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Home My WebLink About218-159P rn a l$ Loepp, Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophilIips.com> Sent: Friday, January 18, 2019 4:22 PM To: Loepp, Victoria T (DOA) Cc: Hobbs, Greg S Subject: MT6-02PH PTD Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please withdraw the MT6-02PH PTD (218-159). Thanks, Andrew Loepp, Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.corn Sent: Friday, January 18, 2019 4:22 PM To: Loepp, Victoria T (DOA) Cc: Hobbs, Greg S Subject: MT6-02PH PTD Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please withdraw the MT6-02PH PTD (218-159). Thanks, Andrew n7-0 a 18 -/s9 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, January 3, 2019 8:54 PM To: Beat, Andrew T Subject: Re: [EXTERNAL]Re: MT6-02 Operations Update (218-159) Andrew, Approval is granted to drill out the shoe track and obtain an FIT prior to running the CBL if required. A CBL will then be obtained. Thanx, Victoria Sent from my iPhone On Jan 3, 2019, at 4:06 PM, Beat, Andrew T <Andrew.T.Beat@conocophillips.com> wrote: Victoria, In case the incoming replacement part does not fix the E-Line unit, we would like to get your approval to drill out the 9-5/8" shoe track and get an FIT before obtaining a CBL. We will not drill additional footage beyond what is needed for an FIT and will still get the CBL. It will just be a change in order of operations. If the unit gets fixed as hoped we will perform the CBL first. Thanks, Andrew (303) 378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, January 03, 2019 11:53 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]Re: MT6-02 Operations Update (218-159) Thank you; good game plan. Sent from my iPhone On Jan 3, 2019, at 11:40 AM, Beat, Andrew T <Andrew.T.Beat@conocophillips.com> wrote: Victoria, We lost returns while pumping our Intermediate 1 cement job on MT6-02 (Doyon 19). We were battling unstable shales and had to set about 300' off bottom. We are currently rigging up E-Line to run a CBL so we can determine our top of cement. We expect the data between 4-5 PM this evening, maybe earlier if we are lucky. I will send you another email with that information and our requested plan forward for your approval. Let me know if you have any questions in the meantime. Thank you, Andrew Beat Senior Drilling Engineer ConocoPhillips Alaska (303) 378-8881 cell (907) 265-6341 office Loepp, Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Thursday, January 3, 2019 4:06 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]Re: MT6-02 Operations Update (218-159) Follow Up Flag: Follow up Flag Status: Flagged Victoria, In case the incoming replacement part does not fix the E-Line unit, we would like to get your approval to drill out the 9- 5/8" shoe track and get an FIT before obtaining a CBL. We will not drill additional footage beyond what is needed for an FIT and will still get the CBL. It will just be a change in order of operations. If the unit gets fixed as hoped we will perform the CBL first. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, January 03, 2019 11:53 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]Re: MT6-02 Operations Update (218-159) Thank you; good game plan. Sent from my iPhone On Jan 3, 2019, at 11:40 AM, Beat, Andrew T <Andrew.T.Beat@conocophillips.com> wrote: Victoria, We lost returns while pumping our Intermediate 1 cement job on MT6-02 (Doyon 19). We were battling unstable shales and had to set about 300' off bottom. We are currently rigging up E-Line to run a CBL so we can determine our top of cement. We expect the data between 4-5 PM this evening, maybe earlier if we are lucky. I will send you another email with that information and our requested plan forward for your approval. Let me know if you have any questions in the meantime. Thank you, Andrew Beat Senior Drilling Engineer ConocoPhillips Alaska (303) 378-8881 cell (907) 265-6341 office Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 8:49 AM To: Beat, Andrew T (And rew.T.Beat@conocophillips.com) Subject: RE: MT6-02 CBL and Plan Forward Thanx for the cement job information. It is not necessary to meet at this time. More interested in the FIT and plans forward. From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 8:45 AM To: Beat, Andrew T (Andrew.T.Beat@conocophillips.com) <Andrew.T.Beat@conocophillips.com> Subject: RE: MT6-02 CBL and Plan Forward Another question: Is there 300' of hole below the shoe? What if the FIT doesn't pass? Could you place cement in the hole versus a squeeze? Let me know your plans. From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 8:23 AM To: Beat, Andrew T (Andrew.T.Beat@conocophiIlips.com) <Andrew.T.Beat@conocophillips.com> Subject: FW: M76-02 CBL and Plan Forward Andrew, Please forward the information below, however, you may move forward with the FIT which must pass to drill ahead. We will likely grant a waiver from the 250' TVD cement required. Will a CBL be run on the 7" right after the cement job? Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 7:54 AM To:'Beat, Andrew T' <Andrew.T.Beat @conocophiIlips.com> Subject: RE: M76-02 CBL and Plan Forward Andrew, Please forward the cement job summary, log and cement job plots. Where is the free pipe indication on the log? Please have your log analyst interpret quality of cement, feet of cement and show the —170' TVD of good cement. Are you in town? Can someone come over and review? We are available anytime. Thanx, Victoria From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 4, 2019 7:33 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Marushack, Andy J <Andy.J.Marushack@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Alexa, Kurt J <Kurt.J.Alexa@conocophillips.com>; Alvord, Chip <Chip.Alvord@conocophillips.com> Subject: MT6-02 CBL and Plan Forward Importance: High Victoria, Last night we logged the top of cement at 8,504' MD (6,899' TVD). Our casing shoe is at 8,742' MD (7,070' TVD) so we have 238' MD (171' TVD) of cement coverage on the backside of our Intermediate 1 casing. We would like to request a waiver from the 500' MD/250' TVD casing cement requirement (20 AAC 25.030 (d) (5)) to allow us to continue with planned operations without any remediation. Our Intermediate 2 casing will cover from the Alpine C reservoir to surface providing additional isolation to the zones exposed in Intermediate 1 and the cement job will be logged. We believe that with this additional barrier along with the 238' MD of cement placed behind the Intl casing that all requirements in 20 AAC 25.030 (a) are met. Please let me know if you have any questions or would like to discuss further. Thank you, Andrew Beat Senior Drilling Engineer ConocoPhillips Alaska (303) 378-8881 cell (907) 265-6341 office Schlumbepgep Cementing Job _sport CemCATv1.7 Well MT6-02 Client ConocoPhillips Field Alpine SIR No. Engineer Lance Kalivas Job Type 9 5/8" Intermediate Country United States Job Date 01-01-2019 Time - - - Pressure Rate Density WHP Messages 16:08:25 16:38:00 17:08:00 PJSM Done Blow Air Down Hard Line Fluid Pack Hard line Low Pr 17:38:00 Trips tripped High Pr High PT Good MudPush Scaled 11.5 Reset Total, Vol = 1.23 bbl Start MudPush Down Hole 18:08:00 Shut Down Drop Bottom Plug Start Batching Lead Cement Reset Total, Vol = 60.03 bbl Cement Scaled 12.5 ppg 18:38;00 End Lead Slurry Start Batching Tail Reset Total, Vol = 98.09 bbl Tail Scaled 15.6 Shut Down Drop 2 top plugs 19:08:00 Reset Total, Vol = 48.82 bbl Fresh water behind Swap to rig to displace Reset Total, Vol = 20.09 bbl Blow air down hard line 19:38:00 20:08:00 20:38:00 21:08:00 21:38:00 22:08:00 22:38:00 23:08:00 23:30:54 hh:mm:ss OAO IWO 20W 3W0 4000 SOW O.W 2A 4.0 6.0 84 10.0 5.0 IOA 15.0 20A 25.0 0.00 1000 20W 3000 4" WW PSI - _ _-- B/M LB/G PSI 01/02/2019 00:59:55 Schlumbep9ep Cementing Service Report Customer ConocoPhillips Job Number Well MT6-02 Location (legal) MT6 Schlumberger Location PRUDHOE OTHER ]ob Start Jan/01/2019 Field Alpine Formation Name/Type Deviation deg Bit Size 12.3 in Well MD 9016.0 ft Well TVD 7218.0 ft County State/Province Alaska BHP psi BHST 163 degF BHCi 100 degF Pore Press. Gradient lb/gal Well Master API/Uy1li Rig Name Doyon 19 Drilled For Service Via Land Casing/Liner Depth, R Size, in Weight, lb/ft Grade Thread offshore Zone Well Class New Well Type Development 8506.0 9.6 40.0 N80 BUTT 0.0 0.0 0.0 Drilling Fluid Type Max. Density lb/gal Plastic Viscosity CP Tubing/Drill Pipe T/D Depth, ft Size, in Weight, lb/ft Grade Thread Service Line Cementing Job Type 9 