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219-158
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Well Integrity Specialist CPF1 & CPF3 Cc:Brooks, Phoebe L (OGC); McLellan, Bryan J (OGC); Earhart, Will C Subject:20221107 1434 KRU 3H-01A (PTD 219-158) Report of IA Sustained Casing Pressure Date:Monday, November 7, 2022 2:39:49 PM Attachments:AnnComm Surveillance TIO for 3H-01A.pdf Jan, I have no disagreement with the plan you describe. Please respond when you find the cause of the IA sustained pressure. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). Cc Phoebe, Bryan Will Earhart From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, November 7, 2022 11:30 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3H-01A (PTD 219-158) Report of IA Sustained Casing Pressure Mel, KRU gas lift producer 3H-01A (PTD 219-158) IA pressure was found to be at 2020 psi this weekend after being shut in due to a failed TIFL. The IA’s 5.5”, 15.5 lb/ft, L-80 liner has a burst rating of 7000 psi. Slickline is currently on the well troubleshooting the source of the AnnComm. Once the well has been repaired it will be returned to production under normal well operating guidelines. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 3H-01A 90-Day Bleed HistoryWELL DATE STR-PRES END-PRES DIF-PRES CASING Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod ByLast Tag:3H-01A jennaltLast Rev Reason Annotation Wellbore End Date Last Mod ByRev Reason: Replace OV 3H-01A 10/26/2022 ferguspNotes: General & Safety Annotation End Date Last Mod ByNOTE:9/29/2021 pprovenGeneral Notes: Last 3 entries Com Date Last Mod ByA Lateral slotted liner TOL=8397.23', BOL=11,303'AL1 Lateral slotted liner TOL=7565', BOL=11637.74'1/4/2020 ncdr3cmCasing StringsCsg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB)Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 3,576.7 2,942.5 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 8,076.4 5,970.5 26.00 J-55 BTC 5 1/2" Tie-Back Liner 5 1/2 4.95 35.0 7,046.0 5,378.6 15.50 L-80 HYD 563 A LINER (CTD) 2 3/8 1.99 8,397.2 11,303.0 4.60 L-80 STL Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 35.0 Set Depth … 6,898.4 Set Depth … 5,271.0 String Ma… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.00 Hanger 6.995 3.5" x 11" FMC TUBING HANGER Gen 5 3.500 555.3 553.7 9.43 X Nipple 3.940 2.813" X-Nipple, 9.3#, 9Cr, EUE Box x Pin, SN# 0004556489-4 Halliburt on 2.813 2,912.2 2,489.2 46.00 GAS LIFT 4.726 3.5" x 1" KBG-2-9, LHT 4130, IBT-M Box x Pin, SN# 19394-06 SLB KBG2-9 2.818 4,561.1 3,606.0 46.67 GAS LIFT 4.726 3.5" x 1" KBG-2-9, LHT 4130, IBT-M Box x Pin, SN# 19300-07 SLB KBG2-9 2.818 5,821.1 4,493.8 42.89 GAS LIFT 4.726 3.5" x 1" KBG-2-9, LHT 4130, IBT-M Box x Pin SLB KBG2-9 2.818 6,823.5 5,216.7 43.63 GAS LIFT 4.726 3.5" x 1" KBG-2-9, LHT 4130, IBT-M Box x Pin, SN# 19300-08 SLB KBG2-9 2.818 6,880.6 5,258.1 43.52 Locator 4.500 Baker Locator Baker 2.980 6,881.4 5,258.7 43.52 Seal Assembly 3.980 Baker 80-40 GBH-22 LTSA, 3-1/2" EUE mod Box x 1/2 Mule shoe Baker 2.980 Top (ftKB) 7,043.0 Set Depth … 7,509.7 Set Depth … 5,723.3 String Ma… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMO D ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,065.0 5,392.6 42.61 LOCATOR 4.180 LOCATOR 2.990 7,066.0 5,393.3 42.60 SEAL ASSY 3.750 BAKER 80-40 SEAL ASSEMBLY Baker 80-40 3.000 7,072.2 5,397.9 42.56 PBR 5.010 BAKER 80-40 PBR Baker 80-40 4.000 7,095.2 5,414.9 42.40 PACKER 5.930 BAKER FHL RETRIEVABLE PACKER 47B2 Baker FHL 2.930 7,485.4 5,705.1 41.40 NIPPLE 4.500 DS NIPPLE 2.813 7,503.1 5,718.3 41.30 OVERSHOT 4.510 BAKER POOR BOY OVERSHOT Baker Poorboy Oversho t 3.750 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,912.2 2,489.2 46.00 1 GAS LIFT GLV BTM 1 1,252.0 9/17/2021 Camco KBG-2 0.188 4,561.1 3,606.0 46.67 2 GAS LIFT GLV BTM 1 1,252.0 9/6/2021 Camco KBG2-9 0.188 5,821.1 4,493.8 42.89 3 GAS LIFT OV BTM 1 0.0 10/26/2022 Camco KBG2-9 0.250 6,823.5 5,216.7 43.63 4 GAS LIFT DMY BTM 1 9/5/2021 Camco KBG2-9 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,920.2 5,286.8 43.39 GAS LIFT 4.726 3.5" x 1" KBG-2-9, LHT 4130, 9.20#, IBT-M Box x Pin. SN#19300-09 3.5" 9.3# L- 80 8rd EUE, 10 2.818 6,947.3 5,306.5 43.28 X Nipple 3.938 2.813" X-Nipple 3.5" 9.3# L- 80 8rd EUE, 10 2.813 7,017.6 5,357.8 42.93 Nipple D 3.500 2.75" D-Nipple 2.750 7,039.3 5,373.7 42.78 Overshot 3.500 3.5" 9.3# L-80 8rd EUE W/Poor Boy Overshot 2.992 8,397.2 5,934.6 92.64 WVCASCOMP 8,397.2 5,934.6 92.64 ALUMINUM BILLET 2.630 Aluminum Liner Top Billet BOT Billet 1.920 9,390.2 5,942.7 88.29 DEPLOYMENT SLEEVE 2.375 Shorty Deployment Sleeve Baker 1.920 10,307.7 5,961.3 93.32 DEPLOYMENT SLEEVE 2.375 Shorty Deployment Sleeve Baker 1.920 3H-01A, 10/28/2022 1:41:23 PMVertical schematic (actual) AL1 LINER (CTD); 7,564.7- 11,637.7 A LINER (CTD); 8,397.2- 11,303.0 SHOE; 11,302.6-11,303.0 DEPLOYMENT SLEEVE; 10,657.9-10,658.3 SHOE; 10,627.2-10,657.9 DEPLOYMENT SLEEVE; 10,307.6-10,308.5 SHOE; 10,307.2-10,307.6 DEPLOYMENT SLEEVE; 9,442.2-9,442.6 SHOE; 9,411.9-9,442.2 DEPLOYMENT SLEEVE; 9,390.2-9,391.1 SHOE; 9,389.8-9,390.2 ALUMINUM BILLET; 8,397.2- 8,406.2 PRODUCTION; 33.0-8,076.4 FLOAT SHOE; 8,074.5-8,076.4 FLOAT COLLAR; 7,986.4- 7,988.3 DEPLOYMENT SLEEVE; 7,854.5-7,854.9 SHOE; 7,852.8-7,854.5 XO Threads (Casing); 7,849.9- 7,852.8 XO Threads (Casing); 7,835.1- 7,849.9 SWELL PACKER; 7,834.2- 7,835.1 XO Threads (Casing); 7,830.4- 7,834.2 XO Threads (Casing); 7,815.6- 7,830.4 Whipstock; 7,762.0 APERF; 7,758.0-7,770.0 IPERF; 7,722.0-7,730.0 Cement Squeeze; 7,680.0 ftKB RPERF; 7,684.0-7,752.0 IPERF; 7,712.0-7,716.0 SOS; 7,613.8 NIPPLE; 7,581.3 TUBING PUNCH; 7,565.0 DEPLOYMENT SLEEVE w/6' SEALBORE RECEPTICAL (PBR); 7,564.7-7,565.3 Norther Solutions LTP; 7,560.0 PACKER; 7,543.3 PBR; 7,529.5 OVERSHOT; 7,503.1 Cement Plug; 7,491.0 ftKB NIPPLE; 7,485.4 PACKER; 7,095.2 PBR; 7,072.2 SEAL ASSY; 7,066.0 LOCATOR; 7,065.0 5 1/2" Tie-Back Liner; 35.0- 7,046.0 Overshot; 7,039.3-7,046.0 Tubing ; 7,018.8-7,039.3 Nipple D; 7,017.6-7,018.8 Tubing -Pup; 6,986.8-7,017.6 Tubing -Pup; 6,976.7-6,986.8 Packer (Tubing); 6,968.4- 6,976.7 Tubing -Pup; 6,948.4-6,968.4 X Nipple ; 6,947.3-6,948.4 Tubing -Pup; 6,926.7-6,947.3 GAS LIFT; 6,920.2-6,926.7 Tubing -Pup; 6,910.6-6,920.2 XO Reducing (Tubing); 6,906.4- 6,910.6 Tubing -Pup; 6,903.5-6,906.4 SBE (Seal Bore Extension); 6,883.5-6,903.5 Seal Assembly; 6,881.4 Locator; 6,880.6 Tubing -Pup; 6,877.6-6,883.5 GAS LIFT; 6,823.5 GAS LIFT; 5,821.1 GAS LIFT; 4,561.1 SURFACE; 35.0-3,576.7 FLOAT SHOE; 3,574.8-3,576.7 FLOAT COLLAR; 3,494.4- 3,496.0 Tubing; 80.3-6,877.6GAS LIFT; 2,912.2X Nipple ; 555.3CONDUCTOR; 36.0-115.0Tubing -Pup; 52.9-80.3Tubing; 35.0-52.9HANGER; 35.0-39.5Hanger; 35.0 KUP PROD KB-Grd (ft)42.01 RR Date1/5/2020 Other Elev…3H-01A...TDAct Btm (ftKB)11,303.0Well AttributesField NameKUPARUK RIVER UNIT Wellbore API/UWI501032008401 Wellbore StatusPROD Max Angle & MDIncl (°)98.22 MD (ftKB)8,236.29WELLNAME WELLBORE3H-01AAnnotationLast WO:End Date9/2/2021H2S (ppm)200 Date5/2/2019Comment V-ro--c-1 Z4 -01A Fl-� z t -q Regg, James B (CED) From: NSK Prod Engr Specialist <nl 139@conocophillips.com> Sent: Wednesday, October 27, 2021 1:38 PM '�C I C' Z(L-e To: Regg, James B (CED); Cook, Guy D (CED) Cc: NSK Prod Engr Specialist; NSK Fieldwide Operations Supt Subject: 31-1-01 new sign Attachments: 31-1-01A Deficiency Report.pdf Jim, Provided below is the corrected well house signage for 3H-01, I also provided a copy of the Deficiency Report from Guy Cook. Regards, Doug Doug McMullen /Darrell Humphrey Production Engineering Specialist .J ConocoPhillips Alaska CP: 907.315.3601 Ph: 907.659.7535 1 Pg: 924 1 Mail: NSK 69 1 350u= ��Mll IMM • by any other party kd • wrl' ten consent �oPhillips Alaska, In ilIM]II11111 State of Alaska Oil and Gaas Consfervation Commission Deficiency Reeport Location-, KRU 3--H-01A Date. 9/17/2021 PTL: 2191580 I Operator: Conoco/Phillips Alaska Type Inspection: SVS Operator Rep: Doug McMullen Inspector: Guy Cook Position: Proiducti6n Engineering Specialist Op. Phone: 907-659-7535 Correct by (date): 10/17,12022 Op. Email: -w Up R-eq'd: Yes Detailed Description of Deficiencies Date Correcte The wellhouse sign on KRU 3H -01A has-, the incorrect Permit to Drill number. Please refer to - - Alaska 00 and Qs Laws and Regulations 20 AAC 25.M /0 /3 0 12 1 Attachments:1 Operator Signatures - Rep AO CC inspector After signIng, a copy cbrit, be left w0 the operator. Follow-up instructions a COPY Of this Def -"C enr----p' REPuilt 70 AGGCC jAttention. In&pecjon ,,eTviso) l�df etDwrereipt� Irflu Corrected" and attach eacb corrective action innpleinented `o address the def; ien -je inspection was performed 11-y AC)GCC, ir-lude thin date and name of Inspeacii% Extensio, s3 5 -s� it a follow- p `he iCorrec" by" Late mus" hp n-Wnted ano accompanied bry justificetion fAttef-ItI00- tnSPFct'On Oervilor], Documentation of defidences qia,, are of oft CC reguia cry Jurisdiction will be forwarded to the aooroorj-3te aui-efority for fojj0%,-up action. J�� 47', 1 tc-v Revised 7j2019 Regg, James B (CED) From: Regg, James B (CED) Sent: Thursday, October 14, 2021 9:41 AM To: McMullen, Doug j��i4/ Z✓I Cc: Cook, Guy D (CED) Subject: RE: 3H -01A Deficiencies Report Please provide photos when new signs have been installed.. Jim Regg Supervisor, Inspections AOGCC 333 W. 711 Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: McMullen, Doug <Doug.McMullen@conocophilIips.com> Sent: Tuesday, September 21, 20213:28 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Cook, Guy D (CED) <guy.cook@alaska.gov> Subject: 3H -01A Deficiencies Report Good afternoon Mr. Regg, Attached is the Deficiencies Report for 3H -01A. The request for the new sign with the corrected PTD number for this well has been placed. I have also ordered the new signs for the wells currently being worked over on 3-H also. Regards Doug McMullen / Darrell Humphrey Production Engineering Specialist onocoPhiliip Alaska Office: 907.659.7535 1 Pg: 924 1 Mail: NSK 69 Cell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y Meredith Guhl at 12:54 pm, Sep 30, 2021 VTL 01/24/2022 DSR-9/30/21 SFD 10/6/2021RBDMS HEW 10/1/2021 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 7,764.0 11/9/2019 3H-01 condijw Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Cut Tubing 8/26/2021 3H-01 bworthi1 Tubing Strings Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,504.7 Set Depth (ft… 7,614.6 Set Depth (TVD) (… 5,802.4 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,529.5 5,738.2 41.17 PBR BAKER PBR 3.000 7,543.3 5,748.5 41.10 PACKER BAKER 'FHL' PACKER 2.937 7,581.3 5,777.2 40.91 NIPPLE CAMCO 'D' NIPPLE NO GO ******( MILL D NIPPLE TO 2.80" )*********** 2.800 7,613.8 5,801.8 40.80 SOS CAMCO SHEAROUT SUB 2.937 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,560.0 5,761.1 41.02 Norther Solutions LTP 2.72" Northern Solutions Liner Top Packer w/ 1.781" R-Nipple (8.29' OAL) 1/10/2020 1.781 7,565.0 5,764.9 41.00 TUBING PUNCH TUBING PUNCH, 4 FT INTERVAL, 4 SPF, 16 SHOTS TOTAL 11/10/2019 2.992 7,762.0 5,914.4 39.97 Whipstock 3.5" MB XL Whipstock w/OHA 12/20/2019 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,684.0 7,752.0 5,855.0 5,906.8 UNIT D, C-4, C- 3, 3H-01 8/21/1988 12.0 RPERF 2 1/8" EnerJet; 60 deg. ph 7,712.0 7,716.0 5,876.2 5,879.3 C-4, 3H-01 12/3/1987 2.0 IPERF 4" Densi Jet; 120 deg. ph 7,722.0 7,730.0 5,883.8 5,889.9 C-4, 3H-01 12/3/1987 2.0 IPERF 4" Densi Jet; 120 deg. ph 7,758.0 7,770.0 5,911.4 5,920.6 A-3, 3H-01 8/21/1988 8.0 APERF 2 1/8" EnerJet; 60 deg. ph 7,782.0 7,800.0 5,929.8 5,943.6 A-2, 3H-01 8/21/1988 8.0 APERF 2 1/8" EnerJet; 60 deg. ph 7,822.0 7,840.0 5,960.4 5,974.2 A-1, 3H-01 5/21/1988 8.0 APERF 2.5" Scallop; 90 deg. ph 7,860.0 10,659.0 5,989.5 A2, A3, 3H-01 1/4/2020 SLOTS Slotted Liner 3H-01A 9,442.6 11,637.0 A2, A3, 3H-01 1/4/2020 SLOTS Slotted Liner 3H-01L1 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,680.0 8,100.0 5,852.0 6,173.5 Cement Squeeze 12/18/2019 7,491.0 8,100.0 5,709.2 6,173.5 Cement Plug 12/18/2019 Notes: General & Safety End Date Annotation 7/7/2007 NOTE: WAIVERED WELL - IA X OA COMMUNICATION 3H-01, 9/29/2021 1:13:30 PM Vertical schematic (actual) SLOTS; 7,860.0-10,659.0 SLOTS; 9,442.6-11,637.0 Cement Squeeze; 7,680.0 ftKB APERF; 7,822.0-7,840.0 APERF; 7,782.0-7,800.0 Whipstock; 7,762.0 APERF; 7,758.0-7,770.0 PRODUCTION; 33.0-8,076.4 AL1 LINER (CTD); 7,564.7- 11,637.7 IPERF; 7,722.0-7,730.0 RPERF; 7,684.0-7,752.0 IPERF; 7,712.0-7,716.0 SOS; 7,613.8 NIPPLE; 7,581.3 TUBING PUNCH; 7,565.0 Norther Solutions LTP; 7,560.0 PACKER; 7,543.3 PBR; 7,529.5 OVERSHOT; 7,503.1 Cement Plug; 7,491.0 ftKB NIPPLE; 7,485.4 PACKER; 7,095.2 PBR; 7,072.2 SEAL ASSY; 7,066.0 LOCATOR; 7,065.0 5 1/2" Tie-Back Liner; 35.0- 7,046.0 Seal Assembly; 6,881.4 Locator; 6,880.6 GAS LIFT; 6,823.5 GAS LIFT; 5,821.1 GAS LIFT; 4,561.1 SURFACE; 35.0-3,576.7 GAS LIFT; 2,912.2 X Nipple ; 555.3 CONDUCTOR; 36.0-115.0 Hanger; 35.0 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 1/5/2020 3H-01 ... TD Act Btm (ftKB) 8,167.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032008400 Wellbore Status PROD Max Angle & MD Incl (°) 48.55 MD (ftKB) 3,900.00 WELLNAME WELLBORE3H-01A Annotation Last WO: End Date 4/11/2015 H2S (ppm) 200 Date 5/2/2019 Comment SSSV: NONE Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:3H-01A jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replaced GLV 9/17/2021 3H-01A zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 3,576.7 Set Depth (TVD) … 2,942.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,076.4 Set Depth (TVD) … 5,970.5 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description 5 1/2" Tie-Back Liner OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 35.0 Set Depth (ftKB) 7,046.0 Set Depth (TVD) … 5,378.6 Wt/Len (l… 15.50 Grade L-80 Top Thread HYD 563 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 35.0 35.0 0.00 Tubing 5.5", 15.5#,L-80 HYD563 MS (5.873" Coupling) SpaceOut W/Slips installed. 4.950 80.3 80.2 0.39 Tubing 5.5", 15.5#,L-80 HYD563 MS (5.873" Coupling) 4.950 6,883.5 5,260.1 43.51 SBE (Seal Bore Extension) Seal Bore Receptacle 80-40 x 20' w/ 5" H521 P x 4.5" H521 B 4.000 6,906.4 5,276.8 43.45 XO Reducing (Tubing) 4.5" 12.6# H563 Box x 3.5" 9.3# EUE Pin Cross over 3.958 6,920.2 5,286.8 43.39 GLM 3.5" x 1" KBG-2-9, LHT 4130, 9.20#, IBT-M Box x Pin. SN#19300-09 2.818 6,947.3 5,306.5 43.28 X Nipple 2.813" X-Nipple 2.813 6,968.4 5,321.8 43.19 Packer (Tubing) 3.5" x 7" Premier Packer, Hydraulic Set 2.992 7,017.6 5,357.8 42.93 Nipple D 2.75" D-Nipple 2.750 7,018.8 5,358.7 42.92 Tubing 3.5" 9.3# L-80 8rd EUE 2.992 7,039.3 5,373.7 42.78 Overshot 3.5" 9.3# L-80 8rd EUE W/Poor Boy Overshot 2.992 Casing Description A LINER (CTD) OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 8,397.2 Set Depth (ftKB) 11,303.0 Set Depth (TVD) … Wt/Len (l… 4.60 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,397.2 5,934.6 92.64 WVCASCOMP 8,397.2 5,934.6 92.64 ALUMINUM BILLET Aluminum Liner Top Billet 1.920 9,390.2 5,942.7 88.29 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.920 10,307.7 5,961.3 93.32 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.920 Tubing Strings Tubing Description Tubing – Completion Upper String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 35.0 Set Depth (ft… 6,898.4 Set Depth (TVD) (… 5,271.0 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 35.0 35.0 0.00 Hanger 3.5" x 11" FMC TUBING HANGER Gen 5 3.500 555.3 553.7 9.43 X Nipple 2.813" X-Nipple, 9.3#, 9Cr, EUE Box x Pin, SN# 0004556489-4 2.813 6,880.6 5,258.1 43.52 Locator Baker Locator 2.980 6,881.4 5,258.7 43.52 Seal Assembly Baker 80-40 GBH-22 LTSA, 3-1/2" EUE mod Box x 1/2 Mule shoe 2.980 Tubing Description Tubing – Completion Lower String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,043.0 Set Depth (ft… 7,509.7 Set Depth (TVD) (… 5,723.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,065.0 5,392.6 42.61 LOCATOR LOCATOR 2.990 7,066.0 5,393.3 42.60 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 7,072.2 5,397.9 42.56 PBR BAKER 80-40 PBR 4.000 7,095.2 5,414.9 42.40 PACKER BAKER FHL RETRIEVABLE PACKER 47B2 2.930 7,485.4 5,705.1 41.40 NIPPLE DS NIPPLE 2.813 7,503.1 5,718.3 41.30 OVERSHOT BAKER POOR BOY OVERSHOT 3.750 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,912.2 2,489.2 46.00 SLB KBG2-9 1 GAS LIFT GLV BTM 0.188 1,252.0 9/17/2021 2 4,561.1 3,606.0 46.67 SLB KBG2-9 1 GAS LIFT GLV BTM 0.188 1,252.0 9/6/2021 3 5,821.1 4,493.8 42.89 SLB KBG2-9 1 GAS LIFT OV BTM 0.250 0.0 9/6/2021 4 6,823.5 5,216.7 43.63 SLB KBG2-9 1 GAS LIFT DMY BTM 0.000 9/5/2021 Notes: General & Safety End Date Annotation 9/29/2021 NOTE: 3H-01A, 9/29/2021 1:13:32 PM Vertical schematic (actual) AL1 LINER (CTD); 7,564.7- 11,637.7 A LINER (CTD); 8,397.2- 11,303.0 PRODUCTION; 33.0-8,076.4 Whipstock; 7,762.0 APERF; 7,758.0-7,770.0 IPERF; 7,722.0-7,730.0 Cement Squeeze; 7,680.0 ftKB RPERF; 7,684.0-7,752.0 IPERF; 7,712.0-7,716.0 SOS; 7,613.8 NIPPLE; 7,581.3 TUBING PUNCH; 7,565.0 Norther Solutions LTP; 7,560.0 PACKER; 7,543.3 PBR; 7,529.5 OVERSHOT; 7,503.1 Cement Plug; 7,491.0 ftKB NIPPLE; 7,485.4 PACKER; 7,095.2 PBR; 7,072.2 SEAL ASSY; 7,066.0 LOCATOR; 7,065.0 5 1/2" Tie-Back Liner; 35.0- 7,046.0 Seal Assembly; 6,881.4 Locator; 6,880.6 GAS LIFT; 6,823.5 GAS LIFT; 5,821.1 GAS LIFT; 4,561.1 SURFACE; 35.0-3,576.7 GAS LIFT; 2,912.2 X Nipple ; 555.3 CONDUCTOR; 36.0-115.0 Hanger; 35.0 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 1/5/2020 3H-01A ... TD Act Btm (ftKB) 11,303.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032008401 Wellbore Status PROD Max Angle & MD Incl (°) 98.22 MD (ftKB) 8,236.29 WELLNAME WELLBORE3H-01A Annotation Last WO: End DateH2S (ppm) 200 Date 5/2/2019 Comment Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:3H-01AL1 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: CTD LATERAL 1/22/2020 3H-01AL1 jennalt Casing Strings Casing Description AL1 LINER (CTD) OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 7,564.7 Set Depth (ftKB) 11,637.7 Set Depth (TVD) … 5,974.9 Wt/Len (l… 4.70 Grade L-80 Top Thread Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,564.7 5,764.7 41.00 DEPLOYMENT SLEEVE w/6' SEALBORE RECEPTICAL (PBR) Deployment Sleeve w/6' Sealbore Receptical (PBR) 2.375 7,834.2 5,961.5 60.87 SWELL PACKER Swell Packer - Halliburton 1.686 7,854.5 5,970.2 68.07 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.920 9,442.2 5,933.6 90.53 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.920 10,657.9 5,985.1 89.21 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.920 3H-01AL1, 9/29/2021 1:13:33 PM Vertical schematic (actual) AL1 LINER (CTD); 7,564.7- 11,637.7 A LINER (CTD); 8,397.2- 11,303.0 PRODUCTION; 33.0-8,076.4 Whipstock; 7,762.0 APERF; 7,758.0-7,770.0 IPERF; 7,722.0-7,730.0 Cement Squeeze; 7,680.0 ftKB RPERF; 7,684.0-7,752.0 IPERF; 7,712.0-7,716.0 SOS; 7,613.8 NIPPLE; 7,581.3 TUBING PUNCH; 7,565.0 Norther Solutions LTP; 7,560.0 PACKER; 7,543.3 PBR; 7,529.5 OVERSHOT; 7,503.1 Cement Plug; 7,491.0 ftKB NIPPLE; 7,485.4 PACKER; 7,095.2 PBR; 7,072.2 SEAL ASSY; 7,066.0 LOCATOR; 7,065.0 5 1/2" Tie-Back Liner; 35.0- 7,046.0 Seal Assembly; 6,881.4 Locator; 6,880.6 GAS LIFT; 6,823.5 GAS LIFT; 5,821.1 GAS LIFT; 4,561.1 SURFACE; 35.0-3,576.7 GAS LIFT; 2,912.2 X Nipple ; 555.3 CONDUCTOR; 36.0-115.0 Hanger; 35.0 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 1/5/2020 3H-01AL1 ... TD Act Btm (ftKB) 11,648.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032008460 Wellbore Status PROD Max Angle & MD Incl (°) 98.22 MD (ftKB) 8,236.29 WELLNAME WELLBORE3H-01A Annotation Last WO: End DateH2S (ppm) 200 Date 5/2/2019 Comment Page 1/3 3H-01 Report Printed: 9/29/2021 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/27/2021 19:00 8/28/2021 00:00 5.00 MIRU, MOVE MOB P PJSM, RAISE SUB, REMOVE RIG MATTING, MOVE SUB OFF 3H-31 MOVE RIG MATS & PIT LINER. RIG RELEASED AT 1900HRS 8-27-21 0.0 0.0 8/28/2021 00:00 8/28/2021 06:00 6.00 MIRU, MOVE MOB P Move to 3H-01 Spot sub, Spot pits, lay out containment, berm in rig. 7ES Accepted @ 0600 Hrs. 8/28/2021 0.0 0.0 8/28/2021 06:00 8/28/2021 08:00 2.00 MIRU, MOVE RURD P Rig up service line & electrical cables in the interconnect, Take on 290 bbl. 9.7 NaCl brine 0.0 0.0 8/28/2021 08:00 8/28/2021 09:00 1.00 MIRU, WELCTL MPSP P Verify I/A and Tbg. Has 0 pressure, PT BPV from below to 1000 psi. 10 min (Good Test) 0.0 0.0 8/28/2021 09:00 8/28/2021 12:00 3.00 MIRU, WELCTL NUND P N/D Tree and adaptor flange, Inspect threads on hanger with FMC Rep. 0.0 0.0 8/28/2021 12:00 8/28/2021 13:00 1.00 MIRU, WHDBOP MPSP P Install blanking plug 0.0 0.0 8/28/2021 13:00 8/28/2021 19:00 6.00 MIRU, WHDBOP NUND P N/U BOPE, 0.0 0.0 8/28/2021 19:00 8/28/2021 21:30 2.50 MIRU, WHDBOP RURD P Change lower pipe rams to 3 ½ x 5 ½ VBR 0.0 0.0 8/28/2021 21:30 8/29/2021 00:00 2.50 MIRU, WHDBOP BOPE P R/U Test BOPE 250/3500 psi. AOGCC Rep. Jeff Jones Waived to witness Test 0.0 0.0 8/29/2021 00:00 8/29/2021 05:00 5.00 MIRU, WHDBOP BOPE P Tested BOPE 250/3000 psi. AOGCC Rep. Jeff Jones Waived to witness Test 0.0 8/29/2021 05:00 8/29/2021 05:30 0.50 MIRU, WHDBOP BOPE P Completed BOP test. L/D test joint, clear and clean rig floor. 8/29/2021 05:30 8/29/2021 07:15 1.75 MIRU, WHDBOP MPSP P PTSM with day crew. Pull BPV and L/D same. Tested Rig Alarms. 8/29/2021 07:15 8/29/2021 07:45 0.50 COMPZN, RPCOMP OWFF P Observe well for flow for 30 minutes 8/29/2021 07:45 8/29/2021 09:00 1.25 COMPZN, RPCOMP THGR P MU and Install landing Joint. Screw into hanger, BOLDS, unseat tubing hanger and pull same to Rig floor and L/D hanger. Unseated Hanger at 85K up weight. 8/29/2021 09:00 8/29/2021 12:30 3.50 COMPZN, RPCOMP PULL P Pulled 6 Joints and L/D same. PU WT 78K. Load Storm packer to rig floor and MU same. RIH with storm packer and set packer at ~112' ft on Drill Pipe. PT Packer to 1000 psi and hold for 10 minutes. (Good Test) 8/29/2021 12:30 8/30/2021 00:00 11.50 MIRU, WHDBOP NUND P ND BOPE & 7" Tubing Spool. NU New 11" Tubing Spool. NU BOPE 8/30/2021 00:00 8/30/2021 00:30 0.50 MIRU, WHDBOP PULD P PU & Install Test Tools. 8/30/2021 00:30 8/30/2021 02:00 1.50 MIRU, WHDBOP PRTS P Test BOPS, Kill Line and break on stack. 250/3000 psi for 10/30 MINs 8/30/2021 02:00 8/30/2021 04:00 2.00 MIRU, WHDBOP PULL P Pump out stack and pull test plug. MU retrieve tool, pull storm packer and L/D same. 8/30/2021 04:00 8/30/2021 06:00 2.00 MIRU, WHDBOP PULL P POOH laying down 3.5" completion. 8/30/2021 06:00 8/30/2021 07:00 1.00 COMPZN, RPCOMP SVRG P PTSM with Day Crew. Remove tubing from pipe shed. Service Rig. 8/30/2021 07:00 8/30/2021 18:00 11.00 COMPZN, RPCOMP PULL P POOH laying down 3.5" completion. Maintaining proper hole fill. 8/30/2021 18:00 8/30/2021 23:00 5.00 COMPZN, RPCOMP PUTB P Load Pipe shed with 5.5", 15.5#,L-80 HYD563 MS (5.873" Coupling) Strap and Tally Rig: NABORS 7ES RIG RELEASE DATE 9/3/2021 Page 2/3 3H-01 Report Printed: 9/29/2021 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/30/2021 23:00 8/31/2021 00:00 1.00 COMPZN, RPCOMP RURD P R/U weatherford casing equipment. 8/31/2021 00:00 8/31/2021 01:00 1.00 COMPZN, RPCOMP PUTB P Rack and Tally 3 1/2" x 5 1/2" Tie back completion 8/31/2021 01:00 8/31/2021 03:00 2.00 COMPZN, RPCOMP RURD P R/U Weatherford casing equipment. 8/31/2021 03:00 8/31/2021 06:00 3.00 COMPZN, RPCOMP RCST P Run Lower 3.5" Tie back completion with overshot, D-Nipple, Premier Packer, X-Nipple, GLM,and SBR. 8/31/2021 06:00 8/31/2021 17:30 11.50 COMPZN, RPCOMP RCST P C/O handling equipment from 3.5" to 5.5" and start RIH with 5.5" TBG and space out same. RD down casing running equipment and RU testing equipment to set Packer. Tagged 3 1/2" tubing top @ 7028' 7ES RKB. Sheared screws, no-go @ 7033'. P/U T/ 7031'. 8/31/2021 17:30 8/31/2021 18:00 0.50 COMPZN, RPCOMP PACK P Pressure up to set packer on tie-back liner T/ 3500 PSI. 8/31/2021 18:00 8/31/2021 19:30 1.50 COMPZN, RPCOMP PRTS P Bleed off T/ 3000 PSI and tested tubing for 30 min - Good test. Bled pressure off tubing and tested backside T/ 2500 PSI for 30 min - good test. 8/31/2021 19:30 8/31/2021 22:00 2.50 COMPZN, RPCOMP PACK P R/D testing equipment. M/U model G retrievable bridge plug and set 62' 8/31/2021 22:00 8/31/2021 22:30 0.50 COMPZN, RPCOMP PRTS P R/U testing equipment and test plug T/ 1000 PSI for 10 min - good test 8/31/2021 22:30 9/1/2021 00:00 1.50 COMPZN, RPCOMP RURD P Drain stack. Suck out 5 1/2" liner T/ wellhead. Pull riser. 9/1/2021 00:00 9/1/2021 01:00 1.00 COMPZN, RPCOMP RURD P ND BOPE and raise stack. 9/1/2021 01:00 9/1/2021 01:30 0.50 COMPZN, RPCOMP WWSP P Set emergency Slips. 9/1/2021 01:30 9/1/2021 05:00 3.50 COMPZN, RPCOMP CPBO P Cut 5.5" Liner W/Wachs saw. 9/1/2021 05:00 9/1/2021 06:30 1.50 COMPZN, RPCOMP RURD P Rack BOPE. ND Spacer spool and DSA 9/1/2021 06:30 9/1/2021 08:00 1.50 COMPZN, RPCOMP WWSP P Dress cut and install pack offs. 9/1/2021 08:00 9/1/2021 16:00 8.00 COMPZN, RPCOMP WWSP P RU CSG Spool,DSA and BOPE. 9/1/2021 16:00 9/1/2021 18:00 2.00 COMPZN, RPCOMP PRTS P RU Test equipment and PT Break, spool, DSA and chart for 30 minutes 9/1/2021 18:00 9/1/2021 19:30 1.50 COMPZN, RPCOMP PULL P Load and MU tools to pull RBP. RIH with pulling assembly and pull RBP. 9/1/2021 19:30 9/1/2021 20:30 1.00 COMPZN, RPCOMP RURD P R/U 3 1/2" tubing equipment. Verify joint count and jewelry order in pipe shed. PJSM w/ rig crew. 9/1/2021 20:30 9/2/2021 00:00 3.50 COMPZN, RPCOMP RCST P RIH w/ 3 1/2", 9.3#, L-80, EUE-M upper completions string T/ 2995', P/U=45K, S/O=45K 0.0 2,995.0 9/2/2021 00:00 9/2/2021 04:30 4.50 COMPZN, RPCOMP RCST P RIH w/ 3 1/2", 9.3#, L-80, EUE-M upper completions string F/ 2995' T/6895'. NO GO with 10K DN. SBR-16' in on Joint 219. PU WT 82K SO WT 60K. 2,995.0 6,895.0 9/2/2021 04:30 9/2/2021 05:30 1.00 COMPZN, RPCOMP HOSO P Space out. Lay down Joint # 219 # 218. PU 8.27' & 10.25 PuPs and Joint # 217. 6,895.0 6,895.0 9/2/2021 05:30 9/2/2021 06:00 0.50 COMPZN, RPCOMP THGR P Landed Hanger and RILDS. PU WT 82k / SO WT 60k. RKB=21.28 TOT. 217 total joints ran. 6,895.0 6,895.0 Rig: NABORS 7ES RIG RELEASE DATE 9/3/2021 Page 3/3 3H-01 Report Printed: 9/29/2021 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/2/2021 06:00 9/2/2021 08:30 2.50 COMPZN, RPCOMP PRTS P RU testing equipment. Test TBG to 3000 psi and chart same for 30 minutes. Test IA to 2500 psi and chart same for 30 minutes. (Good Test on Both). Dump psi on tubing to shear the SOV. Confirmed circulation through SOV. 6,895.0 6,895.0 9/2/2021 08:30 9/2/2021 09:30 1.00 COMPZN, RPCOMP MPSP P Install 'H' BPV and test same down IA thru SOV to 1000 psi for 10 minutes. 6,895.0 6,895.0 9/2/2021 09:30 9/2/2021 10:30 1.00 COMPZN, RPCOMP SVRG P Clean and Clear Rig floor. Clean Upper Bushing. 6,895.0 6,895.0 9/2/2021 10:30 9/2/2021 15:30 5.00 COMPZN, RPCOMP RURD P Drain Stack and ND BOPE. 6,895.0 6,895.0 9/2/2021 15:30 9/2/2021 17:30 2.00 COMPZN, RPCOMP WWSP P NU TBG head adapter. NU new 3 1/2" tree. 6,895.0 6,895.0 9/2/2021 17:30 9/2/2021 18:00 0.50 COMPZN, RPCOMP PRTS P Install test dart and pressure test tree and TBG hanger packoffs to 250/5000 psi. Test dart pulled after test. 6,895.0 6,895.0 9/2/2021 18:00 9/2/2021 23:00 5.00 DEMOB, MOVE DMOB P RD secondary containment. Prep Rig to move to next well. Pick up cellar and secure. 6,895.0 6,895.0 9/2/2021 23:00 9/3/2021 00:00 1.00 DEMOB, MOVE MOB P Pick up cellar and secure. *****Rig Released from 3H-01 @ Midnight**** 6,895.0 6,895.0 Rig: NABORS 7ES RIG RELEASE DATE 9/3/2021 ! 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Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 7,764.0 11/9/2019 3H-01 condijw Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull Catcher & Plug 12/1/2020 3H-01 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 3,576.7 Set Depth (TVD) … 2,942.4 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,076.4 Set Depth (TVD) … 6,155.4 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING - 2015 WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.0 Set Depth (ft… 7,509.7 Set Depth (TVD) (… 5,723.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.0 31.0 0.67 HANGER FMC TUBING HANGER 2.992 7,065.0 5,392.6 42.61 LOCATOR LOCATOR 2.990 7,066.0 5,393.3 42.60 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 7,072.2 5,397.9 42.56 PBR BAKER 80-40 PBR 4.000 7,095.2 5,414.8 42.40 PACKER BAKER FHL RETRIEVABLE PACKER 47B2 2.930 7,485.4 5,705.0 41.40 NIPPLE DS NIPPLE 2.813 7,503.1 5,718.3 41.30 OVERSHOT BAKER POOR BOY OVERSHOT 3.750 Tubing Description TUBING - ORIGINAL String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,504.7 Set Depth (ft… 7,614.6 Set Depth (TVD) (… 5,802.4 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,529.5 5,738.2 41.17 PBR BAKER PBR 3.000 7,543.3 5,748.5 41.10 PACKER BAKER 'FHL' PACKER 2.937 7,581.3 5,777.2 40.91 NIPPLE CAMCO 'D' NIPPLE NO GO ******( MILL D NIPPLE TO 2.80" )*********** 2.800 7,613.8 5,801.8 40.80 SOS CAMCO SHEAROUT SUB 2.937 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,560.0 5,761.1 41.02 Norther Solutions LTP 2.72" Northern Solutions Liner Top Packer w/ 1.781" R-Nipple (8.29' OAL) 1/10/2020 1.781 7,565.0 5,764.9 41.00 TUBING PUNCH TUBING PUNCH, 4 FT INTERVAL, 4 SPF, 16 SHOTS TOTAL 11/10/2019 2.992 7,762.0 5,914.4 39.97 Whipstock 3.5" MB XL Whipstock w/OHA 12/20/2019 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,684.0 7,752.0 5,855.0 5,906.8 UNIT D, C-4, C- 3, 3H-01 8/21/1988 12.0 RPERF 2 1/8" EnerJet; 60 deg. ph 7,712.0 7,716.0 5,876.2 5,879.3 C-4, 3H-01 12/3/1987 2.0 IPERF 4" Densi Jet; 120 deg. ph 7,722.0 7,730.0 5,883.8 5,889.9 C-4, 3H-01 12/3/1987 2.0 IPERF 4" Densi Jet; 120 deg. ph 7,758.0 7,770.0 5,911.4 5,920.6 A-3, 3H-01 8/21/1988 8.0 APERF 2 1/8" EnerJet; 60 deg. ph 7,782.0 7,800.0 5,929.8 5,943.6 A-2, 3H-01 8/21/1988 8.0 APERF 2 1/8" EnerJet; 60 deg. ph 7,822.0 7,840.0 5,960.4 5,974.2 A-1, 3H-01 5/21/1988 8.0 APERF 2.5" Scallop; 90 deg. ph 7,860.0 10,659.0 5,989.5 A2, A3, 3H-01 1/4/2020 SLOTS Slotted Liner 3H-01A 9,442.6 11,637.0 A2, A3, 3H-01 1/4/2020 SLOTS Slotted Liner 3H-01L1 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,680.0 8,100.0 5,852.0 6,173.5 Cement Squeeze 12/18/2019 7,491.0 8,100.0 5,709.2 6,173.5 Cement Plug 12/18/2019 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,935.6 2,505.5 46.09 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 11/17/2020 2 4,636.9 3,657.9 46.77 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,238.0 4/24/2015 3 5,900.9 4,552.4 42.59 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 11/20/2020 4 6,516.6 4,996.6 44.88 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/17/2015 5 7,008.7 5,351.3 42.99 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/24/2015 Notes: General & Safety End Date Annotation 7/7/2007 NOTE: WAIVERED WELL - IA X OA COMMUNICATION 3H-01, 6/17/2021 8:35:56 AM Vertical schematic (actual) SLOTS; 9,442.6-11,637.0 SLOTS; 7,860.0-10,659.0 PRODUCTION; 33.0-8,076.4 Cement Squeeze; 7,680.0 ftKB APERF; 7,822.0-7,840.0 APERF; 7,782.0-7,800.0 Whipstock; 7,762.0 APERF; 7,758.0-7,770.0 AL1 LINER (CTD); 7,564.7- 11,637.7 IPERF; 7,722.0-7,730.0 RPERF; 7,684.0-7,752.0 IPERF; 7,712.0-7,716.0 NIPPLE; 7,581.3 TUBING PUNCH; 7,565.0 Norther Solutions LTP; 7,560.0 PACKER; 7,543.3 Cement Plug; 7,491.0 ftKB NIPPLE; 7,485.4 PACKER; 7,095.2 GAS LIFT; 7,008.7 GAS LIFT; 6,516.6 GAS LIFT; 5,900.9 GAS LIFT; 4,636.9 SURFACE; 35.0-3,576.7 GAS LIFT; 2,935.6 CONDUCTOR; 36.0-115.0 HANGER; 31.0 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 1/5/2020 3H-01 ... TD Act Btm (ftKB) 8,167.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032008400 Wellbore Status PROD Max Angle & MD Incl (°) 48.55 MD (ftKB) 3,900.00 WELLNAME WELLBORE3H-01A Annotation Last WO: End Date 4/11/2015 H2S (ppm) 200 Date 5/2/2019 Comment SSSV: NONE Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:3H-01A jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: CTD LATERAL 1/22/2020 3H-01A jennalt Casing Strings Casing Description A LINER (CTD) OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 8,397.2 Set Depth (ftKB) 11,303.0 Set Depth (TVD) … Wt/Len (l… 4.60 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,397.2 5,934.6 92.64 ALUMINUM BILLET Aluminum Liner Top Billet 1.920 9,390.2 5,942.7 88.29 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.920 10,307.7 5,961.3 93.32 DEPLOYMENT SLEEVE Shorty Deployment Sleeve 1.920 3H-01A, 6/17/2021 8:35:57 AM Vertical schematic (actual) AL1 LINER (CTD); 7,564.7- 11,637.7 A LINER (CTD); 8,397.2- 11,303.0 PRODUCTION; 33.0-8,076.4 Whipstock; 7,762.0 APERF; 7,758.0-7,770.0 IPERF; 7,722.0-7,730.0 Cement Squeeze; 7,680.0 ftKB RPERF; 7,684.0-7,752.0 IPERF; 7,712.0-7,716.0 NIPPLE; 7,581.3 TUBING PUNCH; 7,565.0 Norther Solutions LTP; 7,560.0 PACKER; 7,543.3 Cement Plug; 7,491.0 ftKB NIPPLE; 7,485.4 PACKER; 7,095.2 GAS LIFT; 7,008.7 GAS LIFT; 6,516.6 GAS LIFT; 5,900.9 GAS LIFT; 4,636.9 SURFACE; 35.0-3,576.7 GAS LIFT; 2,935.6 CONDUCTOR; 36.0-115.0 HANGER; 31.0 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 1/5/2020 3H-01A ... TD Act Btm (ftKB) 11,303.