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Home My WebLink About193-073 STATE OF ALASKA AL ,A OIL AND GAS CONSERVATION COM. SION JUN 22 n(� REPORT OF SUNDRY WELL OPERATIONS 11.Operations Abandon CI Plug Perforations CI Fracture Stimulate CI Pull Tubing❑ 'Operafibns'sfi (down El Performed: Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill El Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well❑ Other: Jet Pump Completion 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 193-073 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20451-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018742 Granite Pt St 18742 42 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,813 feet Plugs measured N/A feet true vertical 9,794 feet Junk measured 9,925,9,943&11,20C feet Effective Depth measured 9,943 feet Packer measured N/A feet true vertical 8,027 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 1,220' 18-5/8" 1,220' 1,219' Surface 4,135' 13-3/8" 4,135' 3,615' 3,450 psi 1,950 psi Intermediate 10,321' 9-5/8" 10,321' 8,390' 7,930 psi 6,620 psi Liner 1,717' 7-5/8" 11,708' 9,726' 12,260 psi 11,060 psi Slotted Liner 1,075' 3-1/2" 11,622' 9,640' Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet LS-2-7/8" 6.5#/L-80 9,850'(MD) 7,938'(TVD) Tubing(size,grade,measured and true vertical depth) SS-2-7/8"&2-3/8" 6.5#&4.6#/L-80 9,814'(MD) 7,903'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): 1� N/A Treatment descriptions including volumes used and final pressure. �`„NNED ' ?.01i3 jh N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation: 81 387 8 115 72 Subsequent to operation: 18 15 27 76 69 14.Attachments(required per 20 AAC 25 070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-137 Contact Ted Kramer Email tkramerCa)hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature 1C#1l/ -" --- - Phone (907)777-8420 Date 6/22/2015 7_6 -/5 RBDM9� LI - 1 2015 Form 10-404 Revised 5/2015 Z( Submit Original Only Bruce Platform SCHEMATIC Well No. 42-42 Completed: 05/21/2015 Hilcoru Alaska,LLC CASING AND TUBING DETAIL API#50-733-20451-00 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head =44.30' 18-5/8" 87.5# X-56 Dril-Quip 17.755" Surface 1,220' 13-3/8" 68# K-55 Butt. 12.415" Surface 4,135' 1. 9-5/8" 53.5# L-80 Butt. 8.535" Surface 10,321' 7 5/8"Liner 39# LATERAL 3.5"Slotted Liner P 110 FL 45 6.625" 9,991' 11,708' t TD - 11,813' EZSV 11,669' Window @10,515'to 10,526' ECP Pkr Top @ 10,547' 9.3# L 80 Butt. 2.992" 10,547' 11,622' TD- 11,655' TUBING Long String 2-7/8" 6.5 L 80 EUE 2.441 Surf 9,850' s Short String P 2-7/8" 6.5 L-80 EUE 2.441 Surf 9,807' 2-3/8" 4.6 L-80 Sprmx SC 1.995 9,807' 9,814' t a 3JEWELRY DETAIL , NO. Depth ID OD Item 44.30' Tubing Hanger,MB-107,Dual,13-5/8"x 3-1/2" 1 9,815' Kobe 2.5" MVSR Cavity 2 9,850' Mule Shoe 1 • - Short String A A 9,807' 2.441 3.680 2-7/8"EUE x 2-3/8"Suprmx BxP X-over 1� 1 B B 9,814' 2.250 5.563 Kobe 2.5"MVSR Cavity IIIMIr_uu -_.I. • Ash 2 NO. Depth Length Item 6:046C (Too) C 9,925' - Partial KOBE Cavity X 1 D 9,943' 1,724' 11/18/99-Cut off TCP gun assembly @ 9,942'-appears L • , it only dropped 1'according to well service reports E 11,200' 297' 9-1/2 jts.of 2-1/16",3.25#,CS Hydril tubing fish inside ECP .D. the 3-1/2"lateral's slotted liner. Cut off top @ 11,200' Packer •. D Top @ +r • 10,547' -,,,► Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(ND) Amt SPF Date Comments 4-5/8"Vann lot C-3 10,310' 10,402' 8,380' 8,468' 92' 6 11/4/1993 TCP Guns 4-5/8"Vann C-5 10,561' 10,700' 8,618' 8,748' 139' 6 11/4/1993 TCP Guns E 4-5/8"Vann • C 6 10,980' 11,000' 9,009' 9,028' 20' 6 11/4/1993 TCP Guns 4-5/8"Vann 0 .,, C-7 11,075' 11,135' 9,099' 9,156' 60' 4 11/4/1993 TCP Guns 4-5/8"Vann C-7 11,176' 11,400' 9,196' 9,418' 224' 4 11/4/1993 TCP Guns "` • 4-5/8"Vann C-7 11,418' 11,440' 9,436' 9,458' 22' 4 11/4/1993 TCP Guns ' «' 4-5/8"Vann w C-7 11,470' 11,552' 9,488' 9,570' 82' 4 11/4/1993 TCP Guns 4-5/8"Vann `,rk.1 4 C-7 11,612' 11,662' 9,630' 9,680' 50' 4 11/4/1993 TCP Guns TD @ 11,813' EZSV Set(a 11,669' Updated: 06/19/15 by 1LL Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #42 50-733-20451-00 193-073 4/24/15 5/21/15 Daily Operations: 04/24/15 - Friday RIGGING UP. COIL BOPE WITNESS WAIVED BY JIM REGG ON 4/24/15 @ 1730 HRS BY E-MAIL. 04/25/15 -Saturday REVERSE OUT OIL MASTER JET PUMP WITH PRODUCTION. R/U PUMP LINES TO PUMP DOWN 2" COIL TUBING CATCHING RETURNS UP CT ANNULUS TO PRODUCTION. PUMP TOTAL OF 115 BBLS OF 6% KCL& ESTABLISHED CLEAN RETURNS. R/D PUMP LINES. SPOT SLICK LINE & R/U LUBRICATOR.TEST LUBRICATOR TO 1500 PSI. P/U & RIH WITH 1.5" AD2 STOP, BEAT DOWN &SET INSIDE PUMP CAVITY @ 9,842' SLM. POOH SHEAR PIN, DID NOT SHEAR. CHANGE SHEAR PIN, RIH TO 9,842' SLM, BEAT DOWN & SET AD2 STOP INSIDE PUMP CAVITY. POOH, P/U 1.5" PACKOFF PLUG & RIH SAME, SET SAME @ 9,841', POOH. P/U A-STOP & RIH, SET&SHEAR OFF @ 9,840' SLM. POOH SAME. R/D LUBRICATOR. N/D PRODUCTION FLOW-LINE & UPPER BLOCK VALVE. FLANGE UP TO MASTER VALVE &TEST COIL AGAINST PACKOFF PLUG TO 2500 PSI, HELD SAME. N/D BOWEN FLANGE. N/U 3-1/16' X 4-5/8" 5M ADAPTOR FLANGE WITH 4-5/8" 5M RISER & COIL TUBING 4- 5/8" BOP. TEST BOP & RISER TO 250 LOW& 2500 HIGH ON CHART AGAINST PACKOFF PLUG. ATTEMPT TO R/U ON LONG STRING, MASTER VALVE NOT HOLDING FULLY CLOSED. WORK WITH PRODUCTION & PUMP HIGH PRESSURE GREASE. INSTALL PUMP IN FLANGE & RECORD PRESSURE. 270 PSI ON LONG STRING TUBING & 70 PSI ON TUBING ANNULUS. BLOW DOWN SAME. MIX 110 BBLS OF 8.6 PPG 6% KCL. PUMP 120 BBLS OF 6% KCL 8.6 PPG DOWN LONG STRING TUBING. OPEN TUBING & LONG STRING ON VACUUM. MONITOR TUBING ANNULUS THRU GAS BUSTER, GETTING LIGHT GAS BACK. BUILD 120 BBLS OF 6% KCL 8.6PPG WHILE MONITORING WELL. GAS RETURNS SLOWED TO MINIMAL AFTER 1 HOUR MONITORING. 04/26/15-Sunday MIX& PUMP 100 BBLS OF 6%8.6 PPG KCL DOWN 3-1/2" X 9-5/8" LONG &SHORT STRING ANNULUS. MONITOR LONG STRING TUBING &TUBING ANNULUS, WELL STATIC. N/D MASTER VALVE FROM COIL TUBING HANGER, REMOVE COIL BOP & RISER ASSEMBLY. REMOVE W-LEG FROM COIL STUB & ENGAGE COIL WITH 2" SHORT CATCH OVERSHOT. PULL 62K &SEALS COME FREE FROM PBR. PULL COIL TO TOP DECK, COIL STRING WEIGHT 33K. STRIP OVER WITH COIL TUBING BOP & RISER, N/U 3-1/8" MASTER VALVE FLANGE TO COIL HANGER FLANGE. R/U SCAFFOLDING & EQUIP. TO L/D COIL TUBING. POOH CUTTING & L/D 2" 3.95#COIL TUBING IN 40' SECTIONS ACROSS DECK.TOTAL OF 4810' LAID DOWN @ 0600 HRS. TOTAL OF 139 BBLS ADDED TO WELL LAST 24 HRS. 04/27/15- Monday CONTINUE POOH, CUTTING & LAYING DOWN 2" 3.9#COIL TUBING IN 40' SECTIONS. L/D TOTAL OF 9,900' +/-OF 2" 3.9# COIL TUBING WITH COIL CONNECTOR,JET PUMP CAVITY, &SEAL ASSEMBLY. R/D TOOLS& SCAFFOLDING EQUIPMENT. WASH &CLEAN DECK AREA. MOVE &SPOT CATWALK. PUMP 20 BBLS OF 6% KCL DOWN LONG &SHORT STRING TUBING. SET BPV INSIDE EACH. N/D 3-1/8" DUAL PRODUCTION TREE WITH 13-5/8" 5M GRAYLOC ADAPTOR. BOPE TEST WITNESS WAIVED BY JIM REGG IN E-MAIL ON 4/27/15 @ 18:37 HRS.TOTAL OF 75 BBLS OF 8.6 PPG 6% KCL ADDED TO WELL LAST 24 HRS. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #42 50-733-20451-00 193-073 4/24/15 5/21/15 Daily Operations: 04/28/15-Tuesday N/D 3-1/8" DUAL PRODUCTION TREE WITH GRAYLOCK ADAPTOR FLANGE. CLEAN HANGER LIFTING THREADS& PREP TO PULL. N/U GRAYLOCK ADAPTOR FLANGE, 13-5/8" 5M RISER, MUD CROSS, DOUBLE BOP, & HYDRIL. HOOK UP BOP KOOMEY LINES & PRESSURE UP SYSTEM. OPEN PIPE RAM CAVITY& INSTALL 2-7/8" X 5" RAM BLOCKS. R/U RIG FLOOR, HAND RAILS, & WIND WALLS. P/U 3-1/2" TEST ASSEMBLY& M/U SAME ON SHORT STRING. ATTEMPT TO SHELL TEST BOP, FOUND LEAKS BETWEEN MUD CROSS & BOP FLANGE. TIGHTEN FLANGE. UNIBOLT CONNECTION LEAKING, CHANGE OUT SEAL RING & MAKE BACK UP. TEST 13-5/8" 5M BOPE WITH 3-1/2" TUBING PER SUNDRY TO 250 LOW& 2500 HIGH ON CHART FOR 5 MINUTES EACH TEST.TEST WITNESS WAIVED BY JIM REGG,AOGCC. L/D TEST ASSEMBLY, PULL 2-WAY CHECK. R/U E-LINE. RIH ON SHORT STRING TO CUT TUBING WITH 1.813"JET CUTTER. 04/29/15 -Wednesday RIH ON SHORT STRING WITH 1-11/16" COLLAR LOCATOR ON E-LINE TO 9,820' &TAG SAME INSIDE PBR. UNABLE TO GET DEEPER. POOH & R/U ON LONG STRING. RIH WITH 1-11/16" CCL TO 9,950', LOG THRU KOBE &X-OVER SUB, POOH & P/U 2.5" RTC. RIH & LOG ON DEPTH, CUT 3.5" TUBING AT 9,905' (7' ABOVE KOBE ASSEMBLY). GOOD INDICATION SHOT FIRED. POOH &SET E-LINE TO SIDE. ATTEMPT TO PULL LONG STRING HANGER, HAD GAS ON ANNULUS, BLEED OFF MINIMAL GAS THRU GAS BUSTER. PULL 55K OVER STRING WT WORKING PIPE WITH NO PIPE MOVEMENT. HAD 3.5" OF STRETCH WITH 20K OVER, 16" OF STRETCH WITH 55K OVER INDICATING PIPE HUNG UP OR POSSIBLY TWISTED @ 1,883'. CALL HILCORP ENGINEER & DISCUSS OPTIONS. DECISION MADE TO PULL PIPE IN DUALS. CALL OUT WEATHERFORD FOR DUAL HANDLING EQUIPMENT&SET HANGER BACK INTO BOWL. R/D E-LINE, ATTEMPT TO RUN IN HOLD DOWN PINS TO SEAL HANGER WITH NO SUCCESS. SET TWO WAY CHECK INSIDE SHORT STRING. ATTEMPT TO BACK OUT LANDING JOINT ON LONG STRING & PH-6 BY IBT CROSSOVER BROKE FREE ABOVE LANDING NIPPLE. ATTEMPT TO BACK OUT CROSS OVER WITH NO SUCCESS. NOTIFY JIM REGG WITH AOGCC OF PLAN FORWARD. R/U BRIDLE LINES TO LIFT BOP STACK. N/D GRAY LOCK ADAPTOR FLANGE. LIFT 13-5/8" BOP & RISER. BACK OUT CROSSOVER SUB FROM LONG STRING & SET TWO WAY CHECK. PRESSURE PLATE NOT SITTING EVENLY ON TOP OF DUAL HANGER, LONG STRING HANGER LANDED ON TOP OF SHORT STRING. SET STACK DOWN, RE BRIDLE LIFTING STACK& LONG STRING, CONTINUOUSLY ATTEMPTING TO LAND LONG STRING INTO TUBING HANGER WITH NO SUCCESS. SHORT STRING HANGER SLID OVER INSIDE TUBING HANGER 1/8". SET BOP STACK DOWN. N/U GRAYLOCK FLANGE, BACK OUT 3-1/2" LONG STRING LANDING ASSEMBLY&CLOSE BLIND RAMS. BREAK PIPE RAM BONNETS, CHANGE RAM BLOCKS TO DUAL 3-1/2". R/U WEATHERFORD DUAL HANDLING EQUIPMENT& P/U LONG &SHORT STRING LANDING JOINTS. CURRENTLY PREPARING TO LIFT DUAL STRING TO RIG FLOOR TO ALIGN HANGERS&WILL LAND BACK OUT TO TEST DUAL RAMS. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #42 50-733-20451-00 193-073 4/24/15 5/21/15 Daily Operations: 04/30/15-Thursday M/U SHORT& LONG STING LANDING JOINTS. SECURE DUAL ELEVATORS& CLEAR PERSONNEL FROM RIG FLOOR. PULL 150K& DUAL STRING BEGAN MOVING UP HOLE. PULL UP HOLE 15'TO ANNULAR (190K) IT WAS NOTICED SHORT STRING HAD STRIPPED THE THREADS FROM THE TUBING NECK. SLACK BACK OFF OF LONG STRING. CONSULT WITH HILCORP ENGINEERING ON OPTIONS. DECISION MADE TO CUT& FISH PRODUCTION STRINGS FROM HOLE. EXPEDITE E-LINE & TOOLS. R/D WEATHERFORD DUAL HANDLING EQUIPMENT& RELEASE PERSONNEL. WORK LONG STRING TRYING TO FREE PIPE UP TO 125K WHILE WAITING ON TOOLS. COORDINATE PLANS WITH AOGCC REPRESENTATIVE GUY SCHWARTZ &JIM REGG. CHANGE OUT DUAL RAM BLOCKS TO 2-7/8" X 5" RAM BLOCKS. ATTEMPT TO BACK OUT LANDING JOINT ON LONG STRING TO RETRIEVE BPV. HANGER THREAD BACKED OUT BENEATH HANGER. POOH L/D HANGER. M/U BUTTRESS COLLAR &SCREW BACK INTO LONG STRING. R/U E-LINE. RIH & PUNCH HOLES INSIDE 3.5" LONG STRING @ 4,012'. POOH & P/U 2.5" RCT. RIH &CUT TUBING @ 4,012', INDICATION SHOT FIRED. LOG THRU CUT& POOH. WORK TUBING UP TO 125K, PIPE COME FREE WITH 35K STRING WEIGHT. INSPECT CROWN CLUSTER & BLOCK. PREPARE TO POOH. POOH WITH 3.5" 9.3# LONG STRING PRODUCTION TUBING. 15-20K OVER STRING WT. SLM TUBING ON CATWALK,TOTAL OF 120 JOINTS = 3,828' L/D @ 0600 HRS.TOTAL OF 74 BBLS OF 6% KCL ADDED TO WELL BORE LAST 24 HRS. 05/01/15 - Friday FINISH POOH WITH 3-1/2" 9.3#TUBING FROM LONG STRING. TOTAL OF 127 JOINTS, CUT JOINT, & 3 PUP JOINTS LAYED DOWN. TUBING MEASUREMENT= 3,996.29'. CLEAN & CLEAR RIG FLOOR, INSTALL LANDING JOINT INTO SHORT STRING. R/U E-LINE. P/U 2.65"JET CUTTER, RIH, UNABLE TO PASS HANGER @ 26'. POOH SAME, REMOVE LANDING JOINT& FOUND THREAD OBSTRUCTING LANDING JOINT. FILE OFF BURR & LAND JOINT INTO SHORT STRING HANGER. RIH WITH 2.65"JET CUTTER TO 4,600', LOG WITH CCL F/4,600'TO 4,400'. SET CUTTER INTO POSITION @ 4,506'. SET CHARGE, NO INDICATION SHOT FIRED. POOH & FOUND CRIMP ON IGNITER COME LOOSE. RE CRIMP, RIH & CUT 3.5"TUBING @ 4,506', ALL INDICATIONS SHOT FIRED. POOH & L/D E-LINE. P/U SPEAR ASSEMBLY DRESSED WITH 3.001 GRAPPLE. ENGAGE TUBING NECK ON SHORT STRING HANGER, PULL 47K& PIPE BEGAN MOVING UP HOLE. PULL HANGER TO RIG FLOOR & RELEASE FROM SPEAR. L/D SPEAR ASSEMBLY& PREPARE TO POOH L/D 3-1/2" 9.3#SHORT STRING. POOH, LAYING DOWN 3.5" 9.3# N-80 TUBING FROM SHORT STRING.TOTAL OF 143 JOINTS, 1 CUT JOINT, & 6 PUP JOINTS. TOTAL LENGH OF PIPE RECOVERED = 4,480.04'. PERFORM GENERAL HOUSEKEEPING. CLEAN RIG FLOOR & DECKS. P/U 3.5" TEST ASSEMBLY& PREPARE TO TEST BOPE WITH STATE WITNESS BOB NOBLE.TOTAL OF 120 BBLS OF 6% KCL ADDED TO WELL BORE LAST 24 HRS. 05/02/15-Saturday PRETEST BOPE WHILE WAITING ON AOGCC STATE WITNESS BOB NOBLE. TEST ALL BOPE PER SUNDRY TO 250 PSI LOW & 2500 PSI HIGH, TEST GAS DETECTION SYSTEM (ALL OK). PERFORM KOMMEY DRAW DOWN, CHECKED PRESSURE ON BACKUP NITROGEN BOTTLES (6 @ 2200 PSI). ALL BOPE WAS TESTED FROM MAIN & FUNCTION TESTED REMOTE. ALL TESTS WITNESSED BY AOGCC INSPECTOR BOB NOBLE. L/D TEST ASSEMBLY& PREPARE TO P/U 3.5" 12.95# PH-6 TUBING, RACKING PIPE BACK IN DERRICK. P/U 3.5" 12.95#WORK STRING, RACKING BACK PIPE IN DERRICK,TOTAL OF 300 JOINTS PICKED UP & 110 STANDS RACKED IN DERRICK.TOTAL OF 22 BBLS OF 6% KCL ADDED TO WELL LAST 24 HRS. Hilcorp Alaska, LLC • Well Operations Summary Well Name API Number Well Permit Number Start Date End Date • Granite Pt St 18742 #42 50-733-20451-00 193-073 4/24/15 5/21/15 Daily Operations: 05/03/15-Sunday POOH WITH 45 STDS OF 3.5" 12.95#TUBING,TOTAL OF 300 JOINTS PICKED UP & RACKED IN DERRICK. P/U BHA#1, 8- 1/8" OVERSHOT DRESSED WITH 3.5" GRAPPLE & 3-5/8" CONTROL GUIDE, UPPER EXTENSION, 4-3/4" DRILLING JARS, (6) 4- 3/4" DRILL COLLARS, INTENSIFIER JARS&X-O. TIH WITH 3.5" WORK STRING TO TOF @ 4,032' KB MEASUREMENT. P/U WT = 51K, S/O WT=42K. ENGAGE FISH @ 4,032', WORK PIPE JARRING 40-80K OVER STRING WT. STRAIGHT PULL PIPE UP TO 180K (80%OF PRODUCTION TUBING TENSILE). PIPE PULL FREE WITH 180K OVER PULL. CONTINUE POOH WITH 3.5" 12.95#WORK STRING DRAGGING LONG STRING FISH UP HOLE WITH 25-40K DRAG. L/D INTENSIFIER JARS, RACK BACK DRILL COLLARS, L/D DRILLING JARS &SHUCK OVER SHOT FROM 3.5" PRODUCTION FISH. POOH LAYING DOWN &SLM 3.5" 9.3# N-80 PRODUCTION TUBING FROM LONG STRING.TOTAL OF 169 JOINTS, 5 PUPS = 5,263.04' L/D @ 0600 HRS. TOTAL OF 65 BBLS OF 6%8.6PPG KCL ADDED TO WELL LAST 24 HRS. 05/04/15 - Monday POOH WITH 3.5" 9.3# PRODUCTION TUBING.TOTAL OF 189 JOINTS, 2 CUT JOINTS, & 5 PUP JOINTS. TOTAL LENGTH = 5,864'. P/U BHA#2, 8-1/8" GUIDE, UPPER EXTENSION, BOWEN ITCO SPEAR DRESSED WITH 3.001" GRAPPLE,TOP SUB, 4- 3/4" DRILLING JARS, (6) 4-3/4" DRILL COLLARS, & INTENSIFIER JARS. BHA LENGH = 271.47'. TIH WITH 3.5" 12.95#TUBING FROM DERRICK. ENGAGE FISH @4,534'. P/U WT= 51K, 5/0 =42K. WORK FISH JARRING 70K OVER STRING WT. & PULLING UP TO 180K. PIPE BEGAN MOVING UP HOLE AFTER 2 HRS OF JARRING. DRAG FISH UP HOLE 40-50K DRAG FROM 4,534' TO 4,457'. CONTINUE TO WORK FISH @ 4,457', WORKING PIPE FROM 70K-180K. BEGAN HEARING NOISE FROM MAIN CHAIN DRIVE. SHUT ENGINE DOWN. REMOVE CHAIN GUARD INSPECTION PLATE & FOUND TEETH ON RIGHT ANGLE DRIVE SPROCKET BROKEN OFF. RIG DOWNTIME: EXPEDITE RIGHT ANGLE DRIVE & MECHANIC FROM MONCLA YARD KENAI. TRANSFER WELDER FROM ANNA PLATFORM TO BRUCE. CUT& REPLACE RIGHT ANGLE DRIVE WITH MOUNTING PLATE. PRESENTLY ALIGNING NEW RIGHT ANGLE DRIVE TO WELD INTO PLACE. 