Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
219-032
Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 S-105A 219032 500292297701 10 9/19/2023 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Squeeze in Zone 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ Permit to Drill Number: 219-032 3. Address: P.O. Box 196612 Anchorage, (AP11 AK 99519-6612 Stratigraphic ❑ Service❑ Number: 50-029-22977-01-00 7 Property Designation (Lease Number): ADL 028257 8. Well Name and Number: PBU S -105A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, AURORA OIL 11, Present Well Condition Summary:REei; ' 4 tiF' ig a y Total Depth: measured 10559 feet Plugs 9 measured 8500 feet Novtrue vertical 6876 feet Junk measured 6722, 10540 feet osj s� 201 Effective Depth: measured 8500 feet Packer measured 7593 feet true vertical 6821 feet Packer true vertical 6726 feetA/'{;9 �pCollapse: I`!- Casing: Length: Size: MD: TVD: Burst: Structural Conductor 79 20" 28 - 107 28-107 1490 470 Surface 2968 9-5/8" 28-2996 28-2833 5750 3090 Intermediate 7626 7" 26-7652 26-6779 7240 5410 Production Liner 2950 2-3/8" 7599-10559 6731-6876 11200 11780 Perforation Depth: Measured depth: 7656- 10170 feet True vertical depth: 6782-6852 feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# L-80 24-7631 24-6760 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Penn Packer 7593 6726 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Squeeze in Zone: 7595 - 7652' Frac Stage 1: 8220' - 8500', Frac Stage 2: 7656- 7686' Treatment descriptions including volumes used and final pressure: Squeeze in Zone: 40 Bible Cement, tbg = 3000psi Frac: See Attached 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -MCF Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 224 236 120 1084 217 Subsequent t0 operation: Shut -In 14.Attachments:(required per 20 PAC 25070.25.071,825.283) 15. Well Class after work: Daily Report of Well Operations 0 ` Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ C) Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-292 Authorized Name: Lastufka, Joseph N Contact Name: Wages, David Authorized Title:42M Sped Contact Email: David.Wages@bp.com Authorized Signature. Date: l J`�I� Contact Phone: 907.564.5669 Fgrm 404 RevjseC =oX/gl� �IBDMS.( NCV 0 8 2019 Submit Original Only ***WELL S/I ON ARRIVAL*** (frac) SWCP 4517 RIG UP 9/30/2019 ***CONTINUE WSR ON 10/01/2019*** ***CONTINUE WSR FROM 09/30/2019*** (frac) RAN, 2'x 1.875" STEM, 1.5" S BAILER, UNABLE TO PASS 3072' SLM (paraffin) RAN 2-7/8" BRUSH 2.0"GAUGE RING, UNABLE TO PASS 3080' SLM RAN 1.77" GAUGE RING, UNABLE TO PASS 3124' SLM RAN 1.50" GAUGE RING, CUT PARAFFIN FROM 3124' SLM TO 3150' SLM, RAN CLEAN TO 4050' SLM RAN 1.77" GAUGE RING, CUT PARAFFIN FROM 3124' SLM TO 3375' SLM, RAN CLEAN TO 4050' SLM RAN 2.00" GAUGE RING, CUT PARAFFIN FROM 3124' SLM TO 3375' SLM, RAN CLEAN TO 4050' SLM RAN 2.50" GAUGE RING, 2 7/8" BRUSH, CUT PARAFFIN FROM 3124' SLM TO 3375' SLM, RAN CLEAN TO 4050' SLM RAN 2.73" GAUGE RING, 3 1/2" BRUSH TO DEPLOYMENT SLEEVE @ 7,599' MD WHILE LRS PUMPED HOT DIESEL SET 3 1/2" WHIDDON CATCHER @ 7,599' MD ***CONTINUE WSR ON 10/02/2019*** 10/1/2019 T/1/0=130/120/175 Temp=S/I (LRS Unit 42- Assist Slickline w/ B&F/Fracturing) Pumped 5 bbls 50/50 and 96 bbls of 180* diesel down TBG to assist Slickline with B&F. Capped off 10/1/2019 B&F with 8 bbls of crude so SL could pull out of hole. ** Job continued on 10/2/2019 ** ***CONTINUE WSR FROM 10/01/2019*** (frac) PULLED RK-OGLV FROM ST#2 @ 6,631' MD PULLED RK-LGLV FROM ST#3 @ 4,129' MD SET RK-DGLV IN ST#3 @ 4,129' MD LRS LOADED IA W/ 130 BBLS OF SEAWATER & 70 BBLS OF DIESEL MADE TWO ATTEMPTS TO SET STA#2 RK DGLV (unable to locate) RAN 3-1/2" BRUSH, 2.73" GAUGE RING, BRUSHED STA #2 @ 6631 MD SET RK-DGLV IN ST#2 @ 6,631' MD PULLED EMPTY CATCHER FROM 7,599 MD ***CONTINUE WSR ON 10/03/2019*** 10/2/2019 ** Job continued from 10/1/19 WSR ** (LRS Unit 42 Assist Slickline: Load and Test/Fracturing) Load IA w/ 5 bbls 50/50 meth and 130 bbls Inhibited 1% KCI down IA followed by 2 bbls 50/50 meth spacer and 70 bbls diesel for freeze protect. . 10/2/2019 Load Tubing w/ 3 bbls 50/50 meth spear and 58 bbls Inhibited 1% KCI Daily Report of Well Operations PBU S -105A ***CONTINUE WSR FROM 10/02/2019*** (frac) SET LTTP IN DEPLOYMENT SLV @7599' MD (Irs unable to pressure up above 1500 psi) PULLED LTTP FROM DEPLOYMENT SLV @7599' MD SET LTTP IN DEPLOYMENT SLVE @ 7599' MD (unable to pressure up against Ittp) PULLED LTTP FROM DEPLOYMENT SLV @7599' MD RAN 2.50"LIB TO DEPLOYMENT SLV @7599' MD (clean impression of top of deployment sleeve) RAN 2'x1.875 DRIFT AND SAMPLE BAILER TO DEVIATION @ 7798' SLM RAN 3 1/2" X LINE & XX PLUG TO X NIP @ 7,537' SLM (7,568' MD) FOR CORRECTION RAN 3.80" CENTRALIZER TO XO @ 69' MD FOR TREE SAVER 10/3/2019 ***CONTINUE WSR ON 10/04/2019*** 1 ** Job continued from 10/2/2019 WSR** (LRS Unit 42 - Assist Slickline: Load and Test) Continue to load tubing w/ 42 bbls of Inhibited 1 % KCI. (Total of 100 bbls). followed by 3 bbls 50/50 meth sprear and 25 bbls Diesel Freeze Protect Pumped 17 bbls of crude down TBG to try a pressure on test plug. unable to hold pressure SL pulled plug and re set it. Pressured up IA with .9 bbls dsl to verify valves are holding. Plug reset- pumped 6 bbls crude down TBG and got LLR of .6 bpm @ 1450 psi. Pumped an additional 34 bbls crude down TBG to establish LLR of 5 bpm @ 2550 psi. Re established LLR of .6 bpm @ 1500 psi with 5 bbls crude. 10/3/2019 **Job continued on 10/04/19 WSR** **Job continued from 10/03/2019 WSR** (LRS Unit 42 -Assist Slickline W/ MIT -T / MIT -IA) MIT -T Passed @ 4445 psi. Max applied 4500 psi. Target Pressure 4000 psi. Pressured up TBG to 4470 psi with .81 bbls diesel. 1st 15 min TBG lost 18 psi. 2nd 15 min TBG lost 7 psi for a total loss of 25 psi in 30 min. MIT -IA Passed @ 3654 psi. Max applied 3750 psi. Target pressure 3500 psi. Pressured up IA to 3747 psi with 3.2 bbls diesel. 1 st 15 min IA lost 75 psi. 2nd 15 min IA lost 18 psi for a total loss of 93 psi in 30 min. TBG pressure gained 12 psi from start of test then stabalized and lost 11 psi in final 15 min of test. Started 2nd test to verify TBG stabalization. TBG lost 8 psi in 10 min from start of test, verifying 1 st test is pass per FB WSL. Bled IA to 200 psi and TBG to 800 psi and recovered — 4 bbls. Slickline set Composite Bridge plug in 2-3/8 LNR, pumped 75 bbls diesel down TBG to get SRT as follows: 1 bpm @ 1640 psi / 2 bpm @ 1850 psi / 3 bpm @ 2090 psi / 5 bpm @ 2560 psi. Freeze protected F/L with 5 bbls 50/50 meth. RDMO while SL in control of. 10/4/2019 FWHP's 300/66/182 ***CONTINUE WSR FROM 10/03/2019*** (frac) SET 3 1/2" EVOTRIEVE @ 7,583' MD LRS PERFORMED PASSING MITT AND MIT -IA PULLED EVO TRIEVE FROM 7583' MD SET BAKER CBP (magnum plug) @ 7649'MD LRS PERFORMED INJECTIVITY TEST ON LINER LAP & FREEZE PROTECTED 10/4/2019 FLOWLINE CTU#8 1.5" CT. Job Scope: Frac Support Standby waiting on Slickline & Well Support to finish. 10/4/2019 ***Continued on 10/5/19*** CTU#8 1.5" CT. Job Scope: Frac Support Unit standby. MIRU. Function test BOPS. Make up cementing BHA. RIH. 10/5/2019 ***Job Continued on 10/6/19*** Daily Report of Well Operations PBU S-105A T/I/O = 500/200/450. Remove Crown Valve (Temp #97 not needed) pre Coil RU. ***Job Complete*** Final T/I/O = 500/200/450. 10/6/2019 WV = C. T = RU for Coil. SSV = C. IA, OA = OTG. 18:00 CTU#8 1.5" CT. Job Scope: Frac Support RIH with cementing BHA. Tag CBP and correct depth. PUH to 7550 and begin to down squeeze cement. Pump 40 bbls of cement. Push 20 bbls behind pipe in attempt to achieve a bump. Whip built to 1900psi but would immediately fall when off the pump. Lay in remaining 20 bbls of cement. Puh to safety and begin Hesitation Sqz. Work up to a Final Sqz Pressure of 3000psi. Hold Final Sqz Pressure for 45 mins. Lost 119psi in 45 mins. Slowly bleed down to - 500psi, drop 5/8" ball and contaminate/cleanout cement down to CBP. Chase ooh at 80%. Jet jewelry on way ooh. At surface. Jet BOP'S & tree. Freeze Protect Coil. Wait on compressive strength. Begin weekly BOP test. 10/6/2019 ***Job Continued on 10/7/19*** CTU#8 1.5" CT. Job Scope: Frac Support Complete Weekly BOP Test. Wait on Compressive Strength. Pressure Test Tbg (Liner Lap) to 4500psi (see log for results). APE says okay to proceed. MU & RIH w/ Baker 1.69" Milling Assy w/ 1.75" Junk Mill. Tag CBP at 7642'. Mill and push CBP to 10540CTM. Dry drift liner, POOH. Make up 1.69" GR/CCL. 10/7/2019 ***Job Continued on 10/8/19*** CTU#8 1.5" CT. Job Scope: Frac Support Rih w/ HES GR/CCL Tools. Log from 10475' to 7200'. Flagged pipe at 8500'. Pooh. Receive good data ( + 3.5' Correction). Correlate to Baker Hughes Multiple Propagation Resistivity Log 21-April-2019. MU & RIH w/ Baker 2-3/8" CBP. Pre plug Injection at 0.22bpm @ - 1800psi. Correct depth at flag. Set top of CIBP at 8500'. Pooh. Post plug injection at 0.25bpm @ - 2200psi. Freeze Protect Tbg w/ 23 bbls 60/40 Methanol. Rig Down CTU. Lay down Mast. Turn over to Frac Crew. 10/8/2019 ***Job Continued on 10/9/19*** LRS Unit 70 - Assist Frac Job: Heat Diesel). Heat diesel tanker to 90*F ***WSR continued 10/8/2019 on 10-09-18*** Job Scope: Rig up for Frac and set Tree Saver Rig up complete and tree saver set. 10/8/2019 ***Continue on 10/9/19 WSR*** (LRS Unit 46 - Assist Frac: Heat Freshwater Tanks) Heated frac Tank #49161 to 100*F Started heating Frac Tank # 48261 (See log for details) 10/8/2019 *** WSR continued on 10/09/19*** ** WSR continued from 10/08/19*** (LRS Unit 46 - Assist Frac Crew: Heat Tanks, Hold IA Pressure) Heated Frac Tanks #48261, 2383, 41963 to 100* F (see log for details). Maintained 2500 psi on IA with 4.1 bbls of Diesel. During Frac (SEE LOG FOR DETAILS). Bled IA to 100 psi. Frac-Crew in control of well upon LRS departure. 10/9/2019 FWHP's= SSV/100/-5. 10/9/2019 LRS Unit 70 Assisted Frac: Heated 250 bbl diesel tanker to 90* Daily Report of Well Operations PBU S-105A ***SLB Frac Crew*** Job Scope: Frac Stage 1 of 2 targeting Kuparuk C sands. Spot support equipment and remainder of frac equipment. PJSM. Pressure tested IA to 3500 psi. Pressure tested treating line to 7500 psi. Pump data frac per the following schedule: Injection Test stage 31 bbls 28# WF128 linear gel, 0.5PPA Scour/Data Frac stage 100 bbls of 20/40 river sand in 28# YF128FIexD cross-link gel, Displacements stage 70 bbls WF128. Perform Hard Shut Down, monitor pressures. ISIP = 1635 psi, Frac gradient = 0.58. Pump Frac Stage 1 of 2 as follows: PAD stage 50 bbls YF128FIexD, 0.5PPA Scour stage 200 bbl of 20/40 River Sand, PAD stage 50 bbls YF128FIexD, 1 PPA FLAT stage 100 bbls of 16/20 Carbolite, 1 PPA - 8PPA RAMP stage 400 bbls of 16/20 CarboLite, 8PPA FLAT stage 100 bbls of 16/20 CarboBond Lite, Displacement stage 20 bbls YF128FIexD, Flush stage 19 bbls WF128, Freeze Protect stage 28 bbls. Dropped rate gradually while on Flush and FP from 20 bpm - 1 bpm to try and induce a screenout. SD 5 bbls shy of full flush and allowed frac to close. Were able to get fracture to packoff to 6200 psi after 2 x 20 minute hesitations. Pumped 3 bbls to achieve packoff. Underflushed frac by 2 bbls. Total proppant behind pipe = 104,085 lbs. Rig down standing iron and Tree-Saver. Hand well over to CT to prep for Stage 2. 10/9/2019 ***Job Complete*** CTU#8 1.5" CT. Job Scope: Frac Support Standy for Frac Stimulation #1. RIH with reverse FCO BHA. 10/9/2019 ***Job Continued on 10/10/19*** CTU#8 1.5" CT. Job Scope: Frac Support RIH with reverse FCO BHA. Tag top of sand at 7759CTM. PUH to 7725 and pump large gel sweep. Sand plug pressure tested to 3000 psi. POOH. Pump 1# drift ball at surface. Trim 1' coil. MU & RIH w/ 30'x 1.56" Halliburton Millenium guns. Perforate 7656'- 7686'. Pump 21.8 bbls 60/40 down backside. Shots fired and confirm ball recovered. Rig CTU back. 10/10/2019 ***Continued on 10/11/19*** Job Scope: Rig up Tree Saver RU Tree-Saver and Frac stand pipe. 10/10/2019 ***Continued on 10/11/19 WSR*** T/I/0=700/0/-5 Temp= SI (LRS Unit 46 - Assist Frac: Heat Diesel, Hold IA Pressure) Heated diesel tanker to 85*. Assist Frac by holding 2500 psi on IA while Fracing down Tbg. Pumped a total of 2.38 bbls diesel into IA to maintain 2500 psi on IA. Frac still on well at LRS departure. / **Fluid packed tags hung on IAVNVV** / **AFE sign in place on arrival** 10/11/2019 FWHP= frac/100/0 CTU#8 1.5" CT. Job Scope: Frac Support Continue standby for second stage of frac. Rig frac down, Lay tree saver down. RU coil for reverse FCO. RIH with BDJSN. Tagged top of sand at 7257. Reversed down to 7674 and could not make additional hole. Tried forward circulating and still would notjet off. POOH 10/1112019 for DJN. Daily Report of Well Operations PBU S -105A ***SLB Frac Crew*** Job Scope: Frac Stage 2 of 2 targeting Kuparuk C sands. Spot support equipment and remainder of frac equipment. PJSM. LRS pressure tested IA lines to 3550 psi. SLB pressure test treating line to 7500 psi. Pump Frac Stage 2 of 2 as follows: PAD stage 50 bbls YF128FIexD (cross-link gel), 0.5PPA Scour stage 200 bbls of 20/40 river sand, PAD stage 50 bbls YF128FlexD, 1 PPA FLAT Stage 100 bbls of 16/20 CarboLite, 1 PPA - 8PPA RAMP Stage 400 bbls of 16/20 CarboLite, 8PPA FLAT Stage 50 bbls of 16/20 CarboBond Lite (CBL), 9PPA FLAT Stage of 16/20 CBL, 10PPA FLAT Stage of 16/20 CBL. Dropped rate gradually from 20 bpm to 1 bpm once all proppant was clear of surface to try and induce a screenout. SD with 8 bbls shy of full flush and allowed fracture to close for 20 minutes. Were able to get fracture to pakoff to 6050 psi after one hesitation. Undertlushed frac by 7 bbls. 109,779 lbs of proppant behind pipe. Rig down frac equipment and Tree -Saver. Hand well over to CT to cleanout well. 10/11/2019 ***Job Complete*** Daily Report of Well Operations PBU S -105A CTU#8 1.5" CT. Job Scope: Frac Support Continue out of hole for DJN. Resume clean out with DJN. Cleaned out to CBP at 8508CTM, maintaining 80% returns. POOH for motor and mill. MU BOT tempress + milling bha 1.81" 3 bladed junk mill. RIH. Detained at 8449', able to get free and come back up further inside 2-3/8" liner to 7745'. Detained at —7745'. Came online with N2 down the coil, could not establish returns to surface. Load out mutual solvent. 10/12/2019 ***Job Continued on 10/13/19*** CTU#8 1.5" CT. Job Scope: Frac Support Detained at —7745'. Pump 25bbl of nitrified mutual solvent and 25bbl of non -nitrified mutual solvent. Allow to soak and still no movement. Pump Hot KCL to warm wellbore up. Resume pumping N2 at various rates. Follow with more KCl. Surge coil pressure. Attempt to lift with N2 at 1000scfm, wide open to tanks. No returns seen. 10/13/2019 ***Job Continued on 10/14/19*** CTU#8 1.5" CT. Job Scope: Frac Support Continue to attempt N2 lift at 1000scfm, wide open to tanks. No returns seen. Begin a series of alternating surging the coil followed by surging the backside. Pressure up coil, then pressure up WHP, while holding coil pressure constant dump WHIP. Use this methodology with coil in a static compression, neutral or tension. Only moving coil after WHP/circ pressure bled to minimize coil life stress. Pump in sufficient FP into well to 2500'60/40 (see log for details). 10/14/2019 ***Job Continued on 10/15/19*** CTU#8 1.5" CT. Job Scope: Frac Support Continue to prep for hot tap and chem cut. 10/15/2019 ***In Progress*** CTU#8 1.5" CT. Job Scope: Frac Support Continue to prep for hot tap and chem cut. Perform well kill and no flow test. Standby while Eline rigs up. Standby for winds. 10/16/2019 ***Job Continued on 10/17/19*** ***SLB COIL TUBING STABBED ON WELL ON ARRVAL***(tubing cut) SPOT IN HES LOGGING UNIT AND CRANE. CHECK OUT SLB TOOLS ON ARRIVAL. STANDBY ON WIND. 10/16/2019 ***JOB IN PROGRESS, CONT ON 10/17/19 WSR*** ***CONT FROM 10/16/2019 WSR*** STANDBY FOR WINDS 10/17/2019 ***CONT ON 10/18/2019 WSR*** CTU#8 1.5" CT. Job Scope: Frac Support Standby for winds. Verify injection down coil. Injection rate unchanged. FP in coil down to —1778'. 10/17/2019 ...Continued on WSR 10-18-19.... CTU#8 1.5" CT. Job Scope: Frac Support Standby for winds. Review procedure and review free point calculation. Confirm coil fluid level and FP in coil now down to down to —2091'. ...continued on WSR 10-19-19... 10/18/2019 ***JOB CONT FROM 10/17/2019 WSR***(cut coil) WEATHER STANDBY 10/18/2019 ***JOB CONT ON 10/19/19 WSR*** Daily Report of Well Operations PBU S -105A ***CONT FROM 10/18/19 WSR*** PERFORM HOT TAP CUT COIL, DRESS UP COIL STUB AND INSTALL TIW VALVE. PT SLB COIL BOP AND ELINE LUBRICATOR. 10/19/2019 ***CONT ON 10/20/19 WSR***(cut coil in progress) CTU#8 1.5" CT. Job Scope: Frac Support Standby for winds. Perform free point and the model predicts that we are detained near the BHA. L&K coil with 66bbl of 9.3ppg and 13.2bbl 60/40. Perform flow checks to ensure coil is dead. Hot Tap and Cut coiled tubing. Rig up HES wireline for chemical cut. 10/19/2019 ...Continued on WSR 10-20-19... CTU#8 1.5" CT. Job Scope: Frac Support RIH with HES E -line for chemical cut. E -line tagged and 7570' ELMD but were able to make it to 7870' before deviating out. Pumped tool down to CTC and then picked 5' and cut. When eline bumped up at surface it was discovered the weak point was compromised downhole/the toolstring was left in hole at cut depth of 7923' ELM. Decision made to dummy drift with 1" wt bars to 6800' to ensure cut #2 depth is clear. Drift went well. MU/RIH with chemical cutter #2. Cut at 6700' and POOH. Circulate 9.3 ppg brine down coil and up tubing. Perform flow check and rig E -line off well. Pick up injector and make up double cold roll connector to coil stub. 10/20/2019 ...Continue on WSR 10-21-19... ***CONT FROM 10/19/19 WSR***(cut coil) CUT 1.5" COIL TUBING 5' ABOVE COIL BHA AT 7,923' ELMD WITH 1" CHEMICAL CUTTER. ATTEMPT TO PULL FREE AFTER CUT, CANNOT PULL TS FREE. PULLED OUT OF ROPE SOCKET, TOOLSTRING LEFT IN HOLE. RIH WITH 1" X 23' DRIFT TO 6,800' INSIDE OF COIL, CUT 1.5" COIL AT 6,700' WITH 1" CHEMICAL CUTTER. STANDBY FOR COIL TO ATTEMPT TO PULL CUT COIL FREE. ***CONT ON 10/21/19 WSR*** ***E -LINE TS FISH LEFT INSIDE COIL. TOP OF CHEMICAL CUTTER TOOLSTRING FISH 10/20/2019 AT 7,891' ELMD. OAL = 31'3", MAX OD: 1", TOOL WEIGHT: 158#, FN: 15/16".*** CTU#8 1.5" CT. Job Scope: Frac Support Strip down injector and make up lubricator. Open BOP rams and begin POOH. FP Coil and lay in FP of well with 60/40 Methanol. ...Job complete.... ***Left in hole: 1250' of 1.5" 0.109WT (1.28" ID) + —5' coil stub connected to BOT milling BHA: Kendle ctc 1.5"x 0.32'+DBPV 1.70"x 1.51'+ Gforce bi-di jar 1.69"x 5.69'(open) + TJ disconnect (1/2"ball) 1.69"x 1.34'+ Dual circ sub (3/8"ball) 1.69"x 0.93'+ Tempress screen sub 1.69"x 1.52'+ Tempress hydropulll 1.69"x1.52'+ mud motor 1.69"x 7.64'+ 3 bladed junk mill 1.81"x 0.84' OAL: 21.31' MAX OD: 1.81". There is a 1" chemical cutter bha wedged at 10/21/2019 *** ***CONT FROM 10/20/19 WSR***(cut coil) RELEASED FROM CUT COIL JOB. RIG DOWN PCE. 10/21/2019 ***COIL CUT COMPLETE*** T/I/0= 60/512/49 (Pressure up on TBG) Pumped 7 bbls 60/40 meth to pressure up TBG in attempt to free up BHA. 10/31/2019 ****Job continued 11/01/19 Daily Report of Well Operations PBU S -105A (Pressure up TBG) **Job continued from 10/31/19**** Pumped 14 bbls of 60/40 meth to try and move BI -As. Pumped steady at .15 bbls per min at between 3600-3900 psi. FWHP's 11/1/2019 150/416/49 ***WELL S/I ON ARRIVAL*** (Frac) SET 3-1/2" SLIP STOP CATCHER SUB @ 6650' SLM. PULLED RK-DGLV FROM ST#2 @ 6631' MD. PULLED RK-DGLV FROM ST#3 @ 4129' MD. SET RK-LGLV IN ST#3 @ 4129' MD. CONFIRMED ST#3 GLV W/ 1.70" LIB (latch impression). SET RK-OGLV IN ST#2 @ 6631' MD. PULLED 3-1/2" SLIP STOP CATCHER SUB @ 6650' SLM (empty). RAN BARBELL 2.50" LIB TO 6724' SLM (inconclusive, light impression of debris). RAN 10' OF 2.25" PUMP BAILER TO 6724' SLM-EMPTY RAN 2.5" LIB ON DECENT TO 6724' SLM (impression of coil). 11/1/2019 ***JOB CONTINUED ON 02-NOV-2019*** ***JOB CONTINUED FROM 01-NOV-2019*** (Frac) PLANTED BOWEN OVERSHOT ASSEMBLY ON COIL STUB @ 6724' SLIM (6722' slm top of 3-1/2" G -FN). JARRED ON OVERSHOT ASSEMBLY W/ 13'x 1-7/8" STEM FOR 1.5 HRS (no movement). ***JOB COMPLETE ON 02-NOV-2019*** ***LIH 2.66" O.D. MODIFIED SCOOP GUIDE, 1-1/2" BOWEN BASKET OVERSHOT, 3-1/2" FLOW THROUGH BAIT SUB (oal — 37") @ 6722' SLM TOP OF G -FN*** 1112/2019 CTU#8 1.75" CT. Job Scope: Fish coil MIRU. BOP test. MU & RIH w/ 2-1/8" Baker Hiptripper and 3" hydraulic GS. Tag fish at 6727' CTM. Latch up to coil fish with no issues. Straight pull to 49K with no movement. Circulate well to 9.8 ppg brine. Run hip tripper for —2 hrs, fish did not move. 11/7/2019 ***Job continued on 11/8/19 WSR*** CTU#8 1.75" CT. Job Scope: Fish coil Continue hiptripping. No fish movement. Unlatch and POOH while pumping pipe displacement down the backside with 60/40. MU & RIH w/ accelerator, weight bar, jars, 3" hydraulic GS. Tag fish at 6728.9' CTM. Hit 50 jar licks, no fish movement. Max pull at surface was 45-46k which is max pull for the jars (25k over). After jar licks, straight pull to 49k (max limit of 1.5" coil fish). POOH while pumping pipe displacement down the backside with 60/40. Cut 50' of pipe. Note distance from brass to MV=21' (paint yellow flag). MU & RIH w/ accelerator, weight bar, jars, 3" hydraulic GS. Perform 50 jar licks, no movement. POOH pumping pipe disp with 60/40 for FP cap (20bbl). Trim 130' pipe. MU & RIH w/ accelerator, 2.13" hiptripper, and 3" hydraulic GS. Tag fish at 6730' CTM. Run hip tripper. 11/8/2019 ***Job continued on 11/9/19 WSR*** CTU#8 1.75" CT. Job Scope: Fish coil Continue hiptripping. Run hiptripper for approximately 4 hours, no fish movement. Circulate well to slick 1% KCL and pump 60/40 freeze protect. RDMO. 11/9/2019 ***Complete*** LRS Test Unit 6, Assist CT/ Post Frac Flowback/ Well Test/ Rate Verification. Inlet well S- 105, Outlet well S-103. Current barriers IL- Swab, SSV/OL - Swab/SSV. Begin WSR 11/9/2019 11/09/19, Move Unit, Rig Up, Continue Rig Up/ Cont WSR on 11/10/19. Daily Report of Well Operations PBU S-105A LRS Test Unit 6, Assist CT/ Post Frac Flowback/ Well Test/ Rate Verification. Inlet well S- 105. Outlet well S-103. Current barriers IL- Swab, SSV/OL - Swab/SSV. Continue from WSR 11/09/19/ Continue Rig Up, PT, Pop well. SI/stackout and re-popped well (4 times total) 11/10/2019 Continue trouble shooting well to induce flow, Continue to flow, Cont WSR on 11/11/19. LRS Test Unit 6, Assist CT/ Post Frac Flowback/ Well Test/ Rate Verification. Inlet well S- 105, Outlet well S-103. Current barriers IL- Hardline, vessel /OL - Swab/SSV. Continue from 11/11/2019 WSR 11/10/19/ Continue to flow, Cont WSR on 11/12/19. LRS Test Unit 6, Assist CT/ Post Frac Flowback/ Well Test/ Rate Verification. Inlet well S- 105, Outlet well S-103. Current barriers IL- Hardline, vessel /OL - Swab/SSV. Continue from WSR 11/11/19/ Continue to flow, Perform 12 HR Welltest ,Cont to flow, Cont WSR on 11/12/2019 11/13/19, LRS Test Unit 6, Assist CT/ Post Frac Flowback/ Well Test/ Rate Verification. Inlet well S- 105, Outlet well S-103. Current barriers IL- Hardline, vessel /OL - Swab/SSV. Continue from 11/13/2019 JWSR 11/12/19. Perform 12 HR Welltest, flow, blowdown, RD. Job complete, End WSR. N d E E ° U 2-o. 0 0 0 0 0 0 0 E_+° y o 0 0 0 0 0 0 0 Lo E UE 0 O 00 0 0 0 0 0 .% LL O o O O O o 0 m 0) U O O O O O O O g c c a v v v v v v v v o°« o 0 o e o a o 0 EG �+ > N Oo o O o O O o £ a m E 0 o 0 0 0 0 0 0 0 0 0 0 0 .x "I.° Q1 0Q >, o 0 0 0 0 0 0 0 0 0 0 �cCCav v v v v v v v O ._ e L U 3 N N 0 A v 0, L) 3 3 3 3 3 3 3 3 V m 0— O O O O O O O O N N'_N#mm m a N m m m m L Q U d aai (D d (D aa) d C z N N N (q N 0 J J J J J J J J cR 0 N D� �Q �� co Da Da Da Da 0 ° ° d ° d w N 10 N Cl? N C9 y V% N V! N Vl N (9N C° ON O N O N O N O N O N O N O N Zc Zc Zc z z Crn -0 (D ad aaci C C C a} O C C N O C C N O C C N O C C N O C C CoO C (a 0 = C N O a3 a3 a3 a3 a3 a3 a3 a3 c E O<n E °(n E 90 E.9 E E 00 E E O 0 OU�w CO 0 60 W 0 C. U UdU) U� 0D(U) U.0U) U.fl(O U� E C Y L O m co O w O(O Y (O N -T r O eq V N _Na O m N uri (00 �Q rLO rm co ao m o a m 0 m NO m v of CL N m N O Q ° O N M (00 a Ol m L O O N 7 4 Q Q m LL Y N O °a '_a z "O CLw O -° (tea (a p 0 m a a Q m Q U U _3 LL Q7 Q1 N 01 77 N C Ci >> +.-. of E a >> w >, m ° d o) - p E) rn E) rn C 0 in `° E a. m z E ... _ U f- V °� U R .�. m d a`) d CD a) a) d a) 0 `o 7 rn "' N .o a 9 E m .0 1] d z z c c a E 2 � > > > > E > > J a LL V R O Q y R O 0 O rn o v v v v v v v Rf LL ci a a7 J a > C (/% (i (n (n (n (n (n (n 0 E o a u N c 7 U z j a) m •R > LL m 'S U z N (D 0 N rD W ~ 04 N N O = S C/) (D to 2 2 of '° N C d E E 0 U o o o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 a 0 o 0 0 0 0 0 0 0 0 0 0 ++ G a E C r• 0 O O O V o O (O N V CO N V (o co a) m O) N O V V V M N M n 0 I� n n O O N M (O to 7 N A 3� 0 O O I- O O ((7 I- V M O I- O O � O O W tO M N N E •.a G U. E O O O N W N O O O N O O O O O O O O O 0 0 0 0 0 0 m T O O O 00 O O O O O O O O O O O O O O 6 6 0 tm L) i X Cd ce V V v 1` N U C x o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 �+ O O) E c ++ > O O O (o O (O 1 7 00 N N V 7 co M M LO (D 00 (O to V O (O N W V W N O N 7 a1 _ O O O 1 M 00 00 V O V O Ln d' IT O 0) V 1- tO r E a C a E O O O O O O M co Cl? r N V cr 7 M V Cl) M 00 O I� O r- O LO O N O V O V O N O O O mQ (D a m IM O O O (o O O O 0 0 0 O O O O O O O O O c c v v v m - 0.- e m o 0 o k 2 E Z N N N m q W O O O (o N 1 V' NO) LO � A m m 0 0)4) O V ob r N OCD � M 0 L O O WM(O W r `O- Uay N N N U) Oco NI�co m 0)O M O O M 1� VZ N QNV ) I` M r O N N M M M CO r J J J U Q ti) O) (O CO O N M CO r C E a V) X m N J m O 0 Z a cl o(D -0 ca z'EC ,Un -' m o y N N N U Z c -0 X V O NO NON E OC co0:2 -"OO O Im Z 0 Z -0 () Z -O 0 c O E a) E >a>) N cO (� O 3m 0 E d aL —a) IOD CN«�N D.. U) U U O CN a a) L- 'EX O EE E N 0.ca U) O U) £O a N NU) a)O O ET000TN O U O NmN ❑❑ a) O ❑o L�❑ L O d) LO G UO O N O E O J U) u-0U 0.0 U) 0.0 C4U7❑ WQ Q N UNW QU)❑U)- W U) a m O a 2 0 Q c m U m O co 0 ? CO U) a m a) O) Zn O d 0 N N E E E E Q J m U) U) t tt c U) U) U 0 d E m z 0 V m co � Mo U- N C L O Ed _ N m 0 U ca E o m E J Q N U �noo J - m 3 C J O c 2O -o O O Co a+ r LO V N N N r - O O L a) 'in O O O O O O O O O O O O O Un C Ep LL d E O 0 O o O 0 O a O 0 O 0 O 0 O O O o O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O o y m LLcn E LL N Im V= O O O O O O O O O O O O O O c E U 9 O O O J U c U O U > o @ a o J g o. °c o �� c ^o o e e o o e o 0 0 0 0 0 o e o 0 0 ++ E a1 E C 'w > N r- T N I� (D Cl) N V CO N m W N O r- O N m N c0 m M m cn ce) )O O m (O M N L N N r C 7 N _+ R m O I� O <Y O M N O O O O O O N O O O O O E 0 ca E O o 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O O O O O O O O O O c o a)a y 0C>,0 000 0 00 0 00 000 0 o O 0 o 000 0 0 0 0 n M C C �— C G �� n n N O J.0' - U•°� N N c .L. o w y E o n Q o L o o E N °c RudUoN ^o o m E o) u `4 ° co o uvi O m r v m y w e 0 3 N a M )O I (0CD 0) co v o co o o cD N o Q N n Q O r m (6 �i O Lo CO CN Itv O 0) N_a U O V N c0 N r O U) a `) Z O N m m Cl) co O W )O i0 co v 7 co r- V 3 O .- N d m 1- `- N m n CN LO N t- V V r N m a (� a) E U U (D T W N O u 0 "0 a) m cc U 4 a 0 - .a) E U O L a N c a) w a) N N a) O Qc a..) U O U O a) O p y0 O0. n E -O N "' fn O c a O J U E a1 Y D m L U m U o _m E m E _ o of E N o Z p o >��a oJD c ma c N N YN O O DN a m 1. J Ci U U a w�0 .� C n0 E (u Z- C N N J C c C L m cc CO m w U 3 O.c U 'J O a) a U J c N mu C cm O :E z T m= O j .N. 0 a) N J N O , r .V .0 c U) c C O N a O N O a) l0 c O E cc �L N 016-6 a) O N E? J E C o a) .-� co N y ,O co 3 o o U 7 z' L� v) !� n"2 �i ' O � N o a L) C) Q ��_ �$ c m � dc ac) O U .L.. O O O E o- Q 'D c N m.5 J CO m a)O N O d a N a) 6 O r E O' C N Q_ (a m O m N N (D .L-. N o w rna E p c a N N N a 0 m a) c O M c O - N a) m -? no —.N=0) as E9 U Jrn C J c O 60 C E o >` X a co c N U a) O E E m aM (DQaa �N _D O. N N� Co a U .L- c — Q a D m n' x a' U) >, J c c Co. d a) E m O O O E .E C L N U O N a N fa O E a) a) U L c E N o EcQa) �U u g It a)�aQ mU E _o F- > m f -E as C O U' Z c a..` nN= a c Z` a) O Q' a) E 2 O O ca cO D- c N a E ca a1 E > c F n C >-T , O ca 0 0 O 0 a) Y _O Q- F- 0. O U aO m N Co t. Q min °-O) F V) m V I- O O O N O Q Z Z r- co N N Z 00 E 0 a) Y 0 E CL E E 0 U 0 > N m U 7 6 C m m N E _� O > LL ro c f 0 m rn c LL 7 N m C 7 x N E :2 m o Z V LL IIIL,6-6r—iw NN Ca V c O co CO 00 m W a` c N N S a) E E 0 U C + O O N 7 r LD coo N x N E �LL m moSa c O co c N N E a) ca E E ma m O U Q 2C C _ 0 c o U Ufl 3k O .aEiN2EC eo m UQ�ZU M � N I� J X_ w 2 T ca a� m O. m C U Q C O N N C N (0 m O a a m Q U Z Q N a a E E U C5 d O O E m Z N NN M N U) 0 0 0 0 0 0 0 0 m m a) m CD m Q) m Q m m m m aai m ami W aai J J J J J J J J V O (D O (O m Q C (E) O C O O N C Q 5 O W N« O O n m m Q a <n U C7 U¢ E E E E E E E E E ami ami aa) ami (D ami (D ami m C U C U C U C O C O C U 1 10 C C O 10 C O N O O r U) ^ N N O O N O U) LL '° O (D N (O N O (p V M M r r O N M O O N (D V w O N V V N 00 O r r- D) M O M W O N0 O r O r O N O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O N (D (O V OJ (O W M t0 m i0 V 00 O I� O N 7 M M coW d' O V O (D .