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Home My WebLink About2019-02-11_319-064STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEB 11 2019 a � .ern . . 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑J Repair Well ❑ le eRa o stfutdown ❑ 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: ConocoPhillips Exploratory ❑ Development ❑✓ SUatigraphic ❑ Service ❑ 218-093 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20773-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MT6-06 Will planned perforations require a spacing exception? Yes ❑ No ❑r 9. Property Designation (Lease Number): 10. Field/Pool(s): AA081818, AA092346, AA081798, AA092342 Greater Mooses Tooth Unit Lookout Pool 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): 17482 8111 Casing Length Size MD TVD Burst Collapse Structural Conductor 152 20 115 115 Surface 2155 13.375 2118 2003 Intermediate 10353 9.625 10316 7245 Production 11870 7 11833 7983 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4 112" L80 11675 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): ZXP linertop, no SSSV 11,665'MD no SSSV 12. Attachments: Proposal Summary Lj Wellbore schematic r 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/2312019 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. Contact Adam Klem, 907-263-4529 Email adam.kfem ConocoPhilll s.com Printed Name Ada Clem Title Completions Engineer Signature Phone 907-263-4529 Date 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: Form 10-403 Revised 1112015 Approved appilcadarovR MTN Ac date of approval. Submit Form and Attachments in Duplicate MT6-06, 131 Location: Frost Completian Schematic t i9 pptlf�t0 psi ,j 11117 11 r Coo! 1 YCiskir T;t hq' ice' Ccfm �( . 1 all test. ce'wtded to mt. i � 13Ji6`°.�►�T7CiQBTClt't Caung 3T 214SJTD : 20M T' D M::'a►t d it affraw 4-17. l pp LAO Tewds lNue to itve UD r 20 Vol L40 TSB f8w Tie Back 65r4bdoL447"Ito vmmf 1! L !9 4 W 40 ppf T11.8tr HS TXP (to TO) 103WA.10'7,2 6TI.D I 4 .p i . 'e4 i'r` C at Est :� IiFG 8xt:e Pa&Ar & 5W , EIaa=.a.;.ipf 0G. � Plannec to Una Tor Tap AWWC a u 1190 M 0.'7 3a r, D T' 26 pp( L=W T5 Blue Lbwr to 11 833' AC : 7 98:3 T<T1 @ 73 dog 1:4--a"Lw4mg PVpWk3813 A-LP2,Iatit 2j x 1-GLM 4.tt8i'tx'S9 4-'. x 1-GEM 8,M1 FM d-:aAiGLUj 11,4WIM F'DovmIdeGApe2 ,LSWM $: 3-`5 Ltlitia Nq>pte+3.76" YAf; 7; Lt3�er Tctp Pa3'dte�r # Harr � 11,6$^ A�3 A TwEacp. Nee e 8;, 4', TAP Bijof env. Npew WMr,:a 12M L-W UP Mi Pere Pqs 16826 I.tG a a a3 a�ti�� VWe, TLat at 17,482.' MD / %1117 TVD 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 -Ralf 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 E. Lyons Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the MT6-06 Well ) under the Provisions } of 20 AAC 25.280 } STATE OF ALASKA } H THIRD JUDICIAL DISTRICT ) herein. Jason E. Lyons, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Jason E. Lyons. I am over 19 years old and have personal knowledge of the matters set forth 2. 1 am Staff 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 February 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 February, 9. 201 Jason E. Lyons STATE OF ALASKA ) } H THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 5ch day of February, 2019 by Jason E. Lyons. Aoary Publicof Alaska My Commission Expires: M ANAu Con hillips Alaska February 5, 2019 To: Operator and Owners (shown on Exhibit 2) Jason Lyons Staff Landman Alaska Land & Bp ConocoPhillips Company 700 G Street, ATO-1478 Anchorage, AK 99501 Office: 907-265-6002 Fax:918-662-3472 jason.fyons@cop.com VIA CERTIFIED MAIL Re: Notice of Operations pursuant to 20 AAC 25.283 (1) for MT6-06 Well AA-92346 (ASRC), AA-92342 (ASRC) Greater Mooses Tooth Unit, Alaska CPAI Contract No. 2.04278 Dear Operator and Owners: ConocoPhi Hips Alaska, Inc. ("CPAI") as Operator and 100% working interest owner of the of the Greater Mooses Tooth Unit ("GMTU"), 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 MT6-06 