05/05/15 -Tuesday RIG DOWNTIME: ALIGN &WELD OUT RIGHT ANGLE DRIVE. INSTALL GUARDS &TEST RUN DRAW WORKS. CONTINUE WORKING FISH @ 4,457', PULLING 70K-170K. UNABLE TO PASS TIGHT SPOT. LOWER STRING TO 4,534'. R/U POWER SWIVEL TO RELEASE FROM SPEAR @ 1600 HRS. RELEASE FROM SPEAR. L/D POWER SWIVEL& PREPARE TO POOH. POOH WITH 3.5" 12.95#TUBING. RACK BACK 4-3/4" DRILL COLLARS. L/D JARS & SPEAR. SPEAR GRAPPLE ALL INTACT. P/U 8-1/8" OVERSHOT WITH MILL GUIDE DRESSED WITH 3.50" GRAPPLE, UPPER EXTENSION, &X-O. TIH WITH 3-1/2" 12.95#TUBING TO 4,520'. P/U POWER SWIVEL& ESTABLISH PARAMETERS. P/U WT= 50K 5/0 WT=40K, ROTATING WT= 46K. ENGAGE FISH TO & DRESS OFF SAME @ 4,534'. SWALLOW & LATCH ONTO FISH. R/U POLLARD E-LINE. RIH WITH 3'TUBING PUNCH, CCL, & 1-11/16" WEIGHT BAR. PUNCH HOLES @ 9,812',TOTAL OF 90 BBLS OF 6% KCL ADDED TO WELL LAST 24 HRS. • r- Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #42 50-733-20451-00 193-073 4/24/15 5/21/15 Daily Operations: 05/06/15 -Wednesday POOH WITH SPENT HOLE PUNCH ON E-LINE. P/U 2" RTC & RIH, LOG ON DEPTH & CUT SHORT STRING TUBING AT 9,812'. POOH &SET E-LINE TO SIDE. PICK UP ON TUBING, STRING WT= 84K& PIPE FREE. RID E-LINE. MIX, PUMP, &SPOT 50 BBLS OF NW-50 PILL @ 9,800'. PREPARE TO POOH. POOH WITH 3-1/2" 12.95#WORKSTRING RACKING PIPE IN DERRICK. FISH DRAGGING 5-10K UP HOLE. BID BHA LAYING OUT OVS ASSM W/TOP CUT PIECE. RECOVERED 170 JTS OF 3 1/2" BUTT PRODUCTION TB +4 PUPS AND BTM CUT PIECE = 5,278.75'. SLIPPED & CUT DRILL LINE. REPLACED ALL DRILL LINE (768') DUE TO DAMAGE @ LOAD CELL AREA ON DEADMAN END. M/U BHA(5 3/4" OVS DRESSED LDD WITH 3 1/2" BASKET GRAPPLE W/7" GUIDE, OIL& BUMPER JARS, 4 3/4" DCs X 6, ACC JAR, XO). 05/07/15-Thursday TIH w/overshot/jarring assem on 3 1/2" 12.95# PH6 workstring strapping remainder of TB in derrick to 9,563' (150 stands). Picked up additional 8 jts of workstring strapping and rabbiting same. RIH to 9,813'. R/U power swivel w/single #309 and made up to string. Production personnel checked fluid level down annulus and determined it to be —6,400'. Pumped 58 bbls down TB @ 2 BPM 0 PSI to flush ovs before latching. New fluid level in annulus—5,260' as per production. While pumping Moncla power swivel died. B/O L/D swivel from top of#309. Tagged TOF (SS) at 9,828' (PM) and attempted to latch with no success on first attempt. Found problem with swivel and cranked same. R/U swivel again on top of#309 and latched SS fish. P/U to 130k and let jars hit. B/0 swivel from top of#309 and L/D same. Began jarring on fish at 170k (63k over string wt) then pulling to 180k total. After 1 hr of jarring, fish moved uphole 77' dragging 30-40k over, placing Kobe section in tight spot at 9,836' (TOF now— 9,751'). Stopped jarring and visually inspected derrick. Continued jarring, checked derrick after every hr of jarring. Made 4' in 7.5 hrs of jarring. No hole made in the last 2 hrs. Decision was made to P/U swivel. Jarred fish down in order to break off single. R/U swivel on #307 and attempted to twist off 2 3/8" 8rd connection. Could not get enough torque downhole @ 7000 ft/lbs with weight pulled on fish. B/O swivel from string and M/U singles 308 & 309. 05/08/15 - Friday Attempted to shuck overshot after pushing SS fish to btm. Could not tell if we were shucking ovs due to torque, drag & fish travel. Picked up on string and torqued pipe with swivel. Began rotating uphole roughly. Rotated 4 jts OOH (Kobe section above tight spot at this point) then straight pulled next jt. No overpull or drag, overshot possibly released. B/O L/D power swivel. Pulled OOH w/ 152 stands pumping 3 bbls every 10 stands. B/D BHA. No recovery,grapple was dulled. B/D skirted spear assembly used in earlier trip in hole to use the 8 1/8" WP extension on next BHA. M/U BHA (8 1/8" x 7 1/4" SOD SID wavy btm shoe, WP ext, 1-8 1/8" WP, top bushing, xo, B & 0 jars, DCs x 6, xo = 256.01'). TIH w/ 152 stands + BHA to 9,709' (P/U 104k S/O 60k). Started picking up singles, did not see WP go over TOF (SS) @ 9,828'. Continue in hole tagging something on 5th single at 9,835'. Obstruction moved w/4k down weight. Worked thru this area again with no tag, did not tag again until TOF topped out inside WP on top bushing (@ 9,828'). End of shoe at 9,873'. P/U to connection & B/O#310 putting EOTs at 9,866'. Production attempted to shoot fluid level but could not get dependable depth. Pumped 100 bbls 6% KCL down TB at 2 BPM 0 PSI. Last fluid level was— 5,200'. B/O hose and laid down 3 singles. SOOH pumping 6 bbls 6% KCL every 20 stands. 43 of 153 stands OOH (7,098'). Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #42 50-733-20451-00 193-073 4/24/15 5/21/15 Daily Operations: 05/09/15 -Saturday Finished POOH w/ BHA-8 1/8" SOD SID wavy btm rotary shoe, WP ext, 1 jt 8 1/8" WP, top bushing, B&O jars, 6 DCs, xo. Pumped 6 bbls 6% KCL every 20 stands. B/D L/0 Knight BHA. Cleared and cleaned floor. M/U test plug assembly w/ IBOP & SV w/pump. Landed same and lined up to test BOPE. Filled stack and pretested annular(working air out). Tested all BOPE to 250#s/ low 2500#s/high as per Hilcorp and AOGCC requirements using Moncla 404 test procedure. Witness waived by Mr.Jim Regg. Tested from main. Functioned remote. Performed accumulator draw done test and checked nitrogen bottles- 2200#avg. B/O SV and IBOP. Pulled test plug and landed wear bushing. M/U BHA#6 (5 3/4" ovs w/7" oversize guide Idd w/3 1/2" basket grapple, upper ext, top sub, 4 3/4" x 2 1/4" B &0 jars, 6-4 3/4" x 2 1/4" DCs,4 3/4" x 2 1/4" Acc jar, XO = 228.25'). TIH w/ovs&jarring assem on 153 stands of 3 1/2" 12.95# P110 PH6 TB to 9,743' (P/U 107k 5/0 66k). Picked up 3 singles and tagged TOF (SS) 20' in on #309 = 9,828'. Latched fish. Began jarring at 60k over string weight then pulling to 180k. After jarring for 1 1/2 hr fish released from btm. Pulled uphole at 145k to tight spot at 9,836' (TOF @ 9,751'). Continued jarring while pumping 6% KCL at 2 BPM 0 PSI. Last fluid level shot was 4,397'. Once calculated volume is pumped we'll attempt to circulate. 05/10/15 -Sunday Stopped jarring and checked shackles, turn buckles, pins, bolts & crown while pumping calculated volume of 6% KCL. Continued jarring on fish (SS) at 60k over then pulling to 180k. Hole did not fill at calculated volume-fluid level shot showed 2,441'. Discussed plan forward. Decision was made to attempt to bail deep enough with SL to cut 2 3/8" pup on top of Kobe Assembly (SS side) in order to evaluate tight spot in casing at 9,836'. R/U to pump down SS side to flush tbg prior to R/U SL(2 BPM 200#s) and got returns on annulus. Built 6% KCL volume and tied in to pump to production across shaker. Pumped down SS TB at 2 BPM 0-200#s. Took 57 bbls to get returns. Pumped total of 155 bbls before fluid cleaned up. Sent—70 bbls of oil to production holding tank. SL crew onboard. Spaced out to R/U SL. Built 6% KCL volume and cleaned oil from shaker tank and lines+general housekeeping while waiting on SL equipment. Held PJSM w/ rig, crane and personnel. Offloaded SL equipment and R/U same. M/U full lubricator w/WL rams and pumping sub. M/U Run#1 (1 1/4" rope socket, 10' 1 1/4" stem, 1 1/4" knuckle, 1 1/4" oil &spang jars w/ 10' 1 5/8" pump bailer on .125" alloy wire). Pulled inside lubricator and M/U to string (SS). Tested lubricator to 1000#s. TIH w/ Run #1 to 9,882' (SLM). Bailed and POOH. B/O lubricator and lowered tools to empty bailer. Flapper was stuck open, no recovery with bailer. Changed out bailer btm. Pulled inside lubricator and M/U to string. TIH w/ Run #2 (same as#1 with different bailer btm) to 9,882'. Bailed without making hole. POOH. 3/0 lubricator and lowered tool to empty bailer—4" of fill inside bailer with metal markings around EOT. Broke off bailer and M/U 1 5/8" Imp blk. TIH Run #3 (1 5/8" Imp blk w/same tool string minus pump bailer). TIH and tagged at 9,882'. POOH and B/O lubricator. Lowered tool string and B/O imp blk. Block heavily ringed around 3/4 of circumference. Rigged SL to side and R/U EL. M/U Run #4 (1 3/8" rope socket, 1- 1 11/16" Wt bar, 1 11/16" CCL). Pulled inside lubricator and M/U to string. TIH w/CCL and tagged btm at 9,916' (correlated on depth). Logged thru SS fish and ovs/jarring assm. POOH. B/O lubricator and dropped tools out. M/U centralizer, shock sub & 1 11/16"jet cutter. Pulled inside lubricator and made up to string. TIH w/jet cutter to 9,916' and tagged (correlated on depth). Picked up off btm and fired cutter at 9,911' w/ 10k over pull. POOH and rigged EL to side. M/U single with valve in string and began jarring on cut @ 60k over pulling to 180k. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #42 50-733-20451-00 193-073 4/24/15 5/21/15 Daily Operations: 05/11/15 - Monday Jarred on SS fish at 60k over pulling to 180k. Setting 25k weight down. Did not jar free during 1 hr of jarring. Rigged EL up w/full lubricator. M/U Run#6 (1.906" gauge w/ 1 11/16" CCL&wt bar).TIH to 9,839' and set down (top of Mdl ER pkr- 1.810" id). POOH and B/O gauge. M/U Run #7 (1 11/16"Jet Cutter w/centralizer&shock sub+CCL&wt bar). TIH to 9,016' and correlated on depth, fired cutter @ 9,909' (1' above previous attempt). POOH and rigged EL to side. Worked SS fish at 60k over then pulling to 180k-setting 25k weight down. Cut or connection parted. Laid down 3 singles. POOH w/ 153 stands+ BHA pumping 6 bbls every 20 stands. B/D BHA, recovering 84.01' of SS fish (10.42', 31.66', 30.03',10.42'). Recovered PBR & Mdl ER Pkr in 1st full jt+ 2.9' of perfs in btm cut piece (7.1' of perfs still in hole) ("S 31' of SS fish left on top of Kobe assm). New top of SS fish @ 9,912' (PM). M/U BHA#7 (6 1/2" rock bit, xo, xo, 8 3/8" string mill, xo, xo, 4 3/4" B&O jars, 6-4 3/4" DCs, xo). TIH w/ BHA+ 153 stands of 3 1/2" 12.95# P110 PH6 to 9,738'. RIH 6 singles to 9,910' (15' in on#312- purposely did not tag), no tight spot or set down. Laid 5 singles down. P/U power swivel w/#307 and M/U to string. P/U 101k S/O 61k- rotating P/U 95k S/O 79k @ 4000-4500 ft/lbs-stationary rotating 6000 ft/lbs. Reamed from 9,800'to 9,910' up &down. 05/12/15 -Tuesday Pumped 1 1/2 tb volumes in rev without circulation. Mixed and pumped 50 bbl high vis Drill Express/NW-50 pill. B/O L/D power swivel. Laid down 2 singles. POOH w/ 155 stands to BHA pumping 6 bbls every 20 stands. Replaced McCoy tongs with Foster tongs at 1600 hrs. B/D BHA(bit& string mill,jars & collars). M/U BHA#8 (8" mill guide, lower ext, 5 3/4" ovs Idd w/3 1/2" basket grapple, top sub,4 3/4" B&O jars, 6-4 3/4" DCs, 4 3/4"Acc Jar, xo). TIH w/ BHA+ 155 stands of 3 1/2" 12.95# P110 PH6 Tb to 9,867' (P/U 107 S/0 66). P/U 2 singles and tagged 13' in on #312 @ 9,913' (PM). Could not latch fish. Spaced out to P/U power swivel. Picked up swivel and M/U to string. Could not rotate to dress off top of fish. Adding CFS520 friction reducer to active tank while rolling fluid (1% ratio). 05/13/15-Wednesday Continued pumping 6% KCL w/ 1%friction reducer down tbg covering BHA. Dressed off TOF and attempted to latch with swivel (2 hrs) with no success. Laid down swivel and P/U single to be able to put more weight down. Could not latch fish. Laid down 2 singles+ pup and POOH w/ 154 stands and single (to change brake). Pumping 6 bbls every 20 stands. B/D BHA#8 (ovs&jars w/collars)- no recovery. Examined ovs assembly: no marks on leading edge of 8" oversize guide or inside lower extension. No marks inside grapple or thru MCP rubber. Only marks are on inner edges of MCP teeth. M/U BHA#9 (7" oversize guide w/5 3/4" ovs Idd w/3 1/2" basket grapple and plain control, upper ext, top sub, 4 3/4" B&O jars, 6-4 3/4" DCs, 4 3/4" Acc jar, WS xo). TIH w/ BHA+ 154 stands on 3 1/2" 12.95# P110 PH6 workstring to 9,805'. Picked up 4 singles tagging TOF @ 9,913' (PM). Worked over TOF and set grapple. P/U to trip jars at 20k over then picked up to 135k after jar tripped- something parted (still had BHA weight)- eased down and went 12' deeper(indicating that TOF had changed). Laid down 4 singles-SOOH w/ BHA#9. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #42 50-733-20451-00 193-073 4/24/15 5/21/15 Daily Operations: 05/14/15 -Thursday POOH w/ BHA#9 (ovs&jars w/collars). B/D BHA& recovered 16.89' of SS fish (btm piece of cut 3 1/2" Buttress tbg 15.05' long w/7' perfs (piece was plugged below btm perf), .84' xo sub, 1' piece of 2 3/8" 8rd tbg). Discussed plan forward. Called for 8 3/8" Concave Mill +directions to modify Short Catch ovs. Cleared and cleaned rig floor, built KCL volume and performed general house cleaning while waiting on tools. M/U BHA#10 (8 3/8" x 2 1/4" Concave Mill, 6" x 2" Bit Sub, 4 3/4" x 2 1/4" B&O jars, 6-4 3/4" x 2 1/4" DCs, 4 7/8" x 21/4" xo sub). TIH w/ BHA+ 155 stands of 3 1/2" 12.95# P110 PH6 workstring and 2-singles to 9,914' (PM). B/0 13 5/8" x 11" spool- M/U 13 5/8" x 7 1/16" spool and halls head adapter- P/U swivel w/single #313. M/U to string. 05/15/15- Friday Established milling parameters and milled 4-6" off 2 3/8" 4.6# N80 8rd pup @ 9,930' (PM) 9,904' (strapped measurement). B/O L/D swivel. Laid down 2 singles and N/D stripping head adapter. N/U 13 5/8" x 11" 5k spool. POOH w/ BHA#10 (8 3/8" Concave mill,jars& collars) + 155 stands of 3 1/2" PH6 workstring pumping 6 bbls every 20 stands. B/D BHA#10. Minor markings on mill. M/U BHA#11 (5 7/8" short catch ovs w/7" oversize guide Idd w/2 3/8" grapple, 4 3/4" x 2 1/4" B&O jar, 6-4 3/4" x 2 1/4" DCs, 4 3/4" x 2 1/4" Acc jar, 4 7/8" x 2 1/4" xo). TIH w/ BHA+ 155 stands to 9,864'. Run in 2 singles to 9,926'. P/U power swivel w/ 10' 3 1/2" PH6 pup. Tagged 4' in = 9,930' (WSM) 9,904' strap measurement. Attempted to latch fish for 45 mins. Could not align up TOF into overshot. B/0 L/D swivel, 10' pup & 2- singles. POOH w/ BHA#11+ 155 stands pumping 6 bbls every 20 stands. 130 stands out at report time. 05/16/15-Saturday Finish POOH w/ BHA#11 (5 7/8" short catch ovs w/welded on 7" guide,jars& collars). B/D BHA. Signs are that we did get top of SS 2 3/8" pup 2" inside guide (from worn off paint and shiny areas). P/U single w/test plug and pulled wear bushing. Turned TP over and landed same. M/U pumping, safety valve, IBOP on top. R/U to test BOPE. Pretested Hydril to purge air. Tested BOPE as per Hilcorp and AOGCC requirements 250#s/low 2500#s high (as listed on Sundry 315-137) (witness waived by Mr.Jim Regg 15 May 15). Performed accumulator draw down and checked backup bottles while B/D test jt and pulling test plug. Installed wear bushing. M/U BHA#12 (5 3/4" ovs w/6" hollow mill guide to dress 2 3/8" Idd w/2 3/8" basket grapple, 4 3/4" x 2 1/4" B&O jars, 6-4 3/4" x 2 1/4" DCs, 4 3/4" x 2 1/4" Acc jar, xo). TIH w/ BHA#12 + 155 stands of 3 1/2" 12.95# P110 PH6 workstring. (changed to Moncla Foster at 1830 hrs). P/U R/I 2 singles= 9,927.5'. P/U power swivel w/ 10' pup. M/U to string. Tagged 4' in on pup jt at 9,930.5' (PM). Attempted 2.5 hrs to latch fish with no success. B/0 L/D swivel. 