-- M N V V V M co N O M V M M O O O O O O O O O O O O O O O O O O O O O O O O O O O OO N N O O O CO 7 N (D M OJ D] (fl O O V 0D ^ N O (fl M M V M a (D a a)O N O W � N N M o) co (^D 06 T M N O � O O O M O V O O (0 n Mr n W N M M J J (D O (D r- M O N M (o0p � M a E (D L C C G\' O O O N m Z E >. v� o a =o m Q o o a r Co V Z c L OU 7 L _� 9 O w a m d E Z E a >. a) a3 L U L a5 U a3 OL ¢ O O 7 E o m o 2 d Oc 3 C C E L a ~ a L a U o U U U x �. O (D N _ ao �. N -Q N Co E a Ol E E o md) a as o a E� E c E a m a`) m D s E° aa) m° o° a cs a L o m o a L a N �= 5 O a W m o� N i OU N U) 9 a ¢ 0 a a U W (n 0 U) W U a� m m Q a 0 d E co w c O (ND Lw0 N N N N c ❑ _ N m � � N p1 N N p � L O N 1] Q N N p E � 3 > m w Mo y mE 0 Sop c o N N W � E � oa 30 oa c 'm -Fu E oQ L O j y N > N C n c 5 c y D a m `m o �p N O L N 3 2 0 3 0 p V a am yCY np v ap_' 'TOD NLL y w d L U 0 y N M > a 00 d O O U Q ?E`o a pEm yy C O CU yE u O a E d c�5o 'cr E U pC N y p Op a C p C E N0.0 M N N o y Q E >'-M o c a`�od LL c m mm � c d « Z (WD O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O N (D N W O N r- N O) O D) (D M M N W O O O W (O N M N O f- V M N O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O v (D cs � (OM(O (D M O W Or CO V N OW NN r W M M� O (D r OW f- N CO W = OONuM77 M( M W (D V O CO r 7 V N L C N E U U O > T l6 = U d E U E p L 'N L Q @ U _ U .N O N15 O O. Ol OJ L -C N . (6 C O E M (0 U p O (0 N E O E C O E N U~ O U U Z) Z '._. L (O .N O_ 2i N O d U Q N c ❑ _ N m � � N p1 N N p � L O N 1] Q N N p E � 3 > m w Mo y mE 0 Sop c o N N W � E � oa 30 oa c 'm -Fu E oQ L O j y N > N C n c 5 c y D a m `m o �p N O L N 3 2 0 3 0 p V a am yCY np v ap_' 'TOD NLL y w d L U 0 y N M > a 00 d O O U Q ?E`o a pEm yy C O CU yE u O a E d c�5o 'cr E U pC N y p Op a C p C E N0.0 M N N o y Q E >'-M o c a`�od LL c m mm � c d « Z WELLHEAD = 11' - 5m fnc Ultra SH Gen 5 ACTUATOR= SAFETY NOTES: W ELL ANGLE> -70'a 7815'. OKB. ELEV = 65.08' BF. ELEV = 37.91' KOP= 1500' Max Angle = 101-§8258' Datum M] = 7637' Datum TVD = 6700' SS 4-1/2' TBG, 12.6#, L-80, .01522 bpf, D = 3.958' TOP OF 3-12' TAG_ D = 2 992' 95/8, TOP OF CHEMICAL CUTCOIL- 1.5' 0.109 WALL THICKNESS. -1255' OF COIL LEFT DH (1020119) Minimum ID = 1.995" @ 7605- 2-7/8w X 2-3/6" XO TOP OF 2-3/8' LNR 7699' 312- TBG, 92#, L -80 -EVE, 8RD, .0087 bpf. D = 2.992' TAG 17- CSG, 26#, L-60-13TC, MOD, D = 6.276- E -UNE 1' CHEM CUTTER LEFT DH, INSIDE 1.5' . OAL = 3124'. FN =15/16' (1020/1 9) 1 7631' 1 LNR 4-7#, L-80 HYD511, 10559' opf, ID = 1.995' PERFORATION SUMMARY I ND SAFETY NOTES: W ELL ANGLE> -70'a 7815'. REF LOG: BHI MWD LOG ON 0421/19 I VLVLATCH ANGLE ATTOP PERF: 28' @ 7656' NoE:Referb Pmdwfion DBforhiiorimI rfdata SIZE SPF INTERVAL OWSqz I DATE 1.56' 6 7656-7686 O 10/10/19 1.56' 6 8220-8950 O/C 0425/19 1.56' 6 9875-10170 C 0425/19 LNR 4-7#, L-80 HYD511, 10559' opf, ID = 1.995' I 994' I 14-12' X 3-12' XO. D = 2.992' 1 3-12' HES X NP, D = 2.750' 1 2.66' OD MODIFIED SCOOP GUIDE, 1 -1/2 - NEN BASKETOS, 3-12' FLO-THRU BAIT 1. DAL =-37' (11/02/19) r -Ac / iFTununaci s ST MD I ND SAFETY NOTES: W ELL ANGLE> -70'a 7815'. S-1 I VLVLATCH 095A MAX DLS: 29' dt 7665' 3 I 994' I 14-12' X 3-12' XO. D = 2.992' 1 3-12' HES X NP, D = 2.750' 1 2.66' OD MODIFIED SCOOP GUIDE, 1 -1/2 - NEN BASKETOS, 3-12' FLO-THRU BAIT 1. DAL =-37' (11/02/19) r -Ac / iFTununaci s ST MD I ND I DEVI TYPE I VLVLATCH PORT DATE 3 4129 3775 32 CAM -MMM DOME RK 16 11/01111 2 6631 5877 29 CAMadMM 1 SO RK I 22 11/01/1! h 7475 6620 27 CAMa.1MM Do Y RK 0 0311311, 75931,7 X 4-72' BAKER 5 3 PKR w /XO PUPS tp 3112, D = 3.875' 7697 — 4-12• X 3-12• XO, D = 2.992- 7699' 2.70" DEPLOY SLV, D = 2.250' 1312' HES X NP. ID = 2.750' 7620' ELMO TT NOT AVALABLE MLLOUT WINDOW (S -106A) 7652' - 7655' ICTMILLING BHA I CBP 10540' 1-i FISH: MILLED 2-3/8' CBP AURORA UNIT WELL: S -105A PERMIT No: 219-032 API No: 50-029-22977-01 SEC 35, T12N, R12, DATE REV BY COMMENTS DATE REV BY COMMENTS 11/10/00 ORIGINAL COMPLETION 77/07/19 MH/JMD SET MAGNUM CBP(I 01=19) 0427119 N-CDR2 CTDST(S405A) 77/07/19 JTC/JMD ADPERFS(10110/79) 05/09/19 JNL/JMD ADDED OKB & BF 11/07/19 BTTUJMD EL CHEM CUTTER LEFT 1020/79) 05/30/19 RC/JMD FINAL ODE APPROVAL 11/07/79 JPKIJMD GLV C/O (11/07119) 77/07/19 MH/JMD SET MAGNUM CBP 10/04/79 11/07119 LLG/JMD SCOOP GUIDE&OVERSHOT 11/02/19) BP Exploration (Alaska) 11/07/19 BTNIJMD FISH: MILLED CBP (10/07/19 DATA SUBMITTAL COMPLIANCE REPORT 8/19/2019 Permit to Drill 2190320 Well Name/No. PRUDHOE BAY UN AURO S -105A Operator BP Exploration (Alaska) Inc. API No. 50-029-22977-01-00 MD 10559 TVD 6876 Completion Date 4/27/2019 Completion Status 1-0IL Current Status 1 -OIL UIC No REQUIRED INFORMATION / Mud Log No ✓ Samples No v-1, Directional Survey Yes DATA INFORMATION List of Logs Obtained: MWD / GR / RES (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 31079 Digital Data 7207 10559 8/8/2019 Electronic Data Set, Filename: S- 105A_LW D_ FINAL_ FIELD_COMPOSITE_21 AP R2019_BHI_CTK.Ias ED C 31079 Digital Data 8/8/2019 Electronic File: S- 105A_GR_Res _ 21APR2019_MD_FINAL_FIELD_ BHI_CTK.cgm ED C 31079 Digital Data 8/8/2019 Electronic File: S- 105A_GR_Res _ 21APR2019_TVDSS_FINAL_FIE LD_BHI_CTK.cgm ED C 31079 Digital Data 8/8/2019 Electronic File: S- 105A_GR_Res _ 21APR2019_MD_FINAL_FIELD_ BHI_CTK.pdf ED C 31079 Digital Data 8/8/2019 Electronic File: S- 105A_GR_Res _ 21APR2019_TVDSS_FINAL_FIE LD_BHI_CTK.pdf ED C 31079 Digital Data 8/8/2019 Electronic File: S -105A Final Field Surveys.csv ED C 31079 Digital Data 8/8/2019 Electronic File: S -105A Final Field Surveys.xlsx ED C 31079 Digital Data 8/8/2019 Electronic File: S -106A Final Surveys_.pdf ED C 31079 Digital Data 8/8/2019 Electronic File: S -105A Final Surveys_ xt ED C 31079 Digital Data 8/8/2019 Electronic File: S- 105A_25_tapescan_BHI CTK.txt ED C 31079 Digital Data 8/8/2019 Electronic File: S-105A_5_tapescan_BHI_CTK.txt ED C 31079 Digital Data 8/8/2019 Electronic File: S-105A_output.tap ED C 31079 Digital Data 8/8/2019 Electronic File: S- 105A_GR_Res _ 21APR2019_MD_FINAL_FIELD_ BHI CTK.tif AOG(`(' Page 1 of 2 Monday, August 19, 2019 DATA SUBMITTAL COMPLIANCE REPORT 8/19/2019 Permit to Drill 2190320 Well Name/No. PRUDHOE BAY UN AURO S -105A Operator BP Exploration (Alaska) Inc. API No. 50-029-22977-01-00 MD 10559 TVD 6876 Completion Date 4/27/2019 Completion Status 1-011- Current Status 1-011- UIC No ED C 31079 Digital Data 8/8/2019 Electronic File: S- 105A_GR_Res _ 21APR2019_TVDSS_FINAL_FIE LD_BHI_CTK.tif Log 31079 Log Header Scans 0 0 2190320 PRUDHOE BAY UN AURO S -105A LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report O Production Test Informatior6 NA Geologic Markers/Tops 0 COMPLIANCE HISTORY Completion Date: 4/27/2019 Release Date: 2/25/2019 Description Comments: Compliance Reviewed By: Directional / Inclination Data t,y/ Mechanical Integrity Test InformationY // NA Daily Operations Summary 1`"1 Date Comments Mud Logs, Image Files, Digital Data Y / Core Chips Y � Composite Logs, Image, Data Files YO Core Photographs Y /`/ Cuttings Samples Y(9 Laboratory Analyses Y NA Date: AOGCC Page 2 of 2 Monday, August 19, 2019 BA ER 0 PRINT DISTRIBUTION LIST F�UGHES a GE company COMPANY BP Exploration Alaska Inc. WELL NAME S -105A FIELD Prudhoe Bay Unit CD/DVD COUNTY PRUDHOE BAY PRELIM BHI DISTRICT Alaska SURVEY AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(o@bhge.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. B04 PERSON ATTENTION V t BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aides Ann: Benda Glassmakee & Peggy O'Neil 900 E. Benson Blvd. Anchorage, Alaska 99.508 2 ConocoPhillips Alaska Inc Attn: Ricky Elgarico ATO 708 700 G Street Anchorage. AK 99501 3 Lynda M. Yaskell and/or Leonardo Elias C Street, Suite 505 orage, AK 99503 4 State of Alaska - AOGCC Attn: Natural Resources Technician II 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas ••• Attn: Resource Evaluation 550 Wet 7th Avenue, Suite 1100 Anchorage, Alaska 99501 Exploration (Alaska) Inc. rotechnical Data Center, LR2-1 E. Benson Blvd. :horage, Alaska 99508 to: David Itter TOTALS FOR THIS PAGE: 210032 3 107 9 ase sign and return one copy of this transmittal form to: Exploration (Alaska) Inc. rotechnical Data Center, 1-112-1 E. Benson Blvd. :h, AK 99508 or GANCPDC@bp365.onmicrosoft.com LOG TYPE GR -RES LOG DATE April 21, 2019 TODAYS DATE August 6, 2019 Revision Details: Rev. Requested by: --- FIELD I FINAL CD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS It OF COPIES I# OF COPIES I# OF COPIES 0 0 pi RECEIVED AUG 0 8 2019 7 I Pl THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY David Wages Well Interventions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S -105A Permit to Drill Number: 219-032 Sundry Number: 319-292 Dear Mr. Wages: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. o l o s k o. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED thisLi day of June, 2019. FRBDMS 'JUN 2 61019 STATE OF ALASKA f' ''ASKA OIL AND GAS CONSERVATION COMMISSIr' )PLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 JUN 1 1 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations �sh'u°tdfo'w�n Suspend ❑ Perforate 0 • Other Stimulate ❑ Pull Tubing ❑ Change >Qm Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0• 5. Permit to Drill Number 219-032 3. Address: P.O. Box 196612 Anchorage, AK 6. API Number: 50-029-22977-01-00 ' 99519-6612 Stratigraphic ❑ Service ❑ 7, If perforating. 341 G 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU S -106A - 9. Property Designation (Lease Number): I 10. Field/Pools: ADL 028257 ' PRUDHOE BAY, AURORA OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (m): Total Depth TVD(Ih: Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10559 • 6876 10545 6874 None None Casing Length Sin MD TVD Burst Collapse Structural Conductor 79 20" 28-107 28-107 1490 470 Surface 2969 9-5/8" 28-2996 28-2833 5750 3090 Intermediate 7626 7" 26-7652 26-6779 7240 5410 Production Liner 2960 2-3/8" 1 7599-10559 6731-6876 11200 1 11780 Perforation Depth MD (ft): Pertoretion Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8220-10170 6853 - 6852 3-1/2" 9.2# L-80 24-7631 Packer: and SSSV Type: 4-12" Baker S-3 Penn Packer Packets and SSSV MD (ft) and TVD (ft): 7593/6726 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 • Service ❑ 14. Estimated Date for Commencing Operations: June 21, 2019 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Wages, David be deviated from without prior written approval. Contact Email: David.Wages@bp.com Authorized Name: Wages, David Contact Phone: 907 564.5669 Authorized Title: Well Int rventia PEngineer Authorized Signature: Date: COMMISSION USE NLY r •('7f1 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n I 1 Z61 2- Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑/✓, Other. Ass.P,e F G PF,ew n b iti Arwircaws .40GGc c,�+nrm,�-�✓'r �'-oe /E,e�¢c ru.P.�G oAErPi¢rsesi/ oN f0J'79fX„/ X' Post Initial Injection MIT Req'd7 Yes ❑ No ❑ ZBDMSjk4/JUN 2 6 2019 Spacing Exception Required? Yes No ( Subsequent Form Required: .- zjAy APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date O 1'0111 ORIGINAL ✓Y (.11 6/1 x1%1 tl (1j-/.- �ii�.�lAil��� �(r f Submit Form and Form 10-403 Revised 04/2017 Approved application is//valitl for 12 months from the date of approval. Attar in Duplicate AOGCC Comments regarding Approval for Sundry 319-292 for PTD 219-032, 5-105A Fracturing 1. 5-105A was sidetracked from parent 5-105 at 7646' MD. Perforations for second stage of fracturing treatment will be across the whipstock face. Isolation from parent perforations will be questionable after perforating across the whipstock face, as the reservoir abandonment for 5-105 was approved with a variance to 25.112 (1) with isolation provided by the sidetrack liner cement only. 2. Prior to milling the 5-105A window, cement was squeezed past the whipstock to isolate the S- 105 lateral and to cement the whipstock in place. That cement job had losses, was never pressure tested, and cement never tagged, so good hydraulic isolation to the parent is not assured. S -105A at the upper fracturing perfs will be very near the proximity to 5-105 parent perforations. Modeling for the 5-105A fracturing treatment are essentially the same zones that could see fracturing pressures in 5-105A lateral. 3. AOGCC has determined that the untested 5-105A whipstock cementing, location of 5-105A in close proximity to the original 5-105 wellbore, perforating across the 5-105A whipstock, and the extent of the previously fractured 5-105 wellbore may result in the 5-105A hydraulic fracturing job migrating to 5-105 and its previously hydraulically fractured zones. As per 20 AAC 25.283(1) AOGCC finds that the potentially communicating 5-105 and 5-105A fracturing zones are sufficiently isolated that this will not promote waste, will notjeopardize the ultimate recovery of hydrocarbons, will not jeopardize correlative rights, and will not result in an increased risk to health, safety, or the environment, including freshwater. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF NOTICE OF OPERATIONS I I' Before me, the undersigned authority, on this day personally appeared h C/1 m ct 25 who being duly sworn states: 1. My name is David Wages. I am 18 years of age or older and 1 have personal knowledge of the facts stated in this affidavit. 2. lam employed as an Engineer by BP Exploration (Alaska) Inc. (`BPXA") and I am familiar with the Application for Sundry Approvals to stimulate the S -105a Well (the "Well") by hydraulic fracturing as defined in 20 AAC 25.283(m). 3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well, a true copy of which is attached to this Affidavit as Attachment I ("Notice of Operations"). 4. On May 29th, 2019, the Notice of Operations was sent to all owners, landowners, surface owners and operators within a one-half mile radius of the current or proposed wellbore trajectory of the Well. The Notice of Operations included: a. A statement that upon request a complete copy of the Application for Sundry Approvals is available from BPXA; b. BPXA's contact information. Signed this 4th day of June, 2019. STATE OF ALASKA THIRD JUDICIAL DISTRICT AJ (Signature) Subscribed and sworn to or affirmed before me at AhdAAM 1k on the 7 day of L4 ht 20�. Signature of Officer Shit ofAlaska Title of Offic NdM Public Lortia L. Jordheim Ny Canruission E*w. 3 20 20 Date: May 28, 2019 Subject: 5-105A Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: AOGC Commission Attached is BP's proposal and supporting documents to fracture stimulate the Kuparuk interval of well 5-105A. Well S -105A is a new drill targeting an unswept portion of the fault block We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which requires identification of fresh water aquifers and a plan for basewater sampling. Please direct questions or comments to David Wages Plat Identifying Wells (20 AAC 25.283, a, 2, A -B) Per the plat above, there are no water wells within 'h mile of the subject well. Producers within 1/2 mile of well trajectory (20 AAC 25.283, a, 2, C) me .1.0arsduarm .11 us 5-. Development OII VrMu[er 5hp'lm SIX Service Mhtl01e1^IttLpr Shm-ln OeaG hound AbaMonatl S'3o9PBl DevebpmeM Pluggetl BarFFor Redrill S.I35 Development Oi1M1a0uarWslaN OavebpmeM Abandimed 5-l" M pmn OIpH Suspand. 5-I.NP mnt Derebpe PluggeC lookFor Rephe Devent"am AWMpnetl 5-IOAPBI Development Plugge NO For Redrlll 5136 Senses Wales brlMor lnjMing Derelopmenl ql x.it.,Shu In S-1.82 Development Pluped N& For ReGnll IM ServKK Walermushor lnlMYy DPvelOpment AbiMbnM 511 XMtt A6anpi iIIBPBl Sen". RLgq"Oazk Fm Rudell Development Od Rp0uRr 5nN-m 5110 $eIn- Aoureened SI21mv Servs¢ PIS"Bad Fpr N erih Development On Well III. Semtt Apando^M SIn cevebersom 0.1 hpa1uaer 51 an P01 OevebPmeM Pluyetl auk Far Radial G110B Servlu Water Insecta Shut-in 5@9PBl oavebpmem phalli NO For ReaMll 11 Serve's Militant NO per ped .31 5111 Service WaterinleLTar Inletting Slm.2 Ombpment• PkggMexk For NOW Devebpngnt • oil purposes Gas Lrt S13lPBl Servrte PI uggeO Bad For Rehrll S33A DMbP^=M Abandoned ServRe Mrstlarar,tt05he.a. 5 -Hasa] Servire Pluggetl NO For Nona S12B Development O•I Frpdelr, WS Lill nevpbpmam Abandoned S112 servire Wanrinjett... lente, In P!velopmeM Mentioned Sentries Water maseter SM1UFIn SHILL Servrte Water And .1oJehor 5 -IH Star. sumpolep,sor Shut N II servile Pluggee Bad Forikdnll SIIII. PB] ServoU MLpg"Bad For Padl 11 S-135 Development Od Ratluai Lill Servq Water essism, lruess, G3ISLIPB3 Servie Pluall Said, For ROOM S135PB1 OevelapmeM Mpµ dpass Fpr Rednll Development Abandoned SI13 Development Abandon. S135PB2 DerebpmeM PlLggeal NO Far..dull Ceualppment OII P,ptlueer Spahr 5-113A DN¢Iapmere Abandoned 5-13A OevabpmaM Oil Producer Shvi Oeveboment AbanMned 5113B Development oil P,Wlrter Snupin 113APSI DevabpmeM Pluggeal NO his Redhol Cau..'meM AWrlNrwd 5113011 OevelopmeM CII PraAxer Ore." SU ServKKa AbaNpnetl Development Oil producer She' in 5-I14 0—tirement ADaMoned 5Sea Servire Suspended 5ervlce AbaManed GIIaA Service Water inutionrInletting S15 $'slog WharbuettorsM1ulIn Server Water Myttor Nut -In IIIS Cevebpmem Oil ProduorShut-ln S.Pal Servltt Pblggetl Bad For Rear's SI Servrte ougget NO For Neill 5-116 Servrte Adantloned 5-I6 Derelopmam OR producer Gas LN 33 sm". plugged Bank For Rednl l III" Servide Water lnleRar lnlMlng SI6PB1 DeveloW^eM Plapged Bad For Retell 13 Serve's Plugged BW For Redril Ill"PB1 SeFviee plugged Bad For Redrlll 5-17 DevebpmeM AparbOMd Devslamem. AbaMmed S116APB3 Servire pl.ii aad For Rednll S1]A Development Abandoned Developrrem Oil Moduur Gas ON 5,117 OerNopment tel prompanrGast.it S1IAL1 OF-Imseent aba^donid servYR Wats, ln,..rl^jadm, SIle Development .1 F., Shut -In IIALLFBI Dnebpmem ""heed NO For Retlnll II D'i"'Immena Plugged Odd For Red.11 5-119 DevelopmpM .19,0 1Ws LN S3]AIGI I..Ime^t. Plugged Ooh Far Rsdn 11 Develaanumn Oil producer as tel S11A Service Abandoned S-178 perelopment Aramemretl Devempmim ANnaaned sue Service Water mledor lnpotl lag !s3X Development OI 1%aducer shut -In .OI cetahm:nem Plugged NO For RednR 112 Develeamart ApeMo^ed s]ILPOI ONempment Ph$ged Bad Far aednR 11 OsraharraM Plugged. FWRednll It. samure Wstar Interior nespe, S�3XP82 Oerelppmflt plugged Bad Fa, parme Devebamenl a., ROOumr as it 5131 Development .11 PrWuer Gu LhF 5 I Derebpment ANrdaned Senn. WnerinlMoashurAn S121Pe1 Development PNggW Back For NOW S.M Dwabperem AOandoned Devebpham, UpedueH Gas uN I= Development OR PaMrvsr 11. an S100 Development pduler..a Lift OON Devela0ment Oil P,oNm baa lift S123PB1 DevebpmeM Pegged 084 For Ndrrll 119 Devleassai O.I pmpu¢r Sime -an I, Development Plugged NO For RpWll SM"O Dervelopmare muali OHe For Naval Ile Service Abandon" Serrate MiXlble NleMr Shut -In 5133PB3 Development pluaged NO For Redrlll 13g1 Deverme ant AlandoMd Develepma^I Suspended SIn larvae Wier lnlMar Shulln 5-1. Development Ol shduttlGas Lift Sl Cev H.'me. PltpRetl BM Fpr Redln 1 cerebomenl O. paaduearship", 31 Deuilopmem plural"Bad For Far NI Serves Wrtermle¢orinp6i^g Dev opmam Oil PrMuearGat uh Development ApaMorrtd Development OII endues Ws Lit ISDevelopers. 011vm 1Flowmg 130 Development Ol ProdocerNldom .1-03 nevelopmam OII hoduttv ""gala S31 Development Abantloned 1 DevocpmeM OIIWHI 'Me Samurai MIXIOIe arleISPr Shue In ] LMvalapmeM OIIWell 5-32 Development Abandon" virrisce Witter mlectar uner i, $.I. Dnelopment Oil Rod um Shut. ln Service Water Interior Sout.In S33 Dnelopment 011hoducer Gesuft Serene Miame .phop.r5hrl-In IN Service Mlstlble lsum., Stalin Senate Water lhecur lnDieng 135 ....lusher, Oil producer Gas len pavebpmem Abandpmd Sib Development Oil Producer 5hu61n y y Devslopmenl almnemospi Sal Development ApandoMtl Servs 13]A Development oilpreadrGrslift Cor shipment In 5-37Ao01 OndeverumerS .IF Development BMkhutI 1.1 Lateral Denten M Service AnumtluterNW Aternesrcd 1. alaMprpd 1W Development DeveloS.ruoeomem Oil Fred Oi1WMucer Nut In Abandon" OS Service R tiro Serve Abandon" VVV il seethe final Waley Interior lnjF6in8 hurp,I tenor SeMce Wale, SDua. InDeatho �� ..\ ma^t I'01 Abler Sa01 Service Isomer Walden �J Sarame 5arvite WaleespainarinlMing 5'a01PBI Inca UstrFNuanln Redrlll 81 Senile PlVpmed Bad FOrR"nal DervRe Development Oil prodmersh SM1N-In �� Development $.IP Gas ufi SAI Development Ml ndered AbaMonetl 1 Development Athandoemar Ateando^" Service Wa Demang nelapment AWMorI" 14lo envelopment Gas Lill Pendustar..a Lill Oboradm B1 DsvelaOm.M IQ. Pltgg"Bad Fm R"nll SdILl D.velopmfna d AWntlaned DnelOpmeM I. P,WutP 5hh-In 1i1p01 Xrvite Plugg"Bad For Redull Develo0mar, Abanpoxtl Gat elop.nt Dnm ^ Apando" 0 -:torment Abandoned S.. Dnelopment Oil ProdmerGas Lift Devemounted On PmOOer SboFl^ SdIDel senile olugg"Ba4For Rarml, at Devebpmarna kw NO to, R"dil IQ Dervelopmenl 01. Rod—shut In Development Abando^ed S". Development 011primmarGsLN Rrvlce Walerrnptlar SRUPm Sia Development, Abandoned 1 Sarva. Waanurses'Shut In 5-mA Deuempmem On Pmauremasuit Development 0.1 P,"ue, shpom 'Issi Oavebpment Abanpaned Development AWMocetl 1d41.1981 Development Pluggep NO For Form Servlw Miardi Injector ShutInIS SDA ., i. Water Injector Shut I^ f `MI Exemption for Freshwater Aquifers (20 AAC 25.283, a, 3-4) Well S-1 05A is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated July 11, 1986 where Standard Alaska Production Company requested the Alaska Oil and Gas Conservation Commission to issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II Injection activities. Findings 1-4 state: 1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are situated at a depth and location the makes recovery of water for drinking water purposes economically impracticable. 3. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are reported to have total dissolved solids content of 7000 mg/I or more. 4. By letter of July 1, 1986, EPA -Region 10 advises that the aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a non -substantial program revision not requiring notice in the Federal Registrar. Per the above findings, "Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC 25.440." thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which requires identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283, a, 5-6) 4/18/2018: cement whipstock into place, drill 3-1/2" lateral to 10,559', run 2-3/8" liner and cement in place with 18.7 bbls of cement. No pressure test of liner lap. Perforated liner, RDMO. Please see completion schematic Pressure Test Information (20 AAC 25.283, a, 7) Prior to (racing operations, as part of the prep work, the tubing will be pressure tested to 4000 psi and IA will be pressure tested to 3000 psi per the pre/post frac procedure included, we will also test the liner lap at the same time as the tubing, if the liner lap fails we will install a liner top packer. Accurate Pressure Ratings of Tubulars and Schematic (20 AAC 25.283, a, 8) w Mnimum X) =1.9915' @ 7805' 2-7R' X 2.iw XO Ttpaz319'1W Weight 11• - 5A1111c lti 9RfA815, ACNATOR. S-1 05A M3,5P/- 850Y W HEV • 37.91' 1(Cp. 1-aq' Aft Ae6m m M. It 6]58, De M= Mr Deb 7vv- 9796!5 41? T90. ftY. LY, .Ot3]] y1. D -]6Y' w Mnimum X) =1.9915' @ 7805' 2-7R' X 2.iw XO Ttpaz319'1W �_�] sADTrROr AVAf Arc LLLOUr VIDJN(LxG1765r - ]65'5' Name/Size Weight :fArc 1 T ir)IH:Mtl1Nal>t �Tp+T619'. 18LM 61AMADL000NMIM S-1 05A AIIDLE A T T[P PDF: IM -08M w1e_ refM m weex:bn m rot n•wtr pert 9Am SRE SPF rAH2VAL � OpNS7 I GTE 199' 9 6ilo-8959 0 0103/18 1.w S an-MMO 0123f19 �_�] sADTrROr AVAf Arc LLLOUr VIDJN(LxG1765r - ]65'5' Name/Size Weight :fArc 1 T ir)IH:Mtl1Nal>t �Tp+T619'. ID S-1 05A Collapse, psi 9-5/8" Surface Casing 40# L-80 8.8351 5750 3090 7" Production Casing 26# L-80 M' A-00'X310'XO.D-E91i 7240 5410 4-1/2" Production tbg 12.6# L-80 3.958" !M• TAMPDIrrcD. R 7500 3-1/2" Production tbg 9.2# L-80 2.992" 10,160 10,540 2-3/8" Production Liner _ ae6• _ slrlsxrr.o•:.np L-80 1.995" 11,200 11,780 MS LFI MVlias STIMITVOIDEVI TYPE VLV LATCW rOF GTE 1 A1P JT/5 GMANA OLE M 16 O5V8D9 ] 9531 9T7 m GAAYM 90 R( )D OSVBIl9 1 AT t3M P GM WA ua Rx 0 o31t3n9 TWO —317 I63XWID;ILM' TM—}10'xa10'xO,D-}59Y TMS—,rx+t0'G *3R rMO PU S m }t?. D=3675' 7M7 -A-10•X }tl]'xb,D•S.Mx' �_�] sADTrROr AVAf Arc LLLOUr VIDJN(LxG1765r - ]65'5' Name/Size Weight Grade ID Burst, psi Collapse, psi 9-5/8" Surface Casing 40# L-80 8.8351 5750 3090 7" Production Casing 26# L-80 6.276" 7240 5410 4-1/2" Production tbg 12.6# L-80 3.958" 8430 7500 3-1/2" Production tbg 9.2# L-80 2.992" 10,160 10,540 2-3/8" Production Liner 4.7# L-80 1.995" 11,200 11,780 Wellhead: FMC manufactured wellhead, rated to 5000 psi. Tree: 4-1/16" 5,000psi Tubing head adaptor: 11 " 5,000psi x 4-1/16" 5,000psi Tubing Spool: 11 " 5,000psi w/ 2-1/16" side outlets Casing Spool: 11 " 5,000psi w/ 2-1/16" side outlets Geological Frac Information (20 AAC 25.283, a, 9) litho) is Desc. Surface I TVD SS. top I TVDS S, btm I TVD Thickness MD. Top I MD btm I MD Thickness I Est. Frac Pressure, silk Shale Kalubik 6553 6700 147 7473 7636 163 0.7 Sandstone C4 6700 6722 22 7636 7661 25 0.63 Sandstone C3 6722 6735 13 7661 7677 16 0.65 Sandstone C2 6735 6810 75 7677 7788 111 0.66 Sandstone C1 6810 6845 35 7788 N/A N/A 0.68 Shale B Sifts 6845 6919 74 TATA WA WA 0 7 Location, Orientation and . Report eMechanical Condition eEacB_lmlmyrn_ Confining Zone AAAcaz.mq N !. % � - . - .: y . ®®— % S -105A -&�— _ , .. w, �� �_�_�. yyMa,1 4 88 N ax y E 9 YN v V V E Y L � U 4 L y p 4 4 4 Y V U O q E c m v E m u O E N O a N 6 E s f✓ o V L o 4 V J L V V E G V U S a 0 o o 0 0 n a c E 5 u o C CC C C V � C a o 0 o f '�- `-' o i u Y o 0 y c '- o o o 0 0 5 o L 0 0 C E u n z z 9 o c z z> z z z LL o a z z m n N n n N� ry P o a d F F r LL F t L r f LL i i f i f g i 2 f i F 2_ s E II V V U V V V V V Y V V V V4 O y U Y f ) Y T T T T T) Y} Y Y Y} Y Y Y Y Y T Y T z Y Y Y ti N p � N N b �O b N b m N O Q f 3 E E E E E E E E E E E E E E E E E E E E E E E � J J J J] J J -J J O J J J J J J J J 1 >> i 9 >O 9 >O i >O 3 i >O 9 >O >O 3 9 i i 0 i >° >° i F >O >° 9 � XI m � x �e u q LE Oi P P P P O� P P p V W.W. C L C C V V V V U V V V V V V U O V U V V C V V O p V V V p V V ^ CGO COG'J OOOO GCOD GJ GD G G G G G G G G C ti G G G GL E YC3 GC GC 8 E� EBEE J O �EoQBEEEEEE J J J J J EEQB J O J E�BEE J J SV $V i nV u` aV` c nV` S SV n` n SV SV n i c Y'l -, 6 V G p O F, gn; W O¢¢ yip O Q N m fin`[ Vf 3 . N H N N N N N N 1J N 1% �A JI N JI in Ji Location of, Orientation of, and Geological data for each known or suspected fault. (20 AAC 25283. a. 111 BP's technical analysis based on seismic, well and other subsurface information available indicates that there are 7 -mapped faults that transect the Kuparuk interval and enter the confining zone within the 'h radius of the production and confining zone trajectory for S -105A. Fracture gradients within the confining zone (Kalubik and HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. The HRZ and Kalubik in this area are predominately shale with some silts with an estimated fracture pressure of —0.7 psi/ft. Thickness and fracture pressure for the confining layer is discussed in Section 9. No faults were crossed when the S-1 05A was drilled. No losses were seen once drilling commenced out of the parent wellbore. Faults 1-7 intersect the production interval and confining zone within the h mile radius. Their displacements, sense of throw and zone in which they terminate upwards in are given below. Faults THROW Upward Fault Termination Zone Fault #1 DTW 60' Colville Fault #2 DTN 75' Colville Fault #3 DTW 30' Colville Fault #4 DTN 40' Colville Fault #5 DTN 25' Colville Fault #6 DTW 50' 1 Colville Fault #7 DTNE 35' 1 Colville The location of Frac #1 in the production hole is perpendicular to the maximum horizontal stress which will result in a transverse fracture. The fracture is planned to be initiated at the perforation interval with a midpoint of 8585' MD. With a fracture initiating in the perforations with a modelled 250' half-length, 790' of standoff exist between the tip of the fracture and Fault #1 and 1100' of standoff exist between the tip of the fracture and Fault #2. All other faults are well above 1000ft of standoff. The location of Frac # 2 in the production hole is in the vertical section of the well. The fracture is planned to be initiated at an additional perforation interval in the heel of the well, with a midpoint of 7710'MD. With a fracture initiating in the perforations, with a 250' modelled half-length, 580' of standoff exists between the tip of the fracture and Fault #1. 620' of standoff exists between the tip of the fracture and Fault #2. All other faults have higher standoff than Fault 1 and 2. Summary Hydraulic Fracture Program (20 AAC 25.283, a, 12) (Detailed Program and Pump Schedule included) Maximum Anticipated Treating Pressure: 3500 psi Maximum Allowable Treating Pressure: 4500 psi Anticipated half length: 250' Anticipated height growth: 90' Each frac will initiate at their corresponding perforations. The perforations are located at: Frac Stage MID feet TVD, feet MD Frac Height TVD Frac Height 1 8220'-8950' 6788'-6777' N/A due to well directional 6700'6790' 2 7644'-7674' 6707'-6732' 6730'-6820' Estimated TVD Top and Bottom of Frac: 6608'-6670' Estimated MD Top and Bottom of Frac: 8050'-8140' W Measured Depth PrOle 3.11M 0—--4-- — U;4M*dAW1M,0600ert Measured ❑epth The above frac dimensions were calculated using modeling software. Surface pressure is calculated based on a closure pressure of -0.62 psi/ft or 2700 psi, this combined with the anticipated net pressure to be built, hydrostatics and the friction gives a surface pressure of 2500 psi at the time of flush. The frac height is primarily based on closure pressure differences between the confining shale layers and the unconfined sandstone reservoir. Average confining layer stress is anticipated to be -0.7 psi/ft. Half length is based on confining layer stress as well as leak -off and formation modulus. Given the values, the above half lengths are calculated. Pressure Test Information (20 AAC 25.283, a, 7) Per the frac program, the both the tubing and the IA will be pressure tested. The IA will be tested to 3000 psi and the tubing will be tested to 4000 psi. PRV setting procedures and annulus monitoring: Maximum Allowable Treating Pressure: Stagger Pump Kickouts between: Global Kickout: IA pop-off set pressure: Treating line test pressure: 4050 psi and 4250 psi (90% to 95% of MATP) 4250 psi (95% of MATP) 2250 psi (75% of MIT -IA) 135,000# 16-20 CarboLite, 65,000# 16-20 Sand Requirement CarboBOND Minimum Water Requirement 2400 bbis (pump schedule: 1063 bbls) IA Hold Pressure 2000 psi (IA pop-off @ 2600 psi) Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. r L IS -105a Rig U ■ mea �a.�mu3 rme D. ontrcmg lime Bo Lao Chemical Disclosure (20 AAC 25.283, a, 12) rsOs 4 WcfiN ] Gal/ 79 tD i30000a1 6100 >d _ 1675 --- 6[Nee< Y]121r%a0'wrllD 36,3w Gal - 1606 _ m _ L065 �_ 1 _. M002 _ CM55M w fM�4urj Sole Y6iLaa _l____ �_— tlay Arad Kens � IE661ve _ S "J1006Gg 5150"-_ - -- _ 66 Gil/Ow" i.... .. 5Ao Gal i Gai:_W000a_-_ 900 Gal Cal 1750 Gal i 2 i i00l 2 Lbl IOOO" 275,0 16 610 M275 1012.1650 M nt ..i 01 l6/IOWGII —_ _ ..�.—___— vaaia6 cGrcamabau I 61W.0 tb L U23 6fOgb 2Gal/I GaI 13D 221r65____I_ -�_ _.- M vend _orcenarWau 123,532D W 5522-1610 1SS61620 ftCPPft ADM cdceRlmldx w 56 0 W _ Wa3ar(aldwi�j Mia Wxer w9p!ea bj (1ieM:_._. .. 76% 64147 --_. 0761 _ —_— _.- 3.6}NdaY'n.n.n-OIfMIIryfLMaOfmAOf�[MOM1Oe <1% 610 ndpui-2a1 l <Oi % _ 221r65____I_ -( 11242-s i-uIMOMd cool x 3AA-Z 6pb�i aMbq1r�pyo�taig�i�a^s�a�leQ 0.0001 % 01% 131M5-6 SOdum UVabvah 2662 206 2-mKb}+FMifONr.d }wee <00001 % 7Y7.667 96[36676 WOMa LaifYn[yl 1 <0001 % __. >*pa,)}6 Ma�moOun ynyan <OAS % % JT66561 MD(neaun tNOriOe .0:001 x 900M13O0 _ GOY N^ <iK._ . _ ..... <Oml % 35!3 — OD3 % S00a}5=.a __—�add GaknYntlWnbe I._— <CA1 % 103n.661 Maprvum runate i <0.001 % % ne 010 <ai% --._--. 26FJ2351 546v6 2h-bahateld3a0e 3az6 al<ohd p1Gn6ar 6ow<Nale6 s6J62s1.-- a ---o6abla, v�trdeum,. W Benicia ceranlc mxeron ul6+aWe$, drt ' `20% o6133d9a cuas akgw Rllmylua6 _ 9165}343 Outaniob�¢eaM, olmea <ODi % f25005 -p4 OMM Cub .__ 129514067 IVr - Kid POOW Wellwork Procedure Reauest To: W Date: 5/28/2019 S DRIFT FOR CIBP IN 2-3/8". PULL LGLVS, LOAD TXIA, SET DGLVS, SET LTTP, MIT -T, MIT -IA, PULL LTTP. 2. VER1 Assist SL w/ circ and MITs 2. AFE: If MIT -T Fail, Install LTP From: David Wages IOR: 450 SP Install Tressaver, frac, RD treesaver Est. Cost: 1,400K Subject: S-105 - Pre/Post Frac Procedure Please Derform the followina steDs 1. W Service Tree 2 S DRIFT FOR CIBP IN 2-3/8". PULL LGLVS, LOAD TXIA, SET DGLVS, SET LTTP, MIT -T, MIT -IA, PULL LTTP. 2. F Assist SL w/ circ and MITs 2. PS If MIT -T Fail, Install LTP 3. C Set Plug 4. SP Install Tressaver, frac, RD treesaver 5. C C/O, Set plug, Perforate 6. SP Install Tressaver, frac, RD treesaver 7. CP Contingent Coil FCO 8. S Set Generic GLVs 9. T Flowback Post Frac 10. C FCO/Mill to TD with well flowing Current Status: Minimum ID: Max Deviation: Lnr Top Deviation: Last TD Tag: Last Downhole Op: SBHP/SBHT: Latest H2S: Proaram Contacts Operable 2.250" at @ 7599' MD -101 deg at 8258'MD -25 deg at 7599' MD Rig Workover Rig Workover N/A 25 ppm, 5/2019 2-3/8" Liner Deployment Sleeve Page 11 of 12 Contact Phone -Work Phone - Mobile Interventions Engineer David Wages 907-564-5669 713-380-9836 Pad Engineer Lea Duong 907-564-4840 720-951-7238 Page 11 of 12 Well Summary: Recently CTD drilled sidetrac targeting unswept reserves northeast of the parent wellbore History: 5/2019: SL Drift to deviation (7796'). Set LGLVs Testers flow well, confirm low rates Objectives: Frac and pop S-105 1.1 Critical Issues: Latest MIT -T: N/A Latest MIT -IA: N/A Latest Caliper: 10/2011, 29% wall penetrations at 7446'& 5339' 1.2 Pressure Prediction: Reservoir Pressure SBHP: 2931 psi on 5/6/2019 @ 6500' TVD Page 12 of 12 Procedure 1. Wellhead- Service tree 2. Slickline- DRIFT FOR CIBP IN 2-3/8". SET LTTP, PULL LGLVS, LOAD TXIA, SET DGLVS, MIT -T, MIT -IA, PULL LTTP. a. Drift for composite BP to be set in liner pre stage one frac i. Last slickline drift made it to 7796' b. Set test plug in liner deployment sleeve c. Pull LGLVs d. Load IA with inhibited seawater and freeze protect i. IA Vol: 202 bbls ii. Tbg Vol: 66.5 bbls iii. Freeze protect vol: 88 bbls (freeze protect to 2500') iv. Seawater Vol: 181 bbls e. Install DGLVS as needed for circ, ensure all set for MITs f. MIT -T i. Max Applied Pressure: 4500 psi ii. MIT Target Pressure: 4000 psi g. MIT -IA i. Max Applied Pressure: 3500 psi ii. MIT -IA Target Pressure: 3000 psi h. Pull LTTP Fullbore- Assist Slickline 3. Coil- Set bridge plug a. Drift to deviation, pull a gr/CCL log b. Set Plug @ 9000' per tie in log attached i. Between existing perforations is the goal. ii. Ensure plug is stackable as another will be set above c. RD Coil 4. Special Projects- Install Treesaver, Hydraulic fracture treatment, RD treesaver a. RU and test treesaver b. Frac well per pump schedule Pressure testing Maximum Allowable Treating Pressure: 4500 psi Stagger Pump Kickouts between: 4050 psi and 4250 psi (90% to 95% of MATP) Page 13 of 12 Global Kickout IA pop-off set pressure Line Test Pressure Sand Requirement Minimum Water Requirement IA Hold Pressure OA c. RD Treesaver 5. Coil- Set bridge plug a. Drift, FCO as necessary 4250 psi (95% of MATP) 2250 psi (75% of MIT -IA) 5500 osi 60,000# 16-20 Carbolite, 30,000# 16-20 CarboBOND 1200 bbls (pump schedule: 871 bbls) 2000 psi (IA pop-off @ 2250 psi) Monitor and maintain open to atmosphere b. Set Plug @ 7730" per tie in log attached i. Above existing perforations, below planned perforations ii. Ensure plug is stackable with previously set plug c. Perforate from 7644'-7674' i. 1.69" MaxForce DeepStar HMX guns/charges ii. 6 spf, 60 deg phasing d. RD Coil 6. Special Projects- Install Treesaver, Hydraulic fracture treatment, RD treesaver a. RU and test treesaver b. Frac well per pump schedule Pressure testing Maximum Allowable Treating Pressure: Stagger Pump Kickouts between: Global Kickout IA pop-off set pressure Line Test Pressure Sand Requirement Minimum Water Requirement IA Hold Pressure E c. RD Treesaver Page 14 of 12 4500 4050 psi and 4250 psi (90% to 95% of MATP) 4250 psi (95% of MATP) 2250 psi (75% of MIT -IA) 5500 psi 75,000# 16-20 Carbolite, 35,000# 16-20 CarboBOND 1200 bbls (pump schedule: 811 bbls) 2000 psi (IA pop-off @ 2250 psi) Monitor and maintain open to atmosphere 7. Pending Coil- Contingent FCO a. See Appendix A - CT Screenout FCO Procedure 8. Slickline- D&T, Install Generic LGLVs (Deep design if possible) a. D&T b. Install Generic LGLVs (Deep design if possible) i. This step can be moved to after the post frac FCO/millout if sand top is expected to be above the perforations or if a hard screenout occurred. 