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185-121
2200 sx AS III, 175 sx Class G, 20 Bbls AS I By Grace Christianson at 9:53 am, Jul 25, 2023 Abandoned 5/10/2023 JSB RBDMS JSB 072623 xGMGR08AUG2023DSR-10/25/23 Drilling Manager 07/24/23 Monty M Myers Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.07.24 10:42:02 - 08'00' Taylor Wellman (2143) _____________________________________________________________________________________ Revised By: JNL 7/20/2023 SCHEMATIC Milne Point Unit Well: MP B-15 Last Completed: 6/28/1985 PTD: 185-121 A PLUGBACK INFO APB1: 8864’ – 9955’ APB2: 8805’ – 9350’ APB3: 8790’ – 9098’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / PELP 12.715” Surface 78' 0.1571 9-5/8" Surface 36 / K-55 / Buttress 8.921” Surface 5,625’ 0.0773 7” Production 26 / L-80 / Buttress 6.276” Surface 9,131’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / BTC 3.958” Surface 8,609’ 0.0152 JEWELRY DETAIL No Depth Item GLM DETAIL: 4-1/2” x 1” KBG-2 12,404’GLM STA 6: w/ 1" DGLV w/BK Latch 23,963’GLM STA 5: w/ 1" DCK Shear w/BEK 35,484’GLM STA 4: w/ 1" DGLV w/BK Latch 46,588’GLM STA 3: w/ 1" DGLV w/BK Latch 57,567’GLM STA 2: w/ 1" DGLV w/BK Latch 68,337’GLM STA 1: w/ 1" DGLV w/BK Latch 7 8,403’ Sliding Sleeve (SSD) – Min ID 3.813 8 8,463’ Tri point Perm Iso Packer 9 8,522’ X Nipple w/ RHC-M – Min ID 3.813” 10 8,573’ WLEG: Bottom @ 8,609’ WELL INCLINATION DETAIL KOP @8,790’ Angle @ kickoff 41 deg TREE & WELLHEAD Tree 4” Cameron Tree Wellhead 11” 5M FMC w/ 3-1/2” H BPV Profile OPEN HOLE / CEMENT DETAIL 17-1/2” 100 cf Permafrost 12-1/4”2200 sx Arctic Set III, 175 sx Class G, and 20 bbls Arctic Set I 8-1/2” 275 sx Class ‘G’ TD =9,152 (MD) / TD =7,192’(TVD) 13-3/8” Orig KB Elev.: 59.0’ / Ori g GL Elev.: 24.0’ KB Elev = 59’ (Nabors 27E) 7” 2 5 6 9-5/8” 1 Casing RA marker @ 8,618’ PBTD=8,744’ (MD) / PBTD =6,867’(TVD) 3 Whipstock set @8744’ (6/23/2023)10 9 4 Fish @8,920’ 1” DMY valve and perf guns Min ID 3.813” @ 8,522’ 7 8 Whipstocks set @ 8770’, 8786’, 8801’ & 8860’ (Failed) GENERAL WELL INFO API: 50-029-21374-01-00 Initial Completion by Nabors 27E - 6/28/1985 A Sidetrack by CDR2: Operations Shutdown RWO by Thunderbird #1 – 6/10/2023 ACTIVITYDATE SUMMARY 3/30/2023 *** WELL SHUT IN ON ARIVAL*** BHPS WITH DUAL SPARTEK GAUGES. MADE TWO STOPS. 30 MIN STOP AT 8825' AND A 15 MIN STOP AT 8700' RECIEVED GOOD DATA. FINAL T/IA/OA = 1100/1100/80. 4/1/2023 ***WELL S/I UPON ARRIVAL*** (ctd) SET 3-1/2" WHIDDON CATCHER SUB ON D-NIPPLE @ 8746' MD. PULLED BK-OGLV FROM ST#6 @ 5392' MD. PULLED BK-LGLVS FROM ST#7 @ 4670' MD, ST#8 @ 3851' MD, ST#9 @ 3034' MD & ST#10 @ 2185' MD. SET BK-DGLV'S IN STA #10 @ 2,185' MD, STA #9 @ 3,034' MD, STA #8 @ 3,851' MD, STA #7 @ 4,670' MD RAN 1.25" LIB TO STA #7 @ 4,670' MD (impression of latch) PULLED 3 1/2" SHORTY WHIDDON FROM 8,740' SLM (empty) DRIFTED W/ 20' x 2.70" DUMMY WHIPSTOCK TO 8,889' SLM (lightly sat down) ***CONT WSR ON 4/2/23*** 4/2/2023 ***CONT WSR FROM 4/1/23*** (ctd) RD HES 759 SLICKLINE UNIT ***CONT WSR ON 4/3/23*** 4/3/2023 T/I/O=1166/991/50 (Load and Test Post RWO). Pumped 140 bbls Creisel into IA for load. Pumped 76 bbls Creisel into TBG for load. Pumped 4 bbls Creisel to test plug to 1000 psi. *** Job continued to 4-4-2023 *** 4/3/2023 ***WELL S/I ON ARRIVAL***(ctd) LRS LOADED IA W/ 140bbls CRESOLE SET BK-DGLV IN STA #6 @ 5,392' MD LRS LOAD TUBING W/ 70bbls CRESOLE SET 3 1/2" CA-2 PLUG IN D-NIPPLE @ 8,746' MD ***CONT WSR ON 4/4/23*** 4/4/2023 *** Job continued from 4-3-2023 *** Pumped .44 bbls to assist SL w/ setting plug. Attempted to MIT-T, pumped 3.75 bbls DSL into TBG to achieve 1500 psi, pressure immediatly fell. Conducted a LLR = .11 bpm / 4.62 gpm @ 1500 psi. Attemped to MIT- IA, pumped 7.14 bbls DSL into IA to achieve max applied pressure of 1932, IA pressure was immediatly falling off into TBG. Conduct CMIT - TBG x IA *** PASSED *** at TBG/IA 1862/1870 psi. Pumped a total of 8.65 bbls DSL to achieve max applied pressure of TBG/IA 1934/1943 psi. 1st 15 min, TBG/IA lost 35/34 psi. 2nd 15 min, TBG/IA lost 21/22 psi. 3rd 15 min, TBG/IA lost 16/17 psi. Bled TBG/IA to 294/315 psi. Bled back 3.29 bbls. Pumped 2.3 bbls diesel down TBG to assist Slickline with D&D. Slickline reset dummy in ST.#6. Pumped .70 bbls diesel down TBG and IA tracked. Assisted Slickline with D&D by pumping 1.8 bbls diesel down TBG. CMIT-TxIA PASSED to 2074/2080 psi. Pressured up T/IA to 2161/2171 psi with 2.8 bbls diesel. 1st 15 min T/IA lost 61/64 psi. 2nd 15 min T/IA lost 26/27 psi for a total loss of 87/91 psi in 30 min. Bled back T/IA to 500/540 psi and recovered 2.6 bbls. Final Whps=500/540/37 Daily Report of Well Operations PBU MPB-15 Daily Report of Well Operations PBU MPB-15 4/4/2023 ***CONT WSR FROM 4/3/23*** (ctd) LRS ATTEMPTED MIT-T, GETTING LLR .11bpm @ 1500psi LRS PERFORM PASSING CMIT TxIA TO 1700psi (see log) RAN 3-1/2" D&D HOLFINDER TESTING ABOVE EACH GLM, HELD 350psi DP ABOVE ST#6 @ 5368' SLM.(see log) PULLED BK-DGLV FROM ST#6 @ 5392' MD.(lwr pkg stack torn) RESET NEW BK-DGLV IN ST#6 @ 5392' MD, LRS CONFIRMED TBG/IA COMMUNICATION. RAN 3-1/2" D&D HOLEFINDER MULTIPLE TIMES W/ LRS ASSIST TO CONFIRM HOLE IN TBG @ 5650'-5600' SLM.(see log) LRS PERFORMED PASSING CMIT TxIA TO 2000psi (see lrs log for details) PULLED PRONG FROM 3 1/2" CA-2 PLUG BODY @ 8,746' MD MADE 1 ATTEMPT TO PULL 3 1/2" CA-2 PLUG BODY (sheared rb) ***CONT WSR ON 4/5/23*** 4/5/2023 ***CONT WSR FROM 4/4/23*** (ctd) PULLED 3 1/2" CA-2 PLUG BODY FROM 8,746' MD ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 4/7/2023 T/I/O = 54/89/41 Pumped 3 bbls Criesel down IA into Tubing, LLR of 0.10 bpm, FWP = 55/100/41 4/9/2023 *** WELL SHUT-IN ON ARRIVAL.*** PULL BK-DGLV FROM ST#6 (5,392' md). LRS DISPLACE IA WITH 95bbls SOURCE, FREEZE PROTECT. MAKE 2 ATTEMPTS TO SET BK-DGLV IN ST#6 (5,392' md), METAL RING.GOUGES ON NO-GO. RAN 1" POCKET POKER/BRUSH TO ST#6 AT 5,392' MD (off centered metal ring on no-go). MAKE 3RD ATTEMPT TO SET BK-DGLV IN ST#6 (5,392' md), METAL RING.GOUGES ON NO-GO(see log). *** CONTINUE WSR ON 4-10-23.*** 4/9/2023 T/I/O = 90/80/45 Load and Flush IA, Pumped 95 bbls Source Water down IA, Pumped 54 bbls Diesel down IA, Pumped 5 bbls 60/40 down IA attempting llr, FWP = 100/vac/60 4/10/2023 *** CONTINUE WSR FROM 4-9-23.*** SET 3-1/2" WHIDDON IN D-NIPPLE AT 8,746' MD. MADE MULTIPLE ATTEMPTS TO SET ST#6 BK-DGLV (5,392' md) SEE LOG. *** CONTINUE WSR ON 4-11-23.*** 4/11/2023 *** CONTINUE WSR FROM 4-10-23.*** TAG BK-DGLV at st#6 (5,392' MD) W/ 3-1/2" ok-1, 3" EXT, 1.25" LIB (impression of top of latch). *** CONTINUE WSR ON 4-12-23.*** 4/12/2023 *** CONTINUE WSR FROM 4-11-23.*** RAN KJT, 3-1/2" OK-1, 6" EXT, JK (one brass pin installed TO ST#6 (5,392' md) PUSH BK-DGLV BACK INTO POCKET (jk pin sheared). PULL 3-1/2" EMPTY WHIDDON FROM D-NIPPLE AT 8,746' MD. *** WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED.*** 4/20/2023 T/I/O=0/0/0 Hot flush flowline/Clear Hydrates (Pre RWO) Pumped a total of 3.5 bbls of 60* 60/40 down FL. Unable to clear hydrates. Let soak over night. 650 psi left on flowline. 4/21/2023 Flowline Hot Flush/Hydrates (Pre RWO) Pumped a total of 1.3 bbls of 160* diesel down Flowline. Applied pressure from MOD to Well with gas. FL pressured up. Rigged up in MOD, pumped a total of .10 bbls of 160* diesel. Unable to clear hydrates. Daily Report of Well Operations PBU MPB-15 4/24/2023 Freeze Protect (Clear Flowline Hydrates) Pumped .20 bbls 60/40 down Flowline. Flowline not clear. 4/26/2023 Freeze Protect Flowline (Pre RWO) Pumped1 bbls 60/40 down FL. Flowline frozen. bled to 0 psi. 5/13/2023 Attempt to Clear Flowline, Pressured up and Bleed back multiple times, NO movement, Line Still Frozen, Left 650 psi on Line 5/14/2023 Attempt to Clear Flowline, Pumped 12.5 bbls 60/40 down flowline, Pumped 50 bbls warm Criesel down Flowline to flush, Pumped 10 bbls 60/40 for final Freeze Protect down Flowline 5/22/2023 Assist CDR2 with freeze protect. Pumped 30 bbls of 60* diesel. 5/26/2023 *** WELL SHUT-IN ON ARRIVAL.*** SET 3-1/2" CA2 PLUG IN D-NIPPLE AT 8,746' MD. MAKE 3 ATTEMPTS TO PULL BK-DGLV FROM ST#1 (8,655' MD). RAN 1.25" LIB TO ST#1 (8,655' MD). IMPRESSION OF JUNK ON TOP OF POCKET. PULL BK-DGLV FROM ST#2 (8,118' MD). LRS PEFORMED 4 FAILING CMIT TxIA TO 3000psi. *** CONTINUE WSR ON 5-27-23.*** 5/26/2023 T/I/O=2/70/55 Assist Slickline. CMIT-TxIA to 3000 psi Failed. Pressured up T/IA to 3175/3264 psi with 5 bbls diesel. 1st 15 min T/IA lost 75/74 psi. 2nd 15 min T/IA lost 68/67 psi for a total loss of 143/141 psi in 30 min. Bled T/IA and recovered 3.5 bbls. Final Whps=100/150/53 5/27/2023 *** CONTINUE WSR FROM 5-26-23.*** LRS PERFORMED PASSING CMIT TxIA TO 3000psi (See log). PULL 3-1/2" CA2 PLUG FROM D-NIPPLE @ 8,746'MD. *** WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED.*** 5/27/2023 T/I/O=71/157/54 CMIT-TxIA to 3000 psi PASSED. Pressured up T/IA to 3195/3289 psi with 3.7 bbls diesel. 1st 15 min T/IA lost 66/66 psi. 2nd 15 min T/IA lost 22/22 psi for a total loss of 88/88 psi in 30 min. Bled back 3.7 bbls. Final Whp's=95/185/54 6/17/2023 ***BEGIN WSR*** RIG UP CONNECT WHIPSTOCK WITH BAKER SET WHIPSTOCK 200DEG FROM TOP SIDE BOW AT 8777' RIG DOWN ***END WSR*** 6/18/2023 T/I/O=88/200/20 Pressure test IA to 1500 psi. Pumped 1 bbl diesel to pressure up IA. IA lost 41 psi in 10 min. Final Whps=53/200/20 SET WHIPSTOCK 200DEG FROM TOP SIDE BOW AT 8777' Activity Date Ops Summary 5/7/2023 Complete rig move from PBU to MPB-15. Arrive on pad. Remove jeeps. PJSM, Begin moving main sub into place. RU Stomper for remaining moves over well. Spot mud pits and set down. PJSM, RU Checklists. R/U cellar. R/U return line to tiger tank. PT to 4200 psi. LTT tree valves. N/U MPD line. N/U BOP's. Take on rig water. Grease and service rig valves. Fluid pack coil with 5 bbls methanol and fresh water. 5/8/2023 Completed filling coil. Reverse circulated slack into reel. Cut 246' pipe, Cut 34' Pipe / E-Line (1.63% slack). Check e-line. Continuity good, Meg low. Trouble shoot. Fixed issue. Make up coil connector. Pull test to 35K. Good. Make up BHI UQC w/o floats. Install test cap. PT IRV iron, Bulkhead, Coil, CTC, UQC to 7000#. Good test. Bleed down. Begin initial BOPE test. Test witnessed by AOGCC representative Adam Earl. Test 1: IRV, Stripper, C7, C9, C10, C11 Pass. Test 2: Blind/Shears, R2, B2, C15 Pass. Test 3: Annular (2-3/8"), TIW #1, B1, B4 Fail. Function annular and repeat tests. Fail. Test 4: Upper 2" Pipe/Slips, TIW #2, B2, B3 Pass. Test 5: Lower 2" P/S, C5, C6, C8, TV2 Pass. Test 6: Choke A and C Pass. Test 7: C1, C4, TV1 Pass. Test B1, B4, TIW #1 Pass. Test 8 - Replace leaking sequential valve on 2 3/8" rams. Pass. Draw Down Test on Accumulator. PJSM with Nabors crew and mechanic to replace annular element. Begin changing annular element. Function test new annular element. Test Annular (2"), C2, C3 Pass. Test 2 3/8" Pipe/Slips Pass. Complete BOPE test. L/D test and R/D BOPE test equipment. Measure and record RKB's. R/U PDL's and test to 250/3500. Pass. M/U Nozzle BHA. PT UQC and floats to 250/3500. 5/9/2023 Pump slack forward. Bullhead kill well. 5 bbls 60/40 Methanol. 160 bbls 1%SL KCL Rate: 3.25 bpm 300 psi. Pressure falling. Pump 25 bbls 10.5 ppb Polyswell in Powerpro. 10 bbls Neet Mud. 10 bbls freshwater. Chase with 8.7 ppg Powerpro. Shut down 6 bbls early due to fluid falling. Allow polyswell to hydrate for 1hr. Come online. Pump across top. ~30 bph loss rate. Push 12.5 bbls of polyswell into perfs. Let soak for another 15 minutes. Squeeze 6 bbls. Up to 250 psi. Started breaking over. Let soak. Looks like its broke over. Mix and pump 25 bbls of 20 ppb Polyswell. 2.65 bpm in. Pressure increasing as soon as polyswell hit perfs. Let polyswell soak. 1498 psi on well when 20 bbls pushed into perfs. Let set for 40 min Push 1 bbl, 800 psi. Breaking over. Let sit 20 min. Push another 1 bbl to 1000 psi. Let sit 20 min. Push 2 bbls. to 1000 psi. Let sit 20 min. Push 2 bbls to 1000 psi. Line up down coil. RIH with nozzle BHA #1 to clean out residual polyswell. In Rate = 1.03 bpm, Out Rate = 1.27 bpm. In Mud WT = 8.70 ppg, Out Mud WT = 8.74 ppg. IA = 544 psi, OA = 51 psi. WT CK at 8500' = 37k PUW. WT CK at 8770' (tubing tail) = 37k. WT CK at 8893' = 36k. Increase rate and POOH for whipstock BHA. POOH for whipstock BHA. In Rate = 1 bpm, Out Rate = .42 bpm. In Mud WT = 8.70 ppg, Out Mud WT = 8.74 ppg. OOH - Flow check well and PJSM with Nabors crew. Fill hole and establish 8 bph loss rate. L/D nozzle BHA #1. M/U and RIH with NS 350 - 700 High Expansion Wedge. In Rate = .33 bpm, Out Rate = .31 bpm. In Mud WT = 8.70 ppg, Out Mud WT = 8.74 ppg. Log GR Tie In from 8300' @ 5 fpm. No correction needed on first logging run. PUH to re-log upper character. Log from 8200' to catch additional GR character. Same correction. RIH to whipstock set depth. WT CK = 37k @ 8800'. RIH to setting depth of 8869'. Close EDC and set whipstock. 2600 psi shear. 4.8k down weight. POOH for window milling BHA. In Rate = .77 bpm, Out Rate = .27 bpm. In Mud WT = 8.69 ppg, Out Mud WT = 8.71 ppg. OOH - Flow check well and confirm no flow. L/D whipstock setting tool. 5/10/2023 M/U and RIH with window milling BHA. NSAK fixed bend motor 1 degree. String reamer 2.74" GO/2.73" NOGO. Window mill 2.75" GO/2.74" NOGO. In Rate = .37 bpm, Out Rate = .66 bpm. In Mud Weight = 8.68 ppg, Out Mud Weight = 8.68 ppg. Log tie in from 8220' @ 5 fpm. Correct -.5'. RIH and dry tag whipstock pinch point at 8864.7'. PUH and bring pump up to milling rate. Mill 2.74" HS window from 8864'. In Rate = 1.80 bpm, Out Rate = 1.05 bpm. Free spin = 3260. In Mud Weight = 8.68 ppg, Out Mud Weight = 8.72 ppg. IA = 615, OA = 53. Mill 2.74" HS window from 8864'. In Rate = 1.55 bpm, Out Rate = 1.17 bpm. Free spin = 3250. WOB = 1.62k, ECD = 9.86 ppg, WHP = 0 psi. In Mud Weight = 8.71 ppg, Out Mud Weight = 8.72 ppg. IA = 623, OA = 58. Stall at 8866.56', PU and work down slow to motor work then continue time milling. WOB dropped off at 8867', continue time milling for 1' then start milling 10' of rat hole. Loss rate at 25-30 bph. Milled Rat Hole to 8878', start back reaming passes at 15 L&R of as milled. Catch samples from 8875' and 8878', 20% formation in samples. Completed 4 up ream passes 15 L&R of as milled and HS going down. Dry drift to TD is clean, PU dry to TOWS is clean. Open EDC and POOH for drilling BHA. Static Loss Rate = 18 bph. OOH - Flow check well. PJSM with crew. L/D window milling BHA. Mill 2.74" GO. 2.73" NOGO, String Reamer 2.74" GO, 2.73" NOGO. M/U lateral BHA #4. RIH with lateral BHA #4. In Rate = .36 bpm, Out Rate = .51 bpm. In Mud Weight = 8.71 ppg, Out Mud Weight = 8.72 ppg. Log tie in from 8220' @ 5 fpm. No correction needed. Tag Camco D nipple at 8750'. Pick up clean. Change TF to LS and attempt again. Multiple attempts to get through nipple with no success. POOH to lower motor bend and inspect BHA. L/D motor and lower bend from 1.4 degree to 1.2 degree. Roll wear pad 180 degrees on motor. RIH with BHA #5 - Build/Lateral. 1.2 degree bend w/Hycalog 3.25" bi-center bit. In Rate = .53 bpm, Out Rate = .60 bpm. In Mud Weight = 8.72 ppg, Out Mud Weight = 8.72 ppg. Tie In - No correction needed. Tag D nipple at 8749'. Pull up and turn bit and attempt again. Change TF and repeat. Pump 5 bbls HiVis pill through open EDC. Multiple attempts to pass D nipple. No success. POOH to change BHA/Bit. In Rate = .78 bpm, Out Rate = .45 bpm. In Mud Weight = 8.71 ppg, Out Mud Weight = 8.73 ppg. 5/11/2023 Continue POOH to swap out bits. OOH, flow check well, good no flow, PU injector, pull BHA and swap out Hycalog bit for Hughes bit with a smaller pass through. Bit swapped out, RIH. Log tie in at 8200' with 0' correction, RIH to D-Nipple to see if we can pass through. Tag at 8749.7' with HS TF and 6k WOB. PU and orient to 180, tagged again, PU and try 90 L&R. Tagging at same depth at different orientation. Close EDC and roll the pumps to try and roll the wing of the bi-center. First attempt failed, roll pumps again. Not able to pass through D-Nipple with 2.74 x 3.25", discuss options with DE. POOH to swap to 2.70 x 3.00" Bits. OOH, flow check well. Good no flow, remove the injector and pull the BHA. Set up motor with a 1.26 deg bend for 2.70 x 3.0" Bi-Center Bit. Drift D-Nipple with current motor and 2.74 x 3.25" bit. The Bi-Center wing on the bit forces the bit box of the motor into the no-go of the D-Nipple profile keeping it from passing through. PU Motor and 2.70 x 3.00" Bi-Center and drifted through D-Nipple profile clean. MU injector to BHA. RIH with drilling BHA. Log tie in, no correction, RIH to drift D-Nipple. Pass through D- Nipple clean, PUH to log CCL for Liner top placement. Close EDC and RIH through window clean. Tag TD on depth, retag to confirm, PU to up WT and bring pumps on line to start drilling. Drill 3" lateral from 8956' to 9330' with BHA wiper trips every 150'. In Rate = 1.81 bpm, Out Rate = 1.75 bpm. In Mud WT = 8.73 ppg, Out Mud WT = 8.77 ppg. Circ pressure = 4028 psi. ECD = 10.42. IA = 766, OA = 64. Long wiper trip from 9330'. Pump sweep and jog below window. Pull through window clean. Jet/Clean 7" at max rate. Open EDC and pump max rate. PUH to logging depth. Log tie in from 8200' @ 5 fpm. Correct + 4.5'. Close EDC and RIH clean. Log GR from 8800' bit depth. Drill 3" lateral from 9330' to 9552'. In Rate = 1.81 bpm, Out Rate = 1.81 bpm. In Mud WT = 8.77 ppg, Out Mud WT = 8.79 ppg. Circ pressure = 3611 psi. ECD = 10.46. IA = 758, OA = 82. Drill 3" lateral from 9552'. In Rate = 1.84 bpm, Out Rate = 1.85 bpm. In Mud WT = 8.78 ppg, Out Mud WT = 8.88 ppg. Circ pressure = 4032 psi. ECD = 10.46. IA = 799, OA = 84. 