10' pup & 2 singles. SOOH w/ BHA#12. 50 of 155 stands OOH at report time. 05/17/15-Sunday Finished POOH w/ BHA#12 (overshot,jars& collars). B/D BHA and examined overshot. Determined that SS fish was entering ovs 6-11" but not far enough to engage grapple and that we were turning on LS top. Slipped &cut 65' of drill line. Decision was made to cease cleanout operations and move into completion mode. TIH w/ DCs and laid down same. B/D and packed up tools. TIH w/ 150 jts of 3 1/2" PH-6 workstring. Changed from Moncla's Foster tongs to Knight's McCoy tongs. POOH laying down 150 jts of 3 1/2" PH-6 workstring. Ran in hole remainder of workstring (160 jts). Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #42 50-733-20451-00 193-073 4/24/15 5/21/15 Daily Operations: 05/18/15- Monday POOH laying down remainder of 3 1/2" 12.95# PH-6 workstring. Pulled wear bushing and changed out single variable pipe rams to dual flex packer pipe rams. M/U dual test fixture on 9 5/8" test plug using 2 7/8" tbg to surface. Filled stack and closed rams w/air pressure. Pretested to purge air. M/U Kobe 2.5" MVSR assem while preparing to test. Tested dual pipe rams to 250#s/low 2500#s/high as per Hilcorp &AOGCC requirements (as listed on Sundry#315-137). Witness waived by Mr.Jim Regg/AOGCC. Permission to test early requested and received. Pulled test plug. B/D dual fixture and test joints. Cleared and cleaned floor. Held PJSM w/Weatherford, crane crew and rig personnel covering R/U and handling of dual production strings. R/U Weatherford dual handling equipment and tongs. M/U 2 7/8" 6.5# L-80 EUE singles in top of Kobe assem. P/U clamped single w/ muleshoe and set in slips. M/U Kobe assem to single w/ muleshoe. RIH w/dual production strings of 2 7/8" 6.5# L-80 EUE TB w/ Kobe assem. M/U connections to 1800 ft/lbs. Depth at report time 1,000'. 05/19/15-Tuesday Continued RIH w/ Kobe 2.5" MVSR on dual 2 7/8" 6.5# L-80 EUE production tbg, strapping& rabbiting, torqueing connections to 1800 ft/lbs. Depth at report time is 7,071'. 05/20/15-Wednesday Continued RIH w/ Kobe 2.5" MVSR on dual 2 7/8" 6.5# L-80 EUE production tbg, strapping& rabbiting.Torqueing connections to 1800 ft/lbs. Set top singles in slips w/ EOT(LS) at 9,826'. R/U Pollard SL w/full lubricator. M/U Run #1 (1 1/2" rope socket, 10' of 1 1/2" stem, knuckle, oil &spang jars, 2.260" LIB = 21'). Pull inside lubricator and M/U to LS. TIH w/ Run #1 and tagged at 9,805'. POOH (finding fluid level at 6,400'). B/O lub and remove Imp blk. M/U standing valve and running tool. Pulled inside lub and m/u to LS.TIH to 9,805'. Released from SV and POOH. B/O lub and remove running tool. M/U LIB (rerun) and pulled inside lub. M/U to LS and TIH to 9,805'. Tapped down once and POOH. R/D Pollard S/L. R/U lines to fill dual strings. Pumped 67 bbls to fill both strings and R/U test pump. Pressured up to 3500#s and held for 10 mins on chart. Released pressure and R/D testing equipment. Cleared rig floor and R/D same. Pumped a total of 2702 bbls of 6% KCL down hole during course of job+ 3 bbls of CFS-520 friction reducer, 500#s of NW-50 Bio Polymers and 25 gals of Drill Express. N/D strip off 13 5/8" x 11" 5k spool. M/U dual hanger w/Cameron's assistance. Lower hangers with pins out and set down. Marked pipe and P/U 6". Ran in pins and attempted to land hanger unsuccessfully. Discussed with production about alignment. Decision was made to land hanger w/pins out. End of LS @ 9,851' w/ Kobe cavity at 9,819'. R/D Weatherford dual handling equipment. B/O landing jts and Cameron attempted to set packer. Off on top of hanger sections. Could not work packoff thru Hydril rubber. Removed Hydril. Installed hanger packoff and BPVs. 05/21/15-Thursday R/D floor. B/D accumulator, unmounted driller's shack, prepared derrick to be scoped in. Changed out dual rams to single rams in BOP. R/D Quadco &Total Safety. Scoped derrick in. Broke bolts on riser and BOP stack while prepping derrick to be laid down. Laid down derrick and N/D BOPs. Cleaned BOPs as they hit the top deck. Removed drill line from draw works and lifting cylinders from derrick. Broke down all pump lines under rig. Cameron prepped tbg head to receive adapter&tree. Cleaned shaker tank and active tank sending—50 bbls to production holding tank. N/U tree and Cameron tested void. Did not pass 5000#void test. Cameron consulted w/wellhead specialist and we continued with successful 5000#shell test on tree. Well turned over to production. Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday,April 30, 2015 12:23 PM To: 'Bobby Harrington - (C)'; Regg,James B(DOA) Cc: Juanita Lovett; Daniel Taylor, Stan Golis;Ted Kramer Subject: RE:Granite Pt St 18742-42 Dual Production Removal (PTD 193-073) Bobby, AOGCC approves your plan forward. Be sure to monitor backside fluid level before and during changing out of the dual rams to VBR as you will be exposed to reservoir without a mechanical barrier. Keep us posted on progress and any significant deviation to approved plan below. Regards, Guy Schwartz Senior Petroleum Engineer %WE© MAY. 0 k' Z015 AOGCC 907-301-4533 cell 907-793-1226 office CONFIDEN1IALfYNOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Bobby Harrington - (C) [mailto:bharringtonPhilcorp.com] Sent:Thursday, April 30, 2015 10:44 AM To: Regg, James B(DOA); Schwartz, Guy L(DOA) Cc: Juanita Lovett; Daniel Taylor; Stan Golis; Ted Kramer Subject: Granite Pt St 18742-42 Dual Production Removal Jim/Guy, As discussed in our phone conversation.After removal of the coil injector string from the short string an attempt was made to cut the 3.5"9.3#short string tubing at 9905'+/-.We were unable to go past the coil tubing pbr assembly @ 9817'and decision was made to cut the long string instead. We proceeded with cutting the long string tubing @ 9905'. We then attempted to pull the long string with no success and was getting minimal stretch at surface indicating the dual string was twisted at approximately 2000'.When we went to land the long string back out inside the bowl the hanger landed on top of the short string hanger shifting the short string hanger off center.We then attempted to pull both strings to surface and the short string landing joint stripped from the short string hanger. We now request to change our dual ram blocks to 2-7/8"X 5" VBR and will proceed at making an attempt to work& pull the long string free. If unable,we will cut the long string at+/-4000'.We will pooh laying down the 4000'of long string recovered then switch to the short string cutting it approximately 4100'and pooh laying it down.This will then allow us to land our bope test plug inside the Vetco Gray tubing hanger and test all bope to move forward with fishing operations. If we are able to work the long string free,we will pull it laying the 9905'down, pull the short string hanger to the floor, remove the hanger&hang tubing off to test bope.Then proceed laying down the short string moving on with work over operations. Bobby Harrington WSM-Bruce 1 ryZ_ 9Z *i0,11),„ ___,. .- vk iv) (3°_. -.,,� 46 0 113 - v 73 lif J.14 , 1/ <xi, ..„,_ ,,, A y f' 90°° »rte lft J t/ Rei / \i\/ ." "" ,-V(...4 5 6 -, / A' ¢' � �/ (5 0 \\\\ \ / , ,, , :0 '50 \ // / A., - ' e ...odd.. -,.,,, \ \ .\\ \ r--- � r \�e5 000 ,y j / ` o R 5 r1 00° 1 \\ \\___ /jj /, / fr,f _10 / `r< tOP \ /0. eP / / / ? 5 a Z 3 , 0.- / / iv 2 - a - M O \ \ \ \ t , 3 t- c a o —r T z CO 0 k eata (-D \\ Y oNJ 0 . I.0 0 0 `C` II n o <'' I� V o 0 0. W 3 C. 0 0 0 f O 0 0 I PO oj o O \ 0 b ..� 0 0 0 0 \ Cii `r o 1' 1 c 2 \C \\ 41d) / / i \ \ 3 \ v /. - Jam. �� CI , \,\ 000 v /f, / / / /1//o \ N /, 00 0\ . 00 iA / �`� ,/ F\ 7 x' . �, 4- ' BOJ / °°O ` . / k.O /� OrS\ / / 1V7 7 ° �°O _ ppp ` O -. \ °0 \ \ ,_, � p0pl OO 1 GiO ciNN ° �. / Siooc) __--------- 0 15 ? 7 113--0?3 HILCORP ENERGY 315 137 5-1/8" 10M BOPE FOR BRUCE PLATFORM 11177717 5-1/8" 10M DUAL COMBI, 30.5" TALL DRESSED BLIND/SHEAR IN TOP DRESSED 2" CT SLIP/SEAL IN BOTTOM ,,,,, ,, ,,,, ADAPTER SPOOL, 12" TALL 5-1/8" 10M X 4-1/16" 10M 1 3-1/16" 3" TALL OM X 10M, 10 DSA 4-1/16" 4W'LW 46IJ 51.10 Ztt C #/ • ADAPTER SPOOL, 24" TALL �,� i t,‘ fL) 3-1/16" 10M X 3-1/8" 5M 5 BOLT IJ r Lai iii".114. RISER SPOOL, 55.5" TALL 3-1/8" 5M 5 BOLT en en am cm RED TOOLS ABOVE ARE WEATHERFORD OWNED GREY TOOLS ABOVE ARE HILCORP OWNED 125" TOTAL STACKUP HEIGHT OF T�� • 0,1" �y/,mss THE STATE Alaska Oil and Gas ofALASKA Conservation Commission Witt - ittt ._ _= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALA9I‘ Fax' 907.276.7542 www.aogcc.alaska.gov Dan Taylor Operations Engineer 0 /� Hilcorp Alaska, LLC SCANNED W'�'` 1 Fro - / 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 18742 42 Sundry Number: 315-137 Dear Mr. Taylor: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair 14- DATED this /3 day of March, 2015 Encl. RECEIVED STATE OF ALASKA MAR 1 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 2Q AAC 25.280 1.Type of Request: Abandon El Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforatel=1 I Pull Tubingi=i Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Atter Casing❑ Other. Complete 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 193-073 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic CI Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20451-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 76 / Will planned perforations require a spacing exception? Yes ❑ No 0/ Granite Pt St 18742 42 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 - Granite Pt/Middle Kenai Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): -11,813 • 9,794 9,943 8,027 N/A 9,943&11,200 Casing Length Size MD TVD Burst Collapse Structural Conductor 1,220' 18-5/8" 1,220' 1,219' Surface 4,135' 13-3/8" 4,135' 3,615' 3,450 psi 1,950 psi Intermediate 10,321' 9-5/8" 10,321' 8,390' 7,930 psi 6,620 psi Liner 1,717' 7-5/8" 11,708' 9,726' 12,260 psi 11,060 psi 1 Slotted Liner 1,075' 3-1/2" 11,622' 9,640' Perforation Depth MD(ft). Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,310-11,662 / 8,380-9,680 LS 3-1/2"&SS 3-1/2" LS 9.3#/N-80&SS 9.3#/N-80 LS 9,912'&SS 9,902' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A VA- ?$a.9 EA iAv'c .r 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 4/1/2015 Commencing Operations: Oil Or Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylor@hilcorp.com Printed Name Dan Ta . / Title Operations Engineer Signature/ //' Phone (907)777-8319 Date 3/11/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: R.tr 3/5 -r 37 Plug Integrity ❑ BOP Test iv Mechanical Integrity Test ❑ Location Clearance ❑ 1 Other: h Z5---6 b pry 0301' �t, - ( e',._ , ,,) civt.4_,sio, 002_ r S 1\ Spacing Exception Required? Yes ❑ No V Subsequent Form Required: i 0-14-04 m Ai APPROVED BY Approved by. ? i�67p—`�C�_ COMMISSIONER THE COMMISSION Date: /3 }'° QrRi r, I i4 .' SubmFormand Form 10-403(Revised 10/2012) ctIr 12 months from the date of approval Attachments in Duplicate RBDMSS MAR 1 6 2015 ,/2"is' Well Prognosis Well: Br 42RD-42 Hamra Alaska,LL Date:3/09/2015 Well Name: GRANITE PT ST 18742#42 API Number: 50-733-20451-00 Current Status: Oil Producer Leg: 4 Estimated Start Date: 4/1/2015 Rig: Moncla 404 Reg.Approval Req'd? Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 193-073 First Call Engineer: Dan Taylor 907-777-8319(0) 907-947-8051 (M) Second Call Engineer: Reid Edwards (907)777-8421 (0) AFE Number: Current Bottom Hole Pressure: —2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: —2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Max.Anticipated Surface Pressure: — 1,102 psi Based on 0.1 psi/ft gradient to 8,997ft TVD Brief Well Summary The work plan for this w?ll involves pulling the existing jet pump completion,removing the TCP guns in the well,cleaning out to PBTD, re-perforating,and running a new dual string jet pump completion. Procedure: 1. Mobilize Moncla Rig 404 to Bruce Platform over Br-42-42 on Leg#4. 2. Reverse out jet pump. 3. Circulate water down coil tubing string taking returns out short string until clean. 4. Shut in and bleed off casing pressure. 5. Shoot and record fluid level(casing). Avg producing fluid level=7,950ft. 6. Rig up Slickline on short string, run in hole and pull standing valve. 7. Flush tubing volume down short string using 6% (8.65ppg) KCL as work over fluid. a. Ensure well is dead. 8. Nipple up coil tubing BOP's and test 250psi low,2500psi high. CVA- a. Submit witness request notification to AOGCC 48hrs prior to test. 9. Pull out of hole with 2in coil tubing. 10. Close swab valve. a. Nipple down coil tubing well head. 11. Set back pressure valve(X2)in dual hanger. 12. Nipple down well head, nipple up BOPE. f K.„ on P perp a. Test BOPs 250 low, 2,500psi high. c`j i. Notify AOGCC 48 hours prior to test. 13. Pull hanger to floor and remove. ? 14. Rig up e-line on short string. a. Cut at+/-9,890ft dpm. 15. Pull out of hole with short string. 16. Pull out of hole with long string. 17. Pick up overshot/jar assembly to latch 4.5in OD collar below cut pup. a. Pull out of hole laying down guns. 18. Pick up 9-5/8in clean out assembly cleaning out to top of liner. 19. Pick up 7-5/8in clean out assembly cleaning out to PBTD. 20. Pick up 7-5/8in 39Ib test packer and run in hole to test at 10,050ft. a. Test 1,500psi for 30 min and chart. 21. Pick up TCP assembly spacing out over the following intervals: • II Well Prognosis Well: Br 42RD-42 Hilcorp Alaska,LL Date•3/09/2015 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Commenta 0rlir�s C-3 ±10,310' ±10,402' ±8,380' ±8,468' ±92' 6 11/4/1993 Re-pert 'f r Z C-5 ±10,561' ±10,700' ±8,618' ±8,748' ±139' 6 11/4/1993 Re-pert C-6 ±10,980' ±11,000' *9,009' *9,028' ±20' 6 11/4/1993 Re-pert C-7 ±11,075' ±11,135' ±9,099' ±9,156' ±60' 4 11/4/1993 Re-pert C-7 ±11,176' ±11,400' ±9,196' ±9,418' ±224' 4 11/4/1993 Re-perf C-7 ±11,418' ±11,440' ±9,436' ±9,458' ±22' 4 11/4/1993 Re-perf C-7 ±11,470' ±11,552' ±9,488' ±9,570' ±82' 4 11/4/1993 Re-pert C-7 ±11,612' ±11,662' ±9,630' ±9,680' *50' 4 11/4/1993 Re-perf 22. Pick up and run in hole with dual jet pump completion setting BHA at 11,400ft. r,, s lai A f`/� 4^` 23. Land hanger,set BPV(X2), nipple down BOP, nipple up tree and test. 1`e�s-/- a. Pull BPV 24. Turn well over to production. 25. Complete'No Flow'test in accordance with AOGCC regulations(20 AAC 25.265.Well safety valve systems, section.h). Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Current/Proposed Wellhead Diagram(same) 4. BOP Stack Bruce Platform ALA.s KA 008E Team Well No. 42-42 UNOCAL. Coil Jet Completion 2/9/06 CASING AND TUBING DETAIL API#50-733-20451-00 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head =44.30' 18-5/8" 87.5# X-56 Dril-Quip 17.755" Surface 1,220' t�l1 13-3/8" 68# K-55 Butt. 12.415 Surface 4,135' 'i - 9-5/8" 53.5# L-80 Butt. 8.535 Surface 10,321' 7-5/8"Liner 39# P-110 FL-45 LATERAL Window @10,515'to 10,526' 3 1/2"slotted 9.3# 6.625" 9,991' 11,708' TD - 11,813' EZSV 11,669' ECP Top @ 10,547' Packer A L-80 Butt. 2.992" 10,547' 11,622' liner TD- 11,655' TUBING Long String IL 3-1/2" 9.3# N-80 Buttress 2.992" 45' 9,912' Short String 3-1/2" 9.3# N-80 Buttress 2.992" 45' 9,902' JEWELRY DETAIL Z. , NO. Depth ID OD Item . 