0 V1 qt N 0 V, N 0 V' N 0 01 N 0 VI N 0 3 t .bb a� o m 0 m 0 m 0 m 0 m 0 m 0 cn 0 m 0 can 0 m 4 0 ro r4 2 � W40 CL Ay O O 00 O 00 O W 00 W W 0 W O W o W 0 W 0 W 0 W a O 7 F— 4� QD w w w w w LD en w w w w w Ln �n w Ln F— 0 r-I CD r-I M r-I o0 m r-I M N f� Ln 0 m 00 CD f� M N N lD m W N CD Ln e--I W N f� Rc* m I- N In m Ln W N Ln N I. In N r-I O Ln N m m N R�r N M M r• o 0 o O 0 cc O 0 O 0 0 O 0 0 O 0 0 O 0 0 CD 0 00 O 0 O 0 0 O 0 0 in -- o o 0 r 0 �• 0 I• 0 0 ,• 0 r 0 r• 0 0 i• 0 i• m r-I N m m w N w m r"I r-I v U 0 z a E U N 1- o aJ Ln y V1 E — f9 ;3 N u u m to m �00 a) a cu m C 0 aj to L C U 41 C 2 0 0 ��o N C � L In Q Cu C o C m C H 'n 3 $ a, 0 *' N � L � C C 0 C 0 a..+ E -0 N L �4 >�Ln Ln a� o � Q �o 0 � N � E Q C V � � C d. •� N 0 .� 4-0 4' L u E ai v aj a v a� a aj o41 0 E>ai U Ln L 1 m 00000"% N N 00 Ln u L � cn 01 V W W oQ o0 4, N N N N N N N N N N N 'i o co 0 0 0 0 0 0 0 0 0 a t 00 0 0 0 0 0 0 0 0 0 .t m m m m M m m d- Itt r-I A A A A 0 0 0 0 0 0 00 0 0 0 o0 M 00 M 00 M M 00 00 00 00 a 0 N LD oo oo M M nn Ln M N 00 H Ln d- 't* M M cV 0 1� Uo W Ln y- Ln Ln Ln Ln Ln Ln Ln qt lqr q r-4 F, r- r� rn r• r rn r� r` H 00 r-I w M M m Ln oo 'd' T-1 M --• N N r-1 r-i 0 M W MI:T Ln N yam.. d' to w O N M to m 4 Ln w r-i r-I 0cr) w n w 0 'Ct N N N N N r1 r-I r-I r1 r-I r-I H o 0 0 0 0 0 0 0 0 0 0 �• 0 0 0 0 0 0 O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o O C) Ao Ao Ao A0 /0� /0 /0% tkb fV M Ln to r` 00 Q) o r--I (V r-I r-I T-q rH r-I N ,m r—f N N 6 U ++ O z a, u LA 0 14- a 41 cu C m ro :3 CU �CU U bm L �O c O co VI C 0 L C U L aJ 15 OJ di �Cj O O L. o Q. 0 0 4° c ro I� _ a, "a -O c o co ruE `J ro u, � L 3 o = *' y � � � L � c au to 0 o a E�� wW c ra tm mc� O 0 CL �� v LA E L E u .� = C O 4- O a c., o a� c •E m 4- O 2 V C O L E tO L C }LI 3 O -:5 O L O a1 E :E0 a SECTION 13 — POST -FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through PTS until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.)