9. Flowback a. See Appendix B - Test Separator Additional Flowback Procedure 10. Coil- FCO Mill out to TD a. While flowing, Mill out plugs and push to TD Page 15 of 12 Appendix A - CT Screenout FCO/Millout Procedure i. This is a generic FCO/millout procedure for a post screenout FCO. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the event. ii. The objective of this procedure is to get the well cleaned to continue frac operations or to prep the well for POP. iii. Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure b. MIRU CT c. MU BHA. d. RIH down to estimated sand top and begin cleaning out with slick 1% KCL. e. Continue down to —7544' CTMD. At this point we are 100' above the uppermost perforations. Ensure CT is clean as it is expected that returns will begin to fall off as the nozzle nears the sleeve. If returns begin to fall off, reducing BHP by lowering rate may keep returns at a manageable level. f. Slowly continue to clean out until returns fall off to —80%. g. FP to 2500'. h. Pump a gel pill at surface out to the tanks to ensure CT is clean if necessary. i. RDMO. Page 16 of 12 Appendix B - Test Separator Additional Flowback Procedure 1. MIRU ASRC. RU equipment to in a manner that allows CT to RU if an additional FCO is necessary. 2. POP the well to ASRC at minimum choke. Flow the initial returns to the flowline as long as the shake -outs meet the returned fluid/solids management guidelines. 3. Limit flow to 500 bpd 4. If solids are < I%, increase the production rate to 1000 BLPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1 %, allow well to flow to 1500 BLPD. Flow bottoms up and sample for solids production. If solids are still below 1 % continue to increase the flow rate in 500 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1 %; allow well clean up before choke is opened further. 6. Once at FOC, stabilize the well for 4 hrs. Obtain a 3 hr purge, 8 hr welltest. Page 17 of 12 Current WBD: fVF LOQ BH WAD LOG ON 04021119 TRM= roe: Fbfs m Feeetre DB for Ne A pen B6e VYfl1}Ci1D• 1P-Smf�l&re SN l;mS SPF M AL ACR ATOR - LB6' 6 CKS, E .EV - 85.09' O 0413n9 1-16' W- ELEV . 3781' %75-10170 O OWSMS IB 00438119 2 mw Se77 20 0.eee4o= -- 7ssr 50 Til O,kmTV = - e7a9ss 0' Ite / 747.9 66� n 4-117'780, 136M, L -e0, OY82T Op,D-a96e'69' —! o4n f rTaiOF 3 IIT NG. D • 2.992' Ll— 71' r �951e'COG: I.M. L -W0. -WC.D-6435. 1 I 2988- N k imm- 87 - 7.895' @ 7805 2-7780 X 2-M' XO P9FOR\TION Sl1H w fVF LOQ BH WAD LOG ON 04021119 ANDLEATTO PEW 181'QBT217 roe: Fbfs m Feeetre DB for Ne A pen B6e SFE SPF M AL OpWW DAIS LB6' 6 9320-8950 O 0413n9 1-16' 8 %75-10170 O OWSMS IB 00438119 2 9 3-30, LNL 4 79, Lee RVDe11, 00N W2 e d 1990• Page 18 of 12 BIMt 1 T ND14A: WELLMA&k> -79' a 761s'. S-1 05A WXOLS: 29'Q7666' 66• 4.1?X 3-12•XC, D -RAW IT7T 994' TAM F TJ`t.L AP GAS LFT fMNMRS ST W T•D OE1l TYPE VLV LATCH PORT DATE T 4128 A75 >a GDAMA 004E fi( IB 00438119 2 %Ot Se77 20 GD4&M 50 Til 20 0' Ite 1 747.9 66� n Gh14&M o4n Nrt 0 o21iffi19 7560 —3AWMSXiP,D=2.758", 7M2 —3-1/2'x6-12'xO.D'-2M7 TD9} —7'xft?OANAi a -a RAN w 7X0 fT15 m }f?, D= iBTS' 7997 --4-12' X}117110. a-2.%7 eADnNOtAVALASUj \&LOUT vrmcrN(s_m )7857-r895' ibeMove Analysis: �. MIT -T: 4500 psi MIT -IA: 3500 psi Frac SO: 4500 psi on tubing, 2000 psi on IA, 12.7 ppg fluid Page 19 of 12 Tie M Log Company \ Exploration w- §', Z » 2 ! ,| 15| _ �_w_ . §!! !�z n Alaska 10 !State ,m ;�}51 , / { a# __ u Em� l.. U) , {}I))( !/|[f!/ § ■ Q ! | 4§ E �c�|��� �o p §{ kj 0 �> r ®:!°�'kk� ` — | fK ;,, k \ _ ( ® { � - - ; |iIn( § }2( !!! 02 } ®�| (§k «;\ Page 111 of 12 x i J' i •r}i: is u; r .._ 2 O olua and p ooF F�'v 60 ai �o n ppm N W)Uln I- 0< 7600 7650— 7700 77 Page 1 12 of 12 LEI] - i -L i c� a O [C Page 1 12 of 12 Paragraph PBU S-105A(a) Application for Sundry Approval 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU S -105A (PTD No. 219-032; Sundry No. 319-292) (a)(1) Affidavit (a)(2) Plat Sub -Paragraph Section Provided with application. Provided with application. Complete] SFD 6/13/2019 SFD (o)(2)(A) Well location I Well lies in Sections 35 and 26 of T12N, R12E, UM. SFD 6/13/2019 (a)(2)(B) Each water well within % mile Provided with application. No wells are used for drinking water purposes are known to lie within %: mile of the surface location of PBU S -105A. According to the Water Estate map SFD available through DNR's Alaska Mapper application 6/13/2019 (accessed online June 13, 2019), there are no subsurface water rights or certificates within 7.8 miles of the surface location of PBU S -105A. Provided with application. There are currently 190 oil - related development and service wells and well branches J(2J(C) Identify all well types within Y: that lie within %: mile of PBU S -105A. There are 27 oil -related SFD mile 6/13/2019 development and service wells and well branches that transect the confining zone within %: mile of PBU S -105A. (a)(3) Freshwater aquifers: geological name; measured and true vertical depth None. Tertiary -aged Sagavanirktok Formation, which lies beneath permafrost. In this area, permafrost appears to be about 1,550' thick. (Only one older exploratory well located in this area—N Kuparuk State 26-12-12—was logged with a SFD sonic tool from ground level to surface casing point.) 6/13/2019 However, in AEO 1 the AOGCC concluded that those portions of freshwater aquifers occurring beneath the Western Operating Area of Prudhoe Bay Unit 1) do not currently serve as a source of drinking water, 2) are situated at a depth and location that makes recovery of water for drinking water j purposes economically impracticable, and 3) have TDS AOGCC Page 1 June 20, 2019 Paragraph 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU 5-105A (PTD No. 219-032; Sundry No. 319-292) Sub -Paragraph Section content of 7,000 mg/I or more. By letter dated July 1, 1986, EPA exempted aquifers in this area for Class II injection activities (source: AOGCC's AEO 1 order file, Sections #5 and #6). For an outline of the Western Operating Area, see the EPA's "Alaska Oil & Gas Aquifer Exemptions Interactive Map" available online under the "Permits" section of EPA Region 30's web page at https://www.epa.gov/uic/underground (a)(4) Baseline water sampling plan None required. (a)(5) Casing and cementing information Provided with application. See the attached schematic for As -Built casing and cementing information. 5-105A is a sidetrack of 5-105 from the 7" casing at 7652 ft and a liner to 10559 ft. Original 5-105 7" cementing was 497 sx class g with good cement reported, plugs bumped and floats held, 7" casing tested fine. For S -105A the 2.375" liner was cemented with 97 sx class g and volumes (53% excess of liner top calculation) indicate cement to liner top of approx. 7599 ft. 5-105A was sidetracked from parent 5-105 at 7646' MD. Perforations for second stage of fracturing treatment (a)(6) Casing and cementing operation will be across the whipstock face. Isolation from parent assessment j Perforations will be questionable after perforating across the whipstock face as the reservoir abandonment for 5-105 was approved with a variance to 25.112 (i) with the sidetrack liner cement only. Prior to milling the 5-105A window, cement was squeezed past the whipstock to isolate the 5-105 lateral and to cement the whipstock in place. That cement job had losses, was never pressure tested, and cement never tagged, so good hydraulic isolation to the parent is not assured. S - 105A at the upper fracturing perfs will be very near the oroximity to 5-105 aarent perforations. Modeling for the S- Complete? SFD 6/13/2019 SFD 6/13/2019 CDW 6/14/2019 CDW 6/14/2019 MGR j 6/20/2019 AOGCC Page 2 June 20, 2019 Paragraph 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU 5-105A (PTD No. 219-032; Sundry No. 319-292) Sub -Paragraph Section complete? (o)(6)(A) Casing cemented below lowermost freshwater aquifer and —v.....,c s., In AAr is nen (a)(6)(B) Each hydrocarbon zone is isolated 105A are essentially the same zones that could see fracturing pressures in 5-105A lateral. No freshwater aquifers present. (See Section (a)(3), above.) Surface casing set at 2,996' MD (2,833' ND, -2,767' NDSS) SFD and cemented to surface with full returns throughout and a 6/13/2019 recovery of 122 bbls of cement returns at the surface. Yes. In the original wellbore, PBU 5-105, 8-3/4" production 1 hole was drilled to 8,120' MD (7,203' ND, -7,138' NDSS) , I lined with 7" production casing to surface, and cemented I with 170 barrels of Class G cement. Assuming 30% hole washout, volumetrically the top of cement for the 7" casing string is estimated to be about 3,220' MD (3,018' ND, -2,953' NDSS), so in the original well, cement covers the open -hole interval containing (in ascending stratigraphic order), the Miluveach Shale, Kuparuk, Kalubik Shale, HRZ Shale, Hue Shale, Colville mudstone, Schrader Bluff, and part of the overlying Ugnu Formation. In the well to be fractured, PBU 5-105A, 3-1/4" production hole was drilled from 7,650' MD (6,779' ND, -6,713' NDSS) to 10,559' MD (6,879' ND, -6,814' NDSS), 2-3/8" liner was run from 7,599' MD (6,731' ND, -6,666' NDSS) to 10,559' MD (6,879' ND, -6,814' NDSS), and that liner was cemented with 18.7 barrels (105 ft3) of cement. Again assuming 30% hole washout, the top of cement for the 2- 3/8" production liner calculated to be at the top of the liner, I which covers the Kuparuk pay interval. Again, in the original I well, PBU 5-105, cement is present from the top of the Kuparuk up through part of the Ugnu Formation. SFD 6/14/2019 SFD 6/14/2019 AOGCC Page 3 June 20, 2019 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU 5-105A (PTD No. 219-032; Sundry No. 319-292) Paragraph Sub -Paragraph Section Complete? AOGCC Page 4 June 20, 2019 (a)(7) Pressure test: information andII Provided with application. 7" MITIA 3000 psi planned, frac CDW i pressure -test plans for casing and tubing string 4.5x3.5x2.375" testing plan is 4000 psi. 6/14/2019 j installed in well (0)(8) Pressure ratings and schematics: Provided with application. 5K psi wellhead, pump trips at CDW wellbore, wellhead, BOPf, treating head 4050 psi and 4250 psi plans. Treesaver is mentioned but at 6/14/2019 the max. pressure of 4500 psi may not be warranted. Upper confining zones: Hue Shale, HRZ Shale, and Kalubik i Shale (in descending stratigraphic order) between about 7,241' and 7,636' MD (-6,347' to -6,700' TVDSS), an aggregate thickness of about 350' true vertical thickness (TVT). The Hue Shale is overlain by many hundreds of feet of (aJ(9)(A) Fracturing and confining zones: siltstone, mudstone and shale assigned to the lower lithologic description for each zone Schrader Bluff Formation. Fracture gradient of the Kalubik SFD Shale, which immediately overlies the fracturing zone, is 6/14/2019 (a)(9)(B) Geological name of each zone expected to be about 0.70 psi/ft. Fracturing Zone: Kuparuk C sands from 7,636' to 7,962' MD (o)(9)(C) and (a)(9)(D) Measured and true vertical depths (-6,700' to 6,836' TVDSS), an aggregate thickness of 136' TVT. Fracture zone consists of sandstone with interbedded (a)(9)(E) Fracture pressure for each zone siltstone and claystone. Fracture gradient expected to be about 0.63 to 0.68 psi/ft. SFD Lower confining zones: siltstone and mudstone of the lower 6/14/2019 Kuparuk B and A intervals and the underlying Miluveach and Kingak Shales, which are not penetrated by PBU 5-105A. In nearby well N Kuparuk St 26-12-12, these intervals have an aggregate TVT of over 850' TVD. Fracture gradient expected to be about 0.70 psi/ft. (a)(10) Location, orientation, report on Provided with application. CDW mechanical condition of each well 6/14/2019 AOGCC Page 4 June 20, 2019 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU S -105A (PTD No. 219-032; Sundry No. 319-292) Paragraph Sub -Paragraph Section Complete? AOGCC Page 5 June 20, 2019 (a)(11) Sufficient information to determine CDW wells will not interfere with containment Provided with application. 6/14/2019 within/: mile Map provided within application. (a)(11) Faults and fractures, Location, orientation The operator has identified seven faults that cut the fracturing interval within the one -half -mile radius Area of SFD (a)(11) Faults and fractures, Sufficient Review. Computer modeling indicates that none of the 6/14/2019 information to determine no interference fractures induced in this two-stage operation will approach with containment within'/: mile closer than 580' to any of these faults. It is highly unlikely that any faults will interfere with containment of the injected fracturing fluids. (a)(12) Proposed program for fracturing Provided with application. CDW operation 6/14/2019 (a)(12)(A) Estimated volume Provided with application. 2400 bbl total water, 200K Ib CDW propant. 6/14/2019 (a)(12)(8)Additives: names, purposes, Provided with application. CDW concentrations 6/14/2019 (o)(12)(C) Chemical name and CAS number Provided with application. No proprietary products CDW of each 6/14/2019 j (a)(12)(D) Inert substances, weight or Provided with application. CDW volume of each 6/14/2019 (a)(12)(E) Maximum treating pressure with Max. 3500 psi estimated treating pressure. Max pressure is CDW supporting info to determine 4500 psi. Pump shutdowns start at 4050 psi. With 2000 psi 6/14/2019 appropriateness for program back pressure IA, max tubing differential should be 2500 psi. (a)(12)(F) Fractures—height, length, MD Provided with application. The anticipated half -lengths of and ND to top, description of fracturing the induced fractures are 250' according to the Operator's SFD model computer simulation. Computer simulation indicates the 6/14/2019 I i anticipated height of the induced fractures will be 90', so AOGCC Page 5 June 20, 2019 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU S -105A (PTD No. 219-032; Sundry No. 319-292) Paragraph Sub -Paragraph Section Complete?] (g) Annulus pressure monitoring & notification (h) Sundry Report (i) Reporting 500 psi criteria (g)(I) Notify AOGCC within 24 hours (g)(2) Corrective action orsurveillance IA popoff pressure to be set to 2250 psi per planned sundry MGR program. 6/20/2019 (9)(3) Sundry to AOGCC Sundry request 319-292 received at AOGCC on June 11,MGR 2019. 6/20/2019 FracFocus AOGCC Page 6 June 20, 2019 induced fractures will likely penetrate into, but not through, the overlying confining shale. (a)(13) Proposed program for post- BP has agreements for Class I disposal at BP G&I Pad 3 and CDW fracturing well cleanup and fluid recovery their Class I and II disposal well options. 6/14/2019 (b)Testing of casing 2000 psi back pressure, plan to test to 3000 psi CDW or intermediate Tested >110% of max anticipated pressure Using 4.5x3.5x2.375" tubingxliner for stimulation. 6/14/2019 casing (c) Fracturing string (c)(1) Packer >100'below TOC of 4.5x3.5x2.375" tubing to be pressure tested to 4000 psi. CDW production or intermediate casing 2000 psi backpressure planned. 6/14/2019 (c)(2) Tested >110% of max anticipated 4.5x3.5x2.375" tubing to be pressure tested to 4000 psi. CDW pressure differential 2000 psi backpressure planned. Max differential planned of 6/14/2019 2500 psi. (d) Pressure relief Line pressure <= test pressure, remotely 5K psi wellhead, pump knock out 4050 psi, GORV 4250 psi CDW valve controlled shut-in device plans. IA PRV set as 2250 psi. line test pressure of 5500 psi. 6/14/2019 (e) Confinement Frac fluids confined to approved Provided with application. CDW formations 6/14/2019 (f) Surface casing Monitored with gauge and pressure relief i IA PRV set at 2250 psi. Surface annulus open. CDW pressures device 6/14/2019 (g) Annulus pressure monitoring & notification (h) Sundry Report (i) Reporting 500 psi criteria (g)(I) Notify AOGCC within 24 hours (g)(2) Corrective action orsurveillance IA popoff pressure to be set to 2250 psi per planned sundry MGR program. 6/20/2019 (9)(3) Sundry to AOGCC Sundry request 319-292 received at AOGCC on June 11,MGR 2019. 6/20/2019 FracFocus AOGCC Page 6 June 20, 2019 20 AAC 25.283 Hydraulic Fracturing Application — Checklist PBU 5-105A (PTD No. 219-032; Sundry No. 319-292) Paragraph Sub -Paragraph Section (i)(2) AOGCC Reporting: printed & electronic (j) Post -frac water sampling plan (k) Confidential Clearly marked and specific facts information supporting nondisclosure (I) Variances Modifications of deadlines, requests for requested variances or waivers No plan for post fracture water well analysis. Commission may require this depending on performance of the fracturing operation. Complete? AOGCC Page 7 June 20, 2019 r Y CL u N ai rn t N V I � � M V � � Q on N = N L M 7 LL fV0 Q1 v_ G .5 Z L �i c CL A ooLn 01 O a Ln N H N Q m Q a O N 0 N O N W C $ C L C � w w w a 3 0 q> ry N ]LLR I I ' � {��, �P'!Vi�,�,.... M;4v.�J ro , 1� � ; 1T•'�+!"'�W'.�`.+:^.'�,.�'��. ..;moi 3 G C j, ly C ^ $ �^m $LL'wn li' ikw„T _ 1.. ,4iU ti.,� f +, �. irb . - ... __. �iY w h^•-.. ���yg �J 0$JNe RLLQ 9i 1111111^ 1 I fl E 1 I N I I' �j�i,fY. 1 1: Il llli!It:11111 Il �1i' i Ilfl 1 111111 i 1 1513! 11)1 �Iltl lt:l )i 1 1 ��,iil k�a�h: 362N ! ,.X..:.fC✓ ,l ��.�Y ^ ' Z F' $ C L C � w w w a 3 0 q> ry N ]LLR I I N F v V u V Q ro 3 G C j, ly C 0 $ $LL'wn li' ikw„T _ 1.. ,4iU ti.,� f +, �. irb . - ... __. �iY w h^•-.. ���yg 1 ''i �„ tl l,5 Vi1 ,,,�„ ;it �nui�'�•l ul lli n,'<1 i1 ',1 �� �1 i 1 ; N F v V u V Q d Y !ti CL E O u c O N t CL N a d in .0 CL m WD m m m CL 091'.. OOZ'lt uw2{a n � M2a uRI• 9661 08-1 MCv Jowlw1onpo- -w-i- OVS'Ot~ 09t-01 ,Wit 2662 091 _ - NZ6•- --- luon0npad- UIE' OOSL ocv9 •.pllnnr 896;E OBS p° Z 1 Bol uo'ta"Po'd Z!_l v 4 otic • Ovz1 _ 91Z 9 OR" n9Z � 6u'se;; uononpo,-d ,;t 060E OSLS1 �E99 09" ppb- 6u-se3OW0S..8146 'Kd'mdepo0 pd hung ' 01 • ope,g µ16lam- -- oxlg/owop otU A•te•i aam{ uq,wR2u.aw LaR <ru{ a.uj •v�vf 2.Mwr(` .Iw Al•o m,w2r<..� rl � { .•••lw "TEEM VSO VS t � � Al . 21fIY iT2a (21(fl t I awV '.M-J<I, ___-- OOt .YCZ 1t.YIZ sou O.9K 1 . a Wnwum Ml__ __a•. -O Trww gra vo.•r Il I� Al -n ae L.<OOt, .r JN2-u It 2tf.r w, at. %1. 1. uw2{a n � M2a uRI• F2 1 Dvn rrwotr w.ae2l ,w<'wni. w. w......w(n R•srw•w •w rR{ ''. an o.tM .wool lr 2aar ,Wit ' I2a2.xbee,eMM W,,. wn •Nur Rw •v�vf 2.Mwr(` .Iw Al•o m,w2r<..� rl � { .•••lw "TEEM VSO VS t � � Al . 21fIY iT2a (21(fl t I awV '.M-J<I, ___-- OOt .YCZ 1t.YIZ sou O.9K 1 . a Wnwum Ml__ __a•. -O Trww gra vo.•r Il I� Al -n ae L.<OOt, .r JN2-u It 2tf.r w, at. %1. 1. MCMI •CN��D avo.ta -r.vw ,Wit ..o• wn •Nur Rw ND<q •.pllnnr {+OMeil WAS !1 '9n2{{/I' 18 '9'E8Z SZ MVV OZ) ogeulogag pue uejngn j 10 sbuge8 0lnss0ld olemOaV W ho a Mel, As discussed, well S -105a is a CTD sidetrack. The parent well, S-105, was abandoned by the CTD rig prior to drilling the coil lateral: • Whipstock set @ 7646' • Coil layed in 12 bbls of cement then displaced to perforations. • Coil then proceeded to mill the window then drill the lateral after which they ran the liner and cemented in place. The coil lateral and planned stage two frac is right next to the parent wellbore: Per above, the stage two frac will essentially re -access the original well frac. There are no other horizons open to the parent wellbore. So in the likely event that the new second stage frac penetrates the parent S-105 wellbore, there will be no consequences Printed 5/9/2019 8'.49'.06AM —A11 depths reported in Drillers Depths" North America - ALASKA - BP Page 4 64 Operation Summary Report Common Well Name: 5-105 AFE No Event Type'. RE-ENTER- ONSHORE (RON) Stan Date. 4/14/2019 End Date: 4/21/2019 X3 -019C8 -C'. (2,416,770 00 ) Project: PBU Site: S Rig Name/No.'. COR -2 Spud Date/Time'. 10/25/2000 12'.00'.00AM Rig Release: 4/2712019 Rig Contractor NABORS ALASKA DRILLING INC BPUDI. USA00000133 Active datum KB @65.08ust (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Descrtption of Operations (h4 (usft) 04.30 - 08:00 3.50 RIGU P 7.693.00 PRE MIX HI VIS QUICK DRILL N PILL 15 BBLS PUMP AT 2 BPM IN AND 1 TO 1 BPM OUT. WITH PILL AT NOZZLE SHUT IN AND BULLHEAD 10 BBLS AT 0.5 BPM AFTER 10 BBLS SQUEEZED OPEN CHOKE, CIRCULATE 0.5210 35 BPM. BRING RATE UP TO 1.0510 74 BPM BRING RATE. UP SLOWLY TO 1.510.97 BPM, PUMP A BIU FROM 7680'. 0800 - 1030 2.50 RIGU P 7693.00 PRE PURGE CT RISER WITH BRINE OUT TO TIGER TANK, BRING RETURNS INSIDE, ESTABLISH 10 MIN LOSS RATE. PUMP 1.01/0.63 BPM, LOSS OF 4 BBLS OVER 10 MIN. POOH. AT 10:00 SWAP POWER TO HIGHLINE. 1030 - 11:30 1.00 RIGU P 7,693.00 PRE TAG STRIPPER. PUMP 1.0 / 0.67 BPM FOR 10 MIN TO ESTABLISH LOSS RATE. M1U COILTRAK WHILE WAITING, WITH BHA HANGING MOVE INJECTOR OFF WELL INJECTOR OFF AT 11:00 ATTACH NS WHIPSTOCK AND RUN WHIPSTOCK BHA IN. FILL WELL 2 TIMES WHILE INJECTOR IS OFF. INJECTOR ON AT 11'.20. 11.30 - 15.00 350 WHIP P 7.693.00 WEXIT RIH WITH BHA 92, WHIPSTOCK BHA. CIRC THROUGH OPEN EDC SET PUMP TRIPS LOW. ON LOSSES WHILE RIH, 0 5210 42 BPM @ 330 PSI. LOG GR DOWN FROM 7250', CORRECT 4 CONTINUE RIH TO 7660'. FLAG PIPE HERE (EDP = 7590.5') LOG CCL UP FROM 7660'. BHI CCL MATCHES THE ONE IN THE OCN. DISCUSS RESULTS WITH ODE. NO CORRECTION BASED ON CCL. 15 00 17:00 2.00 WHIP P 7,693.00 WEXIT RIH TO DEPTH OF 7654.8' AND OL TF, PLACES TOP WHIPSTOCK AT 7646' AND PINCH POINT AT 7650'. CLOSE EDC AND PRESSURE UP TO 2200 PSI TO SET WHIPSTOCK. FOLLOWING SET, OPEN EDC. POOH. PUMP 1.00/038 BPM WHILE POOH. Printed 5/9/2019 8'.49'.06AM —A11 depths reported in Drillers Depths" North America -ALASKA - BP Operation Summary Report Page 61 Common Well Name. S-105 AFE No Event Type-. RE-ENTER- ONSHORE (RON) Start Date: 4/14/2013 End Date. 4121/2019 X3 -019C8 -C. (2,416,77000) Project. PBU Site: S Rig Name/No.. CDR -2 Spud Date/Time10125/2000 12:00-00AM Rig Release 4/27/2019 Rig Contractor. NABORS ALASKA DRILLING INC. BPUOI". USA00000133 Active datum. KB g65.08usft (above Mean Sea Level) Dale From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usR) 4117/2019 00.00 - 02'.30 2.50 WHIP P 7,693.00 WEXIT CEMENT WHIPSTOCK -HOLD PJSM WITH ALL INVOLVED CREWS -BULL HEAD DOWN COIL 3 BELS FOR A TOTAL OF 6 BBLS WITH 1600 PSI PUMP PRESSURE / WELLHEAD PRESSURE 350 PSI. AWAY AND HESITATE FOR 15 MINUTES. -BULL HEAD DOWN COIL.5 BBLS FOR A TOTAL OF 6.5 BBLS WITH 1500 PSI PUMP PRESSURE / WELL HEAD PRESSURE 300 PSI LEAVING TOP OF CEMENT AT 7636' (10' ABOVE TOP OF WHIPSTOCK) -SLOWLY BLEED PRESSURE OFF AND OPEN CHOKE. -BRING PUMPS ON TO 1.5 BPM IN / 1.38 BPM OUT AT 2680 PSI -RIH TO 7086OBSERVE INCREASE IN LOSS PRA A ALL ODE _ _ BACK TO 8600�TT MUM RATE AND WAITAITIONAL 75 MINUTES. AGREED PLAN TO CONTAMINATE 'RIH AT MINIMUM RATE TO STIR CONTAM PILL THROUGH WHERE TOP OF CEMENT WAS LEFT PRIOR TO SQUEEZING TO TUBING TAIL. POOH AT PIPE DISPLACEMENT PLUS 0.1 TO 0 2 BPM. -RIH FROM 6600' TO 7590' PUMPING AT 0.2 BPM IN 10 15 BPM OUT AT 40' PER MINUTE WITH CONTAMINATE STILL COMING OUT PIPE. -AT 7590' LOSE RETURNS INCREASE PUMP A 00.5 NUTRATE OF 15 BPM CONTINUE TO RIH TO 7624' AT 20 FPM. 02:30 - 0600 3.50 WHIP P 7,69300 WEXIT POOH FROM 7624' TO 9' AT 7624' POOH PUMPING AT 65 BPM IN / 18 BPM OUT AT 20 FPM WITH CONTAMINATE COMING OUT OF PIPE UNTIL 7200' THEN FOLLWED BY 9.0 PPG BRINE. INCREASE PULLING SPEED AND DECREASE PUMP RATE AS LOSS RATE DECREASES MAINTIA_N1NG O flpE-DISPLACEMENT AT 5000' -SHOWING NO LOSSES INCREASE PUMP RATE SLOWLY TO ATTEMPT TO MOVE CONTAMINATES UPHOLE WITH BETTER ANNULAR VELOCITY. PUMPINGAT 1 BPM IN! li 0.78 OUT AT 60 FPM 7.6 BBLS LOST ON TRIP. -CHECK FOR LOSS RATE! FLOW CHECK -RETURNS i FOR 1. CHECK FLOW NO FLOW. 06:00 - 07:30 1.50 WHIP P 7,693.00 WEXIT INSTALL FLOATS IN UQC. PRESSURE TEST UQC AND FLOATS, GOOD 07:30 - 09'.00 1.50 WHIP P 7,693.00 WEXIT M/U BHA #4 MAKE UP 2 74" MILLING BHA M - PICK UP 1 DEG FIXED BEND WFT MOTOR AND 2-3/8" COILTRAK TOOLS - SURFACE TESTED COILTRAK TOOL. GOOD TEST. - PRESSURE TEST OTS TO 3,500 PSI HIGH FOR 5 MINUTES -INJECTOR ON 08:45 Printed 5/9/2019 8:49:06AM "All depths reported in Drillers Depths" 4-1/8' CAN FLS WELLHEAD'- 11--Sm1mCUrlra SHGenS 7593 4CTL14TOR= CNV W-60 w /XO PUPS to 3-1/2'. D = 3 875' -_— ___._-____..__.____6_50 - Note 3F. ELEV = 37.91' SPF (Op.= 1500' DATE Vex Argle' --- 37° @ 4438' 7650-7670 tum ND = 7637' 2-12' ]atum TVD= 6700' SS S 4-1/2' TBG, 12.64, L.60, .01522 bpf, D = 3.958' - 69' 6 TOP OF 3-1/2' TBG, D = 2.992' - 71' 9 5/8' CSG, 40#, L-80 M BTC, D = 8.835' - 2996' Minimum ID = 2.75" @ 2106' HES X NIPPLE 3-12' TBG, 9.24, L -80 -EVE, .0067 bpf, D = 2.992' NS HIGH EXPANSION WEI w/RA TAG (04/16/19) 1 7630' F[ar:y FLOAT COLLAR -PBTD 7' CSG, 26#, LAOATC, MOD, 0383 bbU6, ID =6 276' - 8103' 7- FLOAT SHOE 8103' S-105 SAFETY NOTES: 69' -4-1/2'X3-1/2'X0, D=2.992' 994' TAM PORT COLLAR 2106' -3 -1/2 -HES X NP, D=2.750' PERFORATION SUPMMRY 7593 Rff LOG. SPERRY DGR MWD ON 1025100 11110/00 w /XO PUPS to 3-1/2'. D = 3 875' ANGLE AT TOP PERF: 25 -@7650 5"@7650'Note: - Note Refer to Production DB for historical pert data SEE SPF 0JTERVAL OprVSgz DATE 2-1/2' 6 7650-7670 S 04/17/19 2-12' 6 7665-7685 S 04/17119 2-1/2' 6 7682-7702 C 05/12/02 2-1/2' 6 7712-7722 C 05/12/02 FLOAT COLLAR -PBTD 7' CSG, 26#, LAOATC, MOD, 0383 bbU6, ID =6 276' - 8103' 7- FLOAT SHOE 8103' S-105 SAFETY NOTES: 69' -4-1/2'X3-1/2'X0, D=2.992' 994' TAM PORT COLLAR 2106' -3 -1/2 -HES X NP, D=2.750' 7692 761 S' -3-1/2'X4-1/2'X0. D=2.992' 7593 GAS LIFT MANDRELS 11110/00 w /XO PUPS to 3-1/2'. D = 3 875' ST ND TVD DEV TYPE VLV LATCH PORT DATE 3 4129 3775 32 CAWMvM DMY RK 0 03/13/19 2 6631 5877 29 CAWMIA I DMY RK 0 03/13/19 1 7475 6620 27 CAM -M M DMY RK 0 03/13/19 — 7668' - 3 112' HES X NP, D = 2.750' 7692 761 S' -3-1/2'X4-1/2'X0. D=2.992' 7593 - 7- X 4-112' BAKER S-3 PKR 11110/00 w /XO PUPS to 3-1/2'. D = 3 875' 7597 .992' -4-1/2'X3-112'X0, D=2.992- 7619'-3-112'HES X NP, D=2.750' _ r • TT 014/04/19 XT, I'M l' 1111111111111111111 7687 -FISH-2.75*X KEY (LEFT 1111111111111111111 111111111111111111 � 1111111111111111111'' a 1111111'1/111/1111 11111, .-1�1�1.1�1 08/10106: TAGGE. 04 104119) DATE REV BY COMMENTS DATE REV BY COMMENTS 11110/00 ORIGINAL COMPLETION 02/19/19 GJB/JMD SETX-LOCK WFLOWTHRU SUB &GAUGES 12/17/06 JCM/PJC GLV GO (12/12/06) 02rM19 GJB/JMD ADDED XO's ABOVE & BELOW PKR 05/31109 PJC/TLH ONE FISH REMOVED 1127/D6 032&19 JMG'JMD PULLED FLOW THRU SUB & GJAGES 1125/15 RC T/JMD SET PX PLUG (11/19/15) 0328/19 GJB/JMD GLV C/O (03/14119) 12/10/15 DU/JM[) TREE C/O (12103/15) 04/10/19 TFA/JMD+ ELHD LOGFISH DEPTH, -CSG BBLS(04AM19) 0127/16 GT1/14JMD PULLED PX PLUG (01/10116) AURORAUNIT WELL S-105 PERMR No: 2001520 API No: 504)29-22977-00 SEC 35, T12N, R12, BP Exploration (Alaska) STATE OF ALASKA 'LASKA OIL AND GAS CONSERVATION COMMISF'—N WELL IMPLETION OR RECOMPLETION REPOS AND LOG MAY 0 9 inin la. Well Status: Oil ® Gas ❑ SPLUG ❑ Omer ❑ Abandoned ❑ Suspended ❑ 1b. Well Class. 20AAC 25.105 20AAC 25.110 Development g-E-irp)omfor f`k❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL 11 No. of Completions: One , B Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Aband.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 4/27/2019 219-032 3. Address: 7. Date Spudded: 15, API Number: P.O. Box 196612 Anchorage, AK 99519-6612 4/17/2019 4 50-029-22977.01.00 4a. Location of Well (Governmental Section): 8. Date TO Reached, 16. Well Name and Number: 4/21/2019 PBU S -105A r Ref Elevations 17. Field/Pool(s): Surface: 4631'FSL, 4496' FEL, Sec. 35, T12N, R12E, UM ' 9 KB 65.08 t Top of Productive Interval: 2491' FSL, 4344' FEL, Sec. 26, T12N, R12E, UM GL 35.41 . BF 37.91 PRUDHOE BAY, AURORA OIL 10. Plug Back Depth(MD/TVD). 18. Property Designation: Total Depth: 4073FSL, 2798' FEL, S.C. 26, T12N, R12E, UM . 10545'/ 6874' ADL 028257 1 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 618930 y- 5980835 Zone - ASP 4 10559-16876' ' 83-47 12, SSSV Depth (MD/TVD): PO Thickness of Permafrost MDTVD: TPI: x- 619027 y- 5983977 Zone - ASP 4 Total Depth: x- 620546 y- 5985583 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes ® (attached) No ❑ 13. Water Depth, if Offshore: 21, Re-drill/Lateral Top Wndow MDrrVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 7652'16779' 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, chpmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MWD/GR/RES 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H<o 28' 107' 28' 107' 30" 260 as Arctic Set (Approx.) 