44.30' Tubing Hanger, 13-5/8",5M,Vetco Dual 3-1/2"x 1' 1 9,912' 2.992 3.75 X-Over,3-1/2"Butt.x 3-1/2" 8rd.EUE x 1' B 2 9,913' 2.687 7.25 Kobe,3"'Dbl D',Cavity x 28'Long 1 C S 3 9,941' 3.00 4.25 3-1/2"Ported Sub x 2.24"long (7.02 sq.in.flow) D 4 9,943' 2.992 4.50 3-1/2"x 11'Pup Joint,8rd,N-80 15 5 9,954' 1.99 4.50 X-over,3-1/2"8rd x 2-3/8"8rd x 1' EA6 9,955' 0.00 2.625 2-3/8"Blank Sub F 7 9,955' 1.99 2.875 X-over,2-3/8"8rd x 2-7/8"8rd G 8 9,956' 2.51 4.56 2-7/8"Pressure Transfer Sub 14 9 9,957' 2.50 3.50 X-over,2-7/8"8rd x 2-7/8"BTC 1 imk15 10 9,957' 2.441 3.50 11 jts.2-7/8" BTC,6.4#,N-80 tubing - 2 -.i. 11 10,307' 2.441 3.50 X-over,2-7/8"BTC x 2-7/8"8rd ��,� 12 10,308' 0.00 4.625 Vann 4-5/8"TCP Gun Assembly(1355'long) .11b13 11,663' 2.441 3.66 2-7/8"Mule Shoe x 3'—EOT @ 11,666' 3 6_ — Short String ._- 14 9,902' 1.99 4.50 X-Over,3-1/2"BTC x 2-3/8"8rd EUE x 1' 15 9,903' 1.99 3.00 Pup,2-3/8"8rd EUE x 10' n g, • , COIL TUBING JET INSTALLATION ECP 0 \. To 1.688 2.00 Coil Tubing 2",.156"Wall Thickness Packer 9,800' Top @ • isr 9,801' 1.688 2.438 Coil Connector w/6'x 2-1/16"IJ pup joint 10,547' B. 9807' 1.600 2.750 2-1/16"IJ x 1.900"NU 10 rd X-over,centralizer& � 1.900'NU lOrd x 5'pup joint C. 9,812' 1.393 2.26 1-1/2"Oilmaster Jet Pump Cavity 0 • D. 9,817' 1.75 2.75 Locator Seal Assy.W 5'of seals buried in PBR To E. 9,817' 1.75 2.78 PBR w/RS Snap latch Seal Assy.(14.4K Shear) #13 F. 9,829' 1.810 2.80 WOTCO 3-1/2"Model ER Packer(Bottom @9832') «, G. 9,883' Tbg punch shot w/10'x 1-9/16"gun. Hole size= 0.39"x 39 holes=4.66 so.in.of flow area 0 M Fish o — .w'. 0 NO. Depth Length Item ITop1 0 40I 11,200' 297' 9-1/2 jts.of 2-1/16",3.25#,CS Hydril tubing fish inside the 3-1/2"lateral's slotted liner. Cut off top @ 11,200' imfr '" 2. 9,943' 1,724' 11/18/99—Cut off TCP gun assembly @ 9942'—appears Zit only dropped 1'according to well service reports. TD @ 11,813' REVISED BY: BGA EZSV Set @ 11,669' 2/9/06 Iruce Platform ...L,..sK... 008E TeamWell No. 42-42 76 uNOCAL Coil Jet Completion 2/9/06 PERFORATION HISTORY '/ Interval Accum. Date Zone Top Btm Amt spf Comments 11/4/1993 C-3 10,310' 10,402' 92' 6 4-5/8"Vann TCP Guns 11/4/1993 C-5 10,561' 10,700' 139' 6 4-5/8"Vann TCP Guns 11/4/1993 C-6 10,980' 11,000' 20' 6 4-5/8"Vann TCP Guns 11/4/1993 C-7 11,075' 11,135' 60' 4 4-5/8"Vann TCP Guns 11/4/1993 C-7 11,176' 11,400' 224' 4 4-5/8"Vann TCP Guns 11/4/1993 C-7 11,418' 11,440' 22' 4 4-5/8"Vann TCP Guns 11/4/1993 C-7 11,470' 11,552' 82' 4 4-5/8"Vann TCP Guns 11/4/1993 C-7 11,612' 11,662' 50' 4 4-5/8"Vann TCP Guns TD @ 11,813' REVISED BY: BGA EZSV Set @ 11,669' 2/9/06 Bruce Platform a ii PROPOSED Well No. 42-42 Completed: Future liikorp Alaska,LLC CASING AND TUBING DETAIL API #50-733-20451-00 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head =44.30' 18-5/8" 87.5# X-56 Dril-Quip 17.755" Surface 1,220' 13-3/8" 68# K-55 Butt. 12.415" Surface 4,135' 'i 9-5/8" 53.5# L-80 Butt. 8.535" Surface 10,321' 7-5/8"Liner 39# LATERAL P-110 FL-45 6.625" 9,991' 11,708' TD - 11,813' EZSV 11,669' Window @10,515'to 10,526' ECP Pkr Top @ 10,547' "Slotted 9.3# L-80 Butt. 2.992" 10,547' 11,622' 4. Liner ING TD 11,655' TUB3.5 Long String 2 7/8" 6.5 L 80 EUE 2.441 Surf ±11,440' I' '. 2-7/8" 6.5 L-80 Sprmx SC 2.441 ±9,900 ±11,440' 1' 11 Short String I 2-7/8" 6.5 L-80 EUE 2.441 Surf ±9,900' 2-3/8" 4.6 L-80 Sprmx SC 1.995 ±9,900' ±11,400' Z JEWELRY DETAIL NO. Depth ID OD Item _ 44.30' Tubing Hanger,13-5/8",5M,Vetco Dual 3-1/2"x 1' 1 ±11,400' Kobe 2.5in MVSR 2 ±11,440' Ratcheting Mule Shoe 1 14 Fish 15 NO. Depth Length Item 2 (Top] I 11,200' 297' 9-1/2 jts.of 2-1/16",3.25#,CS Hydril tubing fish inside 3 the 3-1/2"lateral's slotted liner. Cut off top @ 11,200' X ' , Perforation Detail ECP _ Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Comments Packer Top c@i * C-3 ±10,310' ±10,402' ±8,380' ±8,468' ±92' 6 11/4/1993 Re 10,547' I I11:',FLaiC-5 ±10,561' ±10,700' ±8,618' ±8,748' ±139' 6 11/4/1993 Re-pert 1 I11 C-6 ±10,980' ±11,000' ±9,009' ±9,028' ±20' 6 11/4/1993 Re-perf III C-7 ±11,075' ±11,135' ±9,099' ±9,156 ±60' 4 11/4/1993 Re-perf 40 C-7 ±11,176' ±11,400' ±9,196' ±9,418' ±224' 4 11/4/1993 Re-pert DC C-7 ±11,418' ±11,440' ±9,436' ±9,458' ±22' 4 11/4/1993 . Re-perf C-7 ±11,470' ±11,552' ±9,488' ±9,570' ±82' 4 11/4/1993 . Re-perf 0 C-7 ±11,612' ±11,662' ±9,630' ±9,680' ±50' 4 11/4/1993 Re-perf M w w TD @ 11,813' EZSV Set a 11,669' Updated: 03/10/15 by DRT II Bruce Platform BR-18742-42 Current 02/25/2015 Hileurp:%luakn,l.0 Tubing hanger,Vetco, Bruce MB-107,Dual,13 5/8 X 3 X 42-42 IBT lift and susp,w/3"type 18 5/8 X 13 3/8 X 9 5/8 X H BPV profile,w/Flex neck 3 K x 3)4 and''/.control line nipple, 5 3/64 centers I iI 1 m m / © / Coil tubing head,WCI,RH-4,3 1/8 I I I 5M 5 bolt FE X 21/165M EFO,2' coil tubing slip and seal asry III IP II s S II ri X11 -III KI j LI 1 3 1/8 SM 5bolt FE,HWO, ( ual,Vetco, ilk 0ai , AA trim IIUS ��O I 10, Adapter,Vetco-Dual, EwaSMultibowl,MB-107, •_;,•jp O 31/88 SSM7GraylocX 5M 5 bolt stdd top, X20-GR192 Grayloc bottom X -1 . ttpreppeddXfor Flextlnecklhangerit55 137(13 5/8 SM)GraylocOI O anconroine ex 4-21/16 SM SSO " _l� u� I t =11_•, of 1 � `- I • _��' .�r — MMI !=" `, = All wellhead valves t' 1 2 1/16 SM VG-100 itiriCasing head,CWC-LT,18 5/8 • = =' • SOW bottom x X20-GR192 Grayloc top,arranged for Regan starting head, — �1 2-V 1P0 q�l9 .i II"'O -�I-1.-i I 18 5/8" 13 3/8" 1 9 5/8" 3'/=„I 3 h,. L Bruce Platform • BOP Stack Moncla 02/25/2015 Bruce Platform 2015 Workovers BOP Drawing Moncla I . �I 4.54' HYdrildr GK 13 5/8-500 IF III In IF I I CU 2 7/8-5 variables or Cameron 4.67' dual flex rams P' - Blinds 11111111 iii i►i I11 I�1 In 2.00' Kill Side 1c Choke side 3 1/8 5M w/HCR ,OIII : a : III3 1/85Mw/HCR r 1.00'to 2.00' Ill I l l l l' Ili I l l Drill deck 11.00' Riser 13 5/8 5M FE X 13 5/8 5M FE ii lil Iti III Ili 111 I11 II! III Spacer spool 2.00 13 5/8 5M FE X 13 5/8 5M FE 111 Ili Ill Ill Li' Moncla Rig 404 BOP Test Procedure Hilcorp Ala ka,IJ.0 Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, Grayling WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,►.i.c Attachment#1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile /penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. Moncla Rig 404 BOP Test Procedure eaco.P:uaSka,�.►.�. Attachment#1 d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3,4, 9. After test, open valves 3 &4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5&6, leave 9 closed. iv) Valves, 7, 8, 9. After test,open all valves. e) Close C-2. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test ioint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW(or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. OF To (4:. vI�j„. ATHE STATE Alaska Oil and Gas �'� °fALA Conservation Commission i= = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS�P Fax: 907.276.7542 www.aogcc alaska.gov February 12, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification SCANNED M 11 !ll Granite Pt State 18742 #42 PTD 1930730 Dear Mr. Golis: On January 30, 2015 Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspectors witnessed no-flow tests of Granite Point State 18742 #42 located on the Bruce Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Granite Point State 18742 #42 prior to the test. The well performance was monitored for three hours with resulting flow rates (oil and gas) below the regulatory limits,passing the no-flow test. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Granite Point State 18742 #42 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Bruce Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '"d��' �e DATE: 1/30/15 P. I. Supervisor FROM: Jeff Jones SUBJECT: No Flow Test Petroleum Inspector Granite Pt State 18742 #42 - Hilcorp PTD 1930730 ' 1/30/15: I traveled to Hilcorp's Granite Point Field Bruce platform to witness a No Flow test performed on Well 42. Stuart Allison represented Hilcorp for the test today and he performed the test in a safe and proficient manner. An Armor Flo model 3461-03-T033 flow meter with a 150-1500 scfh span was lined up from the well production to an open top container and monitored for 3 hours. - The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 9:30 150 None 10:00 150 • None 10:30 150 - None 11:00 150 None 11:30 150 None 12:00 150 None 12:30 150 None 1 Pressures are T/IA/OA Summary: Granite Pt State 18742 Well 42 meets the AOGCC criteria for a No Flow - designation. Attachments: None SCANNED r,, f. 2015-0130_No-Flow_GranitePt_State_18742_42_i j.docx Page 1 of 1 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION MAR 0 9 2006 REPORT OF SUNDRY WELL OPERATIONS AI k . as a 0" & Gas Cons. Commission 1. Operations Abandon Repair Well Plug Perforations Stimulate Other .j nc aigePump " Performed: Alter Casing D Pull TubingD Perforate New Pool D WaiverD Time ExtensionD Installation Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Name: Development E! ExploratoryD 193-073" 3. Address: PO Box 196247, Anchorage, AK 99519 StratigraphicD ServiceD 6. API Number: 50-733-20451-00 ,. RECEIVED 7. KB Elevation (ft): RKB to TBG head = 44.30' 8. Property Designation: Bruce Platform/Cook Inlet 11. Present Well Condition Summary: 9. Well Name and Number: . GRANITE PT ST 1874242; Br 42-42 10. Field/Pool(s): Granite Point/Middle Kenai Oil .I Total Depth measured 11,813' feet true vertical 9,781' feet Effective Depth measured 9,943' feet true vertical 8,025' feet Casing Length Size MD Structural Conductor 1,220' 18-5/8" 1,220' Surface 4,135' 13-3/8" 4,135' Intermediate 10,321' 9-5/8" 10,321 ' Liner 1,717' 7-5/8" 11,708' Slotted Liner 1,075' 3-1/2" 11,622' Plugs (measured) n/a Junk (measured) n/a TVD Burst Collapse 1,219' 3,615' 3,450 1,950 8,390' 7,930 6,620 9,708' 12,620 11,060 9,624' Perforation depth: Measured depth: 10,310-11,662' True Vertical depth: 8,380-9,656' Tubing: (size, grade, and measured depth) LS: 3-1/2" 9.3# N-80 @ 9,912'; SS 3-1/2" 9.3# N-80 @ 9,902' Packers and SSSV (type and measured depth) n/a 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a RBDMS BFL '.I,!I! 'I~' r ,J L ! ~.~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 31 26 136 44 40 75 15. Well Class after proposed work: ExploratoryD Development E! 16. Well Status after proposed work: OilE! Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 152 156 Tubing Pressure 66 68 Service D x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 305-357 Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Phone 907-276-7600 Date 3. '-:5;? '-0'= GIN A ~FE 164707 k"tþ -; ''Îo~ Submit Original Only ./ ~ $/t~/~ BR 42-42 Primary Job Type Recompletion Jobs Daily Operations 1/30/200600:00 -1/31/2006 00:00 Operations Summary Unload coil work deck wait on WOTCO parts 1/31/200600:00 - 2/1/2006 00:00 Operations Summary Isolate & removed flowline. AOGCC waived witness of CT BOPE test. RU EL on SS. Ran correlation log. Punched tubing @ 9881' to 9891' w/31 x 0.39" holes (3.70 sqin flow area). Set "ER" pkr w/ shear-out plug @ 9861'. RD EL. Fill SS w/ power oil. Pressure test to 500 psi. 2/1/200600:00 - 2/2/2006 00:00 Operations Summary Complete coil tubing RU, Test BOPE. 2/2/200600:00 - 2/3/2006 00:00 Operations Summary CTC would not fit on CT. sent to beach and refab same. MU CTC & BHA, Test same. Stab injector head. Shell test BOPE. Replace O-ring on quick union. Shell Test BOPE. RIH 4.4'. PBR landed/stuck in CT hanger bowl. Sheared seal assembly. SDFN wait on pulling tool for PBR. 2/3/200600:00 - 2/4/2006 00:00 Operations Summary Remove stuck PBR. Have same turned down to 2.75". MU BHA. Stab injector head. Shell Test BOPE. RIH w/ coil tubing, Tag pkr @ 9864' CTM. No Joy on latching anchor into pkr. 2/4/200600:00 - 2/5/2006 00:00 Operations Summary Continue to attempt to snap WOTCO RS anchorlatch seal assembly into WOTCO ER packer with no luck, POOH w/ CT to inspect tools. Pressure up on tbg to 2,000 psi. Shear shear-out on pkr. Stand-Down CT crew. RU Slickline. Wait-on pulling tool. RIH latched pkr @ 9861'. POOH wll packer. 2/51200600:00 - 2/6/2006 00:00 Operations Summary RI w/ Pkr retrieving tool. POOH w/ pkr. found pkr had failed and shear plug had not sheared. Suspend operations. Work on forward plan, 2/6/200600:00 - 2/7/2006 00:00 Operations Summary Spot/RU Eline. MU "ER" pkr onto setting tool. RIH set pkr @ 9832'. POOH. Found fine metal shavings on CCL. 2/7/200600:00 - 2/8/2006 00:00 Operations Summary Test Packer. Made multiple slickline runs w/ magnet to clean metal shavings from well. 2/8/200600:00 - 2/9/2006 00:00 Operations Summary Continue Slickline magnet runs. RU Coil. PUlMU Hydraulic Cavity BHA. Shell Test BOPE. RIH to 9730'. CBU. Rllatch packer@ 9803'. Test same. Plug sheared prematurely. Work on forward plan. 2/9/200600:00 - 2/10/200600:00 Operations Summary Shear PBR, pull out of seal assembly, space out, land tubing, ND BOP, NU master valve. Secure Coil.' 2/10/200600:00 - 2/11/2006 00:00 Operations Summary 2/11/200600:00 - 2/12/2006 00:00 Operations Summary Load out all Coil Equipment to Dock or Grayling. API # 50-733-20451-00 RKB to TBG Head = 44.30' PBTD = 11,813' MD (' TVD) TD = 11,669' MD (' TVD) DRAWN BY: BGA Revised 02/28/06 CRW SIZE \-vT GRADE CONN II) TO!' BTM. 18-5/8" 87.5# X-56 Dri]-Quip ]7,755" Surf a ],220' ] 3-3/8" 68# K-55 Butt, 12.415" Surfa 4,135' 9-5/8" 53.5# L-80 Butt 8,535" Surtàce ]0,321' 7 - 5/8" Liner 39# P-IIO FL-45 6,625" 9,991' 11,708' TD - 11,813' EZSV ]],669' LATERAL Window úìnO,515' to 10,526' ECP Packer Top(ii¡ 10,547' 3-1/2" slotted 9.3# L-80 Butt. 2,992" ]0,547' 11,622' liner TD- ] 1,655' TUBiNG Long String 3-1/2" 9.3# N-80 Buttress 2,992" 45' 9,912' Short String 3-1/2" 9.3# N-80 Buttress 2,992" 45' 9,902' NO, I Depth In OD itcm 44.30' Tubing Hanger, 13-5/8", 5M, Vetco Dua] 3-1/2"x l' ] 9,912' 2.992 3.75 X-Over, 3-1/2" Butt. x 3-1/2" 8rd. EUE x ]' 2 9,913' 2.687 7.25 Kobe, 3" 'Dbl D', Cavity x 28' Long 3 9,941' 3.00 4.25 3-1/2" Ported Sub x 2,24" long (7,02 sq, in, flow) 4 9,943' 2.992 4.50 3-1/2" x II' PuP Joint, 8rd, N-80 5 9,954' 1.99 4.50 X-over, 3-1/2" 8rd x 2-3/8" 8rd x I' 6 9,955' 0.00 2,625 2-3/8" Blank Sub 7 9,955' 1.99 2.875 X-over, 2-3/8" 8rd x 2-7/8" 8rd 8 9,956' 2.51 4.56 2-7/8" Pressure Transfer Sub 9 9,957' 2.50 3.50 X-over, 2-7/8" 8rd x 2-7/8" BTC 10 9,957' 2.441 3.50 I] its, 2-7/8" BTC, 6.4#, N-80 tubing II 10,307' 2.44] 3.50 X-over, 2-7/8" BTC x 2-7/8" 8rd 12 10,308' 0,00 4.625 Vann 4-5/8" TCP Gun Assemb]v (1355' long) 13 11,663' 2.441 3,66 2-7/8" Mu]e Shoe x 3' - EOT @ 11,666' Short String 14 9,902' 1.99 4.50 X-Over, 3-1/2" BTC x 2-3/8" 8rd EUE x I' 15 9,903' 1.99 3.00 Pup, 2-3/8" 8rd EUE x 10' A. 9,800' 1.688 2.00 Coil Tubing 2", .156" WaH Thickness 9,800' Coil Connector wi pups, XO, Centralizers, jewlery B. 9,812' 2.25 1-1/2" Oilmaster Jet Pump Cavity C. 9,817' 1.75 Locator Seal Assy. W 5' of seals in PBR D, 9,817' 2.390 PBR wi WOTCO Snap Latch Seal Assy, E. 9,832' 1.810 WOTCO ER Pck NOTi'C PIlckCl'dCî'!lICd 9881 Thg punch shot w' ]0' x ]-9/16" gun, Hole size = 0.39" x 31 holes = 3.70 sqin of flow ares Da te 11/4/1993 11/4/1993 11/411993 11/4/1993 11/4/1993 11/411993 11/411993 11/4/1993 " Vann T CP Guns " Vann TCP Guns " Vann TCP Guns 2. 