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032008401 Wellbore Status PROD Max Angle & MD Incl (°) 98.22 MD (ftKB) 8,236.29 WELLNAME WELLBORE3H-01A Annotation Last WO: End DateH2S (ppm) 200 Date 5/2/2019 Comment DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20084-01-00Well Name/No. KUPARUK RIV UNIT 3H-01ACompletion Status1-OILCompletion Date1/5/2020Permit to Drill2191580Operator ConocoPhillips Alaska, Inc.MD11303TVD5987Current Status1-OIL4/1/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/RESNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC1/17/2020 Electronic File: 3H-01A EOW - NAD27.pdf31934EDDigital DataC1/17/2020 Electronic File: 3H-01A EOW - NAD27.txt31934EDDigital DataC1/17/2020 Electronic File: 3H-01A EOW NAD83.pdf31934EDDigital DataC1/17/2020 Electronic File: 3H-01A EOW NAD83.txt31934EDDigital Data0 0 2191580 KUPARUK RIV UNIT 3H-01A LOG HEADERS31934LogLog Header ScansC1/22/20207816 7563 Electronic Data Set, Filename: 3H-01A_MFC_01DEC19_Centered.las31946EDDigital DataC1/22/20207816 7563 Electronic Data Set, Filename: 3H-01A_MFC_01DEC19_Uncentered.las31946EDDigital DataC1/22/20207729 7553 Electronic Data Set, Filename: 3H-01A_MFC_10DEC19_Centered.las31946EDDigital DataC1/22/20207729 7553 Electronic Data Set, Filename: 3H-01A_MFC_10DEC19_Uncentered.las31946EDDigital DataC1/22/20204 7775 Electronic Data Set, Filename: 3H-01A_JEWELRY_17DEC19.las31946EDDigital DataC1/22/20207775 7549 Electronic Data Set, Filename: 3H-01A_MFC_16DEC19_Centered.las31946EDDigital DataC1/22/20207775 7549 Electronic Data Set, Filename: 3H-01A_MFC_16DEC19_Uncentered.las31946EDDigital DataC1/22/20207782 7551 Electronic Data Set, Filename: 3H-01A_MFC_20DEC19_Centered.las31946EDDigital DataC1/22/20207782 7551 Electronic Data Set, Filename: 3H-01A_MFC_20DEC19_Uncentered.las31946EDDigital DataWednesday, April 1, 2020AOGCCPage 1 of 5 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20084-01-00Well Name/No. KUPARUK RIV UNIT 3H-01ACompletion Status1-OILCompletion Date1/5/2020Permit to Drill2191580Operator ConocoPhillips Alaska, Inc.MD11303TVD5987Current Status1-OIL4/1/2020UICNoC1/22/2020 Electronic File: 3H-01A_MFC24_01DEC19_Report.pdf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC_01DEC19.pdf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC_01DEC19_img.tiff31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_01DEC19_CENTERED.cmi31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_01DEC19_CENTERED.wvd31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_01DEC19_CENTERED.wvf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_01DEC19_CENTERED.wvp31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_01DEC19_UNCENTERED.cmi31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_01DEC19_UNCENTERED.wvd31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_01DEC19_UNCENTERED.wvf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_01DEC19_UNCENTERED.wvp31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_10DEC19_Report.pdf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC_10DEC19.pdf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC_10DEC19_img.tiff31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_10DEC19_CENTERED.cmi31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_10DEC19_CENTERED.wvd31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_10DEC19_CENTERED.wvf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_10DEC19_CENTERED.wvp31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_10DEC19_UNCENTERED.cmi31946EDDigital DataWednesday, April 1, 2020AOGCCPage 2 of 5 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20084-01-00Well Name/No. KUPARUK RIV UNIT 3H-01ACompletion Status1-OILCompletion Date1/5/2020Permit to Drill2191580Operator ConocoPhillips Alaska, Inc.MD11303TVD5987Current Status1-OIL4/1/2020UICNoC1/22/2020 Electronic File: 3H-01A_MFC24_10DEC19_UNCENTERED.wvd31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_10DEC19_UNCENTERED.wvf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_10DEC19_UNCENTERED.wvp31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_JEWELRY_17DEC19.pdf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_JEWELRY_17DEC19_img.tiff31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_16DEC19_Report.pdf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC_16DEC19.pdf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC_16DEC19_img.tiff31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_16DEC19_CENTERED.cmi31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_16DEC19_CENTERED.wvd31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_16DEC19_CENTERED.wvf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_16DEC19_CENTERED.wvp31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_16DEC19_UNCENTERED.cmi31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_16DEC19_UNCENTERED.wvd31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_16DEC19_UNCENTERED.wvf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_16DEC19_UNCENTERED.wvp31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_20DEC19_Report.pdf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC_20DEC19_img.pdf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC_20DEC19_img.tiff31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_20DEC19_CENTERED.cmi31946EDDigital DataWednesday, April 1, 2020AOGCCPage 3 of 5 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20084-01-00Well Name/No. KUPARUK RIV UNIT 3H-01ACompletion Status1-OILCompletion Date1/5/2020Permit to Drill2191580Operator ConocoPhillips Alaska, Inc.MD11303TVD5987Current Status1-OIL4/1/2020UICNoC1/22/2020 Electronic File: 3H-01A_MFC24_20DEC19_CENTERED.wvd31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_20DEC19_CENTERED.wvf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_20DEC19_CENTERED.wvp31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_20DEC19_UNCENTERED.cmi31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_20DEC19_UNCENTERED.wvd31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_20DEC19_UNCENTERED.wvf31946EDDigital DataC1/22/2020 Electronic File: 3H-01A_MFC24_20DEC19_UNCENTERED.wvp31946EDDigital Data0 0 2191580 KUPARUK RIV UNIT 3H-01A LOG HEADERS31946LogLog Header ScansC1/23/20207588 11303 Electronic Data Set, Filename: 3H-01A GAMMA RES.las31950EDDigital DataC1/23/2020 Electronic File: 3H-01A 2MD Final.cgm31950EDDigital DataC1/23/2020 Electronic File: 3H-01A 5MD Final.cgm31950EDDigital DataC1/23/2020 Electronic File: 3H-01A 5TVDSS Final.cgm31950EDDigital DataC1/23/2020 Electronic File: 3H-01A 2MD Final.pdf31950EDDigital DataC1/23/2020 Electronic File: 3H-01A 5MD Final.pdf31950EDDigital DataC1/23/2020 Electronic File: 3H-01A 5TVD Final.pdf31950EDDigital DataC1/23/2020 Electronic File: 3H-01A EOW - NAD27.pdf31950EDDigital DataC1/23/2020 Electronic File: 3H-01A EOW - NAD27.txt31950EDDigital DataC1/23/2020 Electronic File: 3H-01A Final Surveys TD 11303.csv31950EDDigital DataC1/23/2020 Electronic File: 3H-01A Final Surveys TD 11303.xlsx31950EDDigital DataC1/23/2020 Electronic File: 3H-01A Survey Listing.txt31950EDDigital DataC1/23/2020 Electronic File: 3H-01A Surveys.txt31950EDDigital DataC1/23/2020 Electronic File: 3H-01A_25_tapescan_BHI_CTK.txt31950EDDigital DataWednesday, April 1, 2020AOGCCPage 4 of 53H-01A GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20084-01-00Well Name/No. KUPARUK RIV UNIT 3H-01ACompletion Status1-OILCompletion Date1/5/2020Permit to Drill2191580Operator ConocoPhillips Alaska, Inc.MD11303TVD5987Current Status1-OIL4/1/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date: 1/5/2020Release Date: 11/22/2019C1/23/2020 Electronic File: 3H-01A_5_tapescan_BHI_CTK.txt31950EDDigital DataC1/23/2020 Electronic File: 3H-01A_output.tap31950EDDigital DataC1/23/2020 Electronic File: 3H-01A 2MD Final.tif31950EDDigital DataC1/23/2020 Electronic File: 3H-01A 5MD Final.tif31950EDDigital DataC1/23/2020 Electronic File: 3H-01A 5TVDSS Final.tif31950EDDigital Data0 0 2191580 KUPARUK RIV UNIT 3H-01A LOG HEADERS31950LogLog Header ScansWednesday, April 1, 2020AOGCCPage 5 of 5M. Guhl 4/1/2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil D Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development (] Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 1/5/2020 14. Permit to Drill Number / Sundry: 219-158 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 12/21/2019 15. API Number: 50-103-20084-01-00 ' 4a. Location of Well (Governmental Section): Surface: 1546' FNL, 281' FWL, Sec 12, T12N, R8E, UM Top of Productive Interval: 705' FNL, 1213' FEL, Sec 14, T12N, R8E, UM Total Depth: 3299' FNL, 123' FEL, Sec 11, T12N, R8E, UM 8. Date TD Reached: 12/25/2019 16. Well Name and Number: KRU 3H -01A 9. Ref Elevations: KB:76 GL: 39 a BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: 7780/5928 • 18. Property Designation: ADL 25547, ADL 25531 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498655 y- 6000111 Zone- 4 TPI: x- 497163 y- 5995673 Zone- 4 Total Depth: x- 498252 y- 5998358 Zone- 4 11. Total Depth MD/TVD: 11303/5987 1 19. DNR Approval Number: 931886000, 931882000 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1764/1637 , 5. Directional or Inclination Survey: Yes 21 (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 7763/5915 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CEMENTING RECORD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 36 115 36 115 24 245 sx AS 1 9518 36 J-55 35 3577 35 2942 121/4 1300sx AS III, 400sx CLASS G, 7 36 J-55 33 8076 33 6155 81/2 300sx Class G, 200sx AS I 23/8 4.6 L-80 8397 11303 5935 5987 3 SLOTTED LINER 24. Open to production or injection? Yes 2] No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @ 8397-11303 MD and 5935-5987 TVD COMPLETION ( AT Z0� Vk-�IFIEda 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3112 7615 7095/5415 7543/5748 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 1/16/2020 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 1/17/2020 Hours Tested: 5hrs Production for Test Period Oil -Bbl: 526 Gas -MCF: 280 Water -Bbl: 269 Choke Size: 4 Gas -Oil Ratio: 645 Flow Tubing Press. 194 Casinq Press: 1210 Calculated 24 -Hour Rate Oil -Bbl: 2325 Gas -MCF: 1500 Water -Bbl: 1277 Oil Gravitv - API (corr): 2L) (fw Form 10-407 Revised 5/2017 CONTINUED � N a -o 2 RBDMs� FEB 0 4 2020 Submit ORIGINIAL onyp. d��.v ,''1.'11 (��t1 28. CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/1VD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No El If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1764 1637 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7764 5915 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk A TD 11303 5986 Formation at total depth: Ku aruk A ' 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, i)aleontoloaical report, production or well test results. r)er 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: James Hayes Authorized Title: Staff CTD Engineer Contact Email: James. C. Ha es co .com Authorized Fw, t pS;�,y„ Contact Phone: 265-6927 Signature: Date: 2ZYIAO INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 16" 62# H-40 shoe) (a115'MD 9-5/8" 36# J-55 shoe @ 3577' MD Liner Top Packer 31-1-01 Final Schematic 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ 2936', 4637', 5910', 6517', & 7009' RKB Baker 3-1/2" PBR 7072' MD (4" ID) Baker FHL Packer @ 7095' MD (2.93" ID) 3-Y2' DS landing nipple at 7485' MD (2.813" ID) Baker Poor Boy Overshot @ 7506' RKB Baker 3-1/2" PBR 7530' MD (3" ID) Baker FHL packer @ 7543' MD (2.937" ID) Camco D -Nipple @ 7581' MD (Milled2.80" Min ID) Camco SOS @ 7614" MD 3H-01AL1 TD 11,637' MD PBR 7,565' MD OP d 7763' h 3H-01APB1 C4 -sand perfs y TD 10,961' MD 7694'-7752' MD To of Billet @ 9640' MD . Swell Packer 31-1-01A A -sand perFs 7,834MD TD 11,303' MD 7758' - 7840' MD ^' Top of Billet @ 839T MD i., ---- - ------------ --------------- -------------------------- - -: -- ---- " 7" 26shoe @ 9076'' MDD KUP PROD WELLNAME 31-1-01 ' r +t ," Well Attributes ConocoPhillips Field Name Wellbore APl/UWI Wel Alaska, Inc. 129R11K RIVER t1NIT 50103200.401 PR Status 175 14/30/2016 1 Last WO: WELLBORE 3H -01A Max Angle & MD ITD 08,1211 (°) MD (ttKB) Act Bt, (ftKB) 8.22 8,236.29 11,303.0 Date KB-Grd (ft) Rig Release Date 42.01 1/5/2020 3H.01A, 127202012:07:07 PM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) I End Date Wellbore 1 Last Mod By ............................................................................................ Last Tag: I 13H -01A 1jennalt HANGER; 31.0 Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: CTD LATERAL 1112212020 31-1-01A 1jermalt Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB Set Depth (ND)... Wf/Len (I... Grade Top Thread A LINER (CTD) 2 318 1.99 8,397.2 11,303.0 4.60 L-80 TTL CONDUCTOR; 36.0.115.0 Annular Fluid -Diesel; 33.0. Liner Details Nominal ID 2.500.0; 1/4/2020 Top (ftKB) Top (ND) (ftKB) Top Incl (°) Item Des Co. (in) 8,397.2 5,934.6 92.64 ALUMINUM Aluminum Liner Top Billet 1.920 BILLET 9,390.2 5,942.7 88.29 DEPLOYMENT Shorty Deployment Sleeve 1.920 SLEEVE GAS LIFT, 2935.6 10,307.7 5,961.3 93.32 DEPLOYMENT Shorty Deployment Sleeve SLEEVE 1.920 Notes: General & Safety SURFACE; 35.03,576.7 Annular Fluid -Seawater; 45.0-L_ End Date Annotation 1/22/2020 NOTE: VIEW SCHEMATIC w/Alaska Schematic 10.0 7,770.0; 1/42020 GAS LIFT; 4,636.9 GAS LIFT; 5,900.9 GAS LIFT; 6,516A GAS LIFT; 7,008.7 LOCATOR; 7,065 0 SEAL ASSY; 7,066.0 PER; 7,072.2 PACKER; 7,095.2 NIPPLE; 7,465.4 OVERSHOT, 7,503.1 PBR; 7,529.5 PACKER; 7,503.3 Norther Sdub— LTP; 7,580.0 TUBING PUNCH; 7,565.0 NIPPLE; 7,561.3 SOS; 7,613.8 IPERF; 7,712.0-7,716.0 RPERF; 7,664.0.7,752.0 IPERF; 7,722.0.7,730.0 APERF; 7,758.0-7,770.0 Whipsmck; 7,762.0 PRODUCTION; 33.0-8,076 4 f� A LINER (CTD); 8,397.2- 11,3030 i 1 AL1 LINER (CTD);7,564.7- t 11,637,7-____ji ConocoPhillips Maska, Inc. KUP PROD WELLNAME 3H-01 Name NONE 1175 14/30/2016 (Last WO: WELLBORE 3H-01 8.55 13,900.00 18,167.0 1 Date KB-Grd (ft) Rig Rel"1/2015 42.01 1/5/2020 3H-01, 127202012:07:07 PM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) 1 End Date Wellbore 1 Last Mod By ............................................................................................ Last Tag: RKB 7,764.0 11/9/2019 3H-01 condijw HANGER; 31.0 Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set NSLTP I 1/10/2020 311-01 Izembael Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Threatl CONDUCTOR 16 15.06 36.) 115.0 115.0 62.50 H40 WELDED Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread CONDUCTOR; 36.0.115.0 SURFACE 95/8 8.92 35.0 3,576.7 2,942.4 36.00 J-55 BTC Annular FIZ � O ' i4 p Casing Description OD (In) I ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen PRODUCTION 7 6.28 33.0 8,076.4 6,155.4 26.00 (I... Grade Top Thread J-55 BTC Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt pbrct) Grade Top Connection TUBING -2015W0 31/2 2.99 31.0 7,509.7 5,723.3 9.30 L-80 EUEBrdABMOD Completion Details Top(TVD) Top Incl Nominal GAS LIFT; 2,935.6 Top (ftKB) (ftKB) (1 Item Des Com ID (in) 31.0 31.0 0.67 HANGER FMC TUBING HANGER 2.992 7,065.0 5,392.6 42.61 LOCATOR LOCATOR 2.990 7,066.0 5,393.3 42.60 SEAL ASSY BAKER 8040 SEAL ASSEMBLY 3.000 SURFACE; voter; 45.0- Annular Fluid -Seawater; 45.0. 7,072.2 5,397.9 42.56 PBR BAKER 8040 PBR 4.000 7,770.0; 1/412020 7,095.2 5,414.8 42.40 PACKER BAKER FHL RETRIEVABLE PACKER 4782 2.930 GAS LIFT; 4,636.9 7,485.4 5,705.0 41.40 NIPPLE DS NIPPLE 2.813 7,503.1 1 5,718.31 41.30 1 OVERSHOT I BAKER POOR BOY OVERSHOT 3.750 Tubing Description String Ma... ID (in) Top (ftKB) Sat Depth (ft.. Set Depth (TVD) (... Wt (Ib/It) Grad, Top Connection TUBING -ORIGINAL 31/2 : 7,504.7 7,614.6 5,802.4 9.30 J-55 EUE8rdABMOD GAS LIFT; 5,900.9 Completion Details Top (TVD) Top Incl Nominal Top (ftKB) (ftKB) C) Item Des Com ID (in) 7,529.5 5,738.2 41.17 PBR BAKER PBR 3.000 7,543.3 5,748.5 41.10 PACKER BAKER THU PACKER 2.937 GAS LIFT; 6,5166 7,581.3 5,777.2 40.91 NIPPLE AM 0'D' NIPPLE NO Go 2.800 --( MILL D NIPPLE TO 2.80") 7,613.8 5,801.8 40.80 SOS CAMCO SHEAROUT SUB 2.937 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT; 7,006.7 Top (TVD) Top Incl Top (ttKB) (ftKB) (6) Des Com Run Date ID (in) 7,560.0 5,761.1 41.02 Norther 2.72" Northern Solutions Liner Top Packer w/ 1.781" R- 1/10/2020 1.781 LOCATOR; 7,065.0 Solutions LTP Nipple (8.29' OAL) 7,565.0 5,764.9 41.00 TUBING TUBING PUNCH, 4 FT INTERVAL, 4 SPF, 16 SHOTS 11/10/201 2.992 SEAL ASSY; 7,066.0 PBR; 7,072.2 PUNCH TOTAL 9 PACKER; 7,095.2 7,762.0 5,914.4 39.97 Whipstock 3.5" MB XL Whipstock w/OHA 12120/201 9 Perforations & Slots Shot Dens NIPPLE; 7,485.4 Top (TVD) St. (TVD) (shotsrrt Top (ftKB) Bt. (ftKB) (ftKB) (ftKB) Linked Zone Date ) Type Co. 7,684.0 7,752.0 5,855.0 5,906.8 UNIT D, C4, C- 8/21/1988 12.0 RPERF 21/8" EnerJet; 60 deg. ph 3, 3H-01 OVERSHOT; 7,503.1 7,712.0 7,716.0 5,876.2 5,879.3 C4, 3H-01 12/3/1987 2.0 (PERF 4" Densi Jet; 120 deg. ph 7,722.0 7,730.0 5,883.8 5,889.9 C4, 311-01 12/3/1987 2.0 (PERF 4" Densi Jet; 120 deg. ph PBR; 7,529.5 PACKER; 7,543.3 7,758.0 7,770.0 5,911.4 5,920.6 A-3, 3H-01 8/21/1988 8.0 APERF 21/8" EnerJet; 60 de h 9P 7,782.0 7,800.0 5,929.8 5,943.6 A-2, 311-01 8/21/1988 8.0 APERF 21/8" EnerJet; 60 deg. ph Norther solutions LTP; 7,560.0 Y 7,822.0 7,840.0 5,960.4 5,974.2 A-1, 3H-01 5/21/1988 8.0 APERF 2.5" Scallop; 90 deg. ph 7,860.0 10,659.0 5,989.5 A2, A3,31-1-01 1/4/2020 SLOTS Slotted Liner 3H -01A TUBING PUNCH; 7,565.0 9,442.6 11,637.0 A2, A3,31-1-01 1/4/2020 SLOTS Slotted Liner 31-1-011-1 Mandrel Inserts NIPPLE; 7,581.3 St at! SOS; 7,613.8 on N Top (ftKB) Top (ftKB) Make Model OD (In) Be, Valve ye Latch Poyn)b`e TRO (si) Run Date Com 1 2,935.6 2,505.5 CAMCO MMG 1 112 GAS LIFT GLV RK 0.188 1,235.0 4/24/2015 2 4,636.9 3,657.9 CAMCO MMG 1 112 GAS LIFT GLV RK 0.188 1,238.0 4/24/2015 3 5,900.9 4,552.4 CAMCO MMG 1 112 GAS LIFT OV RK 0.2501 0.0 4/24/2015 4 6,516.6 4,996.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.0001 0.0 4/17/2015 (PERF; 7,712.0.7,716.0- 5 7,008.7 5,351.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/24/2015 DGR RPERF; 7,fi64.0.7,752.0 Notes: General & Safety (PERF; 7,722.0.7,730.0 End Date Annotation 1/2212020 NOTE: VIEW SCHEMATIC w/Alaska Schematic 10.0 7/7/2007 NOTE: WAIVERED WELL- IA X OA COMMUNICATION AL1 LINER (CTD); 7,564.7- 11,637.7 APERF; 7,758.0.7,770.0` Whipstock; 7,762.0 APERF; 7,782.0.7,800.0 APERF; 7.822.0-7,840.0- ,822.0-7,840.0PRODUCTION; PRODUCTION;33 .06,076.4 SLOTS; 9,442.6-11,6370 SLOTS; 7,860o-10,6590 6" 62# H-40 hoe @115'MD 9-5/8" 36# J-55 shoe @ 3577' MD 3H-01 Proposed CTD Schematic 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ 2936', 4637', 5910', 6517', & 7009' RKB Baker 3-1/2" PBR 7072' MD (4" ID) Baker FHL Packer @ 7095' MD (2.93" ID) 3-1/2" DS landing nipple at 7485' MD (2.813" ID) Baker Poor Boy Overshot @ 7506' RKB Baker 3-1/2" PBR 7530' MD (3" ID) Baker FHL packer @ 7543' MD (2.937" ID) Camco D -Nipple @ 7581' MD (2.75" Min ID) Camco SOS @ 7614" MD Liner Top Packer 3H-01AL1 TD 11,637' MD PBR 7,565' MD KOP @ 7785' MD 3H-01 APB 1 TD 10,961' MD sand perfs 7684'- 768 2' MD Top of Billet @ 5658' MD Swell Packer 31-1-01A A -sand perfs 7,835' MD TD 11,303' MD 7758'- 7840' MD Top of Billet @ 839T MD 7" 26# J-55 shoe @ ------------------ 8076' MD ; . Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/29/2019 11/29/2019 1.00 MIRU MOVE RURD P Prepare rig for move from 2M-21 to 0.0 0.0 12:00 13:00 31-1-01 11/29/2019 11/29/2019 1.00 MIRU MOVE DMOB P Trucks on location, continue to RD, 0.0 0.0 13:00 14:00 load shop and half way house, Crew change, EE long day, TH crew in. PJSM W Peak truckers. 11/29/2019 11/29/2019 0.50 MIRU MOVE DMOB P Walkaround, prep, skarf pad 0.0 0.0 14:00 14:30 11/29/2019 11/29/2019 0.40 MIRU MOVE DMOB P Jackup Utility Module, sow up, pull 0.0 0.0 14:30 14:54 matts 11/29/2019 11/29/2019 0.20 MIRU MOVE DMOB P Pull Pits and spot on pad for exit 0.0 0.0 14:54 15:06 11/29/2019 11/29/2019 0.60 MIRU MOVE DMOB P Jackup Sub Module, sow up, pull 0.0 0.0 15:06 15:42 away from well, spot up on pad for exit, jeep up 11/29/2019 11/29/2019 0.75 MIRU MOVE DMOB P Pickup matts, jeep up Utility Module, 0.0 0.0 15:42 16:27 11/29/2019 11/29/2019 1.00 MIRU MOVE MOB P Begin Move towards 31 -1 -pad @ 2.5 0.0 0.0 16:27 17:27 mph 11/29/2019 11/29/2019 1.00 MIRU MOVE MOB P Hold up on 2B for changeout. 0.0 0.0 17:27 18:27 11/29/2019 11/29/2019 2.50 MIRU MOVE MOB P Continue moving rig 0.0 0.0 18:27 20:57 11/29/2019 11/29/2019 0.30 MIRU MOVE MOB P Holdup at KCS Y, check tires and 0.0 0.0 20:57 21:15 perform walkaround, fuel up loader 11/29/2019 11/29/2019 0.75 MIRU MOVE MOB P Continue moving rig 0.0 0.0 21:15 22:00 11/29/2019 11/29/2019 0.50 MIRU MOVE MOB P Holdup at 1Q -pad, Nabors crew 0.0 0.0 22:00 22:30 change, perform walkaround, check tires 11/29/2019 11/30/2019 1.50 MIRU MOVE MOB P Continue moving rig, crossing CPF3 0.0 0.0 22:30 00:00 pad 11/30/2019 11/30/2019 1.90 MIRU MOVE MOB P Move to 3H pad 0.0 0.0 00:00 01:54 11/30/2019 11/30/2019 1.60 MIRU MOVE MOB P Pull jeeps, troble removing the service 0.0 0.0 01:54 03:30 unit jeeps - 30 min, 11/30/2019 11/30/2019 1.00 MIRU MOVE MOB P Sput Sub & mats, remove tree cap, 0.0 0.0 03:30 04:30 Set down. 11/30/2019 11/30/2019 1.00 MIRU MOVE MOB P Spot Pits & mats, set down 0.0 0.0 04:30 05:30 11/30/2019 11/30/2019 2.00 MIRU MOVE RURD P Crew change, PJSM, start working RU 0.0 0.0 05:30 07:30 check list. 11/30/2019 11/30/2019 1.00 MIRU WHDBOP NUND P Set stack , check tree bolts. spot truck 0.0 0.0 07:30 08:30 shop and Half way house. Highline on location hooking up power, updated AOGCC. 11/30/2019 11/30/2019 2.40 MIRU WHDBOP RURD P Continue to RU, grease crew serviced 0.0 0.0 08:30 10:54 tree. Transfer rig to High line power @ 10:00. take on seawater. Install Tiger tank and hard line. Flood up and shell test to 4000 psi. "' Rig accept @ 10:00 11/30/2019 11/30/2019 0.10 MIRU WHDBOP BOPE T Witness waived by Austin McLeod of 0.0 0.0 10:54 11:00 the AOGCC. Test pressure 250/4000 psi low/high. Test 1.1-eaking past Swab 2, call out valve crew to grease, carry on with test 11/30/2019 11/30/2019 0.70 MIRU WHDBOP BOPE T Test 2. Blind/Shear, BOP TV2, Charlie 0.0 0.0 11:00 11:42 4, 5, 8, &12 Fail, Grease vlave Page 1/39 Report Printed: 1/7/2020 g Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (W[3) End Depth (ftK6) 11/30/2019 11/30/2019 0.20 MIRU WHDBOP BOPE P Retest - Test 2. Blind/Shear, BOP TV2, 0.0 0.0 11:42 11:54 Charlie 4, 5, 8, &12 Pass 11/30/2019 11/30/2019 0.20 MIRU WHDBOP BOPE P Retest Test 1.Swab 2, Pass 0.0 0.0 11:54 12:06 11/30/2019 11/30/2019 0.90 MIRU WHDBOP BOPE P Test 3. BOP TV 1, Charlie 3, 7, & 11 0.0 0.0 12:06 13:00 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 11/30/2019 11/30/2019 0.80 MIRU WHDBOP BOPE T Test 6. Charlie 1, 9, Bravo 5, and 0.0 0.0 13:00 13:48 Tango 1, - F B5 leaking, Grease B5 11/30/2019 11/30/2019 2.10 MIRU WHDBOP BOPE P Install TIW test joint, 0.0 13:48 15:54 Test 7. Lower 2" pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP Test 9. Upper 2" pipe slip rams, Bravo 6, & 8 Test 10. Bravo 7 - swap out 2" test joint for 2-3/8" Test 11. 2-3/8" pipe slip rams, TIW#2 Tested all gas detectors, pits, cellar, rig floor all functioned properly, Verified flow alarms - PVT 11/30/2019 11/30/2019 1.70 MIRU WHDBOP BOPE T Blow down and swap out Swap out 0.0 0.0 15:54 17:36 B5, re flood in preparation to test B5 11/30/2019 11/30/2019 0.90 MIRU WHDBOP BOPE P Retest Test 6. Bravo 5 - Pass, Crew 0.0 0.0 17:36 18:30 change Note: 7.5 hr BOPE Test 11/30/2019 11/30/2019 0.30 MIRU WHDBOP CTOP P check N2 levels, swap to 2" test joint 0.0 0.0 18:30 18:48 Test 12. Draw down accumulator, stabilized starting pressure XXXX psi, time to 200 psi increase 22 sec, full recovery time until pumps shut down 51 sec, N2 bottles - average of 4, 1900 psi. 11/30/2019 11/30/2019 0.60 MIRU WHDBOP CTOP P Stab INJH, reverse circ, test inner reel 0.0 0.0 18:48 19:24 valve and stripper 11/30/2019 11/30/2019 0.30 MIRU WHDBOP CTOP P Blow down testing equipment 0.0 0.0 19:24 19:42 11/30/2019 11/30/2019 0.20 MIRU WHDBOP CTOP P Open up to well, 1,050 WHP, shut 0.0 0.0 19:42 19:54 back in, inspect and change packoffs 11/30/2019 11/30/2019 1.30 MIRU WHDBOP PRTS P Test PDL's and Tiger Tank Line 0.0 0.0 19:54 21:12 11/30/2019 11/30/2019 1.70 SLOT WELLPR PULD P PJSM, PU/MU milling assembly 0.0 62.4 21:12 22:54 11/30/2019 11/30/2019 0.80 SLOT WELLPR PULD T Trouble with obtaining WITS to BHI, 62.4 62.4 22:54 23:42 troubleshoot 11/30/2019 12/1/2019 0.30 SLOT WELLPR TRIP P RIH w/Milling BHA#1, 0.9° ako motor 62.4 305.0 23:42 00:00 and New slick gauge D331 DSM 12/1/2019 12/1/2019 1.30 SLOT WELLPR TRIP P Continue IH with Milling Assembly 305.0 7,400.0 00:00 01:18 BHA#1, pumping 4.0 bpm, 1.0 bpm returns 12/1/2019 12/1/2019 0.50 SLOT WELLPR DLOG P Log formation HRZ (-1.5') 7,400.0 7,416.0 01:18 01:48 12/1/2019 12/1/2019 0.30 SLOT WELLPR TRIP P Continue IH, dry tag TOC @ 7,619', 7,416.0 7,619.0 01:48 02:06 PUW 29 k 12/1/2019 12/1/2019 1.50 SLOT WELLPR DISP P Displace well to Milling Fluid (Power- 7,619.0 7,619.0 02:06 03:36 pro) 12/1/2019 12/1/2019 0.50 SLOT WELLPR MILL P RIH, start milling cement 7,618.4' , 1.9 7,619.0 7,620.0 03:36 04:06 bpm at 4,295 psi, FS diff=483, WHP=70, IA=1006, OA=612 Page 2/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 12/1/2019 12/1/2019 0.30 SLOT WELLPR MILL P Stall motor, PUW 29 k, no=comms 7,620.0 7,620.0 04:06 04:24 with HOT, trouble shoot (good), re- boot software,RIH 12/1/2019 12/1/2019 0.30 SLOT WELLPR MILL P RBIH, stall motor again, PUH and re- 7,620.0 7,621.4 04:24 04:42 start, 1.86 bpm at 4,313 psi, FS diff=510 psi, WHP=70, BHP=3,342, IA= 1006, OA=618 12/1/2019 12/1/2019 2.30 SLOT WELLPR MILL P RBIH, stall motor again, PUH and re- 7,621.4 7,623.6 04:42 07:00 start, 1.86 bpm at 4,313 psi, FS diff=510 psi, WHP=70, BHP=3,342, IA= 1006, OA=618 12 stalls, some cement and metal on the shaker. 12/1/2019 12/1/2019 0.40 SLOT WELLPR DLOG P PUH & tie into the HRZ for a +0.5' 7,623.6 7,419.0 07:00 07:24 1 1 correction. 12/1/2019 12/1/2019 0.40 SLOT WELLPR DLOG P Log CCL from 7419 bit depth to 7,419.0 7,624.0 07:24 07:48 bottom 7624' 12/1/2019 12/1/2019 0.70 SLOT WELLPR MILL P Pull back reaming pass @ 180 ROHS, 7,624.0 7,629.5 07:48 08:30 Baker computer locked up, reboot, reset depth. RBIH and drill 5' with TF @ LS, 7624.5'- 7629.5 ROP up to 60 ft/hr 12/1/2019 12/1/2019 2.00 SLOT WELLPR MILL P Roll TF back to 20 ROHS, drill ahead 7,629.5 7,700.0 08:30 10:30 ROP climbed to 120 ft/hr W 0.48 k lbs WOB @ 7652' Stalls, 7657,7659,7660,7666' Drilling @ 7666'70 ft/hr, 0.2 WOB 12/1/2019 12/1/2019 5.40 SLOT WELLPR MILL P ROP dropped to 10-16 ft/hr @ 7700. 7,700.0 7,741.0 10:30 15:54 7705' PU Wt 31 k lbs 7706.3 PU Wt 31 k lbs Good competent consistant cement from 7724' on down. Mill ahead @ 8 ftph W 2.5 k WOB. 12/1/2019 12/1/2019 1.10 SLOT WELLPR MILL P Softer spot w higher ROP to 57 ft/hr 7,741.0 7,759.0 15:54 17:00 CT 4492 psi @ 1.88/1.84 bpm in/out, OBD diff 784 psi, CT Wt 11.8 k lbs, WOB 1.5 k lbs, WH 5 psi, IA 1041 psi, OA 778 psi. 12/1/2019 12/1/2019 1.20 SLOT WELLPR MILL P Continue Milling, 1.86 bpm at 4193 7,759.0 7,769.0 17:00 18:12 psi, FS Diff=435, WHP=7, BHP=3406, IA=1050, OA=840 12/1/2019 12/1/2019 1.70 SLOT WELLPR MILL P Stall Motor, PU, PUW 30 k, RBIH, mill 7,769.0 7,775.0 18:12 19:54 ahead 1.86 bpm at 4,225 psi, FS Diff=453 psi, WHP12. BHP=3,387, IA=1,050, OA=838 12/1/2019 12/1/2019 0.65 SLOT WELLPR MILL P Wiper up to TOC @ 7,580', PUW 30 k 7,775.0 7,775.0 19:54 20:33 12/1/2019 12/1/2019 0.50 SLOT WELLPR MILL P RBIH, Mill Ahead, 1.86 bpm at 4,225 7,775.0 7,776.0 20:33 21:03 psi, FS Diff=453 psi, WHP12. BHP=3,387, IA=1,050, OA=838, orientor (HOT) turned off, interfierence issues 12/1/2019 12/1/2019 0.30 SLOT WELLPR MILL P PUH, PUW 30 k, confirm TF operation 7,776.0 7,776.0 21:03 21:21 turn TF left and right (good), RBIH 12/1/2019 12/2/2019 2.66 SLOT WELLPR MILL P Mill ahead, 1.86 bpm at 4,225 psi, FS 7,776.0 7,781.0 21:21 00:00 Diff=453 psi, WHP12. BHP=3,387, IA=1,050, OA=838, orientor (HOT) turned off, interfierence issues Page 3/39 Report Printed: 1/7/2020 . Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/2/2019 12/2/2019 0.30 SLOT WELLPR MILL P Mill ahead chasing no WOB @ 5 fpm, 7,781.0 7,791.0 00:00 00:18 1.86 bpm at 4,225 psi, FS Diff=453 psi, WHP12. BHP=3,387, IA=1,050, OA=838, orientor (HOT) turned off, interfierence issues 12/2/2019 12/2/2019 0.20 SLOT WELLPR MILL P Stall motor, PUH, PUW 30 k, re -start, 7,791.0 7,794.0 00:18 00:30 1.86 bpm at 4,178 psi, FS Diff=447, WHP=7, BHP=3,421, IA=1,051 psi, OA=839 12/2/2019 12/2/2019 2.00 SLOT WELLPR MILL P Stall motor 3.5 k DHWOB, PUH re- 7,794.0 7,804.0 00:30 02:30 start, continue milling ahead @ 1.86 bpm at 4,178 psi, FS Diff=447, WHP=7, BHP=3,421, IA=1,051 psi, OA=839, bring tool back on, seems TF is responding within spec. continue milling 12/2/2019 12/2/2019 0.34 SLOT WELLPR MILL P OBM, 1.86 bpm at 4,178 psi, FS 7,804.0 7,807.0 02:30 02:50 Diff=447, WHP=7, BHP=3,421, IA=1,051 psi, OA=839 12/2/2019 12/2/2019 0.20 SLOT WELLPR MILL P Milling break 63 fph 7,807' to 7,913', 7,807.0 7,813.2 02:50 03:02 stall motor, PUH, PUW 30 k, RBIH, Mill ahead 12/2/2019 12/2/2019 0.50 SLOT WELLPR MILL P PUH, PUW 30 k, RBIH, Mill ahead, 7,813.2 7,815.0 03:02 03:32 1.86 bpm at 4,178 psi, FS Diff=447, WHP=7, BHP=3,421, IA=1,051 psi, OA=839 12/2/2019 12/2/2019 0.50 SLOT WELLPR MILL P PUH, PUW 30 k 7,815.0 7,600.0 03:32 04:02 12/2/2019 12/2/2019 0.20 SLOT WELLPR DLOG P Log formation K1 (+4.0') 7,600.0 7,627.0 04:02 04:14 12/2/2019 12/2/2019 0.10 SLOT WELLPR REAM P Ream up at 60 fph @ MTF 7,627.0 7,611.0 04:14 04:20 12/2/2019 12/2/2019 0.90 SLOT WELLPR REAM P Continue Reaming as per RP up at 7,611.0 7,617.0 04:20 05:14 1.0 fpm, down at 5 fpm 12/2/2019 12/2/2019 0.20 SLOT WELLPR TRIP P RIH and dry tag 7819' 7,617.0 7,819.0 05:14 05:26 12/2/2019 12/2/2019 1.80 SLOT WELLPR TRIP P POOH 7,819.0 60.0 05:26 07:14 Jog @ 500', continue out of hole 12/2/2019 12/2/2019 0.60 SLOT WELLPR PULD P Bump up, space out, 60.0 60.0 07:14 07:50 12/2/2019 12/2/2019 1.20 SLOT WELLPR PULD T While stripping off the well observed 60.0 60.0 07:50 09:02 the BHA move up with the injector approximately 1'. When injector cart was stopped BHA continued to move a short distance then stop once the CTC bumped up against the stripper. Stripped down, stabbed injector and worked PD checklist, RIH, bumped up and spaced out. Repeaded PUD with same result, stabbed injector, RIH, Bump up, space out deeper, push pull to 8k no movement. 12/2/2019 12/2/2019 0.20 SLOT WELLPR OWFF T Bleed in increments - 1 bbl off the 60.0 60.0 09:02 09:14 tubing. Well head fell to zero and built to 540 psi 12/2/2019 12/2/2019 0.20 SLOT WELLPR PULD T Work PD check list from current 60.0 60.0 09:14 09:26 position. Bump up set counters. 12/2/2019 12/2/2019 1.30 SLOT WELLPR TRIP T RIH 60.0 7,415.0 09:26 110:44 1 1PU Wt 31 k Ib At 7400' 12/2/2019 12/2/2019 0.20 SLOT WELLPR DLOG T Tie into the HRZ for a +2' correction 7,415.0 7,446.2 10:44 110:56 Page 4/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/2/2019 12/2/2019 0.70 SLOT WELLPR DLOG T Park @ 7600.76/5767.15 MD/TVD 7,446.2 7,600.0 10:56 11:38 and monitor pressure. Trap 3548 psi observe pressure fall to 3299 psi BHP = 11.00 ppg EMW "' note pressure stabilized @ 11.0 ppg, Started bleeding IA, Bottom hole pressure fell slightly, Suspect OV check leaking or TxIA. 12/2/2019 12/2/2019 0.45 SLOT WELLPR DISP T Pump 11. pph NaBr/NaCl KW to the 7,600.0 7,600.0 11:38 12:05 bit. 1.94/1.98 bpm in/out CT 4301 psi 12/2/2019 12/2/2019 1.30 SLOT WELLPR DISP T PUH displacing well to 11.3 heavy KW 7,600.0 62.7 12:05 13:23 fluid 12/2/2019 12/2/2019 1.00 SLOT WELLPR PULD T At surface, flow check - good, Bump 62.7 0.0 13:23 14:23 up, space out, close 2-3/8" deployment rams, pop off and strip up, BHA came up with injector cart. LD BHA #1 over a dead well 12/2/2019 12/2/2019 0.70 SLOT WELLPR CTOP T Examine BHA#1, OD tape measured 0.0 0.0 14:23 15:05 2.32-2.33" at the area where the 2- 3/8" deployment rams bite the tool. 12/2/2019 12/2/2019 1.75 SLOT WELLPR CTOP T Un Stab, change checks, pick up test 0.0 0.0 15:05 16:50 upper section with blind sub and nozzle. Bump up, space out, push pull- good, strip off - good. Lay down upper test tool. 12/2/2019 12/2/2019 1.00 SLOT WELLPR CIRC T Skid cart, inspect pack offs- good, 0.0 0.0 16:50 17:50 make up nozzle, stab injector, jet stack flush MM line. Lots of cement debris and frac sand retuned to the shaker. 12/2/2019 12/2/2019 1.10 SLOT WELLPR PULD P PU BHA#2, real time caliper upper 0.0 24.1 17:50 18:56 coil trak. 12/2/2019 12/2/2019 1.50 SLOT WELLPR TRIP P RIH 24.1 7,600.0 18:56 20:26 12/2/2019 12/2/2019 0.20 SLOT WELLPR DLOG P Log formation w/gamma no correction. 7,636.0 7,736.0 20:26 20:38 12/2/2019 12/2/2019 0.30 SLOT WELLPR TRIP P Continue IH to caliper logging depth, 7,736.0 7,814.0 20:38 20:56 allow fingers to fully open 12/2/2019 12/2/2019 0.20 SLOT WELLPR DLOG P Log up at 50 fpm with caliper 7,814.0 7,590.0 20:56 21:08 12/2/2019 12/2/2019 0.20 SLOT WELLPR TRIP P RBIH 7,590.0 7,814.0 21:08 21:20 12/2/2019 12/2/2019 0.20 SLOT WELLPR DLOG P Repeat pass with caliper @ 50 fpm 7,814.0 7,590.0 21:20 21:32 12/2/2019 12/2/2019 1.10 SLOT WELLPR TRIP P POOH 7,590.0 24.1 21:32 22:38 12/2/2019 12/2/2019 0.50 SLOT WELLPR OWFF P At surface, check well for flow, PJSM, 24.1 24.1 22:38 23:08 inspect Coil Wear above CTC, (min 0.11 inch) 12/2/2019 12/2/2019 0.70 SLOT WELLPR PULD P LD Caliper over a dead well 24.1 0.0 23:08 23:50 12/2/2019 12/3/2019 0.17 SLOT WELLPR CTOP P PJSM/prep changing CTC 0.0 0.0 23:50 00:00 12/3/2019 12/3/2019 2.00 SLOT WELLPR CTOP P Cut off CTC, trim 20' of coil (min 0.0 0.0 00:00 02:00 0.110"), ream and dress coil 12/3/2019 12/3/2019 0.75 SLOT WELLPR CTOP P Install new CTC, Pull test 35 k (good) 0.0 0.0 02:00 02:45 12/3/2019 12/3/2019 0.50 SLOT WELLPR CTOP P Head up BHI UQ 0.0 0.0 02:45 03:15 12/3/2019 12/3/2019 0.75 SLOT WELLPR PULD P MU BHI tools in pipeshed 0.0 0.0 03:15 04:00 Page 5/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/3/2019 12/3/2019 3.00 SLOT WELLPR WAIT T Wait on Haley underreamer hot shot 0.0 54.2 04:00 07:00 from dead horse 12/3/2019 12/3/2019 1.00 SLOT WELLPR PULD T PU BHA#2 over a dead well, Coiltrak 0.0 54.2 07:00 08:00 w BOT 2-1/8" straight extreme motor over a Haley under reamer dressed for 7" with blades that open to 6.12" and a 2.80 D331 ridgeset.2.81 go, 2.80 no. Check pack offs -good, bump up 12/3/2019 12/3/2019 1.50 SLOT WELLPR TRIP T RIH, 54.2 7,598.0 08:00 09:30 PU Wt Ct 28 k lbs, form 7600' 12/3/2019 12/3/2019 0.10 SLOT WELLPR DLOG T Tie into the K1 for +2' corection 7,598.0 7,625.0 09:30 09:36 12/3/2019 12/3/2019 0.70 SLOT WELLPR DISP T Displace KW with milling fluid 7,625.0 7,598.0 09:36 10:18 12/3/2019 12/3/2019 0.20 SLOT WELLPR DISP T Shut in choke, performed injectivity 7,625.0 7,598.0 10:18 10:30 test. Inject 0.2 bpm BHP rose quickly to 3672 psi, plateaued briefly then climbed slowly to 3750 psi. Shut down 12/3/2019 12/3/2019 0.40 SLOT WELLPR UREM T Close EDC RIH to 7620' attempt to 7,598.0 7,642.0 10:30 10:54 open blades in open section of 7" to get free spin numbers, stall. RIH to 7650' online, CT 3247 psi @ 1/1 bpm in / out, free spin 859 psi, Back ream up hole to 7642' stall. 12/3/2019 12/3/2019 1.00 SLOT WELLPR UREM T PU, try to RBIH, stack out, PUH into 7,642.0 7,615.0 10:54 11:54 tubing. RBIH to 7650'w pumps off. PUH pumping 1 bpm, fre spin 815 psi, stall at 7642'. Repeat, stall at 7641.4'. PUH to 7615' with pumps off. 12/3/2019 12/3/2019 0.10 SLOT WELLPR UREM T RIH to 7619' Set rate, CT 4471 psi @ 7,642.0 7,619.0 11:54 12:00 1.5/1.5 bpm in/out. BHP 3418 psi, Ream slowly down with multiple stalls, 12/3/2019 12/3/2019 5.00 SLOT WELLPR UREM T Reaming, CT 4317 psi @ 1.5/1.5 bpm 7,619.0 7,625.0 12:00 17:00 in/out. BHP 3423 psi. OBD CT Wt 11.3 k lbs, WOB 0.8 Mill slowly with -3 stalls per hr MicoMotion out is acting up, reading higher flow than is true. ROP 1.2 ft/hr 12/3/2019 12/3/2019 5.30 SLOT WELLPR UREM T OB reaming, CT 4120 psi 1.5/1.5 bpm 7,625.0 7,657.0 17:00 22:18 in/out. 1058 psi motor work, BHP 3427 psi, CT 13.2 k lbs, WOB 0.8 k lbs Free spin 824 psi, PU WT 28 k lbs. Multiple stalls @ 7226.5' slow going 12/3/2019 12/4/2019 1.70 SLOT WELLPR UREM T OB reaming, CT 4281 psi 1.5/1.5 bpm 7,625.0 7,627.4 22:18 00:00 in/out. 1208 psi motor work, BHP 3410 psi, CT 11.8 k lbs, WOB 0.02 k lbs Milling ahead, 6.0 ft/hr 12/4/2019 12/4/2019 2.00 SLOT WELLPR UREM T OB reaming, CT 4281 psi 1.5/1.5 bpm 7,627.4 7,628.5 00:00 02:00 in/out. Diff=1050 psi, BHP 3410 psi, CT 13 k lbs, WOB 0.02 k lbs Milling ahead, Stall @ 7627.9' 12/4/2019 12/4/2019 2.00 SLOT WELLPR UREM T OB reaming, CT 4150 psi 1.47/1.5 7,628.5 7,629.7 02:00 04:00 bpm in/out. Diff=1122 psi, BHP 3410 psi, CT 13.8 k lbs, WOB 0.02 k lbs Milling ahead, Page 6139 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/4/2019 12/4/2019 2.00 SLOT WELLPR UREM T OB reaming, CT 4123 psi 1.47/1.5 7,629.7 7,630.9 04:00 06:00 bpm in/out. Diff=1053 psi, BHP 3401 psi, CT 13.3 k lbs, WOB 0.02 k lbs Milling ahead, Stall @ 7630.5 12/4/2019 12/4/2019 2.00 SLOT WELLPR UREM T OB reaming, CT 4120 psi 1.47/1.5 7,630.9 7,632.0 06:00 08:00 bpm in/out. Diff=1084 psi, BHP 3410 psi, CT 13.8 k lbs, WOB 0. k lbs Milling ahead, Stall @ 7631.7' 12/4/2019 12/4/2019 2.00 SLOT WELLPR UREM T OB reaming, CT 4045 psi 1.47/1.5 7,632.0 7,633.1 08:00 10:00 bpm in/out. Diff=993 psi , BHP 3410 psi, CT 13.7 k lbs, WOB 0.29 k lbs Milling ahead, Stall @ 7632.9' 12/4/2019 12/4/2019 2.00 SLOT WELLPR UREM T OB reaming, CT 4036 psi 1.47/1.5 7,633.1 7,634.2 10:00 12:00 bpm in/out. Diff=1053 psi, BHP 3407 psi, CT 13.1 k lbs, WOB 0.44 k lbs Milling ahead 12/4/2019 12/4/2019 0.90 SLOT WELLPR UREM T OB Reaming, CT 3,990 psi, 1.47/1.51 7,634.2 7,634.7 12:00 12:54 bpm in/out, Diff=1,034 psi, pump 5x5 time 2 12/4/2019 12/4/2019 1.70 SLOT WELLPR TRIP T POOH, chasing sweep to surface 7,634.7 54.2 12:54 14:36 12/4/2019 12/4/2019 0.70 SLOT WELLPR PULD T PUD and LD Hailey UR milling 54.2 0.0 14:36 15:18 assembly *** Note: Gauge - Upper Blades 5.875", Lower Blades 5.625", excessive wear on both blade pins 12/4/2019 12/4/2019 1.10 SLOT WELLPR PULD T MU, Hailey UR assembly BHA #4 0.0 54.2 15:18 16:24 12/4/2019 12/4/2019 1.30 SLOT WELLPR TRIP T RIH, with UR BHA #4, Hailey UR with 54.2 7,444.0 16:24 17:42 upper 6.1" blades, lower 4.875" blades. 12/4/2019 12/4/2019 0.30 SLOT WELLPR DLOG T Log formation for depth control -1.5'. 7,444.0 7,464.0 17:42 18:00 Close EDC 12/4/2019 12/4/2019 0.70 SLOT WELLPR TRIP T Continue in hole, RIW=13.7K 7,464.0 7,633.0 18:00 18:42 12/4/2019 12/4/2019 2.70 SLOT WELLPR UREM T 7633. Creep in hole, Stall at initial 7,633.0 7,661.0 18:42 21:24 contact them U/reem. 1.5 BPM @ 4199 PSI FS, BHP=3406 12/4/2019 12/4/2019 1.80 SLOT WELLPR UREM T 7661, Stall, PUW=27.5K, Goback to 7,661.0 7,664.0 21:24 23:12 reeming, 1.5 BPM @ 4200 PSI FS, BHP -3406 12/4/2019 12/5/2019 0.80 SLOT WELLPR UREM T 7664', Stall PUW=28.5K. Goback to 7,664.0 7,664.8 23:12 00:00 reeming 1.5 BPM @ 4199 PSI FS, BHP=3706 12/5/2019 12/5/2019 2.00 SLOT WELLPR UREM T Continue under reming cement, 1.5 7,664.8 7,667.6 00:00 02:00 BPM @ 4200 PSI FS, BHP=3226 12/5/2019 12/5/2019 2.00 SLOT WELLPR UREM T 7667', Continue under reaming, Low 7,667.6 7,672.7 02:00 04:00 ROP, No stalls, 1.5 BPM @ 4200 PSI FS, BHP=3431. Full returns 12/5/2019 12/5/2019 2.00 SLOT WELLPR UREM T 7672.7' Continue under reaming. No 7,672.7 7,678.6 04:00 06:00 stalls, Full returns, 1.5 BPM @ 4190 PSI. BHP=3426 PSI 12/5/2019 12/5/2019 2.00 SLOT WELLPR UREM T OB reaming, 1.5 bpm at 4,052 psi, 7,678.6 7,682.3 06:00 08:00 Diff=3,385, WHP=160, BHP=3,385, IA=949, OA=795 12/5/2019 12/5/2019 2.00 SLOT WELLPR UREM T OB reaming, 1.5 bpm at 4,052 psi, 7,682.3 7,685.0 08:00 10:00 DIff=3,385, WHP=160, BHP=3,385, IA=949, OA=795 12/5/2019 12/5/2019 2.00 SLOT WELLPR UREM T OB reaming, 1.5 bpm at 4,052 psi, 7,685.0 7,679.6 10:00 12:00 DIff=3,385, WHP=160, BHP=3,385, IA=949, OA=795 Page 7139 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operabon (ftKB) End Depth (ftKB) 12/5/2019 12/5/2019 0.25 SLOT WELLPR UREM T OB reaming, 1.5 bpm at 4,052 psi, 7,679.6 7,688.1 12:00 12:15 DIff=3,385, WHP=160, BHP=3,385, IA=949, OA=795 12/5/2019 12/5/2019 0.25 SLOT WELLPR UREM T Wiper up hole to 7,629.6'@ 1 fpm, 7,688.1 7,629.6 12:15 12:30 PUW 27 k 12/5/2019 12/5/2019 2.50 SLOT WELLPR UREM T Wiper in hole @ 1 fpm RIW 13.1 k, 7,629.6 778-1- 12:30 15:00 *** Note: Stalled and worked past 7669' and 7672' 12/5/2019 12/5/2019 2.00 SLOT WELLPR UREM T OB reaming, 1.5 bpm at 4,052 psi, 7,688.1 7,690.2 15:00 17:00 DIff=3,385, WHP=160, BHP=3,385, IA=949, OA=795 12/5/2019 12/5/2019 3.50 SLOT WELLPR UREM T OB reaming, 1.5 bpm at 4,052 psi, 7,690.2 7,694-0- 17:00 20:30 DIff=3,385, WHP=160, BHP=3,385, IA=949, OA=795 12/5/2019 12/5/2019 0.50 SLOT WELLPR BKRM T Back ream up hole 7694 to 7675, 7,694.0 7,675.0 20:30 21:00 Pump 5 X 5 sweeps coming off bottom, PUW=29K 12/5/2019 12/5/2019 1.10 SLOT WELLPR TRIP T Stop and open EDC, POOH to inspect 7,675.0 55.0 21:00 22:06 BHA, Overpull @ 7581„ Milled D nipple 12/5/2019 12/5/2019 0.90 SLOT WELLPR PULD T Tag up and space out, PUD BHA #4. 