50-029-21374-01-00API #: Well Name: Field: County/State: MP B-15A Milne Point Hilcorp Energy Company Composite Report , Alaska 5/10/2023Spud Date: 5/12/2023 Continue drilling lateral from 9570'. In Rate = 1.90 bpm, Out Rate = 1.87 bpm. In Mud WT = 8.79 ppg, Out Mud WT = 8.86 ppg. Circ pressure = 4063 psi. ECD = 10.59 ppg. IA = 794, OA = 86. Drilled 450' to 9780' pull wiper to the window. Jog in hole below WS then pull through window. Above the window, open the EDC trapping 10.6 ECD and jet the WS tray. Tag at 8871', PU and tag at 8865' then at 8860'. PUH and log tie in at 8200'. Correct depth +6' and RIH. Stop above the window and close the EDC holding 10.6 EDC. RIH and tag at 8867' 1.7k WOB. PU and RIH tag at same depth. PU and bring pumps on at 0.5 bpm just to roll the bit a little and work down. Several attempts to pass through the bottom of the window have failed, POOH for a clean out BHA. Maintain 10.6 ECD at the window. PUD BHA. Remove RES Tool and bit, bit grade = 1-1. PD Clean Out BHA with Window & String Mills and 1 deg bend Motor. Clean Out BHA deployed, RIH. Log tie in, no correction, close EDC and RIH to to tag. Tag at 8864', PU and start pumps to clean out window pumping L&H Vis Pills. A little ratty through the window then cleaned up. Clean to 8894', RA Marker is on depth, PUH slow to the TT. Continue circulating Hi/Low Vis pills out of well. RIH through window to end of build at 9150'. Minor bobbles less than 1k. Tag @ 9100' with 3k down. Drop rate to 1 bpm and run past to 9150'. Pump Hi/Lo sweeps from end of build. Open EDC above window. Pump max rate and jet whipstock tray with Hi/Lo sweeps. Chase sweeps to tubing tail and circulate out of hole. Close EDC. Drift window and build clean to 9160'. Open EDC above window and jet whipstock tray. Pump final Hi/Lo vis sweep across whipstock and chase to tubing tail. POOH for lateral BHA. In Rate = 2.22 bpm, Out Rate = 2.02 bpm. In Mud WT = 8.78 ppg, Out Mud WT = 8.82 ppg. Circ pressure = 2916 psi. ECD = 10.66 ppg. IA = 794, OA = 97. OOH - Pressure undeploy clean out BHA #8. Hold 10.6# ECD at window. Sequential valve on deployment rams leaking. Well is secured. Continue maintaining 10.6 # ECD through MPD line. Continue L/D cleanout BHA. Repair/Replace sequential valve on deployment rams. Function test rams close on 2 3/8" test joint. Continue with pressure deploy of lateral BHA. RIH with lateral BHA #9 - 1.1 degree motor bend and 3" HYC bi-center bit. In Rate = .55 bpm, Out Rate = .88 bpm. In Mud WT = 8.78 ppg, Out Mud WT = 8.85 ppg. Circ pressure = 1506 psi. ECD = 10.67 ppg. IA = 1075 OA = 69. 5/13/2023 Continue RIH with Drilling BHA. Log tie in, no correction, close EDC and RIH to continue drilling lateral. Set down at 8869, PU, set down at 8880', PU clean, RIH pretty ratty down to 8960' then cleaned up. Getting a little ratty at 9115'. 9165' packing off above the BHA, reduce rate, PUH Ann psi bled of. 9092' starting to pull heavy and packing off then cleaned up. Keep PUH increasing rate, RIH and stacked WT and packing off PU. Pulling clean to 9047', RIH a little ratty to 9183', PUH at rate to 8995'. RIH to 9047' and set down WT. POOH to the window to clean up the OH. Stop at 8905' keeping the bit below the window and the EDC just above the TOWS. Open the EDC and reciprocate EDC in the 7" while circulating bottoms up pills to surface. Circulating up pills and getting sand back like were drilling 50- 60 fph. Bottoms up brought up an increase of silty sand and no chunky stuff. The wellbore should be clean with all the circulating that was done during the clean out run so it looks like and unconsolidated sand that is sluffing off. RIH at min rate to see if we can drift bottom, passed through build without issue. 100' off bottom at 9680', bring pumps up to rate to continue drilling. Pumps at rate, packing off and stacking weight with no change to WOB, packing off around the coil. Reduce rate and PUH, pulled 50k then fell off. 9245' RIH at rate, set down at 9441', PU then RIH at min rate. Tag at 9775', bring pumps up to rate and we are packing off. Wellbore is unloading a lot of sand, PUH slow until it cleans up. Discussed current well condition with the DE. Start control drilling limiting ROP monitoring Ann Psi for packing off. Continue drilling lateral from 9570'. In Rate = 1.90 bpm, Out Rate = 1.88 bpm. In Mud WT = 8.79 ppg, Out Mud WT = 8.82 ppg. Circ pressure = 3725, ECD = 10.65 ppg. ANN Psi = 3940 psi. Lost the RES Tool, attempts to get it to restart failed, calls to the Town Team, continue to drill to TD and swap out the RES Tool on the wiper trip to the swab then Mad Pass log the interval on the drift to TD. 8950' ROP increase and it looks like we are in the C-Sand, start dropping angle down to 92 deg. Well Control Drill - KWD Drill. Increase ROP to 70 fph, Ann Psi stable. Drilled to 9955' pull wiper to window to see how the B-Silts are. Pull to bottom of Rat Hole then jog in hole 100'. PU to 8905' and open the EDC 10' above the WS. Jet WS Tray and POOH to the TT with the EDC. 8832' Ann Psi climbing, CTC at the TT, RIH and circ a bottoms up. Got back a lot of chunky shale. Continue jetting 7" at 2 bpm. Returns cleaning up. Pull into tubing tail and POOH above tie in depth. Tie in from 8200' @ 5 fpm. Correct +11'. RIH through window and tag at 8952' pumping .6 bpm. Increase rate to 1 bpm and RIH to 8970 and tag. PUH. Continue working in hole with rates between .2 and 1 bpm. RIH at 1.8 bpm pumping sweeps. Tag again at 9076'. Pump 30 bbl, 3 ppb nut plug sweep and cont RIH. Attempt to pass 9106' area. Suspect fault at 9085'. Pump 50 bbls new mud and attempt to run past at different pump rates. Run past fault while pumping new mud. Unable to pass ~ 9812'. Appears we are packing off with ECD's as high as 11.47 ppg and 75% losses at times. POOH to clean window and regain returns. Overpulls noted through fault area (9106'). Jog in hole at max rate below window twice. Pump Hi/Lo vis sweep from bottom of window. Pull EDC ports above window. Open EDC. Jet whipstock tray and window at max rate. Jet whipstock tray 3 times and POOH to clean 7". In Rate = 2.47 bpm, Out Rate = 2.42 bpm. In Mud wt = 8.74 ppg, Out Mud wt = 8.77 ppg. Continue jetting 7" with Hi/Lo vis sweeps. Packing off and higher ECD's near tubing tail. RBIH and continue jetting 7" at 2.46 bpm. Pump multiple bottoms up. Well unloading at surface. Discuss plan forward with Drilling Engineer. Clean out 7" for whipstock. 5/14/2023 After discussions with the DE and Town Geo about the instability of this wellbore, we are going to set another WS and re-drill this well. Made calls to NSAK to prep another 3-1/2 x 7" WS while we clean out the 7" for another set. Pump Low & High Vis Pills and verify wellbore is clean before POOH. Last bottoms up pill is clean, POOH max rate at 80 fpm slowing down at GLM's to ensure Wellbore is clean. OOH, flow check well and LD the drilling BHA. Good no flow, PU Injector and LD the BHA. MU NSAK Whipstock, verified HS scribe and drifted the BHA with 2.73" Drift ring. BHA MU, EDC is open and pump trips set to 500psi, RIH. Stop RIH, lost COMMS to the tools, POOH and test UQC connection. OOH remove injector and test the UQC. Eline is good, test the P&C and most likely swap out. Tools swapped out, RIH. Log tie in, no correction. RIH to set depth with TOWS at 8800'. Close EDC, tool sheared at 3100psi, set down 4.5k WOB with no movement. WS set POOH. OOH - Flow check well and confirm no flow. 2.4 bph loss rate. PJSM with Nabors crew. L/D whipstock setting BHA. M/U and RIH with window milling BHA. RIH with window milling BHA #12. 1.1 degree motor and 2.74" mill and string reamer. In Rate = .49 bpm, Out Rate = .51 bpm. In Mud WT = 8.75 ppg, Out Mud WT = 8.78 ppg. Log tie in from 8200' @ 5 fpm. No correction needed. RIH to begin window milling. Dry tag @ 8806'. PUH and begin milling window. Mill 2.74" window from 8805'. In Rate = 1.81 bpm, Out Rate = 1.78 bpm. In Mud WT = 8.75 ppg, Out Mud WT = 8.78 ppg. Circ pressure = 3707 psi. IA = 736, OA = 84. Continue milling 2.74" window from 8806.7'. In Rate = 1.82 bpm, Out Rate = 1.80 bpm. In Mud WT = 8.75 ppg, Out Mud WT = 8.77 ppg. Circ pressure = 3721 psi. IA = 742, OA = 93. Continue milling 2.74" window from 8808.7. In Rate = 1.83 bpm, Out Rate = 1.78 bpm. In Mud WT = 8.75 ppg, Out Mud WT = 8.77 ppg. Circ pressure = 3786 psi. IA = 732, OA = 94. Mill exits at 8909'. Bottom of window. Continue milling at 1 fph to ream bottom of window. Mill rat hole to 8819'. Begin back reaming window. Backream HS, 15 deg LOHS and 15 deg ROHS. 5/15/2023 Continued with window milling Ops - Window milled from 8805' to 8809' plus 10+ of rat hole to 8819. Start reaming passes 15 deg L&R of HS. Bottoms up sample 100% formation. Shut down pump and dry drift. Tag at 8809 bottom of window, PU and bring pumps back online and continue ream passes. Stacking weight with little to no motor work. Still stacking WT, PU to just below the TT to see if we have some debris holding us up. RIH and passed through the window, repeat ream passes then attempt to dry drift again. Still stalling at the bottom of the window at 8808.9', PU then come back down to 8808.5 and time mill down. Getting WOB and motor work at the bottom of the window continue time milling until clean. Time milled 1' passed the bottom of the window with the string mill. Start back ream passes and then dry drift in both directions. Drift is clean, open EDC and POOH. OOH, flow check well, good no flow, LD the milling BHA. Window and string mills gauge 2.73 go, 2.72 no go. MU the build BHA with 2.0 deg motor. RIH with build BHA. Log tie in with 0' correction. Pass through D-Nipple and window without issue to TD. PU to up WT and bring pumps online. In Rate = 1.86 bpm, Out Rate = 1.78 bpm. In Mud WT = 8.69 ppg, Out Mud WT = 8.72 ppg. Circ pressure = 3260 psi. IAP = 613, OAP = 89, ECD = 10.14. Build section completed, POOH for lateral BHA. In Rate = 2.53 bpm, Out Rate = 2.15 bpm. In Mud WT = 8.70 ppg, Out Mud WT = 8.73 ppg. Circ pressure = 3941 psi. IAP = 790, OAP = 102, ECD = 10.15. OOH - PUD build BHA. Bit graded 1:1 with a plugged nozzle. Function test BOP's. Re- tighten inner reel iron and pressure bulkhead. Pressure test coil and inner reel iron to 7000 psi. Replace leaking sequential valve on lower most 2" pipe/slip rams. PD lateral BHA with 1.1 deg motor and HCC 2.70" x 3" bi-center bit. RIH with BHA #14. In Rate = .51 bpm, Out Rate = .76 bpm. In Mud WT = 8.70 ppg, Out Mud WT = 8.76 ppg. Circ pressure = 1481 psi. IAP = 984, OAP = 79, ECD = 10.4. Log Tie In from 8200'. Correct .5'. Close EDC and RIH through window clean. Log RA tag in whipstock and confirm WS/window depths. Drill 3" Lateral from 8900' to 9054' and BHA wiper. Pump lo/hi vis sweep. In Rate = 1.80 bpm, Out Rate = 1.84 bpm. In Mud WT = 8.71 ppg, Out Mud WT = 8.73 ppg. Circ pressure = 3136 psi. IAP = 712, OAP = 82, ECD = 10.18. Drill 3" Lateral from 9054' to 9084'. In Rate = 1.80 bpm, Out Rate = 1.84 bpm. In Mud WT = 8.71 ppg, Out Mud WT = 8.73 ppg. Circ pressure = 3136 psi. IAP = 712, OAP = 82, ECD = 10.18. 5/16/2023 Continue drilling ahead at 9065' in B8 Shale looking for the B7 sand. In Rate = 1.84 bpm, Out Rate = 1.84 bpm. In Mud WT = 8.71 ppg, Out Mud WT = 8.79 ppg. Circ pressure = 3567 psi. IAP = 749, OAP = 104, ECD = 10.36. Drilled 450' to 9350', pull wiper to the window. Jog below the window, PU to 8850, open EDC. Wash across the WS then up into the TT. Tie into RA Marker. We have made 2 passes to log the RA and we are not seeing it. We did see on the way up but are not seeing it now. Continue logging down to see if we tag at the lower WS at 8860'. Tagged at 8859', near bit surveys show we are in the parent wellbore and WS may have released. PUH to 8200' and log gamma tie in to verify we are on depth. Correct depth +4', shut down and reboot BHI Tools then RIH to relog. Relog and tagged at 8858', near bit inclination confirms we are still in the parent wellbore, WS fell on top of the one at 8860'. POOH for READ Caliper Logging Tools. OOH, flow check well. Good Not Flow, PU injector and LD drilling BHA. READ Mem Logger on location. Drilling BHA LD. READ Programming Tools for caliper run. MU Caliper Logging tools. RIH with Caliper Logging Tools. Inner reel iron leaking at the 3" 1502, first connection to the coil. Hammer union was loose, but we have no means of being able to isolate that union to test it. POOH to surface from 1500'. OOH - PJSM with Nabors crew and READ logging specialist. Flow check well and confirm no flow. ~ 1 bph loss rate. L/D READ caliper BHA and secure well. Rig down inner reel iron and replace failed ring gasket. M/U eline pressure bulkhead. Test inner reel iron to 7000 psi. Good. Test eline and pressure bulkhead. Good. Program READ caliper logging tools. M/U caliper logging BHA. RIH READ caliper logging BHA. Continue RIH with logging BHA. Stop NPT at 1500'. In Rate = .52 bpm, Out Rate = .79 bpm. In Mud WT = 8.75 ppg, Out Mud WT = 8.78 ppg. IA = 647 psi, OA = 72 psi. Log Tie In from 8170' @ 5 fpm. No correction needed. RIH to logging depth of 8,855'. Wait until 02:21 for caliper arms to open and then log up. Log 24 arm extended reach caliper from 8855' to 8600' @ 50 fpm. Pause at 8596' until arms closed. RIH to 8855' Wait until 02:53 for arms to open. Log 24 arm extended reach caliper from 8855' to 8600' @ 50 fpm. Wait for arms to close. POOH. POOH with READ caliper logging BHA. In Rate = .99 bpm, Out Rate = .70 bpm. In Mud WT = 8.75 ppg, Out Mud WT = 8.77 ppg. IA = 620 psi, OA = 80 psi. OOH - flow check well and confirm no flow. L/D READ caliper BHA. Download tools to confirm good data. 5/17/2023 Pull data from Caliper Tool and confirmed good data. LD BHI MWD and prep for testing BOP's. Remove BHI Floats and service tree valves. Displace mud from coil with freshwater while flushing stack. Close Swab and PT to test BOP's. Good PT, grease stack and choke valves to prep for testing. Test BOPE, Test witness waived by AOGCC Guy Cook. Test 1: IRV, Stripper, C7, C9, C10, C11 - Pass. Test 2: Blind/Shears, R2, B2, C15 - B/S Fail/Function/Fail. Re-Test 2: R2, B2, C15 - Pass W/O Blind/Shears. Test 3: Annular (2-3/8"), TIW #1, B1, B4 - Pass. Test 4: Upper 2" Pipe/Slips, TIW #2, B2, B3 - Pass. Test 5: Lower 2" P/S, C5, C6, C8, TV2 - Pass. Tested Gas Alarms. Test 6: Choke A and C - Pass. Test 7: C1, C4, TV1 - F/P on TV1 - Pass. Test 8: 2-3/8" Pipe Slips, C2, C3 - Pass. Test 9: Blind Shears - Fail. LO/TO on Koomey. Change out Blind/Shear rams. Test Blind/Shear rams, good. Rig down BOP test equipment. Put drilling risers back in place. Pressure test both PDLs, good. Install floats and M/U nozzle for PT. Change packoffs. PT floats, packoffs together, good. Swap CT back to mud. M/U BHA #17 - NSAK HEW Whipstock. RIH with whipstock. Set pressure and slackoff trips close. Tie-in depth from 8180'. Correct +1.5', RIH to set depth. WTCK = 42k, RIH to 8794.75' (TOWS @ 8786'). PU to 38k and set WS 10 deg ROHS. WS set at 3300psi, set down 6k WOB, no movement, POOH. 5/18/2023 POOH at 5600' from setting WS (TOWS at 8786', Pinch Point at 8790', BTM at 8794.75'). OOH, flow check well, good no flow, PU the injector and LD the WS Setting BHA. Setting tool looks good. Remove BHI UQC and boot wire. PU 1 jut of 2-1/16" CSH and deploy across stack to pump eline slack out. PU injector and cut off pumped out slack. Pumped out 211 of 248'. MU CMT Stinger and 2.5" Nozzle. RIH with CMT BHA. Tag pinch point on depth at 8790'. PU and displace well to 1% KCl. Perform injectivity test. 1100psi at 1 bpm, discuss plan forward with DE. HES on location RU. Hold PJSM to mix and pump 10 bbls of CMT. Fluid Pack CMT line to PT to 4500psi. 16:17 CMT Wet, 6:11 thickening time, ends at 22:28. 16:35 online with CMT Pump. Zero In MM at 13.5 ppg and load 10 bbls of CMT in reel. 10 bbls in reel shut down CMT Pump and flush CMT line. Online with rig pump to displace CMT at 2.0 bpm at 4000 psi. 36 bbls away close choke and squeeze CMT past WS. 40 bbls away injecting at 925 psi shut down at 6 bbls below WS. Online, squeeze 2 bbls then lay in last 2 bbls above WS then pull up to safety. WCTOC at 8550' stop at 8250'. Online with pump to circ contam pill down maintaining 900psi WHP with 1:1 returns. Cleanout to 8650' then 8750' take 100' bites. Reduce WHP to 600 psi to keep 1:1 returns as cement is circ out. Light tag on whipstock pinch point 8789', pick up and repeat. POOH pump 2.1 bpm keep 600 psi WHP on trip out. Near surface bleed off slowly. 10 min no-flow at surface is good. Lift injector up, check cable about 4" hanging out. Remove nozzle, install side jet nozzle for jetting stack. Reverse slack into reel. Rig up hydraulic CT cutter, cut 220'. Install CT connector. Pull test to 50k, good. Install stinger, get on well. Pump reel volume forward 3.3 bpm cable is moving. PT riser break, good. Install BHI cable head with floats. Test CT connector and floats, good. M/U BHA #19 window mill and reamer. Mill is 2.74" Go 2.73" NoGo. Reamer is 2.73 Go 2.72" NoGo. RIH BHA #19. 