9,943' 9-1/2jts. of2-1/16" ,3,25#, CS Hydril tbgfish in the 3-1/2" lateral's slotted !iner. Cut to @) 11,200' 1,724' 11/18/99 - Cut offTCP gun assembly @ 9942' - appears it dropped l' accord to well service re orts. e [ûJ.,' ~.. '. r? ~ : : ~ 6 ,I U e AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: Granite Point St 1874242; Br 42-42 Sundry Number: 305-357 ~ ~ñ'1j. Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 2300 day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, $CANNEG DEC 1 (52005 DATED-thi~~ay of November, 2005 Encl. ® 'I,'.'~ 1. Type of Request: CflJ¡I-¡6-0b a STATE OF ALASKA _ A~ OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Al \<6 Suspend Repair well 0 Pull Tubing 0 Abandon Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: Perforate Waiver Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to D9JI, Dr" Number: 3-073 V Other J CT Jet Pump Installation Development Stratigraphic G o Service Exploratory 0 o PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): RKB to TBG Head = 44.30' 8. Property Designation: Bruce Platform/Cook Inlet 11. Total Depth MD (ft): 11,813' Casing Structural Conductor Surface Intermediate Liner Slotted Liner Perforation Depth MD (ft): 10,310'to 11,662' Packers and SSSV Type: Total Depth TVD (ft): 9,781' Length 9. Well Name and Number: GRANITE PT ST 1874242; Br42-42 10. Field/Pools(s): Granite Point/Middle Kenai ~/,I. PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11,669' 9,662' Size MD TVD Burst Collapse 1,220' 18-5/8" 4,135' 13-3/8" 10,321' 9-518" 1,717' 7-5/8" 1,075' 3-1/2" Perforation Depth TVD (ft): 8,380' to 9,656' 1,220' 4,135' 10,321 ' 11,708' 11,622' Tubing Size: 1,219' 3,615' 8,390' 9,708' 9,624' Tubing Grade: 3,450 7,930 12,620 1,950 6,620 11,060 Tubing MD (ft): LS: 9,912'; SS: 9,902' LS: 3-1/2"; SS 3-1/2" 9.3#, N-80 Packers and SSSV MD (ft): n/a n/a 12. Attachments: Description Summary of Proposal Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 907-276-7600 Date COMMISSION USE ONLY .j 13. Well Class after proposed work: Exploratory 0 Development G Service 0 15. Well Status after proposed work: 12/12/2005 Oil G Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Date: Steve Tyler 263-7649 1(- .I a.~ . . ~1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 Other: 5tX)O ~'='>\ Approv Sundry Number: BOP Test ~ Mechanical Integrity Test 0 Location Clearance ti:.~ I? -'t,,-\- 0-<'" \' b..,,~ . o RBDMS BFl NOV 2 j 2005 COMMISSIONER APPROVED BY THE COMMISSION AFE 164700 RIG I f~ A L Submit in Duplicate Form 10-403 Revised 07/2005 . e e Bruce 42-42 API# 50-733-20451-00 CT Jet Pump Installation Work Summary · MIRU E-line onto SS, PU/MU tbg punch, Punch tbg above 2-3/8" XO · PUMU pkr wi shear plug, RIH set @ 9,888'. POOH. RD · Fill tbg wi Diesel. Pressure testto 500 psi. · Turn-key CT load-out · Turn-key RU CT on into wellhead controls work window. · CT Acceptance, PUMU hydraulic cavity, PBR and snaplath seal assy. · RIH latch packer, shear-out ofPBR, Allow CT to nonnalize to temp. RI stab into PBR. Land CT. · Cut CT. NU swab valve. Release CT to turn-key demob. · Load-out CT equipment · Blow-out shear disc. Circ pump on depth. · Turn well over to production. . 1 API # 50-733-20451-00 RKB to TBG Head = 44.30' 18-5/8" 87.5# X-56 Dril-Quip 17.755" Surface 1,220' 13-3/8" 68# K-55 Butt. 12.415" Surface 4,135' 9-5/8" 53.5# L-80 Butt. 8.535" Surface 10,321' 7-5/8" Liner 39# P-110 FL-45 6.625" 9,991' 11 ,708' TD - 11,813' EZSV 11,669' LATERAL Window @1O,515' to 10,526' ECP Top@ 10,547' Packer 3-1/2" slotted 9.3# L-80 Butt. 2.992" 10,547' 11,622' Hner TD- 11,655' TUBING Long String 3-1/2" 9.3# N-80 Buttress 2.992" 45' 9,912' Short String 3-1/2" 9.3# N-80 Buttress 2.992" 45' 9,902' 44.30' Tubing Hanger, 13-5/8", 5M, Vetco Dua13-1/2"x l' 1 9,912' 2.992 3.75 X-Over, 3-1/2" Butt. x 3-1/2" 8rd. EVE xl' 2 9,913' 7.25 Kobe, 3" 'Dbl D', Cavity x 28' Long 3 9,941' 3.00 4.25 3-1/2" Ported Sub x 2.24" long (7.02 sq. in. flow) 4 9,943' 2.992 4.50 3-1/2" xli' Pup Joint, 8rd, N-80 5 9,954' 1.99 4.50 X-over, 3-1/2" 8rd x 2-3/8" 8rd xl' 6 9,955' 2.625 2-3/8" Blank Sub 7 9,955' 1.99 2.875 X-over, 2-3/8" 8rd x 2-7/8" 8rd 8 9,956' 2.51 4.56 2-7/8" Pressure Transfer Sub 9 9,957' 2.50 3.50 X-over, 2-7/8" 8rd x 2-7/8" BTC 10 9,957' 2.441 3.50 11 jts. 2-7/8" BTC, 6.4#, N-80 tubing 11 10,307' 2.441 3.50 X-over, 2-7/8" BTC x 2-7/8" 8rd 12 10,308' 0.00 4.625 Vann 4-5/8" TCP Gun Assembly (1355' long) 13 11,663' 2.441 3.66 2-7/8" Mule Shoe x 3' - EOT @ 11,666' Short String A 9,902' 1.99 4.50 X-Over, 3-1/2" BTC x 2-3/8" 8rd EUE xl' B 9,903' 1.99 3.00 Pup, 2-3/8" 8rd EVE x 10' 11,200' 297' 9-1/2 jts. the 3-1/2" lateral's slotted Hner. Cut off top @ 11,200' 2. 9,943' 1,724' 11118/99 Cut offTCP gun assembly @ 9942' - appears it only dropped l' according to well service reports. PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 11/4/1993 C-3 10,310' 10,402' 92' 6 4-5/8" Venn TCP Guns 11/4/1993 C-5 10,561' 10,700' 139' 6 4-5/8" Vann TCP Guns 11/4/1993 C-6 10,980' 11,000' 20' 6 4-5/8" Vann TCP Guns 11/4/1993 C-7 11,075' 11,135' 60' 4 4-5/8" Vann TCP Guns 11/4/1993 C-7 11,176' 11 ,400' 224' 4 4-5/8" Vann TCP Guns 11/4/1993 C-7 11,418' 11 ,440' 22' 4 4-5/8" Vann TCP Guns 11/4/1993 C-7 11,470' 11,552' 82' 4 4-5/8" Vann TCP Guns 11/4/1993 C-7 11,612' 11,662' 50' 4 4-5/8" Venn TCP Guns TD @ 11,813' DRAWN BY: BGA EZSV Set @ 11,669' 7/15/05 API # 50M733M20451-00 RKB to TBG Head = 44.30' 18-5/8" 87.5# X-56 Dril-Quip 17.755" Surface 1,220' 13-3/8" 68# K-55 Butt. 12.4 15" Surface 4,135' 9-5/8" 53.5# L-80 Butt. 8.535" Surface 10,321' 7-5/8" Liner 39# P-11O FL-45 6.625" 9,991' 11,708' TD - 11,813' EZSV 11,669' LATERAL Window @10,515' to 10,526' ECP Top@ 10,547' Packer 3-1/2" slotted 9.3# L-80 Butt. 2.992" 10,547' 11,622' liner TD- 11,655' TUBING Long String 3-1/2" 9.3# N-80 Buttress 2.992" 45' 9,912' Short String 3-1/2" 9.3# N-80 Buttress 2.992" 45' 9,902' 44.30' Tubing Hanger, 13-5/8", 5M, Vetco Dual 3-1/2"x I' I 9,912' 2.992 3.75 X-Over, 3-112" Butt. x 3-1/2" 8rd. EUE x I' 2 9,913' 7.25 Kobe, 3" 'Dbl D', Cavity x 28' Long 3 9,941' 3.00 4.25 3·1/2" Ported Sub x 2.24" long (7.02 sq. in. flow) 4 9,943' 2.992 4.50 3-1/2" x 11' Pup Joint, 8rd, N-80 5 9,954' 1.99 4.50 X-over, 3-1/2" 8rd x 2-3/8" 8rd xl' 6 9,955' 2.625 2-3/8" Blank Sub 7 9,955' 1.99 2.875 X-over, 2-3/8" 8rd x 2-7/8" 8rd 8 9,956' 2.51 4.56 2·7/8" Pressure Transfer Sub 9 9,957' 2.50 3.50 X-over, 2-7/8" 8rd x 2-7/8" BTC 10 9,957' 2.441 3.50 11 jts. 2·7/8" BTC, 6.4#, N-80 tubing 11 10,307' 2.441 3.50 X-over, 2-7/8" BTC x 2-7/8" 8rd 12 10,308' 0.00 4.625 Vann 4-5/8" TCP Gun Assembly (1355' long) 13 11,663' 2.441 3.66 2-7/8" Mule Shoe x 3' - EDT @ 11,666' Short String 14 9,902' 1.99 4.50 X-Over, 3·112" BTC x 2-3/8" 8rd EUE xI' 15 9,903' 1.99 3.00 Pup, 2-3/8" 8rd EUE x 10' 2. 11,200' 9,943' 297' 9-1/2jts. of2-1I16" ,3.25#. CS Hydril tubing fish inside the 3-1/2" lateral's slotted liner. Cut off top @ 11,200' 1,724' 11/18/99 - Cut offTCP gun assembly@ 9942' - appears it only dropped l' according to well service reports. PBTD = 9,875' MD (9,853' TVD) TD = 10,330' MD (10,105' TVD) TD @ 11,813' EZSV Set @ 11,669' DRAWN BY: BGA 10/24/05 - enee Platform Well No. 42-42 Proposed Coil Jet Completion - -- &- ~ AL....SK.... OO&E Team - ~ UNOCAL8 PERFORA nON HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 11/4/1993 C-3 10,310' 10,402' 92' 6 4-5/8" Vann TCP Guns 11/4/1993 C-5 10,561 ' 10,700' 139' 6 4-5/8" Vann TCP Guns 11/4/1993 C-6 10,980' 11,000' 20' 6 4-5/8" Vann TCP Guns 11/4/1993 C-7 11,075' 11,135' 60' 4 4-5/8" Vann TCP Guns 11/4/1993 C-7 11 ,1 76' 11 ,400' 224' 4 4-5/8" Vann TCP Guns 11/4/1993 C-7 11,418' 11,440' 22' 4 4-5/8" Vann TCP Guns 11/4/1993 C-7 11,470' 11,552' 82' 4 4-5/8" Vann TCP Guns 11/4/1993 C-7 11,612' 11,662' 50' 4 4-5/8" Vann TCP Guns TD @ 11,813' EZSV Set @ 11,669' DRAWN BY: BGA 10/24/05 RE: GP St. 42 (193-073) e e Suhjcctt RE: GP St. 42 (193-073) J<'rom: "Tyler, Steve L" <tylcrsl@unocal.com> Date: Fri. 18 Nov 2005 11 :56:25 -0900 To: Thomas Maunder <tom maundcr~l5admin,statc.ak.us> -..- ,,~ CC: "Walsh, Chantal -Pctrotcchnical" <walshc@unocal.com>, "Brandenburg, Tim C" <hrandenburgt@unocal.com> Hey Tom Do you need a more detailed procedure type description than the work summary we submitted? Attached is a BOP diagram with the Work Window, We'll pressure test our BOP pipe & bind rams to 300 psi low and 5000 psi high We'll be utilizing Schlumberger 2" CT and unit. Let me know if you need anything else \\ \~ t..< '-<:>~ ~ \:::, \W..~~~~,>\-'ì~~ cP~~ ''0 \.)\~ ~O.\ \ ~~~ "\ ~ c)., \<tCt.. \<:- ~\ ~ (\ '-\ , .. ~ T"\'" \... ~..i\~~~ ~<t\, ç~~\,~o-~- I' .. !\ b,\ \\.-cc ".-o\)~\~ ~ ~C-r \-~.ç;~\~ If \('(.~<c \. ~~~~ Öð~f'.. ~t. \\l~ <¡, S~\f D.~~"c,..<::-<:.Q~~ ~ \t.~t>~~þ -----Original Message-----' ~ Æ~ From: Thomas Maunder [rnailto:torn maunder@admin.s'Cate.ak.us] 7M {t¡ Sent: Friday, November 18, 2005 10:53 AM l~ To: Steve Tyler Subject: GP St. 42 (193-073) Steve Tyler TBA Union Oil Company of California (Office: (907) 263-7649 (Cell: (907) 350-6295 (Home: (907) 696-1837 Hi Steve, Looking at your coil jet-pump proposal. Nice to see some work planned. Could you provide a description of the work?? Also, whose CTU?? Do you have a BOP diagram?? What test pressure do you propose?? Thanks, Tom Maunder, PE AOGCC BOP & window Hyd Jet C t t D . t· CT BOP & window Hyd Jet on en - escnp Ion: P d ump. oc application/msword base64 Content-Type: Content-Encoding: 1 of! 11/18/2005 12:59 PM Re: GP St. 42 (193-073)--additional e e Suh.icct:· Rc: GP St. 42 (193-073)--additional From: Thomas Maunder <tom_ßlé.lUndcr@admin,statc.ak.us> Date: Fri, 18 Nov 2005 II :38:46 -0900 To: Steve Tyler <.tylcrsl@unocal.com> Steve, I have looked into the file on this well. Interesting, an early motherbore and lateral. More than their fair share of fishing problems, although it appears they were fairly successful recovering the fishes. The last correspondence in the file is a Commission letter dated April 7, 1999 regarding the API number. Aside from some document transmittals, the last major item submitted by Unocal was the completion report submitted at the end of December 1993. Is there more information regarding any wellwork in your file?? Call me and we can discuss. If a operational summary can be generated, that might suffice to complete the record on this well. Thanks Steve. Look forward to your call. Tom Thomas Maunder wrote, On 11/18/2005 10:53 AM: Hi Steve, Looking at your coil jet-pump proposal, Nice to see some work planned. Could you provide a description of the work?? Also, whose CTU?? Do you have a BOP diagram?? What test pressure do you propose?? Thanks, Tom Maunder, PE AOGCC 1 of 1 11/18/2005 11:42 AM Coil Tubi s BOP & Window Wellhead Control's Work Window - - BRUCE PLATFORM API # 50-733-20451-00 GRANITE PT. ST. 18742 # 42 WELL HISTORY LAST WORK: October 21, 2005 LAST UPDATED: October 25,2005 by BGA Date Work Periormed 1993 6/28 Spud. 11/4 Completed as a development oil well w/ dual 3-1/2" tubing strings & a Kobe 3-1/2" 'DO' Hydraulic Pump Bottomhole Assembly set @ 9912' MO top. Perforated with 4-5/8" Vann TCP guns; C-3, 5, & 6 w/6 HPF; C-7 w/4 HPF: C-3 C-5 C-6 C-7 10310-10402' 10561-10700' 10980-11000' 11075-11135' 11176-11400' 11418-11440 11470-11552' 11612-11662' 689' 92' 139' 20' 60' 224' 22' 82' 50' The well is also open to a lateral well drilled to 11655' and completed outside of the parent well in the C-5 from 10520-11621, with a 3-1/2" slotted liner. The well was complete 1114/93 as a pumping oil well. Initial production was 434 BOPO, 63 BWPO, 217 MCFO. 1999 11/17 W/L - RIH to equalize S,V. @ 9937' KB. Well went on a vacuum. POOH. RIH - pulled S.V. from 9937' KB. POOH. RIH w 2.57" GR - set down solid @ 9942' KB (Actually 9992' WLM). POOH. RD. 11/17-11/18 APRS - Several operations but finally RIH w/ 2-1/8" decentralized Jet Cutter to 9943' TM. PU to 9942' TM. Fired cutter @ 9942' - no indication it fired. POOH wI cutter - it had fired. 11/18 W/L - RIH w/ 2.25" 18. set down @ 9993' WLM (1' deeper than before). Jar down once, PU clean, POOH. RIH wI SV. to fluid level @ 2100'. Shake off. POOH. - e 2000 2/29 W/L - RIH wI knockout tool to 9937' KB. Well went on vacuum. POOH. RIH to 9937' KB - pulled S.v. POOH. RIH wI 2.25" pump bailer to 9945' KB, tagged obstruction, POOH with bailer empty. RIH wI S.v. to fluid level @ 6520' KB, shook off S.V., POOH. 2001 11/14-11/17 W/L - RIH wI EQ (equalizing prong) to 9940', well went on vacuum, POOH. RIH wI Kobe PT (pulling tool) to 9942', hit several OJ licks, POOH, 2 dogs missing on PT, No S.v. RIH wI Kobe PT to 9942', hit several OJ licks, POOH, 3 dogs missing this time from PT, No S.V. RIH again wI Kobe PT to 9942', hit 1 - 1150# OJ lick, POOH, 3 dogs again missing from PT, No S.V. RIH w Kobe EQ to insure knockouts were broken, POOH. RIH wI Kobe PT to 9942', hit 3 OJ licks, slipped out, POOH, 1 dog missing. RIH wI Kobe PT to 9942', hit 1 - 1000# OJ lick, slipped out, POOH. RIH wI 2.82" GR tagged fluid @ 380', POOH, shoot fluid level on backside @ 7401'. Work wI Production to flush debris through S.V. RIH wI prong to attempt to dislodge debris, pressure tubing up to 1500 psi, work prong, no results, POOH. Began filling casing wI power oil, RIH wI Kobe PT to 9942', latch S.v., pull up 675# bind (225# over pickup weight), stand by for production to fill casing in order to equalize, POOH. RIH w/21" long x .75" prong to try to beat out bottom of S.v., beat down for 1 hr., POOH, prong bent beyond repair. Pollard shop made new tool & sent out. RIH wI S.v. "breaking tool" to 9942', beat down 6 times, well went on hard vacuum, POOH. RIH wI Kobe PT to 9942', latch S.v., tagged fluid @ 3900', shot fluid level on backside @ 5900', allow to equalize more, hit 1200# OJ lick, POOH wI S.V.. RIH wI new S.V. , fluid @ 5850', shook off S.V. @ 6000', POOH. 2004 3/31 W/L - Several attempts to fish S.v. and wouldn't latch. Finally pulled S.v, from 9942' RKB. RIH wI new S.v. to 6600' RKB, shook off S.V., POOH. 2005 4/14 W/L - Pulled S.v. from 9945' KB. RIH wI 2.25" GR I tag obstruction @ 9953' KB, POOH. RIH wI S.V., shake off @7000', POOH. 6/21 W/L - RIH (IN THE SHORT STRING) wI 2.81" GR to 9912' KB & tag Kobe BHA, POOH. 6/24 W/L - RIH (IN THE SHORT STRING) wI PDS (Proactive Diagnostics Services) Caliper Survey Tool to 9866' KB, wait for tool to open, POOH @ 50 fpm to surface. PDS data revealed no holes in the short string. "No significant wall penetrations (>20%) are recorded throughout the interval logged. No areas of significant cross-sectional wall loss (>5%) are recorded throughout the interval logged". e e 7/6 W /L - out to set plug in SS & pressure test. As of 7/14 no well service report received but verbal report from Glynn Brown is the short string held fine @ 850 psi but the long string/cavity/standing valve bundle leaked right off from 500 psi to 0 twice. 