9-5/8" 40# L-80 28' 2996' 28' 2833' 12-1/4" 405 sx AS Lite III, 240 sx Class'G' 7" 26" Lao 26' 7652' 26' 6779' 8-3/4" 497 sx Class *G' 2-3/8" 4.7# L-80 7599' 10559' 6731' 6876' 3-1/4" W sx Class 'G' 24. Open to production or injection? Yes m No ❑ 25. TUBING RECORD GRADE DEPTH SET (MD) PACKER SET (MD/TV If Yes, list each interval open (MDnVD of Top and Bottom; Perforation Size and Number; Date Pend): 3-1/2" 9.2# L-80 7631' 7593'16726' 1.56" Gun Diameter, 6 spf 4/25/2019 8220'- 8950' 6853'- 6842' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9875'- 10170' 6857'- 6852' COMPLETION Was hydraulic fracturing used during completion? Yes 11 No M Per 20 AAC 25.283 (i)(2) attach electronic and printed D T�Er information H T lza DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 2500' Freeze Protect wl 22 Bbls Diesel 27. PRODUCTION TEST Date First Production: May 8, 2019 Method of Operalion (Flowing, gas lift, etc.): Gas Lia Date of Test 5819 Hours Tested: Produdion for OI4Bbl: Ge MCF: Water -Bbl: Choke Size: Gas -Oil Ralior 12 Test Period �► 134 1376 84 176 11072 Flow Tubing 230 Casino Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravitv - API(cord: Press 1275 24 Hour Rate —► 268 2751 188 NIA Forth 10.407 Revised 52017 CONTINUED ON PAGE 2 Submit ORIGINAL only 'er7-B 517,3/lg le��y M&P-13A%Yq3BDMSL6%/ MAY 10 2019 (i 28. CORE DATA I Conventional Core(s) Yes ❑ No 0 I Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 0 Permafrost - Base ` If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 Top of Productive Interval 7632' 6781, AAC 25.071. Kuparuk C4 7632' 6761' Kicked off from Parent Well 7652' 6779' Kuparuk C3 7662' 6788' Kuparuk C2 7676' 6800' Kuparuk Cl 7768' 6865' Kuparuk C2 (Invert) 8063' 6681' Kuparuk C3 8338' 6831' Kuparuk C4 8386' 6822' Kuparuk C3 (Revert) 10400' 6862' Formation at total depth: Kuparuk C3 10400' 6862' 31. List of Attachments: Summary of Daily Drilling Reports, Survey, Cement Report, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inctination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Ciolkosz, Ryan R Authorized Title: SI Sp ialisl Contact Email: Ryan.Ciolkosz@bp.com Authorized Signature: Date: '5/1/11 Contact Phone: +1 907 564 5977 INSTRUCTIONS - General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases 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 Disp, Water Supply for Injection, Observation or Other. Item 41b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level 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 20. Report true vertical thickness of permafrost in Box 20, 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 coretl and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071, 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 512017 Submit ORIGINAL Only Tfam= W13LFEAD---I 1 D = 3.958' D = 8.835' Minimum ID = 1.995" @ 7605' 2-7/8" X 2-3/8" XO ' TOG, 9.29, L4W-EVE, BRC bpf, D = 2.992' HIGH EXPANSDN WEDGE to TAG (04116/19) 80 -BTC, MOD, D = 6.276' PEF FORATDN SUAMARY FEF LOG: BH MWD LOGON 04/21/19 ANGLEAT TOP PERR 101' La) 8220' N1te: Refer to Production DB for historical pert data SIZE SPF MERVAL Opn/Sgz DATE 1.56' 6 8220 - 8950 O 04/25/19 1.56' 6 9875-10170 O 04/25/19 2-318' LNR, 4.74, L-80 HY D511, .0039 bpf, D = 1995'. SAP'—'Y NOTES: WELL ANGLE> —70" L 7815'. S -10 5 A "1A S:29-076.5- 117 1 IT F 69' 4-1/2'X3-1/2'XO, D=2.992' GAS LIFT MAN]RELS STI MD I TVD I DEV I TYPE VLV I LATCH I PORE I DATE 3 05/09/19 GJB/JMD GLV aO(051=19) 32 05!09/19 JNL/JMD ADDED OKS & BF DOME RK 16 05/06119 2 �4129�3775� 6631 5877 29 ICAM4AMI CAMWIVM SO RK 20 05/06119 1 1 7475 6620 27 CAM4&W DW RK 0 03113/19 7508• —j3 -1/2 -HES X NP, D=2.750' 76923-1/2• X 4-112' XO, D = 2.992' 7593 17'X4 -V2' BAKER S-3 PKR w /XO PUPS to 3112', D = 3.875• 7597 �4-1/2'X3-1/2'XO,D=2.992' 76� 2.70' DEPLOY SLV. D = 2250' 7620 9NDTr NOTAVALABLE MILLOUT WINDOW (S-IO6A) 7652' - 7655' DATE REV BY COWANTS DATE REV BY COWAR TS 11/10/00 ORIGINAL COMPLETION 04/27/19 N-CDR2 CTDST(S-105A) 05/01/19 JMD DRLG DRAFT CORRECTME 05/09/19 GJB/JMD GLV aO(051=19) 05!09/19 JNL/JMD ADDED OKS & BF ARRA UNIT WELL: S -105A PERMT No: 219-032 AR No: 50-029-22977-01 SEC 35, T12K R12, SP Exploration (Alaska) Printed 5/9/2019 8:49:06AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 1 of 13 Operation Summary Report Common Well Name. S-105 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 4/14/2019 End Date: 4/21/2019 X3-019C8-C: (2,416,770.00 ) Project: PBU Site: S Rig Name/No.: CDR-2 Spud Date/Time: 10/25/2000 12:00:OOAM Rig Release: 4/27/2019 Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.08usft (above Mean Sea Level) _ Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _ _ _ waft) 4/14/2019 0400 - 21:30 17.50 RIGU P PRE MOVE RIG FROM 1_2-07B TO S-1 05A - PJSM FOR MOVING RIG WITH PEAKAND NABORS CREWS. - MOVE RIG OFF WELL L2-07B -INSTALL JEEPS - MOVE RIG TO S-1 05A - TAKE OFF JEEPS -SPOT STOP BLOCK - VERIFY TREE VALVES CLOSED -SPOT SUB OVER WELLAND SET DOWN - SPOT PIT MODULE AND SET DOWN '- RIG ACCEPTED AT 2130 NOTE: INSTALLED LOCKS AND TAGS ON WINGS AND SWABS ON S PAD WELLS 104 _ 'AND. 124 21:30 - 00:00 2.50 RIGU P PRE 'RIG UP -WORK THROUGH RIG UP CHECKLISTS j - HOOK UP STEAM AND PIPING, ELECTRICAL LINES INTERCONNECT - VERIFY STEAM HEAT THROUGHOUT THE RIG �- SPOTAUXILIARY EQUIPMENT RIG UP MP LINE 4/15/2019 00:00 - 02:00 2.00 RIGU P PRE�'i RIG UP I- COMPLETE RIG UP CHECKLISTS �- LEAK TIGHT TEST SWAB AND MASTER VALVES, GOOD. 02:00 - 07:00 5.00 RIGU P PRE NIPPLE UP BOP -REMOVE TREE CAP - INSTALL BOPS. -INSTALL TURNBUCKLES ON BOPS. -MU TEST JOINT ASSEMBLY -FILL COIL WITH FRESH WATER - CHECK IN AND OUT MM RATESAND DENSITIES, CALIBRATE AND ZERO. AOGCC INSPECTOR BOB NOBLE CALLS AT 0650 AND GIVES PERMISSION TO PROCEED WITH BOP TEST. Printed 5/9/2019 8:49:06AM **All depths reported in Drillers Depths" North America -ALASKA - BP Operation Summary Report Common Well Name: 5-105 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 4/14/2019 End Date. 4/21/2019 X3-019CB-C: (2,416,770.00 ) Proieeh PBU Site: S Rig Name/No.: CDR -2 Spud Daterrme: 10/25/2000 12:00 OOAM Rig Release: 4/27/2019 Page 2 of 13 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.08usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _ (usft) _ _ ,07:00 - 14:00 7.00 BOPSUR P PRE FLUSH LINESFOR BOP SHELL TEST. GOOD SHELL TEST TO 4500 PSI. TEST WITNESS WAIVED BY BOB NOBLE. ALL TESTS TO 250 / 3500 PSI, TEST 1: IRV, RACKOFF, C9, CIO BACKWARDS -PASS TEST2: BLIND/ SHEARS, RI, BOA, BI,B4- PASS INSTALL TEST JOINT WITH SAVER SUB REMOVED. TEST 3: ANNULAR (2"), TIW#2, B3, B2, BL1 - PASS TEST4: UPPER 2-3/8" PIPE/ SLIPS, TIW #2, BL2, R2, T2, C15 - PASS TEST 5: CIO, T7, C11 - FAIL ON VALVE C4, LEAKING PAST THE GREASE PORT. TIGHTEN UP THE GREASE CAPAND RE -TEST PASS TEST 6: LOWER 2" PIPE / SLIPS, C7, C9, CIO, TV2-PASS TEST 7: C5, C6, C8, TV1 - PASS TEST B: CHOKE A, CHOKE C - PASS ACCUMULATOR TEST - PASS, TIMES .RECORDED TAKE OUT TEST JOINT AND INSTALL SUB TO MOVE 2-3/8" ACROSS ANNULAR AND VBR TEST 9: ANNULAR (2-3/8"), C1, C4- PASS TEST 10: VARIABLES -(2-3/8"), C2, C3 - PASS 1400 - 1500 1.00 BOPSUR P PRE RIG DOWN BOP TEST EQUIPMENT - REMOVE TEST RISERS AND INSTALL DRILLING RISERS - PUT INJECTOR ONAND CHECKTORQUE ON _ __ TREE BOLTS 1500 - 1530 0.50 __ _ __ _ BOPSUR P PRE H2S RIG EVAC EXERCISE WITH ROY CREW ALL PERSONS MUSTER AND ACCOUNTED FOR IN 3 MIN. CONDUCTAAR. 15:30 - 17:00 1.50 RIGU P PRE PRESSURE TEST RISER CONNECTION TO 250 14200 PSI, GOOD. INSTALL BHI FLOATS. PRESSURE TEST FLOATS TO 3500 PSI, GOOD_ 1700 - 21:00 4.00 RIGU P PRE FLUID PACK STACK TO PT VC LUBRICATOR -WORK THROUGH COMMAND AND CONTROL VALVE CHECKLIST -PRESSURE UP TO 250 FOR VISUAL LTT - GOOD LOW GO TO 3700 HIGH PT - GOOD PT, BLEED OFF AND OPEN UP TO TWC -TWC PULLED, 0 PSI ON WELL - CLOSE M 8 S VALVES, LTT 3500 PSI CONFIRMED -BLOW DOWN RISER AND REMOVE LUBRICATOR - LD TWC, BODY SEAL IS NOT ON PLUG, LOAD OUT Printed 5/9/2019 8:49:06AM **All depths reported in Drillers Depths** North America - ALASKA - BP Page 3 of 13 Operation Summary Report Common Well Name: 5-105 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 4/14/2019 End Date: 4/2112019 X3 -019C8 -C. (2,416 770.0(l ) Project: PBU Site: S Rig Name/No.: CDR -2 Spud Date/Time: 10/25/2000 12:00:OOAM Rig Release: 4/27/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB Q65.08usft (above Mean Sea Level Date From - To Hm Task Code NPT Total Depth Phase Description of Operations (hr) (usf) _ 21:00 - 22:30 1.50 RIGU P PRE BOTTOM HOLE KILL 0145 - 0300 1.25 0300 - 0430 1.50 RIGU P RIGU N 22:30 - 0000 1.50 RIGU P 4/16/2019 0000 - 01:45 1.75 RIGU P 0145 - 0300 1.25 0300 - 0430 1.50 RIGU P RIGU N Pnnted 5/9/2019 6.49-.06AM `•AII depths reported in Drillers Depths" -HOLD PJSM WITH CREW -MAKEUP NOZZLE BHA WITH CHECKS -MAKE UP INJECTOR AND TEST LUBRICATOR QTS TO 3500 PSI -GOOD TEST -DISPLACE FRESH WATER FROM COIL WITH 13 BBL MEOH SPEAR FOLLOWED BY 9.0 PPG I SLICK KCL -LINE UP TO TAKE RETURNS TO TIGER TANK -OPEN MASTER AND SWAB VALVE -0 PSI ON WELL _ 7.693.00 PRE RIH FROM SURFACE TO 4200' -PUMP 0.25 BPM IN BUILDING UP TO 100 PSI CHOKE PRESSURE THEN 0.45 OUT. -OBSERVE DROP IN OUT RATE, REDUCE CHOKE PRESSURE TOO PSI /WELL HEAD PRESSURE 35 PSI -DISCUSS WITH ODE AND DECIDE TO CONTINUE OPERATIONS. 7,693.00 PRE RIH FROM 4200 TO 7665' -PUMP O.74 BPM IN 0.17 OUT. SUP WT 35K DW WF 21K AT 7650' TAKE 2K WOB AT 7666' NOTE: OBSERVES DROP IN OUT RATE, REDUCE CHOKE PRESSURE TO 0 PSI , DISCUSS WITH ODE AND DECIDE TO CONTINUE OPERATIONS. MAINTAINING RETURNS NOTE:STOP TRIPPING FOR 15 MINUTES TO REMAKE CONNECTION ON INJECTOR WEIGHT INDICATOR. 7,693.00 PRE BOTTOM KILLTAKING RETURNS TO TIGER TANK -DISCUSS FLUID VOLUMES WITH ODE AND DECIDE TO START BOTTOM KILL —SHUT DOWN TO SWAP PITS AND UNABLE TO REGAIN CIRCULATION. -LINE UP DOWN THE BACKSIDE WITH CHARGE PUMP TO FILL WHILE PUMPING DOWN THE COILAT 0.3 BPM-TOOK6 BBLS TO FILL. -SWAP BACK OVER TO PUMPING JUST DOWN THE COIL ESTABLISH CIRCULATION AT 0.4 BPM SLOWLY INCREASE PUMP RATE IN INCREMENTS TO CHECK LOSS RATE.AT 2.5 BPM IN AT 2550 PSI, OUT RATE AT 1.15-DICUSS RESULTS WITH ODE -DECIDE TO WAIT FOR MUD COMING FROM MUD PLANT. 7.69300 PRE WAIT ON 9.0 PPG KCL/ NACL BRINE FROM MUD PLANT PUMP DOWN COIL TO MAINTAIN FULL FLUID COLUMN TAKING RETURNS TO TIGER TANK UNABLE TO MAINTAIN RETURNS, PULL UP HOLE ABOVE PERFS TO 7500' MD PUMPING DOWN COIL TO MAINTAIN WELL HEAD PRESSURE WITH CHOKE CLOSED.DISCUSS STATUS WITH WSUP AND ETLAND AGREE ON PLAN FORWARD. Pnnted 5/9/2019 6.49-.06AM `•AII depths reported in Drillers Depths" North America -ALASKA - BP Operation Summary Report Common Well Name: 5-105 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 4/14/2019 End Date: 4/21/2019 Protect: PBU - - Site. S - _— Rig Name/No.: CDR -2 Spud Date/Time: 10/25/2000 12:00:OOAM AFE No K3 -019C8 -C'.(2,416,770.00) Page 4 of 13 Rig Contractor. NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.08usR (above Mean Sea Level) Date From - To Hm Task Code NPT Total Depth Phase Description of Operations (hr) (usR) _ _ 04:30 - 08:00 3.50 RIGU P 7,693.00 PRE MIX HI VIS QUICK DRILL N PILL 15 BELS PUMPAT 2 BPM IN AND 1 TO 1 BPM OUT. WITH PILLAT NOZZLE SHUT IN AND BULLHEAD 10 BBLS AT 0.5 BPM AFTER 10 BBLS SQUEEZED OPEN CHOKE, CIRCULATE 0.52/0.35 BPM. BRING RATE UP TO 1.05 / 0.74 BPM BRING RATE UP SLOWLY TO 1.5 / 0.97 BPM, PUMP A B/U FROM 7680'. 08:00 - 10:30 2.50 RIGU P 7,693.00 PRE PURGE CT RISER WITH BRINE OUT TO TIGER TANK. BRING RETURNS INSIDE, ESTABLISH 10 MIN LOSS RATE. PUMP 1.01 / 0.63 BPM. LOSS OF 4 BBLS OVER 10 MIN. POOH. AT 10:00 SWAP POWER TO HIGHLINE. 10:30 - 11:30 1.00 RIGU P 7,693.00 PRE TAG STRIPPER. PUMP 1.0 / 0.67 BPM FOR 10 MIN TO ESTABLISH LOSS RATE. WU COILTRAK WHILE WAITING. WITH BHA HANGING MOVE INJECTOR OFF WELL. INJECTOR OFF AT 11:00 ATTACH NS WHIPSTOCKAND RUN WHIPSTOCKBHAIN. FILL WELL TIMES WHILE INJECTOR IS OFF, INJECTOR ON AT 11:20. 11:30 - 1500 3.50 WHIP P 7,693.00 WEXIT RIH WITH BHAN2, WHIPSTOCK BHA. CIRC THROUGH OPEN EDC, SET PUMP TRIPS LOW. ON LOSSES WHILE RIP, 0.52 / 0.42 BPM @ 330 PSI. LOG GR DOWN FROM 7250', CORRECT -9'. CONTINUE RIH TO 7660'. FLAG PIPE HERE (EOP = 7590.5') LOG CCL UP FROM 7660'. BHI CCL MATCHES THE ONE IN THE OCN. DISCUSS RESULTS WITH ODE. NO CORRECTION BASED ON CCL. 1500 - 1700 2.00 WHIP P 7,693.00 WEXIT RIH TO DEPTH OF 7654a'AND OL TF, PLACES CLOSE EDCAND PRESSURE UP TO 2200 PSI TO SET WHIPSTOCK FOLLOWING SET, OPEN EDC. POOH. PUMP 1.00 10.38 BPM WHILE POOH. Printed 5/9/2019 8A9:06AM ..All depths reported in Drillers Depths" North America - ALASKA - BP Page 5 of 13 Operation Summary Report Common Well Name: 5-105 AEE No Event Type: RE-ENTER- ONSHORE (RON) Start Dale. 4/14/2019 End Date4/21/2019 X3 -019C8 -C (2416,770,00) Project. PBU - - - Site: S - - - - Rig Name/No.: CDR -2 Spud Daterrime: 10/25/2000 12:00:OOAM Rig Release: 4/27/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.08usft (above Mean Sea Level) Date From - To Hrs Task i Code NPT Total Depth Phase Description of Operations (hr) _ _ _ (usft) _ - 7700 - 1830 1.50 WHIP P 7,693.00 WEXIT A7 SURFACE, PUMP 0.79 / 0.43 BPM FOR 10 MIN TO ESTABLISH LOSS RATE. LOSE 3.3 BBLS IN 10 MIN. MOVE INJECTOR OFF, TAKE OUT BHA IN ONE PICK. FILL WELL WITH 3.2 BBLS. BREAK DOWN WHIPSTOCK SETTING TOOL, STAND BACK COILTRACK REMOVE FLOATS FROM UOC. FILL WELL EVERY 10 MIN WITH 2 - 3 BBLS. LEAK TIGHT TEST UOC TO 3500 PSI FOR 5 MINUTES -GOOD TEST MAKE UP BHA #4 MAKE UP INJECTOR AT 1820 HOURS SET DEPTH AND TEST OTC TO 3500 PSI GOOD TEST. NOTE:FILLING HOLE EVERY 10 MINUTES :TAKING 3 BBLS TO FILL. _ 1830 - 2115 2.75 WHIP P 7,693.00 WEXIT RIH RIHAT60 FPM, PUMP RATE.441N/.38 OUTAT 202 PSI STOPAT EOP FLAG AND CORRECT -13 FEET TO 7599.53 BIT DEPTH RIH TO 7636' AND PAINT YELLOW FLAG NOTE: SLB PRESSURE TEST TO 3800 PSI OFFLINE -GOOD TEST. 21.15 - 00100 2.75 WHIP P 7,693.00 WEXIT CEMENT WHIPSTOCK -HOLD PJSM WITH ALL INVOLVED CREWS. -SLB BATCH UP 12 BBLS OF 15.8 PPG CEMENT, CEMENT BATCHED UP AT 2156 HRS -PUMP 5 BBLS OF SPACER -PUMP 12 BBLS OF CEMENTAT 1.5 BPM IN / 0.7 OUT 1750 PSI -PUMP 28 BBLS OF SPACER LEAVING 1 BBL OF CEMENT OUT SIDE OF COIL. AT 1.42 BPM IN / 0.76 BPM OUT 2300 PSI -POOH PUMPING CEMENTAT 1 TO 1 CEMENT OUT OF PIPE AT 6920' -POOH TO 6612' -BULL HEAD DOWN COIL 3 BBLS WITH 1200 PSI PUMP PRESSURE/WELLHEAD PRESSURE 100 PSI. AWAYAND HESITATE FOR 15 MINUTES. Printed 5/9/2019 8:49:o6AM **All depths reported in Drillers Depths** North America - ALASKA- BP Operation Summary Report Page 6 of 13 Common Well Name: 5-105 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date'. 4/14/2019 End Date: 4/21/2019 X3 -019C8 -C: (2,416,770.00 ) Project: PBU Site: S Rig Name/No.' CDR -2 Spud Date/Time: 10/25/2000 12:00:OOAM Rig Release: 4/27/2019 Rig Contractor. NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum. KB Q65.08us8 (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 4/17/2019 00:00 - 02:30 2.50 WHIP P 7,693.00 WEXIT CEMENT WHIPSTOCK -HOLD PJSM WITH ALL INVOLVED CREWS. -BULL HEAD DOWN COIL 3 BBLS FOR A TOTAL OF 6 BBLS WITH 1600 PSI PUMP PRESSURE / WELL HEAD PRESSURE 350 PSI. AWAY AND HESITATE FOR 15 MINUTES. -BULL HEAD DOWN COILS BBLS FOR A . TOTAL OF 6.5 BBLS WITH 1500 PSI PUMP PRESSURE / WELL HEAD PRESSURE 300 PSI. LEAVING TOP OF CEMENT AT 7636' (10' ABOVE TOP OF WHIPSTOCK) -SLOWLY BLEED PRESSURE OFF AND OPEN CHOKE. -BRING PUMPS ON TO 1.5 BPM IN / 1.38 BPM OUT AT 2680 PSI -RIH TO 7086' OBSERVE INCREASE IN LOSS RATE, REDUCE PUMP RATE AND CALL ODE TO DISCUSS, PULL BACK TO 6600' AT MINIMUM RATE AND WAIT AN ADDITIONAL 15 MINUTES. AGREED PLAN TO CONTAMINATE :RIH AT MINIMUM RATE TO STIR CONTAM PILL THROUGH WHERE TOP OF CEMENT WAS LEFT PRIOR TO SQUEEZING TO TUBING TAIL, POOH AT PIPE DISPLACEMENT PLUS 0.1 TO 0 .2 BPM. -RIH FROM 6600'TO 7590'PUMPING AT 0.2 BPM IN/ 0.15 BPM OUT AT 40'PER MINUTE WITH CONTAMINATE STILL COMING OUT PIPE. -AT 7590'LOSE RETURNS INCREASE PUMP RATE TO 0.5 BPM IN TO REGAIN OUT RATE OF .15 BPM CONTINUE TO RIH TO 7624' AT 20 _ FPM. 02.30 - 06'.00 3.50 WHIP P 7,693.00 WEXIT POOH FROM 7624' TO 9' AT 7624' POOH PUMPING AT .65 BPM IN /.18 BPM OUT AT 20 FPM WITH CONTAMINATE COMING OUT OF PIPE UNTIL 7200' THEN FOLLWED BY 9.0 PPG BRINE. INCREASE PULLING SPEED AND DECREASE PUMP RATE AS LOSS RATE DECREASES MAINTIANING 0.1 BPM OVER PIPE DISPLACEMENT. AT 5000' SHOWING NO LOSSES INCREASE PUMP RATE SLOWLY TO ATTEMPT TO MOVE CONTAMINATES UPHOLE WITH BETTER ANNULAR VELOCITY. PUMPING AT 1 BPM IN / 0.78 OUT AT 60 FPM 7.6 BELS LOST ON TRIP. -CHECK FOR LOSS RATE / FLOW CHECK -RETURNS 1 FOR 1, CHECK FLOW NO FLOW. 06.00 - 07.30 1.50 WHIP P 7,693.00 WEXIT INSTALL FLOATS IN UQC. PRESSURE TEST UQC AND FLOATS, GOOD 0730 - 09.00 1.50 WHIP P 7,693.00 WEXIT M/U BHA #4. MAKE UP 2.74" MILLING BHA#4 - PICK UP 1 DEG FIXED BEND WET MOTOR AND 2-3/8" COILTRAK TOOLS - SURFACE TESTED COILTRAK TOOL. GOOD TEST. - PRESSURE TEST QTS TO 3,500 PSI HIGH FOR 5 MINUTES ---INJECTOR ON: 08'.45 Printed 5/9/2019 8:49:06AM **All depths reported in Dnllers Depths" North America - ALASKA - BP Page 7 of 13 Operation Summary Report Common Well Name: 5-105 Event Type: RE-ENTER- ONSHORE (RON) Start Date. 4 /1 412 01 9 Project PBU Site: S Rig Name/No.: CDR -2 Spud Date/Time: 1025/200 Rig Contractor. NABORS ALASKA DRILLING INC. Active datum: KB @65.O1 (above Mean Sea Level) Dale From - To Hrs Task Code NPT (hr) _ 09:00 - 11:30 2.50 WHIP P 1130 - 13:00 1.50 WHIP P 13:00 - 20:15 7.25 WHIP P 20:15 - 22:30 2.25 WHIP P 22:30 - 23:15 0.75 WHIP P 23.15 - 0000 0.75 DRILL P 4/18/2019 00:00 - 00:30 0.50 DRILL P AFE No End Date. 4/212019 X3 -019C8 -C: (2,416,770.00 ) Rig Release: Total Depth Phase Description of Operations (u58) 7,693.00 WEXIT RIH RIH WITH 2.74' MILLING BHA #4 - RATE: 0.29 BPM IN, 0.59 BPM OUT. CIRC PRESSURE: 160 PSI — MUD WEIGHT: 9.03 PPG IN, 9.04 PPG OUT - WEIGHT CHECK AT 6600' IS 30K. - LOG DOWN FOR TIE-IN FROM 7300' WITH -11'CORRECTION RIH TO 7636' NO SIGN OF CEMENT. _ 7,693.00 WEXIT SWAP WELL TO DRILLING MUD. WAIT FOR 13:00 FOR CEMENT TO REACH _ 1000 PSI COMPRESSIVE TO START MILLING. 7,664.00 WEXIT CLOSE EDC. LIGHT TAG AT MIN RATE AT 7650'. PICK UP AND GO TO 1.82 / 1.47 BPM EASE DOWN AND START MILLING WINDOW. FREE SPIN = 3200 PSI IN RATE = 1.81 BPM OUT RATE = 1.68 BPM IAP = 317 PSI OAP = 36 PSI WOB=1.38K TO 1.64K WOB DROPPED OFF AT 7653' BOW -MILL RAT HOLE TO 7654 - RAT HOLE MILLED,- PUMP 5 BBL HI VIS SWEEP PU AND START REAMING PASSES AT 130' L, 30° RAND 180' - DRY DRIFT WINDOW. -PAINT FLAG FOR BOTTOM OF RATHOLE (10280.28 EDP) NOTE:: AT BOTTOMS UP FOR 7654' SAMPLE SHOWED 90% FORMATION _ 7,664.00 WEXIT POOH - OPEN EDC -MONITOR WELL FOR 10 MINUTES: LOSSES 6 BPH AT BPM .22 !- MUD WEIGHT: 9.12 PPG IN ,9.04 PPG OUT - RATE: 2.0 BPM IN,1.7 BPM OUT PRESSURE 2820 PSI 7,664.00 WEXIT LD WINDOW MILLING BHA #4: -MONITOR WELL FOR 10 MINUTES AT BHA: STATIC -HOLD PJSM WHILE MONITORING WELL - CLOSE EDC, POWER DOWN - INJECTOR OFF:2245 - 2.74" GO / 2.73" NOGO ON WINDOW MILL. _ REAMER 2.74" GO 12.73" NOG_O _ 7,664.00 PRODi MAKE UP 3-114" BUILD BHA#5 -HOLD PJSM - PICK UP 2-3/8' ULS MOTOR (1.8 DEG AKO) AND 2 318" COILTRAK TOOLS - MAKE UP HYCALOG 3-114° BICENTER BIT 7,664.00 PROD? - SURFACE TESTED TOOL. GOOD TEST. - PRESSURE TEST QTS TO 250 PSI LOW FOR 5 MINUTES 13500 PSI HIGH FOR 5 MINUTES - CHECK TORQUE ON SADDLE CLAMPS ON REEL -INJECTOR ON:000OHRS Printed 5/9/2019 8.49.06AM **All depths reported in Drillers Depths" North America - ALASKA- Blo Operation Summary Report Common Well Name: S-105 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 4/14/2019 End Date: 4/21/2019 AFE No (2,416,770.00) Page 8 of 13 Project: Pau Site: S Rig Name/No.: CDR -2 Spud Date/Time: 10/25/2000 12:00:00AM Rig Release: 4/27/2019 Rig Contractor NABORS ALASKA DRILLING INC. BPUOI: USA00000133 _ Active datum: KB @65.08usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _ _. (usft) _ 10030 - 0230 2.00 DRILL P 7,664.00 PROW RIH WITH 3-1/4" BUILD BHA#5 - RATE:.41 BPM IN, 47 BPM OUT. CIRC 1, PRESSUREA17 PSI - MUD WEIGHT: 9.05 PPG IN ,9.05 PPG OUT - LOG FROM 7265' TO 7301 CORRECTION -10' _ 02:30 - 05:00 250 DRILL P 2664.00 PROD? DRILL 3.25' BUILD FROM 7674MD TO 7767' - FREE SPIN:2843 PSI, 1.6 BPM '- RATE: 1.6 BPM IN, 1.5 BPM OUT. CIRC PRESSURE:2900 - 2960 PSI - MUD WEIGHT: 9.12 PPG IN, 9.06 PPG OUT, ECD: 10.44 PPG - WEIGHT ON BIT 1-2K NOTE: TIE IN TO GEO PDC AND RA TAG CORRECT +2' PUTTING RA TAG AT 7655' AND TOW 7652' 0500 - 2045 15.75 DRILL P 8,100.00 PROD1 DRILL 3.25" BUILD SECTION FROM 7767' TO FOB 8100' - FREE SPIN:2843 PSI, 1.6 BPM - RATE: 1.6 BPM IN, 1.5 BPM OUT. CIRC PRESSURE:2900 - 2960 PSI MUD WEIGHT: 9.13 PPG IN, 9.06 PPG OUT, ECD: 10.44 PPG - WEIGHT ON BIT 1-2K FIRST SURVEY SHOWS WE CAME OUT OF THE WINDOW TO THE LEFTA LITTLE, THIS WILL EXTEND OUR BUILD LANDING -122' - SLOW ROP DRILLING STARTING AT 7820, GEO SAYS WE DRILLED INTO SOME GLAUCONITE, ANCHORAITE AND PYRITE NOTE: RES TOOL QUIT WORKING AT 7910'-8100' 2045 - 0000 3.25 DRILL P 8,100.00 PROD1 BUILD LANDED - 5X5 LOW/HI VIS SWEEP AT BIT AT TD OF I BUILD SECTION. - PERFORM 150' WIPER TRIP AND CIRCULATE THE OH CLEAN - 10 MINUTE DYNAMIC FLOW CHECK WELL -GOOD - POOH TO THE WINDOW - OPEN EDCAND POOH AT 2 BPM -ATTEMPT TIE IN AND CCL LOG FROM 7540' TO 7700'. TAGGED TOW WITH 5K, PU AND RUN THROUGH CLEAN. CCL DATA CORRUPT MAKE DECISION TO PERFORM CCL ON WAY IN HOLE WITH LATERAL BHA. 4/19/2019 00:00 - 01:30 1.50 DRILL P 8,100.00 PROD? POOH 1 -AT SURFACE, JOG IN HOLE 200', PU THEN FLOW CHECK AT 50' - REVIEW BHA HANDLING PROCEDURE WHILE FLOW CHECKING - GOOD NO FLOW CHECK, PU THE INJECTOR - INJECTOR OFF AT 0100, CHANGE OUT BHA - BIT GRADE = 1-11 PN -CONSIDER FOR RE RUN ON NEXT BUILD SECTION _ 01:30 - 02:30 1.00 DRILL P 8,100.00 PROD? BHA MU WITH 0.9° MOTOR, INJECTOR ON AT 0220 - PT THE QTS AND RIH TO 500' -GOOT TEST ON QTS - CLOSE EDC AND TEST AGITATOR GOOD - EDC WOULD NOT CLOSE Printed 51912019 8 49 06A **All depths reported in Drillers Depths" 16:15 - 18:00 1.75 DRILL P 8,813.00 PROD1 DRILLING LATERAL SECTION FROM 8550'-8813' - FREE SPIN: 3648 PSI, 1.77 BPM - RATE: 1.77 BPM IN, 1.75 BPM OUT. CIRC PRESSURE: 3842 PSI - MUD WEIGHT: 9.21 PPG IN, 9.24 PPG OUT, ECD: 10.24 PPG - WEIGHT ON BIT 1- 2.75 K -150' WIPER TRIPS AS NEEDED WITH ATRIP TO ABOVE WINDOW EVERY 450' Primed 5/912019 8:49:06AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 9 of 13 Operation Summary Report Common Well Name: 5-105 AEE No Event Type: RE -ENTER -ONSHORE (RON) Start Date'. 4114/2019 Ertl Date. 4/21/2019 X3 -019C8 -C'. (2,416.77000) Project PBU Site: S Rig Name/No.: CDR -2 Spud Daterrime: 10/25/2000 12:00:OOAM Rig Release: 4/27/2019 Rig Contractor NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB §65.08usft (above Mean Sea Level) Date From - To His Task Code NPT Total Depth Phase Description of Operations — —. (h0 _ _ (usft) 02:30 - 03:45 1.25 DRILL N 8,100.00 PROD? POOH FOR EDC -POOH - FLOW CHECK - INJECTOR OFF AT 0300 - REPLACE EDC IN BHA - INJECTOR ON AT 0345 - PT THE QTS AND EDC -GOOT TEST ON OTS AND EDC 03:45 - 06:25 2.67 DRILL P 8.100.00 PRODi RIH WITH 3 -1/4 -LATERAL BHA 10 - RATE:.30 BPM IN, 60 BPM OUT. CIRC PRESSURE:728 PSI '- MUD WEIGHT: 9.06 PPG IN ,9.07 PPG OUT .-LOG TIE IN,-8'CORRECTION - LOG CCL FOR LINER TOP PLACEMENT (RELOG CCL 11 MINUTES) _ -CLOSE EDC AND RIH 06:25 - 07:00 0.58 DRILL N 8.10000 PROD? RES FAILED ON LAST RUN, RE -LOG MAD PASS FROM 7910' TO TO 07:00 - 12:00 5.00 DRILL P 8,104.00 PROD? TAG TD AND START DRILLING LATERAL SECTION - FREE SPIN: 3520 PSI, 1.72 BPM - RATE: 1.72 BPM IN, 1.71 BPM OUT. CIRC PRESSURE: 3842 PSI - MUD WEIGHT: 9.17 PPG IN, 9.11 PPG OUT, ECD: 10.49 PPG - WEIGHT ON BIT 1- 2.75 K 12:00 - 1615 4.25 DRILL P 8,550.00 PRODi DRILLED 450' WIPER TRIP TO THE WINDOW CHASING SWEEPS ""HOLD A KWr DRILL"" DETAILS IN SAFETY SECTION OF THE REPORT - SEE A LITTLE DRAG PULLING THROUGH THE WINDOW - OPEN EDC PUMPAT MAX RATE AND WASH ACROSS WS TRAY -TAGGING AT BOTTOM OF WINDOW, PU AND CONTINUE CIRCULATING SWEEPS OUT WHILE LOGGING TIE IN - SWEEPS DID NOT BRING UP ANY INCREASE IN CUTTINGS - CLOSE THE EDC AND RIH TO LOG THE WS RA - PASSED THROUGH WINDOW CLEAN "'EACH TIME WE TAGGED IN THE WINDOW WE WERE PUMPING AT MAX RATE BUT WE ARE PASSING THROUGH CLEAN AT MIN RATE. PUMPING AT MAX RATE/HIGH PRESSURE MAKES EVERYTHING RIGIDAND WITH A 3' WINDOW MIGHT BE CAUSING US TO HANG UP WHEN GOING DOWN. 16:15 - 18:00 1.75 DRILL P 8,813.00 PROD1 DRILLING LATERAL SECTION FROM 8550'-8813' - FREE SPIN: 3648 PSI, 1.77 BPM - RATE: 1.77 BPM IN, 1.75 BPM OUT. CIRC PRESSURE: 3842 PSI - MUD WEIGHT: 9.21 PPG IN, 9.24 PPG OUT, ECD: 10.24 PPG - WEIGHT ON BIT 1- 2.75 K -150' WIPER TRIPS AS NEEDED WITH ATRIP TO ABOVE WINDOW EVERY 450' Primed 5/912019 8:49:06AM **All depths reported in Drillers Depths" North America - ALASKA - 8P Operation Summary Report Page 10 cf 13 i Common Well Name: S-105 AFE No Event Type: RE -ENTER -ONSHORE (RON) Start Date: 4/14/2019 End Date: 4/21/2019 X3 -019C8 -C'. (2,416,770.00 ) Project: PBU Site: S Rig Name/No.: CDR -2 Spud Date/Time: 10/25/2000 12:00 OOAM Rig Release: 4/27/1019 Active datum. KB @65.08usft (above Mean Sea Level) Date From - To Hire Task Code NPT 9,048.00 PROD? (110 8813'-9048' 18:00 - 20:30 2.50 DRILL P 2030 - 23:00 2.50 DRILL P BPUOI: USA00000133 Total Depth Phase Description of Operations (usft) _ 9,048.00 PROD? DRILLING LATERAL SECTION FROM 8813'-9048' - FREE SPIN: 3648 PSI, 1.77 BPM - RATE: 1.77 BPM IN, 1.75 BPM OUT. CIRC PRESSURE: 3842 PSI - MUD WEIGHT: 9.21 PPG IN, 9.24 PPG OUT, ECD: 10.24 PPG WEIGHT ON BIT I -2.75K T 9,048.00 PRODt WIPER TRIP TO THE WINDOW CHASING SWEEPS - SEE A LITTLE DRAG PULLING THROUGH THE WINDOW - OPEN EDC PUMP AT MAX RATE AND WASH ACROSS WS TRAY - WENT DOWN THROUGH WINDOW WITH NO PUMPS WITH NO ISSUES - CLOSE THE EDC AND RIH TO LOG THE WS RA - PASSED THROUGH WINDOW CLEAN NOTE:WITH 10X10 LOW/HI VIS SWEEP AT Panted 5/9/2019 8:49.06AM **All depths reported in Drillers Depths" SURFACE CUTTINGS INCREASE OF 22 PERCENT 2300 - 0000 1.00 DRILL P 9,048.00 PROD1 DRILLING LATERAL SECTION FROM 9046-'9112' - FREE SPIN: 3660 PSI, 1.77 BPM - RATE: 1.77 BPM IN, 1.75 BPM OUT. CIRC PRESSURE: 4100 PSI - MUD WEIGHT: 9.23 PPG IN, 9.14 PPG OUT, ECD: 10.82 PPG - WEIGHT ON BIT 1- 2.5 K 4/20/2019 00:00 - 04:30 4.50 DRILL P 9,500.00 PROD1 DRILLING LATERAL SECTION FROM 9112'-9500' - FREE SPIN: 3660 PSI, 1.77 BPM - RATE: 1.77 BPM IN, 1.75 BPM OUT. CIRC PRESSURE: 3970 PSI - MUD WEIGHT: 9.23 PPG IN, 9.14 PPG OUT, ECD: 10.82 PPG - WEIGHT ON BIT 1- 2.5 K NOTE:HELD KICK WHILE DRILLING DRILL WITH MICAH BUSH'S CREW. TIME TO SECURE WELL 1MINUTE 23 SECONDS(SIMULATED) 0430 - 0730 3.00 DRILL P 9,500.00 PROD1 WIPER TRIP TO THE WINDOW CHASING SWEEPS - SEE A LITTLE DRAG PULLING THROUGH THE WINDOW -OPEN EDC PUMPATMAX RATEANDWASH ACROSS WS TRAY - WENT DOWN THROUGH WINDOW WITH NO PUMPS WITH NO ISSUES - CLOSE THE EDC AND RIH TO LOG THE WS RA - PASSED THROUGH WINDOW CLEAN NOTE: WITH 10X10 LOW/HI VIS SWEEPAT SURFACE CUTTINGS INCREASE OF 20 PERCENT - CORRECT DEPTH +4' AND RIH Panted 5/9/2019 8:49.06AM **All depths reported in Drillers Depths" Common Well Name: 5-105 Event Type: RE-ENTER- ONSHORE(RON) Proiect: PBU North America - ALASKA - BP Operation Summary Report Start Date: 4/14/2019 End Date: 4/21/2019 Site: S Spud Date/Time: 10/25/2000 12:00:OOAM AFE No (2,415,770.00 ) Page 11 of 13 1 Rig Contractor: NABORSALASKA DRILLING INC. 20:30 BPUO1: USA00000133 Active datum: KB @65.08usR (above Mean See Level) DRILL P Date From - To Hm Task Code NPT Total Depth Phase Description of Operations (hr)_ _ (usft) DRILL _ 07:30 - 17:00 9.50 DRILL P 9,500.00 PROD1 BACK ON BOTTOM DRILLING - CLOSE THE EDC AND RIH TO LOG THE WS - FREE SPIN: 3660 PSI, 1.77 BPM - PASSED THROUGH WINDOW CLEAN - RATE: 1.81 BPM IN, 1.83 BPM OUT. CIRC NOTE -WITH 1OX10 LOW/HI VIS SWEEPAT PRESSURE: 3930 PSI PERCENT - MUD WEIGHT: 9.22 PPG IN, 9.13 PPG OUT, - CORRECT DEPTH +8' AND RIH ECD: 10.51 PPG RYAN BEARD'S CREW SIMULATED SHUT IN - WEIGHT ON BIT 1- 2.5 K TIME 1 MINUTE 20 SECONDS PROD1 -9530' GETTING PUSHED DOWN, HIGH SIDE - FREE SPIN: 4025 PSI, 1.88 BPM TF AND TRY TO BUILD UP TO 92" - RATE: 1.88 BPM IN, 1.87 BPM OUT. CIRC - STARTING TO LOOSE OUR PUSHNUOB, MUD - MUD WEIGHT: 9.12 PPG IN, 8.98 PPG OUT, SYSTEM HASS 2000' ON IT AND 1.7% DRILL ECD: 10.8 PPG SOLIDS, CALL FOR TRUCKS FOR MUD SWAP PROD1 DRILLING FROM 10245-10400 - BLEED IA FROM 1020 PSI DOWN TO 500 PSI - FREE SPIN: 3882 PSI, 1.80 BPM - 9800'START NEW MUD DOWN HOLE _ 1700 - 2030 3.50 DRILL P 9,950.00 PRODI WIPER TRIP TO THE WINDOW CHASING 02:00 - 05:15 3.25 DRILL P 10,400.00 20:30 - 00.00 3.50 DRILL P 10,245.00 4/21/2019 0000 - 02'.00 2.00 DRILL P 10,400.00 02:00 - 05:15 3.25 DRILL P 10,400.00 Printed 5/9/2019 8:49.06AM **Ali depths reported in Drillers Depths" SWEEPS - SEE A LITTLE DRAG PULLING THROUGH THE WINDOW - OPEN EDC PUMP AT MAX RATE AND WASH ACROSS WS TRAY '- WENT DOWN THROUGH WINDOW WITH NO PUMPS WITH NO ISSUES - CLOSE THE EDC AND RIH TO LOG THE WS RA - PASSED THROUGH WINDOW CLEAN NOTE -WITH 1OX10 LOW/HI VIS SWEEPAT SURFACE CUTTINGS INCREASE OF 10 PERCENT - CORRECT DEPTH +8' AND RIH HELD KICK WHILE TRIPPING DRILL WITH RYAN BEARD'S CREW SIMULATED SHUT IN TIME 1 MINUTE 20 SECONDS PROD1 DRILLING FROM 9950'-10245 - FREE SPIN: 4025 PSI, 1.88 BPM - RATE: 1.88 BPM IN, 1.87 BPM OUT. CIRC PRESSURE: 4243 PSI - MUD WEIGHT: 9.12 PPG IN, 8.98 PPG OUT, ECD: 10.8 PPG - WEIGHT ON BIT 1- 2.5 K PROD1 DRILLING FROM 10245-10400 - FREE SPIN: 3882 PSI, 1.80 BPM - RATE: 1.80 BPM IN, 1.76 BPM OUT, CIRC PRESSURE: 4142 PSI - MUD WEIGHT: 9.10 PPG IN, 9.05 PPG OUT, ECD: 10.86 PPG -WEIGHT ON BIT 1-2.5 K PROD1 WIPER TRIPTO THE WINDOW CHASING SWEEPS - SEE A 3K DRAG PULLING THROUGH THE WINDOW - OPEN EDC PUMP AT MAX RATE AND WASH ACROSS WS TRAY - WENT DOWN THROUGH WINDOW WITH NO PUMPS WITH NO ISSUES - CLOSE THE EDC AND RIH TO LOG THE WS RA - PASSED THROUGH WINDOW CLEAN NOTE:WITH 10X10 LOW/HI VIS SWEEPAT SURFACE CUTTINGS INCREASE OF 10 PERCENT ---CORRECT DEPTH +7' AND RIH Printed 5/9/2019 8:49.06AM **Ali depths reported in Drillers Depths" North America - ALASKA- BP Operation Summary Report Common Well Name: 5-105 Event Type: RE-ENTER- ONSHORE(RON) Start Date: 4 /1 412 01 9 End Date. 4/21/2019 Project: PBU Site: S Rig Nacre/No.: CDR -2 Spud Date/Time: 10/25/2000 12:00:OOAM AFE No K3 -019C8 -C'. (2,416,770.00 ) Rig Release: 4/27/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB Q65.08usft (above Mean Sea Level) Date From - To Hm Task Code NPT Total Depth Phase Description of Operations (hr) (usft)__ 05:15 - 08:00 2.75 DRILL P 10,400.00 PROD? DRILLING FROM 10400-10559 0800 - 15:00 7.00 DRILL P 1500 - 1530 0.50 1� DRILL P 15:30 - 18:00 2.50 DRILL P 18:00 - 21:30 3.50 DRILL P 21:30 - 2230 1.00 DRILL P 22:30 - 23:00 0.50 DRILL P Page 12 of 13 1 Printed 5/9/2019 8:49:06AM "AII depths reported in Drillers Depths" - FREE SPIN: 3865 PSI, 1.80 BPM - RATE: 1.80 BPM IN, 1.76 BPM OUT. CIRC PRESSURE: 4140 PSI -MUD WEIGHT: 9.12 PPG IN, 9.03 PPG OUT, ECD: 10.81 PPG -WEIGHT ON BIT 1- 2-.5-K 10,559.00 PROD1 DRILLED TO TD, WIPER TRIP TO THE WINUOWCHASIN PILLS -JOGATTHE WINDOW — PULL THROUGH WINDOW, OPEN EDC, RUN 'MOTOR THROUGH WINDOW THEN BRING PUMPS GNAT MAX RATE TO JETTRAY -CHASE 10X10 PILLS IN THE 7" TO THE 3.5" !AND RECIPTHETTTO CLEAN UPTHE7" -PUMP PILLS TO SURFACE AND VERIFY CLEAN RETURNS AT SHAKER - RIH TO THE WINDOW, CLOSE THE EDC, RIH THROUGH WINDOWAND LOG TIE IN - CORRECT DEPTH +7.5', RIH - TAG TD AT 10,559', POOH TO WINDOW CHASING 1OX10 LOW & HIGH VIS PILLS ,-JOG ATTHE WINDOW PULL THROUGH WINDOW, OPEN EDC, RUN MOTOR THROUGH WINDOW THEN BRING PUMPS ON AT MAX RATE TO JET TRAY -CIRC PILLS OUT AND UNTIL SHAKER IS CLEAN _ 10,559.00 PROD1 SHAKER IS CLEAN, PREP FOR VOLUME TEST AFTER RECALIBRATING THE IN MM - SHUT DOWN PUMPS, ZERO ALL BBL & STROKE COUNTERS, LINE UP TO EMPTY PILL PIT - ONLINE WITH PUMPS AT 2.0 BPM - SHUT DOWN PUMPS AT 50 BBLS IN PILL PIT IN MM=49.40 OUT MM=49.04 STROKE COUNT = 50.57 BELS - CALL ODE AND DISCUSS 10,559.00 PROD1 - LOG TIE IN AND DRIFT TO TD - CORRECT DEPTH -V AND RIH - CONFIRMED TD - PERFORM 10 MIN DYNAMIC FLOW CHECK - LOSS OF 1.8 BPH 10,559.00 PROD1 POOH - LAY BEADED LINER PILL FOLLOWED BY 9.0 PPG FLUID. - AT THE WINDOW OPEN THE EDC AND POOH DISPLACING WELL TO 9.0 PPG FLUID - STOP AT 7533.33 AND PAINT A TO FLAG FOR LINER (EOP = 7459.04') YELLOW FLAG - STOPAT 4628.33' AND PAINTA WINDOW FLAG FOR LINER (EDP = 4552.04') -AT SURFACE - FLOWCHECKWELL 10,559.00 PROD1 GOOD NO FLOW, PU INJECTOR AND INSPECT PIPE INJECTOR OFF AT 21:30 - FOUND FLAT SPOTS>20% WEAR THAT WILL NEED TO BE CUT OUT LD BHA, BIT GRAGE = 2 -2 -DL -N -Y -I -WT -TD _ 10,559.00 PROD1 FUNCTION TEST BOP'S Printed 5/9/2019 8:49:06AM "AII depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 13 of 13 Common Well Name: 5-105 AFE No Event Type. RE-ENTER- ONSHORE (RON) Start Date. 4/14/2019 End Date. 4/21/2019 X3 -019C8 -C: (2,416,770W) Project: PBU Site: S Rig Name/No.: CDR -2 Spud DateRme: 10/25/2000 12:00:OOAM Rig Release: 4/27/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.08usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations _ (hr) (usft) _ 2300 - 00:00 1.00 DRILL P 10,559.00 PROD? CUT COIL (30') -REHEAD - PULL TEST TO 50K -INSTALL UPC Printed 5/912019 8.49'.06AM **All depths reported in Drillers Depths— Common Well Name: S-105 Event Type: COM- ONSHORE (CON) Project: PBU North America - ALASKA - BP Operation Summary Report Start Dale: 4/22/2019 End Date. 4/27/2019 Site: S AFE No (1,957,577.00) i Rig Name/No.: CDR -2 Spud Date/Time: 10/25/2000 12 00:OOAM Rig Release: 4/27/2019 Pagel of 8 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USADO000133 Active datum: KB Q65.08usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations _ (hr) _ (usft) . 