5/19/2023 Continue RIH with window milling BHA. Log tie in, correct depth 0', RIH, WTCK at 8750' = 43k. Tag pinch point on depth at 8790',. Online with pumps to start milling window pumping pills every 1'. Tag pinch point at 8789.6'. In Rate = 1.80 bpm, Out Rate = 1.79 bpm. In Mud WT = 8.44 ppg, Out Mud WT = 8.44 ppg. Circ pressure = 2958 psi. ECD = 9.31 ppg. IAP = 491, OAP = 66. Milling Window at 8791.0'. In Rate = 1.85 bpm, Out Rate = 1.85 bpm. In Mud WT = 8.44 ppg, Out Mud WT = 8.44 ppg. Circ pressure = 3508 psi. ECD = 9.37 ppg. IAP = 533, OAP = 78. Stall at 8792.6', PU to up WT and work back down to continue milling. Looks like we exited the bottom at 8792.6' for a 3' window. Continue milling at 1 fph to dress the bottom of the window off with the string mill. Swap over to drilling mud while milling 10' of Rat Hole. Milled 10' of Rat Hole to 8803. Start back ream passes. 8795' sample has 35% C-Sand Formation. 8800' Sample is 100% C- Sand Formation. Back ream passes completed, PU 10' and dry drift window. Dry drift is clean, open EDC and POOH for the build BHA. At surface 10 min no-flow is good. Skid injector back, L/D BHA #19. Mill is 2.74" Go / 2.73" NoGo same as when it went in. Reamer is 2.73" Go / 2/72" NoGo. M/U nozzle, jet stack. M/U BHA #20 - Build BHA. RIH BHA #20. Tie-in depth from 8180', no correction. Up wt 39k at 8680'. Close EDC. Ease through window go to min rate. Tag rathole 8799' pick up 2' go to drill rate. In Rate = 1.86 bpm, Out Rate = 1.84 bpm. In Mud WT = 8.72 ppg, Out Mud WT = 8.74 ppg. Circ pressure = 3350 psi. ECD = 10.22 start adding WHP. Drill from 8850'. In Rate = 1.84 bpm, Out Rate = 1.78 bpm. In Mud WT = 8.71 ppg, Out Mud WT = 8.76 ppg. Circ pressure = 3830 psi. ECD = 11.15 ppg w/ 320 psi WHP. 8860' 5 bbls lo/hi vis sweep. Drill to EOB at 8875'. Wiper to window. Jog below window and pull through clean. Open EDC, jet tray. POOH pump 2 bpm keep 11.6# ECD at window. At surface, PUD BHA #20. Deploy BHA #21 - Lateral BHA w/ 1.1 deg AKO. 5/20/2023 Continue RIH with BHA #21 at 2900'. Log tie in with no correction. Close EDC and RIH to continue drilling. PU WT = 41k, RIH WTR = 18k. Back on bottom drilling at 8875'. In Rate = 1.85 bpm, Out Rate = 1.84 bpm. In Mud WT = 8.71 ppg, Out Mud WT = 8.76 ppg. Circ pressure = 4007 psi. ECD = 11.8 at 466 psi WHP. 8940' slow ROP in shale. Drilling ahead at 8965'. In Rate = 1.84 bpm, Out Rate = 1.84 bpm. In Mud WT = 8.72 ppg, Out Mud WT = 8.77 ppg. Circ pressure = 4154 psi. ECD = 11.8 at 474 psi WHP. 9025' well taking a little fluid. 9030' increase in losses 0.3 bpm ~18 bph. 9040' increase in losses 0.4 bpm ~24 bph. 9043' increase in losses 0.5 bpm ~30 bph. Continue holding 11.7 - 11.8 ECD. Still drilling in shale, Geo's think we drilled from the B6 into the B8 and missed the C-Sand, verifying bottom of B7 and what we will need to land. RIH to continue drilling, B7 top should be at ~6975' TVD and the base at 7002', we will need ~13' to land once we see the top of the B7 landing at ~6988'. Starting to pack off, PU and pull wiper trip to the window. BOW, jog in hole then PU to 8835' placing the EDC at 8780', stop and open the EDC. Jet across WS tray and then pull through the window into the TT circulating a bottoms up. Circ 2x B/U until returns clean. Tie-in to HRZ at 8190'. Add 0.5% Hydra-hib to mud. Close EDC, RIH to window. Field wide power outage, rig loses power. Depth is 8793.3' right in window. Shut in well. Get gens running, pick up cleanly out of window. Get pumps running bring ECD back up to 11.8#. ECD fell to 10.2# while power was off. Reboot BHI computers, depth is running backwards. Get all systems working, pick up to tie-in depth. Tie-in from 8190' correct +1'. Close EDC, pass window go to min rate. Tag 8803' pick up and work past at 0.8 bpm. Continue work in hole, build section ratty. At 8900' pull wiper back to window, pull 10k over at 8895' RIH and stack wt. Work pipe and pump to get free, continue wiper to 8820'. Clean back to 8925' at 0.6 bpm. Work down to TD take 50' bites. Wiper from 9050' at 1.4 bpm packing off reduce rate. Unable to circulate at full rate. Pull wiper to window, open EDC. Unable to jet tray stacking wt 8804'. Pump B/U to clean tubing. Considerable cuttings coming back confirmed B8 shale. Tubing clean, close EDC RIH. Clean through window go to 0.5 bpm try to pass B8 shale 8830' - 8880'. Stack wt in shale work past. At 8920' in clean sand pull short wiper go to 1.8 bpm, packing off right away. Unable to circulate at drilling rate when past B8 shale. Pull wiper trip back to 8820' will take 20' bites to clean out. Pick up from 8870' motor stall pulling heavy at 8841'. Pull through window CBU pump 5 bbls lo/hi vis sweeps. RIH close EDC to continue cleaning B8 shale. Unable to pass window try different orientations 20L to 40R and different running speeds. POOH for window cleanout BHA. Undeploy BHA #20. Deply BHA #21 - Window Cleanout. 5/21/2023 PD clean out BHA and RIH. Log tie in with no correction. RIH to TOWS and close the EDC. PU WT = 40k. RIH and dry tag at 8797', PU to up WT and start pump. Work down cleaning out build section at 5 fpm or 300 fph. Ann PSI = 4193 psi at 11.75 ECD. In rate = 1.85 bpm. Took a little WOB at 8820' then milled off. Taking WT at 8843'. Stacking WT at 8843 and losing more returns, PUH 20' then RIH. Stacking WT at 8841' and losing returns again. PU and pump a set of pills to circulate a bottoms up to see what we are milling. PU to the TT to clean out the hole behind us while pumping BTM's up. RIH with mills below the TT in the 7". Bottoms up had fine cuttings of B8 shale. Shut down and RIH to tag and continue clean out. Tag at 8808' PU and start working down again. In Rate = 1.81 bpm, Out Rate = 1.69 bpm. Set down at 8848' losing returns, PU clean and getting returns back. RIH to dry tag and ran past to 8935' clean. We are able to drift through the shale but if we try to pump going down to clean it out it packs off at the mill, stacks WT and lose returns. PUH and work down at slower speed and stacked out at 8831'. PUH above shale shut down pump and see how far we can drift. Getting a little ratty at 9058', PUH to just below the bottom of the shale and try to back ream through. Online with pumps, verify good returns before back reaming and started packing off. Shut down pumps and PU pulling 10-15k over then pulled free and getting returns back. Online with pumps PU to the 7" to circ a bottoms up while talking to DE. RIH to continue clean out, tag at 8838' and stop to allow it to drill off, nothing happening like the mill is balled up just pushing fluid away. Not making any headway with this mill & string mill, it's like the shale has swelled and we are milling a 2.74" gauge hole through the shale. POOH for D331comimng from Kuparuk. Well unloaded some B8 shale 2000' from surface. OOH prep to PUD the FCO BHA. MU & PD the FCO BHA w/D331 Mill on 1 BHI Extreme Motor. RIH BHA #23. Tie-in depth from 8180' no correction. Close EDC. Try RIH through window 1 bpm. Stall several times at 8794' at different rates and RIH speeds. D331 is slightly larger than the NSAK mill, will need to ream out window. P/U to 8788' ream down < 1 ft/min 1.8/1.56 bpm 10R. Ream window from 8793.3' stall 8793.55'. Mill to 8795' PU for backream 10R clean. RIH continue cleanout. Stack 8810', 8817'. Near bit inc not increasing, appear to be inside 7" casing. Stall at 8830'. Pick up to 8760' reboot BHI tool. Log RA, still there. Survey package at 8802' indicates we are in 7". B/U sample from washing down 8805' - 8830' is 90% soft cement. Discuss w/ ODE. Tie-in depth correct +3. RIH will try different TF to find the window. Try 20R RIH tag 8830' NBI indicates in 7". Try 60R, 90R, 120R, 150R, 180R, 150L RIH clean to 8830' each time in the 7". RIH 120L, 90L, 60L, 30L tag 8796' and stall. RIH 0L clean to 8830' NBI indicates we are in the 7". POOH keep 11.8# ECD at window. Pressure undeploy BHA #23. Prep for next BHA run. 5/22/2023 BHA OOH, discuss options with DE and wait for asset team decision to either make a camera run or RDMO to next well. Decision made to RDMO to MPL-13, LD BHA and prep to make a nozzle run. RIH with nozzle BHA and BHI Floats to recover drilling mud, displace the well to source water with a diesel FP. Slowly bleed WHP to 0 psi while RIH. Call out Halliburton N2 to blow down reel. RIH clean to 8805', PUH to 8760' clean, RIH to 8805'. Online with source water, pump at max rate reciprocating from 8805 to the TT with mud in the coil to clean out the 7". Source water at the nozzle, recip from 8805' to the TT 50 bbls to wash any mud off the 7" for possible Eline Camera run then POOH. Freeze protect tubing from 2675'. LRS RU & PT'd, online with 30 bbls of diesel. 30 bbls pumped into coil, RD LRS and MIRU HES N2 Unit. Diesel at surface, POOH at pipe displacement. OOH, waiting on vac trucks to remove fluid from the pits so we can pump fresh water and inhibited water to blow down. Good PT, well is secured. Prep to pump Freshwater, Inhibited water and methanol into the coil to blow down. Pump 30 bbls fresh water, 30 bbls inhibitor, 5 bbls MeOH into reel. Purge reel w/ 1500 scfm 15 min until gas at nozzle. Bleed off to tiger tank. Grease rig valves while bleeding off. Skid injector back, remove nozzle and BHI cable head. Install grapple. Remove inner reel 1502 line. 5/23/2023 Pull CT out of injector and back to shipping spool, secure it there. Hook up reel slings, boot e-line on both ends. Finish vac all fluid out of pits. Start converting injector to 2-3/8" CT. Move 2-3/8" gripper blocks to rig floor, change out blocks on injector. Remove stripper assembly change out stripper brass. Continue converting to 2-3/8" CT size. Swap BOP rams to 2-3/8" configuration and shell test BOPs, good. Swap out gooseneck w/ crane. Remove MPD line and BOPs. Install tree cap and test, good. Finish RDMO checklists. RDMO 18:30 from MP B-15A. 6/21/2023 Spot drill module over MPB-15A. Spot pit module. Accept rig 07:00. Complete MIRU checklists. Nipple up MPD line / BOPE's. Test Gas alarms. Fluid pack rig, Calibrate MM's. Initial BOPE test Witnessed waived by Kam St. John. 7-1/16" 5K Annular, Blind / Shear, 2-3/8" Pipe / Slip, Mud X, 3" Pipe / Slip, 2-3/8" Pipe / Slip. Test 1: IRV, Stripper, C7, C9, C10, C11 Pass. Test 2: Blind / Shear, R2, BL2, C15 Pass. Test 3: Annular (2-3/8"), TIW1, B1, B4 F/P on B1. Test 4: Upper 2-3/8" Pipe/Slips. TIW2, B2, B3 Pass. Test 5: Lower 2-3/8" Pipe/Slips, C5, C6, C8, TV2 Pass. Test 6: Choke A, Choke C Pass. Test 7: C1, C4, TV1 Pass. Test 8: 3" Pipe/Slip, C2, C3 Pass. Drawdown test - Good. Rig down and purge test equipment. Test both MP line break and PDLs 250 / 3500 psi, good. Cart forward and install floats in UQC. Test floats and UQC break to 250 / 3500 psi, good. Load PDL w/ BHA #25. Mill and reamer are 3.80" Go 3.79" NoGo. PT tiger tank line 4250 psi, good. M/U nozzle get on well, pump 8 bbls MeOH forward. Open well, 90 psi then dissipates. M/U BHA #25 - Window mill. 6/22/2023 RIH with window milling BHA #25. Rate: 0.54 bpm in, 1.04 bpm out. Circ pressure: 80 psi. Mud Weight: 8.36 ppg in, 7.08 ppg out. Taking returns to tiger tank. Log down for tie-in from 8185' to 8261.38' MD (formation) with -2' correction. Perform CCL log 8300' to 8700'. Swap well over to Powerpro with Black product. Dry tag whipstock at 8769' MD. Depth discrepancy. Pinch point should be at 8764'. Log 7" casing RA. No sign of it. Verify collars. Collars on depth with original whipstock setting log. Bring pumps online. Went right by 8769'. Run to 8774' without tag. PU and dry tag. Tag at 8770' Top of whipstock. Come back online and start taking weight at 8775.4' (Pinch Point). Whipstock had fallen downhole. Pick up to log primary tie in. +3' correction. Rih and tag at 8778' MD (Pinch point). Puts TOWS at 8773' MD, BOWS at 8791' MD. Inside third window. Open EDC. Pooh for 40 arm extended reach caliper. Pooh with BHA #25. Rate: 2.10 bpm in, 1.72 bpm out. Circ pressure: 1715 psi. Mud Weight: 9.08 ppg in, 9.07 ppg out. Tag up Perform flow check. Static. Stand back BHA#25, Remove motor and mills. Program READ 40 Arm Caliper. Make up READ tools. Surface tested good. Stab injector. RIH with Caliper BHA #26. Rate: 0.54 bpm in, 1.04 bpm out. Circ pressure: 80 psi. Mud Weight: 9.08 ppg in, 9.06 ppg out. . Log down for tie-in from 8185' to 8248' MD (formation) with -2' correction. Up wt 8670' is 46k. Park at 8770' wait for arms to open (18:39). Well on slight losses. Log up at 50 ft/min. Park at 8325' 1 min before closure time, let arms retract. POOH. Flow check at surface is good. Skid inj back, pull BHA #26 - Mem Caliper. Download and confirm good data. M/U BHA #27 - Whipstock. RIH w/ BHA #27 - Whipstock. Set slackoff and pump trips close. Tie-in depth -2.5' correction. While RIH caliper data is finished, review w/ BTT and rig Geo. Decision is made to set anchors 8760', as deep as caliper data goes. Puts pinch point at 8747'. Confirm w/ Geo still in zone at 8747'. RIH to 8760' 160L get up wt back. Close EDC, shear out setting tool at 3890 psi. RIH carefully to confirm set. Take wt at 8764.1' set 5.5k on it for 1 min, solid. Flag pipe 8738.76' bit depth, (8653.81' EOP). Injectivity test, 0 injectivity with mud at 11.83# ECD (940 psi WHP). POOH. Good 10 min no-flow at surface. L/D BHA #27 - Whipstock setting. Tools have functioned normally. Remove floats from UQC. M/U nozzle BHA. 6/23/2023 Rih with BHA# 28 Cementing nozzle. Stop at flag 8670.07' - 8664.36' = -5.71' correction. Dry tag whipstock @ 8747' w/ 3K down. On depth. Circulate wellbore over to 1% SL KCL. Reciprocate from 8744' to tubing tail. Injectivity test (Close Choke). Incrementally increase surface pressure to 1520 psi ( 12.57 ppg EMW) Broke over. Injectivity of 0.4 bpm @ 1412 psi. Push 3 bbls of 1% SL KCL past whipstock. Come off line pressure dropped to 1160 psi then slowly continued to fall off. . Dry tag whipstock on depth. PJSM with HES cementers. PT to 5000 psi Good. Cement Wet:10:59. 70 bc @ 17:22. Cement. Pump 5 bbls freshwater. Pump 7 bbl 15.3 ppg cement. Pump 5 bbls freshwater. Parked at 8744' MD. Cement at nozzle. Close choke. Pressure slowly climbed to 410 psi. Pressure bumped at 1.3 bbls out. Work pressure up to 1600 psi. Held. Squeeze 1.3 bbls cement by whipstock. Crack choke. Circulate 1 bbl of cement around nozzle. Begin laying cement in 1:1. Fresh water at nozzle at 8610' MD. PUH to Safety. Circulate 1.5 ppb Geovis down to nozzle. Cement in place 12:00. RIH and contaminate 1.5:1 from 8610' to 8742' (2' below TOWS). Make pass up and down from TTL to TOWS. Circulate contaminated cement ooh. Pooh for window milling BHA. Rate: 2.93 bpm in, 2.48 bpm out. Circ pressure: 1440 psi. Mud Weight: 8.41 ppg in, 8.34 ppg out. Tag up. Perform 10 min flow check. Well Static. Remove nozzle and stinger. Pull UQC apart. No signs of any cement in voids. Install floats. Test e-line. Good test. Make up swizzle stick. Stab injector. Jet stack. Tested floats to 3500 psi. Good test. Jet Stack. Wait on cement. Clean and service rig. M/U BHA #29 - Window mill. Mill and reamer 3.80" Go 3.79" NoGo. RIH BHA #29. Tie-in depth from 8175' correct -2'. Close EDC 8619'. Up wt 8640' is 46k. RIH min rate tag 8748.8' PU bring pumps up to 2.5 bpm. Ease down see first motor work 8748.1'. Start time milling 8749.5' start increasing ECD. Swap to mud. Mill to 8751.03' mud all the way around PU get new parameters. Mill window from 8751.03'. 2.52 / 2.54 bpm In/Out. 9.05 / 9.04 ppg. Window ECD = 11.83 ppg w/ 630 psi WHP. Pcirc 3100 - 3390 psi. 6/24/2023 Mill 3.80 window to 8755.4'. Rate: 2.54 bpm in, 2.56 bpm out. Mud Weight: 9.03 ppg in, 9.02 ppg out. DWOB: 3.5 klbs. Circ pressure: 3567psi. Maintaining 11.8 ppg ECD at window. 571 psi WH. Mill exiting. WOB fell off to nothing. Appears we exited 2.2' early. Continue to time mill to expected full exit of 8757.8'. WOB and motor work minimal. Mill rathole from 8758' to 8768'. Rate: 2.53 bpm in, 2.56 bpm out. Mud Weight: 9.02 ppg in, 9.03 ppg out. DWOB: 2.8 - 3.0 klbs. Circ pressure: 3341 psi. Maintaining 11.8 ppg ECD at window. 568 psi WH ROP 5.5 fph. Perform reaming passes. Motor work at 8752' during 1st 2 passes. 3rd pass down minimal motor work. 3rd pass up clean. Dry drift. Good. Pooh. Rate: 2.96 bpm in, 2.34 bpm out. Mud Weight: 9.02 ppg in, 9.00 ppg out. Window ECD: 11.8 ppg. Tag up, space out. Undeploy BHA #29 keep 11.8# ECD at window. Mill and reamer 3.80" Go 3.79" NoGo. M/U nozzle, jet stack. Open choke clear metal debris from blowdown. Deploy BHA #30 - Build BHA. RIH BHA #30. Tie-in depth from 8185' correct -2'. RIH close EDC above window. Sliding sleeve opens when running past, took 0.15k DWOB. Pass windows no issues. Go to min rate, light tag 8767' get up wt + 2' go to 2.8 bpm. Drill from 8768'. 2.80 / 2.80 bpm In/Out 9.03 / 9.05 ppg. Pcirc 3500 - 3750 psi. Window ECD 11.76 ppg w/ 540 psi WHP. 8782' 5 bbls lo/hi vis. Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/02/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230416 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPB-15 50029213740000 185121 5/16/2021 READ Caliper Survey MPC-02 50029208660000 182194 4/26/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/17/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/21/2023 READ Caliper Survey MPL-40 50029228550000 198010 4/18/2023 READ Caliper Survey PBU D-03A 50029200570100 200134 5/28/2023 READ MRCBL PBU L-212 50029232520000 205030 4/14/2023 READ Injection Profile PBU S-210 50029236300000 219057 4/17/2023 READ Injection Profile PBU V-212 50029232790000 205150 5/13/2023 READ Injection Profile Please include current contact information if different from above. T37721 T37722 T37723 T37723 T37724 T37725 T37726 T37727 T37728 MPB-15 50029213740000 185121 5/16/2021 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.12 14:32:41 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT B-15 JBR 07/25/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Annular failed and was replaced. Good test otherwise Test Results TEST DATA Rig Rep:N. Wheeler/ W. WilliamOperator:Hilcorp Alaska, LLC Operator Rep:J. Perl/ R. Burnett Rig Owner/Rig No.:Nabors CDR2AC PTD#:1851210 DATE:5/9/2023 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopAGE230521131221 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 10 MASP: 1600 Sundry No: 323-148 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2"P Annular Preventer 1 7 1/16 FP #1 Rams 1 Blind/shear P #2 Rams 1 2" PS P #3 Rams 1 2 3/8" PS P #4 Rams 1 2" PS P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16 P HCR Valves 2 2 1/16 P Kill Line Valves 1 2 1/16 P Check Valve 0 NA BOP Misc 1 2" piper P System Pressure P2975 Pressure After Closure P2250 200 PSI Attained P15 Full Pressure Attained P49 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P10 @ 1950 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 1 P Annular Preventer P6 #1 Rams P4 #2 Rams P2 #3 Rams P2 #4 Rams P2 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9 9999 9 9 9 FP Annular failed Z>ſǿcƃǿ>>Zý>ǿ >>Zý>ǿcǿ>xǿú>ăǿ¼cxZƀĂƫ>cxǿ ¼cwwZZcxǿ $DǿŲŶǿ$ŗ$(Dǿ IĽǿyǷ ǿÈǿ§mġŨ L46ǿ 8 ǿ Aǿ Ƅ "ǿ3Q+m ǿ ơA { ǿ d 01&ǿ&Gǯ6nǿ 3 ǿY Ď ǿ .Gǿ3+8 ǿ Y ǿą4 õ* ǿL 26ǿ ¤ǿ 8 ǿ\ǿ6 ǿ Èǿ ×ǿ ǿ Mĺ1 ǿ3& ǿ[ ǿ ľǿd 0Ǟǿ h·ǿ ƌēėN-ǟ¦ǿtė@jÏ@ķǿ ƓƔ Ŀ ?""ǿ{ ǿ · ¾Ƕ!Ð ĥǿ ` 0ǿ ǿ .P=ǿ ÖÐ!H01Řŀǿ HǿǿQ ǿ H4sǿ JíśJ^J çŁǿL 60&š G5ǿ250 êÜǿ` ¿ǿ ¥4Ţǿ ´: :^Š ^J²ëǿő :: qq ²í::ǿ,ÕÓ-LJ,ÕǿżÓÚǿƤēÕǿJŒ::Úǿt,N¡-Ó@ ĸǿtƒ ¶Ý )Ďǿ!ƿ X îÞǿ[ ǿ Hǿ ǿ H4s {G©ǿM m ©ǿǿŷ2ġĔǿƙ ƹǿ 2 ǿģ ǿ ǿĔǿ©*ǿ! 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Mǿ zûŰ.Ɗ??ǿ 0ŧǿ ?++Ýǿ ÀǿƵ+¥Tǿú¼ƯǿDEp$$p$Eǿ ĘǪ ǿ ǿǜþƋāæŊþűāæŎÀǿ Ǒǫ ǿ/ǿaǿ ăƈǿEp$$p$D$Eǿ Àǿǿǿǝǿ ZĂĻEpWß$Eǿ ù~ĠÒǿãŇŖ®ŏǿƣODzNJkOƼǿã®ņ±®±±ǿ " $ $ $" $ $$ $ $ $ $$ " $ƦǰČǖÎǿƠ½ùǿ~ǿ~ÉƶƷńǛOĠÒÎǬÎĝÉŮǒkǏŅÉ~dzǿ RBDMS JSB 032323 Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: kyle.wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Hilcorp North Slope, LLC Date: 02/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU B-15 -PTD 185-121 -API 50-029-21374-00-00 Definitive Directional Survey (Gyro + MWD Composited) Gyrodata Survey 02/21/2023 Multi-shot Gyro Survey 06/25/1985 Main Folder Contents: Please include current contact information if different from above. . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0·7:) DATE: July 12, 2000 Commissioner I tf /Io/ö(.?/ THRU: Blair Wondzell, Q1~ P. I. Supervisor ·ef1(dJ FROM: ~I:!¡ Jeff Jones ,--" SUBJECT: Safety Valve Tests Petroleum 'I sp c I r Milne Point Unit B & C Pads Julv 9. 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.50/0 failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '3 NP... r-z..+:Z-":?i- 21 well houses were inspected, no failures. r Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON..CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc . . Alaska Oil and Gas Conservation Comlnission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones B-02 N B-03 w B-04A N B-06 B-07 B-09 B-I0 B-13 B-15 B-16 B-19 B-20 B-21 B-22 B-23 Wells: 9../7/00 1811420 1820560 1821000 1850130 1850620 1850340 1850170 1850930 1851210 1851490 1852300 1860050 1860230 1853020 1890160 140 140 140 140 140 140 140 140 140 9 Components: 100 100 100 100 100 100 100 100 100 Submitted By: Date: 7/9/00 FieldlUnit/Pad: Kuparuk River/MPU/B-Pad Separator psi: LPS 140 HI'S NI A 115 95 90 95 95 100 I' P p 95 90 P P ~"'''i :.Well ijai¡i,?~' "(":- ·;,,~i.!·:,'~:,«).';' ':~~:' .::.~' 'Pilots>'; .:I'~;·"::'~/'í::r:, :'~',;' ':,~S \-y,;': . SS",~ Well Permit Separ Set LIP Test Test Test Nun1ber Number PSI PSI Trip Code Code Code 95 p ~ - " ':. "_' ¿ . '. .' I . . -.,.", I ." ~ , ~v ell:':1);jiC·'··" p p p 18 Failures: Oil, WAG, GINJ, GAS or CYCLE P P P OIL OIL OIL p P OIL OIL p OIL p P 4 OIL OIL OIL Failure Rate: 5.5% 090 Day Three well SV's recorded slow closing tÏ1l1es; B-04A(3:20), 8-03(3:03),8-06(3 :30). Some of the wells on this pad do not have well signs on them. Larry Niles, the BP representative, said he would have these items corrected. Remarks: Page 1 of 1 Vvo43m 1 t.xls STATE OF ALASKA h 'éSKAOILANDGASCONSERVATION COM~ ""SION REPO~ _ _ OF SUNDRY WELL O¡:.....~t4TIONS 1. Operations performed: Operation shutdown _ Stimulate _ Plugging _ Pull tubing r Alter casing _ Repair well _ Penorate _ 2. Name of Op'erator CONOCO INC. 5. Type of Well: Development ..x.. Exploratory _ Stratigraphic _ Service ~ Other _ 6. Datum elevation (OF or KB) KB 59 feet 3. Address 7. Unit or Property name 4. Location of 'Nell at surface 300' FSL, 1037' FWL, See. 18, T13N, RIlE, Umiat At top of productive interval NA At effective depth NA At total depth 4865' FNL, 3950' FEL, See 19, T13N, RIlE, Umiat Meridian 12. Present well condition summary Total depth: measured 9136' feet Plugs (measured) true verticalNA feet Effec~ve depth: measured 9052' feet Junk (measured) true vertical NA feet 8. Well number B-15 9. Permit number/approval number 10. API number 50- 029-21374 11. Field/Pool Kuparuk River Field NA 8920' Vann Gun spent perf assby Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 13 3/8 Cemented Measured depth 78' True vertical depth 9 5/8 5625' 7" measured 8786' -8825'; 8825; -8888' 9136' ',_0:/ ¡"J d -.,; , "0 C, 4-~ t !~:~ r~~ ¡:". L! : ..,; :.. ) \.,' (¡ ~(J(ì f_ì ,tJl.1 >' truevertical6916' -6945'; 6966' -6993' '::ìi i~: i~;:¡:j Cun_lo,_',_ oJ UJi!Hflissiau Anchoraç;3 Tubing (size, grade, and measured depth) 3 1/2; 9.2#; L-80 BTRS; 8758' PackersandSSSV(typeandmeasureddepth) BOT "HB" hydrle pkr, 8707'; Cameo NRDP-1A55A SCSSV 742' 13. Stimulation or cement squeeze summary NA Intervals treated (measured) NA Treatment description including volumes used and final pressure NA 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation o 2130 o 754 28 364 1320 1126 180 198 Subsequent to operation 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations *" Oil -X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si neQ . Title S (' . o~ ¡Dr\.! Form 10-404 R v 06/15/88 16. Status of well classification as: Service .--. fOremaN j...; ~...¡ :...( ~"'J C) F: I< CJ \,/ ¡~: F·: U F' E: F? (':'¡·I :¡: (J 1) U :.i.. ~ 1":1 J r.:;.~ tJ ç'J ¡:::' -r [~:~ F;.~ I (4 ~::; j" r=:~f L. L.. I j.....! C3 t.) F:~· r:: t.... LJ (~~ I (.f j''': J. i ::::; T f) r::" (>! ¡....~ ¡.....~ L.! Loo!""! :::::; (";.! ¡.... ¡ :c> r·"{ r::: :',,) T ,....¡ "rF~~t~t~ ~ ....... - F~ E:~ ¡vi (] =\/ E: E{ ('~.! c:: ~< r:= F;.: j:~ ~:; F3 LJ f;~ i:: t..) (:'¡ L.. \/ r:~:: I::;.: I C:Î LJ r:: r:: LJ (-'} r:: ,:.:'¡ j....~ J) C': I ;::;.~ c:: 1.. .i t.. (\ "I" L:: .".t. J:) :: () F:: F~: c-~i F3 F~: I i\ì E:~ '1- t-1 F~~ {] i..J C~¡ ~.! fJ f~~ I F~ Ie:: E:: (~ n( '~~:I f3 ':.?:t: (1 :() "f' CJ 1< J L... L.. í/.J 1:::: L.. L..:: ¡:.:: t.J (.:¡ F·:= ),) CJ ~:..J r·o.! {:! ¡-..~ i\i i,J L_ ¡.J :::3 (:i t) I) r~? E~ "T' tJ F;.~ t··) "( i-"~ f~~ CJ tJ f31'''~ "T' LJ EJ T !"'~ c·::; :: ',,,: 11 I:,; t~. E~ E:: :C) C) ~~:. F~ 'T' tJ I:'; I r) C',} (::) ~~'.~ [) (:'1 (-.! ì\~ I....Î L~.I....i ~~: p¡ r·~ J) ,".'. :"" ..;.. ..-u. .-. .'.... I .. ::::) t::.! J::5 (-i 1..... ¡':'. F' ¡:::': F: :::::: :::3 I..! F: F: :.-./ {::j L. ......... J:::. ~ r~~ t::~ ~"'i CJ:"'/ L:: "T' ¡::;.~ E.~~ E: (::i r"'~ [) i\J I F> F> L~ r~ LJ F> f:; C] F:I .. ~~~; :! iL .. F> f~~ ì:: :::3 ::3 tJ F~~ i~ 'f' E~ ::~; 'T' I) CJ r:; .. ::::; j tJ "~: () () () i-" :~) .L LJ J .'.~ !"'/ (:i L.. ="./ E~ :~::; a .i::.i L. .f. f··.j J.) ::j q r:1 J F:: F~ (::-, )'--..) f> 1.5(=)(::> F::r~~;:[ (~)N ~·IYDF~]:L..n ~,7i ~ ~...: 1. L.: f<. tJ F:: -( LJ 13 I i\~ f:':i (J LJ 'T' fj r::- t"·! {:! t···~ C:-} E: F:.: (:'f r··.! f> ~;:::; '1" I i····~ C3 fJ L.i .'f' LJ f" :::~:; i:::. (:·Il~. (:·f ~::) ~3 L:: t-:.¡ :c.:.; L.. '.-{ H (:.: ~ ! ¡·'1.: .L I···· (J L.l'To 1:1 F=' ~'i (J i.... t::: ~ r;.~ t::: "0-> :C) r~.~ f::: ~::) ~::~; :~3 f; ::3 :'../ (:i 1....·1 X) f~~ J 1"'1 (':'¡ '," / ii ' ,I . ./ 0; ¡::~~ ~::~ F;~ LJ il'..j 'T' L.~ I,:,; I r-..~ C:):t j"1"\! I) F~ fJ -( t::: ~3 'To I r··~ E·:¡ C~: f) i....~~ i"~~ E:: C; 1" I CJ r-,j ::3 (':'¡ '····.1 I) T' LJ F:·: I }\·i C·) CJ ¡····-i "j"" I ..I [:: !".'..J (~"f ....( D PI c.: 1< I ¡---·,I THE H [) L. F (~ 'f 8 n U 0 e f.:; I" b T I ¡---·.I C':¡ Ei P; C i< I (,.If UT' ¡..¡ E F' r:{ F:: (.\, "',·1 r:i LH ~,~.~ f\~ f> T· LJ r:·:; I ¡--~~ C') ~'~i (':) (J E·:¡ t:. F~·: ~ .,,, .. :3 F T )3 F' ¡,) (:.{ j\¡ 0 f,;,l r"J !..) i::" I!;" i-' . . .... ~ ~,- ... . t., CJ r:: (::! "r I (J ('.1 r: --~-- ~-~-~--~--- -----"'---_.-~~---._---=-~----- ---~--- - -- - ----- ------ - - - - ---- - STATE OF ALASKA 0 R f t.1 AI .~ ALASKA OIL AND GAS CONSERVATION COMMISSION U nt ,.'1.~ APPLICATION FOR SUNDRY APPROVALS 'Yt"#1 1. Type of Request: Abandon _ Suspend _ Operation.shutdown _ . Re-enter suspended well_ Alter casing _ Repair well .x... PlugglDQ _ Time extension _ Stimulate - Change approved program _ Pull tubing -A Variance _ . Perforate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (OF or KB) CONOCO INC. Development - KB 59' Exploratory _ Stratigraphic _ Service -t. feet 3. Address 7. Unit or Property name 3201 CST. STE 200 4. Location of well at surface 300' FSL, 1037' FWL, At top of productive interval NA ANCHOR At effective depth NA At total depth 4865' FNL, 3950' FEL, See .." .l::J, TI3N, RIlE, UM 8. Well number B-15 9. Permit number 85-121 10. API number 50- 11. Field/Pool Kuparuk River Field See 18, T13N, RIlE, UM 12. Present well condition summary Total depth: measured true vertical measured true vertical 9136 NA 9052 feet feet Plugs (measured) NA Effective depth: feet feet Junk (measured) 8920' Vann Gun Spent Perf Assby Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 13 3/8 Cemented Measured depth 78' True vertical depth 9 5/8 5625' 711 9136' rr~'vrD RE-r.:~ r measured 8786' -8825'; 8825' -8888' true vertical 6916' -6945'; 6966' -6993' SEP 2 61989 Alaska Oil & Gas Cons. Commission J\nchorage Tubing (size, grade, and measured depth) 3 1/2; 9.2#; L-80 Btrs; 8758' Packers and SSSV (type and measured depth) BOTIIHBIIHydraul ie Paeker,8707' ; Cameo NRDP-IA55A SCSSV 1856' 13. Attachments Description summary of proposal ..x.. Detailed operations program _ BOP sketch _ 14. Estimated date for commencing operation Se tember 19 198 16. If proposal was verbally approved NA 15. Status of well classification as: OilL Gas_ Suspended _ Date approved Service : e foregoing is true and correct to the best of my knowledge. Signed Title Sen i or Prod. I Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance _I Mechanical Integrity Test _ Subsequent form required 10- ßó4 Date j-- /)' ~ . ) Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Approved Copy Returned (:( , c.) '6- )'~ì Date C: ',-- () , _ y{' SUBMIT IN TRIPLICATE ~ B-15 WORKOVER 1. MIRU AFTER INSTALLING VR PLUG IN PIT SIDE ANNULUS AND BPV IN TREE. 2. REMOVE BPV. RIG UP PUMP AND CIRCULATE 10.0 BRINE THROUGH ORIFICE AT 6871' MD TO KILL WELL. PUMP DOWN ANNULUS AND RETURN THROUGH TUBING. 3. BLEED OFF TUBING AND ANNULUS AND SET BPV. REMOVE TREE AND NIPPLE UP BOP'S 4. PRESS. TEST BOP'S TO 3,000 PSI ON VALVES, BLINDS, PIPE AND 1500 PSI ON HYDRIL. 5. PICK UP TUBING OUT OF HANGAR AND STING OUT OF SEAL ASSEMBLY. 6. TRIP OUT OF HOLE. 7. RERUN TUBING, HYDROTESTING CONNECTIONS ON THE WAY BACK IN TO 5000 PSI. STING BACK INTO PBR AND LAND HANGAR. 8. SET BPV AND MOVE OFF LOCATION. R F (' t: ~ \/ E D ¡ '\. ~..., ",.,.< ;>r' í ,~ 1'" rr"" 2 I~ 1ono .;;JCi _ U .t~:íu.::J Alaska on 2.. (3as Cons, Commission Anchomç¡ü 68/të:/6Ø ~:ë:t ......... .. . I ftl,""O'. . I , - "" ....... - ....- Ø6£9-6S9-¿06 ~lJ SdO ndW OJONOJ ë:00 iht'fD'teqa .flf, . Aocce . · 0,.,.,., . · ,.,p.,vf.., efO~ (rev 0'/1"") ... .. .. 1..,.,._.. ~..k on di,,~hårf¡e of l'¿.tMP 1.'It nniho1 t t'epair~p, ~Q tha "no~ ~ Fuunù small ll)~k ~ oross over under dart valvQ. Also r.pa~red o~ ~pot.~ '11f I~TII ,.H~.. 0 "It ,eN 3T ",. .'P'f~ o. r,,'.4..,nt .f ,.f"d ..u'...nt to ~ ~d' ~r'htft ~ ØIYI 6A4 ¡ftl,eot.,/COIIt.lion Df'iot ftð'tf'''. I ~/A ~~ 17.4 IO/5/~/7 ,I 85-121 -- ^ 7" . e.1fn9 .., , 94 .. R.. ~J;old Pr8t~ ~1 ~~ Ivan; ¡ 'ttl1 Ohlt.. J""'~ 2§9ß ".1. aft., ., oaW¡ 1300 . ~ .-... ''''' eftol' .'01 p/Eþ 200 'It, f 'ut, ,haf" ,r'I~~".fn.' .... Ma . B~ ~ - ~ -.-,- ~ -----~ Con'".''' Mutttw.a.J r OK I....... joK II t ft' .__t tob OO'/ff ~ II.~Y ~ 'LOqI..m YAJ.Va. Upp., ""r ~'.'. ".,Iwfl LIH, -.n, l~" "It "..tu", leU .,.. .. DK "I' Jtt.tvr. IMto '0.' ' ft.' '....IUt'. eMkt ..nttol' ~ . Ta,' ".'hIP', ...., YI1v.. .4 6 _~ ......., 11.,,'I.....~ l..... A'jut..". '~ðk.~ ~ M~_f'ij'f,.t'r op.(~.tf '~ðk' ~ , Data V81v~ - OK'- 3000 p9i ......... .. !!L!.. 3000 JOQP 3000 V' ---.... J.W)JJ .'H .!-all -1.Q 8 -.e.. It -1Q .. '1' I. ... ,If, ,If. .. f, 91Jl t - "..." , II l.pr.'tñUtf'i' ~ ~nry Harringto~_ bIJ' tf ...S~ temb...~r 20 I 1982 . T.., Þr...vpt 1.500 l' æ 3000 -.II 3000 3000 - 3000 - NIÃ, Ch.tc, UM vetv.. ~ v,'v. Mi'1 tift' V"v.. C"',ok v.1YI - - ... - ..\ . - Aftftut.r p,tv.ftt.r '.PI Pilla 1 !::p.t" . "fftf "11ft' ll!U.tAaa - ~ I.V4~£MI1 Vilu.' "" tent X J~ 4. 'f' ,'v,_ Derrick. Man , "ow I!9nft., ~n. ,... C.. ".t.t"~' ~ Noni -I .... Aileft. lao.ttoru S.. l~ t~.3IL I 11 ~ _ M W --... 0". .I~t'o"..... EWS ""~ Rei I. LOttt.ft" C,. \..~.1) .21<", 1'." I~,r. ~ Cane,.' ~.w'.k..p'~' OK It. ~ ~...,.w ,t, OK. _ !:;l? ...3. . .. '''1''.'61' """'- Op.r.tor Concco Inc. 'TAt' or ALASICA AWI<A OrL AND W COHI!~"^TrOH ~ HOH ICPr 'ft"totfon ~.p.rt ~~co) Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 July 17, 1987 Ms. Fran Jones Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Ms. Jones: Enclosed please find the drilling "well histories" from Conoco's Milne Point Unit wells No. C-12, C-16 and B-15. If you require additional information concerning these well histories, please contact Mike Zotzky at 564-7623. Your~~ver~ ~j)~ E. D. Wilson Sr. Administrative Coordinator DRG/vv C-12, C-16, B-15 RECE I VED JUL 2 11987 Alaska Oil & Gas Cons Comm' . Anchorag~ ISSJon ,;. (cona~ '-.s" Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage. AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et a1. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shu't-in of all wells located within the Milne Point Unit. There are 19 active and 5 inactive production wells at Milne Peint. ACTIVE: B-3, B-4A, B-6~ B-9, B-l0, B-ll, 3-13, 3-15, B-16, C-1, C-2, C-3, C-4, C-5A, C-ì, C-9, C-ì3, C-14, C-16 STATIC: B-20, 3-21, B-22 C-17, C-18 All active production wells will be freeze protected by displa2ing the top 3000' of the tubing ",~ith a 1:3 diesel:cil mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced ",~ith a diesel:oil mixture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all produc tion wells. After the surveys are run BPVs will be installed and all SCSSVs and we1lh¿ad valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive 'Y7at er inj ec t ion wells in the Milne Point Unit. R E C E. '\f ~~ C' L.\2S~;~ ..' .~ ::.-~ C~',~ ~>;;I~:~:':':, ~ /~( ~ e . ACTIVE: m-B-8,--B-12, B-14-, B-17 ,B--1-8-C-8,-C-l1, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-IO, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50: 50 water :methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static inj ection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-1; CFP-l Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:wa~er mix will be used to carry the inhibitor. If you r.ave an:' qu.e s t ions on the snu t¿Ow-:l proceãur e p le as e con tac t Don Girdler at 5ó4-ï637. Yours very truly, 410 ..;;/ ~. RI. Painter ~--- ~~, .-~~~~ ---~:;- --------- - -- ---- t ..... vWo.. uc::.uc::.g_... W/w - -------- ~- :- : ! \:' -= ~: . ".. t_ .. ,- - .. ..-. ;C::-~"-C ~ --.'- .......... ...... ... ~. . . . . . . ...... .... , - , .. .... I' ..,........ STATE OF ALASKA ALAS. OIL AND GAS CONSERVATION COMt\ _310N APPLICATION FOR SUNDRY APPROVALS ~ ~- / ,"-, ,-I c / 1. Type of Request: Abandon [J Suspend 0 Operation Shutdown Re-enter suspended well 0 Alter casing 0 Time extension 0 Change approved program 0 Plugging 0 Stimulate 0 Pull tubing 0 Amend order C Perforate LJ Other !Xi 1e':') 2. Name of Operator Conoco Inc. 5. Datum elevation (OF or KB) 59' KB feet 6. Unit or ProRerty name Milne POlnt Unit 3. Address j201 C Street, Ste. 200, Anchorage, Alaska 99503 4. Location of well at surface 300' FSL, 1037' FWL, At top of productive interval 4530 FNL, 1317' FWL, At effective depth Sec. 18, T13N, RI1E, U.M. 7. Well number B-15 8. Permit number 85-120 Sec. 19, T13N, RIIE, U.M. N/A 9. API number 50- 029-21374 10. Pool . Kuparuk River AttZ~~~yPÞ~L, 1292' FWL, Sec. 19, T13N, RIlE, U.M. 11. Present well condition summary Total depth: measured true vertical 9152 7192 feet feet Plugs (measured) Effective depth: measured true vertical N/A feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Le n g t h Size Cemented Measured depth True Vertical depth 80' 5589' 16" 9 5/8" To Surface 808 bb 1s 115' 5625' 115' 4650' 9097' 7" 56 bbls 9131 ' 7176' 8786'-8825'; 8852'-8888' true vertical 6916'-6945'; 6966'-6993' r, ~' I;' "..rid C;~·.;~ ~~--Ji);'-). ,.,' . Tubing (size, grade and measured depth) 3~", L-80, 8758' :j '.n:~~;c~·~~:;r' T R SCSSV @ 1586'; Ret. Pkr. @ 8707' Packers and SSSV (type and measured depth) .. 