10/20-10/21 W/L - Pulled jet pump and standing valve. Ran a rebuilt standing valve with a Weatherford checked ball & seat and a new pump seat on it. Attempted to "bundle test" the long string, short string, standing valve and bottomhole assembly. Pressured well up to 1000 psi four times. Each time it bled off 300 psi per minute and bled off to 0 psi in 3-1/2 minutes. Ran the jet pump back in with a plug in it above the nozzle to isolate the long string tubing. Pressured up the long string to 1050 psi. Only bled to 1000 psi after ten minutes and to 950 psi after twenty minutes - this could have been just compressing gas. - long string tubing deemed to be holding adequately. Pulled jet pump and removed plug, reran the jet pump and put well back on production. ~ Since the short string held pressure on 7/6/05, the long string held on 10/21/05 and the standing valve ran was pressure tested OK before being run but the well still will not "bundle" pressure test it is deduced that the leak is in the bottom hole assembly itself - likely the side tubes or tension joints. Pertinent Data: Spud Date: Surface Location: Subsurface Location: Elevation: Initial Completion: TD: PBD: Casing Record: Perforations: Original 11/11/93 e e GRANTE POINT ADL 18742 WELL NO. 42 MIDDLE KENAI SANDS June 28, 1993 Leg 4, Slot 2, GP Platform Bruce 2000'FSL, 1952'FVVL, Sec. 1, T10N, R12VV, S.M. At top production interval, C-3 zone, 10310' MD, 8379 TVD, 893' FNL, 2187' FEL, Section 1, T10N, R12VV, SM. At total depth 1014', FNL, 1881' FEL, Sec. 1, T10N, R12VV, SM. 115' RDB-MSL 62' MSL (VVater depth) Pumping Oil Well 11813' MD, 9794' TVD 11703' MD, 9684' TVD 30" to 242' Driven 18-5/8" 87.5# K-55 to 1220', set with 270 bbls cement. 13-5/8" 68# K-55 to 4135', Set with 707 bbls cement. 9-5/8" 53.5# N-80 to 10320', Set with 604 bbls cement. 7-5/8" 39# P-110 liner from 9990 to 11700', Set with 109 bbls cement. C-3 10310-10402' C-7 11075-11135' 11176-11400' 11418-11440' 11470-11552' 11612-11662' w/4JSPF C-5 10561-10700' C-6 10980-11000' w/6JSPF Initial Potential: None Initial Stimulation: Reservoir Data: Cored Intervals: DST Intervals and Results: Log Inventory: e e GRANTE POINT ADL 18742 WELL NO. 42 MIDDLE KENAI SANDS Continued None None DIL/Sonic/GR DEN/CN/GR CAL SBT/GR Dipmeter FMS Br 4242 Well Tests last Update: 10/1/2005 '# 'S o ... 2 ~ 1/1/06 2000 1800 _ Q CI. m 1600 ¡ '" n: 1400 Õ ~ o 1200 CI. S' 250 a.. 1B. 't:I '¡; i:ï: III III 2 CI 0::: o CI 4/2/03 7/2/03 1 0/2/03 1/1/04 4/1/04 10/1/04 12/31/04 412/05 7/2/05 10/1105 1200 1000 it 800 Ii' 0 ..J LL 600 400 200 R FI I ver Pump vs. 1400 o 0 3/16/98 9/14/98 3/16/99 9/14/99 3/15/00 9/13/00 3/15/01 9/13/01 3/15/02 9/13/02 3/15/03 9/13/03 3/14/04 9/12/04 3/14/05 9/12/05 300 270 240 210 180 ¡¡: m 'Ó 150 ]! LL '" '" o 120(5 90 60 30 Unocal Corporation ~, ' P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager Wednesday, April 07, 1999 Robert Crandall Senior Petroleum Geologist, AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501-3192 APl Numbers on Granite Point Field, Bruce Platform, Well's 17586-~3RD & 18742-~42 Dear Mr. Crandall, As per your request in the meeting held on April 5, 1999, attained by Jack Hartz, Stephen McMains, Robert Crandall, Larry Greenstein and Steve Tyler, the following APl numbers for wells Bruce 17586 #3RD I~.~ '~ Bruce 18742 #42 Will be changed to: Bruce 17586 #3RD Bruce 18742 #42 APl# 50-733-20004-61 APl# 50-733-20451-60 APl# 50-733-20004-01 APl# 50-733-20451-00 This will supercede AOGCC letter dated March 4, 1994. As we also discussed, the previously reported production data associated with this change will not be reissued as revised State Monthly Production Reports, but instead will be changed in the database by hand. Thank you for your assistance in this matter. .~~erely, ,, ~m Dan Williamson Drilling Manager Unocal Alaska Please return a signed and dated copy of this letter to document your approval for our records. R'bbert Crandall Date '/ ' AOGCC PERMIT 93-073 93-073 9'3-073 °3 073 93-073 93~073 93-0'73 93-073 93-073 93-073 DATA 5983 5984 DRY DITCH 407 DAILY WELL OP SURVEY DIP AOGCC individual Well Geological Materials Inventory T DATA_PLUS BHCA/GR CDL/CNL/GR L~0362-11_, ~- 94 COMPUTD 4ARM DIP~6500-10250 93-073 DIFL/GR 93-073 DLL/GR 93-073 DNP 93-073 FMS 93-073 LDL 93-073 PDI 93-073 SBT Are dry ditch samples Was the well cored? .-~~9~28-I1744, ~1128-4168, ~S"~1200-I1800 '~/~COMP DATE'll/04/93 ~/24t93-11/04/93 ~0-11650, GYRODATA ~6500-10250 ~L~J880-10255 ~200-i0255 ~10362-11594 ~I~-9850-11648 ~'~10304-11684 ~L/9850-i1648 ~650-11678 ~L~9922-11671 OH-DITE/LDT OH-GR/DIFL SS~903 Page · 1 Date' 09/29/95 RUN DATE_RECVD 1 01/31/1994 1-3 01/31/1994 04/08/1994 12/29/1993 12/29/1993 12/29/'1993 2 01/31/1994 2 01/31/1994 3 01/31/1994 2 01/31/1994 1-2 01/31/1994 3 01/31/1994 1 01/31/1994 1 01/31/1994 1 01/31/1994 1 01/~1/lC~94~, _ 1 01/31/1994 required? yes ~And received? . Y__~~_3-*o yes ~~Ae~lysis & description received2---- ~ceived? Are well tests required?/12~es Well is in compliance ~ In~-tial ~uMMENT~ yes~ no Unocal Energy Resourcr 'vision Unocal Corporation 909 West 9th Avenue, RO. box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 Alaska TO: Larry Grant UNOCAL DOCUMENT TRANSMITTAL February 17, 1994 FROM: Richard L. Stewart LOCATION: 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL ]~,~ TRANSMYIWING AS FOLLOWS I.J~o/xes of dry samples [ GRANITE POINT 18742 #42 1200 - 2820 2820 -4230 4230 - 5760 5760 - 7200 7200 - 8730 8730 - 10020 10020 - 10430 10430 - 10950 GRANITE POINT 18742 #42 LATERAL 10538- 11330 11330- 11655 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRAN.~TTAL TO.._.~B~HILDERS. THANK YOU RECEIVED BY' · /-"' - / / % V DATED' // // / . ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 March 4, 1994 Russell Schmidt UNOCAL P. O. Box 196247 Anchorage, AK 99519 Dear Mr. Schmidt: As we discussed tOday, my correspondence to you dated January 26, 1994, incorrectly states the APl numbers for wells Granite Point State 42 and Granite Point State 3rd. The correct information for these wells is listed below. WELL NAME PERMIT NUMBER API NUMBER Granite Pt. St. 42 -- 93-073 Granite Pt. St. 3rd 93-127 50-733-20451-60 50-733-20004-61 We do not consider assignment of separate API numbers for each downhole segment practical with a 12-digit API number format nor is it consistent with current API guidelines.. The number 6 in the eleventh digit signifies a well with n~ultiple downhole sections. The twelfth digit is incremented for each drilling permit issued for the surface location which is uniquely identified by the first ten digits. Several downhole sections can be permitted at a single time, so the twelfth digit is not necessarily an indicator of the number of downhole sections present in a well. I regret any inconvenience this change may cause. If any of your staff can suggest an alternate method for tracking wells with multiple downhole sections, please have them give me a call at 279-1433. Thanks. Robert Crandall Senior Petroleum Geologist Unocal Energy Resourc~ ~vision Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOrJtL Alaska DOCUMENT TRANSMITTAL January 28, 1994 TO: Larry Grant FROM' Richard L. Stewart LOCATION: 30Ol PORCUPINE DroVE LOCATION: P.O.BOX 196247 ANCHORAGE, AK 99501 ANCHORAGE AK 99519 ALASKA OIL & GAS CONSERVATION COMM. UNOCAL .-_._-_._._._._._-:::r-_-_-_-::::_-_-: ......... :__:__:_____~ ......... TRANSMITTING AS FOLLOWS 1 blueline and 1 sepia GRANITE POINT 18742 #42 Dual Induction Focused Log/Gamma Ray Segmented Bond Log K\/~z%-[t~7-1 [ 5 4-Arm Diplog ¢.~/t.5o~-m~-oe[ B GRANITE POINT 18742 #42 LAT Dual Laterolog/Gamma Ray ~,b / Compensated Densilog/Neutron/Gamma Computed 4-arm Diplog ~/~ BHC Acoustilog/Gamma Ray Phasor Dual Induction Ca I qt,St:,--lt~'~g [.z+S I Tape & Listing Litho Density Log ~,~ I%~o-~t~,~ FMS ¢,l] to~q.---nt,~;q [ 5 IOpen Hole Edit- DITE/LDT/CNL/GR Density-lq'eutron Porosity ~,\)w,c"~--Itt. ttg/ 5 ILis PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRAN_~~~.~O ~~HILDERS. RECEIVED BY: / DATED: ALASI~A OIL AND GAS CONSERVATION CO~I~IISSION ~ January 26, 1994 WALTER J. HICKEL, GOVERNOR .. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Russell Schmidt UNOCAL P O Box 196247 Anchorage, Alaska 99519 Dear Mr. Schmidt, Recently Alaskan operators have begun to drill wells with multiple downhole sections (or laterals). The AOGCC is highly supportive of this innovative technology, however these wells do pose minor problems with our mainframe database and our established A.P.I. well numbering procedures. Consequently we have modified our A.P.I. numbering procedure. In future wells with multiple downhole sections will be designated by an 8 in the eleventh digit. For example a new well of conventional design (single downhole section) may have an API# 'of 50-029-20000-00, if the well were proposed as having two or more downhole sections the API# will now be 50- 029-20000-80. A conventional redrill of an existing well is designed through the API number being appended with 01 in the eleventh and twelfth digits. If an existing well of conventional design is to be modified through the addition of an additional downhole segment(s) (a procedure which requires a permit to drill) the API# would change from 50-029-20000-00 to 50-029-20000-81. In order to update our records to be consistent with this new well numbering method the following UNOCAL operated wells has a revised API #. Please change your internal records for: 93-0073 Granite Pt St 42 new API #733-20451-80, old #7.33- 20451-00 93-0127 Granite Pt St 3rd new API #733-20004-81, old #733- 20004-01 Advise me if you need further explanation of these changes. Sincerely.~ ~ A Sr. Petroleum Geo ogist cc: Russell Douglass, Commissioner ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 ~anuary 10,1994 Russell Schmidt Unocal P O Box 196247 Anchorage, AK 99519-6247 Dear Mr Schmidt: , The Commission is compiling statewide drilling statistics for 1993. Attached is a list of outstanding Permits to Drill issued to your engineering group (permits for which no form 10-407 has been received by this office). Please review this list to determine if any of the wells were drilled in 1993. If so, please note the well name, total measured depth, and class (development, service or exploratory). If any wells were drilling as of 12/31/93, estimate the depth at 12:00 midnight. We would appreciate your reply by the end of January if possible. Thank you for your cooperation with this project. If I may be of any assistance, please call me at 279-1433. Yours very truly, Robed P Crandall Sr Petr Geologist encl jo/A:RPC.\drlstats · ,;. ;.;. pr~n!(,d ~)n rr'cycl,'d paper b y r, P. 1/03194 OPE~.ATOR UNION OIL CO OF CALI UNION OIL CO OF CALI Ul~ION OIL UI~ION OIL CO OF ~LI ~ION OIL ~ OF'~LI ~ION OIL ~ION OIL CO OF ~LI ~ION OIL ~ OF ~LI ~ION OIL CO OF ~LI ~ION OIL ALJ%SK/% ~f:LLS BY b-NOCAL PERMIT 92-0152-0 93-0073-0 93-0118-0 93-0119-0 93-0120-0 93-0127-0 93-0129-0 93-0165-0 93-0182-0 93-0190-0 WELL NAME IVAN RIVER UNIT 14-31RD1 GRANITE PT ST 18742 42 C~AKAC~ATNA MGS B-29 CHAKAC~ATNA MSS B-28 C~LAKACHATNA MGS B-30 GRANITE PT ST 17586 3RD TRADING BAY U~IT K-24RD T~-ADING BAY U~IT K-26 AMETh~YST STATE 1 T~.ADING BAY U~IT M-31 PACE .... STATE OF ALASKA .- . ALASF ilL AND GAS CONSERVATION COMI~ ION WELL COMPLETION OR RECOMPLETION R,-PORT AND LOG 1 · ,.~ta[us Of YVell ~,laSSlTica~ior] el ~6~1c6 vv611 2. N~eofOperato, ~T~Si 7. PormENumber ~~ P.O. BOX 196247 ANCHO~GE, AK 99519 50-733-~451 , 4. Location of well at sudace Platform Bruce, 20~' FSL, 1952' ~L,----" - --'~ 9. UnE or Le~e Name ~/~-- SEC. 31, T11N, R11W, SM ~-- .............. G~NITE POINT 175~ At Top Producing Inte~ (10,310~ 893' FNL, 2187' FEL, SEC. 1 TION, R12W, SM ~ 10. Well Number ~, AtTo~Dep~ (11.81331014' FNL,~' FE~ SEC. 1,T10N, R12W, SM ; ~/~j~ ~:~,_:~ '~ '11. Field ~d Pool · ~ ..... ~ .... ¢,'-~'~v, ~ MIDDLE KENAI 5. Eleva~on115'KB in fe~ (indicate ~. DF. etc.) 6. ~e Designa~onADL 18742 ~d Seri~ No. 12. Date Spudded06/28/93 13. Date T.D. Reached09/19/93 ~ 14' Date C°mp" Susp' °r Abed' 115' Water Depm' E °~h°re 116' N°' °' c°mplefi°nsl 1/~/93 62 Feet MSL 1 ~7.T~t~D~p~MD+WD)~8.P~u"~ckD~p~MD+WD)~.~k~c"~n~u~2~.~p~wh~r~8~*~t~2~.~"c~n~s~[~r~st~ 1,813'/9794' 11,703'/~84' YES ~ NO ~ N/A feet MD N/A 22. Type Elec~ic or O~er Logs Run DInG ~SONIC/DIPMETE~FMS/SP/SBT/DENSI~/N EUTRON 23. CASING, LINER AND CEMENTING RECORD CASING SIZE ~. PER G~DE TOP ~ BO~OM HOLESIZE CEMENTING RECORD AMOUNT PULLED 30" --- 45' 242' DR~EN - -- 18-5/8" 87.5~ K-55 43' 1220' 24" 270 BBLS (SURFACE) 13-3/8" 68~ K-55 43' 4135' 17-1/2" 707 BBLS (SURFAC~ 9 - 5/8" 53.~ N - 80 42' 10,~0' 12-1/4" 604 BBLS 7-5/8" 39~ P-110 9990' 11,700' 8-1~" 109 BBLS 24. Pedorafions open to Production (MD+~D of Top ~d ~Eom ~d 25. TUBING RECORD inte~, size ~d number) SIZE J DEPTH SET (MD) J PACKER SET (MD) SEE A~ACH ED SEE A~ACH ED 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) ~ AMOUNT & KIND OF MATERIAL USED NONE 27 PRODUCTION TEST Date First Production Me~od of Operation (Flowing, g~ lift, etc.) 11-11-93 HYD~ULIC LIFT Date of Test Hours Tested PRODUCTION FOF OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL ~TIO 11/18/93 12 TEST PERIOD 217 108 . 31~ 500 FlowTubing C~ing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OILG~VI~-API (corO Press. 0 0 24-HOUR ~TE 434 217 63 38.5 DEG 28. CORE DATA Brief description of I~ology, poros~, frac~r~, ~p~ent dips ~d pres~ce of oil, g~ or water. SubmE core chips. NONERECEIVED DEC 2 9 199~ Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate rev. 7-1-80 CONTINUED ON REVERSE SIDE t 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP OF TYONEK 4327' 3745' TOP GRANITE POINT 9913' 7996' DEC SANDS ~'C-1") A. IOSJ~ Olj ~ ~EI$ COils, TOP OF "C-3" SAND 10166' 8241' Ar/Cbora£e TOP OF "C-5" SAND 10565' 8622' TOP OF "C-7" SAND 11083' 9107' 31. LIST OF ATTACHMENTS DAILY REPORT OF OPERATIONS, GYRO-SURVEY, WELL BORE SCHEMATIC 32. I hereby,~e~~~orrect to the best of my knowledge Signed G. RUSSELL SCHMIDT TrUe DRILLING MANAGER Date 12/22/93 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: Indicate which elevation is used 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 showthe 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 Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate 'none'. , , ~ SURVEY CALCULATION AND FIELD WE ,(SHEET Job No. _0_45_0_-~)_12__3_2_ ..... Sidetrack No. 1 .......... Page . of Compan'.,~ ._U.,N_ _O.?~._L Rig Contractor & No. _P._o_...o_! .A.r_c!i? A!ask~.- U0.C. '~!._5_0- ................... Field GR__~_AN/_T_E._P_O_!NT.....F.!_E_.L..D- Well Name & No. BRUCE PLATFORM/42-2 Survey Section Name MWD BHI Rep. DUNN / LONG WELL DATA Target TVD ................................... !.F_T.) ............................. Target Coord. N/S ......................... Slot Coord. N/S ...... 2_~_0!