55.0 0.0 22:06 23:00 All under reamer blades at surface. Blades out Upper @ 5.25", Lower out @ 4.375. Heavy wear on hinge pins. 12/5/2019 12/5/2019 0.50 SLOT WELLPR BHAH T Reconfigure BHA, swap out 2 1/8 BOT 0.0 54.2 23:00 23:30 straight motor and 2 1/4" Haily under reamer with 5" lowers and 6.1 uppers. Ran used hinge pins from 1st run. D- 331 out 2.79 NoGo 12/5/2019 12/6/2019 0.50 SLOT WELLPR PULD T Pressure deploy BHA#5, Make up to 54.2 54.2 23:30 00:00 injector 12/6/2019 12/6/2019 0.30 SLOT WELLPR PULD T Continue pressure deploy BHA#5, 54.2 54.2 00:00 00:18 Surface test BHA, Strip on injector 12/6/2019 12/6/2019 1.40 SLOT WELLPR TRIP T Trip in well, BHA #5, EDC open 54.2 7,404.0 00:18 01:42 12/6/2019 12/6/2019 0.30 SLOT WELLPR DLOG T Close EDC, Log Tie in for -1.5' 7,404.0 7,459.0 01:42 02:00 12/6/2019 12/6/2019 0.30 SLOT WELLPR TRIP T Continue in well. 7,458.1 7,645.0 02:00 02:18 12/6/2019 12/6/2019 0.20 SLOT WELLPR UREM T 7645 bring on pumps start reaming 7,645.0 7,680.2 02:18 02:30 down 12/6/2019 12/6/2019 2.00 SLOT WELLPR UREM T 7682, Stall, pick up and restart 7,680.2 7,684.7 02:30 04:30 12/6/2019 12/6/2019 2.00 SLOT WELLPR UREM T OB reaming, 1.5 bpm at 4,370 psi, 7,684.7 7,686.5 04:30 06:30 DIff=1,182, WHP=157, BHP=3,439, IA=949, OA=827 12/6/2019 12/6/2019 2.00 SLOT WELLPR UREM T OB reaming, 1.5 bpm at 4,226 psi, 7,686.5 7,693.7 06:30 08:30 Diff=1,109, WHP=157, BHP=3,435, IA=949, OA=827 12/6/2019 12/6/2019 2.00 SLOT WELLPR UREM T OB reaming, 1.5 bpm at 4,171 psi, 7,693.7 7,694.4 08:30 10:30 DIff=1,114, WHP=157, BHP=3,431, IA=949, OA=827 12/6/2019 12/6/2019 1.70 SLOT WELLPR UREM T OB reaming, 1.5 bpm at 4,194 psi, 7,694.4 7,695.4 10:30 12:12 DIff=1,126, WHP=157, BHP=3,437, IA=949, OA=827, pump 5x5 sweep 12/6/2019 12/6/2019 2.00 SLOT WELLPR UREM T Pump second 5x5, POOH, chasing 7,695.4 54.2 12:12 14:12 sweeps to surface 12/6/2019 12/6/2019 1.50 SLOT WELLPR TRIP T PJSM, PUD UR BHA#5 54.2 0.0 14:12 15:42 **' Note: Upper Blades gauged 5.5" (6.1 "), Lower Blade 4." 4.875" Page 8/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/6/2019 12/6/2019 0.50 SLOT WELLPR CTOP T PU/MU nozzle, stab INJH onto stump, 0.0 0.0 15:42 16:12 jet BOPE and surface lines @ 2.0 bpm 12/6/2019 12/6/2019 0.70 SLOT WELLPR BHAH T Clean rig floor, tear down and re -dress 0.0 0.0 16:12 16:54 UR 12/6/2019 12/6/2019 1.00 SLOT WELLPR PULD T PD BHA#6 Under reamer with 6.1" 0.0 54.2 16:54 17:54 upper blades, 5" lower blades. Make up to coil and surface test. Tag up. set counters 12/6/2019 12/6/2019 1.10 SLOT WELLPR TRIP T RIH BH #6 54.2 7,405.0 17:54 19:00 12/6/2019 12/6/2019 0.20 SLOT WELLPR DLOG T Log formation for -1.5', PUW=29K 7,405.0 7,448.0 19:00 19:12 12/6/2019 12/6/2019 0.20 SLOT WELLPR TRIP T Continue in hole, Shut EDC 7,448.0 7,618.0 19:12 19:24 12/6/2019 12/6/2019 0.90 SLOT WELLPR UREM T 7618. Bring on pumps 1.5 BPM @ 7,618.0 7,620.0 19:24 20:18 4375 PSI FS, BHP=3419. Start reaming down to 7671 then pick up to 7620. Ream back down to 7671 and stall. PUH. Motor will not come out of stall condition. Bleed off CT pressure and repeat. No good 12/6/2019 12/6/2019 1.60 SLOT WELLPR TRIP T Trip out for possible motor failure 7,620.0 54.0 20:18 21:54 12/6/2019 12/6/2019 0.80 SLOT WELLPR PULD T At surface, Tag up and space out. 54.0 0.0 21:54 22:42 PJSM PUD BHA#6 12/6/2019 12/6/2019 0.30 SLOT WELLPR BHAH T Motor has come unsrewed between 0.0 0.0 22:42 23:00 Stator section and flex drive housing. Pics on S drive. Lay down motor. P/U back up motor 12/6/2019 12/6/2019 0.80 SLOT WELLPR PULD T PD BHA#7 with 2 1/8 BOT straight 0.0 54.2 23:00 23:48 motor and haily under reamer. Upper bladed 6", Lower blades 5" M/U to coil and surface test. Check packoffs - Good 12/6/2019 12/7/2019 0.20 SLOT WELLPR TRIP T RIH BHA#7 54.2 853.0 23:48 00:00 12/7/2019 12/7/2019 1.20 SLOT WELLPR TRIP T Continue in well 853.0 7,405.0 00:00 01:12 12/7/2019 12/7/2019 0.20 SLOT WELLPR DLOG T Log formtion for -2', PUW=29K 7,405.0 7,463.0 01:12 01:24 12/7/2019 12/7/2019 0.20 SLOT WELLPR TRIP T Continue in well 7,463.0 7,650.0 01:24 01:36 12/7/2019 12/7/2019 0.40 SLOT WELLPR UREM T Bring on pumps, 1.5 BPM @ 4242 PSI 7,650.0 7,683.0 01:36 02:00 FS, BHP=3383. Wash / ream down to 7683', RIW=14.3K 12/7/2019 12/7/2019 0.10 SLOT WELLPR UREM T 7683. Hard spot with stall, PUW29K. 7,683.0 7,695.0 02:00 02:06 PUH and reset 12/7/2019 12/7/2019 1.40 SLOT WELLPR UREM T 7694, Under ream, 1.5 BPM @ 4033 7,695.0 7,697.0 02:06 03:30 PSI FS, BHP=3446 12/7/2019 12/7/2019 2.00 SLOT WELLPR UREM T 7697, Stall, PUH and restart, 1.5 BPM 7,697.0 7,697.2 03:30 05:30 @ 4034 PSI FS, BHP=3448 12/7/2019 12/7/2019 2.00 SLOT WELLPR UREM T OB, Reaming down 1.51 bpm at 4,316 7,697.2 7,698.4 05:30 07:30 psi, Diff=1,185 psi, WHP=141, BHP=3449, IA=953, OA=800 12/7/2019 12/7/2019 2.00 SLOT WELLPR UREM T OB, Reaming down 1.51 bpm at 4,316 7,698.4 7,700.5 07:30 09:30 psi, Diff=1,185 psi, WHP=141, BHP=3449, IA=953, OA=800 12/7/2019 12/7/2019 2.00 SLOT WELLPR UREM T OB, Reaming down 1.51 bpm at 4,316 7,700.5 7,701.3 09:30 11:30 psi, Diff=1,185 psi, WHP=141, BHP=3449, IA=953, OA=800 12/7/2019 12/7/2019 0.35 SLOT WELLPR UREM T Ream up at 1 fpm from bottom 7701.3' 7,701.3 7,620.0 11:30 11:51 1 1 I to 7,620' Page 9/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/7/2019 12/7/2019 1.45 SLOT WELLPR TRIP T POOH, chasing sweeps to surface 7,620.0 52.2 11:51 13:18 12/7/2019 12/7/2019 1.20 SLOT WELLPR TRIP T PJSM, PUD Reaming BHA #7 52.2 0.0 13:18 14:30 12/7/2019 12/7/2019 1.00 SLOT WELLPR CTOP T Remove BHI Upper Checks, Slide cart 0.0 0.0 14:30 15:30 forward, stab onto well, jet BOPE and surface lines. 12/7/2019 12/7/2019 0.75 SLOT WHDBOP BOPE P PT inner reel valve and pac-off. 250 0.0 0.0 15:30 16:15 low/4,000 high 12/7/2019 12/7/2019 0.75 SLOT WHDBOP BOPE P Service wellhead and rig valves for 0.0 0.0 16:15 17:00 BOPE test 12/7/2019 12/7/2019 5.00 SLOT WHDBOP BOPE P Begin testing following rig testing 0.0 0.0 17:00 22:00 checklist, witness waived by Adam Earl of the AOGCC. Test pressure 250/4000 psi low/high. All tests passed initial inspection. 12/7/2019 12/7/2019 0.70 SLOT WELLPR RURD P Skid injector to rig floor. Install quick 0.0 0.0 22:00 22:42 test sub. Reinstall float valves in upper quick connect. 12/7/2019 12/7/2019 1.00 SLOT WELLPR PULD T PJSM, Load BHA#8 into PDL, P/U 0.0 0.0 22:42 23:42 Lower BHA under reamer & BOT straight motor 12/7/2019 12/8/2019 0.30 SLOT WELLPR PULD T PD BHA #8 with Haily under reamer 0.0 54.2 23:42 00:00 with 6.1" upper blades / 5.0" lower blades & BOT 2 1/8 straight motor 12/8/2019 12/8/2019 0.60 SLOT WELLPR PULD T Continue PD BHA#8. Make up to coil 54.2 54.2 00:00 00:36 and surface test tool. Tag up and set counters 12/8/2019 12/8/2019 1.40 SLOT WELLPR TRIP T Trip in well, BHA #8, EDC open 54.2 7,405.0 00:36 02:00 12/8/2019 12/8/2019 0.30 SLOT WELLPR DLOG T Log formation for -2' correction. 7,405.0 7,458.0 02:00 02:18 PUW=30K 12/8/2019 12/8/2019 0.10 SLOT WELLPR TRIP T ontinue in well to under ream cement 7,458.0 7,650.0 02:18 02:24 12/8/2019 12/8/2019 0.10 SLOT WELLPR UREM T 7650, Bring pumps online 1.52 BPM 7,650.0 7,672.0 02:24 02:30 @ 4216 PSI FS, BHP=3400. RIH working reamer open 12/8/2019 12/8/2019 2.00 SLOT WELLPR UREM T 7672', Wash down, 1.5 BPM @4761 7,672.0 7,696.8 02:30 04:30 PSI FS. Stall @ 7687, 7699 X2 12/8/2019 12/8/2019 2.00 SLOT WELLPR UREM T OBR 1.51 bpm at 4,253 psi, Diff=969, 7,696.8 7,697.6 04:30 06:30 WHP=137, BHP=3,422, IA=941, OA=738 12/8/2019 12/8/2019 2.00 SLOT WELLPR UREM T OBR 1.51 bpm at 4,253 psi, Diff=969, 7,697.6 7,699.6 06:30 08:30 WHP=137, BHP=3,422, IA=941, OA=738 12/8/2019 12/8/2019 2.00 SLOT WELLPR UREM T OBR 1.51 bpm at 4,253 psi, Diff=969, 7,699.6 7,700.2 08:30 10:30 WHP=137, BHP=3,422, IA=941, OA=738 12/8/2019 12/8/2019 2.00 SLOT WELLPR UREM T OBR 1.51 bpm at 4,339 psi, 7,700.2 7,703.0 10:30 12:30 Diff=1,098, WHP=120, BHP=3,461, IA=947, OA=767 12/8/2019 12/8/2019 2.00 SLOT WELLPR UREM T OBR 1.51 bpm at 4,339 psi, 7,703.0 7,705.0 12:30 14:30 Diff=1,098, WHP=120, BHP=3,461, IA=947, OA=767 12/8/2019 12/8/2019 3.50 SLOT WELLPR UREM T OBR 1.5 BPM @ 4053 PSI FS, 7,705.0 7,706.0 14:30 18:00 BHP=3454 12/8/2019 12/8/2019 3.00 SLOT WELLPR UREM T 7706.2 Reaming, 1.5 BPM @ 4053 7,706.0 7,707.9 18:00 21:00 PSI FS, BHP=3452 12/8/2019 12/9/2019 3.00 SLOT WELLPR UREM T 7707.9', Reaming 1.5 BPM @ 4070 7,707.9 7,709.8 21:00 00:00 PSI FS, BHP=3447 Page 10/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/9/2019 12/9/2019 2.20 SLOT WELLPR UREM T 7710', Continue to under ream 7,709.8 7,710.7 00:00 02:12 cement, 1.5 BPM @ 4070 PSI FS, BHP=3446 12/9/2019 12/9/2019 1.60 SLOT WELLPR TRIP T Sweeps coming out. Trip out to 7,710.7 49.8 02:12 03:48 inspect BHA, PUW=29K. Open EDC @7617'. Jog back in hole 500' to 800' 12/9/2019 12/9/2019 1.00 SLOT WELLPR PULD T Tag up and space out, PJSM, PUD 49.8 0.0 03:48 04:48 BHA#8, D-331 out @ 2.79 NoGo 12/9/2019 12/9/2019 0.80 SLOT WELLPR PULD T Make up new under reamer BHA#9 0.0 54.2 04:48 05:36 with 4 1/8" lower blades, 5" upper blades. PD BHA. Make up to coil and surface test 12/9/2019 12/9/2019 1.20 SLOT WELLPR TRIP T RIH with Hailey UR BHA #9 54.2 7,405.0 05:36 06:48 12/9/2019 12/9/2019 0.15 SLOT WELLPR DLOG T Log formatino for depth (-2.0') 7,405.0 7,441.5 06:48 06:57 12/9/2019 12/9/2019 0.20 SLOT WELLPR TRIP T Continue IH 7,441.5 7,650.0 06:57 07:09 12/9/2019 12/9/2019 2.00 SLOT WELLPR UREM T OB Reaming, 1.52 bpm at 3,972 psi, 7,650.0 7,711.9 07:09 09:09 Diff=663, WHP=97, BHP=3,440, IA=950, OA=782 12/9/2019 12/9/2019 2.00 SLOT WELLPR UREM T OB Reaming, 1.52 bpm at 3,972 psi, 7,711.9 7,713.8 09:09 11:09 Diff=663, WHP=97, BHP=3,440, IA=950, OA=782 12/9/2019 12/9/2019 2.00 SLOT WELLPR UREM T OB Reaming, 1.52 bpm at 3,972 psi, 7,713.8 7,714.8 11:09 13:09 Diff=663, WHP=97, BHP=3,440, IA=950, OA=782 12/9/2019 12/9/2019 2.00 SLOT WELLPR UREM T OB Reaming, 1.52 bpm at 3,921 psi, 7,714.8 7,716.1 13:09 15:09 Diff=629, WHP=104, BHP=3,443, IA=949, OA=790 12/9/2019 12/9/2019 2.00 SLOT WELLPR UREM T OB Reaming, 1.52 bpm at 3,921 psi, 7,716.1 7,718.3 15:09 17:09 Diff=629, WHP=104, BHP=3,443, IA=949, OA=790 12/9/2019 12/9/2019 1.85 SLOT WELLPR UREM T OB Reaming, 1.50 bpm at 3,949 psi, 7,718.3 7,719.8 17:09 19:00 Diff=654, WHP=102, BHP=3,447, IA=949, OA=793 12/9/2019 12/9/2019 2.00 SLOT WELLPR UREM T 7719.8 Reaming, 1.5 BPM @ 3950 7,719.8 7,721.8 19:00 21:00 PSI FS, BHP=3446 12/9/2019 12/9/2019 2.00 SLOT WELLPR UREM T 7721', Under reaming, 1.5 BPM @ 7,721.8 7,723.0 21:00 23:00 3950 PSI FS, BHP=3445 12/9/2019 12/10/2019 1.00 SLOT WELLPR UREM T 7723', Under reaming, 1.5 BPM @ 7,723.0 7,725.4 23:00 00:00 3950 PSI FS, BHP=3452 Midnight 7725.4 12/10/2019 12/10/2019 2.00 SLOT WELLPR UREM T Continue under reaming 1.5 BPM @ 7,725.4 7,727.3 00:00 02:00 3950 PSI FS, BHP=3455. Stall nd reset @ 7725.5, PUW=28K 12/10/2019 12/10/2019 2.00 SLOT WELLPR UREM T Continue reaming, 1.5 BPM @ 3950 7,727.3 7,729.7 02:00 04:00 PSI FS, BHP=3513 12/10/2019 12/10/2019 2.00 SLOT WELLPR UREM T Continue under reaming, 1.5 BPM @ 7,729.7 7,732.2 04:00 06:00 3950 PSI FS, BHP=3578 12/10/2019 12/10/2019 1.00 SLOT WELLPR UREM T OB reaming 1.51 bpm to 4,135 psi, 7,732.2 7,732.6 06:00 07:00 Diff=682 psi, WHP=156, BHP=3,553, IA=947, OA=819, pump sweeps 12/10/2019 12/10/2019 1.50 SLOT WELLPR TRIP T POOH, chasing sweeps to surface 7,732.6 52.4 07:00 08:30 12/10/2019 12/10/2019 1.00 SLOT WELLPR PULD T At surface space out, PUD LD 52.4 0.0 08:30 09:30 reaming BHA#9 12/10/2019 12/10/2019 1.30 SLOT WELLPR PULD T PU/MU Caliper assembly 0.0 0.0 09:30 10:48 Page 11/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 *iA 1 0 0 -6. IN Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/10/2019 12/10/2019 1.00 SLOT WELLPR PULD T Perform surface test w/caliper, on test, 0.0 22.0 10:48 11:48 trouble shoot, found electric issues with cable, make up new connection. Surface test good, 12/10/2019 12/10/2019 1.50 SLOT WELLPR TRIP T RIH with Caliper BHA #10 22.0 7,600.0 11:48 13:18 12/10/2019 12/10/2019 0.20 SLOT WELLPR DLOG T Log Formation for depth (-2.0') 7,600.0 7,657.7 13:18 13:30 12/10/2019 12/10/2019 0.40 SLOT WELLPR DLOG T Log down at 50 fpm 7,550'-7,727' 7,657.7 7,727.0 13:30 13:54 12/10/2019 12/10/2019 0.40 SLOT WELLPR DLOG T Make repeat pass 7,550'-7,727' 7,727.0 7,550.0 13:54 14:18 12/10/2019 12/10/2019 1.20 SLOT WELLPR TRIP T POOH, while uploaded real time data 7,550.0 21.7 14:18 15:30 to Haliburton town 12/10/2019 12/10/2019 1.00 SLOT WELLPR PULD T At surface, PUD Caliper assembly 21.7 0.0 15:30 16:30 12/10/2019 12/10/2019 0.50 SLOT WELLPR PULD T Inspect Caliper, found bent and 0.0 0.0 16:30 17:00 broken Bow Spring Centralizer. all parts returned to surface. Pre -load PDL 12/10/2019 12/10/2019 0.30 SLOT WELLPR PULD T Data in, discuss plan forward, BOT 0.0 0.0 17:00 17:18 dressed Hailey UR 4.875" in upper station, 4.125" in lower station 12/10/2019 12/10/2019 1.10 SLOT WELLPR PULD T PD Hailey UR assembly 0.0 54.2 17:18 18:24 12/10/2019 12/10/2019 1.30 SLOT WELLPR TRIP T RIH 54.2 7,405.0 18:24 19:42 12/10/2019 12/10/2019 0.20 SLOT WELLPR DLOG T Log formation for depth control (-2.0') 7,405.0 7,441.0 19:42 19:54 12/10/2019 12/10/2019 0.30 SLOT WELLPR TRIP T Continue IH 7,441.0 7,725.0 19:54 20:12 12/10/2019 12/10/2019 0.30 SLOT WELLPR UREM T Attempt to bring pump up online, 7,725.0 7,650.0 20:12 20:30 unable to fired up motor, pull up hole to 7,650', still can't bring pump online, pull up to 7,625', open EDC 12/10/2019 12/10/2019 1.40 SLOT WELLPR TRIP T POOH 7,650.0 48.0 20:30 21:54 12/10/2019 12/10/2019 0.50 SLOT WELLPR PULD T Tag up space out. PJSM PUD BHA 48.0 0.0 21:54 22:24 #11 12/10/2019 12/10/2019 1.00 SLOT WELLPR BHAH T Back off motor and under reamer. Test 0.0 0.0 22:24 23:24 motor inconclusive. Lay down motor. Everything on under reamer in spec. P/U back up motor and make up 12/10/2019 12/11/2019 0.60 SLOT WELLPR PULD T PD BHA#12 with 2 1/8" BOT straight 0.0 54.2 23:24 00:00 motor, Haily under reamer w/4.85" & 4.125' blades. Make up to coil and surface test 12/11/2019 12/11/2019 0.10 SLOT WELLPR PULD T Complete surface test BHA #12 54.2 54.2 00:00 00:06 12/11/2019 12/11/2019 1.40 SLOT WELLPR TRIP T Trip in hole BHA #12 54.2 7,405.0 00:06 01:30 12/11/2019 12/11/2019 0.10 SLOT WELLPR DLOG T Log formation for+6'. Inspect / clean 7,405.0 7,469.0 01:30 01:36 counter wheel. PUW=28K 12/11/2019 12/11/2019 0.40 SLOT WELLPR TRIP T Continue in well. 7651' close EDC 7,469.0 7,725.0 01:36 02:00 12/11/2019 12/11/2019 2.00 SLOT WELLPR UREM T 7725 start bringing pumps online. 7,725.0 7,731.0 02:00 04:00 Pressures high1.4 BPM @ 4811 PSI FS, BHP=3478. Start reaming down 12/11/2019 12/11/2019 2.00 SLOT WELLPR UREM T 7731', Continue reaming 1.4 BPM @ 7,731.0 7,735.0 04:00 06:00 4811 PSI FS, BHP=3494 Page 12/39 Report Printed: 1/7/2020 Q Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/11/2019 12/11/2019 2.00 SLOT WELLPR UREM T 7735'. Continue to under ream down, 7,735.0 7,737.7 06:00 08:00 High vibration. 1.48 BPM @ 4304 PSI FS, BHP=3510 12/11/2019 12/11/2019 2.00 SLOT WELLPR UREM T 7737.7 Continue to ream down. less 7,737.7 7,739.0 08:00 10:00 vibration still 4 to 5. 1.48 BPM @ 4304 PSI FS, BHP=3510 12/11/2019 12/11/2019 2.00 SLOT WELLPR UREM T 7739' Ream down. Vibration down to 3 7,739.0 7,741.0 10:00 12:00 - 2. 1.5 BPM @ 4956 PSI FS, BHP=3499 12/11/2019 12/11/2019 2.00 SLOT WELLPR UREM T 7741', reaming down. Vibrations at 7,741.0 7,743.2 12:00 14:00 mostly 2's 1.49 BPM @ 4654 PSI FS, BHP=3469. RIW=13.5K. Stalled @ 7742. PUW=28K Get right back to bottom 12/11/2019 12/11/2019 3.20 SLOT WELLPR UREM T 7743' Under reaming, vibrations 7,743.2 7,747.1 14:00 17:12 normal, 1.49 BPM @ 4654 PSI FS, BHP=3462 12/11/2019 12/11/2019 3.80 SLOT WELLPR UREM T 7747', continue reaming down, 7,747.1 7,751.6 17:12 21:00 vibrations at 1-2, 1.48 bpm, annular = 3458 psi, avg ROP = 1.2 fph 12/11/2019 12/12/2019 3.00 SLOT WELLPR UREM T 7751.6, continue reaming down, 7,751.6 7,755.3 21:00 00:00 annular = 3480 psi, pump = 4597 psi, avg ROP = 1.2 fph 12/12/2019 12/12/2019 2.60 SLOT WELLPR UREM T 7755.3', under-reaming down, annular 7,755.3 7,758.5 00:00 02:36 = 3473 psi, pump = 4579 psi, pump 5x5 sweeps 12/12/2019 12/12/2019 1.90 SLOT WELLPR TRIP T POOH to inspect tools & blades, 7,758.5 54.0 02:36 04:30 PUW = 27K, jog at 500', PJSM 12/12/2019 12/12/2019 0.50 SLOT WELLPR PULD T PUD BHA #12 54.0 0.0 04:30 05:00 12/12/2019 12/12/2019 0.70 SLOT WELLPR BHAH T Pull off under reamer and redress 0.0 0.0 05:00 05:42 12/12/2019 12/12/2019 0.90 SLOT WELLPR PULD T PD BHA# 13 with 2 1/8" BOT straight 0.0 54.2 05:42 06:36 motor, and Hailey Under reamer with 4.85 Upper blades / 4.125 lower blades. Make up to coil and surface test. Tag up and set counters 12/12/2019 12/12/2019 1.30 SLOT WELLPR TRIP T Trip in well, EDC open 54.2 7,405.0 06:36 07:54 12/12/2019 12/12/2019 0.30 SLOT WELLPR DLOG T Log formation for -1 foot, PUW=29K, 7,405.0 7,448.0 07:54 08:12 close EDC 12/12/2019 12/12/2019 0.10 SLOT WELLPR TRIP T Continue in well 7,448.0 7,753.0 08:12 08:18 12/12/2019 12/12/2019 2.70 SLOT WELLPR UREM T Bring pumps online, Wash down to 7,753.0 7,761.5 08:18 11:00 7758, Under ream from there, 1.48 BPM @ 4207 PSI FS, BHP=3476 12/12/2019 12/12/2019 3.00 SLOT WELLPR UREM T 7761 Continue reaming down, 1.48 7,761.5 7,765.0 11:00 14:00 BPM @ 4207 PSI FS, BHP=3476, Diff=153 12/12/2019 12/12/2019 1.50 SLOT WELLPR UREM T 7765 Continue reaming down, 1.48 7,765.0 7,766.3 14:00 15:30 BPM @ 4207 PSI FS, BHP=3476 12/12/2019 12/12/2019 0.20 SLOT WELLPR UREM T 7766', Stall, PUW=29K 7,766.3 7,766.0 15:30 15:42 12/12/2019 12/12/2019 1.60 SLOT WELLPR UREM T 7766.3 Under ream, 1.51 BPM @ 7,766.0 7,768.1 15:42 17:18 4440 PSI FS, BHP=3469 Page 13/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/12/2019 12/12/2019 2.00 SLOT WELLPR UREM T 7768.1', under -reaming, 1.51 bpm @ 7,768.1 7,769.5 17:18 19:18 4466 psi, annular- 3476 psi, vibrations to 4's, reduces to 1'-2's Stall at 7769.5', PUW = 30K, stall RBIH at 7766' (2X), run through w/ pumps off, back ream up through 7766', clean, stall at 7769.4' getting started on bottom 12/12/2019 12/12/2019 2.40 SLOT WELLPR UREM T Difficulty getting restarted at 7769.5', 7,769.5 7,770.0 19:18 21:42 FS = 1035 psi @ 1.46 bpm, annular = 3455 psi, pump = 4301 psi, vibrations at 4's 12/12/2019 12/12/2019 1.30 SLOT WELLPR UREM T 7770', under -reaming, pump = 4319 7,770.0 7,770.7 21:42 23:00 psi, annular = 3455 psi, reduce speed through perfs to avoid stalling (0.6 fph) Stall at 7770.4' 12/12/2019 12/13/2019 1.00 SLOT WELLPR UREM T PU, stall attempting to get to bottom at 7,770.7 7,770.7 23:00 00:00 7768.8'(2X), run past w/ pumps off clean, stall at 7770.3', slowly work to bottom w/ mutltiple stalls 12/13/2019 12/13/2019 2.00 SLOT WELLPR UREM T Go to 7770.8', bring up pumps to 1.5 7,770.7 7,771.4 00:00 02:00 bpm, back ream at 1 fpm to 7765.1', turn around, continue reaming down, avg ROP = 0.35 fph 12/13/2019 12/13/2019 2.00 SLOT WELLPR UREM T 7771.4', under -reaming, pump = 4420 7,771.4 7,772.6 02:00 04:00 psi, annular = 3492 psi, abg ROP = 0.6 fph 12/13/2019 12/13/2019 2.00 SLOT WELLPR UREM T 7772.6', under -reaming, pump = 4388 7,772.6 7,773.9 04:00 06:00 psi, annualr = 3496 psi 12/13/2019 12/13/2019 2.00 SLOT WELLPR UREM T 7773.9', Under reaming, 1.47 BPM @ 7,773.9 7,776.2 06:00 08:00 3619 PSI FS, BHP=3554 12/13/2019 12/13/2019 0.60 SLOT WELLPR UREM T 7776.2 Under reaming, 1.47 BPM @ 7,776.2 7,777.0 08:00 08:36 4417 PSI FS, BHP=3547 12/13/2019 12/13/2019 0.50 SLOT WELLPR DLOG T 7777 start out of well, logging up, 7,777.0 7,625.0 08:36 09:06 PUW=29K 12/13/2019 12/13/2019 1.50 SLOT WELLPR TRIP T Stop and open EDC, Trip out 7,625.0 54.0 09:06 10:36 12/13/2019 12/13/2019 0.90 SLOT WELLPR PULD T At surface, PUD BHA#13 Swap out 54.0 0.0 10:36 11:30 motor and under reamer Blades out lower 3.125 Upper out @ 4.25' 12/13/2019 12/13/2019 0.90 SLOT WELLPR PULD T PD BHA# 14 with new 2 1/8 BOT 0.0 54.2 11:30 12:24 straight motor and Hailey under reamer with 6.1" upper blades, 4.75" lower blades. Make up to coil and surface test 12/13/2019 12/13/2019 1.30 SLOT WELLPR TRIP T Trip in well, EDC open 54.2 7,405.0 12:24 13:42 12/13/2019 12/13/2019 0.40 SLOT WELLPR DLOG T Log formation for +15.. Clean counter 7,405.0 7,442.0 13:42 14:06 PUH and relog formation for zero correction 12/13/2019 12/13/2019 0.20 SLOT WELLPR TRIP T Continue in well, stop and close EDC 7,442.0 7,650.0 14:06 14:18 @ 7600 12/13/2019 12/13/2019 0.90 SLOT WELLPR UREM T 7650, Bring pumps online 1.48 BPM 7,650.0 7,711.0 14:18 15:12 @ 5250 PSI FS. Start easing down well, Stall @ 7680, Continue to wash down 7711 Heavy vibration 7680 to 7711 12/13/2019 12/13/2019 2.50 SLOT WELLPR UREM T 7711 Ream down, 1.5 BPM @ 5100 7,711.0 7,723.7 15:12 17:42 PSI FS, BHP=3532. Vibrations @ 3 - 4. Page 14/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/13/2019 12/13/2019 1.80 SLOT WELLPR UREM T 7723.7', reaming down, pump 5136 7,723.7 7,726.9 17:42 19:30 psi, annular= 3589 psi Stall @ 7725.3', 7726.1', 7727.47', 7727.7', continue w/ multiple stalls 12/13/2019 12/13/2019 2.00 SLOT WELLPR UREM T 7726.9', reaming down, pump = 5160 7,726.9 7,728.5 19:30 21:30 psi, continue to encounter multiple stalls making down -hole progres FS = 1400 psi @ 1.5 bpm, slow getting to bottom after stall at 7728.2', vibrations up to 4's, avg ROP = 0.8 fph 12/13/2019 12/13/2019 1.50 SLOT WELLPR UREM T 7728.5', reaming down, pump = 5071 7,728.5 7,731.5 21:30 23:00 psi, attempt to increase speed, sustained vibration of 4's 12/13/2019 12/14/2019 1.00 SLOT WELLPR UREM T 7731.5', reaming down, pump = 4915', 7,731.5 7,733.8 23:00 00:00 2.5 fph, continued significant vibrations (4's to 5's), avg ROP = 2.3 fph 12/14/2019 12/14/2019 2.00 SLOT WELLPR UREM T 7733.8', under -reaming, pump =4917 7,733.8 7,740.9 00:00 02:00 psi, vibrations at 5's (up to 6's for short periods), avg ROP = 3.6 fph 12/14/2019 12/14/2019 3.00 SLOT WELLPR UREM T 7740.9', under -reaming, pump = 4790 7,740.9 7,756.4 02:00 05:00 psi, vibrations at 4's, vibrations drop to 2's at - 7745.5', avg ROP = 5 fph 12/14/2019 12/14/2019 2.30 SLOT WELLPR UREM T 7756.4', under -reaming, pump = 4813 7,756.4 7,762.0 05:00 07:18 psi, vibrations at 2's, Stall @ 7762 12/14/2019 12/14/2019 2.00 SLOT WELLPR UREM T 7762' Restart after stall, 1.52 BPM @ 7,762.0 7,765.0 07:18 09:18 4886 PSI FS, BHP=3621, Vibration @ 2's 12/14/2019 12/14/2019 2.70 SLOT WELLPR UREM T 7765.5. Restart after stall, PUW=30K. 7,765.0 7,767.4 09:18 12:00 1.49 BPM @ 4905 PSI FS, BHP=3667. Stalled again @ 7766.7 12/14/2019 12/14/2019 2.10 SLOT WELLPR TRIP T 7667, PUH Cycle power for DPS, 7,767.4 51.7 12:00 14:06 Open EDC @ 7650, POOH for BOPE test 12/14/2019 12/14/2019 1.60 SLOT WELLPR PULD T Tag up - Space out, PJSM PUD BHA 51.7 0.0 14:06 15:42 #14. Blades out @ 4.5 lower, 5.5" uppers, Lay down BHA. Skid injector to floor. Pull checks. 12/14/2019 12/14/2019 0.70 SLOT WELLPR CTOP P Make up swizzle stic. Jet stack in 0.0 0.0 15:42 16:24 preperation for BOPE test. Roll CT to water 12/14/2019 12/14/2019 0.50 SLOT WELLPR SVRG P Service remaining valves in 0.0 0.0 16:24 16:54 preperation for BOPE test. Valve crew here to service tree 12/14/2019 12/14/2019 0.60 SLOT WHDBOP PRTS P Flood up, shell test 0.0 0.0 16:54 17:30 12/14/2019 12/14/2019 0.50 SLOT WHDBOP BOPE T Begin test following rig testing 0.0 0.0 17:30 18:00 checklist, witnessed by Lou Laubenstein of the AOGCC. Test pressure 250/4000 psi low/high. Difficulty holding high on test #1 (swab 2), call out valve crew to grease, carry on w/ next tests 12/14/2019 12/14/2019 2.50 SLOT WHDBOP BOPE P Continue BOP test (Test pressure 0.0 0.0 18:00 20:30 250/4000 psi low/high.) Valve crew arrives, grease Swab 2 (post test #6), re -test #1, difficulty holding high Page 15/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/14/2019 12/14/2019 0.60 SLOT WHDBOP BOPE T Re -grease Swab 2, function valve, no 0.0 0.0 20:30 21:06 good on high, re -grease w/ cooler grease, good low/high 12/14/2019 12/15/2019 2.90 SLOT WHDBOP BOPE P Continue with BOP test, accumulator 0.0 0.0 21:06 00:00 draw -down test, & inner reel valve 12/15/2019 12/15/2019 0.50 SLOT WHDBOP BOPE P Complete BOP test / inner reel iron 0.0 0.0 00:00 00:30 All tests passed inspection 12/15/2019 12/15/2019 0.20 SLOT WELLPR PRTS T Plumb in 100 bbl open -top tank to 0.0 0.0 00:30 00:42 tiger -tank line, pressure test hardline & manifold to 1500 psi, good, blow down with air 12/15/2019 12/15/2019 0.70 SLOT WELLPR CIRC T Displace coil to milling fluiid, blow 0.0 0.0 00:42 01:24 down drilling choke 12/15/2019 12/15/2019 0.20 SLOT WELLPR CTOP T Slide back cart, break off nozzle, 0.0 0.0 01:24 01:36 PJSM 12/15/2019 12/15/2019 1.10 SLOT WELLPR PULD T PU & PD BHA#15 Under -Reamer 0.0 0.0 01:36 02:42 (6.1" blades lower & upper), slide in cart, install checks in UQC, check pack -offs, MU to coil, tag up, set counters 12/15/2019 12/15/2019 1.40 SLOT WELLPR TRIP T RIH w/ BHA #15 0.0 54.0 02:42 04:06 12/15/2019 12/15/2019 0.30 SLOT WELLPR PULD T Log HRZ for +1' correction, PUW = 54.0 7,405.0 04:06 04:24 28K 12/15/2019 12/15/2019 0.10 SLOT WELLPR TRIP T Continue RIH, close EDC 7,405.0 7,760.0 04:24 04:30 12/15/2019 12/15/2019 2.50 SLOT WELLPR UREM T Begin under -reaming, FS = 970 psi @ 7,760.0 7,764.2 04:30 07:00 1.5 bpm, pump = 4574 psi Stalled at 7761.5' 12/15/2019 12/15/2019 2.00 SLOT WELLPR UREM T 7764.4, Under reaming, 1.5 BPM @ 7,764.2 7,767.1 07:00 09:00 4182 PSI FS, BHP=3484, Stalled @ 7767, PUW=30K 12/15/2019 12/15/2019 3.00 SLOT WELLPR UREM T 7767.14 Under ream, 1.49 BPM @ 7,767.1 7,768.5 09:00 12:00 4114 PSI FS, BHP=4102 12/15/2019 12/15/2019 3.00 SLOT WELLPR UREM T 7768.5 Under ream, 1.49 BPM @ 7,768.5 7,769.2 12:00 15:00 4150 PSI FS, BHP=3570, RIW=12.5K 12/15/2019 12/15/2019 3.00 SLOT WELLPR UREM T 7769.18, Under ream dowm. 1.51 7,769.2 7,771.2 15:00 18:00 BPM @ 4131 PSI FS,BHP=3586, many stalls at -7770.5', work through 12/15/2019 12/15/2019 3.00 SLOT WELLPR UREM T 7771.2', under -reaming, 1.5 bpm @ 7,771.2 7,773.6 18:00 21:00 435 psi, pump = 4086 psi, annular = 3592 psi, vibrations at 3's to 4's 12/15/2019 12/16/2019 3.00 SLOT WELLPR UREM T 7773.6', under -reaming, 1.5 bpm @ 7,773.6 7,777.3 21:00 00:00 428 psi, pump = 4117 psi, annular = 3610 psi, vibrations at 4's Stall at 7775.3', PU, continue reaming down 12/16/2019 12/16/2019 2.70 SLOT WELLPR UREM T 7777.3', under -reaming, 1.5 bpm @ 7,777.3 7,780.0 00:00 02:42 410 psi, pump = 4025 psi, annular = 3606 psi Pump sweeps (await to exit bit), trip to inspect tools/blades, open EDC 12/16/2019 12/16/2019 1.90 SLOT WELLPR TRIP T POOH, pumping 1.8 bpm, jog from 7,780.0 54.0 02:42 04:36 500', significant cement & metal returns unload from -500' (partially packing off choke), returns clear up, PJSM 12/16/2019 12/16/2019 1.00 SLOT WELLPR PULD T PUD BHA#15 Blades out @ 5.875 54.0 0.0 04:36 05:36 1 1 1 1 1each Page 16/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) .-o'. 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/16/2019 12/16/2019 0.80 SLOT WELLPR PULD T PD BHA#16 with 6.0 X 6.0 blades and 0.0 54.2 05:36 06:24 re run D-331 2.79" no go. Make up to coil and surface test. Tag up and set counters 12/16/2019 12/16/2019 1.30 SLOT WELLPR TRIP T Trip in hole, BHA #16. EDC open 54.2 7,405.0 06:24 07:42 12/16/2019 12/16/2019 0.20 SLOT WELLPR DLOG T Log HRZ for -1', PUW=27K, 7,405.0 7,450.0 07:42 07:54 12/16/2019 12/16/2019 0.10 SLOT WELLPR TRIP T Continue in well, Close EDC @ 7624 7,450.0 7,643.0 07:54 08:00 12/16/2019 12/16/2019 1.10 SLOT WELLPR UREM T Stop, Bring pumps on 1.5 BPM @ 7,643.0 7,770.0 08:00 09:06 4967 PSI FS, BHP=3490. Stall @ 7647. P/U and restart. High vibrations @ 6's 12/16/2019 12/16/2019 2.90 SLOT WELLPR UREM T 7770 Stall, P/U and restart 1.49 @ 7,770.0 7,776.0 09:06 12:00 4332 PSI FS BHP=3514, Stalled multiple times 7770 to 7772 12/16/2019 12/16/2019 2.10 SLOT WELLPR UREM T 7776 Stall and reset, PUW=28K, 1.49 7,776.0 7,780.0 12:00 14:06 BPM @ 4330 PSI FS, BHP=3587 12/16/2019 12/16/2019 0.70 SLOT WELLPR UREM T 7780' Start reaming uphole @ 3 FPM, 7,780.0 7,780.0 14:06 14:48 PUW=29K. Ream up to 7755 turn around back to 7780 mostly clean 12/16/2019 12/16/2019 0.30 SLOT WELLPR UREM T 7780 Back ream up, PUW=28K 7,780.0 7,720.0 14:48 15:06 12/16/2019 12/16/2019 0.40 SLOT WELLPR UREM T 7720 Ream down, RIW 12.9K, Stall @ 7,720.0 7,780.0 15:06 15:30 7726. P/U and ream right through 12/16/2019 12/16/2019 1.00 SLOT WELLPR UREM T Pump sweeps, Ream up to 7635 7,780.0 7,780.0 15:30 16:30 waiting on sweeps 12/16/2019 12/16/2019 2.00 SLOT WELLPR TRIP T POOH chasing sweeps, PUW=29K, 7,780.0 54.0 16:30 18:30 PJSM 12/16/2019 12/16/2019 0.80 SLOT WELLPR PULD T PUD BHA#16, blades came out 54.0 0.0 18:30 19:18 6"/5.75" top/bottom, mill came out 2.78" no-go 12/16/2019 12/16/2019 1.00 SLOT WELLPR CIRC T MU nozzle, jet stack, flush micro- 0.0 0.0 19:18 20:18 motion, PU test jnt, function rams 12/16/2019 12/16/2019 0.50 SLOT WELLPR PULD T PJSM, PU BHA#17 HES Caliper 0.0 22.0 20:18 20:48 Plan: Log CCL 7775' to 7550', Log CCL HRZ to 7770' 12/16/2019 12/16/2019 0.30 SLOT WELLPR TRIP T RIH w/ BHA#17, noisy data from 22.0 270.0 20:48 21:06 caliper on RIH, pause at 269', HES trouble -shoots issue, unable to resolve, POOH for new tools 12/16/2019 12/16/2019 0.20 SLOT WELLPR TRIP T Trip to surface, tag up, PJSM 270.0 22.0 21:06 21:18 12/16/2019 12/16/2019 0.40 SLOT WELLPR PULD T LD BHA #17 22.0 77-0- 21:18 21:42 12/16/2019 12/16/2019 1.10 SLOT WELLPR PULD T MU new caliper, PU BHA#18 HES 0.0 0.0 21:42 22:48 Caliper, unable to connect to caliper, trouble -shoot, no good, LD tools, test tools on rig floor 12/16/2019 12/16/2019 0.40 SLOT WELLPR WAIT T HES tech gathering & bringing 0.0 0.0 22:48 23:12 addiontal tools while hands at rig continue to trouble shoot tool issue Decsion made to PU & run dummy run while HES brings new tools to rig, clear rig floor of both calipers 12/16/2019 12/17/2019 0.80 SLOT WELLPR PULD T Load PDL, begin PD BHA#18 Dummy 0.0 62.0 23:12 00:00 1 1 Pilot -Hole Assembly Page 17/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/17/2019 12/17/2019 0.10 SLOT WELLPR PULD T Complete PD BHA#18 Dummy 0.0 62.0 00:00 00:06 Assembly, slide in cart, check pack - offs, MU to coil, tag up, set counters 12/17/2019 12/17/2019 1.40 SLOT WELLPR TRIP T RIH w/ BHA #18 62.0 7,415.0 00:06 01:30 12/17/2019 12/17/2019 0.30 SLOT WELLPR DLOG T Log HRZ for +2' correction, PUW = 7,415.0 7,463.0 01:30 01:48 29K, close EDC, enable CCL 12/17/2019 12/17/2019 0.30 SLOT WELLPR DLOG T CCL from HRZ to 7751' 7,463.0 7,753.0 01:48 02:06 12/17/2019 12/17/2019 0.20 SLOT WELLPR TRIP T Test interference per DD, RIH to 7,753.0 7,770.0 02:06 02:18 7782', stack out attempting to enter pilot -hole (3X) No interference down to 7782' 12/17/2019 12/17/2019 0.70 SLOT WELLPR DISP T Displace to new mud system, log K1 7,770.0 7,770.0 02:18 03:00 for +3' correction Paint tubing -tail flag at 7661.95' (yellow) 12/17/2019 12/17/2019 1.60 SLOT WELLPR TRIP T POOH, tag up 7,770.0 62.0 03:00 04:36 Perform injectivity test: shut choke, pressure up to 1056 psi, shut down pumps, drops to 1054 psi in 10 min, PJSM 12/17/2019 12/17/2019 SLOT WELLPR PULD T PUD BHA #18 62.0 0.0 04:36 04:36 12/17/2019 12/17/2019 1.40 SLOT WELLPR PULD T PU BHA #19 HES Caliper 0.0 22.0 04:36 06:00 12/17/2019 12/17/2019 1.50 SLOT WELLPR TRIP T Trip in well, 22.0 7,661.0 06:00 07:30 12/17/2019 12/17/2019 0.10 SLOT WELLPR DLOG T Log K1 tie in for+.5' 7,661.0 7,661.0 07:30 07:36 12/17/2019 12/17/2019 0.10 SLOT WELLPR TRIP T Continue in well 7,661.0 7,775.0 07:36 07:42 12/17/2019 12/17/2019 0.60 SLOT WELLPR DLOG T 7775'. Open fingers, Log up to 7548. 7,775.0 7,623.0 07:42 08:18 Close fingers. RBIH to 7775 and repeat logging pass up, Stop and paint flag 7623 12/17/2019 12/17/2019 1.30 SLOT WELLPR TRIP T 7623 Trip out BHA #19 7,623.0 15.0 08:18 09:36 12/17/2019 12/17/2019 0.30 SLOT WELLPR PULD T Lay down BHA #19 15.0 0.0 09:36 09:54 12/17/2019 12/17/2019 0.60 SLOT WELLPR SFTY T PJSM with HES cementers, Vac truck 0.0 0.0 09:54 10:30 drivers, and rig personnel 12/17/2019 12/17/2019 0.70 SLOT WELLPR PULD T Pull checks, M/U BHA#20. Stab on 0.0 15.4 10:30 11:12 well 12/17/2019 12/17/2019 1.60 SLOT WELLPR TRIP T RIH BHA #20 15.4 7,615.0 11:12 12:48 12/17/2019 12/17/2019 0.10 SLOT WELLPR DLOG T At flag, 0 correction 7,615.0 7,615.0 12:48 12:54 12/17/2019 12/17/2019 1.10 SLOT WELLPR TRIP T Continue in to 7775, PUW=27K, Batch 7,615.0 7,775.0 12:54 14:00 up cement. Time starts @ 13:23 12/17/2019 12/17/2019 0.40 SLOT WELLPR PRTS T Pressure test cementer to 4900 PSI 7,775.0 7,775.0 14:00 14:24 12/17/2019 12/17/2019 1.10 SLOT WELLPR CMNT T Cementers online, .5 BPM 5 BBI water 7,775.0 7,775.0 14:24 15:30 spacer, 10 BBIs 16.5 LB/Gal cement followed by 7 BBIs fresh water 12/17/2019 12/17/2019 1.20 SLOT WELLPR CMNT T Shut down cementers and isolate. 7,775.0 7,775.0 15:30 16:42 Come on with rig pump with 20 BBI Hi vis pill. .5 BPM @ 2427 PSI pump pressure Page 18139 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/17/2019 12/17/2019 0.30 SLOT WELLPR CMNT T 2.2 BBIs cement out of coil. Start 7,775.0 7,000.0 16:42 17:00 laying it in 13 FPM, .5 BPM, PUW28K go to 57 FPM @ 7614. 7230 pull to safety @ 100 FPM 12/17/2019 12/17/2019 1.30 SLOT WELLPR CIRC T At safety, Pump 2 BPM circulate 7,000.0 6,990.0 17:00 18:18 Bottoms up. See slight bit of cement coming up in returns. Out micro briefly up to 10.4 PPG 12/17/2019 12/17/2019 0.20 SLOT WELLPR TRIP T Wash down to to 7565'. Estimate 6,990.0 7,565.0 18:18 18:30 TOC @ 7570. PUH slowly until 10 BBIs out of coil 12/17/2019 12/17/2019 1.70 SLOT WELLPR TRIP T POOH chasing contaminated cement 7,565.0 15.0 18:30 20:12 12/17/2019 12/17/2019 0.30 SLOT WELLPR PULD T At surface. Shut in well with 600 PSI 15.0 0.0 20:12 20:30 on it. Lay down cementing BHA#20 12/17/2019 12/17/2019 0.20 SLOT WELLPR CTOP T Test E -Line - Good test, Make up 0.0 0.0 20:30 20:42 Nozzle 12/17/2019 12/17/2019 1.80 SLOT WELLPR CIRC T Stab on injector. Circulate 50 BBI 0.0 0.0 20:42 22:30 black water pill to flush rig surface equipment 12/17/2019 12/17/2019 0.50 SLOT WELLPR CTOP T Break off nozzle, clear rig floor 0.0 0.0 22:30 23:00 12/17/2019 12/18/2019 1.00 SLOT WELLPR CTOP T Open ram doors, begin inspecting 0.0 0.0 23:00 00:00 rams, replace door seals 12/18/2019 12/18/2019 3.00 SLOT WELLPR CTOP T Continue inspecting rams, & replace 0.0 0.0 00:00 03:00 door seals, changed out UQC, pressure test UQC, flood up stack, pressure test, lower 2" doors leaking, pull & replace door seals Await cement cure time 12/18/2019 12/18/2019 1.50 SLOT WELLPR CTOP T Re -pressure test stack, (low 250, high 0.0 0.0 03:00 04:30 4000), pressure dropping, trouble shoot, re -test hi/low, good test 12/18/2019 12/18/2019 1.10 SLOT WELLPR PULD T PJSM, PD BHA#21 Pilot -Hole 0.0 72.0 04:30 05:36 Assembly (spacer pup & 2.80" D331 smooth gauge mill), slide in cart, check pack -offs, MU to coil, tag up, set counters OD EDC @ 2.36" 12/18/2019 12/18/2019 1.40 SLOT WELLPR TRIP T RIH w/ BHA #21 72.0 7,425.0 05:36 07:00 12/18/2019 12/18/2019 0.20 SLOT WELLPR DLOG T Log HRZ for -1.5' correction, close 7,425.0 7,470.0 07:00 07:12 EDC, PUW = 25K 12/18/2019 12/18/2019 1.00 SLOT WELLPR TRIP T Continue RIH to 7595', no cement tag, 7,470.0 7,610.0 07:12 08:12 PU, confer w/town, decision made to RIH to 7610', do not find TOC, PUH, circulate bottoms up 12/18/2019 12/18/2019 1.50 SLOT WELLPR WAIT T Re -log HRZ +0.5' (while circulating 7,610.0 7,445.0 08:12 09:42 bottoms up), continue circualting awaiting plan forward, appear to have green cement over shakers 12/18/2019 12/18/2019 1.30 SLOT WELLPR DLOG T Stopt at 7450', shut down pumps to 7,445.0 7,450.0 09:42 11:00 record bottom hole temp over time, temp climbs from 122°F to 136°F over 1 hr 15 min HES is sending rep to PU cement sample left at the rig. Water sample is being pulled in clean container from wash -bay Page 19/39 Report Printed: 1/7/2020 - Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/18/2019 12/18/2019 0.60 SLOT WELLPR WAIT T Continue circulating, awaiting HES to 7,450.0 7,450.0 11:00 11:36 rig to pickup cement sample Decsion made RIH pumping full rate looking for TOC 12/18/2019 12/18/2019 1.10 PROD1 RPEQPT MILL T RIH, pumping 1.9 bpm, 10 fpm, tag 7,450.0 7,648.0 11:36 12:42 TOC at 7636', mill to 7637', -200 psi motorwork, PU & circulate bottoms up (taking "green" cement to 100 bbl open-top), mill to 7648', 2.5K WOB, 500 psi motorwork, 95 fph, PUW = 25K, circulate cutting up-hole (take slug to open-top tank) 12/18/2019 12/18/2019 1.00 PROD1 RPEQPT MILL T Milling, FS = 496 psi @ 1.9 bpm, stall 7,648.0 7,652.0 12:42 13:42 at 7649' (2X), difficulty getting started at 7652' (multiple stalls), PUW's 25K, unable to get started at 7652', PUH, annular climbing to 3931 psi, packing off, circulate below TT 12/18/2019 12/18/2019 2.30 PROD1 RPEQPT MILL T RBIH, FS = 450 psi @ 1.8 bpm, see 7,652.0 7,697.0 13:42 16:00 WOB at 7650', continue to have difficulty getting started, begin taking 1/10's (7650' is bottom) Roll bit to LS to get by 7650', bet by, roll back to 20° ROHS 12/18/2019 12/18/2019 0.30 PROD1 RPEQPT MILL T Milling, FS = 450 psi @ 1.8 bpm, dp = 7,697.0 7,716.0 16:00 16:18 984 psi, ROP = 60 fph, WOB = 2.2K 12/18/2019 12/18/2019 0.20 PROD1 RPEQPT WPRT T Wiper to TT, PUW = 28K 7,716.0 7,716.0 16:18 16:30 12/18/2019 12/18/2019 1.50 PROD1 RPEQPT MILL T Milling, FS = 450 psi @ 1.8 bpm, 7,716.0 7,729.0 16:30 18:00 pump = 4367 psi 12/18/2019 12/19/2019 6.00 PROD1 RPEQPT MILL T Milling, FS = 450 psi @ 1.8 bpm, OBM 7,729.0 7,745.0 18:00 00:00 pump = 4910 psi, WH 177 psi, IA 945 psi, OA 719 psi. ROP variabl3 0- 5 ft/hr stall, 7730.6' PU 30 k lbs stall, 7734.6' PU 30 k lbs stall, 7734.8' PU 31 k lbs 12/19/2019 12/19/2019 5.00 PROD1 RPEQPT MILL T Continue to mill ahead. 