well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about February 8, 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 Ieaases AA-92346 (ASRC) and AA-92342 (ASRC) as depicted on Exhibit I and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 268' 3189' 10N R3E 6 Umlat Top Open Interval 2040' 2576' T11N 112E 36 Umiat Bottomhole 1824` 1 315' T10N R2E 1 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. Si erely, son ons Staff Lan an Attachments: Exhibits 1 & 2 AA0923" 11 AA092342 Well Pad Well Trajectory Frac Interval LD Half We Frac Point Radius Half Mile Trajectory Radius Wells within Trajectory Radius Lookout PA CPAI Leases Exhibit I ? N A A 4 0.2 0.4 0.6 MU" AAG81?W N. ,,/ Qno6tiihiffips Aiasm MT6-06 Lease Plat IM412019 Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator & Owner: Conocophiilips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Misty Alexa, NS Development Manager Landowners: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage, Alaska 99503-5963 Attention: Teresa Imm, Executive VP, Regional and Resource Development United States Department of Interior, BLM 222 West 7th Avenue, #13 Anchorage, AK 99513 Attention: Wayne Svejnoha, Branch Chief Energy and Minerals Surface Owner: Kuukpik Corporation P.O. Box 89187 Nuiqsut, AK 99789-0197 Attention: Joe Nukapigak, President United States Department of Interior, BLM 222 West 7th Avenue, #13 Anchorage, AK 99513 Attention: Wayne Svejnoha, Branch Chief Energy and Minerals Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within .5 miles AA082342 \ I 1� Well Pact WellTra*6ory 3 Fraoinlervei Half Mkle Fran Pole Radius Hdf Ale Teary Pm. Wells shin T*dwy Ra&A Lookout PA 1 1 i 0 02 04 0.6 Miles i AA081798 MIX MTS-06 i Lease Plat Table 1: Wells within .5 miles API Well Name WeNType Status 501032077000 MT6-03 PROD ACTIVE 501032077070 MT6-03PH SVC PROP 501032077500 MT6-04 INJ ACTIVE 501032077570 MT6-04PB1 EXPEND PA 501032077100 MT6-05 PROD ACTIVE 501032077160 MT6-05L1 PROD ACTIVE 501032077170 MT6-05PB1 EXPEND PA 501032077171 MT6-05PB2 EXPEND PA 501032077370 MT6-06PB1 EXPEND PA 501032077371 MT6-06PB2 EXPEND PA 501032077200 MT6-08 INJ ACTIVE 501032077270 MT6-08PB1 EXPEND PA 501032077900 MT6-09 INJ ACTIVE 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 6 of the Area Injection Order AIO 40- Greater Moose's Tooth Field, Lookout Oil Pool, which states: "There are no freshwater aquifers in the Affected Area of the LOP 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: 13 & 3/8" casing cement pump report on 9/13/18 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg LiteCRETE cement lead, followed by 15.8 ppg class G cement displaced with 10ppg mud. Full returns were seen throughout the job. The plug bumped at 900 psi and the floats were checked and they held. 9 & 5/8" casing cement pump report on 9/22/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 12.2ppg cement lead, followed by 15.8 ppg class G cement, displaced with 10.4ppg mud. Full returns were seen throughout the job. The plug bumped at 1100 psi and the floats were checked and they held. The 7° casing cement report on 9/30/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. 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 9/15/2018 the 13-3/8" casing was pressure tested to 3,000 psi for 30 mins. On 9/24/2018 the 9-5/8" casing was pressure tested to 3,500 psi for 30 mins. On 10/312018 the 7 casing was pressure tested to 3,500 psi for 30 mins. On 10/25/2018 the 4.5" tubing was pressure tested to 3,500 psi for 30 mins. Prior to Frac, the 4.5" tubing will be pressured tested to 4,400 psi and the 7° IA will be pressure tested to 3,850 psi. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 6,000 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 7" Annulus pressure test 3,850 4 1/2" Tubing pressure Test 4,370 Nitrogen PRV 6,935 Highest pump trip 6,735 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 & 3/8" 68 L-80 5,024 psi 2,260 psi 9 & 518" 40 L-80 5,750 psi 3,090 psi 7" 26 L-80 7,240 psi 5,414 psi 4.5" 12.6 L-80 8,430 psi 7,504 psi I able 2: Weilbore pressure ratings g ff" r rN f T Tvk VW-LIF raw �N a bra= f%u.,qP Nra; pub Stimulation Surface Rig -Up • 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 3,600 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. Pup OffTw* Stimulation Tree Saver piss PosrnoN * W ;90.N COKIm.01V4 !,'y&. `.9V::bt • 3 :AL'rC 851` r • The universaI tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75" down 3 % tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm Alpine Wellhead System 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 C interval is approximately 50' TVD thick at the heel of the lateral and thinning to approximately 25' at the toe. The Alpine C sandstone is very fine grained quartz rich sandstone with varying amounts of glauconite and a fining upward log profile. Top Alpine Cis estimated to beat 11,879' MD/ 7,905 TVDSS. The estimated fracture gradient for the Alpine C sandstone is 12.5 ppg. The overlying confining zone consists of greater than 800' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15-16 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ was encountered at 10,288' MD/ 7,135' 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 interval ranges from 7,950' TVDSS ( 12,255' MD in the MT6-06PB1) at the heel to 17,402' MD/ 8,016 TVDSS at the toe of the well. 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. Casing & Cement assessments for all wells that transect the confining zone: MT6-03: The 7" casing cement pump report on 4/16/2018 shows that the job was pumped with 84bbls losses with 47bbis lost after cement was in openhole leaving 37 bbls cement behind liner. The cement job was pumped with 15.8 ppg Class G cement, displaced with 10.8 LSND. The string was then unstung from the cement retainer. MT6-03PH: MT6-03PH was plugged and abandoned per state regulations on 416/2018. MT6-04: 7" casing cement pump report on 11/6/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Class G cement, and displaced with 11.2 ppg LSND. Full returns were seen throughout the job. The plug bumped @ 1100 psi and the floats were checked and they held. MT6-04PB1: This lateral was openhole sidetracked and therefore falls under the casing and cement assessment for MT6-04. MT6-05: 7" casing cement pump report on 5/29/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 12.2 ppg Class G for the lead and 15.8 ppg Class G cement for the tail, and displaced with 10.7 ppg LSND. Full returns were seen throughout the job. The string was then unstung from the cement retainer. MT6-051_1: This is the upper lateral on MT6-05 and therefor falls under the casing and cement assessment for MT6-05. MT6-05PB1: MT6-05PB1 was plugged and abandoned per state regulations on 6/12/2018. MT6-06PB1: MT6-05PB1 was plugged and abandoned per state regulations on 10/7/201 B. MT6-06P82: This lateral was openhole sidetracked and therefore falls under the casing and cement assessment for MT6-06. MT6-08: 7" casing cement pump report on 8/16/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Class G cement, and displaced with 10.8 ppg LSND. Full returns were seen throughout the job. The string was then unstung from the cement retainer. MT6-08PB1: MT6-08PB1 was plugged and abandoned per state regulations on 8/7/2018. MT6-09: The 7" casing cement pump report on 12/7/2018 shows that the job was pumped with 32bbis lost after cement was in openhole leaving 27.5 bbis cement behind liner. The cement job was pumped with 15.8 ppg Class G cement, displaced with 10.8 LSND. The string was then unstung from the cement retainer. La H 2 0 0 0 0 0 $ o 0 m« — a a n a ~ a a a papp C u 6 N m w V c a+ m m u N C „ m w W pup .N-i C q c w a 47 W m a c rNi iJ cR nab u a n"c E H w E° n E. ' E E a m A 4 N n m N N u .N-1 C7 N N Y .Ni '_ C7 N N t�i '+ t�i [7 6 a a s N 10 a m E a ti N � C a u u u c a a a °�•vi Nu �ti y a caa c a of in 4 a3 .2 .c a es$ a °vat E df � m m ti E m E $ ^�L E .oi u ,o-i O Cc M 00 h M1 m ®1 O O O r U o U 0 0 0 H r W e ro •0 t � x t 0 s x t m s m � � m s m 9 m m bm m m m m d o ul M c m O pNp� N N pp O aa O } O h 4° h h IM1 n n ri h q�q 4° .i M1 h �N-I h a� O H d E— a 'S IL 0 cci pe 4 N � � ��mrr m ~ nippp a Q ppmp ppmp ^ ^ N N pmp n H n a T nopp Obi � W Obi ti .may O •�-1 h .