5/8" Intermediate Max. Allowed Tub. Press psi Max. Allowed Ann. Press psi WH Connection 2" 1502 Perforations/Open Hole Top, It Bottom, ft shot/ft No. of Shots Total Interval Service Instructions ft ft ft ft ft Diameter in ft ft Treat Down Casing Displacement 658.4 bbl Packer Type Packer Depth ft Tubing Vol. bbl Casing Vol. 664.6 bbl Annular Vol. bbl Openhole Vol. bbl Casing/Tubing Secured 1 Hole Vol. Circulated prior to Cement Casing Tools Squeeze lob Lift Pressure psi Shoe Type Float Squeeze Type Pipe Rotated Pipe Reciprocated Shoe Depth 8506.0 ft Tool Type No. Centralizers Top Plugs 2 Bottom Plugs I Stage Tool Type Tool Depth ft Cement Head Type Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Jan/01/2019 Arrived on Location Jan/01/2019 Leave Location Jan/01/2019 Collar Type Float Tail Pipe Depth ft Collar Depth 8422.0 ft Sqz. Total Vol. bbl Date Time 24-hr dock Treating Pressure PSI Flow Rate B/M Density LB/G Volume 'CMT_STG_VOL BBL RBL WHP PSI Message 01/01/2019 16:08:25 67 0.0 6.80 0.0 0.0 1 Started Acquisition 01/01/2019 16:10:55 65 0.0 6.80 0.0 0.0 4 01/01/2019 16:13:25 67 0.0 6.80 0.0 1 0.0 3 01/01/2019 16:15:55 68 0.0 6.80 0.0 0.0 1 01/01/2019 16:18:25 69 0.0 6.79 0.0 0.0 120 01/01/2019 16:20:55 66 0.0 6.79 0.0 0.0 123 01/01/2019 16:23:25 65 0.0 6.78 0.0 0.0 1 127 01/01/2019 16:25:55 65 0.0 6.78 0.0 0.0 110 01/01/2019 16:28:25 67 0.0 6.78 0.0 0.0 109 01/01/2019 16:30:55 68 0.0 6.78 0.0 0.0 110 01/01/2019 16:33:25 64 0.0 6.78 0.0 0.0 109 01/01/2019 16:35:55 65 0.0 6.77 0.0 0.0 118 01/01/2019 16:38:25 67 0.0 6.77 0.0 0.0 116 01/01/2019 16:40:55 71 0.0 6.77 0.0 0.0 -178 01/01/2019 16:43:25 67 0.0 6.77 0.0 0.0 241 01/01/2019 16:45:55 68 0.0 6.77 0.0 0.0 201 01/01/2019 16:48:25 68 0.0 6.77 0.0 0.0 224 01/01/2019 16:50:55 65 0.0 6.76 0.0 0.0 245 01/01/2019 16:53:25 66 0.0 6.76 0.0 0.0 299 01/01/2019 16:55:55 68 0.0 6.76 0.0 0.0 344 01/01/2019 16:58:25 1 69 1 0.0 6.76 0.0 0.0 1 383 Page 1 of 5 Well MT6-02 Field Alpine Job Start 3an/01/2019 Customer ConocoPhillips lob Number Date Time 24-hr clock Treating Pressure PSI Flow Rate B/M Density LB/G Volume BBL MT_STG VOL BBL WHP PSI Message 01/01/2019 17:03:25 68 0.0 6.76 0.0 0.0 379 01/01/2019 17:05:55 69 0.0 6.75 0.0 0.0 375 O1/01/2019 17:08:25 68 0.0 6.76 0.0 0.0 381 O1/01/2019 17:10:55 68 0.0 6.75 0.0 0.0 388 O1/01/2019 17:13:25 67 0.0 6.75 0.0 0.0 391 01/01/2019 17:15:37 68 0.0 6.75 0.0 0.0 384 PJSM Done O1/O1/2019 17:15:55 68 0.0 6.75 0.0 0.0 385 01/01/2019 17:16:52 68 0.0 6.74 0.0 0.0 386 Blow Air Down Hard Line 01/01/2019 17:18:25 68 0.0 6.74 0.0 0.0 396 O1/01/2019 17:20:23 87 0.0 6.75 0.0 0.0 172 Fluid Pads Hard line 01/O1/2019 17:20:55 85 0.9 6.75 0.1 0.1 170 O1/01/2019 17:22:40 174 0.0 6.74 1.2 1.2 241 Low PT 01/01/2019 17:23:08 1400 0.0 6.74 1.2 1.2 1511 Trips tripped O1/01/2019 17:23:25 1388 0.0 6.74 1.2 1.2 1471 High PT 01/01/2019 17:25:33 3996 0.0 6.74 1.2 1.2 4057 High PT Good 01/01/2019 17:25:55 159 0.0 6.74 1.2 1.2 218 O1/01/2019 17:28:25 67 0.0 6.74 1.2 1.2 61 O1/01/2019 17:30:55 67 0.0 6.74 1.2 1.2 62 01/01/2019 17:33:25 130 0.0 6.74 1.2 1.2 57 01/01/2019 17:35:55 143 0.0 6.75 1.2 1.2 72 O1/01/2019 17:38:25 134 0.0 11.37 1.2 1.2 62 01/01/2019 17:39:02 135 0.0 11.76 1.2 1.2 66 Mud Push Scaled 11.5 01/01/2019 17:39:18 134 0.0 11.67 1.2 1.2 71 Reset Total, Vol = 1.23 bbl 01/01/2019 17:40:09 155 0.0 11.43 1.2 0.0 93 Start MudPush Down Hole 01/01/2019 17:40:55 417 2.5 11.76 3.3 2.1 248 O1/01/2019 17:43:25 499 3.2 11.38 9.9 j 8.7 278 01/01/2019 17:45:55 481 3.2 11.38 17.9 16.7 276 O1/O1/2019 17:48:25 612 4.0 11.44 26.2 25.0 321 O1/01/2019 17:50:55 577 4.1 11.47 36.3 35.1 278 01/01/2019 17:53:25 594 4.1 11.34 46.4 45.2 298 01/01/2019 17:55:55 429 3.0 11.41 55.8 54.6 249 O1101/2019 17:58:09 157 0.0 11.86 61.3 60.0 103 Shut Down Drop Bottom Hug O1/01/2019 17:58:25 158 0.0 11.86 61.3 60.0 104 O1/O1/2019 18:00:55 158 0.0 8.83 61.3 60.0 64 01/O1/2019 18:03:21 154 0.0 8.67 61.3 60.0 54 Start Batching Lead Cement O1/O1/2019 18:03:25 158 0.0 9.32 61.3 60.0 61 01/01/2019 18:05:55 160 0.0 12.55 61.3 60.0 80 O1/01/2019 18:06:09 163 0.0 12.54 61.3 60.0 87 Reset Total, Vol = 60.03 bbl 01/01/2019 18:06:29 163 0.0 12.54 61.3 0.0 87 Cement Scaled 12.5 ppg 01/01/2019 18:08:25 503 3.1 11.99 66.8 5.5 216 01/01/2019 18:10:55 525 3.2 12.20 75.2 13.9 210 01/01/2019 18:13:25 465 2.9 12.31 83.1 21.8 188 01/01/2019 18:15:55 459 2.9 12.21 90.4 29.1 195 O1/01/2019 18:18:25 557 3.6 12.22 99.6 38.4 186 01/01/2019 18:20:55 545 3.5 12.42 108.4 47.1 210 01/01/2019 18:23:25 526 3.5 12.21 117.1 55.8 182 01/01/2019 18:25:55 508 3.4 12.22 125.7 64.5 195 O1/01/2019 18:28:25 502 3.4 12.08 134.4 73.2 147 O1/O1/2019 18:30:55 459 3.2 12.22 143.1 81.8 176 01/01/2019 18:33:25 467 j 2.7 12.27 150.2 88.9 221 01/01/2019 18:35:55 428 2.4 11.94 156.4 95.1 224 O1/O1/2019 18:37:52 150 0.0 12.02 159.3 98.1 64 End Lead Slurry 01/O1/2019 18:38:25 145 0.0 12.02 159.3 98.1 81 01/01/2019 18:40:55 128 0.0 8.47 159.3 98.1 66 Page 2 of 5 Well MT6-02 Fleld Alpine lob Start Jan/01/2019 Customer ConocoPhillips ]ob Number Date Tfine 24-hr clock Treating Pressure PSI Flow Rate S/M Density LB/G Volume BBL MT STG_VOL BBL WHP PSI Message O1/01/2019 18:42:56 129 0.0 7.22 159.3 98.1 58 Reset Total, Vol = 98.09 bbl 01/01/2019 18:43:25 127 0.0 8.38 159.3 0.0 59 01/01/2019 18:45:55 120 0.0 15.71 159.3 0.0 58 O1/O1/2019 18:47:08 199 0.0 15.58 159.3 0.0 56 Tail Scaled 15.6 01/O1/2019 18:48:25 828 3.6 15.46 163.2 3.8 368 O1/O1/2019 18:50:55 887 3.7 15.78 172.2 12.9 323 O1/01/2019 18:53:25 950 4.0 15.80 181.9 22.6 346 01/01/2019 18:55:55 1000 4.0 15.77 191.9 32.5 342 01/O1/2019 18:58:25 924 4.0 15.49 201.8 42.4 330 01/O1/2019 19:00:47 132 0.0 15.38 208.2 48.8 7 Shut Down Drop 2 top plugs 01/01/2019 19:00:55 112 0.0 15.38 208.2 48.8 -7 01/01/2019 19:02:50 104 0.0 10.01 208.2 48.8 -29 Reset Total, Vol = 48.82 bbl 01/01/2019 19:03:25 104 0.0 9.66 208.2 0.0 0 01/O1/2019 19:05:55 99 0.0 8.98 208.2 0.0 3 O1/01/2019 19:07:46 100 0.0 8.80 208.2 0.0 25 Fresh water behind O1/01/2019 19:08:25 553 4.0 8.77 210.0 1.8 246 O1/O1/2019 19:10:55 557 4.0 8.69 219.9 11.8 216 01/01/2019 19:13:13 92 0.0 8.64 228.3 20.1 -1 Swap to rig to displace O1/O1/2019 19:13:25 88 0.0 8.63 228.3 20.1 14 O1/01/2019 19:13:28 87 0.0 8.63 228.3 20.1 12 Reset Total, Vol = 20.09 bbl 01/01/2019 19:14:48 145 0.0 8.60 228.3 0.0 240 Blow air down hard line 01/01/2019 19:15:55 65 0.0 8.58 228.3 0.0 242 O1/01/2019 19:18:25 66 0.0 9.35 228.3 0.0 246 01/01/2019 19:20:55 67 0.0 9.91 228.3 0.0 233 01/O1/2019 19:23:25 70 0.0 8.97 228.3 0.0 199 O1/01/2019 19:25:55 128 0.0 7.93 231.7 3.4 201 01/01/2019 19:28:25 106 0.0 7.49 231.7 3.4 179 01/01/2019 19:30:55 65 0.0 8.43 231.7 3.4 187 O1/01/2019 19:33:25 67 0.0 8.42 231.7 3.4 170 O1/01/2019 19:35:55 68 0.0 8.43 231.7 3.4 182 01/O1/2019 19:38:25 65 0.0 8.41 231.7 3.4 172 O1/01/2019 19:40:55 67 0.0 8.38 231.7 3.4 170 O1/01/2019 19:43:25 65 0.0 7.34 231.7 3.4 173 O1/O1/2019 19:45:55 65 0.0 0.01 231.7 3.4 167 01/O1/2019 19:48:25 66 0.0 0.00 231.7 3.4 174 O1/01/2019 19:50:55 67 0.0 0.01 231.7 3.4 161 O1/01/2019 19:53:25 85 0.0 5.68 231.7 3.4 180 01/01/2019 19:55:55 64 0.0 5.32 231.7 3.4 167 O1/01/2019 19:58:25 67 0.0 0.00 231.7 3.4 175 O1/01/2019 20:00:55 65 0.0 0.00 231.7 3.4 208 O1/01/2019 20:03:25 66 0.0 0.00 231.7 3.4 200 01/01/2019 20:05:55 66 0.0 0.00 231.7 3.4 190 01/01/2019 20:08:25 66 0.0 0.00 231.7 3.4 195 O1/01/2019 20:10:55 64 0.0 0.00 231.7 3.4 192 O1/01/2019 20:13:25 67 0.0 0.00 231.7 3.4 194 01/O1/2019 20:15:55 64 0.0 0.00 231.7 3.4 185 O1/O1/2019 20:18:25 65 0.0 0.01 231.7 3.4 186 01/01/2019 20:20:55 65 0.0 0.01 231.7 3.4 198 O1/O1/2019 20:23:25 63 0.0 0.00 231.7 3.4 188 O1/01/2019 20:25:55 65 0.0 -0.00 231,7 3.4 204 01/01/2019 20:28:25 62 0.0 0.00 231.7 3.4 195 O1/01/2019 20:30:55 62 0.0 0.01 231.7 3.4 210 O1/O1/2019 20:33:25 63 0.0 0.01 231.7 3.4 216 O1/01/2019 20:35:55 63 0.0 0.00 231.7 3.4 215 Page 3 of 5 Well MT6-02 Field Alpine Sob Start 7an/01/2019 customer Conoco Phillips lob Number Date Time 24-hr clock Treating Pressure PSI flow Rate B/M Density L8/6 Volume BBL MT_STG VOL BBL WHIP PSI Message 01/01/2019 20:40:55 61 0.0 0.01 231.7 3.4 211 01/01/2019 20:43:25 61 0.0 0.00 231.7 3.4 232 01/01/2019 20:45:55 64 0.0 0.00 231.7 3.4 206 01/01/2019 20:48:25 65 0.0 -0.00 231.7 3.4 215 01/01/2019 20:50:55 63 0.0 0.00 231.7 3.4 214 01/01/2019 20:53:25 62 0.0 0.01 231.7 3.4 222 01/01/2019 20:55:55 62 0.0 0.00 231.7 3.4 206 01/01/2019 20:58:25 63 0.0 0.01 231.7 3.4 208 01/01/2019 21:00:55 64 0.0 0.01 231.7 3.4 211 01/01/2019 21:03:25 64 0.0 0.00 231.7 3.4 212 01/01/2019 21:05:55 63 0.0 0.01 231.7 3.4 165 01/01/2019 21:08:25 64 0.0 0.00 231.7 3.4 168 