7,745.0 7,762.5 00:00 05:00 CT 4994 psi @ 1.83 bpm in/out. BHP 3486 psi, CT Wt 12 k lbs, WOB 0.5 k lbs, ROP variable 0 - 6 ft/hr, WH 150 psi, IA 959 psi, OA 802 psi 7759.44' PU Wt 31 k lbs 7759.44' PU Wt 32 k lbs 7762' PU Wt 30 k lbs 12/19/2019 12/19/2019 2.50 PROD1 RPEQPT MILL T Milling, FS = 450 psi @ 1.8 bpm, 7,762.5 7,764.6 05:00 07:30 pump 4926 psi, ROP variable 1-6 fph, stall at 7763.9' 12/19/2019 12/19/2019 3.00 PROD1 RPEQPT MILL T Milling, 1.8 bpm, pump = 4717 psi, dp 7,764.6 7,768.6 07:30 10:30 = 710 psi, PUH to tubing-tail, PUW = 30K Multiple stalls at 7768.5' 12/19/2019 12/19/2019 2.20 PROD1 RPEQPT MILL T Milling, 0.9K WOB, pump = 4706, dp = 7,768.6 7,769.5 10:30 12:42 714 psi, extremly low ROP, -0.4 fph, stall at 7769', PUW = 32K, stall at 7769.5', avg ROP = 0.41 fph 12/19/2019 12/19/2019 1.30 PROD1 RPEQPT MILL T Milling, continued low ROP, struggling 7,769.5 7,769.9 12:42 14:00 to make footage, 1.8 bpm, pump = 4644 psi, stall at 7769.7', bead up hiVis pill pit, pump 7x7 beades sweeps, stall 7769.9, PUW = 32K Page 20/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (WB) End Depth (ftKB) 12/19/2019 12/19/2019 2.00 PROD1 RPEQPT MILL T Short wiper awaiting beaded sweeps 7,769.9 7,771.5 14:00 16:00 to bit, able to keep WOB with reduced stalling Mlling, FS = 465 psi @1.8 bpm, pump 4653 psi, milling "break" at 7770', stall at 7770', 7770.2', PUW = 32K 7770.68', roll to LS for 0.1', WOB drops off, ROP increased, roll back to 20° ROHS, stall at 7771.1', pump beaded sweeps 12/19/2019 12/19/2019 7.50 PROD1 RPEQPT MILL T Milling, FS = 465 psi @ 1.8 bpm, 7,771.5 7,782.0 16:00 23:30 pump = 4722 psi, at 7771.6' roll LS for 0.1', roll back to 20°, stall 7772.5' 12/19/2019 12/19/2019 0.10 PROD1 RPEQPT REAM P TD Pilot hole. Pull back ream pass #1 7,782.0 7,626.0 23:30 23:36 as milled, 20° ROHS, 5 ft/min for 10' at 7646'-7636'. 12/19/2019 12/19/2019 0.30 PROD1 RPEQPT DLOG P PUH and tie into the HRZ for a +2' 7,626.0 7,488.6 23:36 23:54 correction 12/19/2019 12/20/2019 0.10 PROD1 RPEQPT TRIP P RBIH, dry drift TOC transition - clean! 7,488.6 7,657.0 23:54 00:00 12/20/2019 12/20/2019 0.10 PROD1 RPEQPT TRIP P Continue in hole 7,657.0 7,784.0 00:00 00:06 Confirm bottom @ 7784'- Paint flag, PU 32 k lbs 12/20/2019 12/20/2019 0.90 PROD1 RPEQPT REAM P PUH, performe 2 nd back ream pass, 7,784.0 7,573.6 00:06 01:00 as milled, 20° ROHS, 5 ft/min for 10' at 7646'-7636'. Pull two back reaming passes at 200 'ROHS. Dry drift clean Paint flag @ 7573.64' Open EDC, Flow check - Fail 12/20/2019 12/20/2019 1.50 PROD1 RPEQPT TRIP P POOH pumping 1.82 bpm holding 7,573.6 72.0 01:00 02:30 11.3 EMW at TD. Jog at 500' 12/20/2019 12/20/2019 1.20 PROD1 RPEQPT PULD P PJSM, Bump up, space out, checks 72.0 0.0 02:30 03:42 not holding, PUD BHA#21 following failed checks procedure. '*' Mill graded out 2.79" No Go 12/20/2019 12/20/2019 0.80 PROD1 RPEQPT CIRC P Stab injector, jet stack, unstab injector. 0.0 0.0 03:42 04:30 12/20/2019 12/20/2019 0.90 PROD1 RPEQPT PULD P PU BHA # 22, HES 24 arm caliper. 0.0 22.0 04:30 05:24 12/20/2019 12/20/2019 1.60 PROD1 RPEQPT TRIP P RIH w/ BHA #22 22.0 7,400.0 05:24 07:00 12/20/2019 12/20/2019 0.20 PROD1 RPEQPT DLOG P Log HRZ for -1.38' correction 7,400.0 7,432.0 07:00 07:12 12/20/2019 12/20/2019 0.40 PROD1 RPEQPT TRIP P Cotinue RI H, slow by TOC at 7636', 7,432.0 7,780.0 07:12 07:36 clean 12/20/2019 12/20/2019 0.20 PROD1 RPEQPT DLOG P Log 7780' to 7550' 7,780.0 7,550.0 07:36 07:48 12/20/2019 12/20/2019 0.20 PROD1 RPEQPT TRIP P Close caliper arms, RBIH 7,550.0 7,781.0 07:48 08:00 12/20/2019 12/20/2019 0.20 PROD1 RPEQPT DLOG P Log 7781' to 7550' 7,781.0 7,750.0 08:00 08:12 12/20/2019 12/20/2019 1.40 PROD1 RPEQPT TRIP P Close caliper arms, POOH, PJSM 7,750.0 22.0 08:12 09:36 12/20/2019 12/20/2019 0.40 PROD1 RPEQPT PULD P LD BHA #22 22.0 0.0 09:36 10:00 12/20/2019 12/20/2019 0.70 PROD1 RPEQPT WAIT P Recieve & evaluate caliper data, load 0.0 0.0 10:00 10:42 1 WS on rig Page 21/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/20/2019 12/20/2019 1.40 PROD1 RPEQPT PULD P PD BHA#23 Whipstock, break down 0.0 72.0 10:42 12:06 BHA in PDL, open EDC, carry on w/ PD Slide in cart, check pack -offs, MU to coil, tag up, set counters 12/20/2019 12/20/2019 1.30 PROD1 RPEQPT TRIP P RIH w/ BHA #23 72.0 7,425.0 12:06 13:24 12/20/2019 12/20/2019 0.40 PROD1 RPEQPT DLOG P Log HRZ for -1' correction, continue 7,425.0 7,641.0 13:24 13:48 RIH to log K1, PUW = 30K, pumps off, close EDC, log K1 for +1' correction 12/20/2019 12/20/2019 0.30 PROD1 RPEQPT WPST P Continue RIH, arrive at set depth, 7,641.0 7,772.0 13:48 14:06 bring up pumps & PU off WS, TOWS -7762', oriented HS, set down 4K WOB, good set 12/20/2019 12/20/2019 1.40 PROD1 RPEQPT TRIP P POOH, close EDC, PJSM 7,772.0 62.0 14:06 15:30 12/20/2019 12/20/2019 0.80 PROD1 RPEQPT PULD P PUD BHA #23 62.0 0.0 15:30 16:18 12/20/2019 12/20/2019 0.60 PROD1 WHPST PULD P PD BHA#24 Window Assembly (0.6° 0.0 74.7 16:18 16:54 AKO motor, new 2.80" string reamer, & 2.80" window mill) 12/20/2019 12/20/2019 1.40 PROD1 WHPST TRIP P Bump up, RIH, Park @ 7755', close 74.7 7,620.0 16:54 18:18 EDC, RIH 12/20/2019 12/20/2019 0.20 PROD1 WHPST DLOG P Log K1 for 0' correction. 7,620.0 7,646.1 18:18 18:30 12/20/2019 12/20/2019 0.40 PROD1 WHPST TRIP P Continue in hole, dry tag TOWS @ 7,646.1 7,763.0 18:30 18:54 7,763', CT Wt 11.8 k lbs, WOB 3 klbs, PU 31 k lbs PUH, set rate RBIH 12/20/2019 12/20/2019 1.40 PROD1 WHPST MILL P CT 4861 psi, BHP 3435 psi, Free spin 7,763.0 7,762.0 18:54 20:18 diff 471 psi. Stall 7 times, 7762.10 - 7762.18' tryed varying RIH speed down to as low as 0.5 ft/hr. 12/20/2019 12/20/2019 1.40 PROD1 WHPST MILL P Reduce rate to 1.52 bpm, CT 3754 psi 7,762.0 7,763.0 20:18 21:42 @ 1.53 bpm, BHP 3438 psi, Free spin 331 psi. Mill ahead 12/20/2019 12/21/2019 2.30 PROD1 WHPST MILL P Increase rate to 1.89 bpm, CT 4888 7,763.0 7,765.5 21:42 00:00 psi, BHP 3443 psi, Milling ahead, CT 10.2 k lbs, WOB 0.08 k lbs, ROP 1 ft/hr 12/21/2019 12/21/2019 2.30 PROD1 WHPST MILL P Contiune to mill exit window in 7" 7,765.5 7,768.4 00:00 02:18 Observe drop in WOB, mill off at bottom of window - 7768.4' 12/21/2019 12/21/2019 2.20 PROD1 WHPST MILL P Mill ahead, 11.8 k lbs CT Wt 0.1 k 7,768.4 7,772.0 02:18 04:30 WOB 7768.62' incresae ROP from 1 ft/hr to 1.5 ft/hr 12/21/2019 12/21/2019 0.50 PROD1 WHPST MILL P CT 4942 psi @ 1.89 bpm, BHP 3448 7,772.0 7,777.0 04:30 05:00 psi, Start drilling ahead. CT wt 9.5 lbs, WOB 2.56 k lbs, ROP 9 ft/hr TOWS = 7762', BOW = 7768.4' 12/21/2019 12/21/2019 0.70 PROD1 WHPST MILL P TD rat -hole at 7783' 7,777.0 7,783.0 05:00 05:42 12/21/2019 12/21/20191.90 PROD1 WHPST REAM P Perform reaming passes, HS, 30R, 7,783.0 7,783.0 05:42 07:36 30L, & LS Dry drift window up & down, clean, pump 5x5 sweeps 12/21/2019 12/21/2019 1.90 PROD1 WHPST TRIP P Open EDC, await sweeps to bit, 7,783.0 74.0 07:36 09:30 POOH Page 22/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/21/2019 12/21/2019 0.60 PROD1 WHPST PULD P PJSM, PUD BHA#24, string reamer& 74.0 0.0 09:30 10:06 mill came out 2.80" no-go 12/21/2019 12/21/2019 0.60 PROM DRILL CIRC P Blow down motor, MU nozzle, jet 0.0 0.0 10:06 10:42 stack, blow down micro -motion, break off nozzle 12/21/2019 12/21/2019 1.00 PROD1 DRILL PULD P PD BHA#25 Build Assembly (2.3° 0.0 72.0 10:42 11:42 AKO motor, RB Hughes bit), slide in cart, check pack -offs, MU to coil, tag up, set counters 12/21/2019 12/21/2019 1.50 PROD1 DRILL TRIP P RIH w/ BHA #25, close EDC 72.0 7,615.0 11:42 13:12 12/21/2019 12/21/2019 0.10 PROD1 DRILL DLOG P Log K1 for 0' correction 7,615.0 7,631.0 13:12 13:18 12/21/2019 12/21/2019 0.20 PROD1 DRILL TRIP P Continue RIH, clean through top of 7,631.0 7,783.0 13:18 13:30 pilot -hole, PUW = 32K, clean through window 12/21/2019 12/21/2019 0.70 PROD1 DRILL DRLG P Drilling, FS = 755 psi @ 1.9 bpm, 7,783.0 7,853.0 13:30 14:12 CWT = 9.9K @ 0.7K WOB, annular = 3618 psi, WHP = 293 psi, pump = 5475 psi Stall at 7790', PUW = 32K, PUW 35K from 7853' Swap to new mud system #2, hits bit @ 7843' 12/21/2019 12/21/2019 0.70 PROM DRILL DRLG P Drilling, reduce to 1.6 bpm, put more 7,853.0 7,917.0 14:12 14:54 WOB in attempt to build inclination, CWT = 9.7K @ 3.2K WOB, annular = 3599 psi, PUW = 29K 12/21/2019 12/21/2019 0.30 PROM DRILL WPRT P PUH for DD to log K1, LD ODS tools 7,917.0 7,615.0 14:54 15:12 12/21/2019 12/21/2019 0.30 PROM DRILL DLOG P Log K1 for+1' correction, RBIH 7,615.0 7,850.0 15:12 15:30 Log RA at 7770', TOWS = 7763', BOW = 7769.4' 12/21/2019 12/21/2019 0.10 PROM DRILL TRIP P RBIH to drill 7,850.0 7,917.0 15:30 15:36 12/21/2019 12/21/2019 2.40 PROM DRILL DRLG P Drilling, FS = 544 psi @ 1.6 bpm, 7,917.0 8,069.0 15:36 18:00 CWT = 9.2K @ 1 K WOB, annular = 3659 psi, WHP = 353 psi, pump = 4523 psi 12/21/2019 12/21/2019 2.60 PROD1 DRILL DRLG P Drilling, CT 4426 psi @ 1.6 bpm, BHP 8,069.0 8,219.0 18:00 20:36 3670 psi. WH 324 psi, IA 936 psi, OA 667 psi. CWT = 7.9K @ 1.9K WOB. 12/21/2019 12/21/2019 0.20 PROD1 DRILL WPRT P PU Wt 31 k lbs, Pull 200' wiper, RBIH 8,219.0 8,219.0 20:36 20:48 12/21/2019 12/21/2019 1.40 PROM DRILL DRLG P CT 4205 psi @ 1.6 bpm, BHP 8,219.0 8,341.0 20:48 22:12 3664psi, free spin 586 psi. WH 302 psi, CWT = 4.2k @ 3.0 k WOB. 12/21/2019 12/21/2019 0.70 PROM DRILL WPRT P PU Wt 31 k lbs, POOH on swab wipe. 8,341.0 7,603.0 22:12 22:54 Build TD'd. Saw -1.5k WOB tugs starting @ 8002'. High bend motor @ 90 ° ROHS when as drilled was 270° ROHS. RBIH to 8050', PUH, window, pilot hole clean, Park and open EDC 12/21/2019 12/22/2019 1.10 PROD1 DRILL TRIP P Continue to POOH. 7,603.0 1,476.0 22:54 00:00 12/22/2019 12/22/2019 0.40 PROD1 DRILL TRIP P Continue to POOH, PJSM, tag up, 1,476.0 70.1 00:00 00:24 space out. 12/22/2019 12/22/2019 1.20 PROM DRILL PULD P PUD BHA#25, build drilling assembly. 70.1 0.0 00:24 01:36 Page 23139 Report Printed: 1/7/2020 . - Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/22/2019 12/22/2019 0.20 PROD1 DRILL BOPE P BOPE Function test 0.0 0.0 01:36 01:48 12/22/2019 12/22/2019 1.10 PROD1 DRILL PULD P PD BHA#26, ERDAlat drilling 0.0 78.3 01:48 02:54 assembly, 0.6° AKO wA3 Hyc bit and fresh NOV agitator 12/22/2019 12/22/2019 1.50 PROD1 DRILL TRIP P RIH, park @ 500, close EDC, shallow 78.3 7,620.0 02:54 04:24 test agitator - good, continue in hole 12/22/2019 12/22/2019 0.20 PROD1 DRILL DLOG P Tie into the K1 for -1' correction 7,620.0 7,640.8 04:24 04:36 12/22/2019 12/22/2019 0.60 PROM DRILL TRIP P Continue to RIH. 7,640.8 8,341.0 04:36 05:12 12/22/2019 12/22/2019 2.40 PROM DRILL DRLG P Drilling, FS = 1087 psi @ 1.87 bpm, 8,341.0 8,622.0 05:12 07:36 CWT = 9K @ 1.4K WOB, annular = 3665 psi, WHP = 303 psi, pump = 5660 psi Pump efficiency down, aired up mud, add ScreenKlean, 220 fph max when continuously oscillating 12/22/2019 12/22/2019 0.40 PROD1 DRILL DRLG P PUW = 27K from 8622', Drilling, FS = 8,622.0 8,654.0 07:36 08:00 1160 psi @ 1.9 bpm, CWT = 3.8K @ 1 K WOB, annular = 3716 psi, WHP = 257psi, pump = 5700 psi Snubbing -4 CWT, pump sweeps, pull early wiper trip 12/22/2019 12/22/2019 0.70 PROM DRILL WPRT P Wiper up -hole, PUW = 29K, jog build, 8,654.0 7,615.0 08:00 08:42 clean through build, jog 7" casing, clean 12/22/2019 12/22/2019 0.10 PROM DRILL DLOG P Log K1 for +1' correction 7,615.0 7,644.0 08:42 08:48 12/22/2019 12/22/2019 0.40 PROM DRILL WPRT P Wiper in-hole, clean past TOC & 7,644.0 8,654.0 08:48 09:12 through window, RIW = 1 O 12/22/2019 12/22/2019 2.20 PROM DRILL DRLG P Drilling, FS = 1192 psi @ 1.9 bpm, 8,654.0 8,803.0 09:12 11:24 CWT = 3.53K @ 1.65K WOB, annular = 3694 psi, WHP = 265 psi, pump = 5923 psi, quickly go back to snubbing up to -7K Pump 10 bbl beads, improved weight transfer, pump addional 10 bbl to good effect, avg ROP = 68 fph 12/22/2019 12/22/2019 2.80 PROD1 DRILL DRLG P Drilling, CWT = 5.4K @ 1.4K WOB, 8,803.0 9,054.0 11:24 14:12 annular = 3743 psi, WHP = 155 psi, pump = 5861 psi Continue to pump beaded pills built from the active 12/22/2019 12/22/2019 0.20 PROD1 DRILL WPRT P Wiper up -hole, PUW = 27K 9,054.0 8,350.0 14:12 14:24 12/22/2019 12/22/2019 0.30 PROM DRILL WPRT P Wiper in-hole, RIW = 7K 8,350.0 9,054.0 14:24 14:42 12/22/2019 12/22/2019 2.10 PROM DRILL DRLG P Drilling, FS = 1160 psi, @ 1.87 bpm, 9,054.0 9,282.0 14:42 16:48 CWT = 3.4K @ 1.3K WOB, annular = 3720 psi, WHP = 203 psi, pump = 5915 psi, 200' wiper from 9282', PUW = 28K Continue pumping beads 12/22/2019 12/22/2019 2.30 PROD1 DRILL DRLG P Drilling, FS = 1232 psi, @ 1.87 bpm, 9,282.0 9,483.0 16:48 19:06 CWT = 6.6K @ 1 K WOB, annular = 3753 psi, WHP = 149 psi, pump = 6056 psi Page 24139 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (ftKB) 12/22/2019 12/22/2019 0.30 PROM DRILL WPRT P PU 29 k lbs, Wiper trip #2 - 1000' 9,483.0 8,478.0 19:06 19:24 12/22/2019 12/22/2019 0.40 PROM DRILL WPRT P PU 29 k lbs, RBIH 8,478.0 9,483.0 19:24 19:48 8670 ' slight set down 12/22/2019 12/23/2019 4.20 PROD1 DRILL DRLG P CT 5823 psi @ 1.86 in/out, BHP 3791 9,483.0 9,676.0 19:48 00:00 psi, targeting 11.8 ppg EMW at the window, 12.26 ppg @ the bit. Free spin 1148 psi, WH 243 psi, IA 963 psi, OA 792 psi. CT -4.6 k lbs, WOB 1 k lbs. 9514' returns fell from 78 gpm to 20 gpm, Picked up, RBIH, losses healed rapidly 9,594' PU Wt 34 k lbs 9,596' PU Wt 34 k lbs 9,623' PU Wt 38 k lbs 9677' PU Wt 37 k lbs 12/23/2019 12/23/2019 0.70 PROM DRILL DRLG P Drilling, CT 5868 psi, BHP 3786 psi, 9,676.0 9,703.0 00:00 00:42 CT Wt -5 k lbs, WOB 0.78 k lbs. 9,683' PU Wt 35 k lbs. 12/23/2019 12/23/2019 0.80 FROM DRILL WPRT P PU Wt 29 k lbs - pull long wiper to 9,703.0 7,716.0 00:42 01:30 window for tie in. 12/23/2019 12/23/2019 0.10 PROM DRILL DLOG P Tie into the K1 for a +3.5' correction. 7,716.0 7,636.6 01:30 01:36 12/23/2019 12/23/2019 0.40 PROM DRILL DLOG P RIH to 7716.17' MD, 5842.52' TVD 7,636.6 7,716.0 01:36 02:00 Trap 3660 psi - 12 ppg EMW observe pressure bleed stedily to 3480 psi in 7 minutes - 11.45 ppg EMW open choke bleed pressure to 3414 psi - 11.24 EMW. Obsery pressure fall to 3380 psi - 11.12 ppg EMW Bleed IA from 964 psi to 874 psi 12/23/2019 12/23/2019 1.20 PROM DRILL TRIP P RBIH 7,716.0 9,703.0 02:00 03:12 Set down twice at 8,592 and again at 8,668' pulled neg WOB to -1.6 k lbs, continue to RIH. Run out of push @ 8900' Stage beaded pill to bit, continue in hole. 12/23/2019 12/23/2019 2.90 PROM DRILL DRLG P CT 5665 psi @ 1.83 bpm, 1081 psi 9,703.0 9,903.0 03:12 06:06 free spin, BOBD CT -5 k lbs, WOB 0.9 k lbs, Swap to new mud system #3, new mud @ the bit 9,799' Old system retired with 0.9% DS and 2000' Pump 15 bbl beaded pills build from active mud 12/23/2019 12/23/2019 2.10 PROD1 DRILL DRLG P PUW = 37K, drilling, FS = 1131 psi, 9,898.0 10,019.0 06:06 08:12 @ 1.88 bpm, annular = 3817 psi, WHP = 277 psi, pump = 5788 psi Continue pumping beads, add —2% LoTorq to pill pit (test for increasing full active system), pump 15 bbl pill Page 25/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/23/2019 12/23/2019 0.80 PROM DRILL DRLG P Drilling, 15 bbl beaded & 2% LoTorq 10,019.0 10,103.0 08:12 09:00 pill exiting bit, PUW = 31 K, pill works to good effect, increased weight transfer & ROP PU with second lubed pill exiting bit, PUW = 28K, BOBD, again increase weight transfer 12/23/2019 12/23/2019 0.30 PROM DRILL WPRT P Wiper up -hole, PUW = 35k 10,103.0 9,103.0 09:00 09:18 12/23/2019 12/23/2019 0.50 PROM DRILL WPRT P Wiper in-hole, RIW = 5K 9,103.0 10,103.0 09:18 09:48 12/23/2019 12/23/2019 2.30 PROM DRILL DRLG P Drilling, FS = 1177 psi @ 1.88 bpm, 10,103.0 10,204.0 09:48 12:06 CWT = -1 K @ 0.8K WOB, annular = 3843 psi, WHP = 296 psi, pump = 6069 psi, lower ROP searching for pay, avg ROP = 44 fph 12/23/2019 12/23/2019 2.90 PROM DRILL DRLG P Drilling, CWT = snubbing, struggling 10,204.0 10,350.0 12:06 15:00 w/ weight transfer, annular = 3862 psi, WHP = 265 psi, pump = 6095 psi, avg ROP = 50 fph 12/23/2019 12/23/2019 1.50 PROM DRILL DRLG P Drilling, CWT = -6K @ 0.5K WOB, 10,350.0 10,427.0 15:00 16:30 annular = 3857 psi, WHP = 284 psi, pump = 5886 psi, avg ROP = 51 fph BHA wiper from 10,406', PUW = 29K, pump 15 bbl pill w/ 1% drillZone 12/23/2019 12/23/2019 2.10 PROM DRILL DRLG P Drilling, drillZone hits bit, ROP and 10,427.0 10,510.0 16:30 18:36 weight trnsfer continue to degrade. 12/23/2019 12/23/2019 0.30 PROM DRILL WPRT P PU Wt 31 k lbs, PUH on wiper #2 10,510.0 9,513.0 18:36 18:54 12/23/2019 12/23/2019 1.80 PROM DRILL WPRT P RBIH, unable to RIH past 9,973'. PUH 9,513.0 10,510.0 18:54 20:42 slowly while staging second bead pill to the bit. RH snubbing to -10 k lbs 12/23/2019 12/24/2019 3.30 PROM DRILL DRLG P CT 5930 psi @ 1.86 bpm, free spin 10,510.0 10,564.0 20:42 00:00 1082 psi, CT Wt -10 k lbs, WOB 0.8 k lbs. ROP slow and continualy slowing down. Geos lost, targeting 86°. 12/24/2019 12/24/2019 3.00 PROM DRILL DRLG P OBD 10,564.0 10,618.0 00:00 03:00 CT 6037, CT WT -9.8 k Isb, WOB 0.88 k lbs, ROP. Out of zone. 12/24/2019 12/24/2019 1.50 PROM DRILL DRLG P OBD 10,618.0 10,651.0 03:00 04:30 CT 6111, CT WT -9.6 k Isb, WOB 1.0 k lbs, ROP 16 Out of zone. 12/24/2019 12/24/2019 2.50 PROM DRILL DRLG P Drilling, CWT = -9.8K @ 0.9K WOB, 10,651.0 10,715.0 04:30 07:00 annular = 3881 psi, WHP = 247 psi, pump = 6122 psi, avg ROP = 26 fph 12/24/2019 12/24/2019 3.00 PROM DRILL DRLG P Drilling, CWT = -5.8K @ 1 K WOB, 10,715.0 10,817.0 07:00 10:00 annular = 3873 psi, WHP = 298 psi, pump = 4807 psi, avg ROP = 34 fph 12/24/2019 12/24/2019 2.80 PROM DRILL DRLG P Drilling, continual pumping of beads, 10,817.0 10,900.0 10:00 12:48 CWT = -7K @ 1 K WOB, annular = 3887 psi, pump sweeps, avg ROP = 30 fph 12/24/2019 12/24/2019 1.40 PROM DRILL WPRT P Wiper to tubing tail, PUW = 31 K, clean 10,900.0 7,620.0 12:48 14:12 through window, clean through pilit- hole, jog 7" casing 12/24/2019 12/24/2019 0.10 PROD1 DRILL DLOG P Log K1 for+5' correction 7,620.0 7,632.0 14:12 14:18 Page 26/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 12/24/2019 12/24/2019 3.70 PROD1 DRILL WPRT P Wiper in-hole, clean past TOC, clean 7,632.0 10,900.0 14:18 18:00 through window, pump beaded pills to aid in getting to bottom, reduce rate & running speed Difficulty getting to bottom, 0.45 bpm, slow running speed, unable to turn around after PUS, pull 1 OK over at 9950', come up to 9200', attempt to get turned around, good, work to bottom slowly at min rate & 50 bbl beaded pill 12/24/2019 12/24/2019 3.50 PROM DRILL DRLG P Drilling, FS = 1050 psi @ 1.8 bpm, 10,900.0 10,974.0 18:00 21:30 CWT = -8K @ 0.4 WOB, annular = 4000 psi, WHP = 182 psi, pump = 6016 psi, avg ROP = 21 fph 12/24/2019 12/24/2019 1.90 PROD1 DRILL DRLG P OBD @ 1.8 bpm, CWT = -8K @ 0.85 10,974.0 11,011.0 21:30 23:24 WOB, annular = 3938 psi, WHP = 250 psi, pump = 5050 psi ROP = 30 fph 12/24/2019 12/25/2019 0.60 PROD1 DRILL WPRT P PU Wt 39 k lbs, CPF3 called, Lost 11,011.0 10,776.0 23:24 00:00 power frame #5 & 6. PU, start generators and prepare to swap to rig power. 12/25/2019 12/25/2019 0.30 PROD1 DRILL WPRT P Continue to PUH. Rig generators 10,776.0 10,725.0 00:00 00:18 warmed up, confer with CPF# board operator to swap to rig power. CPF 3 power issues resolved 12/25/2019 12/25/2019 0.50 PROM DRILL TRIP P RBIH to drill, Snubbing, time out 50 10,725.0 11,011.0 00:18 00:48 bbl beads work slowly to bottom. 12/25/2019 12/25/2019 5.20 PROM DRILL DRLG P CT 4988 psi @ 1.55 bpm in/out - free 11,011.0 11,144.0 00:48 06:00 spin 816 psi, BHP 3919, 11.8 EMW @ the window, 12.66 ppg @ the bit. Ct Wt 9 k lbs, WOB 1 k lbs. 11,111 PU 40 k Ibs 11,114 PU 42 k lbs 11,119 PU 41 k lbs 12/25/2019 12/25/2019 3.00 PROM DRILL DRLG P CT 4855 psi @ 1.5 bpm, BHP 3946 11,144.0 11,210.0 06:00 09:00 psi, Ct Wt -11 k lbs, WOB 0.8 k lbs 12/25/2019 12/25/2019 3.00 PROM DRILL DRLG P CT 5238 psi @ 1.57 bpm, BHP 3966 11,210.0 11,245.0 09:00 12:00 psi, Ct Wt -9 k lbs, WOB 0.9 k lbs 12/25/2019 12/25/2019 3.00 PROM DRILL DRLG P CT 5300 psi @ 1.57 bpm, BHP 3968 11,245.0 11,279.0 12:00 15:00 psi, Ct Wt -9 k lbs, WOB 0.9 k lbs 12/25/2019 12/25/2019 1.20 PROM DRILL TRIP P CT 4853 psi @ 1.58 bpm, BHP 3970 11,279.0 11,300.0 15:00 16:12 psi, free spin 857 psi. Ct Wt 3.4 k lbs, WOB 0.84 k lbs ***New mud at the bit 11,279' 11295 PU Wt 42 k lbs 12/25/2019 12/25/2019 3.00 PROM DRILL TRIP P PU 36 k lbs, PUH on swab wiper. 11,300.0 78.3 16:12 19:12 12/25/2019 12/25/2019 1.50 PROD1 DRILL TRIP P RBIH 78.3 7,620.0 19:12 20:42 12/25/2019 12/25/2019 0.25 PROD1 DRILL DLOG P Log formation plus 1.5' 7,620.0 7,638.0 20:42 20:57 12/25/2019 12/25/2019 0.40 PROM DRILL TRIP P Perform SBHP @ 7,629.61' CTMD, 7,638.0 7,638.0 20:57 21:21 TVD 5,776.98', 11.089 ppg (AP -3,328 psi) 12/25/2019 12/25/2019 1.50 PROM DRILL TRIP P Continue IH, confirm TD 11,303' 7,638.0 11,303.0 21:21 22:51 12/25/2019 12/25/2019 0.75 PROD1 DRILL CIRC P Recip coil while circulating LRP 11,303.0 11,303.0 22:51 23:36 12/25/2019 12/26/2019 0.40 PROM DRILL TRIP P POOH, Laying in beaded 11.35 ppg, 11,303.0 10,804.0 23:36 00:00 paint TD flag 10,334 EOP (Yellow) Page 27/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (WB) End Depth (ftKB) 12/26/2019 12/26/2019 1.10 PROD1 DRILL TRIP P Continue POOH laying in 11.36 ppg 10,804.0 7,763.0 00:00 01:06 beaded LRP 12/26/2019 12/26/2019 0.20 PROM DRILL TRIP P Pull through window clean, continue 7,763.0 7,620.0 01:06 01:18 POOH w/BLRP 12/26/2019 12/26/2019 0.20 PROM DRILL DLOG P Log formation for Window flag 7,620.0 7,638.0 01:18 01:30 12/26/2019 12/26/2019 1.10 PROM DRILL TRIP P Continue POOH 7,638.0 78.3 01:30 02:36 12/26/2019 12/26/2019 0.50 PROM DRILL OWFF P Check well for flow, PJSM 78.3 78.3 02:36 03:06 12/26/2019 12/26/2019 0.90 PROD1 DRILL PULD P LD, flush, and inspect BHA, inspect 78.3 0.0 03:06 04:00 coil above CTC (no flat spot observed) "' Note: No losses observed. 12/26/2019 12/26/2019 0.40 COMPZ1 CASING PUTB P Prep RF for liner ops, PJSM 0.0 0.0 04:00 04:24 12/26/2019 12/26/2019 1.60 COMPZ1 CASING PUTB P PU Lower lat completion - 25 joints 0.0 995.4 04:24 06:00 of 2-3/8" L-80 ST-L 6.4 ppf R3 slotted liner under a shorty deployment sleve capped with a non ported bull nose. LOA 995.35' Kick drill while running slotted, crew change 12/26/2019 12/26/2019 0.80 COMPZ1 CASING PULD P PU BHA# 27, swap upper checks, 995.4 1,039.6 06:00 06:48 stab injector. 12/26/2019 12/26/2019 1.20 COMPZ1 CASING RUNL P Bump up, set counters, RIH w lower 1,039.6 7,642.0 06:48 08:00 completion. 12/26/2019 12/26/2019 0.20 COMPZ1 CASING DLOG P Tie into window flag for -1.95', 7,642.0 7,627.0 08:00 08:12 PU Wt 29 k WOB -6.3 k lbs. 12/26/2019 12/26/2019 2.60 COMPZ1 CASING RUNL P RIH with lower lat completion 7,627.0 11,301.0 08:12 10:48 S/D @ 8687' work pipe S/D @ 9079' work pipe S/D @ 9812' work pipe S/D @ 9920' work pipe to bottom clean sailing after 10,245' Tag bottom 11301' WOB 1.5 k CT Wt 4 k lbs, PU Wt 35 k WOB -4.28. Stage pump to 1.5 bpm, diff 1141 psi, PU Wt 26 k lbs WOB -2.6 k lbs "'TOL 10,307.65' 12/26/2019 12/26/2019 0.80 COMPZ1 CASING TRIP P PUH, reset counters, pump 49 bbl 11,301.0 9,966.0 10:48 11:36 LRP to bit 12/26/2019 12/26/2019 2.00 COMPZ1 CASING DISP P PUH laying in fresh LRP - 49 bbls 9,966.0 62.0 11:36 13:36 Paint yellow TO flag @ 9347.4' and white window flag @ 6744.24'. 12/26/2019 12/26/2019 1.40 COMPZ1 CASING OWFF P Flow check, LD BHA 27 over a dead 62.0 0.0 13:36 15:00 well. 12/26/2019 12/26/2019 0.90 COMPZ1 CASING PUTB P PU middle A lat completion - 23 joints 0.0 917.4 15:00 15:54 of 2-3/8" L-80 ST-L 6.4 ppf R3 slotted liner under a shorty deployment sieve capped with a ported bull nose. LOA 916.19' 12/26/2019 12/26/2019 0.20 COMPZ1 CASING PULD P PU BHA#28, middle section A lat 917.4 963.0 15:54 16:06 completion. 12/26/2019 12/26/2019 0.20 COMPZ1 CASING RUNL P Bump up, set counters, RIH, w middle 963.0 7,661.7 16:06 16:18 A completion. 12/26/2019 12/26/2019 0.20 COMPZ1 CASING DLOG P Tie into window flag for minus 6.0' 7,661.7 7,661.7 16:18 16:30 PU Wt 30 k WOB -3.8 k lbs. Page 28/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 MW Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 12/26/2019 12/26/2019 2.50 COMPZ1 CASING RUNL P Continue IH, intial set down 8,680', 7,661.7 10,307.0 16:30 19:00 work pipe, PUW 46/-18k DHWOB, continue IH to next set down 9,730', PUW 31k with minimal DHWOB observed. continue IH to bottom, PUW 33 k, DWHOB -3.6 k, set back down on bottom. 12/26/2019 12/26/2019 0.15 COMPZ1 CASING TRIP P Bring pump online 1.5 bpm / 1,123 psi 10,307.0 9,391.0 19:00 19:09 diff, PUH 24 k, minus 1.8 k DHWOB. remove liner length from counters. Line up pumping across the top. 12/26/2019 12/26/2019 0.65 COMPZ1 CASING TRIP P POOH, painting TD/EOP flag @ 9,391.0 7,751.0 19:09 19:48 8,350' (Yellow) 12/26/2019 12/26/2019 0.20 COMPZ1 CASING DLOG P Log the RA marker correction of plus 7,751.0 7,768.0 19:48 20:00 7.0' 12/26/2019 12/26/2019 1.50 COMPZ1 CASING TRIP P Continue POOH, paint window EOP 7,768.0 44.2 20:00 21:30 flag @ 6,600' (White), 12/26/2019 12/26/2019 0.50 COMPZ1 CASING OWFF P At surface, check well for flow, PJSM 44.2 44.2 21:30 22:00 12/26/2019 12/26/2019 0.75 COMPZ1 CASING PULD P LD, flush, and inspect BHA 44.2 0.0 22:00 22:45 12/26/2019 12/26/2019 0.40 COMPZ1 CASING PUTB P Prep RF for Liner OPS, PJSM, 0.0 0.0 22:45 23:09 12/26/2019 12/27/2019 0.85 COMPZ1 CASING PUTB P PU upper liner completion joint 1-15 0.0 592.3 23:09 00:00 12/27/2019 12/27/2019 0.85 COMPZ1 CASING PUTB P Continue PU slotted liner segment #3 592.3 993.0 00:00 00:51 (15-27 jts) 12/27/2019 12/27/2019 0.60 COMPZ1 CASING RUNL P PJSM, PU BOT LTB and BHI CoilTrak 993.0 1,037.2 00:51 01:27 tools, inspect pac-off (change -out), surface test CTK tools (good -test) 12/27/2019 12/27/2019 1.40 COMPZ1 CASING RUNL P Tag up, reset counter depths to zero, 1,037.2 7,636.5 01:27 02:51 RIH 12/27/2019 12/27/2019 0.15 COMPZ1 CASING RUNL P Correct to the EOP flag 7636.5' plus 7,636.5 7,636.5 02:51 03:00 1.0', PUW 29 k, DHWOB -6.1 k 12/27/2019 12/27/2019 0.85 COMPZ1 CASING RUNL P Continue IH, initial S/D @ 8,966' 7,636.5 9,390.2 03:00 03:51 worked pipe down hole to 9,034', continue IH fairly clean to bottom, PUW 32 k, DHWOB - 4.9 k, set back down on bottom. 12/27/2019 12/27/2019 0.20 COMPZ1 CASING RUNL P Bring pump online 1.34 bpm at 3,822 9,390.2 8,397.2 03:51 04:03 psi, Diff=1,046 psi, PUW 24 k, DHWOB=- 2.3 k, remove liner length from counter, line up across the top "' TOL @ 8,397.2- 12/27/2019 12/27/2019 1.60 COMPZ1 CASING TRIP P POOH 8,397.2 63.4 04:03 05:39 12/27/2019 12/27/2019 0.80 COMPZ1 CASING TRIP P LD BHA # 29 over a dead well. 63.4 0.0 05:39 06:27 12/27/2019 12/27/2019 0.50 PROD2 CASING TRIP P Pull checks, stab injector, jet stack 0.0 0.0 06:27 06:57 12/27/2019 12/27/2019 0.70 PROD2 CASING CTOP P Grease and flush 0.0 0.0 06:57 07:39 12/27/2019 12/27/2019 0.50 PROD2 WHDBOP BOPE P Reverse circ, 0.0 0.0 07:39 08:09 Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. 12/27/2019 12/27/2019 1.10 PROD2 WHDBOP BOPE T Fluid pack and test swab #2 to 4k psi- 0.0 0.0 08:09 09:15 fail, grease- fail, grease - pass, shell test to 4000 psi -good release valve crew Page 29139 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (WE) End Depth (WEI) 12/27/2019 12/27/2019 4.50 PROD2 WHDBOP BOPE P Test witness waived by Adam Earl - 0.0 0.0 09:15 13:45 AOGCC Test pressure 250/4000 psi low //high. Test 1. Swab 2 Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Bravo 5, and Tango 1 —install TIW test joint Test 7. Lower 2" pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP Test 9. Upper 2" pipe slip rams, Bravo 6,&8 Test 10. Bravo 7 — swap out 2" test joint for 2-3/8" Test 11. 2-3/8" pipe slip rams, TIW#2 — check N2 levels, swap to 2" test joint Test 12. Draw down accumulator, stabilized starting pressure 2400 psi, time to 200 psi increase 19 sec, full recovery time until pumps shut down 48, N2 bottles — average of 4, 2000 psi Tested all gas detectors, pits, cellar, rig floor all functioned properly, Verified flow alarms - PVT 12/27/2019 12/27/2019 0.50 PROD2 STK CTOP P Stab injector, drop off QTS, PT to 0.0 0.0 13:45 14:15 1500 psi - good, blow down, unstab injector, skid cart, install checks 12/27/2019 12/27/2019 0.90 PROD2 STK PULD P Crew change - PJSM, valve checklist 0.0 78.3 14:15 15:09 PU BHA#30, AL1 lateral drilling assembly. 0.5° AKO motor w dynamus and new agitator. Bump up, set counters. 12/27/2019 12/27/2019 1.40 PROD2 STK TRIP P RIH W BHA #30 78.3 7,620.0 15:09 16:33 12/27/2019 12/27/2019 0.20 PROD2 STK DLOG P Tie into the K1 for -0.5' correction 7,609.0 7,639.0 16:33 16:45 12/27/2019 12/27/2019 0.60 PROD2 STK DISP P PU Wt 27 K lbs 7,620.0 7,630.0 16:45 17:21 Pump mud to the bit 12/27/2019 12/27/2019 0.60 PROD2 STK DISP P Displace well bore to drilling fluid 7,630.0 7,630.0 17:21 17:57 12/27/2019 12/27/2019 0.30 PROD2 STK TRIP P Function closed EDC, continue IH 7,630.0 8,392.0 17:57 18:15 12/27/2019 12/27/2019 0.20 PROD2 STK TRIP P Dry tag TOB @ 8,392', PUH obtain 8,392.0 8,392.0 18:15 18:27 parameters. 12/27/2019 12/27/2019 1.80 PROD2 STK KOST P Kickoff Billet, 1.87 bpm at 5,658 psi, 8,392.0 8,394.7 18:27 20:15 Dlff=1,253 psi, WHP=124, BHP=3,712, IA=833, OA=565, time mill 1, 2, 3 foot as per RP with no stalls 12/27/2019 12/27/2019 1.10 PROD2 DRILL DRLG P Drill ahead, 1.87 bpm at 5,648 psi, 8,394.7 8,493.8 20:15 21:21 Diff=3,675 psi, WHP=232, BHP=3,675, IA=844, OA=590 Page 30/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/27/2019 12/27/2019 0.15 PROD2 DRILL WPRT P PUH, PUW 29 k, dry drift kickoff point 8,493.8 8,375.0 21:21 21:30 (Clean) "` Note: Kuparuk is in cold weather conditions, - 38°, vairance obtained for super sucker work, and loader opertions 12/27/2019 12/27/2019 0.15 PROD2 DRILL WPRT P Wiper back in hole, RIW 10 k 8,375.0 8,493.8 21:30 21:39 12/27/2019 12/27/2019 1.60 PROD2 DRILL DRLG P BOBD, 1.86 bpm at 4,044 psi, 8,493.8 8,716.0 21:39 23:15 DIff=1,235 psi, WHP=178, BHP=3,719, IA=852, OA=830 12/27/2019 12/27/2019 0.25 PROD2 DRILL WPRT P Pull Geo wiper up hole, PUW 28 k 8,716.0 8,416.0 23:15 23:30 12/27/2019 12/27/2019 0.30 PROD2 DRILL WPRT P Wiper back in hole, RIW 8,416.0 8,716.0 23:30 23:48 12/27/2019 12/28/2019 0.20 PROD2 DRILL DRLG P BOBD, 1.86 bpm at 5,053 psi, 8,716.0 8,737.0 23:48 00:00 DIff=1,227 psi, WHP=204, BHP=3,719, IA=859, OA=667 12/28/2019 12/28/2019 2.00 PROD2 DRILL DRLG P OBD, 1.85 bpm at 5,948 psi, OB 8,737.0 9,019.0 00:00 02:00 Diff=1,512, WHP=195, BHP=3,719, IA=859, OA=669 12/28/2019 12/28/2019 0.75 PROD2 DRILL DRLG P OBD, 1.85 bpm at 5,948 psi, OB 9,019.0 9,125.0 02:00 02:45 Diff=1,615, WHP=195, BHP=3,739, IA=858, OA=665 12/28/2019 12/28/2019 0.30 PROD2 DRILL WPRT P Wiper up hole, PUW 31 k 9,125.0 8,425.0 02:45 03:03 12/28/2019 12/28/2019 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 9.4 k 8,425.0 9,125.0 03:03 03:18 12/28/2019 12/28/2019 1.50 PROD2 DRILL DRLG P OBD, 1.85 bpm at 5,948 psi, OB 9,125.0 9,328.0 03:18 04:48 Diff=1,512, WHP=195, BHP=3,719, IA=859, OA=669 12/28/2019 12/28/2019 0.50 PROD2 DRILL WPRT P PUW 30 k - Geo wiper - geo's lost 9,328.0 9,143.0 04:48 05:18 12/28/2019 12/28/2019 0.10 PROD2 DRILL WPRT P RBIH 9,143.0 9,328.0 05:18 05:24 12/28/2019 12/28/2019 3.00 PROD2 DRILL DRLG P CT 5844 psi @ 1.83 bpm in/out, BHP 9,328.0 9,640.0 05:24 08:24 3725 psi, Free spin 1373 psi, OBD CT 5 k lbs, WOB 1 k lbs 12/28/2019 12/28/2019 0.50 PROD2 DRILL WPRT P PUW 33 k lbs - 3rd wiper to the 9,640.0 7,785.0 08:24 08:54 window for tie in 839'500 Ib WOB tug @ the billet 8197' small amount of motor work and MOB to 0.6klbs 7955 - 7874 -500 lbs WOB 12/28/2019 12/28/2019 0.10 PROD2 DRILL DLOG P Tie into the RA tag for +3' corretion 7,785.0 7,811.0 08:54 09:00 12/28/2019 12/28/2019 0.80 PROD2 DRILL WPRT P RBIH 7,811.0 9,640.0 09:00 09:48 12/28/2019 12/28/2019 4.10 PROD2 DRILL DRLG P CT 5812 psi @ 1.82 bpm in/out, BHP 9,640.0 9,966.0 09:48 13:54 3829 psi, diff 1312 psi. OBD -3 k lbs, WOB 1.26 k lbs, WH 166 psi, IA 875 psi, OA 717 psi. 12/28/2019 12/28/2019 1.10 PROD2 DRILL DRLG P PU 33 k lbs - reduce rate in an atempt 9,966.0 10,050.0 13:54 15:00 to target more WOB in order to get some turn. CT 4839 psi @ 1.54 bpm, diff 1007 psi, BHP 3815 psi, 11.8 ppg @ the window, 12.36 ppg @ the bit. CT Wt - 5 k lbs, WOB 1.12 k lbs 12/28/2019 12/28/20190.20 PROD2 DRILL WPRT P PU on Wiper #1 - PU Wt 30 k lbs 10,050.0 9,050.0 15:00 15:12 I Page 31/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/28/2019 12/28/2019 1.00 PROD2 DRILL WPRT P RBIH 9,050.0 10,050.0 15:12 16:12 12/28/2019 12/28/2019 1.80 PROD2 DRILL DRLG P CT 6025 psi @ 1.82 bpm in/out, Diff 10,050.0 10,160.0 16:12 18:00 1321 psi, BHP 3885. WH 90 psi, IA 879 psi, OA 742 psi. CT Wt -5 k lbs, WOB 1.2 k lbs 12/28/2019 12/28/2019 2.00 PROD2 DRILL DRLG P OBD, 1.83 bpm at 5,748 psi, OB 10,160.0 10,260.0 18:00 20:00 Diff=1,524 psi, WHP=90, BHP=3,885, IA=869, OA=713 12/28/2019 12/28/2019 2.20 PROD2 DRILL DRLG P OBD, 1.83 bpm at 5,748 psi, OB 10,260.0 10,450.0 20:00 22:12 Diff=1,484 psi, WHP=276, BHP=3,860, IA=869, OA=713 12/28/2019 12/28/2019 0.40 PROD2 DRILL WPRT P Wiper up hole, PUW 34 k 10,450.0 9,450.0 22:12 22:36 12/28/2019 12/28/2019 0.30 PROD2 DRILL WPRT P Wiper back in hole, RIW 7.5 k 9,450.0 10,450.0 22:36 22:54 12/28/2019 12/29/2019 1.10 PROD2 DRILL DRLG P BOBD, 1.85 bpm at 5,297 psi, Off 10,450.0 10,522.0 22:54 00:00 bottom DIff= 1,462, WHP=269, BHP=3,857, IA=869, OA=687 12/29/2019 12/29/2019 1.20 PROD2 DRILL DRLG P OBD, 1.86 bpm at 5,895 psi, On 10,522.0 10,579.0 00:00 01:12 bottom diff=1,360 psi, WHP=262, BHP=3,872, IA=870, OA=691 12/29/2019 12/29/2019 2.00 PROD2 DRILL DRLG P OBD, 1.85 bpm at 5,889 psi, 10,579.0 10,619.0 01:12 03:12 OBD=1,306 psi, WHP=223, BHP=3,899, IA=875, OA=717, crossing into high gamma +/- 150 api, continue drilling ahead 12/29/2019 12/29/2019 1.20 PROD2 DRILL DRLG P OBD, 1.84 bpm at 5,886 psi, On 10,619.0 10,638.0 03:12 04:24 bottom diff=1,378 psi, WHP=262, BHP=3,919, IA=875, OA=718 12/29/2019 12/29/2019 1.60 PROD2 DRILL DRLG P OBD, 1.84 bpm at 5,886 psi, On 10,638.0 10,661.0 04:24 06:00 bottom diff=1,378 psi, WHP=262, BHP=3,919, IA=875, OA=718 12/29/2019 12/29/2019 3.30 PROD2 DRILL DRLG P OBD, PU @ 10,662' PU Wt 32 k lbs 10,661.0 10,699.0 06:00 09:18 CT 5932 pi @ 1.83 bpm in/out, free spin 1226 psi, BHP 3945 psi - targeting 11.8 ppg @ the window - 12.7 ppg @ the bit. CT -7 k lbs, WOB 0.3 k lbs 12/29/2019 12/29/2019 1.00 PROD2 DRILL WPRT P PU Wt 33 k lbs. Pull up hole above 10,699.0 7,782.0 09:18 10:18 hot gamma. slight WOB tugs until clear of hot gamma @ 10,554'. Attempt to turn around @ 10,348', no success. Pull long wiper to window for tie in Cutting ration is breaking trend and increasing rapidly, 0.3 bbls cutting returned on the trip. 12/29/2019 12/29/2019 0.20 PROD2 DRILL DLOG P Tie into the RA tag for a +4.5' 7,782.0 7,807.0 10:18 10:30 correction. 12/29/2019 12/29/2019 1.10 PROD2 DRILL WPRT P RBIH 7,807.0 10,699.0 10:30 11:36 S/D at historic spot 9,329', work through slowly S/D 10,580' PU continue in hole. WOB spikes to 1 k from 10,567'- 10,614'. 12/29/2019 12/29/2019 3.00 PROD2 DRILL WPRT P CT 6005 psi @ 1.85 bpm in / out. 10,699.0 10,777.7 11:36 14:36 BHP 3876 psi diff 1190 psi, WH 231 psi, IA 876 psi, OA 736 psi, CT -8 k lbs, WOB 1.2 k lbs. 12/29/2019 12/29/2019 2.40 PROD2 DRILL WPRT P OBD - CT 6170 psi @ 1.85 bpm in / 10,777.7 10,830.0 14:36 17:00 out. BHP 3906 psi, WH 196 psi, IA 879 psi, OA 760 psi, CT -8 k lbs, WOB 0.92 k lbs. Page 32/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/29/2019 12/29/2019 2.00 PROD2 DRILL DRLG P OBD, 1.86 bpm at 5,762 psi, DIff=914, 10,830.0 10,867.0 17:00 19:00 WHP=202. BHP=3,918, IA=887, OA=790 12/29/2019 12/29/2019 2.00 PROD2 DRILL DRLG P OBD, 1.86 bpm at 5,762 psi, DIff=914, 10,867.0 10,900.0 19:00 21:00 WHP=202. BHP=3,918, IA=887, OA=790 12/29/2019 12/29/2019 1.00 PROD2 DRILL DRLG P OBD, 1.86 bpm at 5,762 psi, DIff=914, 10,900.0 10,909.0 21:00 22:00 WHP=202. BHP=3,918, IA=887, OA=790 12/29/2019 12/29/2019 0.80 PROD2 DRILL WPRT P Wiper up hole, PUW 35 k, pull heavy 10,909.0 8,450.0 22:00 22:48 @ 10,572' CTSW 47 k, DHWIOB 7.5 k 12/29/2019 12/30/2019 1.20 PROD2 DRILL WPRT P Wiper back in hole with low surface 8,450.0 10,618.0 22:48 00:00 weight -3 to -5 k, pumping beads 12/30/2019 12/30/2019 0.15 PROD2 DRILL WPRT P Continue wiper back in hole working 10,618.0 10,667.0 00:00 00:09 pipe through tight spot @ 10,544'- 10,667', stackout beads, build pill with addtional beads 12/30/2019 12/30/2019 0.85 PROD2 DRILL WPRT P PUH above tight area, Pull 52 k 10,667.0 10,220.0 00:09 01:00 CTSW, 10,598' 12/30/2019 12/30/2019 0.50 PROD2 DRILL WPRT P Unable to RBIH, circluate addtional pill 10,220.0 9,860.0 01:00 01:30 with beads and raise lube in system #6 wtih 1 % to-torq 12/30/2019 12/30/2019 1.30 PROD2 DRILL WPRT P RBIH, work pipe back to bottom 9,860.0 10,909.0 01:30 02:48 slowly 12/30/2019 12/30/2019 3.20 PROD2 DRILL DRLG P BOBD, 1.5 bpm at 4,884 psi, Off 10,909.0 10,935.0 02:48 06:00 Bottom 1070 psi, WHP=288, BHP=3,949, IA=874, OA=733 —Average ROP 8 ft/hr 12/30/2019 12/30/2019 2.60 PROD2 DRILL DRLG P BOBD, 1.5 bpm at 5116 psi, 10,935.0 10,961.0 06:00 08:36 WHP=182, BHP=3921, IA=879, OA=750 12/30/2019 12/30/2019 2.90 PROD2 DRILL WPRT P PU Wt 38 k lbs 10,961.0 78.3 08:36 11:30 Unable to RBIH, town called TD, Pull swab wiper to surface. Pull heavy, 10,633 - 10,561'-5 k WOB to 50 k CT Wt, could not RBIH, clean after 10,560', billet and window clean. Jog at 680', continue out of hole, 0.5 MIS of solids returned on the trip. 12/30/2019 12/30/2019 1.40 PROD2 DRILL TRIP P RBIH 78.3 7,599.0 11:30 12:54 start 1 ppb beaded pill down the coil 12/30/2019 12/30/2019 0.10 PROD2 DRILL DLOG P Tie into the K1 for no correction. 