12.Attachments Description summary of proposal;gJ Detailed operations program C BOP sketch 0 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I her~~rtify t~a~ the foregoing is true and correct to the best of my knowledge Signed ! -LS Title.. Date I ¿ '23 - 8 ~ Conditions of approval Commission Use Only Notify commission so representative may witness Approval No. D Plug integrity 0 BOP Test 0 Location clearance 7 0 CJ Approved by Form 10-403 Rev 12-1-85 Oni&~NAt SIGHED BY LONHIE C. SMITH Ci '-2--~ ';-''::··I/-:':':~-·~ \~/_~-~_' j ,7- L~:¡r~' Commissioner by order of / the commission Date /)' / Su bm it i n/tri pi icate STATE OF ALASKA ALASKA jlL AND GAS CONSERVATION C. ¡1MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG oJ vb 1. Status of Well Classification of Service Well ,- ~ ~. OILXJ GAS 0 SUSPENDED 0 ABANDONED 0 SERVICE 0 "7. >....... 2. Name of Operator 7. Permit Number ./ Conoco Inc. 85-12'1 3. Address 8. API Number Á/ '~//, "'- 3201 C Street, Ste. , 200, Anchorage, Alaska 99503 50-629-21374 4. Location of well at surface 9. Unit or Lease Name 300' FSL, 1037' FWL, Sec. 18, T13N, RIlE, U.H. Hilne Point Unit At Top Producing Interval 10. Well Number 4530' FNL, 1317' FWL, Sec. 19, T13N, RIlE, U.H. B-15 At Total Depth 11. Field and Pool 4769' FNL. 1292' FWL. Sec. 19. T13N. RIlE. U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, OF, etc.) 16. Lea:¡Si~;~;n8and Serial No. 59' KB KUDaruk River 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 6-15-85 6-25-85 6-28-85 N/A feetMSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+1VD) 19. Directional Survey 20, Depth where SSSV set 21. Thickness of Permafrost 9152' (7192') 9052' (9117') YES ex NO 0 1856 feet M 0 1800± 22. Type Electric or Other Logs Run DIL-GR-CNL-CCL-Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASI NG SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3/8" 4811 H-40 0 78' 17k" 100 cf Perm Cm- 9 5/8" 3611 K-55 0 5625' 15" 752 bbls Arctic Set III 56 bbls Class G and 20 bbls Arctic Set I 7" 26# L-80 0 9131' 9!z;" 56 bbls Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3~" 9.2# L-( 0 8758' 8708' 8786'-8825' (6916'-6945') MK-1 8852'-8888' (6966'-6993') MK-2 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5" Hollow Carrier 22 gram 12 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 11-6-85 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WA TER-BB L CHOKE SIZE GAS-OIL RATIO 1-19-86 6 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) Press. 220 1190 24-HOUR RATE .. 2353 805 394 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ¿g Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE ptY ~- 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME IV11:As. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. KA 4503 3887 MA 4867 4137 NA 5168 4242 DA 5366 4476 DB 5450 4533 M. Kuparuk 8786 6916 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Titleà;ØÆ dl1ý..i Date ?-Jrrb 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. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: I ndicate which elevati~m is_LJsed _as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. --- Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas I njection, Shut-in, Other-explain. Item 28: If no cores taken, indicate Jlnone". Form 1 0-407 Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.15- CONFIDENTIAL (7,192'-Kuparuk River) AFE 10-61-1117 API No. 50-029-21374. Ak. Permit No. 85-120. Elevation: 59' KB. Location: 300' FSL, 1037' FWL, Sec. 18, T13N, RIlE, Umiat Meridian 6-15: NU hydril & diverter line, mix spud mud. 6-16: Strap & PU BRA, orient & servie MWD. Function test hydril & pressure to 200 psi. Drill & survey 78' to 1193'. Pump pill. TOOH. Change bit. Replace kelly wiper rubber. Check MWD. TIH to 1163'. Checking for water in diesel. Ream from 1163' to 1193'. Drill & survey 1193' to 1520'. 6-17: Drill & survey 1520' to 2746'. Pump pill, TOOH from 2746'; change BRA & bit. TIH to 2746'. Drill & survey 2746' to 3825'. Pump pill; start out of hole, well swabbing, trip in to 3825'. Circ & condition hole. 6-18: Circ & condition hole. POOH from 3825'. LD stabilizers, LDC. PU Navi-drill. Bent sub, orient MWD. TIH to 3825'. Drill 3825' to 3840' . Navi-drill failed. POOH from 3840'. Change out Navi-drill (dump valve failed). TIH to 1167'. Hit bridge. Work thru, TIH to 3840'. Orient & drill to 3866'. Navi-drill failed. POOH from 3866'. LD Navi-drill (bearing failure). PU new Navi-drill. TIH to 3866'. Drill 3866' to 3923'. 700 psi pressure loss. POOH, LD Navi-drill (dump valve failed). PU new Navi-drill. 6-19: Orient MWD, TIH to 3923'. Navi-drill & survey 3923' to 4245'. POOH from 4245'. LD Navi-drill. PU new BRA. TIH to 3825'. Circ & ream 3825' to 4245'. Drill & survey 4245' to 5152'. 6-20: Drill & survey 5152' to 5645'. Short trip 5645' to 3725'. Circ & condition hole. POOH, LD BRA (SLM no correction). RU to run csg. Running 9 5/8" 36 lb/ft K-55 BTRS csg, broke circ @ 2800'. Tight spot @ 3045'. 6-21: Finish running 9 5/8" 36 lb/ft K-55 BTRS csg, 143 jts, PU fluted mandrel hanger & landing jt. Space out. Recip. pipe w/15' strokes. Circ 480 bbls 9.8 ppg mud. Pump 11 ppg 40 bbl Sepiolite sweep, 752 bbls 12.2 ppg Arctic Set III w/5 lb/sk D-24 (Gilsonite); 56 bbls 15.8 ppg Class "G" w/0.2% D-46; 3% NaCl; displace w/428 bbls 9.8 ppg mud. Lost partial returns @ start of displ. & full returns w/220 bbls left to displace. Float shoe @ 5625'; float collar @ 5542'. LD landing jt; ND hydril. RU for top job; 20 bbls 15.9 ppg Arctic Set I. Install FMC speed head w/19,OOO ft.lb. torque. Install BOP stack & NU. Test BOP stack; choke manifold; upper, lower kelly; inside BOP & ball type valve 500 psi & 5000 psi. Hydril to 350 psi & 3500 psi. Test witnessed by Doug Amos AOGCC. Install wear bushing, strap BHA. PU BRA, service & orient MWD. TIH to 2000'. Slip & cut drlg line. TIH from 2000' to 5542'. -1- Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.15- CONFIDENTIAL (7,192'-Kuparuk River) AFE 10-61-1117 API No. 50-029-21374. Ak. Permit No. 85-120. Elevation: 59' KB. Location: 300' FSL, 1037' ~~, Sec. 18, T13N, RIlE, Umiat Meridian 6-22: Test csg to 1500 psi. O.K. Drill out float equip & cmt. Drill 5645' to 5690'. PU to csg shoe =. Perform mud weight equivalent test. Drill & survey 5690' to 6330'. Pump pill. POOH from 6330'. Change bit, check ~~. TIH to 6330'. Drill from 6330' to 6380'. 6-23: Drill & survey 6380' to 8401'. 6-24: Drilling. 6-25: Drill & survey 9120' to 9152'. Pump pill, short trip 9152' to 5625'. Circ & condition hole. Pump pill. TOOH from 9152' (SLM -31' correction) . LD MWD & Navi-drill. New depth 9121'. RU Gearhart. Logging. RD Gearhart. TIH to 9121'. Drill 9121' to 9152'. Circ & condition hole. POOH from 9152', LD DP. 6-26: Continue to LD DP & BRA. RU to run csg, change top set rams to 7", remove wear bushing. PU & run 231 jts 7" 26 lb/ft L-80 BTRS csg. PU FMC hanger w Ipackoff & pup j t & landing j t. RU cementing head. Circ & recipe pipe w/15' strokes. Pump 360 bbls 10.4 ppg mud; 40 bbls 8.33 ppg Desco Sweep; 56 bbls 15.8 ppg Class G cmt w/0.8% D-60; 0.20% D-46; 0.25% D-13; displace w/9.6 ppg NaCI brine. Full returns, shoe @ 9131' . Collar @ 9050'. 1st packer @ 9003'; 2nd packer @ 8945'; RA marker @ 8618'. RD cementing head; LD landing jt. Test packoff 5000 psi. RU Camco. Logging. 6-27: Finish Gama Ray, CCL, Gyro Run (smooth run). RD Camco, RU to run tbg. PU Vann guns, packer w/PBR & 1st GLM. Run 276 jts of 3~" Butr., 9.2 lb/ft L-80 tbg, 10 GLM(s) w/SSSV @ 8827' w/packer @ 8651'. PU - no additional wt, continue in hole wino additional drag. RU & RIB wi GR & CCL - packer not indicated on CCL. Fish - 197.5' long. POOH. LD pups, hanger & SSSV (PBR pins sheared). LD PBR seal assby. PU O. shot to catch PBR. RIH wi O. shot, tag fish @ 8790'. Set 20,000 lbs on fish, PU indicating 5000 lbs. additional wt. POOH from 8790', slow. 6-28: POOH, did not retrieve fish. Inspect O. shot. RIH, tag fish @ 8790'. Attempting to grab fish. POOH w/fish, slow. LD Pkr, BPV & VCV, Vann Guns, O. shot. RU & run junk basket w/6.125" gauge ring. PU new guns, vents, pkr & PBR. TIH to 5195'. Slip & cut drlg line. TIH. PU pups to space out & land hanger. RU & RIH w/Camco GR & CCL. -2- Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.15- CONFIDENTIAL (7, 192'-Kuparuk River) AFE 10-61-1117 API No. 50-029-21374. Ak. Permit No. 85-120. Elevation: 59' KB. Location: 300' FSL, 1037' FWL, Sec. 18, T13N, RIlE, Umiat Meridian 6-29: Run GR & CCL. Found guns 4' high. Space out, lock-down hanger & displace tbg w/100 bbls diesel, 20 bbl in annulus. Close circ valve, inflate pkr w/3200 psi, press up annulus to 1500 psi - no leaks. Press tbg to 4000 psi to open productin vent. Bleed off press, shear out PBR 49,000 lbs over string wt. Land hanger, test seal assby & SSSV w/1500 psi. ND BOP. NU x-mas tree & test to 5000 psi, open SSSV & install BPV. RIG RELEASED. -3- ~~~-- ------- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 . DRILLING WELL 0 COMPLETED WELLU OTHER 0 2. Name of Operator Conoco Inc. 7. Permit No. 85-~ I ;;!f 8. API Number 50- 029- 21374 3. Address 3201 C Street, Suite 200, Anchorage, Alaska 99503 - 4. Location of Well 300' FSL, 1037' FWL, Sec. 18, T13N, RIlE, U.M. 9. Unit or Lease Name Milne Point Unit 10. Well Number 8-15 11. Field and Pool 5. Eleva5i9~ in ~Bet (indicate KB, OF, etc.) I 6. Lea47~e3¿nation and Serial No. Ku pa ru k Rive r 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) o Altering Casing o Abandonment o Other o (Submit in Triplicate) Perforate 0 Alter Casing 0 Perforations Stimulate 0 Abandon 0 Stimulation Repair Well 0 Change Plans 0 Repairs Made Pull Tubing 0 Other 0 Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170), o o /~ This well was brought on as an oil producing well on 11-2-85, and its suspended status should be removed. 14. hereby certify that the foregoing is true and correct to the best of my knowleg,ge. - ì^ , áJ 7 ,; S;9?"d--------' - #, T;tle ;¡7-T--':V Thè space beJ6 for Commission use !J Conditions of Approval, if any: /" --?) Date - ::){, . f~ Approved by Form 10-403 Rev. 7-1-80 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate r}v ", ,/ -1 (J.~ H 41{ -~ t o ..8.2\ 9"~ Jr9'\g 8'\~ e.e-~ 9.1.... 8 \,...;- ~~.. a"Iot - 9-6"- e 1";- I I I 1 LDCATlON 1M S(CTID,.. ~ , RO"f S LINJ 'RQt.I w LINE . B· II J 464 790' f 8-12 J 76~' 920' ; I~ ~32' 919 l~I~J--;-49' 950' : .11: I :~:" ::::', B . 11 110' II 933 ' I_B~_18 1 e!~ ~~ B·li I ee2' 891' +·"B.20¥. ~:,o' cð73' I '" P..o pc 'Sed Loco. t,ì 0'" (tA'I!"'(AT£, 0' SUf1V(YOR: "'-911 Alaslw¡ ..... 9 \1'1 .... g-,3 ... glEt +91~ +e.2'l -+9 ~ Þ. ..... e , 9·\1+ 9·\k o u ~ R E C EtVflr JAN 0 2 ;~~ "'''.s _!.1~ (;Orlij, v~li¡mjBSjDn Anchorage ~)~ rí'ú^ i7' ;;'" /1 J" ) '"\. /// . \>;;~~"- ~( -- SEC. 18 SEt. 19 :;, I ", ,... .;) V t1 1"..·UVV'1 ~\. . ~.þ + . ~~"~~:::~K····"· ·..·-1 r( ~ > ~. · ~~ · .;J~ ~r.;;;4 ç...!!.. '1 '"' 'co ,\\ ~. '. r;:: ... I~ 'if " r\ 'Y~. \~ '))~. ; ~jl IA "ï ~" 'ZA .., b 11 U A u,.¡ " ~r<1 21 n ?,. N n «_}L -~--- ..--. à .".,0 'Z1 '2t 17 re.. I:"\{ ,.. o~" 1~ " --þ, - ~ w~I.... . ~l .~~... .~~ " Q . If -..:;~.0.:~\ ~, ":\ ~" '" ff}~:~~":~:·:~:~· ':!:?~:J:\ ~ ., C' <:~-.- y' c: J .), f;"k ~<'''.~) r~ :; : \ .~~ '~': ~J r;:;" G::::¡c~þQ f;~'~~~~J'Q:u."u,:~:u .. -:-~) ~;~ ~P'>'VV/ ~ 'f" L-~.. ~-..~Q,"oc=ee.".CI...t:O.O.C~.( Q.:;J t', .~, '~ - I' : c:: d ":, <:...... ~rr~ard 10ml.!. Ich . l.." ,;;; \~ c~;>;.~" l.S. #~Î93 s /'..,~v.,;,1 t·,/,':", .~... ~,,~. ','-:".' J " . c' .; ~ ,0 .. S ~ 'i: ñ~Û f':-~ "......'0....·· -~::oJ """ 'Q .~.¿-~FF)S¡~;:Jf>,: \.,..;~ ~.~~~w:-"~~-.~ . . ~' r , 1-- H ~(. ]1 11 ~J T I' '" T' ., . - ., 12 LI u .. ~ -= tI '" .lr 9.A SCAL( ~ MILLS CONoeo MILN( POINT UNIT [XI&TINC D(V[lON'(HT PiOT[S: I. STAT[ PLANe (0 O~OIN.T{S AR( lON( ~. 2. ALL (¡[OO[TIC POSITIONS AR( eAS[O ON N.A.O. 1927. 3. O"S£TS TO S[CTION lIN(S ARE COp,lPUT(O BAS£O 011 PROTRLCT(D \/8lU[S Dr TH( S£CTION CORIol[R rOSITIONS. 4 LOC ArE 0 WITHIN SECTION 18 B 19. T 1~ N , R II [ , U M ,A I( . STA.TE PLANt CO-oJlOS. G(OO(TIC POSITION NORTHtNCS EASTI~C;S LATITUO( lOPlCI'VD( Ot.T( etlleN(O , '(LO BOOK --- 6 ,023, ~a6.20 !571 ,864. 41 70° 2a' 29.019" N. 149°24' 46.103" W. 6.Z,e!5 J.B.9. 21 - 8~ 6 ,023 .eea .~e 571,932.42 nf 2B' 31.981" N. 149°24' 42 .e,4 "w. e. 2,85 J.B. S. 21·a~ -- 6 ,023,656.07 ~rz ,052.71 TDo 2B' 29.6BB"N. 149° 24' 41.146" W. 6. 2, e~ J.B.S. 21' B!5 - 6 ,023 ,712.38 572,022.58 roO 28' 3D.835"N. 149°24' 42.001 'oW. 10. 23,B!5 B. T. 39·eS 6 . 023,424.25 572, 1\ 3 .60 70° 28' 27. 402"N. 149°24' 39. 42 3"W. 10.23,85 B.T. 3g·8~ - 6 ,023 , ~40.44 512,083.38 700Z8' 28. 548"rt 149°24'40,219" W. 10.23,85 B.T. 39-85 6,023,013.86 572,013.88 roO 2a' 23.376 "r-t 149°24' 42.472"W. lO.23,~ B. T. 39 - 85 6 ,023 I 935.DI 571,773.46 7d'Z8' 3Z. 45e'·N. 149°24' 49.280"W. 10.1 Z ,8!5 L. o. 39 - 8' --.- - ---- 6 ,024, 004.!4 571,961.14 700Z8' 33. 121"N. 149024'43.123 "w, ". 1!5 ,e 5 L.O. 39-85 (ó.024.051.03 S71.743.44 ÎO·. zg'-33.Coaz H. \4f, 24'-50.130 W H.2b. ðS L.a. ~ -55 ~ " - I "fA (flY ([",,,.,. THAT tAM rROI'[RlT AfG'S'fprD AND lIe[IISEO 10 ~RACTICE \,A."O !.UiltVf't"NC I I AIoJO T"AT THIS "lA' ~fPQfS[N'S I.., '....E !;TAT( or ALASKA A LOC ar'l'''' ~URVf Y ~AOE BT ""f O~ UNOE It ...., !.(Ir'£'tY'!:ION, AND '''A' All [)1"'£NSI0'IS ^"O ()TH[" (~rAIL' ARE COR~tCT. '8' PAD 11 ~Ijl~~ uß );1 15 HSSDr1 AS, eUllT ~tLl LDCATlOH S...,,,,,,d fo. J c 0 t~ 0 C 0 .' ::_~\ ro~_·. ..J (O~"'ENIS , 5"[[7 2 0' 3 (NG'N( [RS I ."'0 I l UIU ~Rvf T'l'k!: -- -- .- - .-- -.- Of~(NSIU~ IHI.IS·" ~R~ N.I..INE !'.!!C I. I? Al.l.. (lTHfnS '1\0'" S. ,"/IlL n Cf. II ( conocC?) µ- ~ John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 Cß H #¡ October 11, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the "Well Completion" forms #10-407 from Conoco' s Milne Point Unit wells No. CFP-l, CFP-2, B-5A, B-6, B-7, B-8, B-9, B-l0, B-ll, B-12, B-13, B-14, B-15, and B-16. If you require additional information concerning these completion forms, please contact Jim Hand at 564-7640. Very truly yours, ~ Kemp of Alaska Operations lb RECEIVED OCTJ.'f 1985 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK¡--, "L AND GAS CONSERVATION \ .MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL 0 GAS 0 SUSPENDED ex ABANDONED 0 SERVICE 0 2. Nar, e of Operator 7, Permit Number CONOCO, INC. 85-.' :1.1 3. Address 8, API Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21374 4. Location of well at surface 9. Unit or Lease Name 300' FSL, 1037' Fv.lL , Section 18, T13N, RIlE, U.M. Milne Point unit At Top Producing Interval 10. Well Number 4530' FNL, 1317' FWL, Section 19, T13N, RIlE, U.H. B No. 15 At Total Depth 11. Field and Pool 4769' FNL, 1292' F\VL , Section 19, T13N, RIlE, U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, OF, etc.) 16. Lease Designation and Serial No. Kuparuk River 59' KB ADL 47438 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. NO~ of Completions 6/15/85 6/25/85 6/28/85 N /A feet MSL 17. TotaJ Depth (MD+TVD) 18. Plug Back Depth (MD+lVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9152' (7192') 9052' (9117') YES ~ NO 0 1856 feet MD 1800' 22. Type Electric or Other Logs Run DIL-GR-CNL-CCL-Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASI NG SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 48# H-40 0 78' 17-1/2" 100 cf Perm Cmt 9-5/8" 36# K-55 0 5625' 15" 752 bbls Arctic Set II 56 bbls Class G and 20 bbls Arctic Set I 7" 26# L-80 0 9131' 9-1/4" 56 bbls Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.2# L-8 8758' 8708' 8786-8825' (6916-6945' ) H-'K -1 8852-8888' (6966-6993' ) MK-2 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5" Hollow Carrier 22 gram 12 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR 01 L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PER 100 . I Flow Tubing Casing Pressure CALCULATED . OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) I Press. 24-HOUR RATE I 28. CORE DATA Brief descriptiqn of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~ J r~ L~) ';-:¡ r. ~.-. ~ ¥-= ~~.;..' ~f ~ -- .~.- ;~!ab~~a Uj¡ j~. . (j:J ~-; L:J¡í;:, t ) ~ Ji 1 ~ i i 1 :~~~~. \ U ¡'"¡ '0.< J\; :(JIU;';J~-r~~ Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS I 30 FORMATION TESTS 29. NAME -MEAS. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. KA ("4'503 3887 MA 4867 4137 NA 5168 4242 OA 5366 4476 OB 5450 4533 H. Kuparuk 8786 6916 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed a,-~~ ~ Title Engineer Date 10-22-85 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. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: I ndicate which elevation is used as reference (where not otherwise shown) for depth measurements ---------given Tn other spaces 6-n-thls-form andTn-anyattachmènts~- -- Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gasl njection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 &.;astmé... J WhiR~12£~ (907) 349-4617 P. O. Box 4-1970/AnchoragfJ, Alaska 99509-1970 August, 1985 william Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Van Alen Please find attached two copies of the Gyro Multi-Shot survey run for Conoco Inc. on Pad B, Well No: 15. This is to be considered a formal letter of transmittal. The data herein, is to considered strictly confidential. A copy of this letter is being sent to Conooo's represen- tatives, Mr M. Bradshaw and Mr S. Davies. Should you have any questions regarding this survey data, please refer all questions to CONoeo INC. TOM Dis Coordinator cc: M.' BRADSHAW S. DAVIES .