01/01/2019 21:10:55 63 0.0 0.01 231.7 3.4 155 01/01/2019 21:13:25 64 0.0 0.01 231.7 3.4 197 01/01/2019 21:15:55 63 0.0 0.01 231.7 3.4 541 01/01/2019 21:18:25 64 0.0 0.01 231.7 3.4 1446 01/01/2019 21:20:55 65 0.0 0.00 231.7 3.4 2037 01/01/2019 21:23:25 64 0.0 0.00 231.7 3.4 1765 01/01/2019 21:25:55 63 0.0 0.00 231.7 3.4 2010 01/01/2019 21:28:25 63 0.0 0.00 231.7 3.4 2303 01/01/2019 21:30:55 63 0.0 0.00 231.7 3.4 2395 01/01/2019 21:33:25 62 0.0 0.01 231.7 3.4 2497 01/01/2019 21:35:55 63 0.0 0.01 231.7 3.4 2536 01/01/2019 21:38:25 63 0.0 0.00 231.7 3.4 2469 01/01/2019 21:40:55 64 0.0 0.00 231.7 3.4 2701 01/01/2019 21:43:25 63 0.0 0.00 231.7 3.4 2852 01/01/2019 21:45:55 64 0.0 0.00 231.7 3.4 2883 01/01/2019 21:48:25 64 0.0 0.00 231.7 3.4 2954 01/01/2019 21:50:55 63 0.0 0.01 231.7 3.4 3011 01/01/2019 21:53:25 62 0.0 0.01 231.7 3.4 2978 01/01/2019 21:55:55 65 0.0 0.01 231.7 3.4 2935 01/01/2019 21:58:25 65 0.0 0.00 231.7 3.4 2664 01/01/2019 22:00:55 63 0.0 0.00 231.7 3.4 2427 01/01/2019 22:03:25 62 0.0 0.00 231.7 3.4 2240 01/01/2019 22:05:55 61 0.0 0.00 231.7 3.4 2065 01/01/2019 22:08:25 63 0.0 0.01 231.7 1 3.4 2045 01/01/2019 22:10:55 64 0.0 0.00 231.7 3.4 2064 01/01/2019 22:13:25 63 0.0 0.01 231.7 3.4 2321 01/01/2019 22:15:55 63 0.0 0.00 231.7 3.4 2329 01/01/2019 22:18:25 63 0.0 0.00 231.7 3.4 2326 01/01/2019 22:20:55 62 0.0 0.00 231.7 3.4 2323 01/01/2019 22:23:25 63 0.0 0.00 231.7 3.4 2321 01/01/2019 22:25:55 62 0.0 0.00 231.7 3.4 2385 01/01/2019 22:28:25 61 0.0 0.00 231.7 3.4 2493 01/01/2019 22:30:55 65 0.0 0.00 231.7 3.4 2533 01/01/2019 22:33:25 61 0.0 0.00 231.7 3.4 2592 01/01/2019 22:35:55 64 0.0 MO 231.7 3.4 2571 01/01/2019 22:38:25 60 0.0 0.01 231.7 3.4 2624 01/01/2019 22:40:55 62 0.0 0.00 231.7 3.4 2618 01/01/2019 22:43:25 61 0.0 0.00 231.7 3.4 2638 01/01/2019 22:45:55 63 0.0 0.00 231.7 3.4 2731 01/01/2019 22:48:25 62 0.0 0.00 231.7 3.4 2488 01/01/2019 22:50:55 62 0.0 0.00 231.7 3.4 2567 01/01/2019 22:53:25 62 0.0 0.00 231.7 3.4 2822 Page 4 of 5 Well MT6-02 Field Alpine Job Start )an/O1/2019 Customer Conoco Phillips Job Number Date Time 24-hr clock Treating Pressure PSI Flow Rate BIN Density LB/G Volume BBL MT_STG_VOL BBL WNP PSI Message O1/01/2019 22:58:25 63 0.0 0.00 231.7 3.4 3284 O1/01/2019 23:00:55 61 0.0 0.00 231.7 3.4 3490 01/01/2019 23:03:25 61 0.0 0.00 231.7 3.4 3480 01/01/2019 23:05:55 60 0.0 0.01 231.7 3.4 3477 01/01/2019 23:08:25 61 0.0 0.01 231.7 3.4 2721 01/01/2019 23:10:55 62 0.0 0.00 231.7 3.4 -3 01/01/2019 23:13:25 61 0.0 0.00 231.7 3.4 1 O1/01/2019 23:15:55 60 0.0 0.01 231.7 3.4 1 01/01/2019 23:18:25 61 0.0 -0.00 231.7 3.4 10 01/01/2019 23:20:55 61 0.0 0.00 231.7 3.4 7 O1/01/2019 23:23:25 63 0.0 1 0.00 231.7 3.4 6 O1/01/2019 23:25:55 60 0.0 1 0.00 231.7 3.4 7 Post .lob Summary Average Pump Rates, bbl/min Volume of Fluid Injected, bbl Slurry 3.3 N2 Mud Maximum Rate 4.2 Total Slurry 146.8 Mud 0.0 Spacer 60.0 112 Treating Pressure Summary, psi Breakdown Fluid Maximum 4031 Final 58 Average 168 Bump Plug to Breakdown Type Volume bbl Density lb/gal Avg. N2 Percent % Designed Slurry Volume 145.4 bbl Displacement 0.0 bbl Mix Water Temp degF Cement Circulated to Surface? Volume bbl Washed Thru Pads ❑ To ft Customer or Authorized Kenny Harding Representative Schlumberger Supervisor Lance Kalivas Circulation Lost XO Job Completed X❑ Page 5 of 5 Cement MT6-02 Intermediate Casing Ceme Cement Details Description Intermediate Casing Cement Cementing Start Date 1/112019 16:00 Cementing End Date 1/1/2019 23:00 Weilbore Name MT6-02 Comment SLB pumped 60 bbl Mud Push, 98 bbi 12.2 ppg Lead cement, 48.8 bbl 15.8 ppg Tail cement. Kicked out with 20 bbl water. Rig displaced with 638 bbi LSND. Bottom plug landed on time, @ 490 bbl into displacement, pressure built up to 3000 psi, packed off and lost returns. 110 bbi lost to formation. Cement Stages Stage # 1 Description Intermediate Casing Cement Objective 1000 feet of cement for drilling ahead Top Depth (ftKB) 7,742.5 Bottom Depth (ftKB) 8,742.5 Full Return? No Vol Cement... Top Plug? 11 Yes Btm Plug? Yes Q Pump [nit (bbi/m... 4 Q Pump Final (bbll... 3 Q Pump Avg (bbf/... 3 P Pump Final (psi) 3,080.0 P Plug Sump (psi) 3,080.0 Recip? No Stroke (ft) I Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Lost returns at 490 bbi into displacement, packoff and pressure up to 3100 psi. Lost 110 bbi cement to formation. Cement Fluids & Additives Fluid Fluid Type Intermediate Cement Fluid Description Estimated Top (ftKB) 7,742.5 Est Btm (ftKB) 8,115.0 Amount (sacks) 239 Class Volume G 98.0 Pumped (bbl) Yield (ft'/sack) 2.30 Mix H2O Ratio (gallsack) 13.23 Free Water (%) Density (Ib/gal) 12.20 Plastic Viscosity (cP) 12.0 Thickening Time (hr) CmprStr 5.00 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 8,115.0 Est Btm (ftKB) 8,742.5 Amount (sacks) 236 Class Volume G 48.8 Pumped (bbl) Yield (ft'/sack) 1.16 Mix H2O Ratio (gallsack) 5.06 Free Water I%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 124.0 Thickening Time (hr) CmprStr 5.50 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 1/4/2019 Loepp, Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 4, 2019 9:27 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: MT6-02 CBL and Plan Forward Follow Up Flag: Follow up Flag Status: Flagged Roger that. Results will probably come sometime this evening. I'll touch base with you tonight if it's going to be later. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, January 04, 2019 9:26 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: RE: [EXTERNAL]RE: MT6-02 CBL and Plan Forward Approval is granted to drill out the shoe track and 20' of new formation and obtain an FIT. Would like to see the FIT results before approval is granted to drill ahead. I will be available. Just give me a heads up. Thanx, Victoria From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 4, 2019 9:21 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Bov> Subject: RE: [EXTERNAL]RE: M76-02 CBL and Plan Forward Victoria, Will do To make sure I understand correctly, we have approval to at least drill out the shoe track and 20' of new formation to take an FIT. If that FIT passes, do we have approval to continue on with the remaining well operations? Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Rov> Sent: Friday, January 04, 2019 9:17 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: RE: [EXTERNAL]RE: MT6-02 CBL and Plan Forward Andrew, Please forward the results of the FIT including plot as soon as available. Thanx, Victoria From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 4, 2019 9:00 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: MT6-02 CBL and Plan Forward Victoria, Regarding the CBL of the Int2 cement job, as long as the execution goes per plan we would log it with a sonic tool in the liner running BHA as we have done in the past. So it would not be immediately after pumping. However, if we suspected that there were issues with the execution then we would log before drilling ahead. There is —300' of hole below the shoe. If the FIT did not pass then we would squeeze cement below the shoe allowing it to push into wherever was leaking. We feel confident that the shoe is competent but we did lose circulation so that fracture may be below us and could cause a low LOT. In either case, our first play would be to squeeze the shoe. Thanks, Andrew (303) 378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, January 04, 2019 8:45 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]RE: MT6-02 CBL and Plan Forward Another question: Is there 300' of hole below the shoe? What if the FIT doesn't pass? Could you place cement in the hole versus a squeeze? Let me know your plans. From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 8:23 AM To: Beat, Andrew T (Andrew.T.Beat@conocophillips.com) <Andrew.T.Beat@conocophillips.com> Subject: FW: MT6-02 CBL and Plan Forward Andrew, Please forward the information below, however, you may move forward with the FIT which must pass to drill ahead. We will likely grant a waiver from the 250' TVD cement required. Will a CBL be run on the 7" right after the cement job? Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 7:54 AM To: 'Beat, Andrew T' <Andrew.T.Beat@conocophi Ili ps.com> Subject: RE: MT6-02 CBL and Plan Forward Andrew, Please forward the cement job summary, log and cement job plots. Where is the free pipe indication on the log? Please have your log analyst interpret quality of cement, feet of cement and show the —170' TVD of good cement. Are you in town? Can someone come over and review? We are available anytime. Thanx, Victoria From: Beat, Andrew T <Andrew.T.Beat @conocophillips.com> Sent: Friday, January 4, 2019 7:33 AM To: Loepp, Victoria T (DOA) <victoria.Ioepp@alaska.gov>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Marushack, Andy J <Andy.J.Marushack@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Alexa, Kurt 1 <Kurt.J.Alexa@conocophillips.com>; Alvord, Chip <Chip.Alvord@conocophillips.com> Subject: MT6-02 CBL and Plan Forward Importance: High Victoria, Last night we logged the top of cement at 8,504' MD (6,899' TVD). Our casing shoe is at 8,742' MD (7,070' TVD) so we have 238' MD (171' TVD) of cement coverage on the backside of our Intermediate 1 casing. We would like to request a waiver from the 500' MD/250' TVD casing cement requirement (20 AAC 25.030 (d) (5)) to allow us to continue with planned operations without any remediation. Our Intermediate 2 casing will cover from the Alpine C reservoir to surface providing additional isolation to the zones exposed in Intermediate 1 and the cement job will be logged. We believe that with this additional barrier along with the 238' MD of cement placed behind the Intl casing that all requirements in 20 AAC 25.030 (a) are met. Please let me know if you have any questions or would like to discuss further. Thank you, Andrew Beat Senior Drilling Engineer ConocoPhillips Alaska (303) 378-8881 cell (907) 265-6341 office Loepp. Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Saturday, January 5, 2019 8:51 AM To: Beat, Andrew T Subject: Re: MT6-02 Intl FIT Follow Up Flag: Follow up Flag Status: Completed Andrew, Approval is granted to proceed with the approved well plan. Victoria Sent from my Whone On Jan 5, 2019, at 8:31 AM, Beat, Andrew T <Andrew.T.Beat@conocophillips.com> wrote: Victoria, Attached are the results of the FIT taken below the Intl shoe. Are we approved to proceed as planned with the remainder of the well? Thanks, Andrew (303) 378-8881 <MT6-02 Int 1 Casing Test - 8.75 FIT- 9046.pdf> THE STATE V 0 a I 4FS11 W44, k GOVERNOR MIKE DUNLEAVY Graham Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Greater Mooses Tooth Field, Lookout Oil Pool, MT6-02PH ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-159 Surface Location: 239' FNL, 3115' FEL, SEC. 6, T10N, R3E, UM Bottomhole Location: 2638' FNL, 2192' FEL, SEC. 30, TI 1N, R3E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced service well. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name MT6-02PH and API number 50-103-20792-70-00 from records, data and logs acquired for well MT6-02. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair DATED this day of December, 2018. STATE OF ALASKA AL, A OIL AND GAS CONSERVATION COMM, ON PERMIT TO DRILL 20 AAC 25.005 NOv 2 8 2018 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑� Service - Disp ❑ 1 c. Specify if weft is -proposed for: Drill ❑✓ Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone ❑ Coalbed Gas ❑ ` Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑ Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. Saliallro MT6-02PH 3. Address: 6. Proposed Depth: ts/r-1/9 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 12642 TVD: 7969 Greater Mooses Tooth Unit Lookout Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 239' FNL, 3115' FEL, Sec. 6, T1 ON, R3E, UM ' AA081818,*AA081798 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 4079' FNL, 1861' FEL, Sec. 30, T11N, R3E, UM 932553, 340761, 932533, 340760 12/25/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2638' FNL, 2192' FEL, Sec. 30, T11 N, R3E, UM 1208, 607 1799' to AA093746 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 89.31 15. Distance to Nearest Well Open Surface: x- 317115 y- 5945564 Zone-4 GL / BF Elevation above MSL (ft): to Same Pool: 2251' to MT6 03 16. Deviated wells: Kickoff depth: 318 feet 17. Maximum Potential Pressures in psig (see 2 _2_5.MtJ Maximum Hole Angle: 90 degrees Downhole: 3810 Surface: 3015 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94 H-40 Welded 80 34 34 115 115 10 yds 16" 13.375" 68 L-80 BTC-M 2066 34 34 2100 2036 964 sx 11.0 ppg DeepCrete,330 sx 15.8 ppg G 12.25" 9.625" 40 L-80 TXP 8430 34 34 8464 6868 218 sx 15.8 ppg tail 8.75" 7.0" 26 L-80 Blue 11145 34 34 11179 7905 230 sx 15.8 ppg tail 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 0 Hydraulic Fracture planned? Yes ❑ No 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch Drilling Program ❑ Seabed Report Time v. Depth Plot ❑ Drilling Fluid Program ❑ Shallow Hazard Analysis 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Andrew Beat )W3 Authorized Name: Graham Alvord (265-6120) Contact Email: andrew.t.beat CO .com Authorized Title: Drilling Manager Contact Phone: 907 265-6341 /� i Authorized Signature: „ G , cu Date: i l l Z0 Z� I Commission Use Only Permit to Drill API Number: Permit Approva See cover letter for other Number: i$-� 5 50- 103 - a.Q-79 O - OO Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes ❑ No[K Mud log req'd: Yes ❑ No❑v� Other: i3oP to 3Soo�p s � fits f- measures: Yes ❑ No[K Directional svy req'd: Yes No❑ C ✓lh il�i" �r5 t Aa /--,�,,Hj Spacing exception req'd: Yes El No Inclination -only svy req'd: Yes❑ Noy %,/►/C!-f�l- W Gt I �t� �7 0 �tr/ Post initial injection MIT req'd: Yes 0 No[:] s /�) (z J ( / 7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1,2/ Submit Form and \� 10-401 Revised 5/2017 fiB V IYIaerMit is valid for 24 mont t` IN er 20 AAC 25.005(g) Attachments in Duplicate DEC 18 2010 t.;try/ �ti ,4, (2/0-F 5 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 28th, 2018 Alaska Oil and Gas Conservation Commission 333 West 71 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT6-02PH Dear Sir or Madam: J ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the MT6 drilling pad. The intended spud date for this well is December 25, 2018. It is intended that Doyon Rig 19 be used to drill the well. MT6-02 is planned to be a horizontal Alpine C sand injector. The 16" surface hole will TD above the C-30 sand and then 13- 3/8" casing will be set and cemented to surface. The intermediate hole will be drilled in two sections to mitigate issues with shale instability over the long interval. The 12-1/4" intermediate #1 section will be drilled into the top of the HRZ. A 9-5/8" casing string will be set and cemented from TD to secure the shoe and cover 500' above any hydrocarbon -bearing zones. The second intermediate will be drilled with one of two options, ultimately landing in the Alpine sand. Option 1, a 7" steerable liner drilling assembly consisting of a 6" pilot BHA ahead of the casing shoe and incorporate a 8-3/4" underreamer for increased annular clearance. The drilling assembly inner string will then be tripped and a cement assembly run into the hole to cement the 7" drilling liner annulus. Option 2, will use an 8-3/4" drilling assembly and under reamed to 10 '/4". The section will then be lined with a 7" Liner. Managed Pressure Drilling technology will also be utilized to assist with providing stability through the HRZ, Kalubik, and Miluveach formations. The drilling assembly inner string will then be tripped and a cement assembly run into the hole to cement the 7" drilling liner annulus. The 6" production interval will be geo-steered in the Alpine Sand and will serve as a pilot for future well planning. The method for plugging back this hole will depend on the results. It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT6, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Andrew Beat at 265-6341 (andrew.t.beat@conocophillips.com) or Chip Alvord at 265-6120. Sincerely, cc: MT6-02 Well File / Ann Haggerty-Sherrod ATO 1530 Johnson Njoku ATO 1720 Chip Alvord ATO 1570 Andrew Beat John Cookson ATO 1750 Drilling Engineer Application, 'ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 MT6-02PH Application for Permit to Drill Document Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (9)............................................................ 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2))............................................ 3 Requirements of 20 AAC 25.050(b)............................................................................................................. 3 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) ........................ 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of'20 AAC 25.005 (c) (5))......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) .......... 5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) ......................... 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)).................................... 