4/22/2019 00:00 - 03:30 3.50 CASING P 10,559.00 RUNPRD MAKE UP COIL CONNECTOR - PULL TEST SAME TO 50K - MU LOG - PRESSURE TEST UOC AND COIL CONNECTOR TO 3500 PSI - PREJOB SAFETY MEETING FOR CHANGING PACK OFFS AND FLOATS - CHANGE OUT PACK OFFS ON INJECTOR - PRESSURE TEST FLOATSAND PACK OFF _ AGAINST SWAB VALVE 250/3500 PSI 03.30 - 1215 8.75 CASING P 10,559.00 RUNPRD RUN LINER - PRE JOB SAFETY MEETING - WSUBAKER REP, DRILLER VERIFY PIPE COUNT IN PIPE SHED - PU LINER PER RUNNING ORDER NOTE: HOLD KICK WHILE TRIPPING DRILL WITH MICAH BUSH'S CREW. TIME TO SECURE WELL 4 MINUTES (SIMULATED CLOSING UPPER PIPE RAMS) - CONTINUE RUNNING LINER NOTE: HOLD A KWT DRILL- PU SAFETY JOINT AND DEPLOY, WELL SECURED IN 2:34 WITH CLOSING THE UPPER SET OF COMBI RAMS, TW VALVE AND HCR. COMMENTS IN SAFETY SECTION 12:15 - 19'.00 6.75 CASING P 10,559.00 RUNPRD LINER AND BHA MU, RIH - AT WINDOW FLAG, CORRECT DEPTH TO 7522' (-22' CORRECTION) PUWT=39K RIHWT=20K - PASSED THROUGH WINDOW CLEAN, ONLINE AT 0.02 BPM - SET DOWN AT 9565'20K WOB, 9603, 9651 - TD FLAG CAME IN AT 10426.5' SHOULD HAVE BEEN 10429' 1 OFF) - TAG 3 TIMES AT 10,550.6, COULD BE TD, ONLINE WITH PUMP MONITORING OUT RATE 8 DENSITY IN CASE WE SWABBED IN WB FLUIDS -PU WT'S =48K RIH WT'S =14K -RATES IN=1.52 BPM OUT =1.52 BPM@ 3499 PSI - PU OFF LINER CLEAN AT 37K - REMOVE LINER LENGTH FROM BHA (CURRENT DEPTH) 10527.35 -(LINER LENGTH) 2959.59 = 7567.76 NEW BIT DEPTH - PUH TO 7225' AND LOG TIE IN - CORRECT DEPTH «10' CONFIRMS LINER IS ON BOTTOM, CALL ODE - ODE AGREES, POOH FOR CMT STINGER -CHECK FLO_WAT SURFACE _ 19:00 - 20:00 1.00 CASING P 10,559.00 RUNPRD GOOD NO FLOW, PU INJECTOR AND INSPECT PIPE - LD LINER RUNNING BHA - REMOVE FLOATS (2) FROM THE LOG Printed 5/9/2019 8:49:39AM "All depths reported in Drillers Depths" Common Well Name. S-105 Event Type: COM- ONSHORE (CON) Project: PBU Rig Name/No.: CDR -2 Active datum: KB @65.08usft (above Mean Sea Date From - To Ars --___—(hr). 20:00 - 22:00 2.00 2200 - 00:00 2.00 North America - ALASKA - BP Operation Summary Report Start Date: 4/22/2019 End Date: 4/27/2019 Site:$ - -- — — -- -- Page 2 of 8 AFE No K3 -019C8 -C:(1,957,577.00) Rig Release: 4/27/2019 BPUOI: USA00000133 Task Code NPT Total Depth Phase Description of Operations CASING P 10,559.00 RUNPRD MU CEMENTING BHA - STAB ON INJECTOR @ 20:05 - PRESSURE TEST ON QTS TO 3500 PSI - RIH WITH CEMENTING BHA - @ 7500' PU 36K SO 19K - CIRCULATE AT 1.5 BPM WITH 2280 PSI - REDUCE RATE TO 0.5 BPM WITH 1080 PSI '- OBSERVED 200 PSI INCREASE WHEN SEAL ENTER TOL @ 7605' - NO-GO LAND ON TOL @ 7610' -- INCREASE RATE TO 1.5 BPM WITH 2500 PSI CASING P 10,559.00 RUNPRD DISPLACE WITH 9.0 PPG BRINE BPM 1.50 IN 1 50 OUT - BRINE RETURNS AT SURFACE WITH CORRECT VOLUME FOR CIRCULATING THROUGH THE LINER _ - RIG UP CEMENTER$ 4/23/2019 00:00 - 00:30 0.50 CASING P 10,559.00 RUNPRD DISPLACE WELL WITH 9.0 PPG BRINE IN 1.50 GPM OUT 1.50 GPM _ 00:30 - 03:45 3.25 CASING P 10,559.00 RUNPRD PRESSURE TEST LINES - PREJOB SAFETY MEETING - BLOW BACK TO CEMENT UNIT PRESSURE TEST CEMENT LINES TO 4500 PSI (FAILED), CHANGE PRESSURE SEAL ON 2" CHISAN) - PRESSURE TEST CEMENT LINES TO 4500 PSI - PUMP 50 BBLS FROM CEMENT UNIT TO VERIFY MICRO MOTION -FINAL READINGS PIT STRAP =50.7 RIG MM =48.3(-2.4) SCH MM = 51.7 (+1.0) - DISCUSS WITH ODE TO PERFORM THE CEMENT OPERATION WITH SCHLUMBERGER - TRANSFER CONTAM PILL FROM RIG TO VAC TRUCK FOR CEMENTING UNIT TO DISPLACE AND CONTAMINATE WITH Printed 51912019 8:49:39AM "AII depths reported in Drillers Depths" North America - ALASKA - Blo Operation Summary Report Common Well Name: 5-105 AFE No Event Type: COM- ONSHORE (CON) Start Date: 412212019 Eno Date: 4/27/2019 X3 -019C8 -C: (1,957,577,00) Page 3 of 8 Protect: PBU -- - Site: S -- -- - Rig Name/No.: CDR -2 Spud Daterrime: 10/25/2000 12:00:OOAM Rig Release: 4/27/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.08usft (above Mean Sea Level) Date From - To Hm Task Code NPT Total Depth Phase Description of Operations (hr) (usft) _ _ _ 0345 - 07:00 3.25 CASING P 10,559.00 r RUNPRD PJSM TO PUMP CMT WITH NAD, SLB AND JACOBS MIX AND PUMP 18.7 BBLS OF CEMENT: - CEMENT WET AT 03:49 HRS - SWAP TO SLBAND PUMP, PUMPING 5 BBLS OF KCL AHEAD OF CMT - ZERO IN MM ONCE DENSITY = 15.3 PPG, LOAD 18.7 BELS 15.3 PPG CEMENT IN REEL - DISPLACE CEMENT WITH 9.0 PPG GEOVIS, RATE: 1.4 BPM IN, 1.4 BPM OUT PSI 3200 - 50.5 BBLS AWAY ZERO OUT MM WITH CEMENT AT SHOE, TAKE RETURNS TO ISOLATED TANK FOR MANUAL STRAP 50.51N 49.0 OUT - SHUT DOWN PUMPS AT 71.2 BBLS AWAY (OUT PIT VOL= 69 BBLS) - FINAL STATIC PRESSURE 1050 PSI - OPEN BLEEDER ON THE PUMP TO CHECK !, FLOATS (OK) - BRING PUMPS ON @ 0.1 BPM - PICK UP TO BREAKOVER *6 FT PER BTT REP TO EXPOSE SEALASSEMBLY - PUMP CEMENTAND PERF PILL AT MAX RATE 1.9 BPM 3300 PSI - 12.94 BBLS CEMENT BEHIND PIPE, BASED ON MANUAL STRAP, TOTAL LOSSES 1.2 BBLS (NO LOSSES OBSERVED) -PUH TO 7450' ANO RLUlFKVUAl EACROSS _ THEGLMAT7475' 07:00 - 09:30 2.50 CASING P 10,559.00 RUNPRD POOH LAYING IN CLEAN KCL - OOH FLOW CHECK WELL - TAG UP AND LD BHA (INJECTOR OFF AT 09:00) - LD CMT BHA 09:30 - 12:00 2.50 PERFOB P 10,559.00 OTHCMP BHA OOH, ALLTOOLS LOOK GOOD - HOLD A PJSM TO PUMP SLACK OUT - MU 1 JT OF 2-1/16" CSH -PUMP SLACK OUT - PU INJECTOR, CUTAND VERIFY LENGTH OF WIRE - PUMPED OUT 230'OF 301'(71' UNACCOUNTED FOR) RUN 3 JTS OF PIPE FOR PERF RUN - SEAL WIRE, MU BOT CTC AND PULL TEST TO SOK - MU UPPER MHAAND PT 4000 PSI STAB ON WELLAND PUMP 3/4" DRIFT BALL — BALL RECOVERED __-MOVE INJECTOR BACK 12:00 - 19:30 7.50 PERF P 10,559.00 OTHCMP MAKE UP PERF BHA - PJSM TO MU PERF GUNS - PERF GUNS RAN, MU CSH DRIFT & RATTLE UNTIL CLEAN -MU RAMAINING BHAAND STAB INJECTOR - PRESSURE TEST QTS TO 3500 PSI - CIRCULATE 10 BBLS AT 1.5 BPM 3200 PSI Printed 5/9/2019 8:49:39AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 4 of 8 Operation Summary Report Common Well Name: S-105 AFE No Event Type: COM- ONSHORE (CON) Start Date'. 4/22/2019 End Date: 4/27/2019 X3-019CB-C (1,957,577.00 ) Project: PBU - - - - - -- Site: S — — -- - Rig Nama/No.: CDR -2 Spud Date/Time: 10/25/2000 12:00:OOAM Rig Release: 4/27/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.08usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr)_ (usft) 19:30 - 22:00 2.50 PERF P 10,559.00 OTHCMP �RIH WITH PERF BHA 2200 - 0000 2.00 4/24/2019 00'.00 - 04'.30 4.50 PERF N PERF 04:30 - 15:30 11.00 PERFOB R M - PUMP .0.35 BPM IN / 0.60 BPM OUT @ 350 PSI WHILE RIH - TAG WITH 5K @ 7911' - MULTIPLE ATTEMPTS TO PASS OBSTRUCTION UNDER HALLIBURTON REP INSTRUCTION WITHOUT SUCCESS (MAX WT APPLIED 5K) - PERFORM 10 MIN DYNAMIC FLOW CHECK - STATIC 10,55900 OTHCMP POOH TO LAY DOWN PERF ASSEMBLY - POOH TO TOL @ 40 FPM WITH GPM 0.7 IN / 0.6 OUT - POOH TO SURFACE @ 80 FPM WITH GPM 0.8IN/0.4 OUT FLOW CHECK WITH BHA BELOW BOP'S - STATIC - LIFT INJECTOR @ 23:30 - LAY DOWN PERF BHA 10,559.00 OTHCMP LAYING DOWN PERF ASSEMBLY - PREJOB SAFETY MEETING - LAY DOWN 1" CSH PIPE - PREJOB SAFETY MEETING FOR HANDLING PERF GUNS WITH GUNS 300' BELOW SURFACE - LAY DOWN PERF GUNS NOTE: FOUND TRACES OF CEMENT ON THE BULL NOSE ASSEMBLY - CLEAN AND CLEAR RIG FLOOR 10.559.00 OTHCMP MU CLEANOUT BHA -MOBILIZE BHA TO RIG FLOOR - MU CLEAN OUT BHA - FIRST 38 JTS ARE CLEAN, DRIFT, RATTLE AND CIRC EVERY 20 JTS WHILE MU - 60JTS RAN, HOLD A KWF DRILL TO PU THE SAFETY JOINT, WELL SECURED IN 2:24 ALL HANDS CALLED IN IN 2:34 - CIRC 20 BELS AT 1.2 BPM TO ENSURE CSH IS CLEAN -CONTINUE MU CSH - 80 JTS RAN, PU THE SAFETY JOINT AND CIRCULATE -CONTINUE MU CSH - 100 JTS RAN, PU THE SAFETY JOINTAND CIRCULATE - MU BOT MHAAND 2-1/16" CSH -STAB INJECTOR Printed 519/2019 8:49:39AM **All depths reported in Drillers Depths— North America - ALASKA - BP Printed 5/9/2019 8 49 39A **All depths reported in Drillers Depths** Page 5 of 8 X3 -019C8 -C. (1,957,577.00 ) BPUOI: USA00000133 Description of Operations CLEAN OUT RUN - BHA MU, RIH - STOP AT 4344', GETTING AIR BACK, SHUT DOWN AND FLOW CHECK, GOOD NO FLOW - ONLINE WITH PUMP, CIRC OUT AIR, 10 BBLS CLEAN REURNS, RIH - STOP AT 7500' SHUT DOWN PUMP AND GET WT'S -UPWr=30K RIHWT=18K -TAG AT 7918 PU = 31K START MOTOR AND SLOWLY WORK DOWN TO 7943 - 1.0 BPM AT 3868 PSI - START 10 BBL HIGH VIS PILL - MILLED 10' PU AND CHECK PARAMETERS, PU Wr = 32K - WHP STARTING TO CLIMB AND TAKE RETURNS OUT TO THE TT, OUT DENSITY IS STARTING TO FLUCTUATE. - WHP FLUCTUATING BETWEEN 113 PSI AND 150 PSI BUT DENSITY & RATE IS STAYING SOLID AT 8.99 PPG AND 1.06 BPM - RATES AND DENSITIES ARE STABLE, PUMPED 2 BOTTOMS UP, BRING RETURNS BACK INSIDE, CLEAN RETURNS - FOUND THE STICKERS OFF THE PERF GUNS ARE PACKING OFF THE OUT MM -CIRCULATE HIGH VIS PILL OUT THEN SHUT DOWN THE PUMP AND TRY DRIFTING TO PBTD - TAGGED @ 7943' - CLEAN OUT LINER WITH SMALL BITES AND MULTIPLE SWEEPS, NO HARD OBSTRUCTIONS OBSERVED - CLEAN OUT TO 9532' -BACK REAM TO 300' ABOVE TOL 1.04 BPM IN / 1.02 BPM OUT - DRY DRIFT DOWN TO 9532' TAG W/ 4K - CLEANOUT LINER FROM 9532 TO 10525 WITH 1.04 BPM IN / 1.02 BPM OUT 35 FPM PUMP PRESSURES INCREASING. HAVING TO DROP RATE. START PUMPING CLEAN 9.0 PPG BRINE. Operation Summary Report Common Well Name. S-105 Event Type. COM- ONSHORE (CON) Stan Date: 4/22/2019 End Date: 4/27/2019 Project: PBU Site: S Rig Name/No.: CDR -2 Spud DateTme: 10/25/2000 12:00:OOAM Rig Contractor: NABORS ALASKA DRILLING INC. Active datum: KB @65.08usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase (hr) (usR) — _—_ 15:30 - 00:00 8.50 PERFOB N1 10,559.00 OTHCMP Printed 5/9/2019 8 49 39A **All depths reported in Drillers Depths** Page 5 of 8 X3 -019C8 -C. (1,957,577.00 ) BPUOI: USA00000133 Description of Operations CLEAN OUT RUN - BHA MU, RIH - STOP AT 4344', GETTING AIR BACK, SHUT DOWN AND FLOW CHECK, GOOD NO FLOW - ONLINE WITH PUMP, CIRC OUT AIR, 10 BBLS CLEAN REURNS, RIH - STOP AT 7500' SHUT DOWN PUMP AND GET WT'S -UPWr=30K RIHWT=18K -TAG AT 7918 PU = 31K START MOTOR AND SLOWLY WORK DOWN TO 7943 - 1.0 BPM AT 3868 PSI - START 10 BBL HIGH VIS PILL - MILLED 10' PU AND CHECK PARAMETERS, PU Wr = 32K - WHP STARTING TO CLIMB AND TAKE RETURNS OUT TO THE TT, OUT DENSITY IS STARTING TO FLUCTUATE. - WHP FLUCTUATING BETWEEN 113 PSI AND 150 PSI BUT DENSITY & RATE IS STAYING SOLID AT 8.99 PPG AND 1.06 BPM - RATES AND DENSITIES ARE STABLE, PUMPED 2 BOTTOMS UP, BRING RETURNS BACK INSIDE, CLEAN RETURNS - FOUND THE STICKERS OFF THE PERF GUNS ARE PACKING OFF THE OUT MM -CIRCULATE HIGH VIS PILL OUT THEN SHUT DOWN THE PUMP AND TRY DRIFTING TO PBTD - TAGGED @ 7943' - CLEAN OUT LINER WITH SMALL BITES AND MULTIPLE SWEEPS, NO HARD OBSTRUCTIONS OBSERVED - CLEAN OUT TO 9532' -BACK REAM TO 300' ABOVE TOL 1.04 BPM IN / 1.02 BPM OUT - DRY DRIFT DOWN TO 9532' TAG W/ 4K - CLEANOUT LINER FROM 9532 TO 10525 WITH 1.04 BPM IN / 1.02 BPM OUT 35 FPM PUMP PRESSURES INCREASING. HAVING TO DROP RATE. START PUMPING CLEAN 9.0 PPG BRINE. North America - ALASKA - BP Operation Summary Report Page 6 of 8 Common Well Name. 5-105 AFE No Event Type: COM- ONSHORE(CON) Start Date: 4/22/2019 End Date: 4/27/2019 X3 -019C8 -C:(1,957,577.00) Project: PBU Site: S Rig Name/No.: CDR -2 Spud Date/Time: 10/25/2000 12:00:OOAM Rig Release: 4/27/2019 Rig Contractor. NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.06usR (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _(usH)- _ _ 4/252019 00:00 - 11'.30 11.50 PERFOB N 10,559.00 OTHCMP CLEANOUT LINER TO 10545 (FLOAT COLLAR) TAGGED 2K 200 PSI PRESSURE INCREASE -RETAG FLOAT COLLAR - BACKREAM TO 300'ABOVE TOL - DRY DRIFT FROM TOL TO FLOAT COLLAR 0545 - POH WITH 1 BPM TO 10445 (PAINT WHITE FLAG) EDP 7202.33' - 10 MIN FLOW CHECK - STATIC - POH TO TOL GPM 1.12 IN 10.96 OUT - PUMP 1/2" BALL TO ACTIVATE CURCULATING SUB WITH 5 BBLS OF HI VIS PILL ON EACH SIDE - REDUCE RATE AT 33 BBLS AWAY, NO INDICATION THE BALL LANDED AT VOLUME 42.27 BBLS - CYCLE PUMPA FEW TIMES, STILL NO CHANGE, POOH CHASING HVP AND WILL CHECK FOR THE BALL WHEN WE LD THE BHA - AT SURFACE FLOW CHECK WELL - GOOD NO FLOW CHECK, PU INJECTOR AND INSPECT LAST 100' OF COIL - FOUND SOME GOUGES -17' TAG UP THE WILL NEED TO BE CUT OFF AND REHEAD - LD UPPER BHA, CSH AND MOTOR 8 MILL 1130 - 1400 2.50 PERFOB N 10,559.00 OTHCMP BHAOOH - 1/2" BALL RECOVERED - INSPECT INJECTOR, MU A NOZZLE TO THE CTC AND RIH TO INSPECT PIPE - INJECTOR INSPECTION COMPLETED - NO BROKEN TABS OR MISSING BOLTS OR PINS - CUT 20'OF COILAND MU A NEW BOT CTC - PULL TEST TO 50K, GOOD PULL TEST, PT TO 4300 PSI 14:00 - 20:30 6.50 PERFOB N 10,559.00 OTHCMP MU PERF GUN BHA - HOLDA PJSM TO MU TO MU THE PERF GUN BHA - REWALK GUN LAYOUT WITH HES - LAYOUT IS GOOD, MU PERF GUNS - PERF GUNS RAN, SWAP ELEVATORS AND MU CSH - CSH RAN, REAMINDER OF [ERF BHA -MAKE UP INJECTOR - PRESSURE TEST OTS TO 3500 PSI - CIRC 10 BBLS THROUGH COIL - RIH TO 7911' Printed 5/912019 8.49:39AM **All depths reported in Drillers Depths" Common Well Name: 5-105 Event Type: COM- ONSHORE (CON) Project: PBU North America - ALASKA - BP Operation Summary Report Start Date: 4/22/2019 End Date. 4/27/2019 Site: S Soud Daterrime: 10/25/2000 12:00:OOAM AFE No X3 -019C8 -C:(1,957,577.00) Page 7 of 8 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000133 _ Active datum: KB @65.O8usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations _ (hr) (usft) 20:30 - 23:30 3.00 PERFOB P 10,559.00 OTHCMP PERF LINER 23:30 - 00:00 4/26/2019 00:00 - 02:30 02:30 - 10:30 1030 - 15:30 Pnnted 5/9/2019 8.49:39AM "All depths reported in Drillers Depths" - RIH TO 10545 (TAG FLOAT COLLAR) GPM IN, 0.40 / OUT 0.50 - @ TOL PU 32K $O 18K -TAG FLOAT COLLAR 10545 (CORRECT BOTTOM SHOT DEPTH TO 10536.07) - POH TO 10240 - CIRCULATE ACROSS THE TOP OF THE HOLE WITH 160 PSI APPLIED - PERFORM PERF GUN OPERATING SEQUENCE PER HALLIBURTON REP -PERF LINER (10170-9875)&(6950-8220)@ 7 - CIRULATE @ 0.9 GPM IN / 0.8 OUT WITH 240 PSI APPLIED WHILE POH ( LOSSES TOTAL 1 BBL) 0.50 PERFOB P 10,559.00 OTHCMP POH WITH PERF BHA - FLOW CHECKAT TOL. - STATIC -POH GPM IN I.0/OUT 0.7 2.50 PERFOB P 10,559.00 OTHCMP POH AND LAY DOWN PERF GUNS - POOH TO 3300' (BULL NOSE DEPTH) CIRC SUB 1290 - JOG IN THE HOLE TO 6000 - CIRCULATE GUN GAS FROM WELL TAKING RETURNS TO THE TIGER TANK - POOH TO 3300 (BHAAT SURFACE) -CHECKFLO_W- STATIC 8.00 PERFOB P 10,559.00 OTHCMP LAY DOWN PERF BHA - PREJOB SAFETY MEETING • - LIFT OFF INJECTOR - LAY DOWN CSH - PREJOB SAFETY MEETING WITH GUN 300' BELOW SURFACE - LAY DOWN PERF BHA - 10.00 CALL OUT LRS TO FP WELLAND GREASE CREW TO SERVICE TREE 5.00 PERFOB P 10,55900 OTHCMP PERF GUNS OOH - CLEAR HES TOOLS FROM FLOOR - MU NOZZLE BHA W/CHECKS - RIH LOADING COIL WITH DIESEL - POOH LAYING IN DIESEL FROM 2500' HOLDING 250 PSI WHP, NO LOSSES - GOOD DIESELAT SURFACE - TAG UP, SERVICE TREE VALVES, CLOSE MASTER & SWAB VALVES AND LTT - GOOD LTT, JET STACK WITH NOZZLE TO FLUSH BORE -PU INJECTOR Pnnted 5/9/2019 8.49:39AM "All depths reported in Drillers Depths" Common Well Name: 5-105 Event Type: COM- ONSHORE (CON) Protect: PBU North America - ALASKA - BP Operation Summary Report Start Date: 4/22/2019 End Date: 4/27/2019 Site: S AFE No X3 -019C8 -C'. (1,957,577.00 ) Page 8 of 8 Rig Name/No.: CDR -2 Spud Date/Time: 10/25/2000 12:00:OOAM Rig Release: 4/27/2019 Rig Contractor. NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.08usR (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (ush) - 15:30 - 21:00 5.50 RIGD P 10,559.00 POST PUMP SLACKMANAGEMENT - REMOVE NOZZLE BHAAND STAB ON WELL - LINE UP AND PUMP SLACK BACK - PU INJECTOR, CUT OFF CTC, RU CUTTER AND CUT COIL (275 MIN 300' MAX) - CUT 300' OF COIL- NO WIRE, MU CTC, PULL TEST TO 50K - MAKE UP STINGER AND PUMP SLACK FORWARD - REHEAD UQC FOR BHI AND TEST - BLOW DOWN REELAND SURFACE LINES -CONTACTED DSO TO LET THEM KNOW WE WILL NEED TO SHUT IN 5-104 8 5-114 AS PER OUR CLOSE PROXIMITY SURFACE WELLS RP -20'00 HRS WALKED DOWN WELLS 5-104 8 5-114 WITH DSO TO VERIFY SHUT IN 21:00 - 0000 3.00 RIGD P 1055900 POST IG DOWN EQUIPMENT - FILL TREE WITH METHANOL LTT BETWEEN MASTER AND SWAB VALVE TO 3500 PSI - NO VISIBLE LEAKS OBSERVED - CHANGE RISER TO TEST RISER - NIPPLE DOWN MPD LINE / STACK - WORK ON RIG DOWN CHECKLIST CALL WELLS SUPERINTENDENT TO DISCUSS MOVING OFF WELL WITH MORE THAN 50 PSI ON IA-RECIEVE PERMISSION TO MOVE 4/27/2019 0000 - 01:30 1.50 RIGID 10,559.00 POST - NIPPLE UP TREE CAP FLANGE - FILLTREE CAP WITH METANOL - LTT TREE CAP AND MASTER VALVE TO 3500 PSI - OPEN MASTER AND PUMP .8 BBLS OF METHANOL PSI 780 PSI - CLOSE MASTER VALVE & BLEED RESIDUAL PRESSURE FROM TREE. - CLOSE ALL TREE VALVES/CASING VALVES, VERIFY AND FLAG - IA 0, OA 50 '** RELEASE RIG (19 01:30 HRS *** Printed 5/9/2019 8:49:39AM **All depths reported in Drillers Depths'* by North America - ALASKA - BP PBU S S-105 S-1 05A 500292297701 Design: S -105A Final Survey Report 22 Aprii, 2019 L ee Company: North America - ALASKA - BP Project: PBU Site: S Well: 5-105 Wellbore: 5-105A Design: 5-105A BP Final Survey Report Local Co-ordinate Reference: Well 5-105 TVD Reference: KB @ 65.08usft (NABORS CDR2) MD Reference: KB @ 65.08usft (NABORS CDR2) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Project PBU, PBU, PRUDHOE Map System: Alaska NAD27 State Plane Zones System Datum: Mean Sea Level Geo Datum: NAD27 ` OGP-Usa AK [4267'15864] Using Well Reference Point Map Zone: NAD27. OGP-Usa AK / Alaska zone 4 [26734'1586, Using geodetic scale factor site S, TR -12-12 Site Position: Northing: 5,980,854.540 usft Latitude: 70. 21'23.002 N From: Map Easting: 617,919.920 usft Longitude: 149° 732.343 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.90 ' Well 5-105, Slot 22 as -built Well Position «N/ -S 0.00 usft Northing: 5,980,834.750 usft Latitude: 70° 21'22S51 N +E/ -W 0.00 usft Easting: 618,929.810 usft Longitude: 149° 2'2.831 W Position Uncertainty 0.00 usft Wellhead Elevation: 37.91 usft Ground Level: 35.41 usft Wellbore 5-105A Magnetics Model Name Sample Data Declination Dip Angle Field Strength r) O K) BGGM2018 5/1/2019 16.80 80.93 57,428 _ Design 5-105A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,610.76 Vertical Section: Depth From (TVD) +N/ -S +EI -W Direction (usft) (usft) (usft) (1) 27.17 0.00 0.00 45.00 4222019 10' 12:20AM Page 2 COMPASS 5000 1 Build 81D hre•' BP Final Survey Report Company: North America - ALASKA- BP Local Co-ordinate Reference: Well 5-105 Project PBU TVD Reference: KB @ 65.08usft (NABORS CDR2) Site: S MD Reference: KB @ 65.08usft (NABORS CDR2) Well: 5-105 North Reference: True Wellbore: S -105A Survey Calculation Method: Minimum Curvature Design: S -105A Database: EDM RSK- Alaska PROD -ANCP7 Survey Program Data 4/22/2019 (°/100usR) 27.17 From To 0.00 27.17 (usft) (usft) Survey (Wellbore) Tool Name Description 0.00 147.03 7,610.76 Survey#1 MWD+IFR'AK(5-105) MWD+IFR.AK MWD +IFR(Alaska] 0.00 7,648.00 10,559.00 Survey #1(5-105A) MWD MWD - Standard 4.14 Survey MD Inc Azi TVD TVDSS N/S EIW Northing Easting DLeg (usft) C) (1) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usR) 27.17 0.00 0.00 27.17 -37.91 0.00 0.00 5,980,834.750 618,929.810 0.00 147.03 0.66 4.14 147.03 81.95 0.69 0.05 5,980,835.439 618,929.849 0.55 235.10 0.73 11.24 235.09 170.01 1.74 0.20 5,980,836.497 618,929.978 0.13 330.82 0.72 26.25 330.80 265.72 2.88 0.58 5,980,837.640 618,930.345 0.20 423.45 0.62 38.43 423.43 358.35 3.80 1.15 5,980,838.564 618,930.899 0.19 519.39 0.73 46.02 519.36 454.28 483 1.91 5,980,839.407 618,931.648 0.15 612.54 0.87 50.52 612.50 547.42 5.49 2.88 5,980,840.284 618,932.607 0.16 705.00 1.16 67.43 704.95 639.67 6.29 4.29 5,980,841.111 618,934.000 0.45 799.27 1.45 73.09 799.19 734.11 7.01 6.31 5,980,841.857 618,936.011 0.34 893.81 1.39 78.43 893.70 828.62 7.59 8.58 5,980,842.470 618,938.269 0.15 975.27 1.19 84.61 975.14 910.06 7.86 10.39 5,980,842.777 618,940.074 0.30 1,071.68 0.87 83.56 1,071.54 1,006.46 8.04 12.12 5,980,842.980 618,941.795 0.33 1,166.14 1.56 4.83 1,165.98 1,100.90 9.40 12.94 5,980,844.355 618,942.594 1.73 1,258.82 3.87 349.19 1,258.55 1,193.47 13.73 12.46 5,980,848.676 618,942.045 2.59 1,353.61 4.81 350.70 1,353.07 1,287.99 20.80 11.21 5,980,655.719 618,940.691 1.00 1,444.26 8.63 352.72 1,443.08 1,378.00 31.30 9.74 5,980,866.194 618,939.048 4.22 1,540.46 10.17 357.07 1,537.99 1,472.91 46.94 8.39 5,980,881.812 618,937.451 1.76 1,633.36 12.29 1.85 1,629.10 1,564.02 65.01 8.29 5,980,889.882 618,937.064 2.49 1,726.65 20.09 5.71 1,718.63 1,653.55 90.92 10.21 5,980,925.814 618,938.570 8.44 1,757.71 20.97 6.25 1,747.71 1,682.63 101.75 11.34 5,980,936.663 618,939.534 2.90 1,819.27 21.34 3.86 1,805.13 1,740.05 123.88 13.29 5,980,958.815 618,941.135 1.52 V. Sec (usft) 000 0.52 1.37 245 3.50 4.62 5.92 7.49 9.42 11.43 _ 12.91 14.25 15.80 18.52 2263 2901 39.12 51.83 71.51 79.97 97.00 4222019 10:12:20AM Page 3 COMPASS 5000.1 Build 81D BP bp Final Survey Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-105 Project: PBU TVD Reference: KB ,@ 65.08usft (NABORS CDR2) Site: S MD Reference: KB @ 65.O8usft (NABORS CDR2) Well: 5-105 North Reference: True Wellbore: 5-105A Survey Calculation Method: Minimum Curvature Design: 5-105A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi TVD TVDSS NIS E/W Northing Easdng DLeg V. Sec (usft) V) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°I100usft) (usft) 1,915.30 21.08 2.47 1,894.65 1,829.57 158.57 15.22 5,980,993.526 618,942.505 0.59 122.88 2,006.61 22.58 3.50 1,97941 1,914.33 192.47 16.99 5,981,027.452 618,943.744 1.70 148.11 2,098.79 25.30 4.05 2,063.65 1,998.57 229.79 19.47 5,981,064.802 618,945.623 2.96 176.25 2,190.83 27.63 3.68 2,146.04 2,080.96 270.71 22.22 5,981,105.759 618,947.732 2.54 207.14 2,285.93 29.42 1.88 2,229.60 2,164.52 316.07 24.41 5,981,151.140 618,949.193 2.09 240.75 2,378.87 30.42 2.18 2,310.15 2,245.07 362.40 26.05 5,981,197.484 618,950.102 1.09 274.87 2,474.05 31.86 2.31 2,391.61 2,326.53 411.58 27.98 5,981,248.685 618,951.250 1.51 310.81 2,565.92 30.82 2.85 2,470.08 2,405.00 459.31 30.13 5,981,294.443 618,952.639 1.17 346.09 2,660.07 31.97 3.13 2,550.44 2,485.36 508.29 32.69 5,981,343.452 618,954.421 1.23 382.53 2,754.91 33.14 1.62 2,630.38 2,565.30 559.28 34.79 5,981,394.461 618,955.715 1.50 420.07 2,848.19 32.99 1.25 2,708.55 2,643.47 610.15 36.07 5,981,445.347 618,956.182 0.27 456.95 2,930.77 32.67 1.21 2,777.94 2,712.86 654.91 37.03 5981490.113 618,956.432 0.39 489.28 3,037.20 33.67 1.52 2,867.03 2,80195 713.13 38.42 5,981,548.336 618,956.897 0.95 531.42 3,131.32 34.45 2.16 2,945.00 2,879.92 765.81 40.12 5,981,601.036 618,957.765 0.92 569.88 3,225.16 33.97 1.26 3,022.61 2,957.53 818.54 41.71 5,981,653 784 618,958.514 0.75 608.29 3,318.67 33.40 2.76 3,100.42 3,035.34 870.37 43.52 5,981,705.630 618,959.505 1.08 646.22 3,411.15 32.71 1.92 3,177.93 3,112.85 920.77 45.58 5,981,756.051 618,960.767 0.90 683.32 3,504.47 31.88 2.04 3,256.81 3,191.73 970.60 47.31 5,981,805.897 618,961.698 0.89 719.77 3,596.95 34.21 0.81 3,334.33 3,269.25 1,021.01 48.54 5,981,656.314 618,962.134 2.82 756.29 3,690.84 35.08 1.40 3,411.57 3,346.49 1,074.37 49.58 5,981,909.683 618,982.319 0.99 794.75 3,785.46 34.68 0.81 3,489.19 3,424.11 1,128.47 50.53 5,981,963.787 618,962.411 0.64 833.68 3,879.39 33.74 0.47 3,566.87 3,501.79 1,181.28 51.02 5,982,016.591 618,962.071 1.00 871.37 3,972.08 34.33 2.09 3,643.69 3,578.61 1,233.14 52.19 5,982,068.460 618,962.412 1.17 908.87 4,065.41 33.19 2.74 3,721.28 3,656.20 1,284.96 54.37 5,982,120.301 618,963.770 1.28 94705 4,157.85 31.47 3.81 3,799.38 3,734.30 1,334.31 57.18 5,982,169.688 618,965.799 1.96 983.93 4,250.67 32.76 4.89 3,878.00 3,812.92 1,383.51 60.93 5,982,218.937 618,968.768 1.52 1,021.38 4,343.62 36.23 4.45 3,954.60 - 3,889.52 1,435.97 65.21 5,982,271.452 618,972.210 3.74 1,061.49 4222019 10.12:20AM Page 4 COMPASS 5000.1 Build SID BP Final Survey Report Company: North America -ALASKA - BP Local Co-ordinate Reference: Well S-105 Project: PBU ND Reference: KB Q 65.08usft (NABORS CDR2) Site: S MD Reference: KB Q 65.08usft (NABORS CDR2) Well- 5-105 North Reference: True Wellbore: 5-105A Survey Calculation Method: Minimum Curvature Design: 5-105A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi ND NDSS NIS ENV Northing Easting DLeg V. Sec (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) (°1100usft) (usft) 4438.05 36.52 4.81 4,030.63 3,965.55 1491.79 69.73 5,982,327.332 618,975.844 0.38 1,104.16 4,530.55 35.21 5.46 4,105.59 4,040.51 1,545.76 74.58 5,982,381.373 618,979.832 1.47 1,145.75 4,624.09 34.61 5.41 4,182.29 4,117.21 1,599.05 79.65 5,982,434.733 618,984.056 0.64 1,187.02 4,717.40 33.88 6.30 4,259.43 4,194.35 1,651.29 85.00 5,982,487.040 618,988.578 0.95 1,227.74 4,812.11 33.38 6.56 4,338.29 4,273.21 1,703.41 90.87 5,982,539.246 618,993.622 0.55 1,268.75 4,904.60 33.07 6.89 4,415.66 4,350.58 1,753.74 96.81 5,982,589.658 618,998.756 0.39 1,308.53 4,997.49 32.99 3.34 4,493.54 4,428.46 1,804.15 101.32 5,982,640.130 619,002.469 2.08 1,347.37 5,091.70 33.64 0.46 4,572.27 4,507.19 1,855.85 103.03 5,982,691.849 619,003.352 1.82 1,385.14 5,186.57 33.35 0.41 4,651.39 4,586.31 1,908.21 103.42 5,982,744.198 619,002.918 0.31 1,422.44 5,279.03 33.30 1.29 4,728.65 4,663.57 1,959.00 104.18 5,982,794.989 619,002.865 0.53 1,458.88 5,371.02 33.11 1.34 4,605.62 4,740.54 2,009.36 105.33 5,982,845.361 619,003.221 0.21 1,495.31 5,464.85 33.30 1.63 4,884.12 4,819.04 2,060.73 106.66 5,982,896.738 619,003.737 0.26 1,532.58 5,557.45 33.68 1.82 4,961.35 4,896,27 2,111.80 108.20 5,982,947.825 619,004.465 0.43 1,569.78 5,651.85 33.62 1.53 5,039.93 4,974.85 2,164.09 109.73 5,983,000.124 619,005.164 0.18 1,607.83 5,745.53 33.19 1.96 5,118.14 5,053.06 2,215.64 111.30 5,983,051.690 619,005.914 0.52 1,645.39 5,838.82 32.72 1.66 5,196.42 5,131.34 2,266.36 112.90 5,983,102427 619,006.712 0.53 1,682.39 5,931.72 32.21 1.98 5,274.80 5,209.72 2,316.20 114.49 5,983,152.283 619,007.504 0.58 1,718.76 6,024.92 31.96 1.27 5,353.76 5,288.88 2,365.69 115.89 5,983,201.780 619,008.123 0.49 1,754.74 6,117.54 31.44 0.96 5,432.57 5,367.49 2,41435 116.84 5,983,250.445 619,008.298 0.59 1,789.82 6,209.51 30.93 0.81 5,511.25 5,446.17 2,461.96 117.58 5,983,298.063 619,008.278 0.56 1,824.01 6,305.44 30.18 359.88 5,593.85 5,528.77 2,510.73 117.87 5,983,346.822 619,007.802 0.92 1,858.70 6,398.87 29.80 359.02 5,674.78 5,609.70 2,557.43 117.43 5,983,393.503 619,006.614 0.61 1,891.41 6,490.55 29.64 2.13 5,754.40 5,689.32 2,602.86 117.88 5,983,438.936 619,008.346 1.69 1,923,86 6,584.28 29.34 3.27 5,835.99 5,770.91 2,648.95 120.05 5,983,485.048 619,007.785 0.68 1,957.98 6,678.69 28,78 3.42 5,918.52 5,853.44 2,694.71 122.73 5,983,530.846 619,009.732 0.62 1,992.23 6,772.03 28.27 2.28 6,000.54 5,935.46 2,739.22 124.95 5,983,575.374 619,011.244 0.78 2,025.27 6,863.77 27.87 1.34 6,081.49 6,016.41 2,782.36 126.31 5,983,618.532 619,011.925 0.65 2,056.74 4222019 10:12:20AM Page 5 COMPASS 5000.1 Build 81D BP bp Final Survey Report Company: North America - ALASKA- BP Local Co-ordinate Reference: Well 5-105 Project: PBU TVD Reference: KB @ 65.08usft (NABORS CDR2) Site: S MD Reference: KB @ 65.08usft (NABORS CDR2) Well: S-105 North Reference: True Wellbore: 5-105A Survey Calculation Method: Minimum Curvature Design: 5-105A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi TVD TVDSS NIS E/W Northing Beating DLeg V. Sec (usft) (') (') (usft) (usft) (usft) (usft) (usft) (usft) (°1100usft) (usft) 6,957.09 27.56 0.55 6,164.10 6,099.02 2,82575 127.03 5,983,661.928 619,011.953 0.52 2,087.93 7,050.36 28.79 1.63 6,246.32 6,181.24 2,869.78 127.87 5,983,705.960 619,012.100 1.43 2,119.66 7,144.00 29.68 2.70 6,328.03 6,262.95 2,915.48 129.61 5,983,751.676 619,013.108 1.10 2,153.20 7,238.21 29.13 2.21 6,408.36 6,343.28 2,960.71 131.55 5,983,796.929 619,014.330 0.65 2,186.56 7,329.59 27.65 3.34 6,490.51 6,425.43 3,005.06 133.69 5,983,841.298 619,015.765 1.69 2,219.43 7,423.87 27.22 4.37 6,574.19 6,509.11 3,048.40 136.61 5,983,884.674 619,017.994 0.68 2,252.14 7,517.03 26.43 5.87 6,657.32 6,592.24 3,090.27 140.35 5,983,926.595 619,021.072 1.12 2,284.39 7,610.76 25.44 6.29 6,741.61 6,676.53 3,131.03 144.69 5,983,967.417 619,024.763 1.07 2,316.28 Tie-in to Parent Well 5-105 7,648.00 25.42 6.43 6,775.24 6,710.16 3,146.92 146.46 5,983,983.334 619,026.282 0.17 2,328.77 Top of Whipstock - KOP 7,664.88 30.31 5.80 6,790.16 6,725.08 3,154.76 147.30 5,983,991.188 619,026.994 29.02 2,334.91 Interpolated Azimuth 7,694.86 37.62 5.00 6,815.01 6,749.93 3,171.43 148.86 5,984,007.874 819,028.293 24.43 2,347.80 Interpolated Azimuth 7,724.60 45.46 4.40 6,837.25 6,772.17 3,191.07 150.47 5,984,027.536 619,029.588 26.40 2,362.82 Interpolated Azimuth 7,754.84 53.23 3.95 6,856.94 6,791.86 3,213.93 152.13 5,984,050.421 619,030.888 25.72 2,380.17 1st clean survey 7,783.45 60.19 7.21 6,872.63 6,807.55 3,237.71 154.48 5,984,074.233 619,032.861 26.12 2,398.64 7,815.12 67.60 10.41 6,886.56 6,821.48 3,265.79 158.86 5,984,102.372 619,036.791 25.09 2,421.59 7,844.24 74.39 13.18 6,896.04 6,830.96 3,292.72 164.50 5,984,129.385 619,041.999 24.99 2,444.62 7,875.13 82.52 16.57 6,902.22 6,837.14 3,321.93 172.27 5,984,158.721 619,049.308 28.43 2,470.78 7,905.21 90.09 20.04 6,904.16 6,839.08 3,350.41 181.69 5,984,187.337 619,058.277 27.67 2,497.57 7,935.05 96.00 25.38 6,902.57 6,837.49 3,377.87 193.18 5,984,214.980 619,069.330 26.67 2,525.12 7,965.39 100.59 32.01 6,898.19 6,833.11 3,404.19 207.58 5,984,241.521 619,083.303 26.39 2,553.91 7,996.02 99.97 38.66 6,892.72 6,827.64 3,428.76 225.00 5,984,266.363 619,100.331 21.46 2,583.60 8,026.01 I 100.18 45.27 6,887.47 6,822.39 -- 3,450.70 244.73 5,984,288.615 619,119.711 21.71 2,613.07 4/222019 10:12'20AM Page 6 COMPASS 5000.1 Build BID BP bp Final Survey Report Company: North America -ALASKA - BP Local Co-ordinate Reference: Well S-105 Project: PBU ND Reference: KB @ 65.08usft (NABORS CDR2) Site: S MD Reference: K8 @ 65.08usft (NABORS CDR2) Well: 5-105 North Reference: True Wellbore: 5-105A Survey Calculation Method: Minimum Curvature Design: 5-105A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi TVD NDSS NIS E/W Northing Easting DLeg V. Sec (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 8,056.13 100.47 52.79 6,882.06 6,816.98 3,470.12 267.09 5,984,308.380 619,141.754 24.58 2,642.61 8,080.45 99.91 58.97 6,877.76 6,812.68 3,483.54 286.90 5,984,322.110 619,161.344 25.12 2,666.10 8,110.52 98.57 65.00 6,872.92 6,807.84 3,497.47 313.09 5,984,336.454 619,187.307 20.29 2,694.47 8,140.50 100.22 69.60 6,868.03 6,802.95 3,508.88 340.36 5,984,348.298 619,214.397 16.11 2,721.83 8,170.67 100.72 74.10 6,862.54 6,797.46 3,518.12 368.55 5,984,357.984 619,242.428 14.76 2,748.29 8,200.96 100.97 79.11 6,856.84 6,791.76 3,525.01 397.48 5,984,365.331 619,271.242 16.27 2,773.62 8,227.85 101.12 83.11 6,851.68 6,786.60 3,529.09 423.54 5,984,369.822 619,297.241 14.61 2,794.93 8,257.74 101.44 89.02 6,845.83 6,780.75 3,531.10 452.77 5,984,372.297 619,326.432 19.42 2,817.03 8,287.43 100.84 93.74 6,840.09 6,775.01 3,530.40 481.89 5,984,372.057 619,355.551 15.73 2,637.11 8,320.77 100.90 99.36 6,633.80 0,768.72 3,526.67 514.40 5,984,368.841 619,388.117 18.55 2,85747 8,350.83 101.12 103.82 6,828.06 6,762.98 3,520.74 543.30 5,984,363.375 619,417.103 14.58 2,873.71 8,380.99 98.05 104.89 6,823.04 6,757.96 3,513.37 572.11 5,984,356.460 619,446.020 10.76 2,888.86 8,410.50 94.77 104.34 6,819.74 8,754.08 3,505.97 600.48 5,984,349.514 619,474.504 11.27 2,903.70 8,440.42 91.32 103.71 6,818.15 6,753.07 3,498.73 629.46 5,984,342737 619,503.596 11.72 2,919.07 8470.86 87,17 101.49 6,816.55 6,753.47 3,492.09 659.16 5,984,336.571 619,533.391 15.46 2,935.37 8,502.96 84.99 97.62 6,820.75 6,755.67 3,488.77 690.73 5,984,331.758 619,565.041 13.81 2,953.94 8,530.64 85.91 94.96 6,822.95 6,757.87 3,483.75 718.15 5,984,329.171 619,592.507 10.14 2,971,20 8,562.21 87.11 91.27 6,824.87 6,759.79 3,482.04 749.61 5,984,327.960 619,623.986 12.27 2,992.23 8,590.77 86.78 88.57 6,826.39 6,761.31 3,482.08 778.13 5,984,328.452 619,652.496 9.51 3,012.42 8,621.07 86.93 84.51 6,828.05 6,762.97 3,483.91 808.32 5,984,330.757 619,682.654 13.39 3,035.06 8,650.99 87.48 81.27 6,829.51 6,764.43 3,487.60 837.97 5,984,334.925 619,712.239 10.97 3,058.64 8,681.19 87.76 77.27 6,830.77 6,765.69 3,493.22 867.61 5,984,341.011 619,741.784 13.27 3,083.57 8,711.17 88.22 76.95 6,831.82 6,766.74 3,499.91 896.82 5,984,348.157 619,770.879 1.87 3,108.95 8,741.11 87.17 81.55 6,833.02 6,767.94 3,505.48 926.20 5,984,354201 619,800.166 15.75 3,133.67 8,770.75 86.93 86.92 6,834.55 6,769.47 3,508.46 955.64 5,984,357,641 619,829.553 16.11 3,156.59 8,801.09 86.16 91.16 6,836.38 6,771.30 3,508.96 985.91 5,984,358.629 619,859.812 14.18 3,178.36 11,831.33 87.91 96.67 6,837.95 6,772.87 3,506.90 1,016.03 5,984,357.045 619,889.954 19.09 3,198.20 4/222019 10:12:20AM Page 7 