7,599.0 7,640.0 12:54 13:00 12/30/2019 12/30/2019 0.30 PROD2 DRILL TRIP P Perform SBHP @ 7,707' CTMD, TVD 7,640.0 7,707.0 13:00 13:18 5,868' Trap 3526 psi pressure bled slowly to 3511 psi over 5 min Bleed well to 3390 psi pressure held constant after climbing the 3399 psi over 5 min Bleed well to 3352 psi, pressure increased to 3362 then stabilized over 7 minutes " BHP 11.1 ppg EMW - Page 33/39 Report Printed: 1/7/2020 ` Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (ftKB) 12/30/2019 12/30/2019 1.60 PROD2 DRILL TRIP P Continue IH to 10,550' - Beads exiting 7,707.0 10,221.0 13:18 14:54 hte bit @ 9,300' 8212'2 k WOB spike 8395'0.4 k WOB spike at billet 9338', 1.7 k WOB spike - historic S/D 10221 - slight pack off event - PU to 10095, RBIH 12/30/2019 12/30/2019 0.90 PROD2 DRILL TRIP P PUH to clean up for OH anchored 10,221.0 7,853.0 14:54 15:48 billet on wiper to window. 12/30/2019 12/30/2019 0.75 PROD2 DRILL TRIP P RBIH pumping beaded active pill to 7,853.0 9,640.0 15:48 16:33 the bit. WOB spikes at 9324'- historic and 9451' 12/30/2019 12/30/2019 2.00 PROD2 DRILL DISP P POOH laying in active beaded mud 9,640.0 78.3 16:33 18:33 pill. 12/30/2019 12/30/2019 1.70 PROD2 DRILL PULD P At surface, PUD drilling assembly wtih 78.3 0.0 18:33 20:15 open EDC, checks not holding, function BHI CoilTrak tools close EDC, continue PUD 12/30/2019 12/30/2019 1.50 PROD2 STK PULD P PD, Open Hole Anchored billet and 0.0 72.7 20:15 21:45 CoilTrak tools 12/30/2019 12/30/2019 1.50 PROD2 STK TRIP P RIH, with OH Anchored Billet 72.7 7,622.0 21:45 23:15 assembly BHA#31 12/30/2019 12/30/2019 0.20 PROD2 STK DLOG P Log formation for depth minus 1.0', 7,622.0 7,648.0 23:15 23:27 PUW 27 k 12/30/2019 12/31/2019 0.55 PROD2 STK TRIP P RIH to bottom with weight bobbles @ 7,648.0 9,037.0 23:27 00:00 7,823' (6k DHWOB), 7,836' (8k DHWOB), 8,400' (8.5k DHWOB) 12/31/2019 12/31/2019 0.30 PROD2 STK TRIP P Continue IH with OH Anchored billet 9,037.0 9,651.8 00:00 00:18 12/31/2019 12/31/2019 0.20 PROD2 STK TRIP P On depth, PUW=31 k, Run back in 9,651.8 9,640.0 00:18 00:30 hole to setting depth, bring pump up to shear @ 4,400 psi, set down DHWOB=3.58k 12/31/2019 12/31/2019 1.70 PROD2 STK TRIP P POOH 9,640.0 72.7 00:30 02:12 12/31/2019 12/31/2019 1.40 PROD2 STK PULD P PUD setting tools BHA# 31 72.7 0.0 02:12 03:36 12/31/2019 12/31/2019 0.80 PROD2 STK PULD P Install 2.5" nozzle, stab INJH, reverse 0.0 0.0 03:36 04:24 circ, unstab INJH, change out BHI Upper Quick (houred out) 12/31/2019 12/31/2019 1.30 PROD2 STK PULD P PD Kickoff/Drilling Assembly BHA#32, 0.0 78.2 04:24 05:42 bump up space out 12/31/2019 12/31/2019 0.30 PROD2 STK PULD T RIH w BHA#32 78.2 222.0 05:42 06:00 Lost comms to tool @ 85.5' MWD troubleshooting, park at 222' 12/31/2019 12/31/2019 0.40 PROD2 STK PULD T PUH, bump up, space out. 222.0 78.2 06:00 06:24 12/31/2019 12/31/2019 0.80 PROD2 STK PULD T Partial PUD, un stab injector, BHA#23 78.2 78.2 06:24 07:12 left hanging in the hole. Remove upper Quick sleve, approxi' foot of wire hanging with shorted/ burnt section 1/4" above the boot. test E - line, test tool. Repair connection, Stab injector, bump up, 12/31/2019 12/31/2019 0.30 PROD2 STK TRIP T RIH w BHA# 32. 78.2 497.0 07:12 07:30 Lose comms with tool at 497' Park, Troubleshoot tools 12/31/2019 12/31/2019 0.30 PROD2 STK TRIP T PUH, bump up, space out 497.0 78.2 07:30 07:48 Page 34/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (W]3) 12/31/2019 12/31/2019 1.00 PROD2 STK PULD T Partial PUD, un stab injector, BHA#23 78.2 78.2 07:48 08:48 left hanging in the hole. Remove upper Quick sleve, approxi' foot of wire hanging with shorted/ burnt section pulled out of the boot. 12/31/2019 12/31/2019 1.10 PROD2 STK PULD T PUD and stand back BHA, LD agitator 78.2 0.0 08:48 09:54 and motor. Cut 18' of coil - remove flat spots. Decide to pump slack. 12/31/2019 12/31/2019 2.30 PROD2 STK CIRC T Cut off CTC, boot wire, stab on, pump 0.0 0.0 09:54 12:12 slack back to 2.9 bpm, surge rate 5 times, pop off no wire movement. Stab back on, pump to 2.9 bpm, surge rate 3 times, hear wire move. pop off. 12/31/2019 12/31/2019 3.30 PROD2 STK CTOP T Cut coil, found wire at 47', rig down 0.0 0.0 12:12 15:30 hydrulic cutter and hand cut, Ream and install new CTC pull test to 35 k lbs - good, rehead, test wire - good torque up, PT to 4500 psi - good. 12/31/2019 12/31/2019 1.10 PROD2 STK PULD T PD BHA#33. 0.0 78.2 15:30 16:36 12/31/2019 12/31/2019 0.40 PROD2 STK CIRC T Pump slack forward 1 coil vol @ -1.9 78.2 78.2 16:36 17:00 bpm 12/31/2019 12/31/2019 0.20 PROD2 STK TRIP T RIH pumping 1 bpm 78.2 497.0 17:00 17:12 12/31/2019 12/31/2019 1.40 PROD2 STK TRIP P Close EDC, Shallow test agitator- 497.0 7,616.0 17:12 18:36 good, open EDC, continue to RIH pumping 1 bpm. 12/31/2019 12/31/2019 0.20 PROD2 STK DLOG P Tie into the K1 for -0.5' correction 7,616.0 7,635.9 18:36 18:48 12/31/2019 12/31/2019 1.00 PROD2 STK TRIP P Close EDC, continue in hole. Window 7,635.9 9,641.6 18:48 19:48 and billet clean. SD @ 9293' roll LS, continue in hole. Tag TOB 9641.6' PU and set rate RBIH 12/31/2019 12/31/2019 1.00 PROD2 STK KOST P CT 5870 psi @ 1.85 in/out, free spin 9,640.8 9,641.8 19:48 20:48 diff 1277 psi, BHP 3818 psi targeting 11.8 @ the window, WH 125 psi, IA 851 psi OA 613 psi. CT 12.7 k lbs, 0.6 k lbs Ease into billet, feed a few tenths then engage auto driller at 1 ft/hr 12/31/2019 12/31/2019 0.50 PROD2 STK KOST P Increase ROP to 2 f/hr CT 10.5 k lbs 9,641.8 9,642.8 20:48 21:18 WOB 0.00, WOB spiked to 1 k lbs @ 9,642'no stall, drilled off. 12/31/2019 12/31/2019 0.25 PROD2 STK KOST P Increase ROP to 3 f/hr CT Wt 8.8 lbs, 9,642.8 9,645.0 21:18 21:33 WOB 0.4 Poor weight transfer, billet milling atypical. 12/31/2019 12/31/2019 1.30 PROD2 DRILL DRLG P Drill Ahead, 1.8 bpm at 5,909 psi, On 9,645.0 9,722.0 21:33 22:51 bottom diff=3,801 psi, WHP=193, BHP=3,799, IA=860, OA=663 1/1/2020 1/1/2020 0.35 PROD2 DRILL DRLG P Drill Ahead, 1.8 bpm at 5,909 psi, On 9,722.0 9,746.0 00:00 00:21 bottom diff=3,801 psi, WHP=193, BHP=3,799, IA=860, OA=663 1/1/2020 1/1/2020 0.15 PROD2 DRILL WPRT P Pull up hole to drift kickoff point, PUW 9,746.0 9,630.0 00:21 00:30 29 k 1/1/2020 1/1/2020 0.15 PROD2 DRILL WPRT P Wiper back in hole, RIW 5.5 k 9,630.0 9,746.0 00:30 00:39 1/1/2020 1/1/2020 4.50 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,682 psi, Off 9,746.0 10,145.0 00:39 05:09 Bottom Diff=1,187 psi, WHP=177, BHP=3,804, IA=861, OA=667 Page 35/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) Y 3H-01 • • a' r Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 1/1/2020 1/1/2020 0.30 PROD2 DRILL WPRT P Wiper up hole PUW 28k 10,145.0 9,666.5 05:09 05:27 1/1/2020 1/1/2020 0.30 PROD2 DRILL WPRT P Wiper back in hole, RIW -3.Ok 9,666.5 10,145.0 05:27 05:45 1/1/2020 1/1/2020 6.25 PROD2 DRILL DRLG P BOBD, 1.80 bpm at 4,776 psi, Off 10,145.0 10,550.0 05:45 12:00 Bottom Diff=903 psi, WHP=209, BHP=3,862, IA=867, OA=717 1/1/2020 1/1/2020 0.30 PROD2 DRILL WPRT P Pull wiper up hole to 9,700', PUW 31 k 10,550.0 9,700.0 12:00 12:18 1/1/2020 1/1/2020 0.30 PROD2 DRILL WPRT P Wiper back in hole RIW 2.0 k 9,700.0 10,550.0 12:18 12:36 1/1/2020 1/1/2020 6.65 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,722 psi, Off 10,550.0 10,951.0 12:36 19:15 bottom Diff=1,205 psi, WHP=150, BHP=3,836, IA=872, OA=744 *** Note: :New mud at the bit 10,654' 1/1/2020 1/1/2020 1.40 PROD2 DRILL WPRT P Wiper up hole PUW- 35k 10,951.0 7,617.2 19:15 20:39 1/1/2020 1/1/2020 0.10 PROD2 DRILL DLOG P Tie into the K1 for -2.5' correction 7,617.2 20:39 20:45 1/1/2020 1/1/2020 1.34 PROD2 DRILL WPRT P Wiper back in hole, RIW- -4.3k 7,617.2 10,951.0 20:45 22:05 1/1/2020 1/2/2020 1.91 PROD2 DRILL DRLG P BOBD, 1.5 bpm at 4758 psi, 10,951.0 11,003.0 22:05 00:00 WHP=371, BHP=3,894, IA=857, OA=666 1/2/2020 1/2/2020 2.00 PROD2 DRILL DRLG P BOBD, 1.57 bpm at 4,490 psi, Off 11,003.0 11,047.0 00:00 02:00 Bottom Diff=1,084 psi, WHP=283, BHP=3,943, IA=866, OA=715 1/2/2020 1/2/2020 2.40 PROD2 DRILL DRLG P BOBD, 1.57 bpm at 4,490 psi, Off 11,047.0 11,118.0 02:00 04:24 Bottom Diff=1,084 psi, WHP=283, BHP=3,943, IA=866, OA=715 1/2/2020 1/2/2020 2.00 PROD2 DRILL DRLG P BOBD, 1.86 bpm at 5,300 psi, Off 11,118.0 11,169.0 04:24 06:24 Bottom Diff=1,110 psi, WHP=275, BHP=3,932, IA=866, OA=715 1/2/2020 1/2/2020 2.00 PROD2 DRILL DRLG P BOBD, 1.86 bpm at 5,300 psi, Off 11,169.0 11,215.0 06:24 08:24 Bottom Diff=1,110 psi, WHP=275, BHP=3,932, IA=866, OA=715 1/2/2020 1/2/2020 2.00 PROD2 DRILL DRLG P BOBD, 1.86 bpm at 5,300 psi, Off 11,215.0 11,271.0 08:24 10:24 Bottom Diff=1,110 psi, WHP=275, BHP=3,932, IA=866, OA=715 1/2/2020 1/2/2020 2.00 PROD2 DRILL DRLG P BOBD, 1.86 bpm at 5,300 psi, Off 11,271.0 11,316.0 10:24 12:24 Bottom Diff=1,110 psi, WHP=275, BHP=3,932, IA=866, OA=715 1/2/2020 1/2/2020 1.20 PROD2 DRILL DRLG P BOBD, 1.86 bpm at 5,592 psi, Off 11,316.0 11,350.0 12:24 13:36 Bottom Diff=1,110 psi, WHP=260, BHP=3,932, IA=868, OA=721 1/2/2020 1/2/2020 0.30 PROD2 DRILL WPRT P Wiper up hole PUW 34 k 11,350.0 10,500.0 13:36 13:54 1/2/2020 1/2/2020 0.60 PROD2 DRILL WPRT P Wiper back in hole, RIW 0 k 10,500.0 11,350.0 13:54 14:30 1/2/2020 1/2/2020 2.00 PROD2 DRILL DRLG P BOBD, 1.81 bpm at 5,519 psi, Off 11,350.0 11,428.0 14:30 16:30 Bottom Diff=1,110 psi, WHP=231, BHP=3,941, IA=870, OA=740 1/2/2020 1/2/2020 2.00 PROD2 DRILL DRLG P BOBD, 1.85 bpm at 5,544 psi, Off 11,428.0 11,517.0 16:30 18:30 Bottom Diff=1,110 psi, WHP=255, BHP=3,966, IA=871, OA=742 1/2/2020 1/2/2020 2.00 PROD2 DRILL DRLG P BOBD, 1.84 bpm at 5,552 psi, Off 11,517.0 11,588.0 18:30 20:30 Bottom Diff=1,110 psi, WHP=255, BHP=3,960, IA=871, OA=742 1/2/2020 1/2/2020 2.50 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 5,934 psi, Off 11,517.0 11,640.0 20:30 23:00 Bottom Diff=1,110 psi, WHP=263, BHP=4,009, IA=870, OA=740 Page 36/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 1/2/2020 1/3/2020 1.00 PROD2 DRILL TRIP P POOH for swab wiper. PU- 38k 11,640.0 9,181.0 23:00 00:00 1/3/2020 1/3/2020 2.00 PROD2 DRILL TRIP P Cont POOH for swab wiper. PU- 38k 9,181.0 71.0 00:00 02:00 1/3/2020 1/3/2020 1.50 PROD2 DRILL TRIP P RIH to K1 maker to tie in 71.0 7,621.0 02:00 03:30 1/3/2020 1/3/2020 0.10 PROD2 DRILL DLOG P Tie into the K1 for -0.0' correction 7,621.0 7,629.0 03:30 03:36 1/3/2020 1/3/2020 0.20 PROD2 DRILL OWFF P Perform SBHP test ECD=11.16 ppg, 7,629.0 7,629.0 03:36 03:48 3,350 psi @ 7,580' RKB / 5,776.72' TVD 1/3/2020 1/3/2020 1.70 PROD2 DRILL TRIP P Cont RIH to confirm TD 7,629.0 11,643.0 03:48 05:30 1/3/2020 1/3/2020 0.50 PROD2 DRILL TRIP P Confirm TD, recip pipe while 11,643.0 11,643.0 05:30 06:00 circulating Beaded LRP 1/3/2020 1/3/2020 1.50 PROD2 DRILL TRIP P POOH, while laying in beaded 11.35 11,643.0 7,050.0 06:00 07:30 ppg completion fluid up to 7,050' 1/3/2020 1/3/2020 1.10 PROD2 DRILL TRIP P Continue POOH 7,050.0 78.2 07:30 08:36 1/3/2020 1/3/2020 0.50 PROD2 DRILL OWFF P At surface, check well for flow, PJSM 78.2 78.2 08:36 09:06 1/3/2020 1/3/2020 0.30 PROD2 DRILL PULD P LD, drilling assembly BHA #33 78.2 0.0 09:06 09:24 1/3/2020 1/3/2020 0.50 PROD2 DRILL CTOP P PU Test Joint, perform Fuction test 0.0 0.0 09:24 09:54 1/3/2020 1/3/2020 0.60 COMPZ2 CASING PUTB P Prep rig floor for liner ops, PJSM 0.0 0.0 09:54 10:30 1/3/2020 1/3/2020 1.50 COMPZ2 CASING PUTB P PU liner segment #1 (32 jts) 0.0 979.8 10:30 12:00 1/3/2020 1/3/2020 0.50 COMPZ2 CASING PUTB P PU/MU CoilTrak tools, surface test 979.8 1,024.0 12:00 12:30 (good), stab INJH, tag up, reset counters 1/3/2020 1/3/2020 0.25 COMPZ2 CASING RUNL P RIHw/liner segment#1 (32jts 1,024.0 1,099.0 12:30 12:45 slotted), bring pump online 0.3 bpm, Diff=1,942 psi, shut down pump, decision was made to POOH to surface 1/3/2020 1/3/2020 0.70 COMPZ2 CASING RUNL T POOH to surface, PJSM, unstab 1,099.0 979.8 12:45 13:27 INJH, trouble shoot differiential pressure, break off Coil, slide cart back to sump, bring pump online (clear), slide cart to home position, break off GS (clear), break off BHI float sub, break apart inspect checks (clear), LD CoilTrak tools into the pipe shed (clear), All seems to be clear. 1/3/2020 1/3/2020 0.60 COMPZ2 CASING RUNL P PU/MU BHA#34 979.8 1,024.0 13:27 14:03 1/3/2020 1/3/2020 1.30 COMPZ2 CASING RUNL P RIH w/Liner segment #1, bring pump 1,024.0 7,414.4 14:03 15:21 online 0.35 bpm at 473 psi 1/3/2020 1/3/2020 0.15 COMPZ2 CASING RUNL P Correct to the EOP flag +10.0', PUW 7,414.4 7,424.4 15:21 15:30 30 k 1/3/2020 1/3/2020 1.75 COMPZ2 CASING RUNL P Continued IH towards bottom. 7,424.4 11,643.0 15:30 17:15 Tag bottom 11 643'WOB 1.7 k CT Wt 11 k lbs, Stage pump to 1.5 bpm, diff 1212 psi, PU Wt 26 k lbs WOB 0.4 k lbs '"'TOL 10,663.2' 1/3/2020 1/3/2020 2.00 COMPZ2 CASING TRIP P POOH, reset counters & lay in LRP 11,643.0 0.0 17:15 19:15 1/3/2020 1/3/2020 0.50 COMPZ2 CASING OWFF P Flow check& LD BHA #34 0.0 0.0 19:15 19:45 1 I I I Page 37/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 1/3/2020 1/3/2020 1.00 COMPZ2 CASING P RIHw/liner segment #2 (40 jts 0.0 19:45 20:45 slotted), bring pump online 0.3 bpm, Diff=400 psi 1/3/2020 1/4/2020 3.25 COMPZ2 CASING RUNL P RIH w/ liner segment #2 (40 jts)RIH 0.0 6,065.0 20:45 00:00 1/4/2020 1/4/2020 0.10 COMPZ2 CASING RUNL P RIH w/ liner segment #2 (40 jts)RIH 6,065.0 7,660.0 00:00 00:06 1/4/2020 1/4/2020 0.20 COMPZ2 CASING DLOG P Tie into white flag at 7,663'. -4.66' 7,660.0 7,663.0 00:06 00:18 correction 1/4/2020 1/4/2020 1.30 COMPZ2 CASING RUNL P RIH w/ liner segment #2 (40 jts)RIH 7,663.0 10,663.0 00:18 01:36 Continued IH towards bottom. Tag bottom 10,663.2' WOB 1.7 k CT Wt 11 k lbs, Stage pump to 1.5 bpm, diff 1135 psi, PU Wt 27 k lbs WOB 0.4 k lbs "`TOL 9,447.51' 1/4/2020 1/4/2020 2.40 COMPZ2 CASING RUNL P Reset all counters POOH paint TD 10,663.0 44.2 01:36 04:00 flag - 7,854.22' (Yellow) paint window flag at 6044.22' (Red) 1/4/2020 1/4/2020 0.50 COMPZ2 CASING OWFF P At surface, flow check well, PJSM 44.2 44.2 04:00 04:30 1/4/2020 1/4/2020 0.70 COMPZ2 CASING PUTB P LD setting tools 44.2 0.0 04:30 05:12 1/4/2020 1/4/2020 0.30 COMPZ2 CASING PUTB P Prep RF for liner ops 0.0 0.0 05:12 05:30 1/4/2020 1/4/2020 2.20 COMPZ2 CASING PUTB P PU Liner segment #3 (52 jts) 0.0 1,587.8 05:30 07:42 1/4/2020 1/4/2020 0.75 COMPZ2 CASING PUTB P PJSM, PU/MU BHI CoilTrak tools, 1,587.8 1,632.0 07:42 08:27 perform surface test (good) 1/4/2020 1/4/2020 1.30 COMPZ2 CASING RUNL P RIH with AL1 liner segment #3 (52 jst 1,632.0 7,734.0 08:27 09:45 slotted) 1/4/2020 1/4/2020 0.20 COMPZ2 CASING RUNL P Correction at the EOP flag minus 7.0', 7,734.0 7,734.0 09:45 09:57 PUW 31 k 1/4/2020 1/4/2020 0.50 COMPZ2 CASING RUNL P Continue IH 7,734.0 9,447.5 09:57 10:27 1/4/2020 1/4/2020 0.20 COMPZ2 CASING RUNL P Tag bottom, PUW 35 k, set back 9,447.5 7,859.8 10:27 10:39 down, bring pump online, 1.58 bpm at 4,240 psi, 1077 diff, PUW 25 k, remove liner length from counters 1/4/2020 1/4/2020 0.20 COMPZ2 CASING RUNL P PUH to logging depth 7,859.8 7,755.0 10:39 10:51 1/4/2020 1/4/2020 0.15 COMPZ2 CASING RUNL P Log the RA marker correction of plus 7,755.0 7,773.0 10:51 11:00 7.0' 1/4/2020 1/4/2020 0.20 COMPZ2 CASING RUNL P RIH, tag TOL @ 7854.5' 7,773.0 7,854.5 11:00 11:12 1/4/2020 1/4/2020 1.20 COMPZ2 CASING TRIP P POOH 7,854.5 44.2 11:12 12:24 1/4/2020 1/4/2020 0.50 COMPZ2 CASING PULD P At surface, check well for flow, PJSM 44.2 44.2 12:24 12:54 1/4/2020 1/4/2020 0.30 COMPZ2 CASING PULD P LD setting tools 44.2 0.0 12:54 13:12 1/4/2020 1/4/2020 0.30 COMPZ2 CASING PUTB P Prep RF for liner ops 0.0 0.0 13:12 13:30 1/4/2020 1/4/2020 0.75 COMPZ2 CASING PUTB P PU/MU AL1 liner segement #4 (solid 0.0 289.6 13:30 14:15 joints/ swell packer) 1/4/2020 1/4/2020 0.30 COMPZ2 CASING PUTB P PU/MU CoilTrak tools, surface test 289.6 334.2 14:15 14:33 (good) 1/4/2020 1/4/2020 1.50 COMPZ2 CASING RUNL P Tag up, reset counters, RIH 334.2 7,715.0 14:33 16:03 1/4/2020 1/4/2020 0.30 COMPZ2 CASING RUNL P At flag no correction, PUW 29 k, 7,715.0 7,854.5 16:03 16:21 continue towards bottom Page 38/39 Report Printed: 1/7/2020 Operations Summary (with Timelog Depths) 3H-01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 1/4/2020 1/4/2020 0.20 COMPZ2 CASING RUNL P Tag on depth, PUW 29 k, set back 7,854.5 7,854.0 16:21 16:33 down, bring pump up to 1.5 bpm / 1,237 diff, remove liner length from counters 1/4/2020 1/4/2020 0.75 COMPZ2 CASING DISP P Circulate SW to GS 7,854.0 7,854.0 16:33 17:18 1/4/2020 1/4/2020 0.70 COMPZ2 CASING DISP P POOH, displacing well to SW 7,854.0 2,500.0 17:18 18:00 1/4/2020 1/4/2020 1.00 COMPZ2 CASING FRZP P Pump 30 bbls of diesel to freeze 2,500.0 2,500.0 18:00 19:00 protect 1/4/2020 1/4/2020 1.20 COMPZ2 CASING TRIP P POOH & LD tools 2,500.0 0.0 19:00 20:12 1/4/2020 1/5/2020 3.80 DEMOB WHDBOP RURD P Nipple down, rig down & prep to move 0.0 0.0 20:12 00:00 to 1 R-23 1/5/2020 1/5/2020 1.00 DEMOB WHDBOP RURD P PJSM, change out swab valve 0.0 0.0 00:00 01:00 1/5/2020 1/5/2020 2.00 DEMOB WHDBOP OTHR P Run through rig down check list 0.0 0.0 01:00 03:00 1/5/2020 1/5/2020 1.00 DEMOB WHDBOP NUND P ND BOPE & prep for rig move 0.0 0.0 03:00 04:00 Rig Release @ 04:00am Page 39/39 Report Printed: 1/7/2020 Winston, Hugh E (CED) From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty- Sherrod@contractor.conocophillips.com> Sent: Wednesday, February 5, 2020 6:00 AM To: Winston, Hugh E (CED) ( / Subject: FW: 3H -01A / I �(— Good morning Hugh, The engineer sent me the below answer and I will update our files. From: Plunkett, Ethan T <Ethan.T.Plunkett@conocophillips.com> Sent: Tuesday, February 04, 2020 3:38 PM To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann. Haggerty -Sherrod @contractor.conocophillips.com> Subject: RE: 31-1-01A Hi Ann, The viscosity measurement was not yet available. The viscosity for this well test is 24.8 degrees API. Best, Ethan From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod @contractor.conacophillips.cam> Sent: Tuesday, February 4, 2020 3:29 PM To: Plunkett, Ethan T <Ethan.T.Plunl<ett@conocophillips.com> Subject: RE: 3H -01A Ethan I just received this statement from AOGCC regarding Production Test Data: For 31-1-01A, in box 27 the Oil gravity is reported as N/A. It is my understanding that this measurement must be taken on the test oil production. Can you determine why it is not applicable in this case? Can you tell me the answer to that? Ann From: Plunkett, Ethan T <Ethan.T.Plunkett@conocophillips.com> Sent: Wednesday, January 29, 2020 1:29 PM To: Hayes, James C <James.C.Hayes @conocophi Ili ps.com>; Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com>; Aleshire, Lynn <Lynn.Aleshire@conocophillips.com> Subject: RE: 31-1-01A No problem, looks like Lynn is out of the town: 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 1/16/2020 Gas Lift Date of Test:I Hours Production for Oil -Bbl: Tested: Gas -MCF: Water- Choke Bbl: I Size: ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 3H Pad 3H -01A 50-103-20084-01 Baker Hughes INTEQ Definitive Survey Report 16 January, 2020 Baker Hughes S ConocoPhillips Sake linh.g ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 3H-01 Wellbore: 3H -01A Design: 3H -01A Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 3H-01 Local Coordinate Reference: Well 3H-01 TVD Reference: 3H-01 @ 76.00usft (31-1-01) MD Reference: 3H-01 @ 76.0Ousft (31-1-01) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Well Position -NI-S 0.00 usft Northing: MWD-INC_ONLY (INC -10') ,EI -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 31-1-01A Date From Magnetics Model Name (usft) Sample Date Survey (Wellbore) BGGM2018 7,750.00 12/30/2019 Design3H-01A 7,846.02 »..,..,..�....a.�..,,.._._,_.�,,.�.�....,...„�.,.�..w..,..�.w.....�.,,,.�,.,....�.__-�..... 7,876.27 Audit Notes: 3H -01A MWD(31-1-01A) Version: 1.0 Phase: ACTUAL Vertical Section: MWD-INC_ONLY (INC -10') Depth From (TVD) MWD OWSG OWSG MWD - Standard (usft) Survey 76.00 Survey Program End Date Date From To 12/21/2019 (usft) (usft) Survey (Wellbore) 100.00 7,750.00 3H-01 (31-1-01) 7,763.00 7,846.02 31-1-01A MVVD-INC(3H-01A) 7,876.27 11,266.05 3H -01A MWD(31-1-01A) Mean Sea Level Using Well Reference Point Using geodetic scale factor 6,000,110.73usft 498,655.44 usft usft Declination (I 16.20 Tie On Depth: 7,750.00 +W -S +FJ -W (usft) (usft) 0.00 0.00 Latitude: Longitude: Ground Level: Dip Angle 1°) 80.87 Tool Name Description BOSS -GYRO Sperry -Sun BOSS gyro multishot MWD-INC_ONLY (INC -10') MWD-INC_ONLY_FILLER ( INC>10°) MWD OWSG OWSG MWD - Standard 70° 24'41,531 N 150" 0'39.416 W 0.00 usft 1/162020 8:44; 41AM Page 2 COMPASS 5000.14 Build 85H Field Strength (nT) 57,392 Direction l°) 15.00 Survey Survey Start Date End Date 1/12/2001 12/21/2019 12/21/2019 12/21/2019 12/25/2019 1/162020 8:44; 41AM Page 2 COMPASS 5000.14 Build 85H Conocoftil lips Baker Hughes t�; ConocoPhillips Definitive Survey Report Company: Con000Phillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 31-1-01 Project: Kuparuk River Unit TVD Reference: 3H-01 @ 76.00usn (31-1-01) Site: Kuparuk 3H Pad MD Reference: 31-1-01 @ 76.00usfl (31-1-01) Well: 3H-01 North Reference: True Wellbore: 31-1-01A Survey Calculation Method: Minimum Curvature Design: 3H -01A Database: EDT 14 Alaska Production Survey ,..._,._,.. _ - .,, . .......... 1/162020 8.44: 41AM Page 3 COMPASS 5000.14 Build 85H Map Vertical Mo fusel Inc 111111(°I Axl TVD lush) TVDSS (use) +N/-S+EI-+E/-WDLS (use) (use) ortMap Nhing Eating (°noo•) Section Survey Tool Nettie Annotation (ti) (e) (n) 7,750.00 39.97 181.00 5,905.26 5,829.26 -4,428.66 -1,491.71 5,995,682.78 497,163.08 1.41 4,663.84 BOSS-GYRO(1) TIP 7,763.00 39.97 181.00 5,915.22 5,839.22 -4,437.01 -1,491.85 5,995,674.43 497,162.94 0.00 4,671.94 MWD-INC_ONLY(INC>10°)(2) KOP 7,790.51 45.67 174.00 5,935.40 5,859.40 4.455.65 -1,490.98 5,995,655.79 497,163.81 26.97 4,689.72 MWD-INC_ONLY(INC>10°)(2) Interpolated Azimuth 7,816.65 54.72 174.00 5,952.12 5,876.12 -4,475.61 -1,488.88 5,995,635.84 497,165.90 34.62 4,708.45 MWD-INC_ONLY(INC>10°)(2) Interpolated Azimuth 7,846.02 65.00 174.00 5,966.84 5,890.85 -4,500.83 -1,486.23 5,995,610.62 497,168.55 35.00 4,732.13 MWD-INC_ONLY(INC>10°)(2) Interpolated Azimuth 7,876.27 76.00 173.61 5,976.93 5,900.93 4,529.14 -1,483.15 5,995,582.31 497,171.62 36.38 4,758.68 MWD OWSG (3) 7,905.55 86.99 172.43 5,981.25 5,905.25 4,557.83 -1,479.64 5,995,553.62 497,175.13 37.74 4.785.49 MWD OWSG (3) 7,935.84 92.00 164.48 5,981.52 5,905.52 4,587.48 -1,473.58 5,995,523.98 497,181.18 31.02 -4,812.55 MWD OWSG (3) 7,966.16 93.32 152.51 5,980.11 5,904.11 4,615.60 -1,462.50 5,995,495.85 497,192.26 39.67 4,836.85 MWD OWSG (3) 7,996.13 94.52 140.89 5,978.05 5,902.05 4,640.55 -1,446.11 5,995,470.90 497,208.64 38.89 -4,856.71 MWD OWSG (3) 8,025.87 95.23 129.95 5,975.52 5,899.52 -0,661.63 -1,425.35 5,995,449.83 497,229.40 36.73 -0,871.69 MWD OWSG (3) 8,056.23 95.75 119,48 5,972.60 5,896.60 4.678.81 -1,400.54 5,995,432.64 497,254.19 34.37 4,881.87 MWD OWSG (3) 8,085.64 96.34 110.31 5,969.50 5,893.50 4,691.11 -1,374.04 5,995,420.33 497,280.69 31.07 4,886.90 MWD OWSG (3) 8,115.63 96.37 100.10 5,966.17 5,890.17 4,698.92 -1,345.32 5,995,412.52 497,30941 33.84 4,887.00 MWD OWSG (3) 8,146.31 97.30 89.41 5,962.51 5,886.51 4,701.44 -1,315.01 5,995,409.99 497,339.72 34.73 4,881.60 MWD OWSG (3) 8,175.58 96.55 78.27 5,958.97 5,882.97 4,698.33 -1,286.17 5,995,413.10 497,368.56 37.87 4,871.12 MWD OWSG (3) 8,205.69 96.95 66.68 5,955.42 5,879.42 4,689.34 -1,257.70 5,995,422.08 497,397.02 38.25 4,855.07 MWD OWSG (3) 8,236.27 98.22 55.49 5,951.37 5,875.37 4,674.71 -1,231.21 5,995,436.71 497,423.51 36.51 4,834.09 MWD OWSG (3) 8,266.28 96.89 44.34 5,947.41 5,871.41 4,655.59 -1,208.49 5,995,455.83 497,446.23 37.10 4,809.73 MWD OWSG (3) 8,296.07 95.94 34.88 5,944.08 5,868.08 4,632.80 -1,189.64 5,995,478.60 497,465.08 31.72 4,782.85 MWD OWSG (3) 8,326.58 96.04 22.50 5,940.88 5,864.88 4,606.24 -1,175.10 5,995,505.16 497,479.63 40.36 4,753.42 MWD OWSG (3) 8,357.28 95.88 17.22 5,937.69 5,861.69 4,577.53 -1,164.73 5,995,533.87 497,490.00 17.11 4,723.01 MWD OWSG (3) 8,386.85 93.87 15.55 5,935.18 5,859.18 4,549.27 -1,156.42 5,995,562.13 497,498.31 8.82 4,693.56 MWD OWSG (3) 8,417.75 90.22 12.69 5,934.07 5,858.07 4,519.33 -1,148.89 5,995,592.06 497,505.85 15.00 4,662.69 MWD OWSG (3) 8,447.52 89.05 11.43 5,934.26 5,858.26 4,490.22 -1,142.67 5,995,621.17 497,512.07 5.78 4,632.96 MWD OWSG (3) 8,477.76 88.68 9.32 5,934.86 5,858.86 4,460.48 -1,137.23 5,995,650.90 497,517.52 7.08 4,602.83 MWD OWSG (3) 8,506.55 88.74 4.60 5,935.51 5,859.51 4,431.92 -1,133.74 5,995,679.46 497,521.01 16.39 4,574.34 MWO OWSG (3) 8,536.55 90.15 247 5,935.80 5,859.80 4,401.98 -1,131.89 5,995,709.40 497,522.87 8.51 4,544.94 MWD OWSG (3) 8,567.59 91.76 0.67 5,935.28 5,859.28 4,370.96 -1,131.04 5,995,740.41 497,523.72 7.82 -4,514.75 MWD OWSG (3) 8,603.20 92.52 0.48 5,933.94 5,857.94 -4,335.37 -1,130.69 5,995,775.99 497,524.09 2.15 -4,480.29 MWD OWSG (3) 1/162020 8.44: 41AM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips s�nwgKrg ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 31-1-01 Project: Kuparuk River Unit TVD Reference: 31-1-01 @ 76.00usft (31-1-01) Site: Kuparuk 3H Pad MD Reference: 31-1-01 @ 76.00usft (31-1-01) Well: 31-1-01 North Reference: True Wellbore: 31-1-01A Survey Calculation Method: Minimum Curvature Design: 31-1-01A Database: EDT 14 Alaska Production E Survey 1/162020 8:44:41AM Page 4 COMPASS 5000. 14 Build 85H Map Map Vertical MD (usft) Inc (°) Asl (°) ND (usft) TVDSS (usft) +WS usft ( ► *E14V (usft) Northing Eating DLS (°1106') Section Survey Tool Name Annotation (ft) (ft) (ft) 8,631.93 92.27 0.79 5,932.74 5,856.74 4,306.67 -1,130.37 5,995,804.69 497,524.41 1.39 -4,45248 MWD OWSG (3) 8,661.43 91.78 1.42 5,931.70 5,855.70 4,277.19 -1,129.80 5,995,834.17 497,524.98 2.70 -4,423.87 MWD OWSG (3) 8,691.53 90.77 3.73 5,931.03 5,855.03 -0,247.13 -1,128.45 5,995,864.22 497,526.34 8.37 4,394.48 MWD OWSG (3) 8,721.46 89.85 5.55 5,930.87 5,854.87 -0,217.30 -1,126.03 5,995,894.05 497,528.77 6.81 4,365.04 MWD OWSG (3) 8,751.60 89.02 7.65 5,931.17 5,855.17 4,187.37 -1,122.56 5,995,923.98 497,532.24 7.49 4,335.23 MWD OWSG (3) 8,781.93 89.08 9.63 5,931.67 5,855.67 4,157.39 -1,118.01 5,995,953.96 497,536.80 6.53 -4,305.09 MWD OWSG (3) 8,811.47 90.06 10.13 5,931.89 5,855.89 4,128.29 -1,112.94 5,995,983.06 497,541.87 3.72 4,275.67 MWD OWSG (3) 8,841.92 90.31 13.13 5,931.79 5,855.79 4,098.47 -1,106.80 5,996,012.87 497,548.01 9.89 4,245.27 MWD OWSG (3) 8,866.43 90.00 14.44 5,931.73 5,855.73 4,074.66 -1,100.96 5,996,036.67 497,553.86 5.49 -0,220.77 MWD OWSG (3) 8,896.83 90.25 16.12 5,931.66 5,855.66 4.045.34 -1,092.95 5,996,065.99 497,561.87 5.59 -4,190.37 MWD OWSG (3) 8,931.09 92.06 15.97 5,930.97 5,854.97 -4,012.42 -1,083.48 5,996,098.91 497,571.34 5.30 4,156.13 MWD OWSG (3) 8,957.31 92.37 15.50 5,929.95 5,853.95 -3,987.20 -1,076.38 5,996,124.12 497,578.45 2.15 -4,129.93 MWD OWSG (3) 8,986.94 92.33 15.77 5,928.74 5,852.74 -3,958.69 -1,068.40 5,996,152.63 497,586.44 0.92 -4,100.32 MWD OWSG (3) 9,017.20 89.29 14.88 5,928.31 5,852.31 -3,929.51 -1,060.40 5,996,181.80 497,594.44 10.47 4,070.07 MWD OWSG (3) 9,047.60 87.85 13.91 5,929.07 5,853.07 -3,900.08 -1,052.85 5,996,211.23 497,602.00 5.71 4,039.68 MWD OWSG (3) 9,077.29 87.88 14.81 5,930.18 5,854.18 -3,871.34 -1,045.49 5,996,239.97 497,609.36 3.03 -4,010.02 MWD OWSG (3) 9,106.83 87.70 15.85 5,931.32 5,855.32 -3,842.87 -1,037.69 5,996,268.43 497,617.17 3.57 -3,960.50 MWD OWSG (3) 9,136.47 87.67 15.57 5,932.51 5,856.51 -3,814.36 -1,029.67 5,996,296.94 497,625.19 0.95 -3,950.89 MWD OWSG (3) 9,166.83 87.33 13.60 5,933.84 5,857.84 -3,785.01 -1,022.03 5,996,326.28 497,632.83 6.58 -3,920.56 MWD OWSG (3) 9,196.63 86.87 13.18 5,935.35 5,859.35 -3,756.06 -1,015.14 5,996,355.23 497,639.73 2.09 -3,890.81 MWD OWSG (3) 9,227.97 86.50 14.71 5,937.16 5,861.16 -3,725.69 -1,007.60 5,996,385.59 497,647.27 5.01 -3,859.53 MWD OWSG (3) 9,256.38 87.54 14.51 5,938.63 5,862.63 -3,698.24 -1,000.44 5,996,413.04 497,654.43 3.73 -3,831.16 MWD OWSG (3) 9,287.51 89.85 16.65 5,939.34 5,863.34 -3,668.26 -992.08 5,996,443.01 497,662.80 10.11 -3,800.04 MWD OWSG (3) 9,316.77 88.56 16.05 5,939.75 5,863.75 -3,640.19 -983.85 5,996,471.08 497,671.04 4.86 -3,770.79 MWD OWSG (3) 9,346.59 87.42 15.28 5,940.80 5,864.80 -3,611.50 -975.80 5,996,499.77 497,679.09 4.61 -3,740.99 MWD OWSG (3) 9,376.61 87.36 15.54 5,942.16 5,866.16 -3,582.58 -967.83 5,996,528.68 497,687.06 0.89 -3,711.00 MWD OWSG (3) 9,406.82 89.42 17.50 5,943.01 5,867.01 -3,553.64 -959.25 5,996,557.62 497,695.65 9.41 -3,680.82 MWD OWSG (3) 9,436.37 89.97 17.01 5,943.17 5,867.17 -3,525.42 -950.48 5,996,585.84 497,704.42 2.49 -3,651.29 MWD OWSG (3) 9,481.63 89.51 19.61 5,943.37 5,867.37 -3,482.45 -936.26 5,996,628.79 497,718.64 5.83 -3,606.11 MWD OWSG (3) 9,504.61 9080 20.48 5,943.31 5,867.31 -3,460.87 -928.39 5,996,650.38 497,726.52 6.77 -3,583.22 MWD OWSG (3) 9,535.85 9166 22.31 5,942.64 5,966.64 -3,431.79 -916.99 5,996,679.45 497,737.92 6.47 -3,552.19 MWD OWSG (3) 1/162020 8:44:41AM Page 4 COMPASS 5000. 14 Build 85H ConocoPhillips Bak- Hgh g ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kupamk Local Co-ordinate Reference: Well 3H-01 Project: Kuparuk River Unit TVD Reference: 3H-01 @ 76.00usft (31-1-01) Site: Kuparuk 3H Pad MD Reference: 31-1-01 @ 76.00usft (3H-01) Well: 31-1-01 North Reference: True Wellbore: 31-1-01A Survey Calculation Method: Minimum Curvature Design: 3H -01A Database: EDT 14 Alaska Production E Survey MD Inc AN TVD TVDSS +WS +F1 -W Map Northing Map Fasting DLS Vertical Section (usft) (`) 11 (usft) (usft) (usft) (usft) ("1100') Survey Tool Name Annotation (ft) Ift) (ft) 9,563.73 92.03 24.47 5,941.74 5,865.74 -3,406.21 -905.93 5,996,705.02 497,748.99 7.86 -3,524.62 MWD OWSG (3) 9,592.64 91.59 25.58 5,940.83 5,864.83 -3,380.03 -893.71 5,996,731.20 497,761.21 4.13 -3,496.17 MWD OWSG (3) 9,621.77 89.63 24.38 5,940.52 5,864.52 -3,353.63 -881.41 5,996,757.60 497,773.52 7.89 -3,467.48 MWD OWSG (3) 9,651.44 87.24 23.58 5,941.33 5,865.33 -3,326.53 -869.36 5,996,784.69 497,785.57 8.49 -3,438.19 MWD OWSG (3) 9,681.89 86.65 24.69 5,942.95 5,866.95 -3,298.78 -856.92 5,996,812.43 497,798.01 4.12 -3,408.17 MWD OWSG (3) 9,711.53 86.66 21.84 5,944.68 5,868.68 -3,271.60 -845.24 5,996,839.61 497,809.70 9.60 -3,378.89 MWD OWSG (3) 9,741.67 87.58 19.86 5,946.20 5,870.20 -3,243.47 -834.52 5,996,867.73 497,820.42 7.24 -3,348.95 MWD OWSG (3) 9,772.01 87.17 18.27 5,947.59 5,871.59 -3,214.83 -824.62 5,996,896.37 497,830.32 5.41 -3,318.71 MWD OWSG (3) 9,802.13 86.34 14.97 5,949.29 5,873.29 -3,186.02 -816.02 5,996,925.18 497,838.92 11.28 -3,288.66 MWD OWSG (3) 9,834.31 86.37 13.70 5,951.34 5,875.34 -3,154.90 -808.07 5,996,956.29 497,846.88 3.94 -3,256.55 MWD OWSG (3) 9,861.41 86.22 11.60 5,953.09 5,877.09 -3,128.52 -802.15 5,996,982.67 497,852.81 7.75 -3,229.53 MWD OWSG (3) 9,891.61 86.46 9.77 5,955.02 5,879.02 -3,098.90 -796.56 5,997,012.28 497,858.40 6.10 -3,199.48 MWD OWSG (3) 9,921.25 86.58 8.71 5,956.82 5,880.82 -3,069.70 -791.81 5,997,041.48 497,863.15 3.59 -3,170.04 MWD OWSG (3) 9,951.38 86.65 10.59 5,958.60 5,882.60 -3,040.05 -786.77 5,997,071.12 497,868.20 6.23 -3,140.10 MWD OWSG (3) 9,982.29 87.54 12.18 5,960.16 5,884.16 -3,009.79 -780.68 5,997,101.38 497,874.30 5.89 -3,109.29 MWD OWSG (3) 10,001.94 88.31 12.50 5,960.87 5,884.87 -2,990.61 -776.48 5,997,120.56 497,878.50 4.24 -3,089.67 MWD OWSG (3) 10,032.17 88.28 12.47 5,961.77 5,885.77 -2,961.10 -769.95 5,997,150.06 497,885.04 0.14 -3,059.48 MWD OWSG (3) 10,061.75 88.56 12.74 5,962.59 5,886.59 -2,932.25 -763.50 5,997,178.91 497,891.49 1.31 -3,029.94 MWD OWSG (3) 10,091.61 88.40 15.12 5,963.38 5,887.38 -2,903.28 -756.31 5,997,207.88 497,898.68 7.99 -3,000.10 MWD OWSG (3) 10,121.28 87.63 16.50 5,964.41 5,888.41 -2,874.75 -748.23 5,997,236.40 497,906.77 5.32 -2,970.45 MWD OWSG (3) 10,151.30 88.13 17.37 5,965.52 5,889.52 -2,846.05 -739.49 5,997,265.10 497,915.51 3.34 -2,940.47 MWD OWSG (3) 10,181.47 89.48 18.45 5,966.15 5,890.15 -2,817.35 -730.22 5,997,293.79 497,924.79 5.73 -2,910.35 MWD OWSG (3) 10,211.44 91.10 18.84 5,966.00 5,890.00 -2,788.96 -720.64 5,997,322.18 497,934.37 5.56 -2,880.44 MWD OWSG (3) 10,241.46 92.67 18.92 5,965.01 5,889.01 -2,760.57 -710.93 5,997,350.57 497,944.09 5.24 -2,850.50 MWD OWSG (3) 10,271.45 93.38 19.35 5,963.43 5,887.43 -2,732.27 -701.11 5,997,378.86 497,953.91 2.77 -2,820.63 MWD OWSG (3) 10,291.31 93.41 18.78 5,962.25 5,886.25 -2,713.54 -694.64 5,997,397.59 497,960.38 2.87 -2,800.66 MWD OWSG (3) 10,324.97 93.23 19.03 5,960.30 5,884.30 -2,681.74 -683.75 5,997,429.38 497,971.28 0.91 -2,767.33 MWD OWSG (3) 10,351.51 92.61 19.26 5,958.95 5,882.95 -2,656.71 -675.06 5,997,454.41 497,979.97 2.49 -2,740.90 MWD OWSG (3) 10,381.55 91.93 18.23 5,957.76 5,881.76 -2,628.28 -665.41 5,997,482.83 497,989.62 4.11 -2,710.95 MWD OWSG (3) 10,411.20 9169 18.33 5,956.82 5,880.82 -2,600.14 -656.11 5,997,510.97 497,998.92 0.88 -2,681.36 MWD OWSG (3) 10,441.33 9141 21.08 5,956.01 5,880.01 -2,571.79 -645.96 5,997,539.31 498,009.08 9.17 -2,651.34 MWD OWSG (3) 1/162020 8.44.41AM Page 5 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 31-1-01 Project: Kuparuk River Unit TVD Reference: 31-1-01 @ 76.00usft (31-1-01) Site: Kuparuk 3H Pad MD Reference: 31-1-01 @ 76.00usft (31-1-01) Well: 31-1-01 North Reference: True Wellbore: 31-1-01A Survey Calculation Method: Minimum Curvature Design: 31-1-01A Database: EDT 14 Alaska Production Survey Annotation 8oker Hughes Fj 1/762020 8:44 41AM Page 6 COMPASS 5000.14 Build 85H Map Map Vertical No Waft)(usft) Inc (°) Azl (°) TVD (usft TVDSS +WS (uaR) +Ef-W (usft) Northing Eastinp DLS (°1100•) Section Survey Tool Name Ift) Ift) (ft) 10,471.27 90.71 19.78 5,955.45 5,879.45 -2,543.74 -635.51 5,997,567.36 498,019.53 4.93 -2,621.54 MWD OWSG (3) 10,502.14 88.83 21.05 5,955.58 5,879.58 -2,514.81 -624.74 5,997,596.28 498,030.31 7.35 -2,590.81 MWD OWSG (3) 10,530.85 86.62 18.54 5,956.72 5,880.72 -2,487.82 -615.03 5,997,623.27 498,040.02 11.64 -2,562.23 MWD OWSG (3) 10,556.65 84.87 22.43 5,958.63 5,882.63 -2,463.72 -606.03 5,997,647.36 498,049.03 16.49 -2,536.63 MWD OWSG (3) 10,607.65 84.03 24.81 5,963.57 5,687.57 -2,417.22 -585.69 5,997,693.86 498,069.37 4.93 -2,486.44 MWD OWSG (3) 10,633.61 83.73 25.80 5,966.33 5,890.33 -2,393.88 -574.66 5,997,717.19 498,080.41 3.96 -2,461.05 MWD OWSG (3) 10,671.17 85.18 26.83 5,969.96 5,893.96 -2,360.38 -558.09 5,997,750.69 498,096.98 4.73 -2,424.39 MWD OWSG (3) 10,701.35 85.05 25.57 5,972.53 5,896.53 -2,333.40 -544.81 5,997,777.67 498,110.26 4.18 -2,394.89 MWD OWSG (3) 10,731.44 85.73 23.61 5,974.95 5,898.95 -2,306.12 -532.33 5,997,804.93 498,122.75 6.87 -2,365.32 MWD OWSG (3) 10,761.23 86.68 21.14 5,976.92 5,900.92 -2,278.64 -521.02 5,997,832.41 498,134.06 8.87 -2,335.85 MWD OWSG (3) 10,791.20 88.37 22.17 5,978.22 5,902.22 -2,250.81 -509.97 5,997,860.23 498,145.12 6.60 -2,306.11 MWD OWSG (3) 10,821.35 88.62 23.37 5,979.01 5,903.01 -2,223.02 A98.30 5,997,888.02 498,156.78 4.06 -2,276.25 MWD OWSG (3) 10,851.24 87.29 21.93 5,980.08 5,904.08 -2,195.46 A86.80 5,997,915.58 498,168.29 6.56 -2,246.64 MWD OWSG (3) 10,884.64 86.78 19.00 5,981.80 5,905.80 -2,164.21 A75.14 5,997,946.82 498,179.96 8.89 -2,213.44 MWD OWSG (3) 10,911.22 88.03 17.18 5,983.01 5,907.01 -2,138.97 -466.90 5,997,972.06 498,188.21 8.30 -2,186.93 MWD OWSG (3) 10,934.39 87.88 15.49 5,983.84 5,907.84 -2,116.75 -460.38 5,997,994.27 498,194.72 7.32 -2,163.78 MWD OWSG (3) 10,977.09 88.47 13.43 5,985.20 5,909.20 -2,075.43 -449.73 5,998,035.59 498,205.38 5.02 -2,121.11 MWD OWSG (3) 11,005.55 88.28 11.04 5,986.00 5,910.00 -2,047.63 -443.70 5,998,063.39 498,211.42 8.42 -2,092.69 MWD OWSG (3) 11,041.40 89.60 9.61 5,986.67 5,910.67 -2,012.37 A37.28 5,998,098.64 498,217.85 5.43 -2,056.97 MWD OWSG (3) 11,078.53 90.18 6.35 5,986.74 5,910.74 -1,975.60 A32.12 5,998,135.40 498,223.01 8.92 -2,020.12 MWD OWSG (3) 11,111.20 88.83 5.65 5,987.02 5,911.02 -1,943.11 A28.71 5,998,167.89 498,226.43 4.65 -1,987.86 MWD OWSG (3) 11,141.65 89.29 6.32 5,987.52 5,911.52 -1,912.83 425.53 5,998,198.17 498,229.61 2.67 -1,957.79 MWD OWSG (3) 11,172.09 90.49 7.03 5,987.58 5,911.58 -1,882.60 -421.99 5,998,228.39 498,233.15 4.58 -1,927.67 MWD OWSG (3) 11,201.25 91.32 7.67 5,987.12 5,911.12 -1,853.68 -418.26 5,998,257.31 498,236.88 3.59 -1,898.77 MWD OWSG (3) 11,232.81 90.43 7.86 5,986.63 5,910.63 -1,822.42 414.00 5,998,288.57 498,241.15 2.88 -1,867.47 MWD OWSG (3) 11,266.05 89.51 9.07 5,986.65 5,910.65 -1,789.54 -409.11 5,998,321.44 498,246.05 4.57 -1,834.45 MWD OWSG (3) 11,303.00 89.51 9.07 5,986.97 5,910.97 -1,753.05 -403.28 5,998,357.93 498,251.88 0.00 -1,79770 PROJECTED to TD Annotation 8oker Hughes Fj 1/762020 8:44 41AM Page 6 COMPASS 5000.14 Build 85H Baker Hughes 219158 PRINT DISTRIBUTION LIST 3 195 0 COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3H -01A FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(a)bakerhughes.com 2 STATUS Final COMPANY Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE December 26, 2019 TODAYS DATE January 21, 2020 Revision Replacement: No Details: Rev. Requested by: --- FIELD / FINAL CD/DVD FINAL BP North Slope. PRELIM (las, dlis, PDFMETA, , SURVEY REPORT CGM, Final Surveys ) (Compass) # OF PRINTS 900 E. Benson Blvd. # OF COPIES # OF COPIES # OF COPIES ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION LOGS LOGS BP North Slope. FOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 O G C 700 G Street V C Anchorage, AK 99510 3 F,xxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC 1 1 i Attn: Natural Resources Technician III 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 51 DNR - Division of Oil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, L1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 219158 WELL LOG TRANSMITTAL #906147953 To: Alaska Oil and Gas Conservation Comm. January 16, 2020 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper: 3H -01A Run Date: 12/01/2019, 12/10/2019, 12/16/2019, and 12/20/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3H -01A Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20084-01C C� r VE D JAN 2 2 2020 AOCCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: �� '? Signed: THE STATE °'ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger CTD Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 31-1-01A ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-158 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Surface Location: 1546' FNL, 281' FWL, SEC. 12, T12N, R8E, UM Bottomhole Location: 3002' FNL, 5242' FEL, SEC. 12, TI 2N, R8E, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to redrill the above referenced development well. 