6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10))......................................... 7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ........................ 7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12))...................................7 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) ......................... 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 9 (Requirements of 20 AAC 25.005 (c) (14))............................................................................. 9 15. Attachments............................................................................................................... 9 Attachment 1 Cement Summary ................................................................................................................. 9 MT6-02PH PTD Page 1 of 14 Printed: 28-Nov-18 Attachment 2 Drilling Hazards Summary Attachment 3 Area of Review .................. Attachment 4 Directional Plan ............... Application 'ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 ......................................................... 9 ......................................................... 9 ......... Error! Bookmark not defined. MT6-02PH PTD Page 2 of 14 Printed: 28-Nov-18 Applicatior 3ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 1. Well Name (Requirements of 20 AAC 25.005 ()9) The well for which this application is submitted will be designated as MTU MT6-02. 2. Location Summary (Requirements of20AAC25.005(c)(2)) Location at Surface 239' FNL, 3115' FEL, Sec. 6, T10N, R3E, UM NAD 1927 RKB Elevation 89.3' AMSL • Northings: 5,945,564 • Eastings: 317,115 Pad Elevation 52.1' AMSL Top of Productive Horizon eel 4079' FNL, 1861' FEL, Sec. 30, T11N, ME, UM NAD 1927 Northings: 5,952,252 Eastings: 318,505 Measured Depth, RKB: 11,159' Total Vertical Depth, RKB: 7,847' Total Vertical De th, SS: 7,758' Total Depth Toe 2638' FNL, 2192' FEL, Sec. 30, T11N, RM, UM NAD 1927 Northings: 5,953,700 Eastings: 318,204 Measured Depth, RKB: 12,642' Total Vertical Depth, RKB: 7,969' Total Vertical De th, SS: 7,880' Requirements of 20 AA 25.050(b) Please see Attachment 3: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20 AAC 25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 19. MT6-02PH PTD Page 3 of 14 Printed: 28-Nov-18 Applicatior 3ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient(psi)si Pore pressure ASP Drilling 20 115 1115 10.9 52 54 13.375 2100 / 2036 14.5 918 1332 9.625 8464 / 6868 13.5 3356 2835 7 11179 / 7905 12.5 3625 2825 4.5 22669 / 7809 12.5 3605 N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS Drilling below conductor casing (20") ASP = [(FG x 0.052) - 0.1] D _ [(10.9 x 0.052) - 0.1] x 115 = 54 psi OR ASP = FPP - (0.1 x D) = 918 - (0.1 x 2036) = 714 psi Drilling below surface casing (13-3/8") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2036' = 1332 psi OR ASP = FPP - (0.1 x D) = 3356 - (0.1 x 6868') = 2670 psi Drilling below intermediate casing (9-5/8") ASP = [(FG x 0.052) - 0.1] D _ [(13.5 x 0.052) - 0.1] x 6868 = 4135 psi OR ASP = FPP - (0.1 x D) = 3625- (0.1 x 7905') = 2835 psi MT6-02PH PTD Page 4 of 14 Printed: 28-Nov-18 Applicatior 3ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 4. Drilling below production liner (7) OR ASP = [(FG x 0.052) — 0.1] D = [(12.5 x 0.052) — 0.1 ] x 7905 = 4350 psi ASP = FPP — (0.1 x D) = 3605 — (0.1 x 7809) = 2825 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensityfor differential sticking, Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of20 AAC 25.005 (c)(s)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementin Program Csg/Tbg Hole weight Grade Conn. Length Top MDITVD Btm MD/TVD Cement Program OD (in) Sze (Ib/ft) (ft) (ft) (ft) 20 42 94 H-40 Welded 80 Surf 115 / 115 Cemented to surface with 10 yds slurry H563/ Cement to Surface with 13-3/8 16 68 L-80 TXP 2,063 Surf 2,100 / 2,036 964 sx DeepCrete Lead at 11.0 ppg, 330 sx Class G Tail Slurry at 15.8 ppg TXP/ 9-5/8 12-1/4 40 L-80 THC 0 8,449 Surf 8,464 / 6,868 218 sx Class G Tail at 15.8 ppg 7 6 x/ 26 L-80 Blue 11,142 Surf 11,179 / 7,905 230 sx Class G Tail at 15.8 ppg 4-1/2 n/a 12.6 L-80 BS H 10,942 Surf 10,979 / 7,877 n/a 4 1/2 6 12.6 L-80 TXP 11,690 10,979 / 7,877 22,669 / 7,809 Uncemenkted open hole liner w/ pre - perforated pup joints 7. Diverter System Information(Requirements of20AAC 2s.00s(c)(7)) It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT6, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. MT6-02PH PTD Page 5 of 14 Printed: 28-Nov-18 Applicatior 'ermit to Drill, Well MTU MT6-02PH Saved:28-Nov-18 8. Drilling Fluid Program (Requirements of20AAC25.005(c)(8)) Surface Intermediate Intermediate production #1 #2 Hole Size in. 16 12.25 6.0 x 8.75 6.0 Casing Size in. 13.375 9.625 7 4.5 Density PPG 9.0 — 10.0 9.4 — 10.0 10.0 — 11.0 8.8 PV cP 13 10 10 15 YP I1b./1000 35-50 20 - 28 20 - 28 15-20 Funnel s/qt. 200 40 - 50 40 - 50 60 - 80 Viscosity Initial Gels Ib./100 50 10 10 10 10 Minute Ib./100 60 15 20 15 Gels ft2 API Fluid cc/30 Loss min. N.C. — 15.0 5.0 5.0 4.0 HPHT Fluid cc/30 n/a 8.0 — 12.0 8.0 — 12.0 10.0 Loss min. pH 11.0 9:5-10.0 9.5-10.0 9.0-9.5 Surface Hole: A mixed -metal oxide fresh water drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight <10.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate #2: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight f potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.0 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole. • Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water -based mud drill -in fluid F1oPro weighted to 8.8-9.5 ppg with calcium carbonate. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. MT6-02PH PTD Page 6 of 14 Printed: 28-Nov-18 Applicatior. '3ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 9. Abnormally Pressured Formation Information (Requirements of20 AAC 25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of20AAC25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 19 onto GMTU MT6-02 over pre -installed 20" insulated conductor. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16" hole to the surface casing point as per the directional plan. (LWD Program: GR). 4. Run and cement new 13-3/8" 68 ppf L-80 surface casing to surface. 5. Install BOPE with the following equipment/configuration: 13-5/8" annular preventer, 3-1/2" x 6" VBR, blind ram and 3-1/2" x 6" VBRs. 6. Test BOPE to 250 psi low / 3500 psi high (24-48 hr. AOGCC notice, 72 Hr BLM notice). 7. Pick up and run in hole with 12-1/4" drilling BHA to drill intermediate #1. 8. Chart casing pressure test to 2500 psi for 30 minutes. 9. Drill out shoe track and 20' of new hole. 10. Perform LOT to maximum EMW of 18.5 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW. Forward data to the AOGCC. 11. Displace well to 9.4 ppg LSND mud. 12. Drill 12-1/4" hole to the casing point as per directional plan. (LWD Program: GR/RES). 13. Circulate wellbore clean and POOH. 14. Change upper VBRs to 9-5/8" solid body rams. Test same to 250 psi low / 2,500 psi high. 15. Run 9-5/8" intermediate casing to TD. 16. Pump single stage cement job to isolate the casing shoe and 500' MD or 250' TVD, whichever is larger, above uppermost hydro -carbon bearing zone (none expected). 17. Change upper 9-5/8" solid body rams to 3-1/2" x 6" VBRs. Test BOPE to 250/3500 psi. 18. Pick up and run in hole with 8-3/4" bit and clean out assembly. Perform a LOT down the 13-3/8" x 9 5/8" casing annulus with Ball mill and freeze protect. Forward data to AOGCC. 19. Pressure test casing to 3000 psi for 30 minutes and record results. 20. Drill out shoe track and 20' of new hole. MT6-02PH PTD Page 7 of 14 Printed: 28-Nov-18 Applicatior 'ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 21. Perform FIT to 14 ppg EMW. Minimum required to drill ahead is 12.5 ppg EMW. 22. Circulate wellbore clean and POOH. 23. Perform either Option 1 or Option 2 Option 1 a. Pick up and run in hole with the 7" steerable drilling liner. Pick up and stab in 6" pilot BHA assembly. (LWD Program: GR/RES). b. RIH to bottom with 7" SDL on 5" drill pipe. c. Drill 6" x 8-3/4" SDL hole to production casing point into the Alpine sand using Managed Pressure Drilling to maintain constant bottom hole pressure on connections. (LWD Program: GR/RES). d. Land 7" liner at TD. Disconnect SDL and POOH to surface with inner string and pilot. e. Run in hole with inner string cementing BHA. Stab into liner. Circulate and condition mud in preparations for cementing. Option 2 a. Drill 8-3/4" x 10 '/4" Int. 2 to production casing point into the Alpine sand using Managed Pressure Drilling to maintain constant bottom hole pressure on connections. (LWD Program: GR/RES). b. Circulate hole clean and POOH. c. Pick up and run 7" liner to TD. d. Circulate and condition mud in preparations for cementing. 