COMPASS 5000.1 Build 81D BP Final Survey Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-105 Project: PBU TVD Reference: KB Q 65.08usft (NABORS CDR2) Site: S MD Reference: KB @ 65.O8usft (NABORS CDR2) Well: 5-105 North Reference: True Wellbore: 5-105A Survey Calculation Method: Minimum Curvature Design: 5-105A Database: EDM RSK- Alaska PROD -ANCP7 Survey MD Inc Azi TVD TVDSS N/S Ell Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usfq (usft) (usR) (usft) lush) (°1100usft) (weft) 8,861.00 88.31 101.78 6,838.92 6,773.84 3,502.15 1,045.29 5,984,352.758 619,919.284 17.27 3,215.53 8,890.97 87.39 102.29 6,840.05 6,774.97 3,495.91 1,074.58 5,984,346.980 619,948.668 3.51 3,231.82 8,925.97 88.31 99.68 6,841.36 6,776.28 3,489.24 1,108.91 5,984,340.863 619,983.097 7.90 3,251.39 8,951.11 87.63 98.50 6,842.25 6,777.17 3,485.27 1,133.72 5,984,337.288 620,007.963 5,41 3,266.12 8,981.05 87.11 95.15 6,843.63 6,778.55 3,481.72 1,163.41 5,984,334.206 620,037.706 11.31 3,284.60 9,010.91 89.08 92.93 6,844.62 6,779.54 3,479.62 1,193.18 5,984,332.577 620,067.499 9.94 3,304.17 9,041.27 88.28 88.76 6,845.32 6,780.24 3,479.17 1,223.52 5,984,332.611 620,097.841 13.98 3,325.30 9,070.97 87.11 84.97 6,846.51 6,781.43 3,480.79 1,253.15 5,984,334.704 620,127.435 13.35 3,347.40 9,100.72 87.24 80.44 6,847.98 6,782.90 3,484.56 1,282.61 5,984,338.943 620,156.834 15.21 3,370.90 9,130.77 84.99 76.49 6,850.02 6,784.94 3,490.56 1,311.98 5,984,345.400 620,186.101 15.10 3,395.90 9,160.85 86.78 73.38 6,852.18 6,787.10 3,498.35 1,340.95 5,9174,353.656 620,214.937 11-.91 3,421.90 9,191.00 86.90 69.98 6,853.84 6,788.76 3,507.81 1,369.52 5,984,363.569 620,243.355 11.27 3,448.80 9,220.83 86.90 66.40 6,855.45 6,790.37 3,518.88 1,397.17 5,984,375.070 620,270824 11.98 3,476.17 9,250.68 86.65 63.06 6,857.13 6,792.05 3,531.60 1,424.12 5,984,388.215 620,297.563 11.20 3,504.22 9,281.08 87.27 59.80 6,858.75 6,793.67 3,546.12 1,450.77 5,984,403.151 620,323.984 10.90 3,533.33 9,310.74 88.16 56.67 6,859.93 6,794.85 3,561.71 1,475.97 5,984,419.148 620,348.925 10.96 3,562.18 9,341.02 68.19 52.84 6,860.89 6,795.81 3,579.18 1,500.68 5,964,436.998 620,373.355 12.64 3,592.00 9,370.85 87.73 48.27 6,861.96 6,796.88 3,598.11 1,523.69 5,984,456.295 620,396.064 15.39 3,621.66 9,401.01 89.29 44.13 6,862.74 6,797.66 3,618.97 1,545.45 5,984,477499 520,417.484 14.66 3,651.80 9,433.38 89.02 40.38 6,863.22 6,798.14 3,642.93 1,567.21 5,984,501.791 620,438.859 11.61 3,684.12 9,460.92 90.12 38.59 6,863.42 6,798.34 3,664.18 1,564.72 5,984,523.318 620,456.029 7.63 3,711.53 9,491.09 87.85 35.81 6,863.96 6,798.88 3,688.20 1,602.96 5,984,547.626 620,473.879 11.89 3,741.41 9,520.70 91.07 34.54 6,864.24 6,799.16 3,712.40 1,620.01 5,984,572.090 620,490.545 11.69 3,770.58 9,551.81 90.71 30.71 6,863.75 6,798.67 3,738.60 1,636.78 5,984,598.544 620,506.893 12.36 3,800.96 9,581.00 89.39 25.25 6,863.73 6,798.65 3,764.36 1,650.47 5,984,624.524 620,520.171 19.24 3,828.86 9,610.52 90.34 21.33 6,863.80 6,798.72 3,791.47 1,662.14 5,984,651.812 620,531.407 13.68 3,856.28 9,640.30 91.04 17.49 6,863.44 6,798.36 3,819.55 1,672.03 5,984,680.043 620,540.853 13.11 3,883.13 412212019 10:12:20AM Page 8 COMPASS 5000.1 Build 81D BP bp Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well S-105 Project: Pau ND Reference: KB @ 65.08usft (NABORS CDR2) Site: S MD Reference: KB @ 65.08usft (NABORS CDR2) Well: 5-105 North Reference: True Wellbore: 5-105A Survey Calculation Method: Minimum Curvature Design: 5-105A Database: EDM RSK- Alaska PROD -ANCPt Survey MD Inc Ali ND TVDSS N/S E/W Northing Easting DLeg V. Sao (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) (°1100usit) WWI) 9,670.44 94.21 15.74 6,862.06 6,796.98 3,84840 1,680.64 5,984,709.020 620,549.002 12.01 3,909.62 9,701.00 94.56 11.23 6,859.72 6,794.64 3,878.02 1,687.74 5,984,738.749 620,555.634 14.76 3,935.59 9,730.39 94.97 8.32 6,857.28 6,792.20 3,906.88 1,692.71 5,984,767.682 620,560.147 9.97 3,959.51 9,760.91 91.41 8.10 6,855.58 6,790.50 3,937.04 1,697.07 5,984,797.900 620,564.016 11.69 3,983.91 9,790.30 89.97 4.54 6,855.23 6,790.15 3,966.24 1,700.30 5,984,827.149 620,566.788 13.07 4,006.85 9,822.36 87.48 0.28 6,855.94 6,790.86 3,998.25 1,701.85 5,984,859.178 620,567.628 15.39 4,030.44 9,880.91 90.86 354.91 6,856.79 6,791.71 4,056.72 1,699.19 5,984,917.589 620,564.243 10.84 4,070.04 9,912.11 92.24 352.47 6,855.95 6,790.87 4,087.71 1,695.76 5,984,948.525 620,560.325 8.98 4,089.54 9,940.80 91.66 351.00 6,854.97 6,789.89 4,116.09 1,691.64 5,984,976.828 620,555.753 5.51 4,106.66 9,970.92 92.39 351.85 6,853.90 6,788.82 4,145.85 1,687.15 5,985,006.515 620,550.794 3.72 4,124.56 10,000.67 91.54 353.49 6,852.88 6,787.80 4,175.34 1,683.36 5,985,035.936 620,546.533 6.21 4,142.73 10,030.80 90.09 358.80 6,85246 6,787.38 4,205.38 1,681.28 5,985,065.942 620,543.980 17.63 4,162.50 10,060.87 90.98 3.31 6,852.17 6,787.09 4,235.44 1,681.78 5,985,095.999 620,544.003 15.94 4,184.11 10,091.09 90.71 8.40 6,851.73 6,786.55 4,265.49 1,684.87 5,985,126.091 620,546.607 16.86 4,207.54 10,122.78 90.77 13.87 6,851.32 6,786.24 4,296.57 1,690.98 5,985,157.260 620,552.230 17.26 4,233.84 10,151.01 89.48 16.53 6,851.26 6,786.18 4,323.81 1,698.38 5,985,184.611 620,559.196 1047 4,258.33 10,180.99 86.99 15.66 6,852.18 6,787.10 4,352.60 1,706.69 5,985,213.526 620,567.044 8.80 4,284.56 10,210.88 85.20 13.48 6,854.22 6,789.14 4,381.45 1,714.19 5,985,242.497 620,574.066 9.42 4,310.27 10,240.95 86.06 11.00 6,856.51 6,791.43 4,410.75 1,720.55 5,985,271.891 620,579.975 8.71 4,335.48 10,271.07 86.13 8.21 6,858.56 6,793.48 4,440.38 1,725.56 5,985,301.590 620,584.518 9.24 4,359.98 10,295.47 88.74 5.94 6,859.65 6,794.57 4,464.57 1,728.56 5,985,325.819 620,587.134 14.17 4,379.20 10,330.84 89.26 1.37 6,860.27 6,795.19 4,499.85 1,730.82 5,985,361.130 620,588.827 13.00 4,405.75 10,361.84 89.36 357.51 6,860.64 6,795.56 4,530.84 1,730.51 5,985,392.110 620,588.033 12.45 4,427.44 10,390.74 86.96 356.32 6,861.57 6,796.49 4,559.68 1,728.96 5,985,420.919 620,586.021 9.27 4,446.74 10,420.36 86.35 352.17 6,863.30 6,798.22 4,589.09 1,726.00 5,985,450.280 620,582.591 14.14 4,465.44 10,450.08 85.82 348.41 6,865.33 6,800.25 4,618.31 1,721.00 5,985,479.415 620,577.128 12.75 4,482.57 10,480.94 84.22 345.63 6,868.01 6,802.93 4,648.27 1,714.09 5,985,509.253 620,569.750 10.36 4,498.87 4222019 10: 12,20AM Page 9 COMPASS 5000.1 Build 81D by Company: North America - ALASKA - BP Project: PBU Site: S Well: 5-105 Wellbore: 5-105A Design: 5-105A Survey MD Inc Azi (usft) 1°I (9 10,510.75 84.47 342.40 10,559.00 84.47 342.40 Projection to TD BP Final Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: wells -105 KB @ 65.08usft (NABORS CDR2) KB C 65.08usft (NABORS CDR2) True Minimum Curvature EDM R5K - Alaska PROD - ANCP1 TVD TVDSS NIS EMI Northing Basting DLsg V. Sec (usft) (usft) (waft) (usft) (usft) (usft) (°NOOusft) (usft) 6,870.95 6,805.87 4676.76 1,705.92 5,985,537.632 620,561.131 10.82 4,51325 6,87560 6,810.52 4,722.56 1,69140 5,985,583.169 620,545.686 0.00 4,535.36 4222019 10..12:20AM Page 10 COMPASS 5000.1 Build 81D Plojnot: PBU Win, W419DRE DES -i &105A b►1 61111:6 wyiy 5,65A Y W011: 5106 ge�9ma. WBllbore: 5106A om 5105 DaslOn: S106A waa�i Te on MD: 7810.'!6 fEfE6@L66FORM,m CoaWaelRp6Nm�: WISI05 ti North America - ALASKA - BP PBU S 5-105 S -105A S -105A 500292297701 AOGCC Offset Well Report 23 April, 2019 5 .a Company: North America - ALASKA - BP Project: PBU Reference Site: S Site Error. 0.0i Reference Well: 5-105 Well Error: 0.00usft Reference Wellbore 5-105A Reference Design: 5-105A BP Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 5-105 KB @ 65.01(NABORS CDR2) KB @ 65.08usft (NABORS CDR2) True Minimum Curvature 1.00 sigma EDM R5K-Alaska PROD -ANCP1 Offset Datum Reference S -105A Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tmv. Cylinder North Results Limited by: Maximum center -center distance of 500.001 Error Surface: Elliptical Conic Survey Program Date 4/23/2019 From To (usR) (usft) Survey (Wellbore) Tool Name Description 147.03 7,610.76 Survey#1 MWD+IFR:AK(S-105) MWD+IFR:AK MWD + IFR [Alaska] 7,646.00 10,559.00 Survey #1 1 MWD MWD -Standard 423/2019 12:29:36AM Page 2 01 3 COMPASS 5000.1 Build 81D BP bp Anticollision Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-105 Project: PBU TVD Reference: KB @ 65.08usft (NABORS CDR2) Reference Site: S MD Reference: KB (off 65.08usft (NABORS CDR2) Site Error: 0,00usft North Reference: True Reference Well: 5-105 Survey Calculation Method: Minimum Curvature Well Error: Goousft Output errors are at 1.00 sigma Reference Wellbore S -105A Database: EDM RSK- Alaska PROD -ANCPI Reference Design: 5-105A Offset TVD Reference: Offset Datum Summary Reference Offset Centre to Measured Measured Centre Site Name Depth Depth Distance Offset Well -Wellbore - Design (usft) (usft) (usft) EX NKUPST NKUPST-NKUPST-NKUPST 7,675.00 6,800.00 436.78 S 5-100 - 5-100 - 5-100 1,063.50 1,075.00 168.26 S-101 - 5.101 - 5-101 123.71 125.00 211.10 5-101-5-101 Pet -S-101PB1 123.71 125.00 211.10 5-102 - 5-102 - 5-102 1,544.44 1,575.00 143.06 5-102 - 5-10211 - 5-10211 1,544.44 1,57500 143.06 5-102 - 5-10211 PB1 - 5-1021-1 PBl 1,544.44 1,575.00 143D6 5-102 - 5-102PB1 - 5-102PB1 1,544.44 1,575.00 143.06 5-103-5-103-5-103 1,173.71 1,175.00 57.13 5-104 - 5-104 - 5-104 375.72 375.00 13.04 5-106 - 5-106 - 5-106 394.22 400.00 30.91 5-106-5-106PB1-S-106PB1 394.22 400.00 30.91 5-107 - 5-107 - 5-107 789.74 800.00 69.59 5-108 - 5-108 - 5-108 918.71 925.00 125.15 5-108 - 5-108A' - 5-108A 28.76 28.78 119.49 S-109 - 5-109 - 5-109 223.63 225.00 165.88 5-109-5-109PB1-S-109PBI 223.63 225.00 165.88 5-110 - 5-110 - 5-110 193.70 200.00 151.99 5 -110 -5 -110A -S -110A 193.05 200.00 151.98 5-110 - 5-1108 - 5-110B 180.13 200.00 151.72 5-111 - S-111 - 5-111 1,217.25 1,225.00 61.79 5-111 - S-111 Pet - 5-111PB1 1,217.25 1,225.00 61.79 5-111-S-111 PB2-S-111PB2 1,217.25 1,225.00 61.79 S-113 - 5-113 - 5-113 518.59 525.00 89.56 5-113 - S -113A - 5-113A 518.59 525.00 89.56 5-113 - 5-1138 - 5-1138 518.59 525.00 89.56 5-113 - 5-113611 - S-113BL1 518.59 525.00 89.56 5-114 - 5-114 - 5-114 394.65 400.00 16.55 S-114 - 5-114A - 5-114A 394.65 400.00 16.55 5-115-5-115-S-115 1,185.92 1,200.00 238.02 5-117 - 5-117 - 5-117 673.34 675.00 262.98 5-119 - 5-119 - 5-119 696.42 700.00 131.69 S-120 - 5-120 - S-120 892.35 900.00 274.41 5-121 - 5-121 - 5-121 619.98 625.00 378.07 5-121-5-121 PBI -S-121 Pet 619.98 625.00 378.07 5-122 - 5-122 - 5-122 222.85 225.00 241.13 5-122-5-122PB1-S-122PBl 222.85 225.00 241.13 5-122 - 5-122PB2 - 5-122PB2 222.85 225.00 241.13 5-122-5-122PB3-S-122PB3 222.85 225.00 241.13 5-200-S-200-5-200 1,208.67 1,225.00 320.22 5 -200 -5 -200A -S -200A 1,21688 1,250.00 320.32 5-200-5-200PB1-S-200P81 1,208.67 1,225.00 320.22 5 -201 -Plan S -201A - S-201 A WP05 1,155.95 1,175.00 23.01 5-201 - 5-201 - 5-201 1,174.44 1,175.00 23.16 5-201-5-201 PB1-S-201 PBI 1,174.44 1,175.00 23.16 5-213 - 5-213 - S-213 1,096.65 1,100.00 296.16 5 -213 -5.213A -S -213A 1,100.00 1,100.00 296.20 5-213-5-213ALI-S-213ALl 1,100.00 1,100.00 296.20 5-213-5-213ALl-01-5-213ALl-01 1,100.00 1,100.00 296.20 5-213-5-213AL2-S-213AL2 1,100.00 1,100.00 295.20 5-213-5-213AL3-S-213AL3 1,100.00 1,100.00 296.20 4232019 12.29:36AM Page 3 of 3 COMPASS 5000.1 Build 81D Printed 5/92019 1:33:OOPM Nath America - ALASKA- BP P*gs 1 of 2 Cementing Report Common Well Name: 5-105 / 01 Report no.: 1 Report tlete. 4/23/2019 Project: PBU } Site: S Spud Date/time: 10/25/2000 Event Type: COM- ONSHORE (CON) Stan Date: 4/22/2019 End Date: 4/27/2019 Rig Name/No.: CDR -2 Rig Release: 4/272019 AFE No.: X3-019C&C: (1,957,577.00) Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.08usft (above Mean Sea Level) General Inkmmetlon Job type: Primary Cement job start date/time: 4/23/2019 3 45A Job end dateltime: 4/23/2019 7:OOAM Cement Company: SCHLUMBERGER Cementer: SHANE LOFGREN Cemented String. PRODUCTION LINER 1 String Size: 2.375 (in) String Set TMD: 10,559.00 (usft) Hole Size: 3.250 (in) Pip* Mw4wnenl Pipe Movement: NO MOVEMENT Rotating Time (Start -End): RPM: Rotating Torque (init/avg/max): (ft-lbf) Reciprocating Time (Start -End): Recip Drag Up/Down: - (kip) SPM: Stroke Length: Fluid Hams: CEMENT FBdm (1 of 1) Slurry Type: CEMENT Purpose: PRIMARY Class: G -CLASS Description: TAIL SLURRY Density: 15.30(ppg) Yield 1.3100 (fN/sk) Mix Water Ratio: 4.305 (gal/sk94) Excess: 20.00(%) Mix Method: BATCH Sacks Used 80.00 (941b sacks) Water Volume: 8.2 (bbl) Excess Slurry Volume: 3.1 (bbl) Density Measured by. DENSOMETER Other Volume: Total Vol in Well: Slurry Volume: 18.7 (bbl) Excess Measured From: EST. GAUGE HOLE Mud Type: Density: PV: YP: Viscosity: Gels 10 Sec: Gels 10 Min: Addttiv*s Name Type Amount Units Concentration Unit D163 CEMENT 5.000 % BWOC D047 ANTIFOAMAGENT 0.100 GAUSX D206 ANTIFOAMAGENT 0.100 GAUSX D065 DISPERSANT 1.000 %BWOC D600 G GAS -BLOCK 1.500 GAUSX D187 FLUID LOSS 0.100 % BWOC Fluid Tests Thick time Thick Free water Free water Fluid loss Fluid loss Fluid loss Camp Comp Comp Comp Comp Strength Comp Strength (hr) temp. (%) temp. (cd30min) temp. press. Strength Strength Strength Strength Time Pressure 2 Temperature 2 (°F) ('F) ("F) (psi) Time 1 Pressure 1 Temperature 1 2 (psi) ('F) min 'F min 5.17 139.00 0.00 80.00 40.0 139.00 Printed 5/92019 1:33:OOPM Printed 5/92019 1:33:OOPM Page 2 or 2 North America - ALASKA - BP Cementing Report Common —Welwll Name: 5-105! 01 Report no.: 1 Report date: 4/23/2019 Project: PBU Site. S Spud DeteRime: 10/25/2000 Event Type: COM- ONSHORE (CON) Start Date: 4/22/2079 ,End Date: 4/27/2079 AFE No.: Contractor. NABORSAtASKA DRILLING INC. Rig Name/No.. CDR -2 Rig Release: 41272019 X3 -019C8 -C: (1,957,577.00 ) BPUOI: USA00000133 i Active datum: KB (d 65.OBusft (above Mean Sea Level) at.ges Stage Stage Type Est. Top Est, Bottom Mud Circ. Mud Circ. Top Bottom Plug Pressure Floet Pressure Retums Circulate Cmt Vol to Total Annular no. (usft) (usft) Rate Press, Plug Plug Bumped Bumped Ham Ham Prior Surface Mud Lost Flow (gpm) (psi) I (hr) (bbl) (bbl) After (p -i) (min) 1 RIMARYCEMENT 7,599.00 10,559.00 Y Plunging Schedule Fluid pumped Volume Avg. Max Disp. Slurry Top Slurry Base Start Mix Cmt Start Slurry Pumping end Start Disp Foam Gas Type Gas Vol BH circ. Bh static Pumped Disp. Rete TMD TMD Pmp date/time job Used temp. temp. (bbl) Rate (bbl/mii (usft) (usft) (scf) bbUmin Tests Cuing Test Shoo Test Liner Top Teat Test Pressure: (psi) FIT/LOT: (ppg) Liner Overlap: (usft) Time: (min) Tool: N Positive Test: (ppg) Positive Test Tool: N Cement Found between Shoe and Collar: N Open Hole Length: (usft) Negative Test: (ppg) Negative Test Tool: N Hours Before Start: (hr) Time before test: (hr) Cmt Found on Tool: N Log/Sumay Evaluation Interpretation Summary CBL Run: N Cement Top: (usft) Under Pressure. (psi) How Determined: Bond Quality: TOC Sufficient: N CET Run: N Job Rating: Bond Quality: If Unsuccessful, Detection Indicator: Temp Survey: N Remedial Cement Required: N Him Prior to Log: (hr) How Determined: Printed 5/92019 1:33:OOPM THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean McLaughlin CTD & RWO SDE BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .00gcc.olaska.gov Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S -105A BP Exploration (Alaska), Inc. Permit to Drill Number: 219-032 Revised Surface Location: 4631' FSL, 4496' FEL, SEC. 35, T12N, RUE, UM Bottomhole Location: 4073' FSL, 2798' FEL, SEC. 26, TI 2N, RI 2E, UM Dear Mr. McLaughlin: 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, Daniel T. Seamount, Jr. Commissioner DATED this day of April, 2019. HMUCo v mem APR 2 2 2019 STATE OF ALASKA 'ASKA OIL AND GAS CONSERVATION COMMISS PERMIT TO DRILL 20 AAC 25.005 REVISED Change of Directional Plan over 500' la. Typ p00brk: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp❑ 1c. Specify if well is proposed for: Dnll T, Lateral O - Stratigraphic Test ❑ Development - Oil 0 Service -Winj ❑ Single Zone 0 Coalbed Gas ❑ Gas Hydrates❑ Rednll 0 Reentry ❑ Exploratory - oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5, Bond Blanket 0 Single Well ❑ 11. Well Name and Number: BP Exploration (Alaska), Inc Bond No. 295105380 • PBU S -105A 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196612 Anchorage, AK 99519-6612 MD: 10559' - TVD: 6876' PRUDHOE BAY, AURORA OIL 4a Location of Well (Governmental Section): 7. Property Designation (Lease Number): AOL 028257 8. DNR Approval Number: 13. Approximate spud date: Surface: 4631' FSL, 4496' FEL, Sec. 35, T112N, R1 2E, UM 2491' FSL, 4344' FEL, Sec. 26, T12N, R1 2E, UM 83-47 April 17, 2019 Top of Productive Horizon: 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 4073' FSL, 2798' FEL, Sec. 26, T1214, R12E, UM 6800 4b Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 65.08 feet 15. Distance to Nearest Well Open to Same Pool: Surface: x- 618930 y- 5980835 Zone - ASP 4 GL Elevation above MSL: 36 feet 450 15. Deviated wells: Kickoff Depth: 7650 feel 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 101 degrees Downhole: 3066 Surface: 2382 18, Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade COUDlino Len th MD TVD MD TVD(including stage data 3-1/4" 2-3/8" 4.4# L-60 HYD511 2960' 7599' 6731' 10559' 6876' 97 sx Class'G' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Rednll and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 8120 7203 7648 7646 8773 7687 Casing Length Size Cement Volume MD TVD Conductor/Structural 79 20" 260 sx Arctic Set (Aoorox.) 28-107 28-107 Surface 2969 9.5/6' 405 sx AS Liter III. 240 sx Class'G' 28-2996 28-2833 Intermediate Production 8077 7" 497 sx Class'G' 26-8103 26-7188 Liner Perforation Depth MD (ft): 7650-7722 Perforation Depth TVD (ft): 6777-6842 Hydraulic Fracture planned? Yes ❑ No 0 20. Attachments Property Plat ❑ BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Name Ciolkosz. Ryan R from without prior written approval. Contact Email Ryan.Ciolkosz@)bp.cem Authorized Name Mdaughlin, Sean M Authorized Title Eng i eenng Team Lead - CTD Contact Phone +1 907 564 5977 Authorized Signature Date Commission Use my Permit to Drill Permit Approval n See cover letter for other Number: 219-032 ✓ API: 50- 029-22977-01-00 Date: // requirements: I Conditions of approval : If box is checked, well may not be used to explore for, test, or prouce coalbed methane, gas hydrates, or gas contained in shales: lir Other: �© rpT `� O ' Samples req'd: Yes ❑ No ISK Mud log regd: Yes ❑ No 6Y H2S measures Yes Q� No ❑ Directional svy req'd: Yes 8' No ❑ /� W' �'7�I>.f$pacingexceptionmq'd: Yes ❑ No Inclination-onlysvyreq'd: Yes ❑ No V J6_t'10 �/7A.f r1�1C a �l^'r4" Yes ❑ No ❑ Post initial injection MIT mq'd: APPROVED BY Approvetl by: COMMISSIONER THE COMMISSION Date: Form 10-401 Revised 5/2017 This permit is valid foO n oR4 G IhNALval (20 AAC 25.005(g) Submit Form and /� Attachments in Duplicate 111- v/�TJ•/t,y`d'��.6_ N'�z�I19 To: Alaska Oil & Gas Conservation Commission P From: Ryan Ciolkosz CTD EngineerA�0*4116 Date: April 22, 2019 Re: S -105A Permit to Drill Approval Approval is requested for a permit to drill a CTD sidetrack from well S-105. Parent well, S-105, is a Kuparuk Zone C producer completed in 2000. It currently has 40' of open perfs in the Kuparuk Zone C. The intent of the S -105A wellbore is to access reserves outside the parent wellbore's 500' drainage radius. The parent reserves will be accessed via frac job near parent in the S -105A wellbore. Drill a through tubing sidetrack with the CDR 2 Coiled Tubing Drilling rig on April 4th, 2019. CDR2 set the whipstock. CDR 2 milled a 2.74" window in the 7" liner and drilled a Kuparuk well to —10,559 ' MD. Proposed Plan: The lateral will be completed with a 2-3/8" 4.7# L-80 liner which will be cemented and The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre Rig Work 1 F MIT -IA 2 S Drift for whipstock & caliper to whipstock setting depth 3 E Set NS whipstock Wedge. Set on rig 4 V Pre CTD Tree Work/set TWC Rig Work: 1. MIRU and test BOPE. Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,382 psi. 2. Set W hisptock and Cement in place 3. Mill 2.74" window plus 10' of rathole. Swap the well to 8.7-9.5 ppg drilling fluid. 4. PU drilling BHA with GR/Resistivity 5. Drill 3.25" hole to TD at 10,559 MD 6. Run 2-3/8" L-80 liner. 7. Pump primary cement bringing TOC to TOL, 20 bbls of 15.3 ppg liner cmt planned* 8. Will not be performing a Test liner lap to 2,400 psi. 9. Perforate liner per asset instructions 10. Freeze protect well, RDMO Post Rig: 1. V: Tree work, pull TWC/BPV as necessary 2. SL: Set LGLVs, set LTP (if fail lap); 3.5" WFD widepak LTP with PTSA stinger. Regulatory compliance SBHPS (review state requirements, as there is an effort to drop this requirement in the CO) 3. F: assist SL: PT LTP 4. T: Portable is flowback (plan to perf 1300 ft) 5. F: SIT 6. C: Set CBP/CIBP such that heel perfs are the only thing flowing. 7. C: mill plug to bottom (so we can produce well until frac is ready to execute) 8. S: Dummy GI -Vs 9. C: set CBP. Pert if necessary 10. Special projects: Frac (1 stage) 11. C: Clean out, mill CBP to bottom 12. S: Set LGLVs, regulatory compliance SBHPS. 13. T: Post frac flowback 14. F: SIT post frac (� * Approved alternate plug placement per 20 AAC 25.112(i) Mud Program: J • Well kill: 8.9 ppg brine. • Milling/drilling: 8.9 ppg drilling fluid for milling window and drilling (103 psi over -balance ) Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3.25" Liner Program: • 2-3/8", 4.4#, L-80, HYD511 Solid Liner 7599' MD - 10559' MD • A minimum of 20 bbls of 15.3 ppg cement will be used for liner cementing. (TOC =TOL) • The primary barrier for this operation: a minimum EMW of 8.9 ppg. • A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 102°. • Magnetic and inclination surveys will be taken every 30 ft. • Distance to nearest property — 6800' • Distance to nearest well within pool — 450' NKUPST Logging • MWD directional, Gamma Ray and Resistivity will be run over the entire open hole section. Perforating: 1.56" Perfecta, 1" CSH work string • The primary barrier for this operation: a minimum EMW of 8.9 ppg. A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti -Collision Failures • All wells pass BP Anti -Collison Risk Requirements. The planned S -105A Trajectory is within 415ft of the NKUPST wellbore. The NKUPST has been permanently abandoned to surface. Hazards • S pad is an H2S pad. Reservoir Pressure • The reservoir pressure is expected to be 3,066 psi at 6849' TVDSS. (8.61 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,382 psi. • An EMW of 8.9 ppg for this well will provide 103 psi over -balance to the reservoir. Managed Pressure Drilling — • MPD techniques may be used to improve hole stability. Ryan Ciolkosz CTD Engineer 564-5977 CC: Well File Joe Lastufka by North America - ALASKA - BP PBU S S-105 S -105A 500292297700 Design: S -105A Final Survey Report 22 April, 2019 5 Company: North America - ALASKA - BP Project: Pau Site: S Well: 5-105 Wellbore: 5-105A Design: 5-105A BP Final Survey Report Local Coordinate Reference: Well 5-105 TVD Reference: KB @ 65.08usft (NABORS CDR2) MD Reference: KB @ 65.08usft (NABORS CDR2) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Project PBU, PBU, PRUDHOE Map System: Alaska NA027 State Plane Zones System Datum: Mean Sea Level Geo Datum: NAD27 ` OGP-Usa AK 14267'158641 Using Well Reference Point Map Zone: NAD27'OGP-Usa AK/ Alaska zone 4(26734'1586, Using geodetic scale factor Site S, TR -12-12 Site Position: From: Map Position Uncertainty: 0.00 usft Well S-105, Slot 22 as -built Well Position +N/ -S 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.00 usft Wellbore 5-105A Magnetics Model Name Sample Date BGGM2018 5/1/2019 Design 5-105A Audit Notes: Version: 1.0 Phase: Vertical Section: Depth From (TVD) (usft) 27 17 Northing: 5,980,854.540 usft Easting: 617,919.920 usft Slot Radius: 0.000 in Northing: 5,980,834.750 usft Elating: 618,929.810 usft Wellhead Elevation: 37.91 usft Declination l°) 1680 ACTUAL +N/ -S (usft) 000 Latitude: Longitude: Grid Convergence: Latitude: Longitude: Ground Level: Dip Angle Field Strength 1°I (nT) 80.93 57,428 Tie On Depth: 7,610.76 +E/ -W Direction (usft) (°) 000 45.00 70° 21'23,002 N 149' 2'32,343 W 0.90 ` 70" 21'22.651 N 149° 2' 2.831 W 36.00 usft 4222019 10'12:20AM Page 2 COMPASS 5000.1 Build 81D e BP Final Survey Report Company: North America -ALASKA -BP Local Coordinate Reference: Well S-105 Project: PBU TVD Reference: KB @ 65.08usft (NABORS CDR2) Site: S MD Reference: KB @ 65.08usft (NABORS CDR2) Well 5-105 North Reference: True Wellbore. 5-105A Survey Calculation Method Minimum Curvature Design: 5-105A Database: EDM RSK- Alaska PROD -ANCP1 Survey Program Data 4/22/2019 (usft) From To (•I100usft) (usft) loan) Survey (Wellbore) Tool Name Description 0.00 147.03 7,610.76 Survey#1 MWD+IFRAK(5-105) MWD+IFR:AK MWD + IFR [Alaska] 0.00 7,646.00 10,559.00 Survey#1 (S -105A) MWD MWD - Standard survey MD Inc Azi TVD TVDSS NIS EIWW Northing Seating DLeg (usft) (•) (•) (usft) (usft) (waft) (usft) (usft) (usft) (•I100usft) 27.17 0.00 0.00 27.17 -37.91 0.00 0.00 5,980,834.750 618,929.810 0.00 147.03 0.66 4.14 147.03 81.95 0.69 0.05 5,980,835.439 618,929.849 0.55 235.10 0.73 11.24 235.09 170.01 1.74 0.20 5,980,836.497 618,929.978 0.13 330.82 0.72 26.25 330.80 265.72 2.88 0.58 5,980,837.640 618,930.345 0.20 423.45 0.52 38.43 423.43 358.35 3.80 1.15 5,980,838.564 618,930.899 0.19 519.39 0.73 46.02 519.36 454.28 4.63 1.91 5,980,839.407 618,931.648 0.15 612.54 0.87 50.52 612.50 547.42 5.49 2.88 5,980,840.284 618,932.607 0.16 705.00 1.16 67.43 704.95 639,87 6.29 4.29 5,980,841.111 618,934.000 0.45 799.27 1.45 73,09 799.19 734.11 7.01 6.31 5,980,841.857 618,936.011 0.34 893.81 1.39 78.43 893.70 828.82 7.59 8.58 5,980,842.470 618,938.269 0.15 975.27 1.19 84.61 975.14 910.06 7.86 10.39 5,980,842.777 618,940.074 0.30 1,071.68 0.87 83.56 1,071.54 1,006.46 8.04 12.12 5,980,842.980 618,941.795 0.33 1,166.14 1.56 4.83 1,165.98 1,100.90 9.40 12.94 5,980,844.355 618,942.594 1.73 1,258.82 3.87 349.19 1,258.55 1,193.47 13.73 12.46 5,980,848.676 618,942.045 2.59 1,353.61 4.81 350.70 1,353.07 1,287.99 20.80 11.21 5,980,855.719 618,940.691 1.00 1,444.26 8.63 352.72 1,443.08 1,378.00 31.30 9.74 5,980,866.194 618,939.048 4.22 1,540.46 10.17 357.07 1,537.99 1,472.91 46.94 8.39 5,980,881.812 618,937.451 1.76 1,633.36 12.29 1.85 1,629.10 1,564.02 65.01 8.29 5,980,899.882 618,937.064 2.49 1,726.65 20.09 5.71 1,718.63 1,653.55 90.92 10.21 5,980,925.814 618,938.570 8.44 1,757.71 20.97 6.25 1,747.71 1,682.63 101.75 11.34 5,980,936.663 618,939.534 2.90 1,819.27 21.34 3.86 1,805.13 1,740.05 123.88 13.29 5,980,958.815 618,941.135 1.52 V. Sec (usft) 000 0.52 1.37 2.45 3.50 462 592 7.49 9.42 11.43 12.91 14.25 15.80 18.52 2263 29.01 39.12 51.83 71.51 79.97 97.00 422/2019 10.12.20AM Page 3 COMPASS 5000.1 Build SID M BP Final Survey Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-105 Project: PSU TVD Reference: K8 @ 65.08usft (NABORS CDR2) Site: S MD Reference: KB @ 65,08usft (NABORS CDR2) Well: 5-105 North Reference: True Wellbore: 5-105A Survey Calculation Method: Minimum Curvature Design: 5-105A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azl TVD TVDSS NIS E/W Northing Easting DLeg V. Sec (usft) (•) (•) (usft) (usft) (usft) (usft) (usft) (usft) (ollo0usft) (usft) 1,915.30 21.08 2.47 1,894.65 1,829.57 158.57 15.22 5,980,993.526 618,942.505 0.59 122.88 2,006.61 22.58 3.50 1,979.41 1,914.33 192.47 16.99 5,981,027.452 618,943.744 170 148.11 2,098.79 25.30 4.05 2,063.65 1,998.57 229.79 19.47 5,981,064.802 618,945.623 2.96 176.25 2,190.83 27.63 368 2,146.04 2,080.96 270.71 22.22 5,981,105.759 618,947.732 2.54 207.14 2,285.93 29.42 1.88 2,229.60 2,164.52 316.07 24.41 5,981,151.140 618,949.193 2.09 240.75 2,378.87 30.42 2.18 2,310.15 2,245.07 362.40 26.05 5,981,197.484 618,950.102 1.09 274.67 2,474.05 31.86 2.31 2,391.61 2,326.53 411.58 27.98 5,981,246.685 618,951.250 1.51 310.81 2,565.92 30.82 2.85 2,470.08 2,405.00 459.31 30.13 5,981,294.443 618,952.639 1.17 346.09 2,660.07 31.97 3.13 2,550.44 2,485.36 506.29 32.69 5,981,343.452 618,954.421 1.23 382.53 2,754.91 33.14 1.62 2,630.38 2,565.30 559.28 34.79 5,981,394.461 618,955.715 1.50 420.07 2,848.19 32.99 1.25 2,708.55 2,643.47 610.15 36.07 5,981,445.347 618,956.182 0.27 456.95 2,930.77 32.67 1.21 2,777.94 2,712.86 654.91 37.03 5,981,490.113 618,956.432 0.39 489.28 3,037.20 33.67 1.52 2,867.03 2,801.95 713.13 38.42 5,981,548.336 618,956.897 0.95 531.42 3,131.32 34.45 2.18 2,945.00 2,879.92 765.81 40,12 5,981,601.036 618,957.765 0.92 569.88 3,225.16 33.97 1.26 3,022.61 2,957.53 818.54 4171 5,981,653.784 618,958.514 0.75 608.29 3,318.67 33.40 2.76 3,100.42 3,035.34 870.37 43.52 5,981,705.630 618,959.505 1.08 646.22 3,411.15 32.71 1.92 3,177.93 3,112.85 920.77 45.58 5,981,756.051 618,960.767 0.90 683.32 3,504.47 31.88 2.04 3,256.81 3,191.73 970.60 47.31 5,981,805.897 618,961.698 0.89 719.77 3,596.95 34.21 0.81 3,334.33 3,269.25 1,021.01 48.54 5,981,856.314 618,962.134 2.62 75629 3,690.64 35.08 1.40 3,411.57 3,346.49 1,074.37 49.58 5,981,909.683 618,962.319 0.99 794.75 3,785.46 34.68 0.61 3,489.19 3,424.11 1,128.47 50.53 5,981,963.787 618,962.411 0.64 833.68 3,879.39 33.74 0.47 3,566.87 3,501.79 1,181.28 51.02 5,982,016.591 618,962.071 1.00 871.37 3,972.08 34.33 2.09 3,643.69 3,578.61 1,233.14 52.19 5,962,068.460 616,962.412 1.17 908.87 4,065.41 33.19 2.74 3,721.28 3,656.20 1,284.96 54.37 5,962,120.301 618,963.770 1.28 947.05 4,157.85 31.47 3.81 3,799.38 3,734.30 1,334.31 57.18 5,982,169.688 618,965.799 1.96 983.93 4,250.67 32.76 4.89 3,878.00 3,812.92 1,383.51 60.93 5,982,218.937 618,968.768 1.52 1,021.38 4,343.62 36.23 4.45 3,954.60 3,889.52 1,435.97 65.21 5,982,271.452 618,972.210 3.74 1,061.49 4222019 10.12:20AM Page 4 COMPASS 5000.1 Build 81D BP Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well S-105 Project: PBU TVD Reference: KB @ 65.08usft (NABORS CDR2) Site: S MD Reference: KB @ 65.08usft (NABORS CDR2) Well: 5-105 North Reference: True Wellbore: 5-105A Survey Calculation Method: Minimum Curvature Design: 5-105A Database: EDM RSK - Alaska PROD - ANCP1 Survey MD Inc Azi ND NDSS NIS EM Northing Easting DLeg V. Sec (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) ('1100usft) (waft) 4,438.05 36.52 4.81 4,030.63 3,965.55 1491.79 69.73 5,982,327.332 618.975,844 0.38 1,104.16 4,530.55 35.21 5.46 4,105.59 4,040.51 1,545.76 74.58 5,982,381.373 618,979.832 1.47 1,145.75 4,624.09 34.61 5.41 4,182.29 4,117.21 1,599.05 79.65 5,982,434.733 618,984.056 0.64 1,187.02 4,717.40 33.88 6.30 4,259.43 4,194.35 1,651.29 85.00 5,982,487.040 618,988.578 0.95 1,227.74 4,812.11 33.38 6.56 4,338.29 4,273.21 1,703.41 90.87 5,982,539.246 618,993.622 0.55 1,266.75 4,904.60 33.07 6.89 4,415.66 4,350.58 1,753.74 96.81 5,982,589.658 618,998.756 0.39 1,308.53 4,997.49 32.99 3.34 4,493.54 4,428.46 1,804.15 101.32 5,982,640.130 619,002.469 2.08 1,347.37 5,091.70 33.64 0.46 4,572.27 4,507.19 1,855.85 103.03 5,982,691.849 619,003.352 1.82 1,365.14 5,186.57 33.35 0.41 4,651.39 4,586.31 1,908.21 103.42 5,982,744.198 619,002.918 0.31 1,422.44 5,279.03 33.30 1.29 4,728.65 4,663.57 1,959.00 104.18 5,982,794.989 619,002.865 0.53 1,458.68 5,371.02 33.11 1.34 4,805.62 4,740.54 2,009.36 105.33 5,982,845.361 619,003.221 0.21 1,495.31 5,464.85 33.30 1.63 4,884.12 4,819.04 2,060.73 106.66 5,982,896.738 619,003.737 0.26 1,532.58 5,557.45 33.68 1.82 4,961.35 4,896.27 2,111.80 108.20 5,982,947.825 619,004.465 0.43 1,569.78 5,651.85 33.62 1.53 5,039.93 4,974.65 2,164.09 109.73 5,983,000.124 619,005.164 0.18 1,607.83 5,745.53 33.19 1.96 5,118.14 5,053.06 2,215.64 111.30 5,983,051.690 619,005.914 0.52 1,645.39 5,838.82 32.72 1.66 5,196.42 5,131.34 2,266.36 112.90 5,983,102.427 619,006.712 0.53 1,682.39 5,931.72 32.21 1.98 5,274.80 5,209.72 2,316.20 114.49 5,983,152.283 619,007.504 0.58 1,718.76 6,024.92 31.96 1.27 5,353.76 5,288.68 2,365.69 115.89 5,983,201.780 619,008.123 0.49 1,754.74 6,117.54 31.44 0.96 5,432.57 5,367.49 2,414.35 116.84 5,983,250.445 619,008.298 0.59 1,789.82 6,209.51 30.93 0.81 5,511.25 5,446.17 2,461.96 117.58 5,983,298.063 619,008.278 0.56 1,824.01 6,305.44 30.18 359.88 5,593.85 5,528.77 2,510.73 117.87 5,983,346.822 619,007.802 0.92 1,858.70 5,398.87 29.80 359.02 5,674.76 5,609.70 2,557.43 117.43 5,983,393.503 619,006.814 0.61 1,891.41 6,490.55 29.64 2.13 5,754.40 5,689.32 2,602.86 117.88 5,983,438.936 619,006.346 1.69 1,923.86 6,584.28 29.34 3.27 5,835.99 5,770.91 2,648.95 120.05 5,983,485.048 619,007.785 0.68 1,957.98 6,678.69 28.76 3.42 5,918.52 5,853.44 2,694.71 122.73 5,983,530.846 619,009.732 0.62 1,992.23 6,772.03 28.27 2.28 6,000.54 5,935.46 2,739.22 124.95 5,983,575.374 619,011.244 0.78 2,025.27 6,863.77 27.87 1.34 6,081.49 6,016.41 2,782.36 126.31 5,983,618.532 619,011.925 0.65 2,056.74 4222019 10..12:20AM Page 5 COMPASS 5000.1 Build 810 •e Company: North Amenca- ALASKA - BP Project: PBU Site: S Well: S-105 Wellbore. S -105A Design: S-1 05A Survey MO Inc 6,872.63 (usft) 1°) 3,237.71 6,957.09 27.56 7,050.36 28.79 7,144.00 29.68 7,236.21 29.13 7,329.59 27.85 7,423.87 27.22 7,517.03 26.43 7,610.76 25.44 Tie-in to Parent Well S-105 2,421.59 7,648.00 25.42 Top of Whipstock . KOP 3,292.72 7,664.88 30.31 Interpolated Azimuth 619,041.999 7,694.86 37.62 Interpolated Azimuth 16.57 7,724.60 45.46 Interpolated Azimuth Survey Calculation Method: 7,754.84 53.23 1st clean survey 7,783.45 60.19 7,815.12 67.60 7,844.24 74.39 7,875.13 82.52 7,905.21 90.09 7,935.05 96.00 7,965.39 100.59 7,996.02 99.97 8,026.01 100.18 Azi V) BP Final Survey Report 7.21 6,872.63 6,807.55 3,237.71 Local Coordinate Reference: Well S-105 619,032.861 26.12 2,398.64 10.41 TVD Reference: 6,821.48 KB Q 65.08usft (NABORS CDR2) 158.86 5,984,102.372 619,036.791 MD Reference: 2,421.59 KB @? 