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, J Price Chair DATED this 064 day of November, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED NOV 12 2019 1 a. Type of Work: b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑1c.ecjfy if well is peed for: 'til( Drill Latera Stratigraphic Test ❑ Development - Oil ❑✓ ' Service - Winj ❑ Single Zone Q • Co s drates ❑ Redrill V Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Oper�Qr Name: y h't` `fir 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: " ConocoPhillips Alaska Inc Bond No. W! ' (4a"_21827"--'rV4 3H -01A 3. Address: 6. Proposed Depth: 5 ty 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11,600' TVA 5,872' uparuk River Field/ Kuparuk Oil Pool 4a. Location of Well (Governmental Section : 7. Property Designation: /,,'>1 ,;, Surface: 1,546' FNL, 281' SEC 12, T 12N, R 8E, UM 1hW f}L'�25547, 025531 Top of Productive Horizon: �►1�L S�(i./I,�y 8. DNR Approval Number: 13. Approximate Spud Date: 728' FNL, 1214' FEL, SEC 14, T 12N, R 8E, UM 931886000, 931882000 11/23/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 3,002' FNL, 5,242' FEL, SEC 12, T 12N, R 8E, UM 2560 4,075' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 76' 115. Distance to Nearest Well Open Surface: x- 4GO041-4 y- Zone- 4 GL / BF Elevation above MSL (ft): 39' Ito Same Pool: 40' (3H -26L1) 16. Deviated wells: Kickoff depth: 7,785' feet - 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) .t'` 3 Aimum Hole Angle: •Ay" degrees Downhole: 3,526 • Surface: 2,947 ' 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) 3" 2-3/8" 4.7# L-80 ST -L 3,200' 8,400' 5,852' 11,600' 5,872' Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): ITotal `ib 7 5 `, � /(IA 7,785' NA Casing t i3 z `7 Length Size Cement Volume c �_,.� : MD TVD Conductor/Structural 80' 16 245 sx ASI 121 121 Surface 3,601' 9.625 1300 sx AS III Lead, 400 sx Class G 3,636' 2,951' Intermediate Tail Production 8,143' 7 300 sx Class G 8,177' 6,168' Liner Perforation Depth MD (ft): 7,684'-7,752'- 7,822'-7,843' Perforation Depth TVD (ft): 5,855'-5,907' - 5,960'-5,974' Hydraulic Fracture planned? Yes ❑ No ❑✓ ' 20. Attachments: Property Plat❑ BOP Sketch Drilling Program B Time v. Depth Plot a Shallow Hazard Analysis e Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirementsB 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. Contacte: James Hayes Authorized Name: James Ohlinger Contact Email: 'ames.c.ha eS co .Com Authorized Title: CTD Team Lead Contact Phone: 907-265-6972 Authorized Signature: Date: Commission Use Only Permit to Drill �! API Number:Permit 150- "�� Approval See See cover letter for other Number: / fl�� C,1- 2�j lo Date: I 2 lot requirements. Conditions of approval : If box is checked, well may not used to explore for, test, or produce coalbed methane as hydrates, or gas contained in shales: Other© oF lCeO J not Samples req'd: Yes 0[ Mud log req'd: Yes❑AO1Z �H2S R/N measures: YesNo❑ Directional svy req'd: Yes [0 No Spacing exception req'd: Yes ❑ NoInclination-only svy req'd: Yes ❑ NoR Post initial injection MIT req'd: Yes❑ No[] f ,` APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-4o`I4Be/se/2o This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) r<(�1��(�� ORGJA/",����.yt L Submit t'orm andr Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 8, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the KRU 3H-01 (PTD# 187-110) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin the middle of November 2019. The objective will be to drill Wo laterals KRU 3H -01A and 3H-01AL1 targeting the Kuparuk A -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 3H -01A and 3H-01 AL1 — Detailed Summary of Operations — Directional Plans for 1 F-071_1 and 1 F-071_1-01 — Current wellbore schematic — Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6927. Sincerely, James Hayes Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 31-1-01A & 3 H -01 A L 1 NABORS ALASKA Application for Permit to Drill Document C1rj)q,,, 1. Well Name and Classification...........................................................................................................2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))......................................................................................................................2 2. Location Summary .............................................................................................................................2 (Requirements of 20 AAC 25.005(c)(2))......................................................................................................................................................2 3. Blowout Prevention Equipment Information...................................................................................2 (Requirements of 20 AAC 25.005(c)(3)).....................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure....................................................................2 (Requirements of 20 AAC 25.005(c)(4))..................................................................................................................................................... 2 5. Procedure for Conducting Formation Integrity tests.....................................................................2 (Requirements of 20 AAC 25.005(c)(5))...................................................................................................................................................... 2 6. Casing and Cementing Program......................................................................................................3 (Requirements of 20 AAC 25.005(c)(6))......................................................................................................................................................3 7. Diverter System Information.............................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))......................................................................................................................................................3 8. Drilling Fluids Program.....................................................................................................................3 (Requirements of 20 AAC 25.005(c)(8))......................................................................................................................................................3 9. Abnormally Pressured Formation Information...............................................................................4 (Requirements of 20 AAC 25.005(c)(9))...................................................................................................................................................... 4 10. Seismic Analysis................................................................................................................................4 (Requirements of 20 AAC 25.005(c)(10))..........................................................................................................-........................................4 11. Seabed Condition Analysis...............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11))....................................................................................................................................................4 12. Evidence of Bonding.........................................................................................................................4 (Requirements of 20 AAC 25.005(c)(12))....................................................................................................................................................4 13. Proposed Drilling Program...............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13)). . ....................................................................................................................... .......................... 4 Summaryof Operations.................................................................................................................................................. 4 LinerRunning.................................................................................................................................................................. 6 14. Disposal of Drilling Mud and Cuttings.............................................................................................6 (Requirements of 20 AAC 25.005(c)(14)).................................................................................................................................................... 6 15. Directional Plans for Intentionally Deviated Wells..........................................................................6 (Requirements of 20 AAC 25.050(b)).......................................................................................................................................................... 6 16. Attachments.......................................................................................................................................6 Attachment 1: Directional Plans for 31-1-01A & 31-1-01AL1 laterals.................................................................................. 6 Attachment 2: Current Well Schematic for 31-1-01........................................................................................................... 6 Attachment 3: Proposed Well Schematic for 3H -01A & 31-1-01 AL1 laterals.................................................................... 6 Page 1 of 6 August 1, 2017 PTD Application: 3H -01A & 31-1-01AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3H -01A & 3H-01AL1. All laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3H -01A & 3H-01AL1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the maximum formation pressure in the area of 3,526 psi in 3H-26 (i.e. 11.72 ppg EMW). The maximum potential surface pressure in 3H-26, assuming a gas gradient of 0.1 psi/ft, would be 2,955 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3H-01 was measured to be 2,671 psi (8.77 ppg EMW) on 08/7/2019. The v maximum downhole pressure in the 3H-01 vicinity is to the northwest in the 3H-26 producer at 3,526 psi (11.72 ppg EMW) from 08/2017. - Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injectors we last on MI injection five years ago so there is a low risk of drilling into high pressure injected gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 3H -01A laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3H -01A laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 August 3, 2017 PTD Application: 31-1-01A & 31-1-01AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details MD MD TVDSS TVDSS 31-11-01A 8,400' 11,600' 5,862' 5,872' 2-3/8", 4.7#, L-80, ST -L slotted liner; aluminum billet on to 3H-01AL1 7,556' 11,600' 5,682' 5,890' 2-3/8", 4.7#, L-80, ST -L slotted liner; LTP 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) • Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based FloVis mud (8.6 ppg) — Drilling operations: Chloride -based FloVis mud (8.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". s In the 3H -01A laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 August 3, 2017 PTD Application: 31-1-01A & 31-1-01AL1 Pressure at the 31-1-01A Window (7,785' MD and 5,932' TVD) Using MPD MPD Pressure Table Pumps On Pumps Off A Formation Pressure 2,671 psi 8.77 B Target BHP at Window 3,640 psi 11.80 C Mud Hydrostatic 2,653 psi 8.60 D Annular Friction (ECD) 607 psi 0 psi 0.078psi/ft C+D Mud + ECD Combined (no choke pressure) 3,260 psi 2,653 psi A-(C+D) Overbalanced / Underbalanced 589 psi -18 psi B-(C+D) Choke Pressure Required to Maintain 380 psi 987 psi Target BHP at window and deeper 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3H-01 is a Kuparuk A and C sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A sand to the northeast of 3H-01. The laterals will increase resource recovery and add new resources. Prior to CTD operations, E -line will punch 2' of holes in the 3-1/2" tubing tail below the packer at 7,566' MD and the D nipple at 7,485' MD will be milled out to a 2.80" ID. The existing A and C sand perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze, Nabors CDR3 will drill a cement pilot hole to 7,815' MD and set a mechanical whipstock in the 2.80" pilot hole at the planned kick off point of 7,785" MD. - Page 4 of 6 August 3, 2017 PTD Application: 3H -01A & 3H-01AL1 The 31H-0IA layml will exit through the 7" at 7,785' MD and TD at 11,600' MD, targeting the A sand to the northeast. It will be completed with 2-3/8" slotted liner from TD up to 8,400' MD with an aluminum billet for kicking off the 3H-01 AL I lateral. The 3H-0IAL I lateral will drill to a TD of 11,600' MD targeting the A sand. It will be completed with 2- 3/8" slotted liner from TD up inside 3-1/2" tubing tail to 7,756' MD with a deployment sleeve. Pre -CTD Work Slickline (Fullbore assist): a. SBHP b. Injectivity Test Coil: a. Perf tubing tail b. Lay in Cement Plug (7" casing up to tubing tail) c. Tag TOC d. Pressure Test Cement Squeeze and Negative Test e. Mill D nipple and tag TD for depth control Rig Work 2. MIRU NaborsNaborsCDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 3. 3 H-0 I A Lateral (A sand) a. Drill 2.80" pilot hole through cement to 7,815' MD b. Caliper pilot hole c. Set top of whipstock at 7,785' MD and mill 2.80" window d. Drill 3" bi-center lateral to TD of 11,600' MD. e. Run 2%" slotted liner with an aluminum billet from TD up to 8,400' MD. 4. 3H-01 AL 1 Lateral (A sand) a. Kick off the aluminum billet at 8,400' MD. b. Drill 3" bi-center lateral to TD of 11,400' MD. c. Run 2%" slotted liner with deployment sleeve from TD up into 3-1/2" production tubing to 7,556' MD. 5. Freeze protect, ND BOPS, and RDMO Nabors CDR3- AC rig. Post -Rig Work 1. Obtain SBHP. 2. Install gas lift design. 3. Return to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. Page 5 of 6 August 3, 2017 PTD Application: 31-1-01A & 3H-01AL1 — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 3H -01A laterals will be displaced to an overbalancing fluid (11.8 ppg NaBr) prior to running liner. See "Drilling Fluids" section for more details. — While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. ' • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 3H -01A 4,075' 3H-01AL1 4,355' — Distance to Nearest Well within Pool Lateral Name Distance Well 3H -01A 40' 3H-261_1 3H-01AL1 75' 3H-261_1 16. Attachments Attachment 1: Directional Plans for 3H -01A & 3H-01AL1 laterals Attachment 2: Current Well Schematic for 3H-01 Attachment 3: Proposed Well Schematic for 3H -01A & 3H-01AL1 laterals Page 6 of 6 August 3, 2017 ConocoPs philli ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 3H Pad 3H-01 31-1-01A Plan: 3H-01A_wp02 Standard Planning Report 17 October, 2019 ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc—Kuparuk Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 31-1-01 Wellbore: 31-1-01A Design: 3H-01 A_wp02 ConocoPhillips Planning Report Local Co-ordinate Reference: Well 31-1-01 TVD Reference: Mean Sea Level MD Reference: 31-1-01 @ 76.00usft (31-1-01) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3H Pad Site Position: Northing: 6,000,110.73 usft Latitude: 70° 24'41.531 N From: Map Easting: 498,655.44 usft Longitude: 1500 0' 39.416 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ° Well3H-01 Well Position +N/ -S 0.00 usft Northing: 6,000,110.73 usft Latitude: 70° 24'41.531 N +E/ -W 0.00 usft Easting: 498,655.44 usft • Longitude: 1500 0' 39.416 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 31-1-01A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I V) (nT) BG G M2018 12/1/2019 16.24 80.87 57,395 Design 3H-01A_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,700.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 0.00 0.00 0.00 20.00 10/17/2019 8:58.22AM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 31-1-01 Wellbore: 31-1-01A Design: 3H-01 A_wp02 ConocoPhillips Planning Report Local Co-ordinate Reference: Well 31-1-01 TVD Reference: Mean Sea Level MD Reference: 31-1-01 @ 76.00usft (3H-01) North Reference: True Survey Calculation Method: Minimum Curvature Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°1100usft) (°/1oousft) (°) 7,700.00 40.67 180.89 5,791.13 -4,396.31 -1,491.17 0.00 0.00 0.00 0.00 7,785.00 39.97 181.00 5,855.94 -4,451.30 -1,492.08 0.83 -0.82 0.13 174.24 7,806.00 44.17 181.00 5,871.53 -4,465.37 -1,492.33 20.00 20.00 0.00 0.00 7,907.84 90.00 181.00 5,910.13 -4,556.68 -1,493.92 45.00 45.00 0.00 0.00 8,250.00 93.94 26.75 5,872.32 -4,616.71 -1,256.17 45.00 1.15 -45.08 -81.00 8,425.00 93.85 14.47 5,860.40 -4,453.60 -1,194.83 7.00 -0.05 -7.02 -90.00 8,625.00 90.62 28.11 5,852.57 -4,267.87 -1,122.43 7.00 -1.61 6.82 103.00 8,825.00 90.60 14.11 5,850.43 -4,081.76 -1,050.60 7.00 -0.01 -7.00 -90.00 8,975.00 88.78 24.45 5,851.25 -3,940.37 -1,001.15 7.00 -1.22 6.89 100.00 9,275.00 88.86 3.44 5,857.51 -3,650.90 -929.28 7.00 0.03 -7.00 -90.00 9,450.00 85.53 15.25 5,866.11 -3,478.75 -900.98 7.00 -1.90 6.75 106.00 9,625.00 89.78 3.75 5,873.29 -3,306.62 -872.21 7.00 2.43 -6.57 -70.00 10,025.00 91.21 31.71 5,869.75 -2,929.41 -751.63 7.00 0.36 6.99 87.00 10,175.00 89.92 21.29 5,868.26 -2,795.36 -684.80 7.00 -0.86 -6.95 -97.00 10,325.00 86.35 11.41 5,873.15 -2,651.71 -642.64 7.00 -2.38 -6.59 -110.00 10,425.00 89.86 5.35 5,876.46 -2,552.89 -628.09 7.00 3.51 -6.06 -60.00 10,775.00 89.46 29.85 5,878.55 -2,221.82 -523.07 7.00 -0.11 7.00 91.00 11,125.00 90.34 5.36 5,879.17 -1,890.75 -418.01 7.00 0.25 -7.00 -88.00 11,600.00 91.38 38.60 5,871.84 -1,456.49 -242.72 7.00 0.22 7.00 88.00 Target 1011712019 8:58:22AM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 31-1-01 Company: ConocoPhillips Alaska Inc Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 31-1-01 @ 76.00usft (31-1-01) Site: Kuparuk 3H Pad North Reference: True Well: 3H-01 Survey Calculation Method: Minimum Curvature Wellbore: 31-1-01A Design: 3H-01 A_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +El -W Section Rate Azimuth Northing Easting (usft) (o) (o) (usft) (usft) (usft) (usft) (°/100usft) V) (usft) (usft) 7,700.00 40.67 180.89 5,791.13 -4,396.31 -1,491.17 -4,641.19 0.00 0.00 5,995,715.13 497,163.62 TIP 7,785.00 39.97 181.00 5,855.94 -4,451.30 -1,492.08 -4,693.18 0.83 174.24 5,995,660.14 497,162.71 KOP 7,800.00 42.97 181.00 5,867.18 -4,461.23 -1,492.25 -4,702.57 20.00 0.00 5,995,650.21 497,162.53 7,806.00 44.17 181.00 5,871.53 -4,465.37 -1,492.33 -4,706.48 20.00 0.00 5,995,646.08 497,162.46 Start DLS 46.00 TFO 0.00 7,900.00 86.47 181.00 5,909.89 -4,548.84 -1,493.78 -4,785.42 45.00 0.00 5,995,562.61 497,160.99 7,907.84 90.00 181.00 5,910.13 -4,556.68 -1,493.92 -4,792.83 45.00 0.00 5,995,554.77 497,160.85 Start DLS 46.00 TFO -81.00 8,000.00 95.95 139.88 5,905.14 -4,641.53 -1,463.87 -4,862.29 45.00 -81.00 5,995,469.92 497,190.88 8,100.00 98.98 94.57 5,891.44 -4,685.80 -1,378.14 -4,874.57 45.00 -83.23 5,995,425.64 497,276.59 8,200.00 96.73 49.18 5,877.03 -4,655.72 -1,286.58 -4,814.98 45.00 -89.44 5,995,455.71 497,368.15 8,250.00 93.94 26.75 5,872.32 -4,616.71 -1,256.17 -4,767.92 45.00 -95.99 5,995,494.71 497,398.56 Start DLS 7.00 TFO -90.00 8,300.00 93.93 23.24 5,868.89 -4,571.51 -1,235.10 -4,718.24 7.00 -90.00 5,995,539.90 497,419.64 8,400.00 93.87 16.23 5,862.08 -4,477.66 -1,201.44 -4,618.54 7.00 -90.24 5,995,633.73 497,453.32 8,425.00 93.85 14.47 5,860.40 -4,453.60 -1,194.83 -4,593.67 7.00 -90.72 5,995,657.79 497,459.92 Start DLS 7.00 TFO 103.00 8,500.00 92.65 19.59 5,856.14 -4,382.04 -1,172.91 -4,518.93 7.00 103.00 5,995,729.34 497,481.86 8,600.00 91.03 26.40 5,852.93 -4,290.09 -1,133.88 -4,419.18 7.00 103.29 5,995,821.27 497,520.90 8,625.00 90.62 28.11 5,852.57 -4,267.87 -1,122.43 -4,394.38 7.00 103.51 5,995,843.49 497,532.35 Start DLS 7.00 TFO -90.00 8,700.00 90.62 22.86 5,851.76 -4,200.19 -1,090.18 -4,319.75 7.00 -90.00 5,995,911.15 497,564.61 8,800.00 90.60 15.86 5,850.70 -4,105.91 -1,057.06 -4,219.83 7.00 -90.06 5,996,005.42 497,597.75 8,825.00 90.60 14.11 5,850.43 -4,081.76 -1,050.60 -4,194.92 7.00 -90.13 5,996,029.57 497,604.21 Start DLS 7.00 TFO 100.00 8,900.00 89.69 19.28 5,850.24 -4,009.95 -1,029.07 -4,120.08 7.00 100.00 5,996,101.37 497,625.75 8,975.00 88.78 24.45 5,851.25 -3,940.37 -1,001.15 -4,045.15 7.00 100.01 5,996,170.94 497,653.68 Start DLS 7.00 TFO -90.00 9,000.00 88.78 22.70 5,851.78 -3,917.46 -991.16 -4,020.21 7.00 -90.00 5,996,193.84 497,663.68 9,100.00 88.79 15.69 5,853.91 -3,823.10 -958.31 -3,920.30 7.00 -89.96 5,996,288.18 497,696.54 9,200.00 88.82 8.69 5,855.99 -3,725.44 -937.20 -3,821.31 7.00 -89.81 5,996,385.83 497,717.66 9,275.00 88.86 3.44 5,857.51 -3,650.90 -929.28 -3,748.55 7.00 -89.67 5,996,460.37 497,725.60 Start DLS 7.00 TFO 106.00 9,300.00 88.38 5.12 5,858.12 -3,625.98 -927.41 -3,724.50 7.00 106.00 5,996,485.28 497,727.47 9,400.00 86.47 11.87 5,862.62 -3,527.24 -912.67 -3,626.67 7.00 105.96 5,996,584.01 497,742.23 9,450.00 85.53 15.25 5,866.11 -3,478.75 -900.98 -3,577.11 7.00 105.66 5,996,632.49 497,753.93 Start DLS 7.00 TFO -70:00 9,500.00 86.73 11.95 5,869.48 -3,430.28 -889.25 -3,527.55 7.00 -70.00 5,996,680.96 497,765.66 9,600.00 89.17 5.39 5,873.06 -3,331.54 -874.20 -3,429.62 7.00 -69.78 5,996,779.68 497,780.73 9,625.00 89.78 3.75 5,873.29 -3,306.62 -872.21 -3,405.52 7.00 -69.54 5,996,804.60 497,782.72 Start DLS 7.00 TFO 87.00 9,700.00 90.06 8.99 5,873.40 -3,232.11 -863.90 -3,332.66 7.00 87.00 5,996,879.09 497,791.05 9,800.00 90.42 15.98 5,872.98 -3,134.54 -842.29 -3,233.59 7.00 86.99 5,996,976.66 497,812.67 9,900.00 90.78 22.97 5,871.93 -3,040.32 -808.98 -3,133.66 7.00 87.02 5,997,070.85 497,846.00 10,000.00 91.13 29.96 5,870.26 -2,950.87 -764.44 -3,034.37 7.00 87.10 5,997,160.29 497,890.54 10,025.00 91.21 31.71 5,869.75 -2,929.41 -751.63 -3,009.82 7.00 87.21 5,997,181.75 497,903.36 Start DLS 7.00 TFO -97.00 10,100.00 90.57 26.50 5,868.58 -2,863.91 -715.17 -2,935.80 7.00 -97.00 5,997,247.23 497,939.83 10,175.00 89.92 21.29 5,868.26 -2,795.36 -684.80 -2,861.00 7.00 -97.08 5,997,315.77 497,970.21 Start DLS 7.00 TFO -110.00 10/17/2019 8:58.22AM Page 4 COMPASS 5000 14 Build 85H 1W I ConocoPhillips ConocoPhillips Planning Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 3H-01 Company: ConocoPhillips Alaska Inc-Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-01 @ 76.00usft (3H-01) Site: Kuparuk 3H Pad North Reference: True Well: 31-1-01 Survey Calculation Method: Minimum Curvature Wellbore: 31-1-01A Design: 3H-01 A_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map I Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (a) (o) (usft) (usft) (usft) (usft) (°/100usft) V) (usft) (usft) 10,200.00 89.32 19.65 5,868.42 -2,771.95 -676.06 -2,836.00 7.00 -110.00 5,997,339.18 497,978.95 10,300.00 86.94 13.06 5,871.68 -2,676.10 -647.93 -2,736.32 7.00 -109.99 5,997,435.01 498,007.09 10,325.00 86.35 11.41 5,873.15 -2,651.71 -642.64 -2,711.59 7.00 -109.77 5,997,459.40 498,012.39 Start DLS 7.00 TFO -60.00 10,400.00 88.98 6.86 5,876.20 -2,577.75 -630.75 -2,638.02 7.00 -60.00 5,997,533.35 498,024.29 10,425.00 89.86 5.35 5,876.46 -2,552.89 -628.09 -2,613.75 7.00 -59.81 5,997,558.20 498,026.96 Start DLS 7.00 TFO 91.00 10,500.00 89.77 10.60 5,876.69 -2,478.65 -617.69 -2,540.43 7.00 91.00 5,997,632.44 498,037.37 10,600.00 89.65 17.60 5,877.19 -2,381.72 -593.34 -2,441.02 7.00 90.98 5,997,729.35 498,061.73 10,700.00 89.54 24.60 5,877.90 -2,288.49 -557.36 -2,341.11 7.00 90.95 5,997,822.57 498,097.72 10,775.00 89.46 29.85 5,878.55 -2,221.82 -523.07 -2,266.73 7.00 90.90 5,997,889.23 498,132.03 Start DLS 7.00 TFO -88.00 10,800.00 89.52 28.10 5,878.77 -2,199.95 -510.96 -2,242.04 7.00 -88.00 5,997,911.09 498,144.14 10,900.00 89.77 21.10 5,879.39 -2,109.09 -469.35 -2,142.42 7.00 -87.98 5,998,001.94 498,185.75 11,000.00 90.02 14.11 5,879.57 -2,013.83 -439.13 -2,042.57 7.00 -87.94 5,998,097.18 498,216.00 11,100.00 90.28 7.11 5,879.31 -1,915.60 -420.72 -1,943.97 7.00 -87.93 5,998,195.39 498,234.41 11,125.00 90.34 5.36 5,879.17 -1,890.75 -418.01 -1,919.69 7.00 -87.95 5,998,220.24 498,237.14 Start DLS 7.00 TFO 88.00 11,200.00 90.52 10.61 5,878.61 -1,816.51 -407.59 -1,846.36 7.00 88.00 5,998,294.48 498,247.56 11,300.00 90.76 17.61 5,877.50 -1,719.59 -383.23 -1,746.96 7.00 88.04 5,998,391.38 498,271.94 11,400.00 90.98 24.60 5,875.98 -1,626.37 -347.25 -1,647.05 7.00 88.12 5,998,484.59 498,307.94 11,500.00 91.19 31.60 5,874.09 -1,538.23 -300.18 -1,548.13 7.00 88.22 5,998,572.71 498,355.02 11,600.00 91.38 38.60 5,871.84 -1,456.49 -242.72 -1,451.66 7.00 88.36 5,998,654.43 498,412.48 Planned TD at 11600.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,600.00 5,871.84 2-3/8" 2.375 3.000 10/17/2019 8.58.22AM Page 5 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 31-1-01 Company: ConocoPhillips Alaska Inc-Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 31-1-01 @ 76.00usft (31-1-01) Site: Kuparuk 3H Pad North Reference: True Well: 31-1-01 Survey Calculation Method: Minimum Curvature Wellbore: 31-1-01A -1,492.08 KOP Design: 3H-01 A_wpo2 -4,465.37 -1,492.33 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 7,700.00 5,791.13 -4,396.31 -1,491.17 TIP 7,785.00 5,855.94 -4,451.30 -1,492.08 KOP 7,806.00 5,871.53 -4,465.37 -1,492.33 Start DLS 45.00 TFO 0.00 7,907.84 5,910.13 -4,556.68 -1,493.92 Start DLS 45.00 TFO -81.00 8,250.00 5,872.32 -4,616.71 -1,256.17 Start DLS 7.00 TFO -90.00 8,425.00 5,860.40 -4,453.60 -1,194.83 Start DLS 7.00 TFO 103.00 8,625.00 5,852.57 -4,267.87 -1,122.43 Start DLS 7.00 TFO -90.00 8,825.00 5,850.43 -4,081.76 -1,050.60 Start DLS 7.00 TFO 100.00 8,975.00 5,851.25 -3,940.37 -1,001.15 Start DLS 7.00 TFO -90.00 9,275.00 5,857.51 -3,650.90 -929.28 Start DLS 7.00 TFO 106.00 9,450.00 5,866.11 -3,478.75 -900.98 Start DLS 7.00 TFO -70.00 9,625.00 5,873.29 -3,306.62 -872.21 Start DLS 7.00 TFO 87.00 10,025.00 5,869.75 -2,929.41 -751.63 Start DLS 7.00 TFO -97.00 10,175.00 5,868.26 -2,795.36 -684.80 Start DLS 7.00 TFO -110.00 10,325.00 5,873.15 -2,651.71 -642.64 Start DLS 7.00 TFO -60.00 10,425.00 5,876.46 -2,552.89 -628.09 Start DLS 7.00 TFO 91.00 10,775.00 5,878.55 -2,221.82 -523.07 Start DLS 7.00 TFO -88.00 11,125.00 5,879.17 -1,890.75 -418.01 Start DLS 7.00 TFO 88.00 11,600.00 5,871.84 -1,456.49 -242.72 Planned TD at 11600.00 10/17/2019 8:58:22AM Page 6 COMPASS 5000 14 Build 85H 6,-: O o 0 0 0 0 0 0 0 6 0 0 0 0 .0 00 0 000 o rnorn�0 eo a ®� 0 te0®e a c? o �rnrSao ; �rnrcfl 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 H H LL LL LL li LL LL LL LL LL LL LL LL LL 0 0 F- H H H 0 0 0 0 0 0 0 Cl Cl Cl 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 V V r• t� r` t� r` t� r` t� t� t� � t� t� t� � a-crcc crrr��r�crrr H Y(n Cn UJ UJ Gn Cn Cn UI Cn Cn UJ Cn UJ (n Ul Ul d •-M G6 CV t_MR V LOo* ,O� r c7cD0ic- V'000cf]OOOct Vrh. O C) <o t0 to to t, r, ti �M rO t t(7C Oa0 t�cONO V' McnjMMNNN N� 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O V OOrOM OOOcpO r• t�00raD a0 O M O O O O O O Cl O O O O 0 0 0 0 0 0 O cC O O O O O O O O O O O O O O O O O O O O 4') � t� � t� r• t� t� f� r` ti r t- t� ti t� a O M N 1 M M O a O CO M O -,:I- O f f N r O M O r a 0 c Y C O Cl! O N CR N c D O O O t r N N 00]0MSOV'O � e0 N d - V V cY ct N r r 0 0 0) 6) ap r; c0 cO cD to � N r 0 t` N r 0 t� t 0 t• O� N (0 O N t n O M M M�D r✓ (R cc! 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WtlLen (I... Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD (in) ID (in) Top (ftKB) Sat Depth (ftKB) Set Depth (TVD)... Wt/Len (I Grade Top Thread SURFACE 9 5/8 8.921 35.0 3,576.7 2,942.4 36.00 J-55 BTC Casing Descdptlon OD (in) ID (in) Top '111K.,Sef Depth (kKB) Sel Depth (TVD)... WV' (I... Grade Top Thmed PRODUCTION 7 6.276 33.0 8,076.4 6,155.4 26.00 J-55 BTC Tubing Strings Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (Ibkt) Grade Top Connection TUBING -2015 WO 3112 2.992 31.0 7,509.7 5,723.3 9.30 L-80 EUE8rdABMOD Completion Details Nominal to Top(ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com (in) 31.0 31.0 0.67 HANGER FMC TUBING HANGER 2.992 7,065.0 5,392.6 42.61 LOCATOR LOCATOR 2.990 7,066.0 5,393.3 42.60 SEAL ASSY BAKER 8040 SEAL ASSEMBLY 3.000 7,072.2 5,397.9 42.56 PSR BAKER 8040 PER 4.000 7,095.2 5,414.8 1 42.40 1 PACKER BAKER FHL RETRIEVABLE PACKER 4782 2.930 7,485.4 5,705.0 41.40 NIPPLE DS NIPPLE 2.813 7,503.1 5,718.3 41.30 1 OVERSHOT I BAKER POOR BOY OVERSHOT 3,750 Tubing Dasedpdon String Ma... ID (in) Tap (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (Ibt t) Grade Top Connection TUBING - ORIGINAL 31/2 2.992 7,504.7 7,614.6 5,802.4 9.30 J-55 -P on Completion Details Nominal ID Top IRKS) Top (TVD) (ftK8) Top Incl (c) Item Des Co. (in) 7,529.5 5,738.2 41.17 PBR BAKER PBR 3.000 7,543.3 5,748.5 41.10 PACKER BAKER'FHU PACKER 2.937 7,581.3 5,777.2 40.91 NIPPLE CAMCO'D' NIPPLE NO GO 2.750 7.613.8 5,801.8 40.80 SOS CAMCO SHEAROUT SUB 2.937 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Bbn (TVD) (ftKB) Zone Date Shot Dens (shotsk t) Type Com 7,684.0 7,752.0 5,855.0 5,906.8 UNIT D, C-4, C-3, 3H-01 8/21/1988 12.0 RPERF 2 1/8" EnerJet; 60 deg. ph 7,712,0 7,716.0 5,876.2 5,879.3 C-4, 311-01 12/3/7987 2.0 (PERF 4" Densi Jet; 120 deg. ph 7,722.0 7,730.0 5,883.8 5,889.9 C4, 31-1-01 12/3/1987 2.0 IPERF 4" Densi Jet; 120 deg. ph 7,758.0 7,770.0 5,911.4 5,920.6 -3,3H-01 8/21/1988 8.0 APERF 2 1/8" EnerJet; 60 deg. ph 7,782.0 7,800.0 5,929.8 5,943.6 A-2, 31-1-01 8121/1988 8.0 APERF 2 1/8" EnerJet; 60 deg. ph 7,822.0 7,840.0 5,960.4 5,974.2 A-1, 3H-01 5/21/1988 8.0 APERF 2.5" Scallop; 90 deg. ph Mandrel Inserts at ani N Top (TVD) Valve Latch Port Size TRO Run Top (ftKB) (ftKB) Make Model OD (in) Sere Type Type (i n) (psi) Run Dale Com 1 2,935.6 2,505.5 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,235.0 4/24/2015 2 4,636.9 3,657.9 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,238.0 4/24/2015 3 5,900.9 4,552.4 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 4/24/2015 4 6,516.6 4,996.6 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 4/17/2015 5 7,008.7 5,351.3 CAMEO MMG 1 1/2 GAS LIFT D RK 0.000 0.0 4/24/2015 DCRi Notes: General & Safety End Dale Annotation 717/2007 NOTE: WAIVERED WELL- IA X OA COMMUNICATION 3/3/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 3H-01 Proposed CTD Schematic 6" 62# H-40 hoe Cd) 115' MD 9-5/8" 36# J-55 shoe @ 3577' MD Liner Top Packer 0 Proposed KOP @ 7785' MD C4 -sand perfs 7684'-7752' MD FA send perfs 17758'- 7840' MD 7" 26# J-55 shoe @ 8076' MD 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Cameo MMG gas lift mandrels @ 2936', 4637'. 5910'. 6517'. & 7009' RKB Baker 3-1/2" PBR 7072' MD (4" ID) Baker FHL Packer @ 7095' MD (2.93" ID) 3'/2' DS landing nipple at 7485' MD (2.813" ID) Baker Poor Boy Overshot @ 7506' RKB Baker 3-1/2" PBR 7530' MD (3" ID) Baker FHL packer @ 7543' MD (2.937" ID) Cameo D -Nipple @ 7581' MD (2.75" Min ID) Cameo SOS @ 7614" MD 31-1-01AL1 wp01 TD 11,600' MD Top of Liner -7,560' MD / 31A -01A wp02 Swell Packer TD 11,600' MD Top of Billet @ 8400' MD �...�_ ---------- - ConocoPh i I I i ps ConocoPhillips Alaska Inc _Kuparuk Kuparuk River Unit _2 Kuparuk 3H Pad 3H-01 3H -01A 3H-01A_wp02 Anticollision Report 16 October, 2019 ConocoPhillips Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit_2 Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 31-1-01 Well Error: 0.00 usft Reference Wellbore 3H -01A Reference Design: 3H-01A_wp02 ConocoPhillips Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-01 31-1-01 @ 76.00usft (31-1-01) 31-1-01 @ 76.00usft (31-1-01) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference 3H-01A_wp02 Offset Distance Filter type: GLOBAL FILTER APPLIED: All wellpaths within 2004 100/1000 of reference Measured Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,700.00 to 11,600.