24. Cement 7" liner from shoe to 250' TVD above Alpine Formation. Set liner top packer. Circulate bottoms up from top of liner. POOH laying down 5" drill pipe. 25. Run 7" tie -back and engage seals. Space out to land hanger. 26. Displace 9-5/8" x 7" annulus to corrosion inhibited brine and diesel freeze protect. Land the 7" tie back hanger and pressure test annulus and seals to 2000 psi for 30 min and chart. 27. Pick up 4" DP. Test BOPE to 250 psi low / 3,500 psi high. 28. Pick up and RIH with 6" drilling assembly. (LWD Program: GR/Azimuthal RES). 29. Chart casing pressure test to 3500 psi for 30 minutes and record results. 30. Drill out and perform FIT to 12.5. Minimum acceptable leak -off for drilling ahead is 11.0 ppg EMW. n 31. Drill 6" horizontal hole to pilot section TD (LWD Program: GR/ Azimuthal RES). fo t✓� �� h 32. Perform either Option A or Option B (will be determined based on reservoir quality seen in pilot). Option A a. Circulate the hole clean and POOH to Int. 2 shoe. b. Prepare to perform Open Hole Sidetrack until necessary separation from original hole is achieved. Option B a. Circulate the hole clean and POOH with drilling BHA to surface. b. MU and RIH with cement stinger to TD. C. Condition for cement job and pump enough cement volume to cover entire open hole section. d. LD cement stinger and PU 6" drilling assembly. e. RIH and prepare to perform sidetrack off cement plug. 33. End MT6-02PH PTD. MT6-02PH PTD Page 8 of 14 Printed: 28-Nov-18 Applicatior 3ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well MT6-02PH will be injected into a permitted surface casing x production casing annulus on MT6/CD1. The MT6-02PH surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1200' TVD. Significant hydrocarbon zones include only the Alpine sand based on pre -drill interpretations. There will be 500' MD, or 250' TVD, whichever is greater, of cement placed above the top of the Alpine reservoir. Once MT6-02PH has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,033') + 1,500 psi = 2767 psi Pore Pressure = 910 psi Therefore Differential = 2767 — 910 = 1857 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt Grade Range Connection Collapse 85% of Burst 85% of (ppf) Type Collapse Burst 13-3/8" 68 L-80 3 BTC-M 2260 psi 1921 psi 5020 psi 4267 psi 9-5/8 40 L-80 3 BTC-M 3090 psi 2626 psi 5750 psi 4887 psi 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Area of Review Attachment 4 Directional Plan MT6-02PH PTD Page 9 of 14 Printed: 28-Nov-18 Application 'ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 Attachment 1— Cement Summary GMTU MT6.02PH wp07 +-Go— Wd. 14"rNa0aMwTr.n MT6-02PH PTD Page 10 of 14 Printed: 28-Nov-18 Application 'ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 13-3/8" Surface Casing run to 2,100' MD / 2,036' TVD. Cement from 2,100' MD to 1,600' (500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1,600' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1,106' MD), zero excess in 20" conductor. Lead slurry from 1,600' MD to surface with DeepCrete @ 11.0 ppg Conductor (115' — 37� X 1.0190 ft3/ft X 1.0 (0% excess) = 79 ft3 Permafrost to Conductor (1,106' — 115') X 0.4206 ft3/ft X 3.5 (250% excess) = 1,459 ft3 Top of Tail to Permafrost (1,600' — 1,106� X 0.4206 ft3/ft X 1.5 (50% excess) = 312 ft3 Total Volume = 79 + 1,459 + 312 = 1850 ft3 => 964 sx of 11.0 ppg DeepCrete @ 1.92 ft3 /sk Tail slurry from 2,100' MD to 1,600' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,100'—1,600) X 0.4206 ft3/ft X 1.50 (50% excess) = 315 ft3 Shoe Joint (80� X 0.8407 ft3/ft X 1.0 (0% excess) = 68 ft3 Total Volume = 315 + 68 = 383 ft3 => 330 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk 9-5/8" Intermediate casing to 8,464' MD / 6,868' TVD Cement 500' up from 9-5/8" casing shoe from 8,464' MD to 7,964' MD. Assume 40% excess annular volume. Tail slurry from 8,464' MD to 7,964' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (8,464' — 7,964) X 0.3132 ft3/ft X 1.40 (40% excess) = 219 ft3 Shoe Joint (80') X 0.4257 ft3/ft X 1.0 (0% excess) = 34 ft3 Total Volume = 219 + 34 = 253 ft3 => 218 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk 7" Intermediate liner run to 11,179' MD / 7,905' TVD Top of slurry is designed to be — 250' TVD up from the 7" liner shoe. Assume 30% excess annular volume. 6" x 8-3/4" underreamer to be I00ft behind the drill bit. Tail slurry from 11,179' MD to 9,896' MD with 15.8 ppg Class G + additives (250' tvd) 8-3/4" Hole to Top of Tail (11,179' — 9,896� X 0.1503 ft3/ft X 1.30 (30% excess) = 251 ft3 Shoe Joint (80� X 0.2148 ft3/ft X 1.0 (0% excess) = 17 ft3 Total Volume = 250 + 17 = 267 ft3 => 230 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk MT6-02PH PTD Page 11 of 14 Printed: 28-Nov-18 Applicatior 'ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole / 13-3/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed — control drill, reduce pump rates and circulating time, reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP Abnormal Pressure in Low Diverter drills, increased mud weight. Shallow Surface Formations hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement slurries, port collar, control pipe running seeds 12-1/4" Hole / 9-5/8" Casinci Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, MPD stripping ractices Abnormal Pressure in Low Well control drills, check for flow during Overburden Formations connections, increase mud weight. Shallow hazard study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices 6" x 8-3/4" Hole / 7" Liner - Casing Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight High MPD for shale stability, Steerable Drilling Liner, hole Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Low Well control drills, check for flow during Pressure connections, increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers MT6-02PH PTD Page 12 of 14 Printed. 28-Nov-18 Applicatior, 'ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 6" Hole / 4-1/2" Pre -Perforated Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Low Well control drills, check for flow during Pressure connections, increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: MT6-02PH will be the seventh well drilled on the pad. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset production has the potential to reduce the reservoir pressure. LCM material will be on location to deal with losses. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach in the pilot and intermediate 42 hole sections will require higher mud weights than historically used to enhance wellbore stability. Steerable Drilling Liner and Managed Pressure Drilling will be used in conjunction with a 4-string casing design to mitigate shale instability. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. MT6-02PH PTD Page 13 of 14 Printed: 28-Nov-18 Applicatior 'ermit to Drill, Well MTU MT6-02PH Saved: 28-Nov-18 Attachment 3 —Area of Review MT6-02 Area of Review: This Area of Review is required as MT6-02 is being permitted as an Alpine C Sand Injector. There are currently not any wells or planned wells that fall within %4 mile of the well's entry point into the Alpine C sand. MT6-02 Quarter Mile Plot MT6-02 Quarter Mile Plot / Punt d 11/27'18 7 &M42 \ qCt P.Mr d 1127118 ' 22500 \ _.-•-tns-0z`-uraal - _�� 2000fl \\ - 11500 \ IS004 r •'ula.as 4 2500 1MOO ORB-04 ,, 1500 z�ao •.�� U WT6.06 Attachment 4 — Directional Plan MT6-02 MT6-02PH PTD Page 14 of 14 Printed: 28-Nov-18 m 0. E O V L O 0. x W IA CL c �0. 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UILFb o 0 0 C a a ❑ ❑ ❑ � V N Cl?M O O N CD m 6 ID � M N (0O O NO O N m z m 12 CD M N m O a 0 0 m O O -�6 O 0 is 3 o aO o ff I- a F I- a LL F F- a O 0 CDr O co CD In = O L m_ o w 0 0 0 m O m O -O 1-- O N N N O CD M N N ❑ 0 O O CDO J J J J CO(O J J O F -C m p U (n in cn in in in in in in in in m in in in a O O O m N r V M W V U) (() x O O r d' O N V (O I- M V U) N Ib O O 1� O W u( (n m M c} N O to O (O 1� t` O m In N N N N M M M m O d + m c a 0 0 V O O M M I- t` W W m M O m N O V VO O m V 1� cq (O O N In O cb r-� M O 0 O O OJ O V m ON W 7 of O O J co d' CY (O N m (( Z N V (() (O co t` w + O N O In V O O co O N r m N O O O N O O O m O N V M Cl) Cl) (a L O co (O O O O M 1- O O 1- Vt M m co N (O (O CD N M O O V' N C O (D tl- � m m m j 0 ��„ N N N N M M (O 1- � r r � r t` O N M O O (n 'V 7 V m O (n O V (O N 1� (O O O �- V co m Qo N m V' M N 7 L I� t2 m O O' N O N co(D W 'V N N N Q M .