__2.0_~0 ....... Grid Correction .... O:00__~0 .................. Depths Measured From: RED ~ MSLEi-] ssE_-ji Target Description Target Coord. E/W Slot Coord. E/W 1951.00 Magn. Declination 23.080 Calculation Method MINIMUM CURVATURE Target Direction ..................................... !.O_.D_) ............ Build\Walk\DL per: 100ft[-)~ 30m~ lOmI~ Vert. Sec. Azim. . ........ _2_.3_.4..:_92 ............. Magn. to Map Corr. _ ...... _2_ ~ : _08 _0_ ....... Map North to: O__.T__H_E_R .................................. SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinato Build Rato Walk Rate Date Tool Depth Angle Direction Length 1-VD Section N(.+.) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DB) (Fl') (FT) (Fl') (FT) Per 100 Fl-) Drop (-) Left (-) .......................................................................................................................... BeD 11132.O0 16.10 98.00 9134.97 4897.15 -2989.15 -3885.17 TIE IN POINT 14-SEP-93 MWD 11184.00 17.40 99.00 52.00 9184.76 4886.50 -2991.37 -3870.35 2.56 2.50 1.92 SIDETRACK PT (~ 11156 14-SEP-93 MWD 11247.00 18.00 99.70 63.00 9244.78 4872.82 -2994.48 -3851.45 1.01 0.95 1.11 .......................................................................................................................................................................................................................................................................................... 15-SEP-93 MWD 11309.00 16.00 101.10 62.00 9304.07 4860.11 -2997.74 -3833.62 3.29 -3.22 2.26 16-SEP-93 MWD 11372.00 17.00 101.10 63.00 9364.47 4847.72 -3001.19 -3816.06 1.59 1.59 0.00 16-SEP-93 MWD 11436.00 17.40 100.40 64.00 9425.61 4834.53 -3004.72 -3797.47 0.70 0.62 -1.09 ........ ................................ 17-SEP-93 MWD 11498.00 17.20 99.00 62.00 9484.81 4821.44 -3007.82 -3779.30 0.74 -0.32 -2.26 ..................................................................................... ............................... 17-S EP-93 MWD 11560.00 14.80 96.90 62.00 9544.40 4808.97 -3010.21 -3762.38 3.98 -3.87 -3.39 .......... .............................................................. 17-SEP-93 MWD 11592.00 13.30 93.40 32.00 9575.44 4803.05 -3010.92 -3754.65 5.38 -4.69 -10.94 ................ 17-SEP-93 MWD 11623.00 11.70 94.10 31.00 9605.71 4797.82 -3011.36 "-3747.95 5.18 -5.16 2.26 ........................................................... .......................................................................................................................... 18-SEP-93 MWD 11687.00 9.80 96.20 64.00 9668.58 4788.70 -3012.41 -3736.06 3.03 -2.97 3.28 ............................... ..................................... 18-SEP-93 MWD 11719.00 8.00 99.00 32.00 9700.20 4785.05 -3013.05 -3731.16 5.78 -5.62 8.75 18-SEP-93 MWD 11751.00 5.70 99.00 32.00 9731.96 4782.31 -3013.65 -3727.39 7.19 -7.19 0.00 18-SEP-93 MWD 11813.00 1.40 99.00 62.00 9793.83 4779.55 -3014.25 -3723.60 6.94 -6.94 Projected Bit Depth ...................................................................... ............................... .................................. ................................................................................ ._ ................. ...................................................................... .................... BRUCE WELL #42 ADL 18742 18-5/8' ~ 1220' 13-3,/8' @ 4135' COMPLETION I 3-1/2' 9.2# SPC Butt TBG to 9912' 2 3-1/2' 9.2# SPC Butt TBG to 991 2' 3 Kobe Type DD 3-1/2' Cavity @ 991 2' 4 Ported Sub 7' flow area @ 9940' 5 3-1/2' $PC TBG to 9954' 6 Blank sub @ 9954' 7 3-1/2' x 2-7/8' XO @ 9955' 8 Vann 4-5/8' TCP guns from 10,307'-11,662' 9 2-7/8' TBG 11,663-11,666 '7' TOL @ 9990' 9-5/8' 53.5# ~ 10,320' C-3 10,310 - 10,402 Top of Window ~ 10,515' Base of Window at 10,526' ECP Packer Top @ 10,536' C-5 1 O, 561-1 O, 700 C-6 1 O, 980-11,000 2-1/16' Top of Fish @ 11,200' 3-1/2' Slotted liner @11,623' EZSZ @ 11,669' 7' 39~ ~ 11,700' TD @ 11,813' C-7 11,075-11,1 35 11,1 76-11,400 11,41 8-11,440 11,470-11,552 11,612-11,662 PERFORATION RECORD WELL #42 ADL 18742 C-3 C-5 C-6 C-7 Measured Depth Intv'l True Vertical 10,310' - 10,402' 92' 8379' - 8646' 10,561' - 10,700' 139' 8616' - 8747' 10,980' - 11,000' 20' 9008' - 9027' 11,075' - 11,135' 60' 9098' - 9155' 11,176' - 11,400' 224' 9193' - 9408' 11,418' - 11,440' 22' 9425' - 9446' 11,470' - 11,552' 82' 9476' - 9550' 11,612' - 11,662' 50' 9613' - 9662' (The C-7 was 4 689' SPF and all the others were 6 SPF) DEC 2 9 i~i~.ska 0il & Gas Cons, Col~r~issio~ Anchorage BRUCE PLATFORM WELL #42 DAY 0 (06/24/93) MOVED PUMPS. REMOVED LANDINGS AND STAIRS. PREP TO SKID RIG. DAY 1 (06/25/93) MOVED RIG TO LEG #4, SLOT #2. MOVED MUD PUMPS AND CONNECTED PIPING. RIGGED UP. DAY 2-4 (06/25-27/93) OFFLOADED BOAT. INSTALLED 30" RISER AND MUD RETURN LINE. CONTINUED RIG-UP AND MIXED SPUD MUD. RAN BHA #1 AND TAGGED INSIDE CONDUCTOR @ 220'. CLEANED OUT 220'-242' AND DISPLACED HOLE TO 8.8 PPG SPUD MUD. CLEANED OUT 30" DRIVE SHOE AT 242' AND SPUDDED WELL #42 AT 02:45 HRS 06/26/93. DRILLED 17-1/2" HOLE 242'-251' CENTERED BY 26" STABILIZER. CIRCULATED CLEAN AND TRIPPED FOR BHA. DRILLED 17-1/2" HOLE F/251'-1231'. CIRC. POOH. DAY 5 (06/28/93) RAN IN AND OPENED 17-1/2" HOLE TO 24" FROM 242'-1110'. DAY 6 (06/29/93) OPENED 17-1/2" HOLE TO 24" FROM 1110'-1225'. CBU. TRIPPED. HELD SAFETY MTG AND RAN 30 JTS 18-5/8" 87.5 PPF CSG W/DRILL-QUIP CONNECTORS. CEMENTED 18-5/8" CSG AT 1220' THROUGH D.P. INNER STRING WITH 1220 SX "G" CMT MIXED AT 12.9 PPG FOR LEAD SLURRY AND 610 SX "G" CMT MIXED AT 15.8 PPG FOR TAIL SLURRY. HAD EARLY CMT RETURNS WHILE PUMPING LEAD SLURRY; RIGGED UP AND RECIPROCATED 18-5/8" UNTIL CHANNELING STOPPED. GOOD RETURNS THROUGHOUT CMT JOB. POH WITH D.P. AND WOC. DAY 7 (06/30/93) WOC. REMOVED 30" RISER SECTIONS AND CUT 18-5/8" CSG. INSTALLED VETCO 18-5/8" X 20" 3M SLIPLOC STARTING HEAD. INSTALLED 20" RISER. INSTALLED 20" DOPE. DAY 8 (07/01/93) CONTINUED TO INSTALL 20" DOPE. DRIFTED DOPE WITH 13-3/8" CASING HANGER. TESTED DOPE TO 3000 PSI, OK. TESTED CASING TO 1500 PSI, OK. PICKED UP 17-1/2" BHA. CLEANED OUT CEMENT TO 1195'. DAY 9-12 (07/02-05/93) CLEANED FLOAT TRACK OUT AND DRILLED TO 1240'. PERFORMED L.O.T. (1.16 PSl/FT). DRILLED 17 1/2" HOLE F/1240'-2150'. STANDPIPE UNION WASHED OUT. CIRC. TRIP FOR BIT. DRILLED F/2150'-2395'. WIPER TRIP TO 1881'. DRILLED 17 1/2" HOLE F/2411'-2565'. TRIP FOR BIT. DRILLED F/2565'- 2720'. DAY 13 (07/06/93) DRILLED 17 1/2" HOLE F/2720'-3215' DAY 14 (07/07/93) CIRC. TRIP FOR BHA. DRILLED 17 1/2" HOLE F/3215'-3420'. DAY 15 (07/08/93) DRILLED 17 1/2" HOLE F/3420-3673'. SHORTTRIP TO 1654'. DRILLED F/3673'- 3824'. DAY 16-18 (07/09-11/93) DRILLED 3824'- 4143'. CIRC. POOH. RAN DI~L/GR/SP/_CHT COULD NOT GET PAST 3190. WIPER TRIP. CIRC. RAN DIL~/GR/SPTCHT FM 4130'-1200'. SHOT SIDE WALL CORES. INSTALLED AND TESTED 13 3/8" RAMS. RAN 13 3/8", 68#, K-55 CASING TO 4135'. CIRC. PUMPED 502 BBLS OF 12.9 PPG LEAD AND 205 BBLS 15.8 PPG TAIL. CEMENT RETURNS TO SURFACE. BACKED OUT LANDING JTS. RAN PACK OFF. DAY 19 (07/12/93) REMOVED 20" BOPE. REMOVED 13-3/8" PACKOFF. REDRESSED. INSTALLED PACKOFF AND TESTED TO 3000 PSI, OK. INSTALLED 18-5/8" x 13-3/8" W.H. TESTED TO 3000 PSI, NO TEST. REMOVED W.H. RE-INSTALLED PACKOFF, NO TEST. DAY 20 (07/13/93) REDRESSED AND RE-INSTALLED PACKOFF. TESTED PACKOFF TO 3000 PSI, OK. INSTALLED 18-5/8" x 13 3/8" W.H. INSTALLED 13 3/8" BOPE AND TESTED TO 5000 PSI. RAN AND LANDED 9-5/8" HGR. CHANGED OUT KILL LINE VALVE. DAY 21 (07/14/93) FINISHED TESTING BOPE TO 5000 PSI, OK. CLEANED OUT CEMENT TO 4086'. TESTED 13-3/8" CASING TO 2500 PSI. DRILLED FLOAT TRACK AND NEW HOLE TO 4153'. PERFORMED L.O.T. (1.1 PSl/FT). DRILLED 12-1/4" HOLE F/4153'-4322'. DAY 22 (07/15/93) DRILLED 12-1/4" HOLE F/4322'-4270'. CIRC. BEGAN TRIP. DAY 23-25 (07/16-18/93) TRIP FOR BIT & BHA. DRILLED 12-1/4" HOLE F/4720'-5317'. TRIP FOR BIT. REAMED F/4293'-4427'. DRILLED 12-1/4" HOLE F/5317'-5496'. TRIP FOR BHA. DRILLED 12-1/4" HOLE F/5496'-5535'. DAY 26 (07/19/93) DRILLED 12-1/4" HOLE F/5535'-5940'. DAY 27 (07/20/93) DRILLED 12-1/4" HOLE F/5940'-6021'. TRIP FOR BIT. DRILLED 12-1/4" HOLE F/6021 '-6143'. DAY 28 (07/21/93) DRILLED 12-1/4" HOLE F/6143'-6370'. TRIP FOR BHA. DAY 29 (07/22/93) TESTED DOPE TO 5000 PSI, OK. REPAIRED 4" MUD LINE IN CENTER BAY. RIH. DRILLED F/6370'-6507'. DAY 30-32 (07/23-25/93) DIRECTIONALLY DRILLED F/6507'-6998'. CONT TO DRILL TO 7062'. (HOLE ANGLE DROPPING). NEW BIT, DRILL. DIRECTIONALLY DRILLED TO 7562'. DAY 33 (07/26/93) DRILLED TO 7697'. PULLED BIT DUE TO HIGH TORQUE. RIH W/NEW BIT. DRILLED F/7697'-7744'. MADE SHORT TRIP TO 4605'. RIH. TIRP FOR BHA AND DAY 34 (07/27/93) DRILLED TO 7744'-8119'. LOW PEN. POOH. DAY 35 (07/28/93) DRILLED 12-1/4" HOLE F/8119'-8317'. DAY 36 (07/29/93) DRILLED 12-1/4" HOLE F/8317'-8636'. DAY 37-39 (07/30-08/01/93) DRILLED 12-1/4" HOLE F/8636'-8730'. TRIP FOR BIT. TEST DOPE TO 5000 PSI, OK. DRILLED F/8730'-9046'. TRIP FOR BIT. DAY 40 (08/02/93) CONT'D TRIP FOR BIT. DRILLED 12-1/4" HOLE F/9046'-9140'. DAY 41 (08/03/93) DRILLED 12-1/4" HOLE F/9140'-9235'. TRIP FOR BIT. DAY 42 (08/04/93) CONT'D TRIP. DRILLED 12-1/4" HOLE F/9235'-9352'. DAY 43 (08/05/93) DRILLED 12-1/4" HOLE F/9352'-9511'. DAY 44-46 (8/06-08/93) DRILLED 12-1/4" HOLE F/9511'-9618'. POOH. TESTED DOPE, OK. DRILLED F/9618'-9790' DAY 47 (8/09/93) DRILLED 12-1/4" HOLE F/9790'-9802'. JARRED ON STUCK PIPE. DRILL STRING PARTED AT CONNECTION AT 447'. ENGAGED FISH. CIRC. JARRED, PIPE PARTED AT 447'. ENGAGED FISH. PUMPED 40 BBL HIGH SOLTEX PILL. JARRED ON PIPE. CONNECTION AT 447' PARTED. REPAIRED KELLY SWIVEL. DAY 48 (8/10/93) ENGAGED FISH. FIRED STRING SHOT 754' AND BACKED OFF SAME. ENGAGED FISH AND RAN FREEPOINT TO THE MWD TOOL. BACKED OFF AT 9695' WLM. POOH. LAID DOWN BENT DRILL PIPE. DAY 49 (8/11/93) RIH W/JARRING ASSEMBLY. SCREW INTO FISH AT 9695'. JAR FISH FREE (6 HRS). POOH RECOVER ENTIRE BHA TO BIT, L/D SAME. DAY 50 (8/12/93) POOH L/D BENT DRILL PIPE. RIH WITH DIRECTIONAL DRILLING BHA. DRILLED 12-1/4" HOLE FROM 9802'-9839'. DAY 51-53 (8/13-15/93) POOH L/D BENT DRILL PIPE. RIH WITH DIRECTIONAL DRILLING BHA. DRILLED 12-1/4" HOLE F/9802' - 9979'. SHORT TRIP TO 7595'. DRILLED 12- 1/4" HOLE F/9979' - 10,024'. TRIP FOR BIT. TESTED ROPE, OK. DRILLED 12- 1/4" HOLE F/10,024' - 10,044'. DAY 54 (8/16/93) DRILLED 12-1/4" HOLE F/10,044' - 10,166'. DAY 55 (8/17/93) DRILLED 12-1/4" HOLE F/10,166' - 10,273'. CIRC. WIPER TRIP TO 4135'. DAY 56 (8/18/93) RIH TO 10,273. CIRC. RAN DIL/BHO/GI~ F/3880' - 10,255'. METER LOG. DAY 57 (8/19/93) FINISHED RUNNING DIPMETER LOG F/6500' - 10,250'. RAN CIBL TOOL, UNABLE TO WORK PAST 4228'. DRILLED 12-1/4" HOLE F/10,273' - 10,315'. DAYS 58-60 (8/20-22/93) DRILLED 12-1/4" HOLE F/10,317' - 10,334'. CIRC. POOH. CHANGED TO 9-5/8" RAMS. RAN 9-5/8" CASING TO 10,320'. CEMENTED WITH 439 BBLS LEAD CEMENT AND 165 BBLS TAIL CEMENT. BACKED OUT LANDING JOINT. RAN PACKOFF AND TESTED TO 3000 PSI. CHANGED OUT HOOK ON TRAVELING BLOCKS. CHANGED TO 5" RAMS AND TESTED TO 5000 PSI, OK. RIH TO 10,224'. TESTED CASING TO 4000 PSI, OK. DRILLED 8-1/2" HOLE F/10,334' - 10,345'.TESTED SHOE TO 4000 PSI, OK. DRILLED 8-1/2" HOLE F/10,345'- 10,457'. RIH WITH DIP DAY 61 (8/23/93) DRILLED 8-1/2" HOLE F/10,457' - 10,496'. BECAME STUCK ON BOTTOM. JARRED FISH. BACKED OFF D.P., RETRIEVED SCREEN. RIGGED UP SLICK LINE AND LATCHED RETRIEVABLE MWD. SPO~-FED SOLTEX PILL ACROSS FISH. JARRED ON FISH. RIGGED UP WlRELINE. RAN FREE POINT. DAY 62 (8/24/93) CONT'D RUNNING FREE POINT. BACKED OFF AT 10,407'. POOH. RIH WITH FISHING ASSEMBLY AND ENGAGED FISH AT 10,407'. JARRED FISH FREE. DAY 63 (8/25/93) POOH AND LAID DOWN FISH, FULL RECOVERY. RIH. DRILLED 8-1/2" HOLE F/10,496'- 10,529'. DAY 65-67 (8/27-29/93) DRILLED 8-1/2" HOLE F/10,658'-10,672'. DMWD TOOL NOT WORKING. POOH TO 10,320' RECOVERED DMWD TOOL AND REPAIRED. DRILLED 8-1/2" HOLE F/ 10,672'-10,751'. POOH. TESTED BOPE, OK. DRILLED 8-1/2" HOLE F/10,751'-10,974'. REPAIRED #2 AND #3 MUD PUMPS. DRILLED 8-1/2" HOLE F/10,974'-11,053'. CIRC. POOH. DAY 68 (8/30/93) TRIP FOR BHA. ADJUST AKO. DAY 69 (8/31/93) DRILLED 8-1/2" HOLE F/11,053'-11,248' DRILLED 8-1/2" HOLE F/11,248'-11,407'. SHORT TRIP TO 10,930'. DRILLED 8- 1/2" HOLE F/11,407'-11,597'. DAY 70 (9/01/93) CIRC FOR TRIP. PULLED TO 9-5/8" SHOE. REPAIRED DRAWWORKS. POOH. RIH. REAMED F/11,196'-11,282'. DAY 71 (9/02/93) REAMED F/11,282'-11,534'. DRILLED 8-1/2" HOLE F/11,597'-11,666'. DRILL STRING BECAME STUCK. JARRED ON FISH. SPOTTED LOW FLUID LOSS PILL. RAN FREE POINT LOG. RAN STRING SHOT AND BACKED OFF AT 11,555'. POOH. DAY 72-75 (9/03-06/93) CONT'D POOH. RIH WITH JARRING ASSEMBLY. ENGAGED FISH. JARRED 8 HRS. BACKED OFF AT 11,585' (ON TOP OF MWD/LWD). POOH. TESTED BOPE. RIH WITH 7-5/8" WASH PIPE. WASHED F/11,585'-11,630'. TRIP FOR 8- 1/8" WASH PIPE. WASHED F/11,585'-11,637'. SCREW OF STYLE STABALIZER DISENGAGED. POOH. DAY 76 (9/07/93) TRIP FOR JARRING ASSEMBLY. ENGAGED FISH AT 11,585'. JARRED ON FISH. PULLED FISH UP 45'. BLEW PUMP OUT SUB. CONTINUED TO POOH. FISH HAD DROPPED OFF WHILE POOH. RIH WITH SPIRAL GRAPPEL OVERSHOT. DAY 77 (9/08/93) RIH. ENGAGED FISH AT 11,585'. JARRED ON FISH FOR 14 HRS. RELEASED F/FISH. CIRC. POOH. DAY 78 (9/09/93) CONT'D POOH. P/U 8-1/8" WASHPIPE. WASHED OVER FISH F/11,583'-11,644'. CIRC. POOH. DAY 79-81 (9/10-12/93) CONT'D POOH W/WASH PIPE. RIH WITH OVERSHOT AND A~-FEMPT TO ENGAGE FISH AT 11,585', GRAPPLE PULLING OFF FISH. POOH. RIH WITH OVERSHOT AND ENGAGED FISH AT 11,585'. JARRED ON FISH FOR 9 HRS. RELEASED F/FISH. POOH. PICKED UP 2-7/8" TUBING AND RIH. PLACED A CEMENT PLUG F/11,585'-11,025'. POOH. TESTED BOPE. DAY 82 (9/13/93) CONT'D WEEKLY BOPE TEST. RIH TO 10,320'. CIRC. RIH WASHED F/10,792'- 11,111' (TOC). DRILLED CEMENT TO 11,156'. DAY 83 (9/14/93) TIME DRILL OFF PLUG F/11,156'-11,187'. DRILLED F/11,187'-11,334'. DAY 84 (9/15/93) DRILLED F/11,334'-11,396'. CIRC. POOH TO 10,320'. REPLACED LOW DRIVE CHAIN. POOH. MADE UP BHA. CHECKED DMWD @ SURFACE, OK. RIH TO SHOE. CHECKED DMWD, NEG. DAY 85 (9/16/93) RETRIEVED DMWD. DROPPED BACK UP TOOL. CHECKED DMWD, OK. CONT'D REPLACING BRAKE BANDS. RIH. DRILLED F/11,396'-11,546'. REPAIRED #3 MUD PUMP. DAY 86-88 (9/17-19/93) CONT'D REPAIRING MUD PUMP. DRILLED F/11,546'-11,699'. CIRC. TRIP FOR BIT. DRILLED F/11,699'-11,806'. POOH TO SHOE. RETRIEVED DMWD. DROPPED NEW DMWD. DRILLED F/11,806'-11,813'. BECAME STUCK ON BO~-FOM. JARRED ON FISH. RETRIEVED DMWD. RAN FREE POINT TOOL. HUNG UP IN JARS. POOH WITH FREE POINT. DAY 89 (9/20/93) CHANGED FREE POINT RIH. FREE TO 11,713'. JARRED ON FISH FREE TO 11,748'. BACKED OF AT 11,717'. POOH. RIH TO 6145'. DAY 90 (9/21/93) WI~,PER ./TRIP,~ TO 11_...,712'..~ RAN (DIL/PHASOR/GR/SP~LITHODENSITY/CNL) FROM 11 (FMS) FROM 11,700' TP 10,320'. LOGS RUN #1 ,700' TO 10,320'. RUN #2 DAY 91 (9/22/93).