~\ \-:< \ \)...\.; ~(~'\\1 ~ ~ ,\"\ (, . v ~~ 2 "C}(~. Ii; ¡ ;, " ...' .: /~ //.'./ ¡ \"~%0f~, 1(f0{')._ ~ v'~{;~i~~"~-+"", ~' ¡,.' I' '. 'I( '1 ' '/} , :, \)' ,J:'::'lt\ ~ ~ ,-'- ~ Lif c; ~ Directional Drillers/Sub-Surface SUNeyors/lnstrument & Tool Rentals/Sales/Worldwide \1! \ ]\laska Cnmitir.", OF F I CE ·""··'{·I" .7\ n C'11'or a [J e ; " . :-... ~, C 1-. 2 [::1 -- lJ U N - ~ I) (~'.7 r 0 ~1 u 1 t i .- ? h c' t DATE TYPE OF SURVEY LOCATION Milne Point, North Slo0o, ^las~a WELL NAME Pad B I : "~ ell N u m b fT : IS COMPANY CONOCO I 1]\1 C . REPORT of SUB-SURFACE DIRECTIONAL SURVEY Eastman f ~ Whipstock 1 J. A PETROLANE COMPANY FORM g-]02 R2 SURVEY BY B JÞ,HN JOB NUMBER A.0685G0.311 ~~ .~~ ~ Eastman Whipstock A ÆTR01ANE W.lFW-/Y (907) 563-3650 P. O. Box 4-1970/Anchorage, Alaska 99509-1970 Date: August 7, 1985 Conoco, Inc. 3201 C Street Suite 200 Anchorage, Alaska 99503 Well Number: Pad B, Well No: 15 Location: Milne Pt., North Slope, Alaska Type of Survey: Gyro Multi-Shot Date: 25-JUN-85 Method of Computation: Radius of Curvature Surveyor: B JAHN Job Number: A0685G03ll Atten: Mr. Dan Robertson Dear Mr. Robertson: We are enclosing the orginal and one copy of the Gyro Multishot survey run on the above mentioned well. To date, the following distribution has been accomplished: A. 1 Copy delivered to drilling for in-house distribution. B. 9 Copies noted for oil company representatives. C. 3 Copies for E/W permanent well files. We wish to take this opportunity to thank you for using Eastman Whipstock and look forward to being of service in the future. ¡flelY, TOM JO ES Distr c Technical Coordinator cc/file cc: Phil Salvador - Conoco West Coast & Alaska Division O.G. Kiel - P.E.S. Reservoir Section Conoco H.E. Gilliland - P.R.D. Reservoir Section Conoco ~- William Van Alen - Alaska Oil & Gas Conservation Commission J.L. Weaver - Chevron U.S.A., Inc. Dave Engstrom - Chevron U.S.A., Inc. Concord Office Dale Bossert - Champlin Petroleum Co. C.E. Seery, Jr. - Reading & Bates Petroleum Co. Neil Buttram - Cities Service Oil & Gas Corp. Directiona! Drillers/Sub-Suriace Surveyors/Instrument & Tool RentaJs/SaJes/Worldwide '--~ast~n L~-~J li..'=:3 WhI~~9E!f lJ ~ RI~D I !.I~3 OF CI..IR\.,,'ATUI::;:E MFTHOD F\ECOF\D OF~ ~~:;'..IR'JFY VERT I CAI. ~=;ECT I ON Cf~LCI.JL..A TED I I\! PL.?~I\IF OF PROF'O:~;AL DIRECTION: S 2 DEG. 33 MIN. E FORESIGHT: N87 30W CAM~RA NO: 79, 90 DEG A/U NO: 1488, GYRO NO: 399 CONCICO, I NC a PAD B 1 WEL.L NO: :1.5 GMS .JOB NCt: A0685GO:::: ~ 1 MILNE PT., NORTH SLOPE, ALASKA 13M~;;7 0--9000 MD, SURVFYOR: B .JAHN, [lATE RUN: 2~-..JI.,IN-:=:5 '~ l~a~a~tiickill ----..-,.--- ~TROIANE CCMF¥lNY -;.31 0.99 0.70 .-:. ·25 2.00 2.07 1.5:3 1 . ;:: 1 1.00 1 . 51':, 1.54 -. (:. ::: 1 " 7 '?) 129 1 .. :::~~ 2. 5 (:, 1 . 5:2 2 II ~1!:; .-:' 94 1 ' ,-, . t:·¿ 1 . 13 1.::::1 2. 0:::: 1 ,"),;::) " ........- ,¡~ 51 0,00 0.00 0.00 0.25 0,22 S 17 25 E - 17 33 E S 17 43 E 3 17 57 E S 18 9 E S 15 22 E Q 16 5 E _ L6 37 E S 17 0 E ~ 17 15 E ~:; 1 2 1::2 E -. 1 2 1. 5 f.: ':; 1 2 47 E _. 1:::: J :::: E :::; 14 29 E 4 17 E 6 48 E 9 31 E S 1j 11 E - L2 0 E E E E 5 ~4 E E 4 24 S 15 ~~ Q 15 46 9 6 o 0 o 0 o 0 ~=; 20 0 W :3 2 27 t-.J 7~5.27 77';'1. 9:3 :::: 4::=¡ . 0 3 (:. 5 :~: . :~::3 5·~5. OJ 345.20 390.56 438.12 487.64 539.84 :~:()2 t; 4:~: 261.. ~~~9 ::;-~ 2 :~~ " :::: :::-: 1~54. 14 1::::7 . 10 ,-, 39.64 54.49 7~ 00 ~.~~. 97.19 123.86 178.04 E 197.00 E 217.72 E 240.41 E 263.2~ E 142.63 E 160.07 E ':;) 1 . 45 E 1 0::::. 1 5 E 1 ~~5 . ~?5 J::: ~~.58 E 39.71 ~ 49.29 E 61.62 ~ 75.67 E 2.96 F.: 6. 4(-. E 12.22 E 1 fL :::: 5 E 25.77 F o. ::':8 E 1 . 04 E 1 .. :::: 9 E 1.75 E 2.1:? E 0.00 0.00 0.00 0.07 W 0..0:3 W C LOS U R E DOGLEC DISTANCE DIRECTION SEVERIT FEET D M DG/I00F 1 ~:: -, c- 17.05 27.69 681.33 S 742.00 S 802.99 - 6·22 II :~2 .=- 5(-, 7 r 75 :=; 515.~6 ~:- 332.87 _ 375.29 S 4t9.84 - 466.3J S '-::'I~J ·::r _ :~ :~: C· ':?~4. ./:¿ _ 182.84 c 217.36 _ j 50. 6~~ ~=' 1 ,-, 1 '1 r.= .... (II.. ._' _ 54.10 S 72.96 _ 95.~:4 S :.:: IjI a ~5 :~: .=. 16.96 S :'7 . 61 :::; E:. /:.. ';J 1=' :3. 1:.. I? ~=; 1.. :39 S 0./')2 S 0.00 0..00 0.00 0.20 S 2478.30 2554.48 2630.32 ;~ :~: I~J '"9 . I;J 1 231 :~:. 6:::: :22:~:5. 25 1886.29 1975.29 ~Ob3.17 2J49.99 1.51. 9 . :~{:::: j '- _I .-:. -, .-;:. . '..' .. ..:... / '-' 1 704. ::;::(:. 179(-,,, 04 j424.97 13';?'::} . {. 7 939.19 1088.05 1136.08 1233u3j :::: ::=: t~J . '~J l 440.99 540.96 640.83 740.49 4~. .00 141..00 :?41 u 00 341.00 -'~)9 . 00 R E eTA N G '-' L A R COO R DIN ATE S FEET :::;UBSF.:A Tvn FFET COMPUTATION PAGE NO. TIME (lATE ~. 0: 52: 01 :::: ~ -,JUL. -::::5 ,-, ,-, .=. :=:. ::;:0 :~:ø :34 1.44 0.62 () II 2:2 0..00 0..00 0.00 575.10 630.97 690.34 751.96 813.9~ 336.61 379.73 424..99 472.20 522.17 ¿' .~}~;. :~: .:;) 151.96 184.43 2)9.34 2~6n71 1 22. U:: :-::9. 1-..2 ~4.34 7:::. 43 ':)6.09 :~:. 74 l7..02 27.6::::: 3.74 1 . 4~. 0.00 0.00 0.00 0.20 0.62 2 (~. :=: '~) a :::~ :~: 2377.63 2458.91 2537.30 2613.48 ·22'?4. :¿~~ 1 945. .;? 9 20::':::4.29 ~'?122. 17 2~:-::O::::. 99 J483.97 1578.38 1671.78 17b3.8ê 1855.04 998.19 1097.0~ 1195..08 1292.31 1388.67 79'::). 49 89:::: r 91 (:. '~) I~I " t: :~: 599.96 49';' . 9'-:;) 0..00 100.00 200.00 300..00 400.00 100. 100. 100. 100. 100.. 100. 100. 100.. 100. 100. JOO" 100. 100. 100. 100. 100.. 100. 100. 100. 100. 100. 100. 100. 100. 100. o. 100, 100. 100. 100. S 19 E S 19 E S 20 E S 21 E S 20 E ~ 22 E S 21 E S 21 E S 20 E S 19 E S 12 E _ 13 E - 18 E - 19 E - 21 E S 10 E S 17 E 3 17 E S 16 E S 14 ~ S 23 E 9 E 1 W 6 E ? W o o o S 20 V-" S ::::3 E 34 30 36 45 40 0 40 45 40 30 :29 0 30 :~:O 32 :30 o :;;::6 15 24 45 2:::: .<l5 o 18 ::::0 20 (> 7 15 10 0 12 45 14 15 t6 45 ~=: o 45 o 3 45 ~ 45 6 30 2500. 2600. 2700. 2800. 2900. 2:~: 2000. 2100.. 2200. 2300. 2400. ,- -;::0 , ' ..=, ~=; (> 0 (> 0 o 0 o 15 o 15 .- 1500. 1600. 1700. 1800. 1900. 1000. 1100. 1~00. 1300. 1400. 'j ..:.. 500. 600" 700. 800. '::)00.. O. 100M 200. 300. 400, TRUE l'1EASURED DR I FT DR I FT CnURSF VERT I C:AI.. VERT I CAl. DF::PTH ANGLE DIRECT ION LENGTH DF.:PTH :=';;ECT I ON FEET D M D FEET FFET FEET JOB NO: A0685G0311 CaNoe 0, INC. PAD B, WELL NO: 15 GMS MILNE PT., NORTH SLOPE, ALASKA '"" ITL~astl11an t---rrD ~_____~ WhIpstock L__- A r'f T ROI ANE n:t.mWy Or74 O~50 0,25 0.75 Or25 (> ~ 2~ï O"2~ 0.75 0" 7:::: 1.49 25 2 g :'~:2 1 " LI·4 0"77 o . 2~~i 5.,27 2 r ·~J.t.1 1 I.. I:~~ . '-'--..' 1 .O:? 0.:::6 :::: 1\ :~: 1 0.50 0.50 0.50 :125 0.69 0.65 0.65 o. ::;:2 0.50 S 10 57 E S 10 28 E 9 59 E 9 33 E 9 8 E _ t3 37 E S 13 2 E 3 12 30 E S 11 58 E S 11 27 E S 16 27 E S 15 55 E ç 15 22 E ~ 14 48 E S 14 12 E Q t9 13 E _ 18 44 E _ 18 10 E S 17 3~ E S 17 1 E S 19 6 E S 19 15 E ~; 19 2::: E - 19 80 E S 19 30 E S 18 17 E S 18 26 E S 18 37 E S 18 47 E S 1:3 ~6 E r=' 2:~:7::::. 5:~J 492.87 E 483.85 E 474.78 E 465.74 E 4~6.73 E 5~8.71 E 522~35 E 515.96 E 508.9j E 501.22 E ~37.08 E 538.95 E 53'~N59 E 537.67 E 533.8~ E 513.84 E 521.93 E 527.28 E ~31.53 E 584.60 E 403.64 E 427.84 E 452.30 E 477.00 E 499.06 E 2:~:5. 54 E 308.40 E 332.14 E 3~,i5 . 82 E :7.::79.!S0 E 2::;:42. 13 .=, :::-:: 7/-.· :=: II :~: () ~; 2695 r 19 .=, 26:::: 1 . 21::) "_. 2547. ::::1 S 2182.43 S 225~.14 S 2328.14 S 240j.38 S 2474.56 S 21 ()';J. :~::;: ~3 :~:():::5. ::::5 ~= j818.16 S 1889.91 S 1962.60 S 1607.~2 S 1677.01 Ë 1747.34 c 15~:~' II ~::: ~: l4 73. () 1 ~: 1165.78 S 1225.h4 S 1786.16 S 1347.29 S 1409.58 S 1045. :::6 S 1105.98 S 9L~5. 4::=: E; ·~J:~:5. 7 4 ~3 :3(:-4. :1:~: -::. 4574.79 464J.54 4708.Al 4776.0J 4507..55 41b8.t5 423b.51 4304.55 4372.27 4439.90 3'-:)64. 3~ LI·i)::::::2. :::::9 4100. 1 j :::: ~::: '~J 5. (~. :::: :::: :~: 21.:. II () 5 ::::755. ~¡O 3612.70 36::::4.4:::: :~:5:~:'~1 n 57 :34/:.4. S2 :::: :::: ::: '~, II 4 S"' 3087.19 3163.51 3239.27 3314.45 ::?9:34.40 ~'::010. 72 ·2:::~8. 08 27:=: l . :::.~) :7~706. 14 C L 0 :::; U R E DOGI EI:' DISTAN~E DIRECTION SEVERll FEET D M DG/l00F R E C TAN G U I.. A R COO R DIN ATE S FEET ::;;UBSEA TVD FEET .-. .;:. ';:-::807. 70 COMPUTATION PAGE NO. TIMF: DATE 10: 52: 01 31-,.JUL-S5 2 .-. .::' 273/;.. {~.~J '2665.57 2595..05 231 4 . f: 4 23::::4. (:·3 2454..72 2524. :::: 1 2"245 ø 5.::, 1895.83 1965.26 2035..43 2105.65 2j75.83 1691.78 1759.23 1827.?Q 1625. ::i9 :l ~ÓO. ,s :::: 1298.17 1363.37 1429.24 1495.32 1 :?~::;:. 6:::;: 975.51 1040.20 1104.73 1169.28 910. ::?:::: :2 ;~: ~ '~) r I~' :::: "27 :=:: .'~'. 7:=: 2567.22 2640.22 2713.64 24:?1.65 :~~4':;J4. 41 2:::4::::. 71;' :2' 276. 1 4 2203.79 1840.25 1912.02 1984.66 2057.76 2130.99 1 769" .':'0::"' 1 (:. I~' ::::. ';'1;1 1. 6::::: 9 . :-=:: :::: 1495.02 1561.. :23 1243,,46 1305.01 1367.18 1430.39 11 :::2. 5:;: 1 060 ~ 61:.. 1121.77 999" ~~5 ~..) :~::=: . 2 :~: :;::76. :1.8 463:::. 79 4700..54 4767.61 4:::::35. 01 456("" 55 44~:1. 27 449::::. 99 43/:.:::: u 55 4227.15 4:?95.51 A02:~:.. :~:5 4091 . :-;::9 4 J 59. 11 :-:::'~J54.. /-..:3 :~: :~:: :::: 5. (=>::=; 3671.70 3743.48 3814.50 :::: ~i~) ~:.:: u 5 7 ::;:52::;:. :=:2 :337:3. 4~ï ::::44:~:. 49 :::¿~S-J:=:.. 27 ;::2::?2 . 51 3 1 4 (-, u 1 9 2917.08 2993.40 3069.72 2840.::::9 :27{·5.14 100. 100. 100.. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. lOOM tOO. 100.. 100. 100. 100. 100. 100. 100. 100. 7 W 7 W 7 l.J 7 W 7 W 5 W 5 W 5 l.-.J /;. ~, 6 W 2 E 1 E (> E -- I,.-J :::: l..J 9 E 5 E 4 E :3 E 2 E S 22 E - 22 E S 22 E S 22 E - 17 E S 20 E S 21 E S 22 E S 21 E Q 22 E r· .=. 47 30 4::: (> 4:::: 15 47 30 47 45 5500. 5600. 5700. 5::::00. 5900. 5000. 5100. 5200ø 5~:OO. 5400. 4500. 4600. 4700. 4800. 4900. 4000. 4100. 4200. 4300. 4400. 3900. 3:300. 3500. ::::600. :3700. 3400. ::'::000. ~: 1 0 (> . 3200. :3::::00. TRUE MEASURED DRIFT DRIFT COURSE VERTJCAL. VERTICAL DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION FEET D M D FFET FFET F~ET JOB NO: A0685G0311 .=~ , . ~3 ,-. .:;. :; 47 0 46 45 47 30 47 15 47 30 C:ONOCI] , I NC . PAD B, WELL NO: 15 GMS MILNE PT n' I\ICIRTH SLOPE, ALASKA ,=. ,-. .;:. .-. .=. '=~ .-:1 45 15 46 30 46 45 47 30 47 15 ~3 ,---. - .::- .=. '-' 41 0 1.1::? 15 4;::: 4- 5 44 ~:O 45 0 r· =. .-. .=. ~=; c· 40 (> 40 30 4l 0 41 :::;:0 41 15 41 0 40 30 40 15 40 15 40 15 í~ Cl:~~~a~g~iickfÌ) A f'f, IF/C)t ANE Cx:NPANY Or75 0.69 0.65 0.00 0.70 1.00 0.82 0.50 0.00 0.25 - 50 o. '7~5 1.00 0.73 () . :::: 1~' 0.:36 o. :;::7 2. :::';:6 0. ::'::7 0.71 u. ::;::7 0.50 0.71 0.75 ¡I ,-)1::' :tko.,' (>. 2~i 0.77 0.50 Or 7::: 0.B9 3 39 E :3 32 E :3 24 E :3 1::;: E :~: 11 E 4 19 E 4 10 E 4 2 E :3 5·4 E :3 L¡·7 E 5 8 E 4 57 E 4 46 E 4 37 E 4 28 E 6 1:::: E to 4 E 5 49 E 5 34 E 5 20 F 7 17 E 7 4 E to 51 E Ó ,(~O E to 29 E :3 45 E :=: 24 E 8 5 E 7 4f: E 7 ::::2 E -, 4655.09 4719.06 4783.21 4847.46 4911.82 296.63 E 290.42 E 784.19 E 278.53 E 272.29 E 326.80 E 3'9.96 E 313.71 E 308.02 E 302.30 E 350.46 E 343.9' F 337.98 E 332.12 E :::57 . ~15 E 400. (':.:3 E ::::93.24 E 3:3:~: II '~'7 E :374. 74 E 365.~5 E 419.25 E 414.::::7 E 411.16 E 408.07 E 405.00 E 448.89 E 441.36 E 485.02 E 429r33 E 424.28 E 4645.63 S 4710.\1 S 4774.76 Ë 48~9.46- 4904.27 c 4319.61 S 4385.41 Ë 4450.38 S 4~15.4' - 4580.77 S 4-:~ 5:::. 1 :~: ~=: 3981.85 S 4050.31 S 4118.3A S 4186.14 S :~~:I;¡ 12. ~2 .- 3702.21 S 3772.62 S 3842.77 S ::;::'-='::: 1 . 44 ,- :;:~ï60. 86 S :34 ';:J (). :3:3 -_, 341 9. 7:::: S; :=: :~: 4 :==. :::: 1 ~:; :3 ;: 7 7 . :::::? :;:; 3133.20 S 3205.40 S ::: t:) ,~. (:). :~: =::: .-. :2 (il E: ::::" :;::2 ~; :2'~ 15. ;:::3 ~=; 6715.13 6791.17 6867.21 6943.11 /.:' (:- :~: ~~: . .~J 5 65(-:.::::. O~3 6261.02 6336.06 6411.82 6487.58 (~) 1 :=: (:- . 5 '~'I 5893.73 5966.27 6039.26 6112.~4 5::::2:;;:~. 'I. (> 5751.09 ~ï 1:.. :::: (>. :::: :::: !:i ¿:' ° 9 . 9:~: 55 :::: J:;ï d ·ì :::: 5469.02 ~:~:::.~,:=:.. t 5 5257.04 5::::27 . 44- 5:1 ::::-7. 2(-. 4:;::43. ~57 49:1 1 . 61 L ,9:~:O. 1:3 504::::.96 5117.95 C LOS U R E DOGLEC DISTANCE DIRECTION SEVERIl FEFT D M DG/l00F R E eTA N G U L A R COO R DIN ATE S FEET f;!...IBSEA Tvn FEET ,-- ,;:. ,-. .=. 1=' , . - 4331.92 4397.06 4461.43 4525.91 4590.73 COl"'PI.JTATION PAGE NO., TIME DATE 10: 52: 01 31-·JUL-:35 :::: - ~=' =, - =. 3997.88 4065.44 4'37.69 4199.76 4?66.06 - - - - -=. :~: ':! ~::: '"iJ ,. 5 I~' =, 3:~:60. 9!:-i - 3653.48 3723.04 3792.11 - '::1' .-, ....·1 :~: 5 :::: :~: Q :::: :;: ~; 3304. o:? 3374.41 3444. :3.:':, :;:: ~ J. 4. 1 5 - ~=: ~=; ~=I· ~: 2 :.:: ::::.. :3/';. ,.... .=, 2949.66 3020.74 3091.64 3162.47 .-. .:;- .-' ~=; 4654.23 4718.37 4782.67 4847.06 4911.53 45::::9.6:::: 4524.65 4:~:95. ::::0 445'::) n 9:::: 4::=:';:::1? . :::::5 3993.Q¿ 4061.89 4129.58 4197.03 4263.68 :3 9 '? 4. 9 1 :~:7:35. '"i'7 :~::~:55 II 5';} 3645.67 371 (:0 . 04 ::::~75.36 34:34.64 3505.07 :;::3t,:~:. '?5 :::: :;:: '~J:2. 7 :~. 2982.44 3005.00 3077.21 3149.19 3221.11 6697.95 6774.13 6850.17 69?6.21 7002.11 66:22. O~ 6320.02 6395.06 h470.82 6546.58 6245.56 60:.-:::5. ·?7 60"~}f:. 26 61 71 . ~54 5S"J52. 7:~: 5:::10.09 5:3 :;::: 1 . 1 (> ~(~,t.:=:. S"J:~: 57:~:'~. ::~::3 5598.73 552:=:. ()~~ 5457.t5 5:::::=:(-:1. 44 5:3l/:...04 524(:.. 26 4970.61 50:~:::9. 13 5'.07.9/:.. 5176.95 490:2.57 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. 100. /:.. W 5 W 6 L-J 5 W 5 [;.J 5 W 6 W 5 ~\I 5 l-o--t 5 ~J 6 W 6 W 5 W 5 t,.j 5 W 4 W :::: W 7 W 8 hi 7 Irl 4 l..J :3 W :::: W 2 W :::= W /:.. W 5 W 5 W 4 W 4 W .::' 40 15 40 30 40 30 40 30 40 45 8500. 8600. 8700. 8800. 8900. ::;:000. ::::100. 8200. ::::300. 8400. 7500. 7600. 7700. 7800. 7900. 7000. 7100. 7200. 7300. 7400. 6500. 6600. 6700" 6::::00. (':'900 " 6000. 6100. 6200. 6300. 6400. TRUE MEASURED DRIFT DRIFT COURSE VERTICAL V~RTICAL DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION FEET D M D FEET FEFT FEET JOB NO: A0685G0311 .-, .-. .=, ,-. r· .::. ~; ·41 45 41 0 40 :30 41 0 41 0 CONOCO., INC. PAD B., WELL NO: 15 GM~::~ MILNE PT.., NORTH SLOPE., ALASKA ,....' .~, ~=: ,.... .~. .::. ,..., .=, 44 0 4:3 0 43 15 42 30 42 0 ~=; ,.... .-. .:;- ,-. ..~I - 45 15 45 30 45 0 45 0 44 30 ~: .-, -. ~=; S ~=; 46 0 45 ::: 0 45 0 45 (> 44 45 - ,..., .::. .-. .::. ç' --' .-. -. 47 15 47 0 46 :30 46 30 46 15 ~=; ~~: ~=; ..... ,::> i[LËastf7?8n f=- k l ì J ~_-::=::J Whle~19£, - 0,.00 0.00' o. :;;:~5 ·-1 5 :::: E: 5074.94 ;~55.. 0::: E S 2 DEGS 52 MINS 50 SECS ~ 5074.94 FEET 506:::: r ~5::::: .-. ~OO:3. 2:::: S 49/:.';:J. :~:5 8 7' :;:::.:. 44 7057.97 701:3. 72 5074. E:~ 5009 . 9:~: 4976. '?4 7l92.41. . 7l1(:...97 7077.72 DIRECTION: n J ~=;T ANCE : FINAL CLO:::;URE ,-. o E .-, ..:. 5010. 1 ~:: 21:..1 II :=::3 E 100.. {. W C· -.-' 41 '::J j !:i~) .. ~; :3 E ~3 4976..44 2(-;.5.45 E o PRO...IECTED TO T[I 52. (:. W 41 90!:'~2 . .-, '-~' o ~~; PROJECTED TO PBTD too. 6 W .-- .;:. (> 41 9000. TRUE 'w1EA~:;URF.:D DR I FT DRIFT COUR~::;F VERT I CAL VERT J CAl_ ~=;UB~~;EA R E eTA N G U L A R C L (I SUR E DOGLEf DEPTH ANGLE DIRECTION LENGTH DEPTH :3EC:T ION TVD COO R [I I N ATE S DISTANCE DIRECTION SEVER I " FEET D M D FEET FEET FEET FEET FEET FEFT [t M DCi/ 1001 4 COMPUTATION PAGE NO~ TIME DATE 1 (> : 52: (> 1 :31-.JUL -::::5 JnB Nn: AOb85G0311 CONoeo, INC. PAD B, WELL NO: 15 GMS MILNE PT.., NORTH SLOPE, ALASKA .~ ( flEastl1?an ~I ~ ~~_-=~~3 Whipstock L._j~ A il Ti?U/ANE CCMrnNY F~:FCOR[: OF I I\ITFRF'OL.ATED ~=;URVF-Y FORESIGHT: N87 30W CAMERA NO: 797 90 DEG A/U NO= 14887 GYRO NO: 399 C(INOCO'l I NC . PAD 8, WELL NO: 15 GMS JOB NO: A0685G0311 MILNE PT., N()RTH SL.OPE, ALASKA GM::::, 0-9000 MD, SURVEYOR: B .-'AHN, DATE RUN: 25-.-'UN-:~:5 rrL East11?an F--=:- ~J ~~:~~=3 lNhlpstockL_L A F'UFlOIANE CCMPANY 768R5~ S 17 55 E 854.t8 S 18 10 E 940.29 S 18 2~ E 1075.70 S f8 35 E Jfl0.31 S 18 48 E 426.12 S 16 :~9 E 482.5~ S 16 58 E 543.h4 S t7 16 E 611.03 S 17 27 E 685.75 S 17 39 E S 1? 24 E ~ 13 4 E ~ 14 0 E - 14 57 E S 15 49 E 6 ~5 E 9 37 E - 11 16 E S 12 2 E _ 12 13 E ~~; 1 5 4 ~i E '9 5 E 5 ~;:~: E 4 :?4 E: /1 --. "' 1:-" ~. .¿.. . t::. o 0 o 0 S :20 0 W ~=; 2 2 7 l~ S 15 :22 E :::: 7:::: nO::::: :3 :~~ :~:. 7 ~~; 195. ::::'::) 2:~:4. 7~; 277.77 159.73 1 :~'7 r 4(~. '"-;}'-;J . :~: 2 .,-. .=, :55. 07 75" 1 ~5 - .=. ".-' :::: 9 . 9 l c~· 27 II :~:2 '-~ 17.10 ;3 :=:. :::: 1 :::: I :=: 4 1.44 0..';:::2 0.62 0.00 OrOO C LOS U R E DISTANCE DIRECTION FEET D M COMPUTATION PAGE NO~ TJME DATE 10: 5::;: : 0::;: 31-,-'UL -::::5 l 972.~4 S 3~6.82 E 1051.06 S 357.87 E 731.27 S 236.39 E 811.59 S 2A6.34 ~ 892.47 S 296.06 E 170.94 E 140.83 E 161.81 E 183.26 E 207.86 E 41.93 E ~3.07 E 67.19 F 83.53 E 101.72 E 6.63 E 12.5~ E 19.40 E 26.58 E ~3.79 E l . 04 E 1 . :::.~ E 1.75 E 2.13 E 3.02 E 0.00 0.00 0.07 W 0.03 W 0.38 E 408..60 ~ 461.50 S 519.t6 ~ ~82.90 ~ 653.49 S :::: 5 ::: If ~} 4 :::; :::: 1. 2. 7'7 ~=; ;'/:.9 2f 5:::-~ ~=; ]90.84 S 2?8.b7 0 54.67 S 74.10 8 97.40 - 124r66 S 156.t2 S :~: '~J " E: () ~=; ::::. 7 0 ~=; ::::. 70 S 17.01 S ·:?7. 74 S 1 .. ~:.? .:~ 0.00 0.00 o. :20 ~:; 0.62 S R E C TAN G U L A R COO R DIN ATE S FFET JOB NO: A0685G0311 254~.OO 2641.00 2741.00 2841.00 294j.00 2041.00 2]4~.OO 2241.00 2341.00 2441.00 1541.00 1641.00 1741.00 1841.00 1941.00 1041.00 1141.00 1 ::;:: 4 1 . 00 134:1.00 14·41 . 00 541.00 641.00 741nOO 841.00 941.00 41.00 141.00 241.00 341.00 441.00 SUBSEA VF.:RTICAL DF:PTH FEET 2600.00 2700.00 2800.00 2900.00 3000.00 2100.00 2200.00 2300.00 2400.00 2500.00 1600.00 1700.00 1800.00 1900.00 2000.00 1100.00 1200.00 1300.00 1400.00 1500.00 600.00 700.00 800.00 900.00 1000.00 100.00 200.00 300.00 400.00 500.00 TRUE VFF<T I CAI. DEPTH FEET ::-::~:(}:=:. (-;.5 27:3:;~ n 30 ~'?914.. 02 3046. O~? 3177.58 .-,/ ¡::;o.