65.08usft (NABORS CDR2) 6,896.04 6,830.96 3,292.72 184.50 5,984,129.385 North Reference: 619,041.999 True 24.99 2,444.62 16.57 6,902.22 6,837.14 3,321.93 Survey Calculation Method: Minimum Curvature 619,049.308 28.43 2,470.78 20.04 Database: 6,839.08 EDM R5K - Alaska PROD - ANCP1 181.69 5,984,187.337 TVD TVDSS N/S EM Northing Easting DLeg V. See 3,377.87 (usft) (usft) (usft) (usft) (waft) (usft) (°/100usft) (usft) 0.55 6,164.10 6,099.02 2,825.75 127.03 5,983,661.928 619,011.953 0.52 2,087.93 1.63 6,246.32 6,181.24 2,869.78 127.87 5,983,705.960 619,012.100 1.43 2,119.66 2.70 6,328.03 6,262.95 2,915.48 129.61 5,983,751.676 619,013.108 1.10 2,153.20 2.21 6,408.36 6,343.28 2,960.71 131.55 5,983,796.929 619,014.330 0.65 2,186.56 3.34 6,490.51 6,425.43 3,005.06 133.69 5,983,841.298 619,015.765 1.69 2,219.43 4.37 6,574.19 6,509.11 3,048.40 136.61 5,983,884.674 619,017.994 0.68 2,252.14 5.87 6,657.32 6,592.24 3,090.27 140.35 5,983,926.595 619,021.072 1.12 2,284.39 6.29 6,741.61 6,676.53 3,131.03 144.89 5,983,967.417 619,024.763 1.07 2,316.28 6.43 6,775.24 6,710.16 3,146.92 146.46 5,983,983.334 619,026.282 0.17 2,328.77 5.80 6,790.16 6,725.08 3,154.76 147.30 5,983,991.188 619,026.994 29.02 2,334.91 5.00 6,815.01 6,749.83 3,171.43 148.86 5,984,007.874 619,028.293 24.43 2,347.80 4.40 6,837.25 6,772.17 3,191.07 150.47 5,984,027.536 619,029.588 26.40 2,362.82 3.95 6,856.94 6,791.86 3,213.93 152.13 5,984,050.421 819,030.888 25.72 2,380.17 7.21 6,872.63 6,807.55 3,237.71 154.48 5,984,074.233 619,032.861 26.12 2,398.64 10.41 6,886.56 6,821.48 3,265.79 158.86 5,984,102.372 619,036.791 25.09 2,421.59 13.18 6,896.04 6,830.96 3,292.72 184.50 5,984,129.385 619,041.999 24.99 2,444.62 16.57 6,902.22 6,837.14 3,321.93 172.27 5,984,158.721 619,049.308 28.43 2,470.78 20.04 6,904.16 6,839.08 3,350.41 181.69 5,984,187.337 619,058.277 27.67 2,497.57 25.38 6,902.57 6,837.49 3,377.87 193.18 5,984,214.980 619,069.330 26.67 2,525.12 32.01 6,898.19 6,833.11 3,404.19 207.58 5,984,241.521 619,083.303 26.39 2,553.91 38.86 6,892.72 6,827.64 3,428.76 225.00 5,964,266.363 619,100.331 21.46 2,583.60 45.27 6,887.47 6,822.39 3,450.70 244.73 5,984,288.615 619,119.711 21.71 2,613.07 412212019 10 12:20AM Page 6 COMPASS 5000.1 Build 81D am BP Final Survey Report Company: North America -ALASKA - BP Local Coordinate Reference: Well 5-105 Project: PBU TVD Reference: KB @ 65.08usft (NABORS CDR2) Site: S MD Reference: KB @ 65.08usft (NABORS CDR2) Well: 5-105 North Reference: True Wellbore: S -105A Survey Calculation Method: Minimum Curvature Design: 5-105A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi TVD TVDSS NIS EIW Northing Elating DLeg V. Sec (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) (°AOOusft) (usft) 8,056.13 100.47 52.79 6,882.06 6,816.98 3470.12 267.09 5,984,308.380 619,141754 24.58 2,642.61 8,08045 99.91 58.97 6,877.76 6,812.68 3,463.54 286.90 5,984,322.110 619,161.344 25.12 2,666.10 8,110.52 98.57 65.00 6,872.92 6,807.84 3,497.47 313.09 5,984,336.454 619,187.307 20.29 2,694.47 8,140.50 100.22 69.60 6,868.03 6,802.95 3,508.88 340.36 5,984,348.298 619,214.397 16.11 2,721.83 8,170.67 100.72 74.10 6,862.54 6,797.46 3,518.12 368.55 5,984,357.984 619,242.428 14.76 2,748.29 8,200.96 100.97 79.11 6,856.84 6,791.76 3,525.01 397.48 5,984,365.331 619,271.242 16.27 2,773.62 8,227.85 101.12 83.11 6,851.68 6,786.60 3,529.09 423.54 5,984,369.822 619,297.241 14.61 2,794.93 8,257.74 101.44 89.02 6,845.83 6,780.75 3,531.10 452.77 5,984,372.297 619,326.432 19.42 2,817.03 8,287.43 100.84 93.74 6,840.09 6,775.01 3,530.40 481.89 5,984,372.057 619,355.551 15.73 2,837.11 8,320.77 100.90 99.36 6,833.80 6,768.72 3,526.67 514.40 5,984,368.841 619,388.117 16.55 2,85747 8,350.83 101.12 103.82 6,82806 6,762.98 3,520.74 543.30 5,984,363.375 619,417.103 14.58 2,873.71 8,380.99 98.05 104.89 6,823.04 6,757.96 3,513.37 572.11 5,984,356.460 619,446.020 10.76 2,888.06 8,410.50 94.77 104.34 6,819.74 6,754.66 3,505.97 600.48 5,984,349.514 619,474.504 11.27 2,903.70 8,440.42 91.32 103.71 6,818.15 6,753.07 3,498.73 629.46 5,984,342.737 619,503.596 11.72 2,919.07 8,470.86 87.17 101.49 6,818.55 6,753.47 3,492.09 659.16 5,984,336.571 619,533.391 15.46 2,935.37 8,502.96 84.99 97.62 6,820.75 6,755.67 3,486.77 690.73 5,984,331.758 619,565.041 13.81 2,953.94 8,530.64 85.91 94.96 6,822.95 6,757.87 3,483.75 718.15 5,984,329.171 619,592.507 10.14 2,971.20 8,562.21 87.11 91.27 6,824.87 6,759.79 3,482.04 749.61 5,984,327.960 619,623.986 12.27 2,992.23 8,590.77 86.78 88.57 6,826.39 6,761.31 3,482.08 778.13 5,984,328.452 619,652.496 9.51 3,012.42 8,621.07 86.93 84.51 6,828.05 6,762.97 3,483.91 808.32 5,984,330.757 619,682-654 13.39 3,035.06 8,650.99 87.48 81.27 6,829.51 6,764.43 3,487.60 837.97 5,984,334.925 619,712.239 10.97 3,058.64 8,681.19 87.76 77.27 6,830.77 6,765.69 3,493.22 867.61 5,984,341.011 619,741.784 13.27 3,083.57 8,711.17 88.22 76.95 6,831.82 6,766.74 3,499.91 896.82 5,984,348.157 619,770.879 1.87 3,108.95 8,741.11 87.17 81.55 6,833.02 6,767.94 3,505,48 926.20 5,984,354.201 619,800.166 15.75 3,133.67 8,770.75 86.93 86.92 6,834.55 6,769.47 3,508.46 955.64 5,984,357.641 619,829.553 18.11 3,156.59 8,801.09 86.16 91.16 6,836.38 6,771.30 3,508.96 985.91 5,984,358.629 619,859.812 14.18 3,178.36 8,831.33 87.91 96.67 6,837.95 6,772.87 3,506.90 1,016.03 5,984,357.045 619,889.954 19.09 3,198.20 4/222019 10: 12:20AM Page 7 COMPASS 5000.1 Build BID In BP Final Survey Report Company: North America - ALASKA - BP Local Co-ordinate Reference'. Well S-105 Project: PBU TVD Reference: KB @j 65.08usft (NABORS CDR2) Site: S MD Reference: KB Q 65.08usft (NABORS CDR2) Well: 5-105 North Reference: True Wellborn: 5-105A Survey Calculation Method: Minimum Curvature Design: 5-105A Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi ND NDSS NIS E1VI Northing Basting DLsg V. Sec (usft) (°( (°) (usft) (usft) (usft) (usft) (usft) (usft) (°HOOusft) (usft) 8,861.00 88.31 101.78 6,838.92 6,773.84 3,502.15 1,045.29 5,984,352.758 619,919.284 1727 3,215.53 - 8,890.97 87.39 102.29 6,840.05 6,774.97 3,495.91 1,074.58 5,984,346.980 619,948.668 3.51 3,231.82 8,925.97 68.31 99.68 6,841.36 6,776.28 3,489.24 1,108.91 5,984,340.863 619,983.097 7.90 3,251.39 8,951.11 87.63 98.50 6,842.25 6,777.17 3,485.27 1,133.72 5,984,337.288 820,007.963 5.41 3,266.12 8,981.05 87.11 95.15 6,843.63 6,778.55 3,481.72 1,163.41 5,984,334.206 620,037.706 11.31 3,284.60 9,010.91 89.06 92.93 6,844.62 6,779.54 3,479.62 1,193.18 5,964,332.577 620,067.499 9.94 3,304.17 9,041.27 88.28 88.76 6,845.32 6,780.24 3,479.17 1,223.52 5,984,332.611 620,097.841 13.98 3,325.30 9,070.97 87.11 84.97 6,846.51 6,781.43 3,480.79 1,253.15 5,984,334.704 620,127.435 13.35 3,347.40 9,100.72 87.24 80.44 6,847.98 6,782.90 3,484.55 1,282.61 5,984,338.943 620,156.834 15.21 3,370.90 9,130.77 84.99 76.49 6,850.02 6,784.94 3,490.56 1,311.98 5,984,345.400 620,186.101 15.10 3,395.90 9,160.85 86.78 73.38 6,852.18 6,787.10 3,498.35 1,340.95 5,984,353.856 620,214.937 11.91 3,421.90 9,191.00 86.90 89.98 6,853.84 6,788.76 3,507.81 1,369.52 5,984,363.569 620,243.355 11.27 3,448.80 9,220.83 86.90 66.40 6,855.45 6,790.37 3,518.88 1,397.17 5,984,375.070 620,270.824 11.98 3,476.17 9,250.68 86.65 63.06 6,857.13 6,792.05 3,531.60 1,424.12 5,984;388.215 620,297.563 11.20 3,504.22 9,281.08 87.27 59.80 6,858.75 6,793.67 3,546.12 1,450.77 5,984,403.151 620,323.984 10.90 3,533.33 9,310.74 88.16 56.87 6,859.93 6,794.85 3,561.71 1,475.97 5,984,419.148 620,348.925 10.96 3,562.18 9,341.02 88.19 52.84 6,860.89 6,795.81 3,579.18 1,500.68 5,984,436.998 620,373.355 12.64 3,592.00 9,370.85 87.73 48.27 6,861.96 6,796.88 3,598.11 1,523.69 5,984,456.295 820,396.064 15.39 3,621.66 9,401.01 89.29 44.13 6,862.74 6,797.66 3,618.97 1,545.45 5,984,477.499 620,417.484 14.66 3,651.80 9,433.38 89.02 40.38 6,863.22 6,798.14 3,642.93 1,567.21 5,984,501.791 620,438.859 11.61 3,684.12 9,460.92 90.12 38.59 6,863.42 6,798.34 3,664.18 1,584.72 5,984,523.318 620,456.029 7.63 3,711.53 9,491.09 87.85 35.81 6,863.96 6,798.88 3,688.20 1,602.96 5,984,547.626 620,473.879 11.89 3,74141 9,520.70 91.07 34.54 6,864.24 6,799.16 3,712.40 1,620.01 5,984,572.090 620,490.545 11.69 3,770.58 9,551.81 90.71 30.71 6,863.75 6,798.67 3,738.60 1,636.78 5,984,598.544 620,506.893 12.36 3,800.96 9,581.00 89.39 25.25 6,863.73 6,798.65 3,764.36 1,650.47 5,984,624.524 620,520.171 19.24 3,828.86 9,610.52 90.34 21.33 6,863.80 6,798.72 3,791.47 1,662.14 5,984,651.812 620,531.407 13.66 3,856.28 9,640.30 91.04 17.49 6,863.44 6,798.36 3,819.55 1,672.03 5,984,680.043 620,540.853 13.11 3,883.13 4/22/2019 10,12:20AM Page 8 COMPASS 5000.1 Build BID p BP Final Survey Report Qibb� Company: North America - ALASKA- BP Local Coordmate Reference: Well S-105 Project: PBU TVD Reference: KB Q 65.08usft (NABORS CDR2) Site: S MD Reference: KB @ 65.08u dt (NABORS CDR2) Well: S-105 North Reference: True Wellbore: S -105A Survey Calculation Method: Minimum Curvature Design: S -105A Database: EDM R5K-Alaska PROD -ANCP1 Survey MD Inc An TVD TVDSS NIS E/W Northing Easting DLeg V. Sec (usft) C) (1) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 9,670.44 94.21 15.74 6,86206 6,796.98 3,84840 1,68064 5,984,709.020 620,549.002 1201. 3,909.62 9,701.00 94.56 11.23 6,859.72 6,794.64 3,878.02 1,687.74 5,984,738.749 620,555.634 14.76 3,935.59 9,730.39 94.97 8.32 6,857.28 6,792.20 3,906.88 1,692.71 5,984,767.682 620,560.147 9.97 3,959.51 9,760.91 91.41 8.10 6,855.58 6,790.50 3,937.04 1,697.07 5,984,797.900 620,564.018 11.69 3,983.91 9,790.30 89.97 4.54 6,855.23 6,790.15 3,966.24 1,700.30 5,984,827.149 620,566.788 13.07 4,006.85 9,822.36 87.48 0.28 6,855.94 6,790.86 3,998.25 1,701.65 5,984,859.178 620,567.628 15.39 4,03044 9,880.91 90.86 354.91 6,856.79 6,791.71 4,056.72 1,699.19 5,984,917.589 620,564.243 10.84 4,07004 9,912.11 92.24 352.47 6,855.95 6,790.67 4,087.71 1,695.76 5,984,948.525 620,560.325 8.98 4,089.54 9,940.80 91.66 351.00 6,854.97 6,789.89 4,116.09 1,691.64 5,984,976.828 620,555.753 5.51 4,106.68 9,970.92 92.39 351.85 6,853.90 6,788.82 4,145.85 1,687.15 5,985,006.515 620,550.794 3.72 4,124.56 10,000.67 91.54 353.49 6,852.88 6,787.80 4,175.34 1,683.36 5,985,035.936 620,546.533 6.21 4,142.73 10,030.80 90.09 358.60 6,852.46 6,787.38 4,205.38 1,681.28 5,985,065.942 620,543.980 17.63 4,162.50 10,060.87 90.98 3.31 6,852.17 8,787.09 4,235.44 1,681.78 5,985,095.999 620,544.003 15.94 4,184.11 10,091.09 90.71 8.40 8,851.73 6,786.85 4,265.49 1,684.87 5,985,128.091 620,546.607 16.86 4,207.54 10,122.78 90.77 13.87 6,851.32 6,786.24 4,296.57 1,690.98 5,985,157.260 620,552.230 17.26 4,233.84 10,151.01 89.48 16.53 6,851.26 6,786.18 4,323.81 1,698.38 5,985,184.611 620,559.196 10.47 4,258.33 10,180.99 86.99 15.66 6,852.18 6,787.10 4,352.60 1,706.69 5,985,213.526 620,567.044 8.80 4,284.56 10,210.88 85.20 13.48 6,854.22 6,789.14 4,381.45 1,714.19 5,985,242.497 620,574.086 9.42 4,310.27 10,240.95 86.06 11.00 6,856.51 6,791.43 4,410.75 1,720.55 5,985,271.691 620,579.975 8.71 4,335.48 10,271.07 86.13 8.21 6,858.56 6,793.48 4,440.38 1,725.56 5,985,301.590 620,584.518 9.24 4,359.98 10,295.47 88.74 5.94 6,859.65 6,794.57 4,464.57 1,728.56 5,985,325.819 620,587.134 14.17 4,379.20 10,330.84 89.26 1.37 6,860.27 6,795.19 4,499.85 1,730.82 5,985,361.130 620,588.827 13.00 4,405.75 10,361.84 89.36 357.51 6,860.64 6,795.56 4,530.84 1,730.51 5,985,392.110 620,588.033 12.45 4,427.44 10,390.74 86.96 356.32 6,861.57 6,796.49 4,559.68 1,728.96 5,985,420.919 620,586.021 9.27 4,446.74 10,420.36 86.35 352.17 6,863.30 6,798.22 4,589.09 1,726.00 5,985,450.280 620,582.591 14.14 4,465.44 10,450.06 85.82 348.41 6,865.33 6,800.25 4,618.31 1,721.00 5,985,479.415 620,577.128 12.75 4,482.57 10,480.94 84.22 345.63 6,868.01 6,802.93 4,648.27 1,714.09 5,985,509.253 620,569.750 10.36 4,498.87 4222019 10:12:20AM Page 9 COMPASS 5000.1 Build 81D by Company: North America-ALASKA -BP Project: PBU Site: S Well: S-105 Wellbore: SA05A Design: 5-105A Survey MD Inc Azi (usft) V) (') 10,51075 84.47 342.40 10,559.00 84.47 342.40 Projection to TD BP Final Survey Report 4222019 10, 1220AM Page 10 COMPASS 5000.1 Build 81D Local Co-ordinate Reference: Well 5-105 TVD Reference: KB @ 65.08usft (NABORS CDR2) MD Reference: KB @ 65.08usft (NABORS CDR2) North Reference: True Survey Calculation Method Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 TVD TVDSS NIS Erw Northing Easting DLeg V. Sec (usft) (usft) (usft) (usft) (usft) (usft) ('1100usft) (usft) 6,870.95 6,805.87 4,676.78 1705.92 5,985,537.632 620,561.131 10.82 4,513.25 6,875.60 6,810.52 4,722.56 1,691.40 5,965,583.169 620,545.886 0.00 4,535.36 4222019 10, 1220AM Page 10 COMPASS 5000.1 Build 81D WELLHEAD= 11" - 5m fmo Lara SH Gen 5 SPF I ACRYITOR= QW NE -60 I Opn/Sgz I KB. ELB7 = 66 2-12" BF. E.EV = 7650-7670 KOP = 1500' 03/09/01 Max Angle = 37° @ 4439 6 Datum NO = 763T O Datum TVD= 67W'SS 2-12" 6 7682-7702 14-12 i S-105 "TBG, 12.88. L-80, .01522 bpi, D = 3.958' - 69' 1TOP OF3-12"TBG, D=2.992.1 71' 9-5/8" CSG, 40p, L -80 -M -BTC, D = 8.835' 2996' Minimum ID = 2.75" @ 2106.1 HES X NIPPLE TBG, 9.2#, L -80 -EVE, 8RD• w.r n=1aa1- I r PEZFORATDN SUMMARY REF LOGSPERRY DGR MWD ON 10/25/00 ANGLE AT TOP PERF. 25` Q 7650' Note: Rider to Production DB for historical perf data SIZE SPF I NTERVAL I Opn/Sgz I DATE 2-12" 6 7650-7670 O 03/09/01 2-12" 6 7665-7685 O 08/07/06 2-12" 6 7682-7702 C 05/12/02 2-12" 6 7712-7722 C 05/12/02 7" FLOAT COLLAR- PBTD 1--i 801T 7" CSG, 26N, L$0 -BTC, MOD, .0383 bbK ID = 6.276" 8103' 7" FLOAT SHOE 8103' SAFETY NOTES: 4-12"X3-12"XO, D=2.992" 894' �7AM PORI COLLAR 2106' :�]-� 3-12- HES X NP, D = 2.750" GAS LFT MANDRELS STI MD ITVDIDEVI GJBIJMD JMG/JMD r0:328/19 TYPE VLV LATCH PORT DATE 3 4129 3775 32 CAM -MMM DMY RK 0 03/13/19 2 6631 5877 29 CAM -MMM DMY RK 0 03/13/19 1 7475 6620 27 CAM -MMM DMY RK 0 03/13/19 3-12" HES X NP, D= 7592 1 3-12• X 4-12" XO, D= 2.992" I 7593 17"X 4-12" BAKER S-3 PKR w 1XO RJPS to 3-12", 0= 3.875" —A-97-14-1/2- X 3-12" XO, D = 2.992- Y619' —13-12"FESXNP,D=2.750"_ 7631' —j3-12" WLEG, D=i 7620'—CTMDTT04/04/19 DATE I REV BY COMMENTS 11N0/00 ORIGINAL COMPLETION 12/17/06 JCMPJC GLV CAO 12M2AD� I REV BY GWJMD COMMENTS SETX-LOCK MUFLOWB-RU SUB B GAUGE GJBIJMD JMG/JMD r0:328/19 ADDED Xds ABO✓E & BELOW PKR 05(37/09 PJCfrLH ONE FISH REMOVED 1127 PLA-LEDFLOWTHRUSUB81125115 RCTIJMD SET PX PLUG 11/19/15 GJB/JMD GLVCAD 0317411912/10115 DIYJMD TREECAO 12103/15 TFAIJMD+l ELMD LCQFISH DEPTH-CSGBBLS 04104 0127116 GTWJMD PULLED PX PLUG(01/10/16 ALIRORA UT•1T S WELL S-105 PERMRNo: 2001520 APINo: 50-029-22977-00 SEC 35, T12N, R12, '19) BP Expimbon (Alaska) From: Ciolkosz Ryan R To: Lastufka.]oseph N Subject: FW: PTD# 219-032 S -105A TD extension Date: Monday, April 22, 2019 6:47:40 AM Ryan Ciolkosz Drilling Engineer BP Exploration Alaska Office: (907)564-5977 Cell: (907)2 W-3357 From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Saturday, April 20, 2019 11:50 PM To: Ciolkosz, Ryan R <Ryan.Ciolkosz@bp.com> Cc: Mclaughlin, Sean M <Sean.McLaughlin@bp.com>; Warren, Abigail M <Abigail.Warren@bp.com>; Egbejimba, John <John.Egbejimba@u k.bp.com>; AK, GWO Rig Nabors CDR2 Well Site Leader <AKGWORIGNABORSCDR2WSL@bp.com>; Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: Re: PTD# 219-032 S -105A TD extension Ryan BPXA has AOGCC approval to drill to the adjusted proposed TD as described below. Please send a revised PTD on Monday morning if your bottom hole location is greater that 500' from the original PTD bottom hole location. Mel Rixse On Apr 20, 2019, at 9:27 PM, Ciolkosz, Ryan R <Rvan CioIkoszPbp com> wrote: Mel, as discussed on the phone we are requesting the AOGCC's approval to drill beyond 500' from the original plan submitted in the PTD for 5-105A. The new TD may be as much as 725 ft from the original permitted TD depending on the amount of oil column drilled up to that point. The well may be cut short if the required amount a pay is drilled before that point. An anti -collision scan was performed against the new plan and there are no additional collision risks. Distance to the nearest property line for the original plan was 6,820', therefore, the new plan should not encroach on any lease lines. If the plan is extended 500' beyond the original TD as stated in the PTD, a revised PTD will be submitted on Monday to the AOGCC. See the attached updated traveling cylinder plot and plan view. Thank you, Ryan Ciolkosz Drilling Engineer BP Explonafion Alaska Office: (907)564-5977 Cell: (907)244-1357 <S -105A WP13 Plus 500ft MD - 750ft Range.pdf> <S -105A Plan for NW Corner of Polygon View.docx> WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, AURORA OIL- 640120 Well Name: PRUDHOE BAY�IN AURO 5-105A Program DEV _ Well bore seg ❑ PTD#:2190320 Company BP EXPLORATION (ALASKA) INC. Initial Class/Type DEV / PEND GeoArea 890 Unit -tlaQ On/Off Shore On___ Annular Disposal ❑ Administration 17 Nonconven, gas conforms to A$31,05,0304. 1.A),Q.2.A-D) .... _ _ _ _ _ NA ..... _ 1 Permit fee attached - -NA 2 Lease number appropriate- - - - - - - _ _ - - - - - - _ _ _ _ _ -Yes - - - . Entire well in ADL0028257 3 Unique well. name and number - - - - - - _ _ _ _ _ Yes 4 Well located in.a defined pool _ _ _ _ _ _ _ _ _ _ _ _ _ Yes .. _ PRUDHOE BAY, AURORA OIL - 64.0120, governed by CO 4578.- Corrected 5 Well located proper distance from drilling unit boundary_ _ ....... Yes ... _ . Rule 1: "Spacing units within the pool shall be a minimum of 40 acres.. 20-AAC 25.055(a)(1) 6 Well located proper distance. from. other Wells...Yes Yes _ _ _ _ _ and -(2) shall -not apply to property lines within the a#ernal boundaries of the Aurora. 7 Sufficient acreage available in, drilling unit_ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ Participating Area." -As -planned, this well will conform to spacing requirements 8 If. deviated, is. wellbore platincluded- - _ _ _ _ _ _ _ _ . Yes 9 Operator only affected party.... _ _ ... _ _ _ Yes 10 Operator has appropriate bond in force _ ..... _ _ _ _ _ _ _ Yes Appr Date 11 Permit can be issued without conservation order _ _ _ ... _ Yes DLB 4/25/2019 12 Permit can be issued without administrative approval _ - - _ - _ - _ _ - _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ 13 Can permit be approved before 15 -day wait_ _ _ _ _ _ _ Yes 14 Well located within area and.strata authorized by Injection Order # (put. 10# incomments)(For- NA...... 15 All wells. within 1/4. mile area of review identified (For service well only) ..... _ _ . _ .. NA- - - - - -- - - - - - - - - - - - 16 Pre -produced injector, duration of pre -production less than 3 months. (For service well only) - - NA - .... 18 Conductor string - - - - . - _ .. _ _ _ .. NA .. _ _ _Slim CTD sidetrack, all drilling within the reservoir Engineering 19 Surface casingprotectsall-known USDWs _ _ .. NA- - - - - - _ Slim CTD sidetrack, all drilling .and completion within the reservoir... 20 CMT vol adequate to circutate.on conductor & sud_csg _ _ .... _ _ _ NA. .... _ - - Slim CTD sidetrack, all drilling within the reservoir 21 CMT. vol adequate to tie-in long string to surf csg.. .. NA.. _ _ _ . _ Slim CTD sidetrack, all drilling within the reservoir 22 CMT will cover. all known productive horizons- - - - Yes - . .... _ . 23 Casing designs adequate for C, T, B &-permafrost _ _ Yes . 24 Adequate tankage -or reserve pit _ .. _ _ _ _ _ .... _ _ _ Yes .. _ _ _ _ _ Continuing operations on Rig CDR2. _ 25 If a -re -drill, has. a 10-403 for abandonment been approved _ _ .. _ _ NA- - - ... _ - Variance. approved to 20AAC 25,112(1) 26 Adequate wellbore separation proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ WelJpath.passes all BP separation. risk criteria. 27 If diverter required, does it meet regulations _ _ _ _ _ _ _ _ _ _ _ _ NA.. _ _ .... Slim CTD sidetrack, all drilling within the reservoir Appr Date 28 Drilling fluid program schematic & equip list adequate... _ _ _ Yes MGR 4/26/2019 29 BOPEs,.do they meet regulation . . . . . ........ . . . . . . . .. Yes .. _ 5M 7-1/16.4 ram stack .... 30 BOPS -press rating appropriate; test to -(put psig in comments).. _ Yes ..... 5000 psi equipment, tested to 3500 psi - 31 Choke, manifold complies w/API-RP-53 (May 84)... _ _ _ _ _ Yes - - - - - - - - - - - - -- - - - - - - - --- - - - - - - - - - - 32 Work will occur without operation shutdown _ _ _ _ _ _ _ _ _ _ _ ... Yes - _ _ _ . CDR2 Ongoing Operations 33 Is presence of H2S gas. probable- - - - - - - ---- - --- - - - - - - - _ - - - _ _ Yes .... _ Standard BP monitoring, in place_ ...... 34 Mechanical condition of wells within ADR ve(died (For service well only) ..... _ _ _ NA.. _ _ _ _ _ This well will/ -be fractured on 10-40$ - - 35 Permit can be issued drogen. sulfide measures - ued w/o h - Y - - . - ...... _ _ .. ....No _ _ . No, S -Pad is H2S bearing, Measures required. ..... . . . . . . . . . . . . . . ........... . . . Geology 36 Datapresentedon potential overpressure zones - - - - - - - - - - - - - - - - - - - - - - - - - - Yes . _ .. _ - Planned mud weights appear adequote.t0 control Operator's fore -case downhole.pressures. Managed Pressure - - Appr Data 37 Seismic anabsis. of shallow gas -zones _ _ _ ... _ _ ____ _ _ _ _ _ _ _ NA - _ _ _ Drilling technique -may be used to control -hole stability.. _ _ _ _ ......... DLB 4/25/2019 38 Seabed condition survey -(if off -shore)- - -- -------- - - - - -- -- _ _ _ _ _ _ ... NA, _ . _ .. _ .. _ ... -. _ _ _ _ _ , ....... . - --- - -. 39 Contact name/phone for weekly progress reports [exploratory only] ..... . . . . . . . ... NA_ _ ...... _ ... _ _ _ _ _ _ _ _ _ _ ............. Geologic Engineering Public Commissioner: Date: Commissioner: (/D(/atte Commissioner Date Y4/25,2019 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean McLaughlin CTD & RWO SDE BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 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 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S -105A BP Exploration (Alaska), Inc. Permit to Drill Number: 219-032 Surface Location: 4631' FSL, 4496' FEL, SEC. 35, T12N, R12E, UM Bottomhole Location: 3695' FSL, 2352' FEL, SEC. 26, T12N, R12E, UM Dear Mr. McLaughlin: 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, 191-1 Daniel T. Seamount, Jr. Commissioner 7.1 DATED this sday of February, 2019. STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMMIS; PERMIT TO DRILL 20 AAC 25.005 la. Type of Work: ib. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - DISP❑ 1c. Specify if well is proposed for Drill 11Lateral ❑ Stretigrephic Test 13Development-Oil 0 ' Service-Winj E)Single Zone ® Coalbed Gas ,❑ Gas Hydrates 11 Redrill 0 Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service -Supply ❑ Multiple Zone Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond Blanket 51 'Single Well ❑ 11. Well Name and Number: BP Exploration (Alaska), Inc Bond No 295105380 • PBU S -105A ' 3 Address: 8, Proposed Depth: 12. Field/Pool(sy P.O. Box 196612 Anchorage, AK 99519-6612 NO 10341' ' TVD: 6802'ss - PRUDHOE BAY, AURORA OIL 4a. Location of Well Governmental Section). ( ) 7. Property Designation (Lease Number): ADL 028257 - 8. DNR Approval Number: 13. Approximate spud date: Surface: 4631' FSL, 4496' FEL, Sec.35, T12N, R12E, UM Top of Productive Honzon: 2491' FSL, 4344 FEL, Sec. 26, T1 2N, R1 2E, UM 83-47 May 1, 2019 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 3696 FSL, 2352' FEL, Sec. 26, T1 2N, R1 2E, UM 6820 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KS Elevation above MSL: 65.08 -feet 15. Distance to Nearest Well Open Same Pool: Surface. x- 618930 y- 5980835 Zone - ASP 4 GL Elevation above MSL: 36 • feet 4 16. Deviated wells: Kickoff Depth: 7650 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 102 degrees Downhole: 3066 Surface: 2382 18, Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, of or sacks Hole Casino Weiqht Grade Couolina Len th MD TVD MD TVD (including stage data 3-1/4" 2-3/8" 4.4# L-80 HYD511 2733' 7608' 6674'ss 10341' 6802'ss 97 sx Class'G' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (8): Total Depth TVD (1i Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (R): Junk (measured)* 8120 7203 7693 7693 6816 7631 Casing Length Size Cement Volume MD TVD Conductor/Structural 78 20" 260 su Arctic Set (Aoorox.l 28-107 28-107 Surface 2969 9-58" 405 sx AS Lite 111. 240 sx Class'G' 28-2996 28-2833 Intermediate Production 8077 7" 497 sx Class'G' 26-8103 26-7188 Liner Perforation Depth MD (f): 7650-7722 Perforation Depth TVD (ft): 6777 - 6842 Hydraulic Fracture planned? Yes RI No ❑ 20. Attachments Property Plat ❑ BOP Sketch 0 Drilling Program IZ Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program R1 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Name Ciolkosz. Rvan R from without prior written approval. Authorized Name Mclaughlin, Sean M Contact Email Ryan.Ciolkosz@bp.com Authorized Title CTD 8 RWO SDE Contact Phone +1 907 564 5977 Authorized Signature Date 2 Z1g I cl Commission Use Only Pennit to Drill pPermit Approval See cover letter for other Number: /. L�� API: 50- 029-22977-01-00 pate: requirements' Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrat s, or gas contained in shales: / Other: Samples ni Yes ❑ No 2 Mud log req'd: Yes 11No C3" h '3 -mo o 1's H2S measures Yes �/ No ❑ Directional svy req'd: Yes 12' No ❑ S�Ps1 iZ T C d n9Q R, i Y F- — Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No 10 4<_ -mi, RU VUPost initial injection MIT req'd: Yes 11No ❑ 7�pn /V\�IVtt I+�I�1rC�''AFr Fch1 F'l) F�i +>�'✓"�•-� /PROVED BY Approved by: �C. COMMISSIONER THE COMMISSION Dal 25711 QRIGINAL Form 10-007 Revised 5/2017 This permit is valid for 2 months from the date of approval (20 AAC 25.005(8))ie Su -hint Foon and -21 � tachments in Duplicate �� 2.2i4 To: Alaska Oil & Gas Conservation Commission x,440% r-1 From: Ryan Ciolkosz b CTD Engineer ZN�S �" Date: February 18, 2019 Re: S-1 05A Permit to Drill Approval Approval is requested for a permit to drill a CTD sidetrack from well S-105. Parent well, S-105, is a Ku aruk Zone C producer completed in 2000. It currently has 40' of open perfs in the Kuparuk Zone C. The intent of the S -105A wellbore is to access reserves outside the parent wellbore's 500' drainage radius. The parent reserves will be accessed via frac job near parent in the S-1 05A wellbore. Proposed plan: Drill a through tubing sidetrack with the CDR 2 Coiled Tubing Drilling rig on or around May 6th. 2019. E -line unit will set a CTD whipstock. CDR 2 will mill a 2.74" window in the 7" liner and drill a Kuparuk well to —10,341 ' MD. The lateral will be completed with a 2-3/8" 4.7# L-80 liner which will be cemented and perforated. This Sundry covers plugging the existing S-105 perforations via the S -105A liner cement 6ob or liner top packer set post -rig (alternate plug placement per 20 AAC 25.112(i)) and via cosi-set plug. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Start Date: February 20th, 2019 Pre ig Work 1 F MIT -IA 2 S Drift for whipstock & caliper to whipstock setting depth 3 ESet NS whipstock Wedge ✓ 4 V Pre CTD Tree Work/set TWC Rig Work: Z 9 L Ir 1ti6 . C '�_ 40 G- U- 1. MIRU and test BOPE. Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,382 psi. 2. Mill 2.74" window plus 10' of rathole. Swap the well to 8.7-9.5 ppg drilling fluid. 3. PU drilling BHA with GR/Resistivity - 4. Drill 3.25" hole to TD at -10,341 MD 5. Run 2-3/8" L-80 liner. 6. Pump primary cement bringing TOC to TOL, 20 bbls of 15.3 ppg liner cmt planned* 7. Test liner lap to 2,400 psi. 8. Perforate liner per asset instructions 9. Freeze protect well, RDMO Post Rig: 1. V: Tree work, pull TWC/BPV as necessary 2. SL: Set LGLVs, set LTP (if fail lap); 3.5" WFD widepak LTP with PTSA stinger. Regulatory compliance SBHPS (review state requirements, as there is an effort to drop this requirement in the CO) 3. F: assist SL: PT LTP 4. T: Portable is flowback (plan to perf 1300 ft) 5. F: SIT 6. C: Set CBP/CIBP such that heel perfs are the only thing flowing. 7. C: mill plug to bottom (so we can produce well until frac is ready to execute) 8. S: Dummy GLVs �,�•,� 1 �� 9. C: set CBP. Perf if necessary HYiL�c -;'AA .^nolle! 10-5peceTjecfs Frac sage p ))/� // - / 11. C: Clean out, mill CBP to bottom �' ISG �je?46 wr• G/S•e � 12. S: Set LGLVs, regulatory compliance SBHPS. ATOS -C4 r, x! 13. T: Post frac flowback / 14. F: SIT post frac * Approved alternate plug placement per 20 AAC 25.112(i) Mud Program: • Well kill: 8.9 ppg brine. • Milling/drilling: 8.9 ppg drilling fluid for milling window and drilling (103 psi over -balance ). Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3.25" Liner Program: • 2-3/8", 4.4#, L-80, HYD511 Solid Liner 7608' MD - 10341' MD ' • A minimum of 20 bbis of 15.3 ppg cement will be used for liner cementing. (TOC =TOL) V�_ • The primary barrier for this operation: a minimum EMW of 8.9 ppg. • A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 1020 . • Magnetic and inclination surveys will be taken every 30 ft. • Distance to nearest property — 6820' • Distance to nearest well within pool — 450' NKUPST Logging • MWD directional, Gamma Ray and Resistivity will be run over the entire open hole section. Perforating: • 1.56" Perfecta, 1" CSH work string • The primary barrier for this operation: a minimum EMW of 8.9 ppg. A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti -Collision Failures • All wells pass BP Anti -Collison Risk Requirements. The planned L2 -07B Trajectory is within 415ft of the NKUPST wellbore. The NKUPST has been permanently abandoned to surface. Hazards ,i • S pad is an 1-12S pad. Reservoir Pressure • The reservoir pressure is expected to be 3,066 psi at 6849' TVDSS. (8.61 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,382 psi. • An EMW of 8.9 ppg for this well will provide 103 psi over -balance to the reservoir. Managed Pressure Drilling — • MPD techniques may be used to improve hole stability. ✓ $' Wi'�tt� t K Ryan Ciolkosz CTD Engineer 564-5977 CC: Well File Joe Lastufka Wa HBkD = 11' - 5mfmo Ulm SH Gen 5 ACTUATOR= awW60 KB. ELN = 66 BF. ELN = Refer to Production DB for historical KOP= 1500 Akx Angle = 37° @ 4438' Datum MD= 763T DatumTVD= 67WSS ITOPOF3-12'TBG,D=2.992' I Minimum ID = 2.75" @ 2106' HES X Nipple I 7630' I .0087 bpf, D = 2.992' r S-105 SAFETY NOTES: 1 994' 1 13-12' HES X NP. D = 2.750' 1 (.AS I.FT MAAd1RFLS ISTI PEFFORATK)N SIJAMARY ITVDIMVI REF LOG: SPERRY DGR MWD ON 1025/00 TYPE I VLV ANGLEAT TOP PERF: 25@76W WOe: Refer to Production DB for historical pert data SIZE SPF WERVAL Opn/Sgz DATE 2-12" 6 7650-7670 O 03/09/01 2-12' 6 7665-7685 O 08/07/06 2-12' 6 7682-7702 c 05/12102 2-1/2' 6 7712- 7722 c 05112X12 r S-105 SAFETY NOTES: 1 994' 1 13-12' HES X NP. D = 2.750' 1 (.AS I.FT MAAd1RFLS ISTI MD ITVDIMVI TYPE I VLV LATCH PORT DATE 3 4129 3775 32 CAM-kMRd DOME PoC 18 1122/06 2 6631 5877 29 CAM -MMM DOME W 16 12/12108 1 7475 6820 27 CAM -MMM SO RK 20 12/12/06 7568' H 3-12- HES X NP, 7'x 4-112' BAK92 S-3 MOR WITH XO PINS to 312', D = 3.875' 761W 1-i312'H5XNP.D= 7620• EIMD TT NOTAVALABLE 4i FISH -2.75' X KEY (08/10/06', DATE REV BY ODkm@1T5 DATE RN BY OOMAB4fS 11110M ORIGINALCOMPLEnON 12/17/06 JCWRJC GLV C10(12/12/06) 05/31/09 PJC/TLH ONE FSH REMOVED II/27/06 1125/15 RCT/AU SEf PX R -UG (11119115) 12//0N5 DLYJMD TwEgo 12/03/15) 0127116 GTW/ PILLED PX R.UG (01/10/16) AURORA LW WELL: S-105 PERWT No: 02MI520 API No: 50-029-22977-00 BP BgAorabon (Alaska) WELLHEAD= 1 V - 5mf= Ultra SH Gen 5 ACTINTOR= CIWME80 KB.ELEV = 65, BF. l3 EV = DATE KOP= 1500' Max Angle = 37e @ 4438' Datum mb = 7637* WtumTVD= 67W SS = 3.958' L.