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 10/16/2019 From To (usft) (usft) Survey (Wellbore) Tool Name 100.00 7,700.00 3H-01 (31-1-01) BOSS -GYRO 7,700.00 11,600.00 3H-01A_wp02 (31-1-01A) MWD OWSG Summary Description Sperry -Sun BOSS gyro multishot OWSG MWD - Standard Offset Design Reference Offset Distance 0.75 2.76 Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) 37.16 Kuparuk 3H Pad 2.45 15.166 7,896.86 5,985.66 Distance 31-1-01 - 3H-01 - 31-1-01 8,900.00 6,900.00 797.26 793.06 189.481 CC, ES 31-1-01 -3H-01 -3H-01 9,268.33 6,525.00 1,053.09 1,047.23 179.603 SF 31-1-01 - 3H-01AL1 - 3H-01AL1_wp01 9,244.86 9,250.00 10.92 7.83 3.540 CC 31-1-01 - 3H-01AL1 - 3H-01AL1_wp01 11,373.29 11,375.00 12.81 -43.94 0.226 STOP Drilling, SF 31-1-01 - 3H-01AL1 - 3H-01AL1_wp01 11,397.58 11,400.00 14.96 -46.75 0.242 STOP Drilling, ES 3H-02 - 3H-02 - 31-1-02 (') (usft) (usft) (usft) Out of range 3H-03 - 31-1-03 - 3H-03 5,985.65 7,725.00 5,886.13 7,725.00 5,886.15 Out of range 3H-05 - 3H-05 - 3H-05 9,950.00 6,925.00 1,014.49 806.19 4.870 SF 3H-05 - 31-1-05 - 3H-05 9,965.35 6,850.00 1,013.17 805.48 4.878 CC, ES 31-1-06 - 3H-06 - 3H-06 -4.86 -4,428.66 -1,491.71 0.13 Out of range 31-1-07 - 31-1-07 - 3H-07 0.222 STOP Drilling 7,775.00 5,924.28 7,775.00 5,924.42 Out of range 31-1-26 - 31-1-261-1 - 31-1-261-1 11,600.07 6,700.00 34.66 -171.42 0.168 STOP Drilling, CC, ES, SF 3H-26 - 3H-261-1-01 - 3H-261-1-01 11,600.07 6,700.00 34.66 -171.42 0.168 STOP Drilling, CC, ES, SF 3H-26 - 31-1-261-1-02 - 31-1-261-1-02 11,600.07 6,700.00 34.66 -171.42 0.168 STOP Drilling, CC, ES, SF Offset Design Kuparuk 3H Pad - 3H-01 - 31-1-01 - 3H-01 7,875.00 6,001.05 0.75 2.76 0.94 Offset Site Error: 0.00 usft Survey Program: 100 -BOSS -GYRO 20.51 2.21 10.283 7,883.17 5,983.75 7,900.00 6,020.21 0.76 3.15 Offset Well Error: 0.00 usft Reference Offset 37.16 Semi Major Axis 2.45 15.166 7,896.86 5,985.66 Distance 6,039.37 0.77 3.54 Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth -4,557.12 -1,493.95 from North -N/-S +E/ -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (') (usft) (usft) (usft) (usft) (usft) 5,985.65 7,725.00 5,886.13 7,725.00 5,886.15 0.21 0.40 -4.87 -4,412.54 -1,491.43 0.03 -0.38 0.41 0.077 STOP Drilling 7,750.00 5,905.18 7,750.00 5,905.26 0.42 0.79 -4.86 -4,428.66 -1,491.71 0.13 -0.44 0.57 0.222 STOP Drilling 7,775.00 5,924.28 7,775.00 5,924.42 0.63 1.19 -4.85 -4,444.72 -1,491.99 0.21 -0.51 0.72 0.289 STOP Drilling 7,799.98 5,943.16 7,800.00 5,943.58 0.72 1.58 -1.07 -4,460.77 -1,492.27 0.61 -0.35 0.96 0.634 STOP Drilling 7,824.42 5,959.77 7,825.00 5,962.73 0.73 1.97 0.66 -4,476.83 -1,492.55 3.74 2.31 1.44 2.605 Normal Operations 7,846.96 5,971.85 7,850.00 5,981.89 0.74 2.37 0.89 -4,492.89 -1,492.83 11.31 9.44 1.88 6.032 7,866.61 5,979.52 7,875.00 6,001.05 0.75 2.76 0.94 -4,508.94 -1,493.11 22.72 20.51 2.21 10.283 7,883.17 5,983.75 7,900.00 6,020.21 0.76 3.15 0.97 -4,525.00 -1,493.39 37.16 34.71 2.45 15.166 7,896.86 5,985.66 7,925.00 6,039.37 0.77 3.54 0.98 -4,541.06 -1,493.67 53.91 51.30 2.62 20.589 7,908.25 5,986.13 7,950.00 6,058.53 0.78 3.94 0.80 -4,557.12 -1,493.95 72.40 69.67 2.73 26.484 7,922.60 5,986.00 7,975.00 6,077.69 0.79 4.33 -6.22 -4,573.17 -1,494.23 91.71 88.91 2.81 32.694 7,936.03 5,985.65 8,000.00 6,096.85 0.81 4.72 -13.60 -4,589.23 -1,494.51 111.34 108.46 2.88 38.691 7,948.34 5,985.13 8,025.00 6,116.01 0.83 5.11 -20.83 -4,605.29 -1,494.79 131.33 128.37 2.95 44.477 CC - Min centre to center distance or coveroent ooint. SF - min seoaration factor. ES - min ellipse seoaration 10/16/2019 1 24 15PM Page 2 COMPASS 5000.14 Build 85H Offset Design Kuparuk 3H Pad - 31-1-01 - 31-1-01 - 31-1-01 ConocoPhillips ConocoPhillips Anticollision Report offset Site Error: 0.00 usft Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well 31-1-01 Project: Kuparuk River Unit -2 TVD Reference: 3H-01 @ 76.00usft (31-1-01) Reference Site: Kuparuk 3H Pad MD Reference: 31-1-01 @ 76.00usft (31-1-01) Site Error: 0.00 usft North Reference: True Reference Well: 3H-01 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 2.00 sigma Reference Wellbore 3H -01A Database: EDT 14 Alaska Production Reference Design: 3H-01A_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3H Pad - 31-1-01 - 31-1-01 - 31-1-01 offset Site Error: 0.00 usft Survey Program: 100 -BOSS -GYRO Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North -N/-S +EI -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (I (usft) (usft) (usft) (usft) (usft) 7,960.00 5,984.49 8,050.00 6,135.17 0.85 5.51 -27.92 -4,621.35 -1,495.07 151.69 148.66 3.03 50.038 7,970.00 5,983.81 8,075.00 6,154.33 0.87 5.90 -34.27 -4,637.40 -1,495.35 172.44 169.34 3.11 55.509 7,978.31 5,983.16 8,100.00 6,173.49 0.88 6.29 -39.79 -4,653.46 -1,495.63 193.57 190.40 3.17 61.049 7,986.19 5,982.48 8,125.00 6,192.65 0.90 6.68 -45.04 -4,669.52 -1,495.91 215.07 211.83 3.23 66.534 7,993.18 5,981.82 8,150.00 6,211.81 0.92 7.08 -49.77 -4,685.57 -1,496.19 236.89 233.60 3.29 72.097 7,997.48 5,981.40 8,167.00 6,224.84 0.93 7.34 -52.72 -4,696.49 -1,496.38 251.90 248.59 3.32 75.945 8,900.00 5,926.24 6,875.00 5,253.99 3.35 0.00 -15.06 3,845.88 -1,458.21 814.25 810.02 4.23 192.335 8,900.00 5,926.24 6,900.00 5,272.12 3.35 0.00 -15.59 -3,862.93 -1,460.51 797.26 793.06 4.21 189.481 CC, ES 8,915.46 5,926.35 6,850.00 5,235.87 3.41 0.00 -13.50 -3,828.82 -1,455.81 831.34 827.03 4.30 193.123 8,925.22 5,926.45 6,825.00 5,217.77 3.45 0.00 -12.35 -3,811.76 -1,453.30 848.59 844.23 4.36 194.725 8,934.91 5,926.56 6,800.00 5,199.68 3.49 0.00 -11.23 -3,794.70 -1,450.68 865.96 861.55 4.41 196.364 8,950.00 5,926.78 6,750.00 5,163.58 3.56 0.00 -9.37 -3,760.53 -1,445.28 901.13 896.63 4.50 200.322 8,950.00 5,926.78 6,775.00 5,181.62 3.56 0.00 -9.78 -3,777.63 -1,448.00 883.50 879.02 4.48 197.292 8,963.53 5,927.02 6,725.00 5,145.58 3.63 0.00 -8.07 -3,743.40 -1,442.52 918.90 914.33 4.56 201.355 8,975.00 5,927.25 6,700.00 5,127.61 3.68 0.00 -6.94 -3,726.25 -1,439.72 936.81 932.19 4.62 202.716 9,007.04 5,927.93 6,675.00 5,109.67 3.86 0.00 -8.78 3,709.07 -1,436.90 954.67 949.92 4.75 200.827 9,049.18 5,928.83 6,650.00 5,091.76 4.08 0.00 -11.29 -3,691.86 -1,434.06 972.13 967.21 4.92 197.413 9,092.18 5,929.74 6,625.00 5,073.87 4.31 0.00 -13.82 -3,674.64 -1,431.20 989.17 984.07 5.10 193.870 9,135.83 5,930.66 6,600.00 5,056.00 4.54 0.00 -16.38 -3,657.39 -1,428.32 1,005.78 1,000.49 5.29 190.284 9,179.90 5,931.58 6,575.00 5,038.17 4.78 0.00 -18.93 -3,640.11 -1,425.43 1,021.96 1,016.49 5.47 186.687 9,224.15 5,932.49 6,550.00 5,020.38 5.02 0.00 -21.46 -3,622.79 -1,422.52 1,037.73 1,032.06 5.67 183.106 9,268.33 5,933.38 6,525.00 5,002.63 5.26 0.00 -23.96 -3,605.42 -1,419.59 1,053.09 1,047.23 5.86 179.603 SF 9,282.70 5,933.68 6,500.00 4,984.92 5.34 0.00 -23.37 -3,588.02 -1,416.65 1,068.27 1,062.33 5.94 179.840 9,291.74 5,933.89 6,475.00 4,967.23 5.40 0.00 -22.26 -3,570.61 -1,413.71 1,083.65 1,077.65 5.99 180.788 9,300.00 5,934.12 6,425.00 4,931.79 5.45 0.00 -20.75 -3,535.83 -1,407.83 1,115.16 1,109.10 6.06 184.119 9,300.00 5,934.12 6,450.00 4,949.52 5.45 0.00 -21.23 -3,553.21 -1,410.77 1,099.25 1,093.21 6.04 181.891 9,318.56 5,934.70 6,400.00 4,914.05 5.57 0.00 -19.09 -3,518.46 -1,404.89 1,131.11 1,124.96 6.15 183.880 9,327.37 5,935.02 6,375.00 4,896.26 5.63 0.00 -18.08 -3,501.14 -1,401.97 1,147.38 1,141.18 6.20 185.008 9,336.10 5,935.36 6,350.00 4,878.40 5.69 0.00 -17.10 -3,483.89 -1,399.07 1,163.91 1,157.66 6.25 186.200 9,350.00 5,935.95 6,275.00 4,824.37 5.78 0.00 -15.04 -3,432.58 -1,390.52 1,215.02 1,208.69 6.34 191.738 9,350.00 5,935.95 6,300.00 4,842.43 5.78 0.00 -15.42 -3,449.63 -1,393.37 1,197.71 1,191.38 6.33 189.207 9,350.00 5,935.95 6,325.00 4,860.46 5.78 0.00 -15.80 -3,466.72 -1,396.21 1,180.71 1,174.39 6.32 186.751 9,370.13 5,936.93 6,250.00 4,806.29 5.93 0.00 -13.40 -3,415.56 -1,387.60 1,232.26 1,225.82 6.44 191.353 9,378.47 5,937.37 6,225.00 4,788.21 5.99 0.00 -12.53 -3,398.56 -1,384.62 1,249.74 1,243.25 6.48 192.721 9,386.75 5,937.83 6,200.00 4,770.11 6.06 0.00 -11.67 -3,381.59 -1,381.57 1,267.34 1,260.81 6.53 194.109 9,400.00 5,938.62 6,125.00 4,715.82 6.16 0.00 -9.91 -3,330.72 -1,372.08 1,320.96 1,314.35 6.60 200.088 9,400.00 5,938.62 6,150.00 4,733.91 6.16 0.00 -10.21 -3,347.67 -1,375.30 1,302.92 1,296.32 6.60 197.417 9,400.00 5,938.62 6,175.00 4,752.01 6.16 0.00 -10.51 -3,364.63 -1,378.46 1,285.09 1,278.49 6.60 194.799 9,419.33 5,939.87 6,100.00 4,697.73 6.32 0.00 -8.41 -3,313.77 -1,368.81 1,338.92 1,332.21 6.70 199.757 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/1612019 1:24:15PM Page 3 COMPASS 5000 14 Build 85H Offset Design ConocoPhillips ConocoPhillips Anticollision Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well 31-1-01 Project: Kuparuk River Unit -2 ND Reference: 31-1-01 @ 76.00usft (31-1-01) Reference Site: Kuparuk 3H Pad MD Reference: 31-1-01 @ 76.00usft (31-1-01) Site Error: 0.00 usft North Reference: True Reference Well: 31-1-01 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 2.00 sigma Reference Wellbore 31-1-01A Database: EDT 14 Alaska Production Reference Design: 3H-01A_wp02 Offset ND Reference: Offset Datum Offset Design Kuparuk 3H Pad - 31-1-01 - 3H-01AL1 - 3H-01AL1_wp01 Offset She Error: 0.00 usft Survey Program: 100 -BOSS -GYRO, 7700 -MWD OWSG, 8400 -MWD OWSG Offset Well Error 0.00 usft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North -NI-S +E/ -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (usft) (usft) (usft) 8,424.98 5,936.40 8,425.00 5,936.03 0.05 0.D4 69.01 -4,453.77 -1,194.35 0.63 0.34 0.29 2.194 Caution Monitor Closely 8,449.96 5,934.81 8,450.00 5,933.28 0.10 0.07 56.36 4,430.03 -1,187.03 2.01 1.67 0.34 5.842 8,474.90 5,933.39 8,475.00 5,929.82 0.17 0.11 42.22 -4,406.45 -1,179.48 3.92 3.53 0.39 10.036 8,499.81 5,932.15 8,500.00 5,926.23 0.23 0.15 36.48 4,383.08 -1,171.37 6.19 5.76 0.44 14.168 8,524.70 5,931.09 8,525.00 5,922.78 0.31 0.20 34.83 -4,359.94 -1,162.54 8.55 8.06 0.49 17.409 8,549.58 5,930.19 8,550.00 5,919.46 0.39 0.25 34.69 -4,337.07 -1,153.02 10.97 10.42 0.55 20.092 8,574.44 5,929.48 8,575.00 5,916.29 0.48 0.31 35.25 4,314.48 -1,142.79 13.42 12.82 0.61 22.149 8,599.29 5,928.94 8,600.00 5,913.26 0.57 0.37 36.20 4,292.19 -1,131.88 15.92 15.25 0.67 23.890 8,624.15 5,928.58 8,625.00 5,910.63 0.68 0.44 36.94 4,270.12 -1,120.45 18.17 17.44 0.73 24.928 8,649.00 5,928.31 8,650.00 5,908.66 0.79 0.52 35.74 4,248.17 -1,108.65 19.91 19.11 0.80 24.922 8,673.81 5,928.04 8,675.00 5,907.35 0.90 0.60 37.68 4,226.36 -1,096.49 21.24 20.34 0.90 23.649 8,698.47 5,927.78 8,700.00 5,906.71 1.02 0.69 42.45 -4,204.72 -1,084.00 22.35 21.31 1.04 21.460 8,722.99 5,927.51 8,725.00 5,906.44 1.13 0.78 48.16 -4,182.98 -1,071.66 23.64 22.41 1.23 19.195 8,747.41 5,927.25 8,750.00 5,906.26 1.24 0.87 53.10 4,160.87 -1,059.99 25.19 23.76 1.43 17.585 8,771.74 5,926.99 8,775.00 5,906.18 1.35 0.97 57.32 -4,138.42 -1,048.99 26.97 25.33 1.64 16.443 8,795.97 5,926.74 8,800.00 5,906.19 1.46 1.07 60.86 -4,115.65 -1,038.68 28.92 27.08 1.84 15.706 8,820.12 5,926.48 8,825.00 5,906.30 1.56 1.18 63.83 -4,092.57 -1,029.07 31.00 28.96 2.04 15.211 8,845.35 5,926.26 8,850.00 5,906.50 1.68 1.28 68.51 4,069.21 -1,020.16 32.84 30.55 2.29 14.332 8,871.04 5,926.18 8,875.00 5,906.79 1.80 1.38 72.03 -4,045.60 -1,011.96 33.59 31.04 2.55 13.163 8,896.78 5,926.23 8,900.00 5,907.18 1.94 1.49 73.95 4,021.75 -1,004.48 33.13 30.34 2.79 11.888 8,900.00 5,926.24 6,875.00 5,253.99 1.95 0.00 -15.06 -3,845.88 -1,458.21 814.25 812.27 1.99 409.851 8,900.00 5,926.24 6,900.00 5,272.12 1.95 0.00 -15.59 -3,862.93 -1,460.51 797.26 795.29 1.98 403.173 8,915.46 5,926.35 6,850.00 5,235.87 2.04 0.00 -13.50 -3,828.82 -1,455.81 831.34 829.28 2.06 404.249 8,922.41 5,926.42 8,925.00 5,907.65 2.08 1.59 74.19 -3,997.68 -997.72 31.45 28.46 2.99 10.512 8,925.22 5,926.45 6,825.00 5,217.77 2.10 0.00 -12.35 -3,811.76 -1,453.30 848.59 846.48 2.10 403.487 8,934.91 5,926.56 6,800.00 5,199.68 2.15 0.00 -11.23 -3,794.70 -1,450.68 865.96 863.81 2.15 402.962 8,947.80 5,926.75 8,950.00 5,908.22 2.23 1.69 72.29 -3,973.43 -991.70 28.65 25.53 3.12 9.180 8,950.00 5,926.78 6,750.00 5,163.58 2.24 0.00 -9.37 -3,760.53 -1,445.28 901.13 896.91 2.22 405.560 8,950.00 5,926.78 6,775.00 5,181.62 2.24 0.00 -9.78 -3,777.63 -1,448.00 883.50 881.28 2.22 398.623 8,963.53 5,927.02 6,725.00 5,145.58 2.33 0.00 -8.07 -3,743.40 -1,442.52 918.90 916.61 2.29 401.859 8,972.81 5,927.20 8,975.00 5,908.89 2.39 1.80 67.11 -3,949.00 -986.42 24.98 21.87 3.11 8.043 8,975.00 5,927.25 6,700.00 5,127.61 2.40 0.00 -6.94 -3,726.25 -1,439.72 936.81 934.47 2.34 399.998 8,996.81 5,927.72 9,000.00 5,909.64 2.54 1.90 54.80 -3,924.43 -981.89 21.29 18.49 2.81 7.591 9,007.04 5,927.93 6,675.00 5,109.67 2.61 0.00 -8.78 -3,709.07 -1,436.90 954.67 952.18 2.49 383.189 9,020.88 5,928.23 9,025.00 5,910.48 2.70 2.01 38.40 -3,899.73 -978.10 18.58 16.25 2.33 7.976 9,045.12 5,928.75 9,050.00 5,911.41 2.86 2.11 18.56 -3,874.94 -975.06 17.34 15.23 2.11 8.223 9,049.18 5,928.83 6,650.00 5,091.76 2.88 0.00 -11.29 -3,691.86 -1,434.06 972.13 969.45 2.68 362.693 9,069.69 5,929.27 9,075.00 5,912.44 3.02 2.22 0.19 -3,850.14 -972.03 17.66 15.03 2.63 6.712 9,092.18 5,929.74 6,625.00 5,073.87 3.16 0.00 -13.82 -3,674.64 -1,431.20 989.17 986.30 2.87 344.937 9,094.64 5,929.80 9,100.00 5,913.55 3.18 2.34 -12.67 -3,825.46 -968.24 18.53 15.26 3.27 5.668 9,119.85 5,930.33 9,125.00 5,914.76 3.34 2.46 -20.83 -3,800.90 -963.71 19.04 15.30 3.74 5.093 9,135.83 5,930.66 6,600.00 5,056.00 3.44 0.00 -16.38 -3,657.39 -1,428.32 1,005.78 1,002.73 3.05 329.523 9,145.19 5,930.86 9,150.00 5,916.05 3.50 2.59 -25.25 -3,776.50 -958.43 18.73 14.71 4.03 4.652 9,170.49 5,931.38 9,175.00 5,917.44 3.66 2.73 -26.13 -3,752.28 -952.42 17.44 13.30 4.14 4.217 9,179.90 5,931.58 6,575.00 5,038.17 3.72 0.00 -18.93 -3,640.11 -1,425.43 1,021.96 1,018.73 3.23 315.954 9,195.63 5,931.90 9,200.00 5,918.91 3.82 2.88 -22.42 -3,728.25 -945.67 15.23 11.25 3.98 3.825 9,220.46 5,932.41 9,225.00 5,920.47 3.97 3.03 -10.82 -3,704.44 -938.20 12.57 9.16 3.40 3.692 9,224.15 5,932.49 6,550.00 5,020.38 3.99 0.00 -21.46 -3,622.79 -1,422.52 1,037.73 1,034.31 3.42 303.822 9,244.86 5,932.91 9,250.00 5,922.11 4.12 3.19 14.08 -3,680.88 -930.01 10.92 7.83 3.08 3.540 CC 9,268.33 5,933.38 6,525.00 5,002.63 4.27 0.00 -23.96 -3,605.42 -1,419.59 1,053.09 1,049.50 3.60 292.901 9,268.91 5,933.39 9,275.00 5,923.72 4.27 3.36 42.96 -3,657.32 -921.81 12.46 7.74 4.73 2.636 Normal Operations 9,282.70 5,933.68 6,500.00 4,984.92 4.36 0.00 -23.37 -3,588.02 -1,416.65 1,068.27 1,064.60 3.67 291.442 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/16/2019 1:24.15PM Page 4 COMPASS 5000.14 Build 85H Offset Design Kuparuk 3H Pad - 31-1-01 - 3H-01AL1 - 3H-01AL1_wp01 ConocoPhillips Conocoips Anticollision Report Offset Site Error: 000 Usti Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well 31-1-01 Project: Kuparuk River Unit -2 TVD Reference: 31-1-01 @ 76.00usft (31-1-01) Reference Site: Kuparuk 3H Pad MD Reference: 3H-01 @ 76.00usft (31-1-01) Site Error: 0.00 usft North Reference: True Reference Well: 31-1-01 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 2.00 sigma Reference Wellbore 31-1-01A Database: EDT 14 Alaska Production Reference Design: 3H-01A_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3H Pad - 31-1-01 - 3H-01AL1 - 3H-01AL1_wp01 Offset Site Error: 000 Usti Survey Program: 100 -BOSS -GYRO, 7700 -MWD OWSG, 8400 -MWD OWSG Offset Well Error. 0.00 usft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North -NI-S +E1 -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft( (usft) (usft( (usft) 9,291.74 5,933.89 6,475.00 4,967.23 4.42 0.00 -22.26 -3,570.61 -1,413.71 1,083.65 1,079.93 3.71 291.714 9,293.33 5,933.93 9,300.00 5,925.16 4.43 3.53 62.01 -3,633.51 -914.32 16.26 10.21 6.04 2.690 Normal Operations 9,300.00 5,934.12 6,425.00 4,931.79 4.47 0.00 -20.75 -3,535.83 -1,407.83 1,115.16 1,111.39 3.77 295.767 9,300.00 5,934.12 6,450.00 4,949.52 4.47 0.00 -21.23 -3,553.21 -1,410.77 1,099.25 1,095.49 3.76 292.374 9,318.32 5,934.69 9,325.00 5,926.45 4.60 3.70 71.88 -3,609.49 -907.54 19.91 13.06 6.85 2.908 Normal Operations 9,318.56 5,934.70 6,400.00 4,914.05 4.60 0.00 -19.09 -3,518.46 -1,404.89 1,131.11 1,127.25 3.86 293.153 9,327.37 5,935.02 6,375.00 4,896.26 4.66 0.00 -18.08 -3,501.14 -1,401.97 1,147.38 1,143.48 3.90 293.876 9,336.10 5,935.36 6,350.00 4,878.40 4.72 0.00 -17.10 -3,483.89 -1,399.07 1,163.91 1,159.96 3.95 294.751 9,343.66 5,935.67 9,350.00 5,927.57 4.78 3.87 77.02 -3,585.26 -901.48 22.58 15.15 7.43 3.038 9,350.00 5,935.95 6,275.00 4,824.37 4.82 0.00 -15.04 -3,432.58 -1,390.52 1,215.02 1,211.00 4.02 302.111 9,350.00 5,935.95 6,300.00 4,842.43 4.82 0.00 -15.42 -3,449.63 -1,393.37 1,197.71 1,193.69 4.02 297.996 9,350.00 5,935.95 6,325.00 4,860.46 4.82 0.00 -15.80 -3,466.72 -1,396.21 1,180.71 1,176.69 4.02 294.063 9,369.20 5,936.88 9,375.00 5,928.53 4.97 4.04 79.44 -3,560.85 -896.15 24.05 16.13 7.92 3.035 9,370.13 5,936.93 6,250.00 4,806.29 4.98 0.00 -13.40 -3,415.56 -1,387.60 1,232.26 1,228.14 4.12 299.110 9,378.47 5,937.37 6,225.00 4,788.21 5.05 0.00 -12.53 -3,398.56 -1,384.62 1,249.74 1,245.57 4.16 300.361 9,386.75 5,937.83 6,200.00 4,770.11 5.11 0.00 -11.67 -3,381.59 -1,381.57 1,267.34 1,263.14 4.20 301.687 9,394.79 5,938.30 9,400.00 5,929.32 5.17 4.21 79.73 -3,536.29 -891.54 24.25 15.94 8.31 2.917 Normal Operations 9,400.00 5,938.62 6,125.00 4,715.82 5.21 0.00 -9.91 -3,330.72 -1,372.08 1,320.96 1,316.70 4.26 310.083 9,400.00 5,938.62 6,150.00 4,733.91 5.21 0.00 -10.21 -3,347.67 -1,375.30 1,302.92 1,298.66 4.26 305.638 9,400.00 5,938.62 6,175.00 4,752.01 5.21 0.00 -10.51 -3,364.63 -1,378.46 1,285.09 1,280.82 4.26 301.324 9,419.33 5,939.87 6,100.00 4,697.73 5.38 0.00 -8.41 -3,313.77 -1,368.81 1,338.92 1,334.56 4.36 307.203 9,420.30 5,939.94 9,425.00 5,929.95 5.39 4.38 77.74 -3,511.61 -887.67 23.26 14.69 8.56 2.716 Normal Operations 9,445.58 5,941.77 9,450.00 5,930.41 5.60 4.55 72.58 -3,486.81 -884.54 21.28 12.75 8.52 2.497 Caution Monitor Closely 9,470.03 5,943.59 9,475.00 5,930.71 5.81 4.73 61.24 -3,461.93 -882.14 19.04 11.13 7.91 2.406 Caution Monitor Closely 9,494.46 5,945.16 9,500.00 5,930.84 6.03 4.90 47.11 -3,436.98 -880.49 17.47 10.62 6.85 2.551 Normal Operations 9,519.12 5,946.50 9,525.00 5,930.88 6.25 5.09 33.71 -3,412.04 -878.83 16.99 11.20 5.79 2.935 Normal Operations 9,544.03 5,947.58 9,550.00 5,930.91 6.47 5.27 25.04 -3,387.16 -876.41 17.35 12.06 5.30 3.275 9,569.07 5,948.41 9,575.00 5,930.92 6.70 5.47 21.50 -3,362.36 -873.23 18.04 12.71 5.33 3.386 9,594.09 5,948.97 9,600.00 5,930.92 6.92 5.67 22.65 -3,337.67 -869.30 18.87 13.10 5.76 3.273 9,618.96 5,949.26 9,625.00 5,930.91 7.15 5.88 27.77 -3,313.12 -864.61 20.04 13.34 6.69 2.993 Normal Operations 9,643.94 5,949.35 9,650.00 5,930.88 7.38 6.10 37.24 -3,288.72 -859.17 21.83 13.77 8.06 2.709 Normal Operations 9,669.12 5,949.40 9,675.00 5,930.84 7.63 6.33 46.25 -3,264.49 -853.00 24.02 14.61 9.41 2.553 Normal Operations 9,694.41 5,949.40 9,700.00 5,930.79 7.88 6.56 54.00 -3,240.47 -846.08 26.52 15.86 10.65 2.490 Caution Monitor Closely 9,719.82 5,949.37 9,725.00 5,930.72 8.14 6.80 60.72 -3,216.67 -838.44 29.22 17.44 11.78 2.481 Caution Monitor Closely 9,745.35 5,949.29 9,750.00 5,930.64 8.41 7.04 66.62 -3,193.11 -830.07 32.08 19.28 12.81 2.505 Normal Operations 9,770.99 5,949.17 9,775.00 5,930.55 8.68 7.29 71.86 -3,169.82 -820.99 35.05 21.30 13.75 2.549 Normal Operations 9,796.76 5,949.00 9,800.00 5,930.44 8.96 7.54 76.59 -3,146.82 -811.20 38.10 23.47 14.63 2.604 Normal Operations 9,822.73 5,948.80 9,825.00 5,930.32 9.26 7.80 80.44 -3,123.82 -801.41 40.51 25.11 15.41 2.629 Normal Operations 9,848.90 5,948.55 9,850.00 5,930.19 9.55 8.06 83.19 -3,100.53 -792.33 41.57 25.51 16.05 2.589 Normal Operations 9,875.12 5,948.25 9,875.00 5,930.04 9.85 8.33 85.01 -3,076.97 -783.96 41.21 24.62 16.59 2.483 Caution Monitor Closely 9,901.22 5,947.91 9,900.00 5,929.89 10.16 8.60 85.86 -3,053.17 -776.31 39.45 22.45 16.99 2.321 Caution Monitor Closely 9,927.07 5,947.54 9,925.00 5,929.71 10.46 8.86 85.48 -3,029.14 -769.40 36.33 19.12 17.21 2.111 Caution Monitor Closely 9,952.50 5,947.13 9,950.00 5,929.53 10.77 9.13 83.25 -3,004.92 -763.22 31.98 14.91 17.07 1.873 Caution Monitor Closely 9,977.39 5,946.69 9,975.00 5,929.33 11.07 9.40 77.79 -2,980.52 -757.79 26.68 10.45 16.23 1.644 Caution Monitor Closely 10,001.62 5,946.23 10,000.00 5,929.13 11.36 9.68 65.95 -2,955.97 -753.10 21.11 7.41 13.70 1.541 Caution Monitor Closely 10,025.35 5,945.74 10,025.00 5,928.91 11.65 9.95 44.37 -2,931.41 -748.41 17.25 8.36 8.89 1.941 Caution Monitor Closely 10,049.02 5,945.28 10,050.00 5,928.70 11.95 10.23 16.24 -2,907.01 -742.98 17.08 7.71 9.37 1.824 Caution Monitor Closely 10,073.34 5,944.90 10,075.00 5,928.48 12.26 10.52 -4.27 -2,882.79 -736.80 19.49 5.43 14.06 1.386 Take Immediate Action 10,098.17 5,944.60 10,100.00 5,928.27 12.58 10.82 -16.82 -2,858.77 -729.89 22.49 5.32 17.18 1.309 Take Immediate Action 10,123.40 5,944.39 10,125.00 5,928.06 12.91 11.12 -24.34 -2,834.96 -722.24 25.00 5.99 19.01 1.315 Take Immediate Action 10,148.87 5,944.27 10,150.00 5,927.84 13.25 11.42 -28.68 -2,811.41 -713.88 26.55 6.46 20.09 1.322 Take Immediate Action 10,174.46 5,944.26 10,175.00 5,927.63 13.59 11.73 -30.65 -2,788.12 -704.79 26.99 6.35 20.63 1.308 Take Immediate Action CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/16/2019 1:24:15PM Page 5 COMPASS 5000.14 Build 85H z. ConocoPhillips Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 3H-01 Well Error: 0.00 usft Reference Wellbore 3H -01A Reference Design: 3H-01A_wp02 ConocoPhillips Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-01 31-1-01 @ 76.00usft (31-1-01) 31-1-01 @ 76.00usft (31-1-01) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Offset Design Kuparuk 3H Pad - 31-1-01 - 3H-01AL1 - 3H-01AL1_wp01 Offset Site Error: 0.00 usft Survey Program: 100 -BOSS -GYRO, 7700 -MWD OWSG, 8400 -MWD OWSG Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North +N1 -S +E1 -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) l°) (usft) (usft) (usft) (usft) (usft) 10,199.86 5,944.42 10,200.00 5,927.42 13.93 12.04 -30.18 -2,765.12 -695.00 26.35 5.73 20.62 1.278 Take Immediate Action 10,225.15 5,944.85 10,225.00 5,927.55 14.27 12.36 -28.28 -2,742.19 -685.04 25.04 4.85 20.19 1.240 Take Immediate Action 10,250.34 5,945.54 10,250.00 5,928.33 14.61 12.68 -26.02 -2,719.13 -675.43 23.31 3.74 19.56 1.191 Take Immediate Action 10,275.43 5,946.50 10,275.00 5,929.77 14.96 13.01 -23.10 -2,695.95 -666.18 21.18 2.52 18.66 1.135 Take Immediate Action 10,300.38 5,947.71 10,300.00 5,931.88 15.29 13.33 -18.98 -2,672.67 -657.31 18.69 1.42 17.28 1.082 Take Immediate Action 10,325.23 5,949.16 10,325.00 5,934.02 15.63 13.66 -12.01 -2,649.24 -648.85 16.54 1.61 14.92 1.108 Take Immediate Action 10,350.35 5,950.57 10,350.00 5,935.57 15.97 13.99 -1.56 -2,625.61 -640.84 15.31 3.53 11.78 1.300 Take Immediate Action 10,375.33 5,951.58 10,375.00 5,936.54 16.31 14.33 10.91 -2,601.80 -633.28 15.06 4.53 10.52 1.431 Take Immediate Action 10,400.19 5,952.21 10,400.00 5,936.93 16.65 14.66 23.42 -2,577.84 -626.18 15.94 2.72 13.22 1.206 Take Immediate Action 10,424.95 5,952.46 10,425.00 5,937.01 16.99 15.00 33.99 -2,553.69 -619.69 17.60 0.24 17.36 1.014 Take Immediate Action 10,450.06 5,952.52 10,450.00 5,937.06 17.33 15.34 43.77 -2,529.37 -613.94 19.28 -1.38 20.66 0.933 STOP Drilling 10,475.38 5,952.60 10,475.00 5,937.08 17.70 15.68 48.97 -2,504.87 -608.93 20.29 -2.18 22.47 0.903 STOP Drilling 10,500.78 5,952.70 10,500.00 5,937.08 18.06 16.02 50.61 -2,480.24 -604.67 20.38 -2.67 23.05 0.884 STOP Drilling 10,526.11 5,952.80 10,525.00 5,937.05 18.43 16.36 48.70 -2,455.49 -601.17 19.55 -2.74 22.28 0.877 STOP Drilling 10,551.22 5,952.92 10,5%00 5,936.99 18.81 16.69 42.31 -2,430.64 -598.42 18.07 -1.52 19.59 0.922 STOP Drilling 10,575.98 5,953.06 10,575.00 5,936.91 19.18 17.03 29.70 -2,405.72 -596.43 16.63 2.02 14.61 1.138 Take Immediate Action 10,600.26 5,953.20 10,600.00 5,936.80 19.55 17.37 10.42 -2,380.75 -595.20 16.53 3.37 13.16 1.256 Take Immediate Action 10,624.17 5,953.35 10,625.00 5,936.68 19.93 17.72 -8.58 -2,355.78 -593.98 18.86 -1.92 20.78 0.908 STOP Drilling 10,647.89 5,953.51 10,650.00 5,936.55 20.30 18.06 -21.53 -2,330.86 -591.99 22.99 -4.47 27.46 0.637 STOP Drilling 10,671.43 5,953.68 10,675.00 5,936.43 20.67 18.42 -29.55 -2,306.02 -589.24 28.11 -3.60 31.71 0.886 STOP Drilling 10,694.80 5,953.86 10,700.00 5,936.31 21.04 18.78 -34.42 -2,281.27 -585.73 33.74 -0.70 34.45 0.980 STOP Drilling 10,718.00 5,954.05 10,725.00 5,936.19 21.41 19.16 -37.36 -2,256.63 -581.47 39.64 3.28 36.36 1.090 Take Immediate Action 10,741.04 5,954.24 10,750.00 5,936.06 21.77 19.53 -39.08 -2,232.14 -576.46 45.68 7.90 37.79 1.209 Take Immediate Action 10,763.92 5,954.45 10,775.00 5,935.94 22.14 19.92 -39.99 -2,207.81 -570.71 51.79 12.86 38.93 1.330 Take Immediate Action 10,788.33 5,954.67 10,800.00 5,935.82 22.54 20.30 -42.03 -2,183.67 -564.21 57.73 17.65 40.08 1.440 Take Immediate Action 10,814.71 5,954.89 10,825.00 5,935.70 22.97 20.69 -45.03 -2,159.74 -556.98 62.43 21.17 41.27 1.513 Caution Monitor Closely 10,841.52 5,955.08 10,850.00 5,935.59 23.41 21.09 -47.53 -2,136.05 -549.02 65.66 23.35 42.31 1.552 Caution Monitor Closely 10,868.58 5,955.24 10,875.00 5,935.47 23.86 21.48 -49.63 -2,112.60 -540.34 67.38 24.15 43.23 1.559 Caution Monitor Closely 10,895.74 5,955.37 10,900.00 5,935.35 24.32 21.88 -51.36 -2,089.43 -530.95 67.57 23.54 44.03 1.535 Caution Monitor Closely 10,922.83 5,955.47 10,925.00 5,935.24 24.78 22.28 -52.71 -2,066.56 -520.86 66.23 21.53 44.70 1.482 Take Immediate Action 10,949.68 5,955.53 10,950.00 5,935.13 25.23 22.69 -53.59 -2,044.01 -510.07 63.40 18.20 45.20 1.403 Take Immediate Action 10,976.15 5,955.57 10,975.00 5,935.02 25.68 23.09 -53.88 -2,021.80 -498.60 59.10 13.63 45.48 1.300 Take Immediate Action 11,002.06 5,955.57 11,000.00 5,934.91 26.12 23.49 -53.29 -1,999.95 -486.46 53.44 8.03 45.42 1.177 Take Immediate Action 11,027.55 5,955.54 11,025.00 5,934.80 26.56 23.91 -51.75 -1,978.10 -474.32 47.20 2.28 44.92 1.051 Take Immediate Action 11,052.80 5,955.49 11,050.00 5,934.69 26.98 24.32 -49.23 -1,955.89 -462.84 41.15 -2.70 43.85 0.938 STOP Drilling 11,077.83 5,955.40 11,075.00 5,934.58 27.41 24.74 -45.29 -1,933.33 -452.06 35.38 -6.52 41.90 0.844 STOP Drilling 11,102.64 5,955.29 11,100.00 5,934.47 27.82 25.16 -39.27 -1,910.46 -441.96 30.08 -8.42 38.50 0.781 STOP Drilling 11,127.17 5,955.16 11,125.00 5,934.37 28.23 25.58 -29.98 -1,887.29 -432.57 25.54 -7.37 32.91 0.776 STOP Drilling 11,151.11 5,955.00 11,150.00 5,934.26 28.64 26.01 -15.78 -1,863.85 -423.90 22.53 -3.56 26.09 0.864 STOP Drilling 11,175.50 5,954.82 11,175.00 5,934.34 29.06 26.44 -2.63 -1,840.17 -415.89 20.90 0.40 20.50 1.020 Take Immediate Action 11,200.23 5,954.61 11,200.00 5,934.81 29.49 26.87 7.87 -1,816.29 -408.51 19.82 1.55 18.27 1.085 Take Immediate Action 11,225.16 5,954.37 11,225.00 5,935.66 29.93 27.31 15.01 -1,792.23 -401.77 18.73 0.19 18.54 1.010 Take Immediate Action 11,250.16 5,954.10 11,250.00 5,936.88 30.38 27.74 18.28 -1,768.01 -395.68 17.27 -1.78 19.05 0.906 STOP Drilling 11,275.11 5,953.81 11,275.00 5,938.49 30.84 28.17 16.70 -1,743.67 -390.23 15.32 -3.57 18.90 0.811 STOP Drilling 11,299.86 5,953.50 11,300.00 5,940.47 31.29 28.60 7.91 -1,719.21 -385.44 13.21 -8.11 21.32 0.620 STOP Drilling 11,324.44 5,953.16 11,325.00 5,942.65 31.74 29.04 -7.71 -1,694.78 -380.60 11.81 -20.57 32.38 0.365 STOP Drilling 11,348.91 5,952.80 11,350.00 5,944.82 32.19 29.48 -25.72 -1,670.51 -375.02 11.66 -34.87 46.53 0.251 STOP Drilling 11,373.29 5,952.42 11,375.00 5,946.98 32.65 29.92 -42.13 -1,646.42 -368.69 12.81 -43.94 56.75 0.226 STOP Drilling, SF 11,397.58 5,952.02 11,400.00 5,949.14 33.10 30.37 -54.47 -1,622.54 -361.63 14.96 -46.75 61.70 0.242 STOP Drilling, ES 11,421.78 5,951.60 11,425.00 5,951.30 33.56 30.82 -62.89 -1,598.88 -353.84 17.74 -45.73 63.47 0.280 STOP Drilling 11,445.89 5,951.16 11,450.00 5,953.44 34.01 31.28 -68.45 -1,575.48 -345.33 20.89 -42.89 63.79 0.328 STOP Drilling 11,469.92 5,950.70 11,475.00 5,955.57 34.46 31.73 -72.09 -1,552.34 -336.10 24.26 -39.29 63.55 0.382 STOP Drilling CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/16/2019 1:24:15PM Page 6 COMPASS 5000 14 Build 85H V- ConocoPhillips Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 3H-01 Well Error: 0.00 usft Reference Wellbore 31-1-01A Reference Design: 3H-01A_wp02 ConocoPhillips Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-01 31-11-01 @ 76.00usft (31-1-01) 3H-01 @ 76.00usft (31-1-01) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Offset Design Kuparuk 3H Pad - 31-1-01 - 3H-01AL1 - 3H-01AL1_wp01 Offset Site Error: 0.00 usft Survey Program: 100 -BOSS -GYRO, 7700 -MWD OWSG, 8400 -MWD OWSG Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North +N/ -S +EI -W Centres Ellipses Separation Factor lush) (usft) (usft) (usft) (usft) (usft) V) (usft) (usft) (usft) (usft) (usft) 11,493.86 5,950.21 11,500.00 5,957.68 34.91 32.19 -74.44 -1,529.50 -326.17 27.76 -35.35 63.12 0.440 STOP Drilling 11,517.72 5,949.71 11,525.00 5,959.78 35.36 32.65 -75.90 -1,506.97 -315.55 31.34 -31.30 62.64 0.500 STOP Drilling 11,541.50 5,949.20 11,550.00 5,961.87 35.81 33.12 -76.75 -1,484.77 -304.23 34.95 -27.22 62.17 0.562 STOP Drilling 11,565.20 5,948.66 11,575.00 5,963.93 36.25 33.58 -77.14 -1,462.93 -292.25 38.59 -23.14 61.72 0.625 STOP Drilling 11,588.83 5,948.11 11,600.00 5,965.97 36.70 34.04 -77.21 -1,441.47 -279.59 42.22 -19.07 61.30 0.689 STOP Drilling CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/16/2019 1:24:15PM Page 7 COMPASS 5000.14 Build 85H Offset Design ConocoPhillips ConocoPhillips Anticollision Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 31-1-01 Project: Kuparuk River Unit_2 TVD Reference: 3H-01 @ 76.00usft (3H-01) Reference Site: Kuparuk 3H Pad MD Reference: 3H-01 @ 76.00usft (31-1-01) Site Error: 0.00 usft North Reference: True Reference Well: 3H-01 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 2.00 sigma Reference Wellbore 3H -01A Database: EDT 14 Alaska Production Reference Design: 3H-01A_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3H Pad - 3H-05 - 3H-05 - 3H-05 Offset Site Error: 0.00 usft Survey Program: 100-BOSS-GYR(D Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North +N/ -S +EI -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (usft) (usft) (usft) 9,884.46 5,948.13 7,155.00 6,190.04 129.93 76.82 -81.49 -2,672.43 -1,758.37 1,046.31 841.75 204.56 5.115 9,885.77 5,948.12 7,150.00 6,185.98 129.95 76.79 -81.18 -2,669.81 -1,757.08 1,045.18 840.45 204.73 5.105 9,900.00 5,947.93 7,050.00 6,104.85 130.11 75.77 -75.85 -2,617.35 -1,731.28 1,026.73 819.75 206.98 4.960 9,900.00 5,947.93 7,075.00 6,125.13 130.11 76.11 -76.94 -2,630.47 -1,737.73 1,030.52 823.85 206.68 4.986 9,900.00 5,947.93 7,100.00 6,145.42 130.11 76.45 -78.03 -2,643.58 -1,744.18 1,034.90 828.64 206.26 5.018 9,900.00 5,947.93 7,125.00 6,165.70 130.11 76.62 -79.11 -2,656.69 -1,750.63 1,039.86 834.25 205.61 5.057 9,918.80 5,947.66 7,025.00 6,084.56 130.33 75.43 -73.41 -2,604.24 -1,724.84 1,023.15 815.57 207.58 4.929 9,925.45 5,947.56 7,000.00 6,064.28 130.41 75.09 -71.82 -2,591.13 -1,718.39 1,020.24 812.37 207.86 4.908 9,932.09 5,947.46 6,975.00 6,043.99 130.49 74.75 -70.23 -2,578.03 -1,711.93 1,017.82 809.76 208.06 4.892 9,950.00 5,947.17 6,875.00 5,962.69 130.70 73.40 -64.43 -2,525.88 -1,686.02 1,013.18 805.52 207.66 4.879 9,950.00 5,947.17 6,900.00 5,983.03 130.70 73.74 -65.57 -2,538.89 -1,692.51 1,013.54 805.50 208.04 4.872 9,950.00 5,947.17 6,925.00 6,003.36 130.70 74.08 -66.70 -2,551.91 -1,699.00 1,014.49 806.19 208.30 4.870 SF 9,950.00 5,947.17 6,950.00 6,023.68 130.70 74.41 -67.83 -2,564.95 -1,705.47 1,016.04 807.60 208.44 4.874 9,965.35 5,946.91 6,850.00 5,942.36 130.88 73.06 -62.20 -2,512.87 -1,679.50 1,013.17 805.48 207.69 4.876 CC, ES 9,972.02 5,946.79 6,825.00 5,922.03 130.96 72.73 -60.59 -2,499.87 -1,672.97 1,013.73 806.39 207.34 4.889 9,978.69 5,946.67 6,800.00 5,901.70 131.03 72.39 -58.99 -2,486.88 -1,666.41 1,014.80 807.89 206.90 4.905 9,985.37 5,946.54 6,775.00 5,881.38 131.11 72.05 -57.38 -2,473.89 -1,659.85 1,016.37 809.99 206.38 4.925 10,000.00 5,946.26 6,700.00 5,820.35 131.29 71.04 -52.99 -2,434.97 -1,640.19 1,024.18 820.12 204.06 5.019 10,000.00 5,946.26 6,725.00 5,840.70 131.29 71.38 -54.10 -2,447.93 -1,646.74 1,021.05 815.92 205.13 4.978 10,000.00 5,946.26 6,750.00 5,861.04 131.29 71.72 -55.22 -2,460.90 -1,653.29 1,018.52 812.44 206.08 4.942 10,441.14 5,952.50 6,675.00 5,800.00 137.14 70.70 -74.96 -2,422.00 -1,633.66 1,025.17 818.93 206.24 4.971 10,450.00 5,952.52 6,600.00 5,738.97 137.27 69.70 -70.83 -2,382.99 -1,614.22 1,021.99 816.66 205.33 4.977 10,450.00 5,952.52 6,625.00 5,759.31 137.27 70.03 -72.00 -2,396.01 -1,620.67 1,022.44 816.78 205.66 4.972 10,450.00 5,952.52 6,650.00 5,779.65 137.27 70.37 -73.18 -2,409.02 -1,627.15 1,023.53 817.66 205.87 4.972 10,465.65 5,952.57 6,575.00 5,718.62 137.50 69.36 -68.57 -2,369.96 -1,607.78 1,021.89 817.36 204.53 4.996 10,471.85 5,952.59 6,550.00 5,698.28 137.59 69.02 -66.97 -2,356.95 -1,601.32 1,022.41 818.54 203.87 5.015 10,478.08 5,952.61 6,525.00 5,677.93 137.68 68.69 -65.37 -2,343.95 -1,594.86 1,023.45 820.33 203.12 5.039 10,484.32 5,952.63 6,500.00 5,657.57 137.77 68.35 -63.77 -2,330.96 -1,588.39 1,025.01 822.72 202.28 5.067 10,500.00 5,952.69 6,400.00 5,576.36 137.99 67.00 -58.09 -2,278.80 -1,562.22 1,036.20 837.98 198.22 5.228 10,500.00 5,952.69 6,425.00 5,596.62 137.99 67.34 -59.23 -2,291.88 -1,568.81 1,032.62 833.31 199.31 5.181 10,500.00 5,952.69 6,450.00 5,616.91 137.99 67.68 -60.37 -2,304.93 -1,575.37 1,029.61 829.31 200.30 5.140 10,500.00 5,952.69 6,475.00 5,637.23 137.99 68.01 -61.51 -2,317.96 -1,581.90 1,027.16 825.97 201.19 5.105 10,516.13 5,952.76 6,375.00 5,556.12 138.23 66.66 -55.85 -2,265.71 -1,555.60 1,040.07 843.19 196.88 5.283 10,522.59 5,952.79 6,350.00 5,535.88 138.33 66.32 -54.29 -2,252.60 -1,548.98 1,044.52 848.95 195.58 5.341 10,529.09 5,952.82 6,325.00 5,515.65 138.43 65.98 -52.75 -2,239.49 -1,542.36 1,049.47 855.25 194.21 5.404 10,535.61 5,952.85 6,300.00 5,495.43 138.53 65.64 -51.21 -2,226.38 -1,535.73 1,054.89 862.10 192.79 5.472 10,550.00 5,952.92 6,200.00 5,414,52 138.74 64.27 -46.02 -2,174.03 -1,509.01 1,081.17 894.63 186.54 5.796 10,550.00 5,952.92 6,225.00 5,434.75 138.74 64.61 -47.04 -2,187.09 -1,515.73 1,073.88 885.69 188.19 5.706 10,550.00 5,952.92 6,250.00 5,454.98 138.74 64.95 48.08 -2,200.17 -1,522.42 1,067.10 877.32 189.77 5.623 10,550.00 5,952.92 6,275.00 5,475.21 138.74 65.30 49.14 -2,213.26 -1,529.09 1,060.83 869.55 191.28 5.546 10,568.50 5,953.01 6,175.00 5,394.28 139.02 63.93 -43.72 -2,161.00 -1,502.26 1,088.62 903.72 184.90 5.888 10,575.12 5,953.05 6,150.00 5,374.04 139.12 63.59 42.27 -2,147.99 -1,495.48 1,096.62 913.42 183.20 5.986 10,581.75 5,953.09 6,125.00 5,353.78 139.23 63.25 -40.83 -2,135.02 -1,488.68 1,105.03 923.56 181.47 6.089 10,600.00 5,953.19 6,025.00 5,272.61 139.50 61.90 -35.83 -2,083.41 -1,461.32 1,142.62 968.44 174.18 6.560 10,600.00 5,953.19 6,050.00 5,292.93 139.50 62.24 -36.74 -2,096.27 -1,468.16 1,132.58 956.49 176.09 6.432 10,600.00 5,953.19 6,075.00 5,313.23 139.50 62.57 -37.66 -2,109.16 -1,475.01 1,123.02 945.06 177.97 6.310 10,600.00 5,953.19 6,100.00 5,333.51 139.50 62.91 -38.60 -2,122.07 -1,481.85 1,113.95 934.15 179.80 6.196 10,615.00 5,953.29 6,000.00 5,252.27 139.74 61.56 -33.90 -2,070.58 -1,454.48 1,152.90 980.44 172.46 6.685 10,621.66 5,953.33 5,975.00 5,231.92 139.84 61.23 -32.57 -2,057.79 -1,447.63 1,163.61 992.98 170.62 6.820 10,628.33 5,953.37 5,950.00 5,211.56 139.94 60.89 -31.25 -2,045.01 -1,440.75 1,174.65 1,005.87 168.78 6.960 10,635.00 5,953.42 5,925.00 5,191.19 140.05 60.56 -29.96 -2,032.27 -1,433.86 1,186.02 1,019.09 166.93 7.105 10,650.00 5,953.52 5,825.00 5,109.59 140.28 59.22 -25.76 -1,981.60 -1,406.03 1,234.69 1,075.40 159.29 7.751 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/16/2019 1:24:15PM Page 8 COMPASS 5000.14 Build 85H ConocoPhillips Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit_2 Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 3H-01 Well Error: 0.00 usft Reference Wellbore 3H -01A Reference Design: 3H-01A_wp02 ConocoPhillips Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-01 31-1-01 @ 76.00usft (3H-01) 31-11-01 @ 76.00usft (3H-01) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Offset Design Kuparuk 3H Pad - 3H-05 - 31-1-05 - 3H-05 Survey Program: 100 -BOSS -GYRO Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Depth Depth Depth Depth from North +N! -S +E/ -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (I (usft) (usft) (usft) (usft) (usft) 10,650.00 5,953.52 5,850.00 5,130.01 140.28 59.55 -26.52 -1,994.21 -1,413.03 1,222.02 1,060.73 161.29 7.577 10,650.00 5,953.52 5,875.00 5,150.41 140.28 59.89 -27.30 -2,006.86 -1,420.00 1,209.71 1,046.43 163.27 7.409 10,650.00 5,953.52 5,900.00 5,170.81 140.28 60.22 -28.10 -2,019.55 -1,426.94 1,197.77 1,032.52 165.25 7.248 10,668.42 5,953.65 5,800.00 5,089.15 140.57 58.88 -23.74 -1,969.03 -1,399.00 1,247.43 1,089.68 157.75 7.906 10,675.11 5,953.70 5,775.00 5,068.72 140.67 58.55 -22.55 -1,956.47 -1,391.95 1,260.56 1,104.62 155.94 8.083 10,681.82 5,953.76 5,750.00 5,048.29 140.78 58.22 -21.38 -1,943.90 -1,384.91 1,273.97 1,119.81 154.15 8.264 10,700.00 5,953.90 5,650.00 4,966.65 141.06 56.89 -17.47 -1,893.48 -1,356.76 1,330.31 1,183.38 146.93 9.054 10,700.00 5,953.90 5,675.00 4,987.07 141.06 57.22 -18.11 -1,906.08 -1,363.78 1,315.79 1,166.94 148.85 8.840 10,700.00 5,953.90 5,700.00 5,007.47 141.06 57.55 -18.76 -1,918.69 -1,370.81 1,301.60 1,150.82 150.78 8.633 10,700.00 5,953.90 5,725.00 5,027.88 141.06 57.88 -19.42 -1,931.30 -1,377.86 1,287.75 1,135.04 152.71 8.432 10,715.51 5,954.02 5,625.00 4,946.21 141.31 56.55 -15.78 -1,880.90 -1,349.76 1,344.97 1,199.44 145.54 9.242 Offset Site Error: 0.00 usft Offset Well Error: 0.00 usft Warning CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/16/2019 1 24 15PM Page 9 COMPASS 5000.14 Build 85H ConocoPhillips Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 31-1-01 Well Error: 0.00 usft Reference Wellbore 31-1-01A Reference Design: 3H -01A wp02 ConocoPhillips Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-01 31-1-01 @ 76.00usft (31-1-01) 31-1-01 @ 76.00usft (31-1-01) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Offset Design Kuparuk 3H Pad - 31-1-26 - 31-1-261-1 - 31-1-261-1 Offset She Error 0.00 usft Survey Program: 121 -MWD OWSG, 6230 -MWD -INC -ONLY, 6350 -MWD OWSG Offset Well Error 0.00 usft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North -NI-S +El -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (usft) (usft) (usft( 9,600.00 5,949.06 8,750.00 5,900.76 126.91 105.43 90.51 -3,381.68 -261.32 617.15 390.14 227.01 2.719 Normal Operations 9,600.00 5,949.06 8,773.00 5,900.91 126.91 106.00 90.53 -3,403.91 -267.20 613.52 385.12 228.40 2.686 Normal Operations 9,618.69 5,949.26 8,725.00 5,900.60 127.09 104.82 89.30 -3,357.51 -254.93 621.56 395.19 226.37 2.746 Normal Operations 9,683.77 5,949.41 8,700.00 5,901.12 127.73 104.21 93.06 -3,333.41 -248.31 626.00 397.99 228.02 2.745 Normal Operations 9,789.97 5,949.05 8,675.00 5,902.44 128.86 103.61 100.66 -3,309.52 -241.07 628.18 399.07 229.11 2.742 Normal Operations 9,897.06 5,947.97 8,650.00 5,903.36 130.08 103.03 108.32 -3,285.71 -233.52 627.47 400.65 226.83 2.766 Normal Operations 10,001.85 5,946.22 8,625.00 5,903.31 131.31 102.46 115.78 -3,261.90 -225.88 623.70 402.31 221.38 2.817 Normal Operations 10,035.78 5,945.53 8,600.00 5,903.56 131.71 101.90 116.70 -3,238.34 -217.53 618.57 398.13 220.44 2.806 Normal Operations 10,050.00 5,945.26 8,575.00 5,904.17 131.89 101.37 115.76 -3,215.07 -208.41 614.56 393.30 221.27 2.777 Normal Operations 10,064.06 5,945.03 8,550.00 5,904.49 132.06 100.86 114.82 -3,192.13 -198.49 611.86 389.77 222.09 2.755 Normal Operations 10,078.36 5,944.83 8,525.00 5,904.15 132.24 100.37 113.81 -3,169.53 -187.81 610.47 387.62 222.84 2.739 Normal Operations 10,100.00 5,944.58 8,475.00 5,902.11 132.51 99.46 112.15 -3,125.10 -164.97 610.81 386.23 224.58 2.720 Normal Operations 10,100.00 5,944.58 8,500.00 5,903.09 132.51 99.91 112.21 -3,147.24 -176.53 610.30 387.29 223.01 2.737 Normal Operations 10,121.28 5,944.40 8,450.00 5,900.65 132.78 99.03 110.55 -3,103.18 -153.04 612.17 387.44 224.73 2.724 Normal Operations 10,135.47 5,944.32 8,425.00 5,898.74 132.97 98.62 109.41 -3,081.65 -140.48 614.78 389.54 225.24 2.729 Normal Operations 10,150.00 5,944.27 8,400.00 5,897.36 133.15 98.25 108.31 -3,060.73 -126.88 618.99 393.30 225.69 2.743 Normal Operations 10,163.33 5,944.25 8,375.00 5,897.38 133.33 97.91 107.43 -3,040.54 -112.14 624.82 398.63 226.18 2.762 Normal Operations 10,175.00 5,944.26 8,350.00 5,897.83 133.48 97.60 106.71 -3,020.67 -96.97 631.54 404.87 226.67 2.786 Normal Operations 10,190.66 5,944.33 8,325.00 5,897.35 133.69 97.29 105.68 -3,000.86 -81.73 638.81 411.85 226.96 2.815 Normal Operations 10,200.00 5,944.42 8,300.00 5,897.12 133.82 97.00 105.09 -2,981.41 -66.04 647.01 419.66 227.35 2.846 Normal Operations 10,217.30 5,944.69 8,275.00 5,897.27 134.05 96.73 104.01 -2,962.27 -49.95 655.99 428.44 227.55 2.883 Normal Operations 10,230.45 5,944.97 8,250.00 5,897.04 134.23 96.44 103.16 -2,942.76 -34.33 664.82 437.07 227.75 2.919 Normal Operations 10,250.00 5,945.53 8,200.00 5,894.34 134.49 95.73 101.65 -2,900.36 -8.06 678.10 450.22 227.88 2.976 Normal Operations 10,250.00 5,945.53 8,225.00 5,895.90 134.49 96.10 101.81 -2,922.04 -20.40 672.16 444.35 227.81 2.950 Normal Operations 10,270.79 5,946.30 8,175.00 5,892.73 134.78 95.32 100.15 -2,878.19 3.37 683.35 455.51 227.84 2.999 Normal Operations 10,284.29 5,946.90 8,150.00 5,891.10 134.96 94.89 99.11 -2,855.60 13.94 688.13 460.41 227.72 3.022 10,300.00 5,947.68 8,125.00 5,889.82 135.18 94.43 97.94 -2,832.54 23.51 692.19 464.63 227.56 3.042 10,311.40 5,948.32 8,100.00 5,889.01 135.34 93.94 97.08 -2,809.02 31.95 695.41 468.14 227.28 3.060 10,325.00 5,949.15 8,075.00 5,888.53 135.52 93.41 96.09 -2,785.12 39.25 697.82 470.86 226.96 3.075 10,339.69 5,950.02 8,050.00 5,888.31 135.73 92.85 95.12 -2,760.87 45.32 699.32 472.72 226.60 3.086 10,350.00 5,950.55 8,025.00 5,887.69 135.87 92.26 94.37 -2,736.27 49.69 699.52 473.51 226.01 3.095 10,369.09 5,951.36 8,000.00 5,886.70 136.14 91.62 93.09 -2,711.46 52.57 698.58 472.93 225.65 3.096 10,383.78 5,951.83 7,975.00 5,885.55 136.34 90.95 92.05 -2,686.54 54.24 696.84 471.78 225.07 3.096 10,400.00 5,952.20 7,950.00 5,884.47 136.57 90.26 90.94 -2,661.58 54.84 694.40 469.90 224.50 3.093 10,413.19 5,952.38 7,925.00 5,883.58 136.75 89.55 90.02 -2,636.60 54.45 691.34 467.59 223.75 3.090 10,454.36 5,952.53 7,900.00 5,882.60 137.33 88.83 91.23 -2,611.64 53.30 687.79 463.38 224.42 3.065 10,594.38 5,953.16 7,875.00 5,881.85 139.42 88.09 100.85 -2,586.74 51.23 680.57 453.56 227.00 2.998 Normal Operations 10,716.66 5,954.03 7,850.00 5,881.99 141.33 87.35 109.24 -2,561.86 48.81 669.24 444.58 224.66 2.979 Normal Operations 10,775.00 5,954.55 7,825.00 5,882.65 142.25 86.60 113.18 -2,537.06 45.78 654.77 432.14 222.63 2.941 Normal Operations 10,791.09 5,954.70 7,800.00 5,883.29 142.51 85.84 111.95 -2,512.36 41.95 639.42 416.57 222.85 2.869 Normal Operations 10,800.00 5,954.77 7,775.00 5,884.00 142.65 85.07 111.21 -2,487.78 37.46 623.86 400.39 223.47 2.792 Normal Operations 10,813.07 5,954.88 7,750.00 5,885.49 142.86 84.30 110.25 -2,463.45 31.91 607.63 383.82 223.81 2.715 Normal Operations 10,823.93 5,954.96 7,725.00 5,887.21 143.04 83.52 109.45 -2,439.31 25.64 591.07 366.83 224.24 2.636 Normal Operations 10,834.44 5,955.03 7,700.00 5,888.23 143.21 82.74 108.60 -2,415.60 17.83 573.66 349.08 224.58 2.554 Normal Operations 10,850.00 5,955.14 7,650.00 5,890.21 143.46 81.18 107.23 -2,369.15 -0.56 537.49 312.19 225.30 2.386 Caution Monitor Closely 10,850.00 5,955.14 7,675.00 5,889.10 143.46 81.96 107.37 -2,392.25 8.92 555.71 331.11 224.61 2.474 Caution Monitor Closely 10,865.17 5,955.22 7,625.00 5,891.15 143.72 80.41 106.00 -2,346.40 -10.88 518.85 293.55 225.30 2.303 Caution Monitor Closely 10,875.29 5,955.28 7,600.00 5,892.49 143.88 79.65 105.16 -2,323.96 -21.82 499.95 274.48 225.47 2.217 Caution Monitor Closely 10,885.29 5,955.33 7,575.00 5,893.21 144.05 78.90 104.23 -2,301.89 -33.54 480.78 255.21 225.56 2.131 Caution Monitor Closely 10,900.00 5,955.39 7,525.00 5,894.56 144.30 77.43 102.66 -2,258.65 -58.60 441.92 216.23 225.69 1.958 Caution Monitor Closely 10,900.00 5,955.39 7,550.00 5,893.69 144.30 78.16 102.92 -2,280.15 -45.87 461.43 235.96 225.47 2.047 Caution Monitor Closely 10,915.28 5,955.45 7,500.00 5,895.52 144.55 76.73 101.32 -2,237.53 -71.93 422.11 196.54 225.57 1.871 Caution Monitor Closely CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/1612019 1:24:15PM Page 10 COMPASS 5000.14 Build 85H ConocoPhillips Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 31-1-01 Well Error: 0.00 usft Reference Wellbore 3H -01A Reference Design: 3H-01A_wp02 ConocoPhillips Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-01 31-1-01 @ 76.00usft (3H-01) 3H-01 @ 76.00usft (3H-01) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Offset Design Kuparuk 3H Pad - 31-1-26 - 31-1-261-1 - 31-1-261-1 Offset Site Error: 0 00 usft Survey Program: 121 -MWD OWSG, 6230 -MWD -INC -ONLY, 6350 -MWD OWSG Offset Well Error: 0.00 usft Reference offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North +N/ -S +E/ -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (usft) (usft) (usft) 10,925.11 5,955.48 7,475.00 5,895.56 144.72 76.04 100.21 -2,21688 -86.02 402.12 176.72 225.40 1.784 Caution Monitor Closely 10,935.67 5,955.50 7,450.00 5,895.30 144.90 75.35 98.95 -2,195.84 -99.51 382.84 157.68 225.16 1.700 Caution Monitor Closely 10,950.00 5,955.53 7,425.00 5,894.55 145.14 74.67 97.33 -2,174.38 -112.31 364.41 139.61 224.79 1.621 Caution Monitor Closely 10,958.81 5,955.55 7,400.00 5,893.77 145.29 73.99 96.04 -2,152.79 -124.90 346.38 122.07 224.31 1.544 Caution Monitor Closely 10,971.60 5,955.56 7,375.00 5,894.07 145.51 73.32 94.62 -2,130.66 -136.49 329.25 105.38 223.88 1.471 Take Immediate Action 10,985.49 5,955.57 7,350.00 5,895.63 145.75 72.65 93.35 -2,107.88 -146.68 313.32 89.79 223.54 1.402 Take Immediate Action 11,000.00 5,955.57 7,325.00 5,897.32 145.99 71.98 92.06 -2,084.93 -156.43 298.07 74.93 223.14 1.336 Take Immediate Action 11,015.11 5,955.56 7,300.00 5,898.94 146.25 71.32 90.71 -2,061.77 -165.72 283.59 60.92 222.67 1.274 Take Immediate Action 11,030.92 5,955.54 7,275.00 5,900.43 146.52 70.67 89.30 -2,038.36 -174.35 270.08 47.98 222.10 1.216 Take Immediate Action 11,050.00 5,955.49 7,250.00 5,901.64 146.85 70.02 87.62 -2,014.78 -182.57 257.43 35.73 221.70 1.161 Take Immediate Action 11,064.32 5,955.45 7,225.00 5,902.60 147.09 69.38 86.23 -1,990.99 -190.20 245.76 25.20 220.57 1.114 Take Immediate Action 11,081.92 5,955.39 7,200.00 5,903.47 147.39 68.75 84.62 -1,967.02 -197.23 235.14 15.51 219.63 1.071 Take Immediate Action 11,100.00 5,955.31 7,175.00 5,904.25 147.70 68.13 82.96 -1,942.98 -204.06 225.22 6.64 218.58 1.030 Take Immediate Action 11,118.40 5,955.21 7,150.00 5,904.57 148.02 67.51 81.18 -1,918.86 -210.61 216.17 -1.12 217.30 0.995 STOP Drilling 11,145.42 5,955.04 7,125.00 5,904.74 148.48 66.91 81.66 -1,894.57 -216.51 208.00 -9.77 217.77 0.955 STOP Drilling 11,176.71 5,954.81 7,100.00 5,905.11 149.02 66.31 83.42 -1,870.00 -221.10 200.22 -18.85 219.07 0.914 STOP Drilling 11,207.78 5,954.54 7,075.00 5,906.21 149.57 65.73 85.40 -1,845.23 -224.28 192.68 -27.60 220.28 0.875 STOP Drilling 11,238.58 5,954.23 7,050.00 5,908.10 150.12 65.16 87.62 -1,820.37 -226.08 185.34 -36.15 221.49 0.837 STOP Drilling 11,269.19 5,953.88 7,025.00 5,910.19 150.68 64.60 89.94 -1,795.46 -226.49 178.36 -44.17 222.53 0.802 STOP Drilling 11,299.28 5,953.51 7,000.00 5,912.45 151.23 64.06 92.27 -1,770.57 -226.46 170.89 -52.43 223.32 0.765 STOP Drilling 11,329.06 5,953.10 6,975.00 5,915.97 151.78 63.54 95.09 -1,745.87 -224.93 163.69 -60.64 224.34 0.730 STOP Drilling 11,358.37 5,952.66 6,950.00 5,920.69 152.32 63.04 98.41 -1,721.48 -222.23 156.56 -68.94 225.51 0.694 STOP Drilling 11,387.27 5,952.20 6,924.91 5,925.98 152.86 62.55 102.02 -1,697.16 -218.98 149.10 -77.46 226.56 0.658 STOP Drilling 11,415.28 5,951.72 6,900.00 5,931.29 153.38 62.07 105.68 -1,673.02 -215.94 140.83 -86.45 227.28 0.620 STOP Drilling 11,442.46 5,951.22 6,875.00 5,936.62 153.88 61.59 109.43 -1,648.71 -213.55 131.28 -96.38 227.66 0.577 STOP Drilling 11,468.60 5,950.72 6,850.00 5,941.69 154.37 61.10 113.19 -1,624.29 -211.93 120.44 -107.23 227.66 0.529 STOP Drilling 11,493.63 5,950.22 6,825.00 5,946.21 154.84 60.61 116.92 -1,599.71 -211.11 108.35 -116.92 227.27 0.477 STOP Drilling 11,517.37 5,949.72 6,800.00 5,950.21 155.27 60.12 120.70 -1,575.04 -211.20 94.97 -131.53 226.51 0.419 STOP Drilling 11,539.80 5,949.23 6,775.00 5,953.74 155.69 59.64 124.75 -1,550.30 -212.09 60.48 -144.86 225.34 0.357 STOP Drilling 11,561.01 5,948.76 6,750.00 5,957.10 156.08 59.15 129.69 -1,525.57 -213.52 65.22 -158.25 223.47 0.292 STOP Drilling 11,581.05 5,948.29 6,725.00 5,960.86 156.45 58.68 137.20 -1,500.92 -215.29 49.70 -169.57 219.27 0.227 STOP Drilling 11,600.07 5,947.84 6,700.00 5,964.63 156.80 58.21 150.27 -1,476.29 -217.32 34.66 -171.42 206.08 0.168 STOP Drilling, CC, ES, SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/16/2019 1:24:15PM Page 11 COMPASS 5000 14 Build 85H V ConocoPhillips Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit_2 Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 31-1-01 Well Error: 0.00 usft Reference Wellbore 31-1-01A Reference Design: 3H-01A_Wp02 ConocoPhillips Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-01 31-1-01 @ 76.00usft (31-1-01) 31-1-01 @ 76.00usft (31-1-01) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Offset Design Kuparuk 3H Pad - 31-1-26 - 31-1-261-1-01 - 31-1-261-1-01 Offset She Error: 0.00 usft Survey Program: 121 -MWD OWSG, 6230 -MWD -INC -ONLY, 6350 -MWD OWSG, 6772 -MWD -INC -ONLY, 6890 -MWD OWSG Offset Well Error: 0.00 usft Reference offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North -NIS +E/ -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (') (usft) (usft) (usft) (usft) (usft) 9,513.20 5,946.20 8,890.00 5,841.52 126.09 102.33 91.59 -3,537.01 -246.88 659.85 436.25 223.60 2.951 Normal Operations 9,521.18 5,946.60 8,875.00 5,845.34 126.17 102.07 91.44 -3,524.85 -238.96 664.76 441.21 223.56 2.974 Normal Operations 9,534.33 5,947.19 8,850.00 5,851.71 126.29 101.64 91.19 -3,504.57 -225.80 673.21 449.77 223.44 3.013 9,550.00 5,947.80 8,800.00 5,864.32 126.43 100.74 91.32 -3,462.94 -201.15 689.64 467.06 222.58 3.098 9,550.00 5,947.80 8,825.00 5,858.07 126.43 101.19 90.77 -3,483.96 -213.15 681.51 458.18 223.33 3.052 9,573.59 5,948.53 8,775.00 5,870.36 126.66 100.26 90.35 -3,441.47 -189.87 697.14 474.50 222.64 3.131 9,587.00 5,948.84 8,750.00 5,875.99 126.78 99.73 89.96 -3,418.85 -180.90 702.80 480.63 222.17 3.163 9,600.00 5,949.06 8,725.00 5,881.04 126.91 99.21 89.55 -3,396.02 -172.11 708.71 487.11 221.61 3.198 9,613.28 5,949.22 8,700.00 5,885.35 127.03 98.71 89.08 -3,373.93 -161.25 717.19 496.14 221.06 3.244 9,642.42 5,949.35 8,675.00 5,888.53 127.32 98.22 89.84 -3,351.66 -150.35 726.13 504.86 221.28 3.282 9,863.88 5,948.38 8,650.00 5,890.23 129.70 97.73 105.57 -3,329.14 -139.63 731.52 507.76 223.76 3.269 10,025.00 5,945.75 8,625.00 5,891.14 131.58 97.24 117.12 -3,306.70 -128.64 730.69 513.50 217.19 3.364 10,042.26 5,945.40 8,600.00 5,891.15 131.79 96.75 115.92 -3,284.19 -117.78 728.36 510.69 217.68 3.346 10,050.00 5,945.26 8,575.00 5,891.69 131.89 96.27 115.44 -3,261.65 -106.99 726.38 507.59 218.79 3.320 10,068.64 5,944.97 8,550.00 5,893.34 132.12 95.78 114.28 -3,239.15 -96.21 724.64 505.49 219.15 3.307 10,081.85 5,944.78 8,525.00 5,895.01 132.28 95.30 113.50 -3,216.50 -85.76 722.99 503.17 219.82 3.289 10,100.00 5,944.58 8,475.00 5,899.08 132.51 94.29 112.56 -3,170.50 -66.63 719.06 497.70 221.36 3.248 10,100.00 5,944.58 8,500.00 5,897.22 132.51 94.80 112.41 -3,193.64 -75.89 721.14 500.96 220.18 3.275 10,121.50 5,944.40 8,450.00 5,900.73 132.79 93.77 111.19 -3,147.08 -58.03 716.54 495.06 221.49 3.235 10,134.76 5,944.32 8,425.00 5,901.89 132.96 93.23 110.36 -3,123.42 -50.03 713.91 491.99 221.92 3.217 10,150.00 5,944.27 8,400.00 5,902.45 133.15 92.69 109.33 -3,099.60 42.48 711.25 489.03 222.22 3.201 10,161.38 5,944.25 8,375.00 5,903.01 133.30 92.14 108.58 -3,075.69 -35.19 708.71 486.12 222.59 3.184 10,175.00 5,944.26 8,350.00 5,903.40 133.48 91.59 107.65 -3,051.71 -28.15 706.33 483.49 222.84 3.170 10,188.35 5,944.31 8,325.00 5,903.81 133.66 91.03 106.79 -3,027.57 -21.65 703.80 480.76 223.04 3.155 10,200.00 5,944.42 8,300.00 5,904.08 133.82 90.46 105.02 -3,003.29 -15.72 701.09 477.89 223.20 3.141 10,215.64 5,944.66 8,275.00 5,904.75 134.03 89.89 105.01 -2,978.95 -10.06 698.47 475.21 223.26 3.128 10,229.31 5,944.95 8,250.00 5,905.99 134.21 89.30 104.18 -2,954.53 4.85 695.77 472.47 223.30 3.116 10,250.00 5,945.53 8,200.00 5,907.89 134.49 88.09 102.85 -2,905.10 2.36 688.41 465.28 223.13 3.085 10,250.00 5,945.53 8,225.00 5,907.03 134.49 88.70 102.87 -2,929.87 -0.86 692.31 469.05 223.26 3.101 10,270.27 5,946.28 8,175.00 5,908.97 134.77 87.47 101.56 -2,880.25 4.87 684.14 461.12 223.03 3.068 10,284.01 5,946.88 8,150.00 5,910.30 134.95 86.85 100.69 -2,855.42 7.45 680.38 457.55 222.83 3.053 10,300.00 5,947.68 8,125.00 5,911.40 135.18 86.24 99.66 -2,830.62 10.40 677.42 454.80 222.62 3.043 10,311.69 5,948.34 8,100.00 5,911.56 135.34 85.63 98.82 -2,805.82 13.56 675.10 452.84 222.26 3.037 10,325.00 5,949.15 8,075.00 5,910.65 135.52 85.03 97.78 -2,781.05 16.77 673.32 451.47 221.85 3.035 10,340.31 5,950.05 8,050.00 5,909.34 135.74 84.44 96.66 -2,756.34 20.37 672.35 450.90 221.45 3.036 10,350.00 5,950.55 8,025.00 5,907.58 135.87 83.86 95.85 -2,731.72 24.30 672.17 451.39 220.77 3.045 10,369.86 5,951.39 8,000.00 5,905.61 136.15 83.29 94.44 -2,707.16 28.57 672.67 452.19 220.48 3.051 10,384.67 5,951.86 7,975.00 5,904.06 136.35 82.73 93.38 -2,682.68 33.37 674.08 454.13 219.95 3.065 10,400.00 5,952.20 7,950.00 5,903.32 136.57 82.19 92.38 -2,658.27 38.70 676.34 456.91 219.43 3.082 10,414.27 5,952.39 7,925.00 5,903.02 136.77 81.65 91.49 -2,633.87 44.16 679.07 460.23 218.83 3.103 10,464.66 5,952.57 7,900.00 5,901.92 137.48 81.10 93.53 -2,609.33 48.78 681.20 460.95 220.26 3.093 10,608.59 5,953.25 7,875.00 5,900.41 139.64 80.53 103.40 -2,584.65 52.47 679.31 456.00 223.31 3.042 10,741.96 5,954.25 7,850.00 5,899.00 141.73 79.94 112.48 -2,559.81 54.91 672.04 451.19 220.85 3.043 10,784.04 5,954.63 7,825.00 5,897.88 142.39 79.34 113.94 -2,534.88 56.34 661.26 441.31 219.95 3.006 10,800.00 5,954.77 7,775.00 5,897.12 142.65 78.13 112.55 -2,484.92 57.85 639.18 417.60 221.58 2.885 Normal Operations 10,800.00 5,954.77 7,800.00 5,897.12 142.65 78.74 112.66 -2,509.92 57.48 650.38 429.99 220.40 2.951 Normal Operations 10,821.53 5,954.94 7,750.00 5,897.86 143.00 77.50 111.01 -2,459.94 57.47 627.37 405.64 221.74 2.829 Normal Operations 10,833.66 5,955.03 7,725.00 5,897.64 143.20 76.87 110.01 -2,435.08 55.04 614.33 392.13 222.20 2.765 Normal Operations 10,850.00 5,955.14 7,675.00 5,895.05 143.46 75.55 108.30 -2,386.23 44.78 584.96 361.93 223.02 2.623 Normal Operations 10,850.00 5,955.14 7,700.00 5,896.47 143.46 76.21 108.61 -2,410.52 50.50 599.96 377.58 222.38 2.698 Normal Operations 10,868.55 5,955.24 7,650.00 5,893.59 143.77 74.90 106.69 -2,361.94 39.05 570.14 347.08 223.07 2.556 Normal Operations 10,880.83 5,955.31 7,625.00 5,892.18 143.98 74.26 105.52 -2,337.47 34.15 556.40 333.12 223.27 2.492 Caution Monitor Closely CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/16/2019 124 15PM Page 12 COMPASS 5000 14 Build 85H ConocoPhillips Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 31-1-01 Well Error: 0.00 usft Reference Wellbore 3H -01A Reference Design: 3H -01A wp02 ConocoPhillips Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-01 31-1-01 @ 76.00usft (3H-01) 3H-01 @ 76.00usft (31-1-01) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Offset Design Kuparuk 3H Pad - 31-1-26 - 31-1-261-1-01 - 31-1-261-1-01 Offset Site Error: 0.00 usft Survey Program: 121 -MWD OWSG, 6230-MWD-INC_ONLY, 6350 -MWD OWSG, 6772 -MWD -INC -ONLY, 6890 -MWD OWSG Offset Well Error: 0.00 usft Reference Offset semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North -N/-S +E1 -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (usft) (usft) (usft) 10,900.00 5,955.39 7,575.00 5,889.44 144.30 73.01 103.55 -2,288.06 27.07 532.32 308.70 223.62 2.380 Caution Monitor Closely 10,900.00 5,955.39 7,600.00 5,890.59 144.30 73.63 103.84 -2,312.84 30.16 543.84 320.52 223.32 2.435 Caution Monitor Closely 10,920.75 5,955.46 7,550.00 5,888.45 144.65 72.41 101.83 -2,263.21 24.53 521.54 297.87 223.67 2.332 Caution Monitor Closely 10,934.77 5,955.50 7,525.00 5,887.67 144.88 71.82 100.60 -2,238.33 22.21 511.40 287.68 223.72 2.286 Caution Monitor Closely 10,950.00 5,955.53 7,500.00 5,888.00 145.14 71.23 99.41 -2,213.44 19.92 501.53 277.75 223.76 2.241 Caution Monitor Closely 10,963.36 5,955.55 7,475.00 5,888.87 145.37 70.64 98.40 -2,188.61 17.12 491.50 267.71 223.78 2.196 Caution Monitor Closely 10,977.56 5,955.57 7,450.00 5,889.70 145.61 70.05 97.32 -2,163.98 12.94 480.62 256.90 223.72 2.148 Caution Monitor Closely 11,000.00 5,955.57 7,400.00 5,891.78 145.99 68.88 95.56 -2,115.61 0.54 456.35 233.22 223.13 2.045 Caution Monitor Closely 11,000.00 5,955.57 7,425.00 5,890.60 145.99 69.46 95.65 -2,139.64 7.32 468.93 245.07 223.86 2.095 Caution Monitor Closely 11,019.01 5,955.55 7,375.00 5,892.58 146.32 68.30 94.07 -2,092.18 -8.11 442.55 219.43 223.12 1.983 Caution Monitor Closely 11,031.98 5,955.53 7,350.00 5,892.53 146.54 67.74 92.85 -2,069.63 -18.89 427.39 204.68 222.71 1.919 Caution Monitor Closely 11,050.00 5,955.49 7,300.00 5,891.60 146.85 66.70 90.71 -2,026.72 -44.49 394.75 173.80 220.94 1.787 Caution Monitor Closely 11,050.00 5,955.49 7,325.00 5,891.97 146.85 67.21 91.16 -2,047.86 -31.15 411.40 188.82 222.58 1.848 Caution Monitor Closely 11,069.41 5,955.43 7,275.00 5,891.97 147.18 66.20 88.97 -2,005.87 -58.28 377.74 156.76 220.98 1.709 Caution Monitor Closely 11,081.88 5,955.39 7,250.00 5,891.73 147.39 65.73 87.57 -1,985.46 -72.71 360.68 140.46 220.23 1.638 Caution Monitor Closely 11,100.00 5,955.31 7,225.00 5,891.78 147.70 65.27 85.77 -1,965.33 -87.53 343.59 123.51 220.08 1.561 Caution Monitor Closely 11,107.53 5,955.27 7,200.00 5,892.74 147.83 64.83 84.83 -1,945.14 -102.24 326.58 107.99 218.59 1.494 Take Immediate Action 11,121.31 5,955.19 7,175.00 5,894.20 148.07 64.39 83.54 -1,924.53 -116.32 310.42 92.67 217.74 1.426 Take Immediate Action 11,147.34 5,955.03 7,150.00 5,894.73 148.51 63.96 84.33 -1,903.68 -130.09 294.78 76.15 218.63 1.348 Take Immediate Action 11,177.05 5,954.81 7,125.00 5,895.27 149.03 63.53 85.86 -1,882.21 -142.89 279.36 59.45 219.91 1.270 Take Immediate Action 11,205.72 5,954.56 7,100.00 5,895.59 149.53 63.12 87.20 -1,860.41 -155.11 263.86 43.08 220.77 1.195 Take Immediate Action 11,233.81 5,954.28 7,075.00 5,896.19 150.04 62.70 88.51 -1,838.08 -166.33 248.52 27.17 221.35 1.123 Take Immediate Action 11,261.78 5,953.97 7,050.00 5,897.34 150.54 62.29 89.69 -1,815.10 -176.10 233.64 11.89 221.75 1.054 Take Immediate Action 11,289.51 5,953.63 7,025.00 5,898.61 151.05 61.88 91.25 -1,791.61 -184.53 219.21 -2.67 221.89 0.988 STOP Drilling 11,317.70 5,953.26 7,000.00 5,901.20 151.57 61.48 93.04 -1,767.49 -190.52 205.62 -16.36 222.18 0.926 STOP Drilling 11,345.64 5,952.85 6,975.00 5,904.96 152.08 61.09 95.18 -1,743.17 -194.90 192.81 -29.79 222.60 0.866 STOP Drilling 11,372.66 5,952.43 6,950.00 5,910.08 152.58 60.70 97.72 -1,718.98 -198.54 179.47 -43.75 223.22 0.804 STOP Drilling 11,398.41 5,952.01 6,925.00 5,916.34 153.06 60.34 100.62 -1,695.02 -202.01 165.46 -58.53 223.99 0.739 STOP Drilling 11,423.26 5,951.57 6,900.00 5,923.25 153.53 59.98 103.89 -1,671.19 -204.99 151.24 -73.60 224.84 0.673 STOP Drilling 11,447.96 5,951.12 6,875.00 5,930.33 153.99 59.70 107.58 -1,647.27 -206.66 137.63 -86.49 224.12 0.614 STOP Drilling 11,471.91 5,950.66 6,850.00 5,937.28 154.43 59.56 111.57 -1,623.30 -208.12 123.79 -99.62 223.41 0.554 STOP Drilling 11,495.15 5,950.19 6,825.00 5,943.87 154.86 59.53 115.86 -1,599.22 -209.47 109.69 -114.06 223.75 0.490 STOP Drilling 11,517.77 5,949.71 6,800.00 5,949.50 155.28 59.52 120.31 -1,574.90 -210.78 95.28 -128.26 223.54 0.426 STOP Drilling 11,539.81 5,949.23 6,775.00 5,953.73 155.69 59.51 124.74 -1,550.30 -212.08 80.49 -142.20 222.68 0.361 STOP Drilling 11,561.01 5,948.76 6,750.00 5,957.10 156.08 59.15 129.69 -1,525.57 -213.52 65.22 -158.25 223.47 0.292 STOP Drilling 11,581.05 5,948.29 6,725.00 5,960.86 156.45 58.68 137.20 -1,500.92 -215.29 49.70 -169.57 219.27 0.227 STOP Drilling 11,600.07 5,947.84 6,700.00 5,964.63 156.80 58.21 150.27 -1,476.29 -217.32 34.66 -171.42 206.08 0.168 STOP Drilling, CC, ES, SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/16/2019 1:24:15PM Page 13 COMPASS 5000 14 Build 85H ConocoPhillips Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 3H-01 Well Error: 0.00 usft Reference Wellbore 3H -01A Reference Design: 3H -01A wp02 ConocoPhillips Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-01 3H-01 @ 76.00usft (31-1-01) 3H-01 @ 76.00usft (31-1-01) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Offset Design Kuparuk 3H Pad - 31-1-26 - 31-1-261-1-02 - 3H-261-1-02 Offset Site Error: 0.00 usft Survey Program: 121 -MWD OWSG, 6230 -MWD -INC -ONLY, 6350 -MWD OWSG, 6772 -MWD -INC -ONLY, 6890 -MWD OWSG, 7408 -MWD -INC -ONLY, 7471 -MWD OWSG Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North +N1 -s +E1 -W Centres Ellipses Separation Factor (usft) (usft) (usft) lush) (usft) (usft) (') (usft) (usft) (usft) (usft) (usft) 10,950.00 5,955.53 7,525.00 5,883.18 145.14 70.06 99.60 -2,216.72 67.79 548.45 323.99 224.46 2.443 Caution Monitor Closely 10,950.00 5,955.53 7,550.00 5,886.25 145.14 70.30 100.24 -2,229.20 89.20 571.93 347.16 224.77 2.544 Normal Operations 10,950.00 5,955.53 7,575.00 5,889.28 145.14 70.49 100.84 -2,237.96 112.40 596.12 371.10 225.02 2.649 Normal Operations 10,950.00 5,955.53 7,600.00 5,891.15 145.14 70.62 101.28 -2,243.97 136.57 620.61 395.44 225.18 2.756 Normal Operations 10,950.00 5,955.53 7,625.00 5,893.21 145.14 70.69 101.70 -2,245.91 161.36 644.55 419.26 225.30 2.861 Normal Operations 10,950.00 5,955.53 7,650.00 5,895.37 145.14 70.69 102.08 -2,243.52 186.14 667.32 441.98 225.35 2.961 Normal Operations 10,961.69 5,955.55 7,500.00 5,881.03 145.34 69.78 98.20 -2,200.89 48.60 525.97 301.64 224.33 2.345 Caution Monitor Closely 10,968.29 5,955.56 7,675.00 5,896.96 145.45 70.59 101.11 -2,237.01 210.19 688.11 462.42 225.70 3.049 10,969.85 5,955.56 7,475.00 5,881.25 145.48 69.45 97.30 -2,182.20 32.07 505.02 280.82 224.20 2.253 Caution Monitor Closely 10,977.29 5,955.57 7,700.00 5,897.80 145.61 70.42 100.68 -2,226.17 232.64 706.55 480.76 225.79 3.129 10,980.08 5,955.57 7,450.00 5,884.76 145.65 69.12 96.65 -2,161.44 18.65 486.12 264.93 221.19 2.198 Caution Monitor Closely 10,987.99 5,955.57 7,725.00 5,898.26 145.79 70.19 100.07 -2,210.89 252.40 721.47 495.61 225.86 3.194 11,000.00 5,955.57 7,400.00 5,891.78 145.99 68.86 95.56 -2,115.61 0.54 456.35 233.22 223.13 2.045 Caution Monitor Closely 11,000.00 5,955.57 7,425.00 5,889.72 145.99 69.00 95.56 -2,139.28 8.26 469.86 248.70 221.16 2.125 Caution Monitor Closely 11,000.00 5,955.57 7,750.00 5,898.03 145.99 69.93 99.30 -2,193.85 270.68 734.86 508.96 225.90 3.253 11,000.00 5,955.57 7,775.00 5,898.17 145.99 69.67 99.40 -2,176.23 288.41 747.97 522.48 225.49 3.317 11,019.01 5,955.55 7,375.00 5,892.58 146.32 66.30 94.07 -2,092.18 -8.11 442.55 219.43 223.12 1.983 Caution Monitor Closely 11,021.50 5,955.55 7,800.00 5,898.13 146.36 69.40 97.98 -2,158.53 306.07 761.01 535.21 225.80 3.370 11,031.98 5,955.53 7,350.00 5,892.53 146.54 67.74 92.85 -2,069.63 -18.89 427.39 204.68 222.71 1.919 Caution Monitor Closely 11,032.33 5,955.53 7,825.00 5,897.96 146.55 69.15 97.29 -2,140.98 323.88 774.67 548.96 225.71 3.432 11,050.00 5,955.49 7,300.00 5,891.60 146.85 66.70 90.71 -2,026.72 -44.49 394.75 173.80 220.94 1.787 Caution Monitor Closely 11,050.00 5,955.49 7,325.00 5,891.97 146.85 67.21 91.16 -2,047.86 -31.15 411.40 188.82 222.58 1.848 Caution Monitor Closely 11,050.00 5,955.49 7,850.00 5,897.77 146.85 68.91 96.12 -2,123.71 341.95 788.97 563.07 225.89 3.493 11,050.00 5,955.49 7,875.00 5,897.51 146.85 68.68 96.19 -2,106.79 360.35 803.82 578.51 225.30 3.568 11,062.88 5,955.46 7,900.00 5,897.30 147.07 68.45 95.36 -2,090.33 379.17 819.42 594.14 225.28 3.637 11,069.41 5,955.43 7,275.00 5,891.97 147.18 66.20 88.97 -2,005.87 -58.28 377.74 156.76 220.98 1.709 Caution Monitor Closely 11,072.68 5,955.42 7,925.00 5,897.00 147.24 68.23 94.74 -2,073.45 397.60 834.84 609.75 225.09 3.709 11,081.88 5,955.39 7,250.00 5,891.73 147.39 65.73 87.57 -1,985.46 -72.71 360.68 140.46 220.23 1.638 Caution Monitor Closely 11,082.62 5,955.38 7,950.00 5,896.81 147.41 68.00 94.11 -2,055.81 415.32 849.66 624.79 224.86 3.779 11,100.00 5,955.31 7,225.00 5,891.78 147.70 65.27 85.77 -1,965.33 -87.53 343.59 123.51 220.08 1.561 Caution Monitor Closely 11,100.00 5,955.31 7,975.00 5,896.99 147.70 67.75 92.97 -2,037.30 432.11 863.72 638.71 225.00 3.839 11,100.00 5,955.31 8,000.00 5,897.37 147.70 67.50 93.06 -2,017.74 447.66 876.56 652.44 224.12 3.911 11,107.53 5,955.27 7,200.00 5,892.74 147.83 64.83 84.83 -1,945.14 -102.24 326.58 107.99 218.59 1.494 Take Immediate Action 11,113.69 5,955.24 8,025.00 5,897.23 147.94 67.24 92.15 -1,997.39 462.18 888.63 664.66 223.97 3.968 11,121.31 5,955.19 7,175.00 5,894.20 148.07 64.39 83.54 -1,924.53 -116.32 310.42 92.67 217.74 1.426 Take Immediate Action 11,147.34 5,955.03 7,150.00 5,894.73 148.51 63.96 84.33 -1,903.68 -130.09 294.78 76.15 216.63 1.348 Take Immediate Action 11,177.05 5,954.81 7,125.00 5,895.27 149.03 63.53 85.86 -1,882.21 -142.89 279.36 59.45 219.91 1.270 Take Immediate Action 11,205.72 5,954.56 7,100.00 5,895.59 149.53 63.12 87.20 -1,860.41 -155.11 263.86 43.08 220.77 1.195 Take Immediate Action 11,233.81 5,954.28 7,075.00 5,896.19 150.04 62.70 88.51 -1,838.08 -166.33 248.52 27.17 221.35 1.123 Take Immediate Action 11,261.78 5,953.97 7,050.00 5,897.34 150.54 62.29 89.89 -1,815.10 -176.10 233.64 11.89 221.75 1.054 Take Immediate Action 11,289.51 5,953.63 7,025.00 5,898.61 151.05 61.88 91.25 -1,791.61 -184.53 219.21 -2.67 221.89 0.988 STOP Drilling 11,317.70 5,953.26 7,000.00 5,901.20 151.57 61.48 93.04 -1,767.49 -190.52 205.82 -16.36 222.18 0.926 STOP Drilling 11,345.64 5,952.85 6,975.00 5,904.96 152.08 61.09 95.18 -1,743.17 -194.90 192.81 -29.79 222.60 0.866 STOP Drilling 11,372.66 5,952.43 6,950.00 5,910.08 152.58 60.70 97.72 -1,718.98 -198.54 179.47 -43.75 223.22 0.804 STOP Drilling 11,398.41 5,952.01 6,925.00 5,916.34 153.06 60.34 100.62 -1,695.02 -202.01 165.46 -58.53 223.99 0.739 STOP Drilling 11,423.26 5,951.57 6,900.00 5,923.25 153.53 59.98 103.89 -1,671.19 -204.99 151.24 -73.60 224.84 0.673 STOP Drilling 11,447.96 5,951.12 6,875.00 5,930.33 153.99 59.70 107.58 -1,647.27 -206.66 137.63 -86.49 224.12 0.614 STOP Drilling 11,471.91 5,950.66 6,850.00 5,937.28 154.43 59.56 111.57 -1,623.30 -208.12 123.79 -99.62 223.41 0.554 STOP Drilling 11,495.15 5,950.19 6,825.00 5,943.87 154.86 59.53 115.86 -1,599.22 -209.47 109.69 -114.06 223.75 0.490 STOP Drilling 11,517.77 5,949.71 6,800.00 5,949.50 155.28 59.52 120.31 -1,574.90 -210.78 95.28 -128.26 223.54 0.426 STOP Drilling 11,539.81 5,949.23 6,775.00 5,953.73 155.69 59.51 124.74 -1,550.30 -212.08 80.49 -142.20 222.68 0.361 STOP Drilling 11,561.01 5,948.76 6,750.00 5,957.10 156.08 59.15 129.69 -1,525.57 -213.52 65.22 -158.25 223.47 0.292 STOP Drilling CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/16/2019 1:24:15PM Page 14 COMPASS 5000 14 Build 85H ConocoPhillips Company: Project: Reference Site: Site Error: Reference Well: Well Error: Reference Wellbore Reference Design: ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit _2 Kuparuk 3H Pad 0.00 usft 3H-01 0.00 usft 3H -01A 3H-01A_wp02 ConocoPhillips Anticollision Report Local Co-ordinate Reference ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-01 31-1-01 @ 76.00usft (31-1-01) 31-1-01 @ 76.00usft (31-1-01) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Offset Design Kuparuk 3H Pad - 31-1-26 - 31-1-261-1-02 - 31-1-261-1-02 Offset Site Error: 0.00 usft Survey Program: 121 -MWD OWSG, 6230-MWD-INC—ONLY, 6350 -MWD OWSG, 6772-MWD-INC—ONLY, 6890 -MWD OWSG, 7408-MWD-INC—ONLY, 7471 -MWD OWSG Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Warning Depth Depth Depth Depth from North -NI-S +EI -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (I (usft) (usft) (usft) (usft) (usft) 11,581.05 5,948.29 6,725.00 5,960.86 156.45 58.68 137.20 -1,500.92 -215.29 49.70 -169.57 219.27 0.227 STOP Drilling 11,600.07 5,947.84 6,700.00 5,964.63 156.80 58.21 150.27 -1,476.29 -217.32 34.66 -171.42 206.08 0.168 STOP Drilling, CC, ES, SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/1612019 1:24:15PM Page 15 COMPASS 5000.14 Build 85H Rixse, Melvin G (CED) From: Hayes, lames C <James.C.Hayes@conocophillips.com> Sent: Thursday, November 21, 2019 6:09 AM To: Rixse, Melvin G (CED) Subject: RE: [EXTERNAL]RE: PTD219-158 KRU 3H -01A Anticollision Report Missing Yes this does fall below the COP anti -collision guidelines however we have a dispensation in place because the well at risk 3H-26 1-01 & 02 were drilled in the C - sand. There is enough known geologic structure that separates these two sands, B -sand, that we are able to de -risk this well for anti -collision. Same is applied while drilling the L1 because we will be tracking the first drilled lateral, but we have enough geologic separation to keep us from colliding. Thanks, James Hayes C: +1918.914.9609 From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Wednesday, November 20, 2019 12:31 PM To: Hayes, James C <James.C.Hayes@conocophillips.com> Subject: RE: [EXTERNAL]RE: PTD219-158 KRU 3H -01A Anticollision Report Missing James, I see 'STOP Drilling' flags on your anti -collision reports. How does CPAI justify drilling these directional plans? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin. Rixse(@alaska.gov). From: Hayes, James C <James.C.Hayes@conocophillips.com> Sent: Monday, November 18, 2019 6:22 AM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL]RE: PTD219-158 KRU 3H -01A Anticollision Report Missing Mel, Attached are the two ACR's that you requested. As for H2S you can see the information below for our most recent H2S readings: Max Well Reading Date Max Level on Pad (Well) Max Reading (Pad) Date 200 ppm 5/2119 3H-02 260 ppm 6/26/19 Thanks, James Hayes C: +1918.914.9609 From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Friday, November 15, 2019 3:03 PM To: Hayes, James C <James.C.Hayes@conocophillips.com> Subject: [EXTERNAL]RE: PTD219-158 KRU 3H -01A Anticollision Report Missing James, Any H2S on 3H pad? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin. Rixse@a laska.gov). TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: 'z' /V— Development l— Development Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: K;a C POOL: 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 ( PIT) and API number (50--- 50-- _) from records, data and logs acquired for well -___) name on permit). 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: b% Well Logging Requirements 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. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 _ Well Name: KUPARUK RIV UNIT 31-1-01_A ___Program DEV Well bore seg ❑ PTD#: 2191580 Company ConocoPhillips Alaska Inc. Initial Class/Type DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 11 Permit fee attached_ NA Appr Date SFD 11/13/2019 Engineering Appr Date MGR 11/15/2019 Geology Appr Date SFD 11/13/2019 2 Lease number appropriate- - - - - - - - -- - - - - - - - - - .. - - Yes - - _ - Surf Loc &_TD lie in ADL0025-531; Top productive_ interval lies_ in ADL0025547._ 3 Unique well -name and number - - - - - - - - - - Yes Surface casing -protects all -known- USDWs - -- 4 Well located in -a- defined_pool- - - - - - - - - - - - - - - - - - - _ - Yes Kuparuk River Oil_ Pool, governed by Conservation Order No. 432D 5 Well located proper distance- from drilling unit -boundary_ - _ _ - - Yes CO 432D Rule 3: There shall be no restrictions as to well spacing except that no pay shall be opened in_ - - - 6 Well located proper distance from other wells_ _ Yes a well closer_ than 500 feet to an external property -line where ownership or landownership changes- - - - - - - 7 Sufficient acreage available in -drilling unit_ Yes As planned, well conforms with -spacing _requirements - - - - - - - - - - - - - ---------------- -- 8 If deviated, is wellbore plat -included - Yes 23 9 Operator only affected party_ - - _ Yes - - - - - - - - - - - 10 Operator has -appropriate_ bond in force Yes - - - - - _Yes 11 Permit can be issued without conservation order_ Yes If_a_re-drill, has_a 1.07403 for abandonment been approved 12 Permit_can be issued -without administrative_approval - - - - - - - - - Yes - - - - - - 13 Can permit beapproved before 15 -day wait- - - - - - - - - - - - - Yes _ . - _ _ - - - _ - - - - - - - - - - - - - - - - - - - 14 Well located within area and_strata authorized by Injection Order # (put 10# in_comments)_ (For_ NA_ N_A_ - - - 15 All wells within 1/4 a _mile area of review identified (For service well only) - - - NA_ - Drilling fluid program schematic-&- equip list adequate_ - - - - - - 16 Pre -produced injector: duration of pre production Less than 3 months_ (For -service well only) - NA_ - - - - - - - - - - - - - - - - - - - - - - _ _ - - - - - - - - - 17 Nonconven.ga_sconforms-to AS31,05.030(j.1_.A),(j.2.A-D) - - - - - - - - - _ - - - NA_ - - - _ _ _ I - - _ _ - _ - - - - - - - - - - - - - - -- - - - 18 Conductor string -provided - - - - - _ _ _NA_ - - - CTD sidetrack from existing wellbore._ All drilling will be in the reservoir._ 19 Surface casing -protects all -known- USDWs - -- _ _ NA_ CTD sidetrack from existing wellbore._ All drilling will be in the_reservoir._ - - - - 20 CMT vol. adequate -to circulate -on conductor & surf csg .. - - NA- CTD sidetrack from existing wellbore. _ All drilling will be in the reservoir. - 21 CMT vol adequate to tie-in long string to surf csg_ - - - - - - - - - - - - - - - NA. CTD sidetrack from existing wellbore._ All drilling will be in the_ reservoir.- - 22 _C_MT will coverall -known-productive horizons No CTD sidetrack_ from_ existing wellbore. All drilling will be in the_ reservoir._ Slotted- liner will_ be -run - - - - - - 23 Casing designs adequate for C,_T, B &_ permafr_ost_ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage_or reserve pit - - - - - - _Yes CDR3 is ongoing operations. _Previous ops demonstrate good truck support and adequate tankage. _ 25 If_a_re-drill, has_a 1.07403 for abandonment been approved Yes - - - - - Sundry 319-499 - _ _ - - 26 Adequate wellbore separation -proposed _ _ _ - - Yes 27 If_diverter required, does it meet_ regulations_ - - - - - - - - - - N_A_ - - - - - - - CTD sidetrack from existing wellbore. - AII_ drilling will be in the_ reservoir.- 28 Drilling fluid program schematic-&- equip list adequate_ - - - - - - Yes 29 BOPEs,.do they _meet regulation - - - - - - - - - - - - - Yes 30 BOPE_press rating appropriate; test to -(put psig in comments)_ - - - - - - - Yes - - - - - - 31 Choke manifold complies w/API_ RP -53 (May 84)- - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - _ - - . 32 Work will occur without operation shutdown_ - - - - - - - - - Yes CDR3 is ongoing operations - 33 Is presence_ of H2S gas_ probable - - - _ - N_o_ 34 Mechanical.condition of wells within AOR verified (For_ service well only) - - - - - - _ _ _ _ NA . ... This is a development well. - - - - - - - - 35 Permit can be issued w/o hydrogen_ sulfide measures- - - - - - - - - - - - - - - - - - - - - - - - No- - - - . 31 -1 -Pad wells are_H_2S-bearing._H2S_measures are required. - - _ - - - - - - - - - _ _ _ _ - _ . . - _ - - - - - - 36 Data presented on potential overpressure zones - - - - - - - - - - - - - - - - - - - - Yes Max. potential -res. pressure is 11.7 ppg EMW; expected -res. pressure is 8.8 ppg EMW_. Well will be - 37 Seismic_ analysis_ of shallow gas_zones- - NA_ drilled using 8.6_ ppg mud,_a coiled -tubing rig, and -managed -pressure drilling technique -to control_ 38 Seabed condition survey -(if off -shore) - - - - - - - - - - - - - - - - - - - - - - - - N.A formation pressures and stabilize shale sections withconstantBHP of about -11.8 ppg EMW. - 39 Contact-name/phone for weekly_ progress reports [exploratory only] - - - - - - - - - - - - - - NA_ Geologic Engineering Public Commissioner: Date: Commissioner: Date C mi ne Date Lxc