-, 4·-, Ll')~_".a::. ¿ ~~527 . 52 2174.77 22::-:9.64 2406.90 1 9':!-9 ~ :~:2 2061.47 1 ::: :~: '~] . l-.. :~: 162::': N 11;. 1. 7:~:0. /:.:3 1.10:3.01 1205p06 1 :::::07 . ';J:;:: 1 4 ~ 1 . :39 151.6 N 9:;: 901.0';) l 001 . ::::3 :::;:00.5:2 1':'00. 04 700..17 100.00 200.00 300..00 400.00 500.01 MEASURED DEPTH FEET "I~ I -. - Nf -. - t N - LU JLU., I...:. PAD B, WELL NO: 15 (;1"1::-; MILNE PT., NORTH SLOPE, ALASKA rll-( Eastß?an ~ ) ~~~~~~~ Whipstock L_L~ A r"le Tl?U/ ANI: CalF!t1.Ny 3654.74 S 6 18 E 37~3.47 ~ 5 ~7 E ~ 3851.13 ~ 5 36 E ~ 3947a58 ~ 5 \7 E 0 404~.90 ' . c 1 E ~I ~ C LOS U R E DISTANCE DIRECTION FF.ET D M 1194.76 S 19 o E j279.13 S 19 12 E 1364.89 S 19 23 E 1452.62 S 19 30 E 1589.98 S 19 18 E 162~.89 S 18 43 E 1718.35 S 17 56 E 1813.38 S 17 8 E 1910.72 S t6 20 E 2011.55 S 1~ 3~ E 2114.56 S 14 43 E 2217.71 S 13 51 E 2319.44 S 13 o E 2422"33 S 12 12 E 2525ø:~6 S 11 27 E 2630.11 S 10 42 E 27~6.11 S 10 o E 2841.75 r· 9 2J E ~. 2946.95 - 8 45 E 3051.14 ~ 8 16 E ~. 3154.28 ~ 7 50 E 0 325~.85 ~ 7 27 E - 3358.?2 S 7 7 F.~ 3457.74 ~ 6 49 E ~. :3556.27 S 6 84 E 2 COMPUTATION PAGE Nd~ TIMF DATE 10: 5:::: 08 :31-·JUL -:35 SUBSEA VFRTICAL R E eTA N G U L A R DEPTH COO R DIN ATE S FEET FFFT 3041.00 1129.64 S 389.06 E 3141.00 1207.97 S 470.71 E 3241.00 1287.57 S 452.87 E 3341.00 1369.33 S 484.80 E 3441.00 1453.:~7 S 509.16 E 3541.00 1540.86 S 522.04 E 3641.00 1634.91 S 5:?8.96 E 3741.00 173?a98 ~: 533u98 E 8841.00 \883.56 S 587.48 E 3941.00 1937.88 S 539.37 E 4041.00 2045.19 S 537.t8 E 4141.00 215~.2b S 530.75 E 4241.00 2259.95 S 5?1.93 E 4341.00 2367"56 S 512.16 E 4441.00 2475.66 S 501.09 E 4541.00 2584.37 S 488.38 E 4641.00 :2h94.~9 S 474.85 E 4741.00 2804.04 S 461.41 E 4841.00 2912_~9 S 448.71 E 494~.00 3019.45 S 488.64 E 5041.00 3124_83 S 429.98 E 5141.00 3229.3J ~ 422.60 E ~ 5241.00 3382.:37 ~3 4t5.88 E 5341.00 8433.28 S 410.57 E 5441.00 3532_99 S 406.21 E 5541.00 3632.72 ~: 400.54 E 5641.00 373:3_24 ~3 ~~9.16 E 5741.00 3832.72 ~: 376.0b E 5841.00 ~980.81 S 363.47 E 5941.00 4026.46 S 352.97 E JOB NO: A0685G0311 5600.00 5700.00 5800.00 5900.00 6000.00 5100.00 5200.00 5300.00 5400.00 5500.00 4600.00 4700.00 4800.00 4900.00 5000.00 4100.00 4~00.00 4300.00 4400.00 4500.00 3600.00 3700.00 3800.00 3900.00 4000.00 :3100.00 3200.00 3:300.00 ::::400. 00 3500.00 TRUE VERTICAL DE=:PTH FEET 7565.16 7 42,~,. :::::3 72:35. 74 7001.:::::1. 7144.07 6577.01 67J9.17 6860.46 (::t 4 :~: :::: Þ 2 5 «2:~::=:.. 44 5996. ~::-:O (':.1 4:2. ':'/0 5~=:4:=:.. ()/~. 5699."20 5549. 7!:i 5401.49 ~;25~:. E:::::' , -4:::: l2.. 71 4960.09 5106.1;;.(> 4521..47 4666.00 4::::7S-J " 5::~ 4239.4:3 4101.96 :39 6E: . :-:::3 ::::8:35. 38 :3439. /:.0 :3570.51 3702. :30 MEASURED DF:PTH FFET CONCICO, I NC . PAD B, WFLL NO: 15 GMS MILNE PT., NORTH SLOPE, ALASKA CC~ Eastf7?éJn ~ -lJ ~_~ Whipstock L .- A I'f'TR01Af\lr (y""'~^J)' C L (t SUR E DISTANCE DIRECTION FEET D M 41 :34. 2:=': c" 4 46 E - 4225.25 f""." 4 :33 E .::0 4:314. :?1 ro· 4 22 E .::0 44·01 .26 ,... 4 10 E .=. 44:36. :?6 ..... 3 59 E .::0 4571.79 ,=. :::: 49 E '-' 4656.:32 - :::: ::;;: .~J [:: 4740. :::::~:: ~=: :~: ;:: '~J E 4:3:?5 a 31 .=. ::;:: 20 E - 4910..03 ~=: :;: 11 E 4995, ~56 '-' :::: 1 r" .. 'J '-' COMPUTATION PAGE NO. TIME=' DATE 10: 5:3: £):3 81--·JUL -::;:5 2(:,:3. 4:3 E ::;:0::::. 97 E 2';:J6. 46 E 2 :::: ::: . :::: (:) E 2::;::0" 4:3 E 272.46 E :34:3. 77 E ~::~:5. 72 E ::;:-;27 . ::: 6 E 319.56 E '311.52 E 4 ~J :::::::: II l:1 1 .::. 4561 . 6f: :::: 4647. :'::7 8 4 7:::::~~ a 11 \:::: 4 ::.:;: 1. 7 . ,. /.:. S 490::? 47 S 4:301 . 7:3 :;:: 4::::::::9.64 S 44·75. 4:~: S 41 19. 97 ~=; 4;~ 11 . :=:'~J ~:; R E C TAN G U L A R COO R DIN ATE 3 FEET JOB NO: AOb85G03~1 7041.00 6541.00 6641.00 6741uOO 6841.00 6941.00 6041.00 614'.00 6241.00 6341.00 6441.00 ::::UBSEA VERTICAl.. DI;::PTH FEET 7100.00 6600.00 6700.00 6800.00 6900.00 7000.00 6100.00 6200.00 6:300.00 6400.00 6500.00 TRUE VERTICAL DE:PTH FEET 9029.52 :=::=:-:'-J7 .. ::?~~ :::;:765. 5:3 ::::/:..:;:4.0:? ::::370.79 :?502a70 :::: 2:3 :=:. 5:;:~ 7973.11 ::;:106.52 78:;:::;: r 45 7702. :::8 MEASURED DEPTH FEET - CONOCO., INC. PAD B, WELL NO: 15 13M3 MILNE PT., NORTH SLOPE, ALASKA ¡.~(."<Ì' III Eastl1?an ~ J\ ~___:._.~ Whipstock i__,~J A F'UROI ANF (':t"MIWJY RFCORD OF II\ITERPOLATFD SURVEY FORESIGHT: N87 30W CAMERA NO: 79., 90 DEG Aft! NO: ~.4::::8'J GYRCI NO: :399 cCtl\lCICO, I Ne.. PAD B, WELL NO: 15 GMS ,JOB NO: A0685GO:::: j 1 MILNE PT., NORTH S'-OP~, ALASKA OMS, 0-9000 MD, SURVEYOR: B .-'AHN? DATE RUN: 25-.-'I..IN-:35 ~ /-/-7 Eastman f==~=-~J-) \,---~----?~~~l Wh~ostock L_____ A (-'f.'TROIANE CCMIN-JY 4 E o E .-;, 53 E .. ..:> ·~f :3 12 E .-::' (:. E 3 42 E 3 33 E 3 19 E :3 16 E ? 14 E S tl 48 E S 1~ 37 E S 11 12 E ~ 10 20 E [~ .:;. C' S 12 40 E - 12 29 E ~ 12 19 E Q 12 14 E - 12 6 E S 15 tE S 14 48 E S 14 24 E S 13 57 E ~ 13 26 E ~=; 1 6 49 E ~3 l6 ::?6 E S 16 6 E S 1.5 51 E ~::; 15 17 E ,-. 4902.81 4954.47 4969.33 5010.1:3 5074.94 ,-. .~ ,-. - ,-. .=- 4630.63 4707.54 4838.47 4862.91 4880.93 ,-. .=. r=· -=. .-' I-~' =. - 45~5. ·7:~: 2/':.::-::4 at 7~ :2 ~~!=:~ ';) . I~) 1. :2~iOO" '~/6 24 7!:i. 72 2407.74 2418.25 2436.47 2 ::: :=~5. .~! .-:. 2::':::62.27 2 :21::.1.:.. ::;: :~~ 2::;~ 15.,55 :~ 1 ~52. ,~)5 20/::.3.49 2l04.2~::; 1. ::::97 . ';'1 1940.94 197:3.67 204~.24 1 :~:50. ~i7 C LOS U R E: DISTANCE DJR~CTION FEF::T D M 4895.\9 S 273.16 E 4947.22 S 267.78 E 4962.\9 S 266.20 E 5003n28~; 2t.l.8f: E 50A8.~:3 S 255.0:3 E 4830.40 S 279.32 E 4855.01 S 277.03 E 4873.1A S 275.29 E 4698.51 S 291.53 E 4620.99 S 298.78 E ~06.bO E 503.83 E 497.04 E 481.40 E 305.39 E 518.00 E 515.89 E 513.63 E 512.58 E 510.74 E 538a82 E 537.71 E 535.09 E 530.9~ E 526.80 E 535.44 E 537.13 E 538.30 E 539.0:3 E 539.32 E :~4:?3. 34 S ::;::449. 6:::: ~:.:. ? 5 1 1 . 1. 9 .- 264 ~ . 24 ==; 4545. 4::':: ~; 2:~::=:2. ~:4 .=, :23/:.:3.30 S 2352 . :~: l t=- "2:3 :~~:3 . ::: 7 ~=; 2304. 7::::: ~=; 2j51.00 S 2204.24 S 20::::5. 08 S 2 () :::: 4 II ::::3 ~:; 1991.90 S 1771.42 S l820.31 S 1864.80 S 1898.A4 S 1'972.85 S R E C TAN G U L A R COO R DIN ATE S FEET 1 COMPUTATION PAnE Ncì; TIME DATE 10: 56: 46 :31 -.JUL -:3!:ï 6932.48 6993.01 7010.41 7057.97 7133.44 6';'/06.6:::: l-., :::: :::: 5. i+:3 I':. :::: ~è (:. a ~~ (~-I 6 (:. 1 O. 1 j. 6701.42 <:,522 a :~:liJ 4392.59 4416.97 4473.77 4592.81 4305. :"?:3 4326.90 4:337.06 4:::54 p 61..-. 42:::2a1 7E: 40::;:: l . 0:::: 4077.76 4l ::::~:. 90 41 :~:8. /:.6 :::991 . ~7 :~:~/7:::. E:E: ::::903. 92 3:?71 . ::;:: j :~::3 ~::~:3.. 1. 4 3779.49 ~::;I.IB~::;EA VF.:RTICAL rlEPTH FEET JOB NO: A06:?5G0311 6991.48 7052.01 7069.41 7116"97 7192.44 6965. 6:::: 6b69.Jl 6760.42 6915.5b 6944.43 4451.59 4475.97 4532.77 465).81 A581.29 4341.78 4364.73 438~.90 4396.06 4413.66 4050.~7 4090.02- 4 1 :36" 76 4~.97. 90 4247.66 :~: ':;> (.,:2. ':;1 2 4 (:> :::: :;J . :~: 8 39::::0. ;:: 1 ::::::::37 a J 4 :~: :::: :~: ::::" 4 '~J TRUE=: VERTICAL DEPTH FE¡:':T 8966.00 8989.00 9052.00 9152.00 :::::386. 00 :=:85:~:. 00 :=:781.:.. 00 :3:=:24. 00 :::::~:~:2. 00 :=:4«?00 5330.00 5866.00 ~450.00 5627.00 8346.00 5233uOO 5748.00 5274.00 ~16::'::. 00 ~~:?O 1 . 00 4740.00 4798QOO 48~7.00 4957.00 5080.00 4434"00 4503.00 4~65.00 4612.00 4714"00 ME:ASURF.:D DEPTH FEET B/MK-2 L-8 L-9 PBTD TD !"1~:~R 1 9 T / KUF' I NTEF;VAL T Ir11<:-1 B/I"1K-l T /M~<-2 L. C:RET. I..JNCO!\lF 9 ::¡ / :~: II c.::=:1j \IF CIA OB I\! A Nfl NC ND NE L.A LB ~"A t1B M'-: ,-'PI K?) KB I<C KD -------MARKER------- ------- CODE ------- ------- NAME ------- CONoeo, I NC . PAD B7 l.-.JELL NO: 15 GMS M I L \IE PT., NORTH ~::a.OPE, ALASKA Ò~\~':iY. _u.. "t.~~ -1 - -, ~ "." ,'" -, .'. CON Dca. 1 HC. PAD 8, WELL NO' 15 GMS r1.I LNE PT.. t NORTH SLOPE '" ALASKA EASTMAN WHIPSTOCK. INC. FINAL STATION' DEPTH 9152 MD. 7192.44 TVD SOUTH 5068.53 EAST 255.03 CLOSURE 5074.94 S 2 52 50 E UAtA rlL~' d2~~6 HORIZONTAL PROJECTION SCALE 1 IN. · 1000 FEET DEPTH .INDICATORc TVD 5246 5953 6698 3885 4567 ,- , CLOSURE 5074.94 S 2 52 50 E 6000 2000 4000 VERTICAL SECTION 9000 o 8000 2000 -i ;u C (TI < (TI ::::0 4000 ...... - (") :> r 0 (TI -c -i ::I: 6000 o EASTMAN WHIPSTOCK. INC. VERTICAL PROJECTION SCALE 1, 'I N. · :2000 FEET . ~ I r , CONOCO. INC. PAD B. WELL NO: 15 GMS . MILNE PT., NO~TH SLOPE. ALASKA , , ioI'" I r\ I ¡ '-i-. ....(.::b~o t ¡ t or,. ~. ... ~~--- Suggested form to be inserted in each "Active" well folder to check for ~îmeîy c-o-mp-ri-an-c-e-wiLh-otrr-L'e-gula t ions. ÛJ Ki?C411/ £/N '¡:(1(1; f II. ß-IS OPERATOR, LL AME NUMBER . Reports and Materials to be received by: 7 -a.rz ~ r¡;g- Date Required Completion Report Mud Log ~-PI Core Chips Corê'Descript~on ¡/"#j . Date Received Remarks - cJ I< .-r . - \"~'fi=4= ÎÌ1~~Ji1firtl-oiÍ/s~'rV'~~ '0 -. (J J.-- f) ~. .~~:5 ~ .()I< Directional Survey Drill Stem Test Reports Production Test Reports PerF¿b¿¡f Log Run . A.. . ðl< ð' ();< Digitized Data ~ L.FJ.04 WEll B-II 8-12 8 - ß e -14 8'1~ B'16 6-'7 .,. 9·G~ ~.9·~ - 9.2-+ "-9'~ -- .Jrt- ~_9A 9' \ .... ~ ~. ~_ 9·\2 e~ ...8'\1'\ B·7~ .. 9"~ e-\\ ~ ~-e"(,( ~-9"~ 9-9'-'- 8'\~ - . [] SIMPS"':' LAGOON N l ~~ "'1 tq4", .þ .. -~ pyt;:: .':!. Y~~!!!~P.~~~... ..... "'-1 rf... ? ~ .-r--;-~ · ;0~ -Ç sD-:-~" ~~* t' n " ~ \, ~/~'~ ~ \~" ~ I~ . ~I '"'" '1 'J:J 2A ~ ,. 21 U A c:;, I "~ 21 ! "'nJ ,\ , ~~ ¿/.' 2~ 17 1'- þ~ [ 'D 05 l' n N A fr , H '" '0 ~ ,,' " 31 n ,~ ~ )1 ).:'. " L.~~... .)2 T " '" 'T 12 ..., ... ...... ,., III ,. 2 III III ~ . , J TIJ~ !! = "'- - . . L-.:-. ' SCALE IN MILES CONoeo MIL NE EXISTlNC POINT UNIT DE VELOPM E NT SEC. 18 SEC. 19 NOTf:S: I. ST .,.[ PLANE CO·ORDINA.TES ARE lONE... Z. ALL GEODETIC POSITIONS ARE BA.SED ON N.A.D. 1927. - 3. OffSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES DF THE SE cnON COR NE R POSITIONS. 4. LOCATED WITHIN SECTION 18 619, TIJ N, RIIE,U.M.,AK. LOCATION IH S(CTlOH STATE PLANE CO-QRDS. GEODETIC POSITION '-RO~S.lI~[ fROM w. LINE NORTHINGS EASTlNGS LATITuDE LONG IT UDE DAT( CHECI(EO "[LO BOOK 464' 790' 70°28' 29.019" N. 149°24' 46.703" W. . 6 ,023,586.20 ~7J ,864. 47 6. 2 ,8~ J.B. S. 21-8~ 76~' 920' 6 ,023,888.56 571,992.42 1ff 28' 31 .981N N. 149°24' 42.854"W. 6.2,8~ J.B. S. 21-85 532' 979' 6 ,023,656.07 572 .D~2.77 roO 28' 29.6SSwN. 149°24' 41.146" W. 6.2, 85 J.B.S. 21-85 I Ç/7Ç 9'1f ' t;,oD,o 11.7' CE'ìT"'CI.T[ Of SURV£YOR: I H(UEB'f C[JH'fY THAT I AM PROPERLY R [ C.I 5 1( RED A "J D LI C UJ SED TOP R ACT I C ( LAND SUJivfYING IN TH[ STAT[ or e.Lt.SKA AND T H~T THIS PLAT R[PH[S[ NT S A LOCLTION ~URV(Y þ,AAD( flY M[ OR UND[R My ~UPlJ¡""SION. MJD THAT All DIM[NSIONS A"'D OTH(R OfTAtLt AH[ CORRECT. - . ____ __ _h____.__.________"__ ~ 72, 0 /3· ., 2. 70 · .28' :U. 3 ; $" Ñ Ill'" ,J y' '0.1('17" ~ ----. .-- KtLtlVtU '... ~~~'~,~~\\ AUG 2 ,.,., -: 0 F A ( A ~~ ~ ::\ ~ oeGOlOl.C'() <-~,r ~'-:rt (.ø~I!·~øøcetl A1cì. "" SKa::~GU;~) r(1as /-!i .~.... ~:'q "0 <~ A~-ho .. '(t ...0''' ~ r'\ L:i?-,' [Ie "I,~ tJl 0 {;f.- ':;} T~1 1:'-". ". :\ II 1! '¡-' ~."./.~~'~';::.:7?::::; ~.~ é'::~t:~ðeo.."'.,.o."ø.....o:J.. !: "ß -:p "i " v. ~.J¡ ~ ~ Bernard Tomu!ich · f§ ¿¿' t', ÇJ · 0 , tØf ~~~ &e L.S. #3793 S 0" ~¡;; tØ \It, <1><,°et',.. "Q."~Q::. ø ~_ \() P ·"~e'.'ectøe~ ,,~\) ~ ~ ~ í?OFfSSIONf\L \..~~ ~,,'-.~~..:..~~~ 181 PAD 1985 .£:"f ~I{ 1š aSSDft AS, BUILT W(LL LDCATlOH S\l'~rJr( fo. CONoeD SC.\L[ : 1- · 400' SH(ET' 2 0'- " -- [NGINE [ RS AND CO"'µ[NTS I L ANO 5t1~V! YOJó [)'''''['''SIO''l THUS'''' HH)M N, LI~l ~ l ( T ,~. A l. Lor 1'1 [ R S , R 0"" S L "I t L[( T_ 1ft, _ m_,_ __., . - -- ---- - -_._-~.----- - --~-- ------._- ., - -. -- - ---- -- --.__. .. GEARHART iiJ]JEE]l. 'j¡~/;/",I;, GEARHART INDUSTRIES, INC. CUSTOMER CONOCO, INC. FIELD MILNE POINT NORTH SLOPE ALASKA County State CDL/CNS RAW WEL Type'of Logs Distributed O/H, DIL, CDL, CDL/CNS Well Name !'-~ILNE POINT B-15 Date 7-17-85 Date Job Ran6-24- 85 Blue Line 1 Sepia Pre-Fold 0 Rolled Logs mailed to: COMPANYbLASKA,OIL ~~D GAS PERSON WILLIAM VAN ALEN ADDRESS 3001 PORCUPINE DRIVE CRRR# \15 %~q (p~ ~ PRINTS MAILED FROM GEARHART INDUSTRIES DISTRIBUTED BY TESSIE HORNBECK 211/100· TYPE WEL GR/CNS/CSNG , DIL CDL/CNS RAW CDL/CNS i1:lr DEPTH BonOH DEPTH 7800 3600 5600 ~6UU 5600 9075 5650 9078 ~0~5 9055 511/100· TYPE ~ WEL G.H.lCNS DIL CDL/CNS CDL/ ellS 7800 _, 3 6 0 0 - ....,--:> b U U 9075 5650 9078 9055 9055 RA\"T 5600 5600 Please date and sign and return in the enclosed self-addressed and return to ConocD. ~ n; fJj (\?S t~('I~.3. I\\'?~.\','ð. \j,\ \-. J-....¿:l....... NO. OF LIS TAPE~ 1 SIGNED 1ió ~;zçfL - O-O¡;eÞ - 35'9 ~-9//õJ.. DATED 139 East 51st St., Suite 102 Po. Box 102436 Anchorage, AK 99510 Telephone (907) 562-2538 ~--------------~--- ----~--- STATE OF ALASKA ALASKA G._ AND GAS CONSERVATION CO~, ,IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well IXJ Workover operation 0 2. Name of operator Conoeo Inc. 3. Address 3201 "C" Street, Ste. 200 4. Location of Well at su rface 7. Permit No. 85-121 8. API Number 50- 029-21374 9. Unit or Lease Name 300' FSL, 1037' FWL, Sec. 18, T13N, RIlE, U.M. Milne Point Unir 10. Well No. R N(')_ 11) 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 16. Lease Designation and Serial No. I::;Q' VR ånT I, 7/. ~Q Kuparuk River Field Kuparuk River For the Month of June ,19~ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud Date: 6-15-85 Depth at end of Month: 9152' RIH, tag fish @ 8790' (6-26-85) POOH w/fish. 13. Casing or liner rlJn and quantities of cement, results of pressur'3 tests Ran 143 jts. 9 5/8" 36# K-55 Butt esg. Pumped 56 bbls. 15.8 ppg Class G Cmt. w/.2% D-46, 3% NaCl Ran 231 jts. 7" 2611 L-80 Butt esg. Pump 56 bbls. 15.8 ppg Class G Cmt. w/.8% D-60, .2% D-46, .25% D-13. 14, Coring resume and brief description None 15. Logs run and depth where run DIL 9079' to 5625' GR-CNL 5625' to 3600' Laser Log 9079' to 7800' Gyro from surface to 9000' CCL-GR 8550' to 8950' GR-CCL 16, DST data, perforating data, shows of H2S, miscellaneous data 1 11 r L t, \~ 1. ~ LJ None \ U \ t::; l ::;:}5 ¡(\\ciSK3 01\ (~ C~(t~_~ {.~U¡I~I. i\ncr;~)r:)U(; (;(JJ!li i! I: don 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I SIGNED ~ J !l..s~ NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. TITLE ~rYr,. ~~L [¿"'J 1'. DATE 1/17IJ~ Form 10-404 Submit in duplicate I MEMO~A~JUM StatE;, of Alaska ALAS~ ûIL AND GAS CONSERVATION CO}~IISSION TO: Ç';ì. ....01 c. V:L.C~.. erton Chai~A.---- Lonnie C . Smith /] ì'lJ Commissioner T Doug Amos ~~ Petroleum Inspector DATE: July 16, 1985 D.ADA.25 FILE NO: THRU: TELEPHONE NO: FROM: SUBJECT: BOPE Test Conoeo's HPU B-15 vJell, Permit No. 85-121, Kuparuk River Field. Wednesday, June 19, 1985: I traveled this date from Prudhoe Bay to Milne Pt. to witness the BOPE test at Conoco's B-15 well. Thursday, June 20, 1985: The testing commenced at 10:00 pm and was concluded at 1:00 am, June 21, 1985. The lower pipe rams accumulator master panel switch failed, but was repaired and function tested during this test. In summary, I witnessed the BOPE test at Conoea's Milne Pt. B-15 w·ell. Attachment 02-001 A(Rev 10/79) O&G #4 4/80 D' C1 vHOfÎ c::L (!"'h y!',¿; ft-p., 0 £ :~ µè"'S'~'1! "n. £'1'" 'f> . STA'rE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report tfu T) . '5)' ItJ', OD fl· fl1-~ I " 00 A,J/ J - -------------- -- . Inspector Operator Well ÐðUC) ~D5 Co no CO ß-15 Sec 113 Date JIA n'é!... 2-D) Jc¡ÆS Well ¡, - I .s iJi;'¡ III! fJ., U ;1 ; t ,.. . Representative /<o\-/ J2c;bJn..so}1 I Permit # 85-/ ZJ ./': 5¡¡I!J / I ~Casing Set @ 5~z.s Z Î e Representativ ACCUMULATOR SYSTEM Location: T /3NR I;e l'l Ú. ItA f Nt::( 6oý':) Drilling Contractor Location, General Rig # {)J(' . Well Sign General Housekeeping Reserve pit Rig ðK Full Charge Pres sure 3 / co 0 ps ig } Pressure After Closure I 40 tJ psig o 200 psig Above Precharge Attained~min~se( F~ll Charge Pressure Attained: / min~se( psig Of~ " N2 ZZ-C¢¡ì ¿IOO} 2'2Z--~ LléJO Controls: Master () k::: * Remote ð Blinds switch cover BOPE Stack Kellv and Floor Safety Valves / . VTest Pressure ,42 Lower Kelly / ~ Tes t Pres sure Ball Type I ti=-Test Pressure Ins ide BOP I vr-Tes t Pres sure Choke Manifold ~est Pressure If II I { Tes t Pres sure ~' 000 , / Annular Preventer Upper Kelly Pipe Rams Blind Rams Choke Line Valves ··vrvr~ H.C.R. Valve v(" vY .1- Kill Line Valves ~;V~ II ! ! {I n I I No. Valves 18 Check Valve 'I No. flanges Adjustable Chokes Hydrauically operated choke 7 -:-:3 . 8 Tes~ .Kesul~s: ,t'al.lures Tes t T l.me ....=:5 hrs. / Repair or Replacement of failed equipment to be made within / day, and III/I Inspector/Commission off ice notified. III Remarks: '* Lowev {J'.fJe' mm ~ ¡;,¡ '/ e-d -/0 610s e c?J'¡.¡j¡~ l' CC,-< /y] "1 fA~./ I f ..- .. . ' I~r; r ~~:1~~;' ~ /. A./~:t-, ~;> ~0 r¡;  ~ e~~4 :::; +~~" ;M"%f, Distribution or ig. - AO&GCC· cc - Operator cc - Supervisor Inspector ~{rA h~ / ' Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal 1-later Pollution Control Act, as amended. Pri.or to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. f.1any rivers in Alaska and their drainage systems have been classified as important for the spaŸm.ing or migration of anadromous fish. ODerations in these areas are sub;ect to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core i.s required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Enclosed is the approved application for permit to drill the above referenced well. De ar }!r. Hand: Re: Milne Point Unit No. B-15 Canoeo Inc. Permit No. 85-121 Sur. Loc. 300'FSL, l037'FWL, Sec. 18, T13N, RIlE, UM. Btmhole Loe. 4865'FNL, 3950tFEL, Sec. 19, T13N, RIlE, Tn1. ì~. James R. Hand Engineer Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 June 12, 1985 cc: Department of Fish & Gamet Habitat Section w/o encl. Department of Envi.ron.mental Conservation w/a encl. Hr. Doug L. Lowery Enclosure be BY OF~ER OF THE COMMISSION Very trul~f~' .r ð ~ /J //// ¿ I ,·')F t~ \ f/A. ¡, 1¡4~'/'ß;;-7:ì '~>__~ / "'-___._), u>-) 1.f:-->7¿/ " C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission In the event of suspension or abandonmentt please give this office adequate advance notification so that we may have a witness present. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Corm:n5.ssfon may be present to witness testing of the equipment before the surface casing shoe is drilled. ~~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. J un e 1 2, 1. q 85 -2- :Hr. James Hand Milne Point Unit B-15 (con'""~ John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 ') June 10, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill application for Milne Point B-15. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, please call Jim Hand at 564-7640. Very truly yours, Kemp of Alaskan Operations JRH/vv cc: MP B-15 Correpondence File n í~' r C ¡ .. If I r"? ¡''< r { r! \¡ to' 3) . '". ", ~ .~, . \I I~ t. ¡ ¡ í i'" ., "jitïH, ,., U I \j t ,..1 c',::Jo,,J þ,\fjski:i 011 (;~ \i:s Con;), COliìì1lisSIOti STATE OF ALASKA ALASKA l,1L. AND GAS CONSERVATION CO,.,1V1ISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work. DRILL G REDRILL 0 DEEPEN D 1b. Type of well EXPLORATORY D DEVELOPMENT OIL I;j DEVELOPMENT GAS D SERVICE D STRATIGRAPHIC D SINGLE ZONE D MULTIPLE ZONE D 2. Name of operator Conoco Inc. 3. Address 3201 "C" Street, Suite 200, Anchorage, p.K. 4. Location of well at surface 99503 j J I-~~d _~r~. ~ ;/ L~. _~-",":>.~ ,'" ( ", 'c ( '/' J 9, Unit or lease name j¿~>&,. i '</."'</") Milne Point Unit . f . . Well number B No. 11. Field and pool 15 300' FSL, 1037' FWL, Sec 18, T13N, R11E, U.M. At top of proposed producing interval 4700' FNL, 3950'FEL, Sec 19, T13N,R11E, U.M. At tota I depth Á(10:::fq. G 4865' FNL, 3950' FEL, Sec 19, TI3N, RIlE, D.M. 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. /-.!/l(~.;'v r:/'c:~'v: t/f.? /1 ""'01' . KB 59' Pad 24' ADL 47438 Ku aruk River 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15- 54 13. Distance and direction from nearest town 14. Distance to nearest property or lease line miles 580' at Taret feet 17. Number of acres in lease Amount $200 000.00 15. Distance to nearest drilling or completed well B- 3 feet 18. Approximate spud date 33 mi ~M of Deadhorse 16. Proposed depth (MD & TVD) 9,019 MD 7112'TVD feet 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 2 544 6 11 85 3100 psig@_-t!B-º-F'Surface 3700 psig@ 7112 ft. TD (TVD) 20. Anticipated pressures MAXIMUM HOLE ANGLE 42.1 (see 20 AAC 25.035 (c) (2) SIZE Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH Weight Grade MD TOP TVD MD BOTTOM TVD 48 36 QUANTITY OF CEMENT (include stage data) Hole 26 L-80 BTRS 8984' 35' 35' 90191 7112' ±275 sks ±180 sks ± 60 BBL Class G Perm Cmt Arctic Pak I Conoco Inc. proposes drilling the subject well as a delineation well in the Kuparuk River field. Mud system wi 1 be non-dispersed, low solids with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.2 ppg. A 20" 2000 psig diverter will be installed on the 13 3/8" conductor for driUi ing the surface hole. A 13 3/8" 5000 psig RSRRA BOPE stack will be used on surface casing. Pressure tests wili be performed as per State Regulations. Maximum anticipated surface pressure was based on a fluid column at T.D of 80% gas and 20% oil. Casing will be pressure tested tò 1500 psig. B No. 15 is no closer than 78' to B No 3 The B-15 well will cross over the B-3 well as it is drilled in a southeast direction. Arctic pak will be place in the 71i X 9 5/8" annulus after disposing of test oil and excess drilling fluid. The perforating élnd completi n assemblies will be run in the well before releasing the drilling rig. The perforating guns will be detonated a d the well flow tested once the drilling rig has moved off location. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge ! 22. Describe proposed program: SIGNED /?~ TITLE En in e DATE The space b ow for Commission use CONDITIONS OF APPROVAL Samples required DYES 'fSNO Permit number Mud log required DYES ØNo Directional Survey required ¡&yES DNO API number 50- (, l-C[ ~ 1....-1 37'-( APPROVED BY SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER by order of the Commission DATE June 12, 1985 Form 10-401 Rev. 7-1-80 Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. B-15 Conoco Inc. 3201 "c" Street, Suite 200 Anchorage, Alaska 99503 I. CEMENTING PROGRAM A. The 13-3/8" conductor will be set at 80' below the surfac.e (115' K.B.), then cemented to the surface with permafrost cement. B. The 9-5/8" surface casing will be cemented with ±1535 sacks of Permafrost cement follmved by ±275 sacks of Class "G" cement. A top job will be done if cement is not circu],ated to the surface. C. The 7" production casing will be cemented in two stages. The first stage will consist of ±275 sacks of Class "G" cement pumpeà around the casing shoe (estimated ±llOO' of annular cement, based on 100% excess over gauge hole). The secondary cement job will consist of ±180 sacks of permafrost type 'c' cement followed by 60± barrels of Arctic Pack pumped down the 7" x 9 5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, clay, silt and sand sequences. Estimated base of permafrost at ±1700'. 4500' - TD Predominately shale until the Kuparuk Sands - expected at ±6770' subsea TVD. III. FOP~lliTION EVALUATION A. ~'¡ireline logs for the 8~fi hole (from T. D. to ±1000' above the Kuparuk interval) wi].l include: Dual Induction Jog; Spherically Focused log; Litho Density log; Compensated Neutron log - Gamma Ray. IV. DRILLING FLUIDS A high viscosity fresh water gel (non-dispersed) mud system will be used from 0'-1000'. r~: L (, l' ,J ~~: t EfJ ~ ": ~ ' . I .. .! ) hI ( i t t) b :.; /\18S;<'(ì Uil 84 Gus CUllS. COUI!I!!0(;¡0I~ /\: l~~h,.Jj ~"~qr~ A low solids non-dispersed gel/w'ater mud system will be used from lOOO'-Surf. Csg. Pt. Low solids lightly dispersed mud system 5730'-T.D. v. DIRECTIONAL PROGRAM The B-15 well will be drilled to a proposed KOP of 500', then build angle in a south 2.6° east direction. The closest that the B-15 will come to another wellbore is at ±1790 M.D., where the proposed B-15 ,·¡ill be 78' west of the existing B-3 well. An MWD tool is to be run while drilling for surveying purposes. Final hole angle will be 42.1°. * The proposed depth is an estimate only. If actual depth exceeds the permit depth by over 300', a Sundry Notice will be submitted. 0( F' (~ I·: i ~~J - '.', '., f') !: ,{; ¡ P,! , , SIMPSON LAGOON ~-. ." N t ~~~ '~1 ~~ ~ ~3 I U .. , l ;' . -. ,. /' ~ A -0- ~"'-\ 1 Ç.~ .þ ~ f~~~f:..r:r.·· ~~,:!~!~.~!..--. -.......... ~...- ì " ,.1.. <1>---- ,~ I:~ ~:í(çf~T\" \1 .. ·1,. 2> I n I ~\I~p l ,~ I .. I n ¡ \: :Q\; \a\ ~7\%~þ~£\ ~\;~: ~~L\ u i 31 I 3Z \~, I 3A I ~ ~ \ ~I 3' \ niB I T 1~ U ............ .-......... . TIZIoI \ '" .. 2 :: ",... I' . . . . . . . III IU ~ 2 M. Ci 2 , ~ SCALE. J" MI1.£S' cor:oco I \ '. MILNE POINT UNIT EXISTING OEVELOPMENT' ~.18 SEC. l:r . . NOTE!;~ t. STATE PLANE CO.ORDINAT~S ARE ZONE ~. Z. ALL GEODETIC POSITIONS ARE BASED ON N.A.O. 1'327. 3. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. , LDC.l.TIOH L'f ~t:CTZOP( tTJ..TE PLl.H!: CO-oROS. töEOOETIC POSITIOH Ii ~'!LL t 'RQV~. ll"H.l f"'P.~ w. UNE I ~ORTHJNGS EASTING5 LATITUDE t..Qt;Gli UDt CH(()(ED \F'I!:LD BOOK ,; 5-7 , . ':;¡ f, . ïfdJ t (,vZ'3,7oz, "'9 I 571,&3421 ìo··U'- 30,\ b& ~ \ 14Q: 24'.47 C:f:-a w I II·~-U I J. U . I . . ~ II I i~~ , G. OZ3 . SSß. '3& I 571. "'3Z.4~' . I £, t . I \ --;~. M I , \ \ a-IZ ~ZO 70·"2.ß-SI.c.J 11.1 14Q.'Z.4 -42.ßS4w J. }I . .. - e- n , 532' -~7<3 &,D23 GSC:r3b , S720Sê .'1~ 70'· z.~'. 2.9.{,91 \oJ t 14~·. 2.1'-41,1..11 ~ , . -II -~- &41 J .-H. \." ..-- --: . I 9·14 t C;~'. ,~SO· , ". oz3 ,ï72.¿ï ~ 572 022.6& 70#-Z3-30.83b..,¡ I IAq: '24 '-41. CJ9!:, ~ 1\ -3-84 t J. ~- ~ ,~- .. I B"~ t 3co 1D37:- Go 023424..12>." , 572. \13. 4S , 7D#~ '2ß'-Z7. 4DI, '4.Q~~ -;Q.::.U I.J t 1I~'-:;-ð.11 J·}.{·-I..;. .- B"". , .dJ ç: toaS!, C. ozj 5~.2S I S72083.2o 7D-.Zß'-2S,SM..·' L:::JQ··Zd'-4I) ~S~~ 1I--3-8A I J. H . . f B- ., . B- ~. . -' ~ Ct~T¡rICLTt 0' 'SURVEYOR: · at PAD f.. ~n: i T~ '\~'t' UTI I ñJl -r: H S S n TI1 4.S-64HLT 'W'I'LL1.. .1....OCJ..TS{)t( . ..[ACe'" c.tR'TlfY ~M.U J J,.J.A P;¡OP.ER.1..Y "'1'1"(1; r:;-: T 'RD) .A t.I n LLCJ: I ~ S E:..D 70 P RA:: 7 J a: LAIoID ~U~"(Y'NC IN "fWC 5'TAT[ or l.LASKA ..oeo "T....."T "t4,~ p\.&:r FlI:.PR(~t NT Ii " LOCATION ~URVt:" ).tIlD!: BY ....E OR UNDER ...,. l.u"("""~IO~. "-NO ¡HAT ALt.' DIIoA[NSIONS .ucO OTtotCR OCTAILt A~E: CORRECT. S"f_~JC( (01' . caNoca '.. . Ò', . ~ (N(..JN[[RS ""I D l>C1.L( ;~.,\ .- . ~oo' :'>ti([T I '2. 01 2 ,'\Lx~h;~ em L"IoIO ~R"'('rO~ COU .,I£NT$t DIu r oJ SION THUS'1(' f RCt''' . "I. 1111E t(CT. I~, ALL UTti(RS f RO~ S. LIN[ t (C T. I 8 . 6000 2000 3000 4000 VERTICAL SECTION ((£:~@)) 5000 o 1 000 TARGET TVD=6929 TMD=8773 DEP=SOOS -TENTATIVE- TD TVD=7112 TMD=9019 DEP-S170 - _.. --- _~__.__~__ _0_____.._.___ .__. b_ . . AVERAGE ANGLE 42 DEG 3 MIN ------...,. ---- ---- -- ------..- .. -- - --..-.......-~. -- 9 5/8- CSG PT TVD-4669 TMD-S729 DEP=2966 ---_._.~._~----- ---.. ---.... - - ~- -- .- ..- -- -- --_.. . .- - -' - - -- ~ - -- . --.. -. -- . - -.. .--. -~.., r" ._k~__.... 5 10 _. _ __ _~ __ __~ _. -_4 __'_.0 ¥~ .____ ____ _~~. _ _.. ....._.___..... _. _.__ .~__ ._____~. __ _ ........_ __ .___. 15 BUILD 2 1/2 DEG 20 PER 100 FT 25 U ___H_. __ .______._...____. JO 35 ~ fOB ·-TVD=2035 TMD=2182 DEP=590 - -. --- - '-- - .- -- -.-- - ----- ..., - -.. --- KOP TVD=500'TMD-500 DEP=O - ..- ..-... _.----- SURFACE 8000 __ .. __ 7000 _________ 6000 - ----- ~-- .- ,____ __3000 - ~- -I ::0 c: ~ ..2:~~fT1 ____ . -- -...-~:-< --' ", ::0 :: 4000 (') > r- c ITI " -I _____~_ __5000 "- ----.---- - ------ ____>-______2000 -~---------.--. - - - __'n --¡---- - , -- T - --.- - !- _~__~_1 000 --~---- -- --- -- - _ _ __ .0 _____ ____ __ __ ___ - __ _0 __ ~ EASTMAN WHIPSTOCK. INC. ~"'n"'~"'. I.n~. PAD 8. WELL NOe 15 PROPOSED MI LNE PT., NORTH =-~.OPE. ALASKA -- .-...-.----,...... -.,-.....- ~ '- '.. -.1- _1000 o 1000 :z 2000 o ::::0 -t :J: I (I) o c: ~ 3000 4000 5000 C~ 6000 HOR I ZON-- '~L PROJECT I ON SCALE 1 IN. = 1000 FEET CONOCO. INC. PAD 8. WELL NOe 15 PROPOSED MILNE PT.. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. 2000 -WEST-EAST 1000 0 - - ---- CE - - ~- --- TARGET TVD-S929 Ttm-8773 DEP-soas SOUTH 5000 EAST 224 T .__._)._,___._,~~, _.. __. ._~~_. 'u.__.......~"~____.__~. ,_ - - - ______.____ - - __ - ._.___ __ ._ - _d . -- .--j.. _. --- --- ------~--- --- - i --- - ~ - ---- , ,I 1000 2000 ~... -, ~ ~-~ -.-- --..~.--;.- - _._----'.----~ ------!..--~---'- SURFACE LOCATION' 300' FSL. 1037' FWl SEC. 18. TI3N. RIlE ,,.. ._ ,~___..,_.____ ~_. __h__ __ _ __. __ _ __. ".___.. - --0---- ~.._ _ _~ _4 ___ __ . _. ~_ ._ _. . -. -. -- .._..._"_, _._ _ _~._._ ,_n_ __._u_~_,_._..~......_..._____~,._ .'o-~. TARGET LOCATION' 4100' FNL. 3950' FEL SEC. 19. TI3M. RIlE S 2 DEG 34 MIN E 5005' (TO TARGET) , " , . ;" ~ [, j r¡,~. NORTH 300 200 100 100 200 400 ,200 o . . - 100 ..-100 ~ ,._ _u·~~_ _. "-.__.__ . - - -- -- -- ------- --- - -- - 1378 -~._.. ---,,"--.- -~---'"~-""'~.--- --- 1559 .300 .- -._.~- --- - 400 . - ~ > - ---. ---~ . - - . .600 2036 - - -- ---~-~ 700 caNoca, I NC. PAD 8. WELL NOt 15 PROPOSED MILNE PT.. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. " f" t."" I: . NOTEt WELL PATHS EXTEND BEYOND THIS VIEWING WINDOW 800 ''-. k .} {\J~,;::f.8 0\\ f, (n":, U'/i~5- 900 ¡ FROM MUD PUMP NOTE: I. H'J1)RAULlC CONTROL SYSTEW FOR BOP STACK 8 CHOKE WANIFOLD TO INCLUDE {51 STATION CONTROL MANIFOLD LOCATED REMOTELY WITH 3000 PSI ACCUt,(ULA TOR a 160 GAL. RESERVOIR 8 AUX. ENERGY SOURCE. {5 STA. CONTROL MANIFOLD PLUS VARIABLE CHOKE CDNTROl TO BE WCATED ON RIG FLOOR. 2. KILL a CHOKE MANIFOLDS TO MEET API RP53 ct. 5¡'¡ sroS. 3, KIll MANIFOlD SIZE - RATING 2" - 5000 4. CHOKE MANIFOLD SIZE - RATING 3" - 5000 KILL MANIFOLD FROM REMOTE HIGH PRESSURE PUMP ~ GAGE SENSœ HYDRAULIC CONTROLLED REMOTE OPERATED DRILLING SPOOL HYDRAULIC CONTROLLED REMOTE OPERATED .,. REMOTE PRESSURE GAGE SENSOR ADJUSTABLE CHOKE CHOKE MANIFOLD .~~ TO SHALE SHAKER ~ BLEED LINE TO PIT I TO ATMOSPHERIC MUD/GAS SEPARATOR CHOKE a KILL MANIFOLDS FOR 9s/8¡\ a 7" OD CASING [';('1: ¡!Ii ,,,r.no.. ~JJ .~~ 'J, I, J] ~1 u ~' ~ assoc. BOP MANIFOLD LAYOUT - CONOCO, INC. ,......,... ..... I'" .._...- Fill-up Line 2" - 5000 Side Outlets 3" - 5000 Side Outlets Flow Line 13 5/8" - 5000 13 5/8" - 5000 CONOCO INC. MILNE POINT UNIT BOP STACK (1) B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. (2) BOPE to be operated on each trip & pressure tested weekly. (3) Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet API RP 53 class 5M requirements. 3" - 5000 Side Outlets 13 5/8" - 5000 11" - 5000 '.0.. -..... 0' .. . . .. .. ~o ~ . . u .. --. . ø ·.0: .. . ø 3 3/8 - CSG. 0' t.) _ ~.;. ..c.. .~ o .... ... A/Ij;';ka 00 ~j L ,:; ,{~, {'\:i ;;: I' CONOCO INC. MILNE POINT UNIT 20" DIVERTER STACK Fill-up Line Flow Line ·20" 2000 psi Annular Preventer * 6" Relief Line Drilling ) Spool 20" x 20" 2000 psi * 6" Relief Valve <fi Diverter Quick Connect Assembly C\ 17:::,: o ~... .þ " c. "'.; ð:.. co .. co. 6 0:- .. o 1:1 ~ Q <: Saver Sub Assembly ( .. ø · a G ø ø <:> «> . 06- -6 6 ..- 00 . . .0 .. .. C> .. . . .... . ., ~ Starting Head . '. . .. I;) (;I 13 3/8" Casing . (J '. · . 1¡(J{. , It.', ./ . (v/¡, " ~. I). . ~ C\ .., II .. G~i .. ~ . Coo /,~ _ c.../", .., ,"!'J' ..~ ,-.. - , ..-.....~...... o· . . .. 0,. :.. .., ....- .'" ~ .. .. b .. &.,. .. o .. ~ ., 1. Relief lines .from the drilling spool will be routed for downwind diversion. 2. Hydraulic control system will be in accordance with API specifications and AOGCC regulations. 3. Both HCR valves will open when the preventer closes, then either one may be closed. * Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. DRG 7-17-84 Company t~-u Lease & Well No. CHECK LIST FOR NEW WELL P::RMITS ITEM APPROVE DATE t(~ /' ( 1) Fee (¡-I/-f) (2) Loc ft~ ~-) )-Ir I "',{ 2 thru 8) ) ,J . ._--------, --,-- __n______. .æ~ r;;,!JI)gS- (8) Adminþþ-- &~7/-t>/ ~12) . ~ (Dirt f~ç (10 and 12) (4) Casg Æ~fol(IJBtÇ (13 t h ru 21) (3) (5) BOPEæ~ '}1I185 (22 thru 26) (6) Add:æ~ ~/r~(8~ Geology: En~ering: . HWK £ LCS ' BEW~ WVA .. . MTM ~ HJH /" JAL rev: 03/13/85 6.011 YES .~ . Is the permit fee attached .......................................... ~ _ Is well to be located in a defined pool .............................~/ ___ Is well located proper distance from property line ..................' ___ Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ (.~ ___ ..Iª_~~:JJ-_.J;g.._þ_~~~viate(Lan_~..~_~~.~~ore plat included ................ /.___ Is op era tor the only a ff ec t ed part y --~.:_:-:..:-:_~u=-.:_:_._~_:~-=--:~~~_..--:_:-:-:-:--:_:- .- -..__.._~ Can permit be approved before ten-day wait ..........................~ === .> . -- ) . I L L 1), Ii. 1 2. Does'" operator have a bond' in force .................................. d..t-. Is a conservation order' needed ...................................... ~ ¿:1~ Is administrative approval needed ................................... æ Is the: lease number appropriate .. '. . '. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. O~ ___ 13. 1s 'conductor" string provided ........................................ ~ 14. Is enough: é'emeri't u'sëd to circulate on conductor and surface ......... ~ 1.5. Will'ceme,Ii.'t tie in surface and 'intermediate or production strings ... Æ- I~). Wili<'cement cover all known productive horizons ..................... ~ 17. Will surface casing protect fresh water zones ....................... J'.8.- : 3. Will all c'asing givead'equate safety in. collapse, tension and burst.. Æ- 19·. Is this well",to be kicked off from an existing wellbore ............. ___ 151- ¡ O. 'Is old well bore abandonment procedure included on 10-403 .... .'. . . . . . . ----- ;: 1. Is' adequate wèllbore separation proposed .................. '.. · . · . . · .. .tB- >2. Is a di ver-ter sys tern required .... .'~ . . .. .. . . .. . . . ,¡ . .. . . . . . . . ... . . . ~ . . .. ð3 Ate' necessary diagrams'of diverter and BOP equipment attached ....... ~ Does' BOPE have sufficient pressure rating- Test to soot) psig.. t13- Döes:thechoke'manifold'comply w/API RP-53 (Feb. 78).................. Æ- Is the, presence, o~ H2S gas probable ................................. ) 3. ;~ 4. ..5. t. 6. .~,. 7. Additiònal requirements'.. ~ . . . . . . ~ . .; . . . . . . . . . . . .; .. . . .~ . . .. . ... ... . .. . / (J'.v I ) . /0 ../ I S NO REMARKS -- -.-- -~~----_. - ,-~ --,---_. --------.---. - - - .tE- lL Additional Remark's:ß-lr-t,unr ",þ~ '78/ fro^", ß -(3 ðñ¿ (1 f? "roo.. ~ h. e s ' , r .' lOb \. -F'·f'J 1V\..ß - t.¡. +!U?r-oJ@ lJr'@ ",/') ð Me r l'/os~ , INITIAL GEO. UNIT ON/OFF POOL CLASS ST1\'rUS AREA, NO. SHORE · / G 0 { .~ ò ()w /7.;) ,'} ~$ .) Ii ]~ OtJ ."-f./ . ,. - - - - ---------,~- .' t::::I o ~ ::r::z HO CJ)~ ~ ~' :>H C1~ t:tjt:tj H Z . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the VVell History file and to simplify finding information I information of this nature is accumulated at the end of the file under APPENDIX. 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