— CSG, 40#, L -80 -M -BTC, D = 8.835" 2996' Minimum ID = 2.75" @ 2106' HES X Nipple 312' TBG, 9.2#, L -80 -EVE, BRD, 7630' .0087 bpf, D = 2.992' High Expamion Wedge 7650 H 2.75' KEY (08110/061 —-?? PERFORATOM SUMMARY REF LOG'. SERRY OOfl MNG OR 10/25/00 A NOLE A T TOP PERF'. 25 a 1050' Mele: Re 1.11A Pm p..Uo OO ier \u+o real pe r+e+le SaE SPF MTERVAL Ope,SR. DATE 2-112' 0 7050 7070 O 03/00/01 2-1R' s 70es 70a5 O 0`102100 z -+a• s 7002 17 L 05nzmz z -+R' 0 T7+2 7722 G 05nzro2 7" FLOAT COLLAR- PBTD 8017' CSG 26#, L-80YBTC, MOD, D = 6.276' 6103' 6103' S-1 0 5A I SAFETY NOTES: L i I I F 69'4-12'X3-12'XO,D=2.997 3-12' HES X NP, D = 2.750' GAS LFT MANDRELS STI ND I TVD I DEV I 7608' 2.70' DET1..OYNCNT SLEEVL 112250' FORT DATE 3 7631' 3-12' WtIEG, D = 2.992' 7620' 32 C/LM-kM\7 DMY RK 16 11127/06 �4129�37751 2 6631 5877 29 CANFMsT4 DMY RK 16 12/12106 1 7475 66 DMY RK 20 12112/06 7568' H3-12" HES X NP, D = 2.750" 7594' 7' x 4-12' BAKER S3 PKR 11110100 ORIGINAL COMPLETION VNTH XO Pl1PS to 3-12', D = 3.875' 7608' 2.70' DET1..OYNCNT SLEEVL 112250' 05/31/09 PJC/TLH OPE TSH RE&uv®1127/06 7679' 3-12' H6 X NP, D = 2.750' 7631' 3-12' WtIEG, D = 2.992' 7620' l3MD TT NOT AVALABLE 2-31W LJV2, 4.7#, L -80 -HV D511 D=1.995 10341' I DATE REV BY CORWElJIB DATE I REV BY COMv84T5 11110100 ORIGINAL COMPLETION 12/17/06 JCRNPJC GLV GO (12112106) 05/31/09 PJC/TLH OPE TSH RE&uv®1127/06 1125/15 RUMMD SET PX PLUG (11/19/15) 12/10/15 DLYJND TREE 00(12103/15) 0127/16 GTVWJ PLLLED PX PLUG (01/10/16) AURDRA LUT WELL S-105 FEATT NO: `1001520 AR No: 50-029-22977-00 SEC 35, T12N, R12, BP 6tploration (Alaska) North America - ALASKA - BP PBU S S-105 PLAN S -105A Plan: S-1 05A WP13 BP Coil Tubing Report 13 February, 2019 Project PBU, PBU, PRUDHOE Map System: Alaska NAD27 State Plane Zones System Datum: Mean Sea Level Geo Datum: NAD27' OGP-Usa AK (4267.15864] Using Well Reference Point Map Zane: NAD27 ° OGP-Use AK/ Alaska zone 4 )26734.1586• Using geodetic scale factor Site S, TR -12-12 BP by BP Coil Tubing Report Site Position: Company: North America - ALASKA- BP Local Co-ordinate Reference: Well 5-105 Project PBU TVD Reference: Mean Sea Level Site: S MD Reference: Kelly Bushing / Rotary Table Q? 65.08usft (NABORS 9E Well: S-105 North Reference: ' True Wellbore: PLAN S -105A Survey Calculation Method: Minimum Curvature Design: 5-105A WP13 Database: EDM RSK- Alaska PROD -ANCP1 Project PBU, PBU, PRUDHOE Map System: Alaska NAD27 State Plane Zones System Datum: Mean Sea Level Geo Datum: NAD27' OGP-Usa AK (4267.15864] Using Well Reference Point Map Zane: NAD27 ° OGP-Use AK/ Alaska zone 4 )26734.1586• Using geodetic scale factor Site S, TR -12-12 Site Position: Northing: 5,980,854.540 usft Latitude: 70° 21'23.002 N From: Map Easting: 617,919.920 usft Longitude: 149° 2'32.343 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.90 ° Well 5-105, Slot 22 as -built Well Position -NI-S 0.00 usft Northing: 5,980,834 750 usft Latitude: 70° 21'22S51 N +El -W 0.00 usft Easting: 618,929.810 usft Longitude: 149° 2'2 831 W Position Uncertainty 0.00 usft Wellhead Elevation: 37.91 usft Ground Level: - 36.00 usft Wellbore PLAN 5-105A Magnetics Model Name Sample Date Declination Dip Angle Field Strength I°I 1°7 (nT) BGGM2018 5/1/2019 16.80 8093 57,428 Design S -105A WP13 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,61076 Vertical Section: Depth From (TVD) +W -S +EI -W Direction (usft) (usft) (usft) (°I -37.91 0.00 000 45.00 2/13/2019 12:33:41PM Page 2 COMPASS 5000.1 Build 810 '� b BP BP Coil Tubing Report Company: North America - ALASKA - BP Local Coordinate Reference: Well S-105 Project: PBU TVD Reference: Mean Sea Level Site: S MD Reference: Kelly Bushing / Rotary Table 0 65.08usft (NABORS 9E Well. 5-105 North Reference: True Wellbore: PLAN 5-105A Survey Calculation Method: Minimum Curvature Design: 5-105A WPI 3 Database: EDM RSK - Alaska PROD - ANCPI Survey Tool Program Date 2/13/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 147.03 7,610.76 Survey#1 MWD+IFR:AK(5-105) MWD+IFRAK MWD + IFR [Alaska] 7,610.76 10,341.00 5-105A WP13(PLAN S -105A) MWD MWD -Standard Planned Survey MD Inc Azi TVDSS NIS EM Northing Easting DLeg V. Sec TFace (usft) (°) (1) (usft) (usft) (usft) (usft) (usft) ("I100usft) (usft) (°) 7,610.76 25.44 6.29 6,676.53 3,131.03 144.69 5,983,967.417 619,024.763 0.00 2,316.28 0.00 5-108 Actual Survey - TP 7,650.00 25.42 6.43 6,711.97 3,147.77 146.56 5,983,984.189 619,026.363 0.16 2,329.44 10846 KOP 7,670.00 27.22 6.43 6,729.89 3,156.59 147.55 5,983,993.015 619,027.216 9.00 2,336.38 0.00 End 9deg/100ft 7,700.00 36.22 643 6,755.39 3,172.24 149.31 5,984,008.697 619,028.732 30.00 2,348.69 0.00 7,710.00 39.22 6.43 6,763.30 3,178.32 150.00 5,984,014.785 619,029.320 30.00 2,353.48 0.00 4 7,800.00 62.93 23.43 6,819.69 3,244.59 169.48 5,984,081.350 619,047.748 30.00 2,414.11 35.00 7,897.45 90.00 34.91 6,842.36 3,326.13 215.63 5,984,163.607 619,092.587 30.00 2,504.40 24.04 5 7,900.00 90.44 35.54 6,842.35 3,328.22 217.10 5,984,165.713 619,094.025 30.00 2,506.91 55.00 7,968.29 102.00 52.56 6,834.91 3,376.82 263.97 5,984,215.048 619,140.115 30.00 2,574.42 55.00 End 30deg/100ft 8,000.00 102.00 56.47 6,828.32 3,394.81 289.22 5,984,233.441 619,165.077 12.00 2,605.00 89.60 8,100.00 102.00 68.74 6,807.52 3,439.73 375.90 5,984,279.727 619,251.026 12.00 2,698.06 88.72 8,200.00 102.00 Blot 6,786.73 3,465.20 470.15 5,984,306.690 619,344.848 12.00 2,782.71 68.72 8,268.29 102.00 89.39 6,772.53 3,470.79 536.65 5,964,313.329 619,411.252 12.00 2,833.69 89.13 7 8,300.00 98.42 88.08 6,766.91 3,471 48 567.85 5,984,314.516 619,442.426 12.00 2,856.24 -160.00 8,400.00 87.12 84.04 6,762.09 3,478.35 667.31 5,984,322.967 619,541.760 12.00 2,931.43 -160.23 '. 2/13/2019 12.33: 41PM Page 3 COMPASS 5000.1 Build BID EEO BP BP Coil Tubing Report Company: North America -ALASKA - BP Local Coordinate Reference: Well S-105 Project: PBU TVD Reference: Mean Sea Level Site: S MD Reference: Kelly Bushing / Rotary Table @ 65.08usft (NABORS 9E Well: 5105 North Reference: True Wellbore: PLAN 5-105A Survey Calculation Method: Minimum Curvature Design: 5-105A WPI 3 Database: EDM RSK- Alaska PROD -ANCP7 Planned Survey MD Inc Azi TVDSS NIS E/W Northing Easting DLeg V. Sec TFace (usft) 0 1°I (waft) lusft) (usft) (usft) (usft) 1°I100usftl (usft) (°I 8,401.04 87.00 84.00 6,762.14 3,478.46 668.34 5,984,323.091 619,542.787 1200. 2,932.23 -160.43 8 8,500.00 87.06 72.11 6,76228 3,498.89 764.85 5,984,345.045 619,638.958 12.00 3,014.92 -90.00 8,501.00 87.07 71.99 6,767.33 3,499.19 765.80 5,984,345.367 619,639.899 12.00 3,015.81 -89.38 9 8,600.00 87.73 83.88 6,772.37 3,519.83 862.32 5,984,367.527 619,736.069 12.00 3,098.64 90.00 8,700.00 87.32 95.89 6,777.23 3,520.02 962.02 5,984,369.305 619,835.743 12.00 3,169.28 89.40 8,741.00 87.43 100.82 6,779.11 3,514.07 1,002.52 5,984,364.000 619,876.335 12.00 3,193.72 88.81 10 8,800.00 87.83 93.73 6,781.66 3,506.61 1,060.96 5,984,357.470 619,934.878 12.00 3,229.76 -88.50 6,900.00 88.06 81.73 6,785.43 3,510.56 1,160.63 5,984,362.999 620,034.463 12.00 3,303.03 -88.19 9,000.00 88.57 69.74 6,788.38 3,535.15 1,257.32 5,984,389.116 620,130.749 12.00 3,388.79 -87.74 9,021.00 88.69 67.22 6,788.88 3,542.85 1,276.85 5,964,397.124 620,150.148 12.00 3,408.04 -87.39 11 9,100.00 89.20 76.69 6,790.34 3,567.29 1,351.87 5,984,422750 620,224.764 12.00 3,478.37 87.00 9,200.00 89.88 88.67 6,791.14 3,580.01 1,450.87 5,984,437.038 620,323.541 12.00 3,557.37 86.83 9,241.00 90.16 93.58 6,791.13 3,579.20 1,491.84 5,984,436.883 620,364.521 12.00 3,585.77 86.73 _ 12 9,300.00 90.03 86.50 6,791.03 3,579.16 1550.81 5,984,437.777 620,423476 12.00 3,627.44 -91.00 9,400.00 89.82 74.50 6,791.16 3,595.63 1,649.26 5,984,455.806 620,521.643 12.00 3,708.70 -91.01 9,500.00 89.62 62.51 6,791.65 3,632.20 1,742.13 5,984,493.848 620,613.916 12.00 3,800.23 -91.00 9,600.00 89.43 50.51 6,792.46 3,687.29 1,825.37 5,984,550.240 620,696,263 12.00 3,898.04 -90.94 9,700.00 89.27 38.51 6,793.62 3,758.47 1,895.34 5,984,622.518 620,765.085 12.00 3,997.85 -90.84 9,800.00 89.14 26.51 6,795.01 3,842.64 1,948.98 5,984,707.522 620,817.374 12.00 4,095.29 -90.70 9,900.00 89.05 14.51 6,796.59 3,936.12 1,983.94 5,984,801.539 620,850.844 12.00 4,186.11 -90.54 9,971.00 89.01 5.98 6,797.80 4,005.91 1,996.55 5,984,871.514 620,862.347 12.00 4,244.38 -90.34 13 70,000.00 89.07 9.46 8,798.29 4,034.64 2,000.45 5,984,900.302 620,865.787 1200 4,287.45 89.00 2/13,2019 12:33:41PM Page 4 COMPASS 5000.1 Build 81D Plan Annotations Measured Vertical Local Coordinates Depth BP a141 -S .EI -W (usft) (usft) by (usft) Comment 7,610.76 BP Coil Tubing Report 3,131.03 144.69 5-105 Actual Survey - TIP 7,650.00 6,711.97 Company: North America - ALASKA - BP KOP 7,670.00 6,729.89 3,156.59 Local Co-ordinate Reference: wells -105 6,763.30 3,178.32 Project: PBU 4 7,897.45 6,842.36 3,326.13 215.63 TVD Reference: 7,968.29 Mean Sea Level 3,376.82 263.97 Site: S 8,268.29 6,772.53 3,470.79 536.65 7 MD Reference: 6,762.14 Kelly Bushing / Rotary Table @ 65.08usft (NABORS 9E Well: 5-105 8 8,501.00 6,767.33 3,499.19 765.80 North Reference: 8,741.00 True 3,514.07 1,002.52 Wellbore: PLAN S -105A 9,021.00 6,788.88 3,542.85 1,276.85 11 Survey Calculation Method: Minimum Curvature 1,491.84 12 Design: 5-105AWP13 6,797.80 4,005.91 1,996.55 13 10,211.00 Database: 4,228.50 EDM RSK- Alaska PROD -ANCP1 14 Planned Survey 6,801.62 4,344.00 2,138.05 TD at 10341.00 MD Inc Azl TVDSS fila E1W Northing Easting DLeg V. Sec TFace (usft) (°) V) (usft) (usft) (usft) (usft) (usft) (*1106usft) (usft) (°) 10,100.00 89.31 21.46 6,799.71 4,130.84 2,027.06 5,984,996.898 620,890.867 12.00 4,354.29 88.94 10,200.00 89.58 33.46 6,800.68 4,219.40 2,073.09 5,985,086.175 620,935.482 12.00 4,449.46 88.77 10,211.00 89.61 34.78 6,800.75 4,228.50 2,079.26 5,985,095.374 620,941.504 12.00 4,460.26 88.65 14 10,300.00 89.62 24.10 6,801.35 4,305.90 2,122.94 5,985,173.448 620,983.948 12.00 4,545.88 -90.00 10,341.00 89.63 19.18 6,801.62 4,344.00 2,138.05 5,985,211.775 620,998.454 12.00 4,583.50 -89.93 TD at 10341.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth a141 -S .EI -W (usft) (usft) Just) (usft) Comment 7,610.76 6,676.53 3,131.03 144.69 5-105 Actual Survey - TIP 7,650.00 6,711.97 3,147.77 146.56 KOP 7,670.00 6,729.89 3,156.59 147.55 End 9deg/100ft 7,710.00 6,763.30 3,178.32 150.00 4 7,897.45 6,842.36 3,326.13 215.63 5 7,968.29 6,834.91 3,376.82 263.97 End 30deg/1008 8,268.29 6,772.53 3,470.79 536.65 7 8,401.04 6,762.14 3,478.46 668.34 8 8,501.00 6,767.33 3,499.19 765.80 9 8,741.00 6,779.11 3,514.07 1,002.52 10 9,021.00 6,788.88 3,542.85 1,276.85 11 9,241.00 6,791.13 3,579.20 1,491.84 12 9,971.00 6,797.80 4,005.91 1,996.55 13 10,211.00 6,800.75 4,228.50 2,079.26 14 10,341.00 6,801.62 4,344.00 2,138.05 TD at 10341.00 2/13/2019 12.33:41PM Page 5 COMPASS 5000 1 Build 81D North America - ALASKA - BP PBU S S-105 PLAN S -105A S-1 05A WP13 Anticollision Summary Report 13 February, 2019 v by Company: North America - ALASKA - BP Project: PBU Reference Site: S Site Error: 0 0ouaft Reference Well: 5-105 Well Error: 0.00usft Reference Wellbore PLAN 5-105A Reference Design: S -105A WP13 BP Anticollision Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 5-105 Mean Sea Level Kelly Bushing I Rotary Table @ 65.08usft (NABORS 9ES) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference 5-105AWP13 gfter type: NO GLOBAL FILTER: Using user defined selection 8 filtering cmena WARNING. There is hidden fight data in this project nterpolation Method MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,610.76 to 10,341.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,231.38usft Error Surface: Elliptical Conic Survey Tool Program Data 2/132019 From To (Usk) (Usk) Survey(Wellbore) Tool Name Description 147.03 7,610.75 Survey#1 MWD+IFR.AK(5-105) MWD -IFR AK MWD + IFR [Alaska] 7,610.76 10,34100 5-105AWP13(PLAN S -105A) MWD MWD -Standard Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (Usk) from Plan Offset Well - Wellbore - Design (Usk) (Usk) (Usk) (Usk) EX NKUPST NKUPST-NKUPST-NKUPST 8.291 52 6,80000 41455 8.59 41244 Pass - Minor 1200 S 5100 - 5-100 - 5-100 Out of range 5-102 - 5-102 - 5-102 Out of range 5-102 - S-1021-1 - 5-1021-1 Out of range 5-102 - 5-10211 PB1 - 5-10211 PB1 Out of range 5-103 - 5-103 - 5-103 Out of range 5-104 - 5-104 - 5-104 Out of range 5-105-5-105-5-105 762500 7,625.00 0.00 0.00 0.00 Pass - NOERRORS SAGS - 5-106 - 5-106 Out of range 5-107 - 5-107 - 5-107 Out of range 5-109 - S-109 - 5-109 Out of range 5-109 - 5-109PB1 - 5-109PB7 Out of range 5-110 - 5-110 - 5-110 Out of range 5-110 - 5-110A - 5-110A Out of range 5-110 - 5-1108 - 5-11 OB Out of range S-111 - 5-111 - 5-111 Out of range 5-111 - 5-111 PB1 - 5-111 PB1 Out of range 5-111 - 5-111 P82 - 5-111 PB2 Out of range S-114 - 5-114 - 5-114 Out of range 5-114 - 5-114A - 5-114A Out of range 5-119 - 5-119 - 5-119 Out of range 5-121-5-121-5-121 6,135.76 8,200.00 1,132.71 95.87 1,039.82 Pass - Major Risk 5-121-5-121 PB1-S-121 PB1 8,135.76 8,200.00 1,132.71 95.87 1,039.82 Pass - Major Risk 5-122 - 5-122 - 5-122 Out of range S-122 - S722PB1 - 5-122PB1 Out of range 5-122 - 5-122PB2 - 5-122PB2 Out of range 5-122 - 5-122PB3 - S-122PS3 Out of range 5-13 - S-1 3A - S -13A Out of range 5 -15 -S -15-S-15 8,944.63 9,550.00 1,096.63 175.09 937.46 Pass - Major Risk 5-15-S-15PB1-S-15PB1 8,944.63 9,550.00 1,096.63 175.09 93746 Pass - Major Risk 5-200 - 5-200A- 5-200A Out of range 2/132019 12r35.'01PM Page 2 of 3 COMPASS 5000.1 Build 81D e4 Company: North Amerim- ALASKA -BP Project: PBU Reference Site: S She Error: 0.00ush Reference Well: 5-105 Well Error: 0.00ush Reference Wellbore PLAN 5-105A Reference Design: 5-105A WP13 BP Anticollision Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 5-105 Mean Sea Level Kelly Bushing / Rotary Table @ 65.08usft (NABORS 9ES) True Minimum Curvature 1.00 sigma EDM RSK - Alaska PROD - ANCP1 Offset Datum Reference Depths are relative to Kelly Bushing / Rotary Table @ Coordinates arerelative to: 5-105 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27' OGP-Usa AK OeMral Meridian is 150° 0'0.000 W ° Grid Convergence at Surface is: 0.91° Ladder Plot tzoo $ S-213,5-213AL1,S-213AL1 V9 I $ 5-110,S-1lo,S110V18 I 1 I $ 5-110,5-110B,S-110BVO I I � - J 5-113,5-113B,S-113BV6 C I I 1 I _ -Ar 5-213,5-213A,S-213AV22 $ 5-113,S-113BL1,S-113BL1 VO � 900 I 1 I tJ I I I 1 I $ S-102,5-102L1PB1,5102L1PB1 Vll $ 5-200,5200A,5200AVO -0' 5-115,5-115,5-115V7 n I f I 1 I �---_ $ 5-102,5-102PB1,S-102PB1 V14 -___ --- --- -- ---- ----1 --- --------- .. o I I I r m I I I I I m I I I I I d I I I 600 I � , I el C I I I i I 0 ----J,------------1---JI--------J--------- ;----------- I o I I I C I `w 300 U I --- --------- -'i-__-1---- ���_---�____ ���_-------- -'I--------------- - L E G E N D -49- 5 -104,5 -104,5 -?9% 4W 5-106,5-106,5'5Q/2 60& 5-122,5-122A9P,@Q22PB2V2 12000 -W 5-106,5-106,5-10BV6 -jar SWWBu(ts0M%4WQ0Qj2sftlln) $ 5-119,5-119,5-ll9V7 -+- 5 -107,S -107,5-107V36 $ S-213,5-213AL1,S-213AL1 V9 $ 5-120,S-120,S-12OV4 $ 5-110,S-1lo,S110V18 $ 5-213,5-213AL2,S-213AL2V5 5-113,S-113A,S-113AV3 $ 5-110,5-110B,S-110BVO -4- 5-213,5-213,5-213V9 5-113,5-113B,S-113BV6 $ 5-110,5-110A,S-110AVO $ 5-213,5-213AL1-01,5-213AL1-01 V-/ 5 -113,5 -113,S -113V14 -)(- 5-100,S-100,5-tO0V10 -Ar 5-213,5-213A,S-213AV22 $ 5-113,S-113BL1,S-113BL1 VO $ 5-101,5-101PB1,S-101PB1 V10 $ S-200,5-200PB1,S-200PB1 V10 43-- 5 -114,5 -114,S -114V13 -j- S-101,5101,5-101 V5 $ 5 -200,5 -200,S -200V1 $ 5-114,5-114A,S-114AV6 $ S-102,5-102L1PB1,5102L1PB1 Vll $ 5-200,5200A,5200AVO -0' 5-115,5-115,5-115V7 $ 5-102,S-102L1,S-102L1 V5 $ 5-121,5-121,S-121 V8 $ 5-109,5-109,5-109V9 $ 5-102,5-102PB1,S-102PB1 V14 $ 5-121,5121PB1,S-121PB1 V4 -&- S-109,S-109PB1,S-109PB1 V3 2/132019 12.35:O1PM Page 3 of 3 COMPASS 5000.1 Build 81D WELL DETAILS: 5105 Ground Lewt 36.00 -W-S EFW N.n'n9 Ee.9 "aft"I Lon011uEe 6101 000 000 5980434150 61893,810 70']1'22.551N 149.2.2.831W WELLBORE DETAILS: PLAN H -105A Protect: PHD SMA W+Mw:eN�iao- by j Site: S Well: 5165 WA IWmenge: Parent Wellbore: 5105 swasMmanr Ti9 an MD: ]610.]6 S -IM L._ Mei9n: 5166,4 WPt3 q r4io-ee0lslglp WELL DETAILS: 5105 Ground Lewt 36.00 -W-S EFW N.n'n9 Ee.9 "aft"I Lon011uEe 6101 000 000 5980434150 61893,810 70']1'22.551N 149.2.2.831W WELLBORE DETAILS: PLAN H -105A fEFF1E1l;Eri0BIM1pN SMA Log6nblNn 6aMmu' MS105 I.N. Dg VxY'tl(IWIPebero' 3eelewl Parent Wellbore: 5105 Per S"I^'0'Sl Sa4exe. 561Nn0x.e 00E) Ti9 an MD: ]610.]6 .4'eraeb�aze: M1MBusbhplRaryiebb®65n0:Mp:PSON59E31 144"9 CKu6b: MNN'. M..Gmmtee sec MD Inc Ari a41VD .NAS .Et -W Dg TF. VSacl Tmel TVD W Atrnlgon 1 7610.76 25,41 629 86]653 3131,43 144"9 Om 040 231620 6676.53 7610.76 S-105AdualSune6-TIP 2 760,40 25.42 61)3 671197 3147.77 146513 0.16 1WA6 2" 6]1197 765ROO KOP 3 7670DO 27.22 6.43 6729.89 315659 14755 9DO NO 2336.30 6725.69 767ROO ETA9degMOOK 4 7710,40 39.22 6A3 6763.30 317832 150,40 30,40 040 2353.48 6763.30 771ROO 4 5 7897,45 No 3491 6842]6 3326.13 21593 3050 35DO 2504AO 664236 7897.45 5 6 796829 102.50 5258 6834.91 337882 263.97 30AO 55DO 2574,42 6834.91 796&29 EW304y10ft 7 82M.3? 1020 89.39 677243 3470.79 535.65 12.00 90DO 2833"9 6PI53 826&29 7 8 8401,44 87,40 84.0 6762.14 3478.46 66834 12.00 -1500 293223 676214 8401.04 8 9 8501DO 8707 71.99 676733 3499.19 76580 121)0 -90,40 301591 6767.33 8501.0 9 10 8741D0 8743 1092 6779.11 351447 1W2.5212.00 90,40 3193.72 6779.11 8741.0 10 11 0211)0 8899 67.22 678898 354285 127685 12.00 58.50 340A4 6788.86 9021.00 11 12 9241DO 90.16 9358 6791.13 3579.20 149194 1200 87DO 3585.77 6791.13 9241.0 12 13 W7140 89,41 5.98 6797M 4005.91 199655 12,40 4111)0 424438 6797.83 9971.00 13 14 1021100 6981 34.78 6800.75 4228.50 2079.26 12.50 89BO 445028 6800.75 10211.0 14 15 10341.00 89.83 19.18 6801"2 434.W 21MZ 1200 4)0,40 45WS) 6801.62 10341.00 TD 4110341.00 6700--6:c4 6720.LL 3u G 6290'. LLc2c a 2d 6)50'. 7 f dc2c ry 6780Oc2b t O 2e 6 Wee, y ;Mzlc Q U20 w V tact" y GBWi 2 tl36 M910Sea Lwel 1750 400 1900 2500 2150 man 2350 KOP End`k ,/100ft � Fsd1LMuP/IWft 5 5450 52W= 54150 S-105, WP13 S -1115A"13 ltlW S-IOSAn S-I51'HI 3800 5-105AT1 5-105AT2 F-lu? 1450. 32116,. - - '. _ NKGVti'f app, 220(: 24pi.. .......:. ... ..... .. .. ....,.... .. ... 2W 4lp 6W 800 1" 1200 1400 1600 NOO 2000 2250 2450 }Llp 25110 3M 3200 3260 31,40 West( -)/East(+) (200 usfl/in) S -1055) A WP10 S-105AT1 ( N 'y S-IOSAT2 7 0 12 S-IWAT3 S-105ML NS -165A 13 14 1Dtl1WaLW p 27()0 2RW 29W 3000 3100 3250 3350 3400 3550 3500 3750 3906 3900 4503 41W 4250 4350 400 45W 46011 4750 4400 491q SW3 SIW 5250 5300 5450 5%41 5650 Vertical Section at 45.00° (100 usR/in) DIM Protect: PSU SU: 5 Well: &106 Wagllore: PIANS405A Plan: 5+106AWP12 ANTISOUISION SETRNO8 COMPANY DUAJL : NodM1America-AIA8RA.BP InlepolaOon Memo: MD.inkrval: 2500 cakuMSonMemod: Mblmumcmvalcre Depen Range From: ]810.]8 To 10341 A0 Error Spbm: ISCWSA Reside Wubd By: Cerra DNMno: 1231]e Son Meaod: Tm, Cyander Nmm Reference: Plan: Sla5AWP13(E105/PIANS-105A) Ener Wrleca: ElrpSWUNc Warong Memod: Ruble Based Ladder Plot Measured Depth (100 usftIm) From Colour To MD 7611 7800 7800 7900 7900 10341 SURVEY PROGRAIM Wrb Acarica -fi A -BP FloeN Tool Delm D To W r,,Vlan Delon p 18.03 ]fitg.]fi Wrvay it MWDe1FRF1((8-105) 4M'0*IFRAK ]810.]8 10311.00 8-105A"t3rPL 1S105A) MWD Vea . a�n.1-1 som=a, a -a�mnm. eaw �aaysm�smea v� �swae �wertew _ � Vc VI,— - _I'll x�4anw r_ xaurara xw . r--11 w Mxn RE PrpShe: PBU WELL DETAILS: RNT COUIVON SETTINGS COM Na DUALS'. Noitn Americ9-AIASM-SP Ground Leah: 35 InlnrMIRS. 176 CakWEtlOn MCN00: MinimumcurvaNe WON: S-106 Wy; &106 5980 NOMOn9: 518929. FrSnn: 701MD, T. 10341 DepNRenpe Rom:ID 1034123 E SWbm: ISCWSA L94tl 06A E9cenp: 70.21- 10 10 to DIS OI¢f0noe'. 12]1D8 ReeMB limina an Scan Moftdsinw.: C*der Fon: S406A PhD[$-0p7AWPip Lelffionghnie: 7PN' 2ASIN43167 Rekmnca: S-105.4 WPt] ce S-10 Ertp Surbce: Eule,iBG0nic fi29 Lon4tl]tle'. 148'2'2.311 W 31310] WumpMeFa6 Rubs Eesetl Depth lunge: 76'10.76 To 1034'L0O ¢.1E1. a1o1. a.w;�Pe v10 ]-tmiY N E.It; 6113 E611]a1N esna able r� FFS F4 Vt Ip621 VJ FI]Po1, s.1�B� Vt s.U. ]11,67 s1w, vml5nx rwern 1 Ell....11." 6ELTONGETALS �qn 4 Sec MO Inc An ND -N S ."M DI, TFue VS.d 1 761078 2514 fi29 58)8.53 31310] 1N.fi9 0,00 0.00 2H830 2 7550.00 25.42 5.43 6711.97 314777 145.55 0.16 108.46 232828 3 7870,00 ..22 6.43 6729.89 315659 14755 9.00 0.00 2335.35 47710.00 3932 643 8753.30 3178.32 15000 30.00 000 235348 5 7897.45 ,'DO 24.91 6802.38 332613 21563 30.00 3500 250440 6 7675.29 10200 5250 8034.91 337662 28397 3000 56.00 2574.42 7 8208.29 102.00 69.39 67. S3 3470.79 55S.11].00 90.00 2833.89 8 540104 6700 80.00 VW 14 347&40 668.28 12.00 -160.00293223 9 555100 5707 71.99 6767.33 3499.19 765.60 12.00 -90.00 W15,8110 074100 5743 100.82 6779.11 351407 100252 12.00 90.00 318372 11 :G11, 0 00.69 67.22 67U SO 3542.85 1276.85 12.00 4650 3408.04 12 2400 SO 83.58 6791.13 357820 1401,04 12.00 87.00 3513577 13 9971.00 89.01 5.98 8797.80 4005.91 1995.55 1200 41.00 4N4.30 14 1021100 6981 28.78 68M]S 4228.67 207936 1200. 89,00 446028 1fi 10.1.00 139&3 19.15 5501.62 4328.67 2138.05 12.00 40.00 456350 svkV MOLW/M Depth Fmm Ne Tc S.",7 Tod 14767 7610.76 Survey FlkM-IFR0$15105) M -IFRM 7610.76 10341,00 51054Y?131GIANS105A) MWD ]-tmiY N E.It; 6113 E611]a1N esna able r� FFS F4 Vt Ip621 VJ FI]Po1, s.1�B� Vt s.U. ]11,67 s1w, vml5nx rwern 1 Ell....11." �qn 4 m, 3.1. . s�N Ell. ESI]W VE E.IW 8.1028 n11R1, E-nIPe�V] v. me s lnaav c1ia:N aw. w F1o;cln. enmw wm.cmw c]mr.W ¢.110. s119. 511E w ]-tmiY N E.It; 6113 E611]a1N esna able r� FFS F4 Vt Ip621 VJ FI]Po1, s.1�B� Vt s.U. ]11,67 s1w, vml5nx rwern 1 by North America - ALASKA - BP PBU S S-105 PLAN S -105A S-1 05A WP13 Plus 500ft MD AOGCC Offset Well Report 13 February, 2019 {., Pmpnt PBU site: s wwMxea z nl WELLBORE ttETAILS: PIAN 5.105A S105A IEF9tElCENgANrgN tauaneklNARewa�ve weoslas, r�wNuk 4pp Y Well'. S-105 v,.,yn III IST Vebd(rMlwwem. Aken smlaw Wellbore: PL NS105A np�ue..eox>' $105 j 5-105 &oeecvs)WaI. SM.Ne0N,0WE1 S -IDSA WP10 Plus 500tt M0 �x Tie on M01 J MNC+eA 0pNM6mre. KW BwYg/Mw/iWe®65ABUAIWB fdulaka AYIIrG: W.CUl . SEEM Easling (400 Iselin) Mean Sea Leval iby Company: Norm America - ALASKA - BP Project: PBU Reference Site: S She Error: 0.00usft Reference Well: S-105 Well Error: 0 oousft Reference Wellbore PLAN S -105A Reference Design: S -105A WP13 Plus 500ft MD BP Anticollision Report Local Coordinate Reference: TVD Reference: MD Reference: Norm Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well S-105 Mean Sea Level Kelly Bushing I Rotary Table @ 65.08usft (NABORS 9ES) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference S -105A WP13 Plus 50011 MD Fitter type: NO GLOBAL FILTER: Using user defined selection & fltenng criteria WARNING There is hidden fight data in this project Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Sun Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 200.00usft Error Surface: Elliptical Conic Surrey Tool Program Date 2/13/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Descdptlon 147.03 7,610.76 Survey#1 MWD+IFR:AK(S-105) MWD+IFR:AK MWD + IFR [Alaska] 7,610.76 10,841.00 S-1 05A WPI 3 Plus 50011 MD (PLAN S-105 MWD MWD -Standard Summary Reference Offset Centre to Measured Measured Centre Site Name Depth Depth Distance Offset Well - Wellbore - Design (usft) (usft) (us11) EX NKUPST S S-100 - S-100 - 5100 1,063.50 1,075.00 168.26 S-102 - S-102 - S-102 1,544.44 1,575.00 143.06 S-102 - S-102LI - S-1021-1 1,544.44 1,575.00 143.06 S-102 - S-10211 PB1 - S-102LI PB1 1,544.44 1,575.00 143.06 S-102 - S-102PBI - S -102P81 1,544.44 1,575.00 143.06 S -103 -S -103-S-103 1,173.71 1,175.00 57.13 S-104 - S-104 - S-104 375.72 375.00 13.04 S-1 05 - PLAN S-1 05A - S-1 05A WP13 10,341.00 10,341.00 0.00 5-106 - S-106 - S-106 394.22 400.00 30.91 S-106-S-106PB1-S-106PB1 394.22 400.00 30.91 S-107 - S-107 - S-107 789.74 800.00 69.59 S-108 - S-108 - S-108 918.71 925.00 125.15 S-108 - S -108A' - &108A 28.76 28.78 119.49 S-109 - S-109 - S-109 223.63 225.00 165.88 S-109-S-109PB1-S-109PB1 223.63 225.00 165.88 S-110 - S-110 - S-110 193.70 200.00 151.99 S-110 - S -1 10A- S-11 OA 193.05 200.00 151.98 S-110 - S-1108 - 5110B 180.13 200.00 151.72 S -111 -S -111-S-111 1,217.25 1,225.00 81.79 S -111-S-111 PBt-S-111 PB1 1,217.25 1,225.00 61.79 S -111-S-111 PB2-S-111 PB2 1,217.25 1,225.00 6179 S-113 - S-113 - S-113 518.58 525.00 89.56 S-1 13 - S-1 13A - S-11 3A 518.59 525.00 89.56 S-113 - S -1 13B- S -113B 518.59 525.00 89.56 S-113 - S-113811 - S-113BL1 518.59 525.00 89.56 S-114 - S-114 - 5114 394.65 400.00 16.55 5114 - S-1 14A - S -114A 394.65 400.00 16.55 S-119 - S-119 - S-119 696.42 700.00 131.69 S -201 -Plan S -201A - S -201A WP04 1,155.85 1,175.00 23.01 S-201 - S-201 - S-201 1,174A4 1,175.00 23.16 5201-5-201 PBI -S-201 PB1 1,174.44 1,175.00 23.16 2/132019 12:56:45PM Page 2 of 2 COMPASS 5000.1 Build 81D Well Slimhole CDR2-AC 4 Ram BOP Schematic Date 21 -Nov -17 Quick Test Sub to Otis -1.1 ft - M — Top of 7" Otis l 0.0 ft 4 CDR2 Rig's Drip Pan Distances from top of riser Excluding quick -test sub 71116" Sk Flange X T' Otis Box Top of Annular 6.0 ft 7 Top of Annular Element Bottom Annular CL Blind/Shears CL 2" Pipe/Slips 10.1 ft i Bt B2 Kill Line CL 2-3/8" Pipe/Slips 12.6 k CL 2" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab T1 CL of Flow Cross FIIA CL of MasterLDS LDS O Ground Level T2 Choke Line Test Pump Hose TRANSMITTAL LETTER CHECKLIST WELL NAME: _O C R 4Q vISP�� / PTD: f Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 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 ( PH) and API number (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 throu h target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: / Well Logging Requirements er 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 PRUDHOE BAY, AURORA OIL-- 640120 Well Name: PRUDHOE BAY UN AUR0-SmIQ5A Program .DEV Well bore seg ❑ I PTD#:2190320 Company BP EXPLQRATION (ALASKA) INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal ❑ Administration'17 Nonconven, gas conforms to AS31,05,0300A-A).02.A-D) _ _ NA I1 Permit fee attached . . . . ... . ....... NA ................. 2 Lease number appropriate .. .... _ _ Yes _ Entire well in ADL0028257 3 Unique well. name and number - - _ Yes 4 Well located in.a defined pool _ _ _ _ _ _ _ . _ _ Yes PRUDHOE BAY, AURORA -OIL - 640120, governed by CO 4576-- Corrected 5 Well located proper distance from drilling unit. boundary _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Rule 1: "Spacing units within the.pool shall be a minimum of 40 acres, 20.AAC 25.055(a)(1)- 6 Well located proper distance from other wells. _ _ _ _ _ _ _ .... Yes - and (2) shall -not apply to property lines within the external boundaries of the Aurora- 7 Sufficient acreage. available indrillingunit- - _ _ _ _ _ _ _ _ _ _ Yes Participating -Area." -As planned, this.well will,cpnform to spacing requirements 8 If deviated, is. wellbore platincluded- - - - - - . _ _ _ _ _ _ _ _ _ _ ... Yes 9 Operator only affected party. _ _ _ _ - - - - - - - - .. _ .. Yes 10 Operator has.appropriate- bond in force _ _ _ .. _ . _ _ _ . .. Yes . . . . ........... . Appr Date 11 Permit can be issued without conservation order ........ . ... . Yes 12 Permit can be issued without adminislrative.approval Yes SFD 2/21/2019 13 Can permit be approved before 15 day wait- - _ _ .... . . . . . . . . . Yes 14 .Well located within area and strata authorized by Injection Order # (put. 10# ln.comments)_ (For NA 15 All wells within 1/4 mite area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ NA .. 16 Pre -produced injector: duration of pre production less than 3 months. (For service well only) NA 18 Conductor stringProvided- - - - _ _ _ _ ...... NA....... - Slim CTD sidetrack, all drilling within the reservoir _ Engineering 19 Surface casingprotectsall.known USDWs .............. . . . . . . . . . . . . . NA..... - - _ Slim CTD sidetrack, all drilling and completion within the reservoir 20 CMT. vol adequate to circulate.on conductor & surf _csg . . . . . . . . . . ......... . . . . . NA- . _ - _ _ _ _ Slim CTD sidetrack, all drilling within the reservoir - 21 CMT vol adequate.to tie -(n long string to surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ______NA..... . _ Slim CTD sidetrack, all drilling within the reservoir - - - - 22 CMT.will cover all known. productive horizons- - _ . ................... . . . . Yes 23 Casing designs adequate for C, T, B &. permafrost---- - - - - - - - - - - - - - - - - - - - - -- Yes _ _ _ _ _ _ _ .. _ ......... 24 Adequate tankage, or reserve pit _ _ .... _ _ _ _ _ _ ..... Yes - - Continuing operations on Rig CDR2_ 25 If.a. re -drill, has a 10-403 for abandonment been approved _ _ _ _ _ _ _ . _ _ _ _ _ _ _ NA_ _ _ Variance_ approved to 20AAC 25,112(1) _ _ - ------ - - - - - - - - - - - - - ----- - - - - - - - - - - - - 26 Adequate wellbore separation proposed _ _____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ Yes _ Wellpath-passes all BP separationrisk criteria. _ _ _ _ _ _ _ _ _ _ ...... _ _ _ _ _ _ .......... 27 Ifdiverter required, does it meet regulations. _ _ _ _ .. NA_ _ _ _ _ Slim CTD sidetrack, all drilling within the reservoir Appr Date 28 Drilling fluidprogramschematic & equip list. adequate_ . _ _ _ _ _ _ _ _ _ ...... Yes - - _ _ . . . . . . . ................. . . . . . . . ....... . . . . . . . . ........ . . . MGR 2/22/2019 29 BOPEs, do they meet regulation _ _ _ _ _ _ ___ _ _ _ _ _ _ _ _ _ Yes ..... 30 ROPE,press rating appropriate; test to -(put psig in comments)_ _ _ ........... Yes _ _ 5000 psi equipment, tested to 3500 psi 31 Choke. manifold complies w/API_RP-53(May 84)___ _ _ Yes_..... 32 Work will occur without operation shutdown. _ ..... _ _ _ ... Yes 33 Is presence of H25 gas probable _ _ _ _ _ _ _ ____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ Yes ....... Standard BP monitoring in place_ .......... 34 Mechanical condition of wells within AOR verified (For service well only) _ _ _ . NA- - - _ _ ... This well will be fractured on 10-003 ............. 35 Permit can be issued w/o hydrogen sulfide measures _ _ _ _ _ _ _ _ _ ......No. _ _ _ _ _ No, S. -Pad is H2S. bearing. Measures required... _ _ _ _ .. . . . . . . . ..... ...... . . . . Geology 36 Data. presented on potential overpressure zones _ _ _ _ _ _ _ _ ... Yes ...... Planned mud weights appear.adequate to control Operator's forecase.downhole pressures. Managed Pressure . . Appr Date 37 Seismic analysis of shallow gas.zones.. . . . . . . . . . . . . ............ . . . NA- - - - - - - Drilling technique may be used to control hole stability.. SFD 2/212019 38 Seabed condition survey -(if off -shore) . - - - - - - . - - - .... NA - - ... - 139 Contact name/phone for weekly progress reports. [exploratory only] ... ... NA_ Geologic Engineering Public Date: Date Date Commissioner: Com Commissioner II F'V P -/1-5(t7