--- (n O O m m N m Lo O I- t` <} M O N (O O N v (O C M V M (O N N N M V' N co O O O N N 2 O co a m O O a 0 U co cl T CO _0 zz w > p @ p_ 4 a Q R 0]o p Y N N U � ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-02 MT6-02 Pilot Hole MT6-02PH_wp07 Anticollision Summary Report 14 November, 2018 BER BA 0 GE company ,ya- ConocoPhillips BAT ConocoPhillips Anticollision Summary Report UGHES a GEcompany Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Reference Site: GMT1 Lookout Pad Site Error: 0.00 usft Reference Well: MT6-02 Well Error: 0.00 usft Reference Wellbore MT6-02 Pilot Hole Reference Design: MT6-02PH_wp07 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well MT6-02 Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Plan MT6-02 @ 89.30usft (Doyon19 Planned) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Survey Tool Program Date 11/14/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 37.20 1,100.00 MT6-02PH_wp07 (MT6-02 Pilot Hole) GYD-GC-SS Gyrodata gyro single shots 1,100.00 2,100.00 MT6-02PH_wp07(MT6-02Pilot Hole) MWD MWD- Standard 1,100.00 2,100.00 MT6-02PH_wp07 (MT6-02 Pilot Hole) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,100.00 8,464.00 MT6-02PH_wp07 (MT6-02 Pilot Hole) MWD MWD - Standard 2,100.00 8,464.00 MT6-02PH_wp07 (MT6-02 Pilot Hole) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,464.00 10,820.00 MT6-02PH_wp07 (MT6-02 Pilot Hole) MWD MWD - Standard 8,464.00 10,820.00 MT6-02PH_wp07 (MT6-02 Pilot Hole) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,820.00 12,642.34 MT6-02PH_wp07 (MT6-02 Pilot Hole) MWD MWD - Standard 10,820.00 12,642.34 MT6-02PH_wp07 (MT6-02 Pilot Hole) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) GMT1 Lookout Pad MT6-02 - MT6-02 - MT6-02_wp07 11,199.97 11,200.00 20.09 12.64 2.697 No Errors, CC, ES, SF MT6-03 - MT6-03 - MT6-03 37.20 37.20 20.06 18.56 13.366 CC MT6-03 - MT6-03 - MT6-03 299.88 300.00 21.28 15.72 3.829 ES, SF MT6-03 - MT6-03PH - MT6-03PH 37.20 37.20 20.06 18.56 13.366 CC MT6-03 - MT6-03PH - MT6-03PH 299.88 300.00 21.28 15.72 3.829 ES, SF MT6-04 - MT6-04 - MT6-04 37.20 36.52 40.09 38.75 30.053 CC MT6-04 - MT6-04 - MT6-04 300.57 300.00 42.01 35.55 6.508 ES, SF MT6-04 - MT6-04 - MT6-04 wp10 299.90 300.00 40.09 34.51 7.184 CC MT6-04 - MT6-04 - MT6-04 wp10 399.45 400.00 40.54 33.22 5.538 ES, SF MT6-05 - MT6-05 - MT6-05 37.20 36.50 60.06 58.83 49.048 CC MT6-05 - MT6-05 - MT6-05 300.59 300.00 61.62 55.23 9.640 ES, SF MT6-05 - MT6-051-1 - MT6-051-1 37.20 36.50 60.06 58.83 49.048 CC MT6-05 - MT6-051-1 - MT6-051-1 300.59 300.00 61.62 55.23 9.640 ES, SF MT6-05 - MT6-05PB1 - MT6-05PB1 37.20 36.50 60.06 58.83 49.048 CC MT6-05 - MT6-05PB1 - MT6-05PB1 300.59 300.00 61.62 55.23 9.640 ES, SF MT6-05 - MT6-05PB2 - MT6-05PB2 37.20 36.50 60.06 58.83 49.048 CC MT6-05 - MT6-05PB2 - MT6-05PB2 300.59 300.00 61.62 55.23 9.640 ES, SF MT6-06 - MT6-06 - MT6-06 37.20 36.94 80.07 78.84 65.388 CC MT6-06 - MT6-06 - MT6-06 399.18 400.00 82.44 74.07 9.850 ES, SF MT6-06 - MT6-06P61 - MT6-06 P81 37.20 36.94 80.07 78.84 65.388 CC MT6-06 - MT6-06PB1 - MT6-06 PB1 399.18 400.00 82.44 74.07 9.850 ES, SF MT6-06 - MT6-06PB2 - MT6-06PB2 37.20 36.94 80.07 78.84 65.388 CC MT6-06 - MT6-06PB2 - MT6-06PB2 399.18 400.00 82.44 74.07 9.850 ES, SF MT6-07 - MT6-07 - MT6-07 wp05 300.30 300.00 100.05 93.66 15.649 CC MT6-07 - MT6-07 - MT6-07 wp05 399.19 400.00 100.50 92.03 11.860 ES, SF MT6-08 - MT6-08 Lower Lat - MT6-08 399.12 400.00 116.55 109.42 16.353 CC, ES, SF MT6-08 - MT6-08PB1 Lower Lat - MT6-08PB1 399.12 400.00 116.55 109.42 16.353 CC, ES, SF MT6-09 - MT6-09 - MT6-09 wpl3 299.80 300.00 140.01 134.43 25.099 CC MT6-09 - MT6-09 - MT6-09 wpl3 398.27 400.00 140.76 133.48 19.339 ES, SF Plan: MT6-01 - MT6-01 - F-wp02 619.50 600.00 17.05 5.96 1.537 No Errors, CC, ES, SF Plan: MT6-02 - MT6-02 - E-wp02 219.30 200.00 0.00 -3.04 0.000 Major Risk, CC Plan: MT6-02 - MT6-02 - E-wp02 9,976.20 10,100.00 40.56 -168.16 0.194 No Errors, ES, SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1111412018 4:51:58PM Page 2 COMPASS 5000.14 Build 85D �. ConocoPhillips BA_ �CER ConocoPhillips Anticollision Summary Report i1 IGHES BAT GE company Company: Conoco Phillips(Alaska) Inc. -WNS Project: Western North Slope Reference Site: GMT1 Lookout Pad Site Error: 0.00 usft Reference Well: MT6-02 Well Error: 0.00 usft Reference Wellbore MT6-02 Pilot Hole Reference Design: MT6-02PH_wp07 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well MT6-02 Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Plan MT6-02 @ 89.30usft (Doyonl9 Planned) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference Depths are relative to Plan MT6-02 @ 89.30usft (Doyonl9 P Coordinates are relative to: MT6-02 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4 Central Meridian is 150' 0' 0.000 W Grid Convergence at Surface is: -1.390 Ladder Plot 1400 1050 0 CO Q N D 700 U 0 2 C N U 350 0 0 2500 5000 7500 10000 12500 15000 Measured Depth LEGEND ♦� M1802, M1802. M1602 wpOl W �� IHL , MBOA1. M18o5L1 Vo �� M180], MRM], I�rt601 wp95 W a� MI603. N1603, MR03 VO . Mre05PB 1, MieOW BI V o MIGOB, M1803 Lmva Lat Mi6® VO MI603. I.R603PH.-vo"Hb e�M0 82 Mie05PBi Vo ARGOB. A11fi0BPB1 Lower Lat. M6oBPB1 Vo nrtepa, MI60a, MIeOa Art rrteo0, M18W, MI600 wp13 W +� ArtGOa, MieOe, nr18M wP10 W M1rt80o, MieL3Pe1, MI606 Pet VO Plan: MIBOt, hrtGot, F N210 �� M1805. M16g5. M1rt605 V o MiooO. M10 .2. M o00P62 V0 + Plans MIG02, M1rt602, E+vp02 W I I i I I I I I I i I I I I i I I I I I I I I I I I I I I I I I I J I I I I 1 I I I I I I I 1 I I I I I 1 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I i I I I I I i I I I I 1 1 1 1 I I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I i i I I I I I I I 1 I I I I I CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 11/14/2018 4:51:58PM Page 3 COMPASS 5000.14 Build 85D 1w. ConocoPhillips BA_ ICER ConocoPhillips Anticollision Summary Report I � IGHES BAT GE company Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Reference Site: GMT1 Lookout Pad Site Error: 0,00 usft Reference Well: MT6-02 Well Error: 0.00 usft Reference Wellbore MT6-02 Pilot Hole Reference Design: MT6-02PH—wp07 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well MT6-02 Plan MT6-02 @ 89.30usft (Doyon19 Planned) Plan MT6-02 @ 89.30usft (Doyon19 Planned) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference Depths are relative to Plan MT6-02 @ 89.30usft (Doyonl9 P Coordinates are relative to: MT6-02 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4 Central Meridian is 150' 0' 0.000 W Grid Convergence at Surface is: -1.39' Separation Factor Plot I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I i 1 I m 6.00 I I I I -- L.L I O (6 I I I I I U) I I I I I I I I I I 3.00 I --- -- --- I I I I I I I I I I I I I I I I I I I _ _ _ _ _ I I I _ _ — — — L — _ _ I I I _ _ _ _ _I_ _ _ _ _ _ I I I _ _ _ _ _ _ _ _ I I I _ _ _ _ L I I I I I I I I j I I I 0.00 0 2500 5000 7500 10000 12500 Measured Depth LEGEND MBOl. M1602. MI60z war+ w� M1nsos. MIBU5L1, nn6a5L1 V O # M601, M1fIGQI, M160] wars w �•� M�,nnsaa.u�vo rnsos. rmsaSPei. n�aosae�vo �araue, errooe wwa ��. nns®vo M�IHBAiM160JPH, MI603PHw ML60.5,MBUSPB2-5-0 6OB, MI6C8PB1 Lava Lao M60BPB1 V0 M1801, NIBOa VO MieOB, MI809, M1809 wDt� w .} MRwa, rmsoa, rn*soa wD+o w Mrsae. va Pla,: . nnoa+. P.wDoz w Mie .2, u. 1 —2 Mnws. nrtsaa �sosva � vo Pia�� nrtsaz. nnoaz. P.