�i h N rl A ei p0 N N m \ z z qC R u ^ Z h h ^ 2 2 2 Z h 2 ^ N x Z 1I1 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 2 fault or fracture systems transect the Alpine C formation or enter the confining zone within one half mile radius of the wellbore trajectory for MT6-06. The two faults system were interpreted from seismic data prior to drilling and 1 was confirmed with log data while drilling. The fault was a single fault plane with 5' of throw at 16,495' MD and the second fault is not present in the MT6-06 wellbore. 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 C formation, along with the well path, all the fractures will be longitudinal, running parallel to 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 Depth Depth Vertical Loss Name MD (ft) TVDSS (ft) Displacement (bbls/hr) MT6-06 16,495 7990 5' None SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) MT6-06 was completed in 2018 as a producer with 4.5" tubing and a 4.5" liner with pert pups. Due to low production rates, a diversion frac will be performed. After the 1st stage we will drop and array of dissolvable pods to attempt to plug of the pert holes to divert the frac to new formation. Proposed Procedure: Halliburton Pumping Services: 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 15 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. 6,500 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU Stinger Tree Saver Equipment and HES Frac Equipment. 6. PT Surface lines to 9,000 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Pump the 310 bbl breakdown stage (35# Hybor G) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 30 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 9. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 10. Pump the Frac job by following attached HES schedule @ 30bpm with a maximum expected treating pressure of 7,500 psi. • 4 stages, 400,000 lbs of 20140 Wanli proppant 11. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 12. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). a,E �m " = S 13css If d d W _ dd6 n'y.d56 d 1--l-iq j :11 6 6 dd d o ,d Id o odd d F, 888 ry�ry 888BQ88$88�$$80�8 ti��«ry N�rn 11 N��$88ory8888S s o o d a o o d d d a o �d d d d d 6 o d d d d 66 o 0 o d d d d �� 888 88SS88$8858$$$8SS88$88$eSS$8 u 6 d a d d Is d 6 e d o d o d a & 3 cs d Is i.1 daoaeo° �ddd d oodda AA u, d d St d �c u' ' �'d '� o oadyv�i, 9j�u, d oo� r 8S8 �88888888$588888888BB8$i�ii88 r m 9 m 8 Y m y m o b b a rg wss8$ao99bo8$� �3 08 0 00 o tfbo o tl tl o oodofSo v' e # C$' I f = nl j � I E $ r� Si Am 11 mAStmm 17AAAM MA1g1RI+++-IR RAm ag$ses 4 sass w v ease sass e l:i2 <_ << }'_ 9 9 3 g 3 3 9 9 9 g � LL L A a a a �� a a� 1a S d 3$ a at a� n 6 1. S S� 5 f 8 r , E sees` Q� e' a 8 T e= a �o enu3$:i is�Eis5�e�w3wa:�iidaSa�s:;�ai"^a:9'S C i IIIIIIIII m = LL $ d. L'a¢LA►E'tZeeL-ee'6aeLL� a' � u � 1 R�plul � LL � � m e w� m sa Sa � Cm �m 31 n4 O 2 T� i2 2 � Z Z � Z' B��Yt tl �ggggqdqqq �� S xCx EJ 8 � @ E SO 11 ZlIX 9.1292 11 1- s . �= os g S m n s a a oa �V W 4 z3 1 3 M� I $ Al 3 19�I ll dF � wax z' e ms�BS a��' o a� `21 Um- u oar o'b'amon.ma = z ast � � � a� � g u n q q H 0/ m m m m 5:3 7 d d d d $§§ J� §_� k m � . o di 0 x aj c Ln « w $ � w / / :5 § \ o 2 j k E 2 m 0 c g S o 2 C CL in vi Ln sn m m E o & & � £ u � 0 0 in j S 0% o / CD m m m c n n n E k C w Ln \�' m C § 217LD � o L o & CL 0 qLn q q k 2 " CL CL � � cn q r-Aq Ln E L o Ln u � � to CL .- aj # 2 E 0 0 E 7 0 0 0 0 9£ o C) o ■ 2 � a o o § / � £ k cu @ £ a 0 d ■ 20' E 2 § � w q m E u ) w m �ci 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 alpine disposal facilities until they are clean enough for production.)