�Doz w CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1111412018 4:51:58PM Page 4 COMPASS 5000.14 Build 85D Transform Points l Source coordinate system Target coordinate system State Plane 1927 - Aaska Zone 4 M 76 o a PH fibers Equal Area -158) Datum: Datum: NAD 1927 - North America Datum of 1927 (Mean) NAD 1 S27 - North America Datum of 1927 (Mean) I 5993905.62 476227.35 Easting Northing 1 5945564 '1'11` 1-56779.0 2253617.5 2 2 i ype values irrto the spreadsheet or cagy and paste columns of data from a spreadsheet using the keyboard sharictts Ctd+C to ° �opy and Ctfl+Vto paste. Then click on the appropriate amen° button to transform the points to the desired coordinate system. ` Help < Back ; Prnrsh Cancel From: Beat, Andrew T To: Boyer, David L (DOA) INA T Cc: Loeoo, Victoria T (DOA); Davies. Stephen F (DOA) b I Subject: Re: [EXTERNAL]Confirmation of KB and GL Elevations for MT-6-06 + Date: Wednesday, December 5, 2018 12:53:57 PM 1 David, That is correct. The Baker plans have a couple issues that we are working on now. In addition to the elevation, the casing and formation depths aren't all accurate. The numbers in the PTD are correct. I thought I caught all of the GL mistakes but it looks like I missed one! Thanks for reviewing closely. Andrew From: Boyer, David L (DOA) <david.boyer2@alaska.gov> Sent: Wednesday, December 5, 2018 12:45 PM To: Beat, Andrew T Cc: Loepp, Victoria T (DOA); Davies, Stephen F (DOA) Subject: RE: [EXTERNAL] Confirmation of KB and GL Elevations for MT-6-06 Andrew, I am currently reviewing the PTD for MT6-02PH & MT6-02. It appears that on BakerHughes directional plan that thy are still using 37.2' for ground level instead of for the rig height with a correct KB=89.3'. On the PTD cover page, the Pad Elevation (GL) is 55' but on P.3, the pad elevation is 52.1', consistent with other wells on the pad. So I am assuming we should run with KB=89.3', GL (pad)=52.1', and rig height (constant)=37.2'. Please confirm. Thank you, Dave Boyer AOGCC From: Beat, Andrew T <Andrew.T.Beat@conocophiIli ps.com> Sent: Thursday, August 2, 2018 6:30 AM To: Boyer, David L (DOA) <david.boyer2@alaska.gov> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL] Confirmation of KB and GL Elevations for MT-6-06 Dave, Loepp, Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophiIlips.com> Sent: Thursday, November 29, 2018 6:07 AM To: Loepp, Victoria T (DOA) Cc: Rixse, Melvin G (DOA) Subject: RE: [EXTERNAL]Re: M76-02 PTD Submission Follow Up Flag: Follow up Flag Status: Flagged 3-4 weeks. We are anticipating sometime around Christmas right now. Thanks, Andrew (303) 378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, November 28, 2018 4:19 PM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Subject: [EXTERNAL]Re: MT6-02 PTD Submission How soon to spud? Sent from my iPhone On Nov 28, 2018, at 3:30 PM, Beat, Andrew T <Andrew.T.Beat@conocophillips.com> wrote: Victoria, We've had a last minute schedule change for Doyon 19 and MT6-07 will no longer follow MT6-09 (current well). Instead, MT6-02 will follow. I will be dropping off the permits later this afternoon for your review. I have also attached the directional text files for you to load. We are drilling a pilot on this well that is a bit different than what we've done in the past so please let me know if you have any questions. I can come by and discuss the submission as well. Thanks, Andrew (303)378-8881 <MT6-02_wp07 Canvas - NAD27.txt> <MT6-02PH_wp07 Canvas - NAD27.txt> TRANSMITTAL LETTER CHECKLIST WELL NAME: T _ 9—d a PH PTD:�$ —q Development V'Service Exploratory _ Stratigraphic Test _ Non -Conventional Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( M-r6— O&PH) and API number (50-_[0'3r -OAO) from records, data and logs acquired for well name on ermit . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.0719 composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool GRTR MOOSES TOOTH, LOOKOUT OIL - 2821 Well Name: MOOSES TOOTH 6-02PH Program SER - Well bore seg ❑ PTD#: 2181590 Company CONOCOPHILLIPS ALASKA. INC. Initial Class/Type SER / PEND GeoArea 890 Unit 10750 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31,05.030(j1_.A),(j.2.A-D) - - - - - - - - - - - - - - - - - - - - NA_ - - - - - - - - - - - - - - - - - - - - - - - _ - - - - - - - - - - - - - - - - - - 1 Permit -fee attached- - - - - - - - - - - - - - - - - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Lease number appropriate Yes 3 Unique well name -and number - - - - _ _ _ _ _ - . _ - - - - - Yes- - .. - . 4 Well located in -a- defined pool - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . .. - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 5 Well located proper distance from_ drilling unit -boundary -- - - - - - - - - - - - - - - - - - .... Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - .. - - - - - - - - - - - - - 6 Well located proper distance from_ other wells- - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - - - - - - - - - - - 7 Sufficient acreage available in -drilling unit _ _ - - - - - - Yes - - - - - - - - - - - - - - - - - - 8 If -de viated, is-wellbore plat included - _ - _ _ _ _ _ No- - _ - Directional_Area of Review is included. _ - --- ----------------------- 9 Operator only affected art p y Yes - - - - - -- - - - - - - - - - - - - . _ _ - - 10 Operator has appropriate bond in force - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - I - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 11 Permit -can be issued without conservation order_ - - - - - - - - - - ----- --- --- ---- Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - 12 Permit_can be issued without ad ministrativ_e_approval - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - DLB 12/5/2018 13 Can permit be approved before 15-day wait_ - - - Yes - - - - 14 Well located within area and strata authorized by -Injection Order # (put_IO# in_comments)_(For_ Yes - - - - - - - AIO_No, 40 applies- - - - - - - - - - - - - - - - - - - - - - - - 15 All wells -within 1/4_mil_e area of review identified (For service well only) - - - - - - - - - - - - - Yes - - - - - - - - - - - . - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre -produced injector: duration of pre production less than 3 months_ (For service well only) Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor string -provided - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - 80_' conductor set- - - - - - - - - - - - - - Engineering 19 Surface casing -protects all -known_ USDWs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes .. - - - - - Surface casing set at 2100' MD 20 CMT-vol_adequate_to circulate -on conductor & surf_csg - - - - - - - - - - - - - Yes - - - - - _ 153%_excess - - - - - - - - - - - - _ - _ - - _ 21 CMT-vol-adequate-to tie-inlong string to surf csg_ No----- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT_will coverall known _productive horizons_ NA_ - - _ _ pilot hole_- no productive interval- - - - - - - - - - - - - - - - 23 Casing designs adequate for C, T, B &_ permafrost_ - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate -tankage or reserve pit - .. - - Yes _ - - - - - _ Rig has steel tanks; all_waste_to approved disposal wells_ 25 If -a- re -drill, has_a 10-403 for abandonment been approved - .. - . - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequate wellbore separation proposed - - - - - - - - - - - . - . - . - - Yes - - - - - - - Anti -collision analysis complete; no major risk failure - - 27 If_diverter required, does it meet regulations- - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Diverter waiver approved per 20 AAC 25.035(h)(2) - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 Drilling fluid_ program schematic & equip list adequate_ _ - - - - - - Yes - - - - - - - Max reservoir pressure is 3810_psig(9,4_ ppg E_M_W); will drill w/ 9A-11.0_ppg EMW_ VTL 12/17/2018 29 BOPES,_do they meet regulation - _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - Yes . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30 BOPE_press rating appropriate; test to_(put psig in comments)- - - - - - - - - - - - - - - - - - - Yes - - - - - - - MPSP is 3015 psig; will test BOPs_to 3500_psig - - - - - - - - _ - - - - - - - - - - - - - 31 Choke -manifold complies w/API_RP-53 (May 84)--- Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown- - - - Yes _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . - - - - - - - - 33 Js presenceofH2S gas_ probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - H2S measures required_ - - - - - - - _ - - . - - - - _ _ _ _ _ _ _ _ 34 Mechanical -condition of wells within AOR verified (For service well only) - _ - - _ - Yes - - - No wells within the 1/4-mile AOR - - - - - - - - - - - - - - - - - - - - 35 Permit can be issued w/o hydrogen sulfide measures - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Only MT6-03 has-been flowed back to date but no H2S was -encountered in that well.- - - - - - - - Geology 36 Data_presented on potential overpressure zones -------- ---------- Yes Drilling fluid program -appears adequate to control -operator's forecast pressures.. Production interval will Appr Date 37 Seismic -analysis of shallow gas -zones --- NA_ be drilled -with 8.8-9.5 ppg_mud_using Managed Pressure DrillingTechnique _ DLB 12/5/2018 38 Seabed condition survey _(if off_ -shore) --- -NA ------------------ ----------------- ------------- --------------------------- 39 Contact name/phone for weekly_ progress reports_ [exploratory only] - - _ - _ _ - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Engineering Public Date: Date Date Commissioner: Commissioner,: ommissio