~ RAN LOG #2 (FMS) FROM 11,685'-10,320'. TESTED DOPE OK. TRIP AND CONDITIONED HOLE TO 11,702'. MADE WIPER POH. RAN 7-5/8" LINER. DAY 92 (9/23/93) RAN LINER TO 11,435'. HANG UP. WORKED FREE. CIRCULATED LINER TO 11,712'. RIGGED UP CEMENTERS. CEMENTED LINER IN PLACE. SET LINER HANGER. POH. DAY 93-95 (9/24-26/93) WHILE WOC CHANGED ROTARY TABLE & CATHEAD. RIH WITH 8-1/2" BIT AND CLEANED OUT TO 9990' (T.O.C.) CHANGED Boq-rOM RAMS TO 3-1/2" AND TESTED. RIH TO 10,021'. PRESSURE TESTED LINER LAP TO 1500 PSI, OK. DRILLED OUT FLOAT TRACK TO 11,703' AND RE-TESTED CASING AND LAP TO 1500 PSI, OK. POOH. RECEIVED Aiaska Oil & 13as Cons. Cot~lmissJon Anchorage DAY 96 (9/26/93) RIH WITH 7-5/8" AND 9-5/8"~6ASlN~G SCRAPERS. CHANGED OVER TO INLET WATER. POOH. RAN SBT-VD[ LOG F/11,686'-9922'. RAN GYRO-DATA SURVEY F/11,650' - SURFACE. DAY 97 (9/27/93) RAN GAUGE RING. RAN 7-5/8" EZSV RETAINER AND SET AT 10,520'. PRESSURE TESTED BOPE. RIH WITH 7-5/8" RETRIEVABLE WHIPSTOCK. UNABLE TO GET THROUGH LINER HANGER. DAY 98 (9/28/93) POOH. WHIPSTOCK LEFT IN HOLE. RIH AND RECOVERED WHIPSTOCK. REDRESSED AND MODIFIED WHIPSTOCK. RIH. DAY 99 (9/30/93) CONT'D RIH TO 10,453' (THROUGH LINER HANGER). RAN GR LOG TO VERIFY DEPTH. SET WHIPSTOCK AT 10,514'. MADE STARTER MILL RUN TO 10,515'. POOH. DAY 100-102 (10/01-03/93) RIH WITH 6.5" WINDOW MILL. MILLED F/10,515'-10,521'. POOH. RIH WITH WINDOW MILL. MILLED F/10,521'-10,526'. DRILLED F/10,526'-10,538'. TRIP FOR DRESSING ASSEMBLY. DRESSED WINDOW F/10,517'-10,535'. POOH. PIN AT FLOAT SUB PARTED. MADE UP 5-3/4" SPIRAL GRAPPLE AND RIH. DAY 103 (10/04/93) WASHED DOWN TO TOF AT 10,526'. WORKED FISH. PUMP PRESSURE INCREASED. POOH. NO RECOVERY. RIH W/5-3/4" OVERSHOT. WORKED FISH. SAW INCREASE IN OFF BO~-FOM TORQUE AND DRAG. POOH. NO RECOVERY. OVERSHOT CUT LIP BENT, SHOWING PAq-FERN OF FISH. DAY 104 (10/05/93) RIH W/6-1/4" X 5-3/4" BEVELED OVERSHOT. WORKED FISH. POOH. NO RECOVERY. HAD INDICATIONS THAT OVERSHOT HAD BEEN OVER FISH. TESTED BOPE, OK. RIH W/MODIFIED 6-1/4"X 5-3/4" OVERSHOT. DAY 105 (10/06/93) CONT'D RIH. WORKED FISH @ 10,527'. POOH. NO RECOVERY. RIH WITH OVERSHOT AND DRESSING MILL. DRESSED FISH. POOH. DAY 106 (10/07/93) RIH. WORKED FISH @ 10,527'. JARRED LOOSE. POOH. FULL RECOVERY. PICKED UP 4-3/4" COLLARS AND BHA. DAY 107-109 (10/08-10/93) RIH. A~-FEMPT TO ORIENT DMWD. RETRIEVED DMWD, ADJUSTED AND DROPPED. DRILLED F/10,538'-10,553'. UNABLE TO ORIENT. TRIP FOR BHA. RIH AND DRILLED F/10,553'-10,670'. RAN GYRO SURVEY. NOT TURNING FAST ENOUGH WITH BHA. TRIP FOR BHA, ADJUST AKO. DRILLED F/10,670'- 10,732'. RETRIEVED DMWD. RAN GYRO. WELL APPEARS TO BE SLIGHTLY OFF COURSE. POOH. CHECKED ALIGNMENT OF TOOLS, OK. DAY 110 (10/11/93) RIH. REAMED F/10,692'-10,732'. A~-FEMPT TO ORIENT DMWD TOOL, NEG. POOH. MADE UP a BHA WITH A STEERING TOOL. RIH. DAY 111 (10/12/93) RIH. RIGGED UP STEERING TOOL. WASHED F/10,673'-10,732'. 1/2" HOLE F/10,732'-10,786'. TRIP FOR BIT. DAY 112 (10/13/93) DRILLED 6- POOH. TESTED DOPE. RIH. DAY 113 (10/14/93) DRILLED F/10,786'-10,824'. DRILLED F/10,824'-10,890'. DRILLED F/10,890'-10,912'. TRIP FOR BIT. REAMED F/10,838'-10,890'. DAY 114-116 (10/15-17/93) DRILLED 6-1/2" HOLE F/10,912'-11,022'. TRIP FOR BIT. DRILLED F/11,022'- 11,097'. TRIP FOR BIT. DRILLED F/11,097'-11,224'. TRIP FOR BIT. DRILLED F/11,224'-11,251' DAY 117 (10/18/93) DRILLED 6-1/2" HOLE F/11,251'-11,319'. TRIPPED FOR BIT. REAMED 11,248'- 11,319' AND DRILLED 6-1/2" HOLE 11,319'-11,321'. DAY 118 (10/19/93) DRILLED 6-1/2" HOLE F/11,321'-11,418'. TRIP FOR BIT. DAY 119 (10/20/93) DRILLED 6-1/2" HOLE F/11,418'-11,433'. MWD NOT WORKING. POOH. TESTED BOPE. RIH. DRILLED F/11,433'-11,441'. DAY 120 (10/21/93) DRILLED 6-1/2" HOLE F/11,441'-11,529'. TRIP FOR BIT. DRILLED F/11,529'- 11,534'. DAY 121-123 (10/22-24/93) DRILLED 6-1/2~H0,1,.E F~/11,534'-11,65,5'. POO,H. RAN RESIS~TI/VITY-INDUCTION LOG. RAN DEN-CN-GR LOG F,/11,630-10,525. RAN 64 ARM"CALIPER F,/9990'- SURF. WIPER TRIP. TIGHT F/11,617'-11,650'. POOH. RAN 3.5" SLO'i-I-ED LINER WITH 2.062" STINGER AND AN INFLATABLE PACKER. RIH WITH SLOTTED LINER F/10,548'-11,623' (DPM). DAY 124 (10/25/93) CORRELATED INFLATABLE PACKER DEPTH WITH GR. LINER 10,536'-11,611' DIL. SPOt-FED 50 BBLS 3% KCL IN LATERAL. DROPPED BALL. INFLATED PACKER. CHASED LINER DOWN HOLE 10'. RELEASED FROM LINER. DISPLACED HOLE WITH 8.5 PPG 3% KCL. SPO~-FED POLYMER BREAKER IN LATERAL. POOH. HUNG UP AT 10,472' AND 10,409'. 2-1/16" WASH STRING PARTED UNDER THE LINER HANGER. DAY 125 (10/26/93) RIH AND ENGAGED FISH AT 10,467'. RAN FREEPOINT. INCONCLUSIVE. RAN 1.375" CU~-FER AND SHOT AT 11,480'. PULL FREE. RIH WITH FREEPOINT. RESULTS UNABLE TO DAY 126 (10/27/93) RAN FREEPOINT. SHOWED FREE AT 11,200'. POOH WITH F.P. CUT WASH STRING AT 11,200'. POOH. RECOVERED 738'. T.O.F. AT 11,200'. DAY 127 (10/28/93) TEST DOPE, OK. RIH WITH 6-1/2" MILL AND TAGGED TOP OF 3-1/2" LINER AT 10,547'. POOH. RIH WITH WHIPSTOCK RETRIEVING HOOK. DAY 128-130 (10/29-31/93) RIH TO 10,519'. RECOVERED RETRIEVABLE WHIPSTOCK. RIH WITH A 6-1/2" BIT AND DRILLED UP THE EZSV AT 10,536'. CHANGED 7-5/8" LINER OVER TO FILTERED 3% KCL. RIH AND SET EZSV AT 11,669' D~L. CHANGED TO DUAL 3-1/2" RAMS AND TESTED, OK. RIH WITH TCP GUNS, 3-1/2" KOBE CAVITY, AND DUAL 3-1/2" TUBING STRING. HYDROTESTING L. STRING TO 4000 PSI. DAY 131 (11/01/93) ~. RAN DUAL 3-1/2" COMPLETION. RAN GR CORRELATION. EZSV OR GUNS OFF BY 9'. DAY 132 (11/02/93) CONT'D RUNNING GR CORRELATION. POOH. CHECKED MEASUREMENTS, OK. RIH WITH ELECTRIC LINE TAGGED EZSV AT 11,669', OK. DAY 133 (11/03/93) ,~ LOGGED WITH GR TO CORRELATION POINT SHOWS 8' OF STRETCH IN THE DIL. RIH WITH GUNS AND COMPLETION. HYDROTESTING L.S. TO 4000 PSI. DAY 135 (11/04/93) CONT'D RUNNING COMPLETION. TAGGED EZSV AT 11,669'. P/U 7' TO ACCOUNT FOR STRETCH. SPACED OUT AND LANDED TBG. INSTALLED BPV'S. REMOVED BOP. INSTALLED TREE AND TESTED TO 5000 PSI, OK. A Gyro da t a D i r e c t i o n a i S u rvey for UNOCAL WELL: GRANITE POINT UNIT NUMBER 42-2, 9 5/8, 7" LINER LOCATION: BRUCE PLATFORM, COOK INLET ALASKA Job Number: AK0993G457 Run Date: 27-Sep-93 18:48:38 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 60.983330 deg. N Bearings are Relative to True North Proposed Well Direction: 107.000 deg Vertical Section Calculated from Local Horizontal Reference Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference MI(. Oi:iLi4ED A Gyro d a t a D i r e c t i o n a i Survey UNOCAL WELL: GRANITE POINT UNIT LOCATION: BRUCE PLATFORM, Job Number: AK0993G457 NUMBER 42-2, 9 5/8, 7" LINER COOK INLET ALASKA MEASURED DEPTH ft 0.0 I N C L AZIMUTH deg deg 0.00 0.00 DOG-LEG VERTICAL VERTICAL C L O S U R E SEVERITY DEPTH SECTION DIST AZIMUTH deg./100 ft ft ft deg 0.00 0.0 0.0 0.0 0.0 MEASURED DEPTHS REFERENCED TO R.K.B. ELEVATION 100.0 .14 58.09 .14 100.0 .1 200.0 .12 148.36 .18 200.0 300.0 .30 130.13 .19 300.0 400.0 .83 116.36 .54 400.0 500.0 1.92 94.85 1.18 500.0 600.0 2.01 100.24 .21 599.9 .2 .6 1.5 3.9 7.2 700.0 1.86 119.43 .66 699.8 800.0 1.70 144.52 .79 799.8 900.0 1.92 161.82 .59 899.7 1000.0 2.49 174.52 .75 999.7 1100.0 3.65 186.26 1.31 1099.5 10.6 13.3 15.5 17.3 18.7 1200.0 4.53 195.90 1.11 1199.3 1300.0 6.49 209.52 2.35 1298.8 1400.0 8.29 225.74 2.74 1397.9 1500.0 10.71 235.08 2.86 1496.5 1596.0 12.39 237.54 1.82 1590.6 19.4 18.2 13.5 4.3 -7.9 1700.0 14.76 241.39 2.43 1691.7 1800.0 16.64 243.81 1.99 1787.9 1900.0 19.30 245.44 2.71 1883.0 2000.0 21.55 245.26 2.25 1976.7 2100.0 23.22 243.43 1.82 2069.2 -24.4 -43.7 -66.5 -92.6 -120.6 Page H O R I Z O N T A L COORDINATES feet 0.00 N 0.00 E 26.9 33 .6 42.3 53.9 69.0 89.9 212.8 75.57 S 48.62 W 114.1 219.5 87.99 S 72.65 W 142.6 224.8 101.18 S 100.52 W 175.7 228.8 115.73 S 132.23 W 212.7 231.5 132.24 S 166.54 W 151.0 23.58 S 13.04 E 164.1 32.29 S 9.18 E 178.3 42.25 S 1.23 E 192.4 52.60 S 11.56 W 203.6 63.24 S 27.57 W 10.6 105.0 2.73 S 10.22 E 13.4 110.8 4.74 S 12.50 E 15.8 118.5 7.54 S 13.88 E 18.5 127.7 11.29 S 14.61 E 22.0 138.9 16.62 S 14.47 E .3 80.7 .04 N .26 E .6 112.4 .21 S .52 E 1.5 117.2 .70 S 1.37 E 3.9 107.6 1.17 S 3.69 E 7.3 102.9 1.62 S 7.08 E .1 58.1 .07 N .10 E A Gyro d a t a D i r e c t i o n a i S u rvey UNOCAL WELL: GRANITE POINT UNIT LOCATION: BRUCE PLATFORM, Job Number: AK0993G457 NUMBER 42-2, 9 5/8, 7" LINER COOK INLET ALASKA Page MEASURED I N C L AZIMUTH DEPTH ft deg deg 2200.0 25.55 240.92 2300.0 27.97 239.14 2400.0 30.33 239.00 2500.0 32.80 238.39 2600.0 37.30 236.49 DOG-LEG VERTICAL VERTICAL C L O S U R E SEVERITY DEPTH SECTION DIST AZIMUTH deg./100 ft ft ft deg 2.54 2160.2 -149.8 253.3 233.3 2.55 2249.5 -180.5 298.1 234.3 2.36 2336.8 -213.2 346.6 234.9 2.49 2422.0 -248.0 398.9 235.4 4.63 2503.8 -285.1 456.2 235.7 H O R I Z O N T A L COORDINATES feet 151.54 S 203.02 W 174.04 S 241.99 W 199.07 S 283.76 W 226.27 S 328.48 W 257.20 S 376.81 W 2700.0 37.76 233.99 2800.0 37.06 232.29 2900.0 38.69 232.03 3100.0 41.92 230.90 3200.0 43.85 231.84 1.59 2583.1 -322.8 517.1 235.6 291.93 S 426.84 W 1.25 2662.5 -358.7 577.8 235.4 328.36 S 475.45 W 1.63 2741.5 -394.0 639.1 235.1 366.02 S 523.93 W 1.66 2893.9 -467.2 768.2 234.5 446.62 S 625.05 W 2.03 2967.2 -505.6 836.2 234.2 489.09 S 678.21 W 3300.0 45.25 234.21 3400.0 45.85 235.99 3500.0 46.14 237.61 3600.0 46.40 239.11 3700.0 47.51 239.87 3800.0 46.28 239.97 3900.0 45.73 240.09 4000.0 46.52 240.54 4100.0 46.57 240.39 4200.0 47.89 240.28 2.18 3038.4 -546.8 906.3 234.1 1.41 3108.5 -590.9 977.7 234.2 1.20 3177.9 -636.9 1049.5 234.4 1.12 3247.1 -684.7 1121.6 234.6 1.24 3315.3 -734.0 1194.4 234.9 1.23 3383.7 -783.8 1267.2 235.2 .57 3453.1 -832.9 1338.9 235.5 .86 3522.4 -882.3 1410.7 235.7 .12 3591.2 -932.2 1483.1 235.9 1.33 3659.1 -982.6 1556.3 236.2 531.25 S 734.25 W 572.09 S 792.80 W 611.47 S 852.98 W 649.36 S 914.49 W 686.45 S 977.46 W 723.05 S 758.99 S 794.69 S 830.47 S 866.81 S 1040.63 W 1102.95 W 1165.57 W 1228.73 W 1292.51 W 4300.0 47.56 239.35 4400.0 48.37 239.69 4500.0 47.78 237.76 4600.0 47.95 237.17 4700.0 46.60 237.09 .76 3726.4 -1032.9 1630.1 236.3 .84 3793.3 -1083.1 1704.3 236.5 1.55 3860.1 -1132.6 1778.6 236.6 .47 3927.2 -1180.7 1852.7 236.6 1.35 3995.1 -1228.1 1926.2 236.6 904.01 941.69 980.30 1020.18 1060.05 1356.47 W 1420.48 W 1484.06 W 1546.58 W 1608.28 W A Gyro da t a D i r e c t i on a i Survey UNOCAL WELL: GRANITE POINT UNIT LOCATION: BRUCE PLATFORM, Job Number: AK0993G457 MEASURED I N C L AZIMUTH DEPTH ft deg deg 4800.0 46.56 236.76 4900.0 46.31 236.71 5000.0 46.87 236.75 5100.0 46.56 237.05 5200.0 47.07 237.00 5300.0 47.00 237.19 5400.0 48.30 236.92 5500.0 48.22 237.40 5600.0 47.08 237.56 5700.0 47.25 236.93 5800.0 46.08 237.71 5900.0 45.26 237.66 6000.0 44.34 237.55 6100.0 43.67 237.52 6200.0 42.97 237.16 6300.0 41.97 237.69 6400.0 41.24 238.48 6500.0 40.65 238.63 6600.0 41.10 238.63 6700.0 40.56 240.18 6800.0 40.27 239.55 6900.0 40.18 239.69 7000.0 39.48 240.35 7100.0 39.40 240.85 7200.0 40.07 241.35 NUMBER 42-2, 9 5/8, 7" LINER COOK INLET ALASKA DOG-LEG VERTICAL VERTICAL C L O S U R E SEVERITY DEPTH SECTION DIST AZIMUTH deg./100 ft ft ft deg .24 .25 .56 .38 .52 .16 1.32 .37 1.15 .49 1.30 .83 .92 .67 .74 1.07 .89 .60 .45 1.15 .5O .13 .81 .33 .75 4063.8 -1274.7 4132.7 -1321.0 4201.4 -1367.4 4270.0 -1414.1 4338.4 -1461.0 4406.6 -1508.2 4473.9 -1555.7 4540.5 -1603.8 4607.9 -1651.8 4675.8 -1699.2 4744.5 -1746.3 4814.3 -1792.9 4885.3 -1838.7 4957.2 -1883.9 5030.0 -1928.3 5103.7 -1972.1 5178.5 -2015.7 5254.0 -2059.2 5329.7 -2102.7 5405.3 -2146.7 5481.5 -2190.8 5557.8 -2234.6 5634.6 -2278.3 5711.8 -2322.1 5788.7 -2366.6 Page 1998.8 236.6 2071.3 236.6 2143.9 236.6 2216.7 236.6 2289.7 236.7 2362.8 236.7 2436.7 236.7 2511.4 236.7 2585.2 236.7 2658.6 236.7 2731.3 236.7 2802.8 236.8 2873.3 236.8 2942.7 236.8 3011.3 236.8 3078.9 236.8 3145.2 236.9 3210.7 236.9 3276.2 236.9 3341.5 237.0 3406.2 237.0 3470.7 237.1 3534.7 237.1 3598.1 237.2 3661.9 237.3 H 0 R I Z 0 N T A L COORDINATES feet 1099.69 S 1139.43 S 1179.29 S 1219.04 S 1258.73 S 1669.14 W 1729.73 W 1790.47 W 1851.45 W 1912.62 W 1298.48 S 1338.68 S 1379.14 S 1418.87 S 1458.56 S 1974.06 W 2036.08 W 2098.77 W 2161.09 W 2222.76 W 1497.83 S 1536.07 S 1573.81 S · 1611.10 S 1648.12 S 2283.98 W 2344.43 W 2403.92 W 2462.54 W 2520.30 W 1684.48 S 1719.59 S 1753.77 S 1787.84 S 1821.12 S 2577.19 W 2633.54 W 2689.46 W 2745.33 W 2801.59 W 1853.66 S 1886.32 S 1918.33 S 1949.52 S 1980.40 S 2857.65 W 2913.36 W 2968.84 W 3024.19 W 3080.15 W A Gyro d a t a D i r e c t i o n a i Survey UNOCAL WELL: GRANITE POINT UNIT LOCATION: BRUCE PLATFORM, Job Number: AK0993G457 NUMBER 42-2, 9 5/8, 7" LINER COOK INLET ALASKA MEASURED I N C L AZIMUTH DOG-LEG VERTICAL VERTICAL DEPTH SEVERITY DEPTH SECTION ft deg deg deg./100 ft ft 7300.0 41.40 241.57 7400.0 42.72 241.50 7500.0 44.11 241.37 7600.0 44.98 241.62 7700.0 45.23 241.69 7800.0 44.27 241.43 7900.0 43.44 242.11 8000.0 42.66 242.22 8100.0 42.26 242.60 8200.0 42.30 241.83 8300.0 41.82 242.15 8400.0 41.33 242.34 8500.0 41.04 241.56 8600.0 39.52 240.94 8700.0 37.57 237.50 8800.0 34.16 236.67 8900.0 32.46 234.25 9000.0 29.58 230.32 9100.0 27.39 222.43 9200.0 24.79 216.74 9300.0 22.73 212.22 9400.0 21.31 207.29 9500.0 19.40 201.60 9600.0 17.07 194.28 9700.0 15.27 182.55 1.34 5864.5 -2412.3 1.32 5938.7 -2459.2 1.39 6011.4 -2507.4 .89 6082.7 -2556.5 .25 6153.2 -2606.3 .97 .96 .78 .48 .52 .52 .51 .59 1.57 2.90 3.45 2.15 3.52 4.35 3.61 2.74 2.33 2.74 3.27 3.72 6224.3 -2655.7 6296.4 -2704.5 6369.4 -2752.9 6443.2 -2801.0 6517.2 -2848.7 6591.4 -2896.1 6666.2 -2943.2 6741.5 -2989.7 6817.8 -3034.8 6896.0 -3076.7 6977.0 -3114.4 7060.6 -3148.6 7146.2 -3178.4 7234.1 -3201.8 7323.9 -3218.8 7415.4 -3230.9 7508.1 -3239.3 7601.9 -3243.8 7696.8 -3244.5 7792.8 -3240.5 Page C L O S U R E H O R I Z O N T A L DIST AZIMUTH COORDINATES ft deg feet 3727.0 237.3 3793.8 237.4 3862.3 237.5 3932.3 237.6 4003.0 237.6 4073.2 237.7 4142.3 237.8 4210.4 237.8 4277.7 237.9 4344.7 238.0 4411.6 238.0 4477.8 238.1 4543.5 238.1 4608.0 238.2 4670.3 238.2 4728.8 238.2 4783.7 238.2 4834.9 238.1 4881.5 238.0 4923.2 237.8 4960.2 237.6 4993.4 237.4 5022.6 237.2 5046.9 237.0 5065.3 236.8 2011.58 S 2043.50 S 2076.36 S 2109.84 S 2143.47 S 3137.48 W 3196.37 W 3256.73 W 3318.37 W 3380.72 W 2176.99 S 2209.77 S 2241.65 S 2272.91 S 2304.27 S 3442.62 W 3503.65 W 3564.01 W 3623.84 W 3683.36 W 2335.73 S 2366.64 S 2397.60 S 2428.68 S 2460.52 S 3742.51 W 3801.23 W 3859.34 W 3916.02 W 3969.54 W 2492.33 S 2523.43 S 2554.86 S 2587.60 S 2621.37 S 4018.71 W 4063.95 W 4104.73 W 4139.24 W 4167.30 W 2654.52 S 2687.01 S 2718.59 S 2748.26 S 2775.63 S 4190.14 W 4208.77 W 4223.22 W 4232.95 W 4237.16 W A Gyro da t a D i r e c t i o na i S u r v ey UNOCAL WELL: GRANITE POINT UNIT LOCATION: BRUCE PLATFORM, Job Number: AK0993G457 NUMBER 42-2, 9 5/8, 7" COOK INLET ALASKA LINER Page MEASURED I N C L AZIMUTH DEPTH ft deg deg DOG-LEG VERTICAL VERTICAL C L O S U R E SEVERITY DEPTH SECTION DIST AZIMUTH deg./100 ft ft ft deg H O R I Z O N T A L COORDINATES feet 9800.0 15.82 168.12 9900.0 15.90 154.94 10000.0 16.10 142.36 10100.0 16.80 124.12 10200.0 16.39 109.80 3.90 7889.2 -3230.6 5078.1 236.5 3.60 7985.4 -3214.9 5085.1 236.2 3.47 8081.5 -3194.4 5086.4 235.9 5.19 8177.4 -3169.3 5080.2 235.6 4.10 8273.2 -3141.4 5066.7 235.3 2802.13 S 4234.94 W 2827.88 S 4226.33 W 2851.27 S 4212.06 W 2870.35 S 4191.63 2883.24 S 4166.38 W 10300.0 16.41 107.97 10400.0 17.04 107.43 10500.0 19.87 105.49 10600.0 20.89 105.49 10700.0 20.61 106.74 .52 8369.2 -3113.1 5050.0 235.1 .66 8464.9 -3084.4 5032.6 234.8 2.90 8559.8 -3052.7 5013.0 234.5 1.01 8653.5 -3017.9 4991.2 234.2 .52 8747.0 -2982.5 4969.4 233.9 2892.38 S 4139.67 W 2901.13 S 4112.25 W 2910.06 S 4081.89 W 2919.36 S 4048.33 W 2929.19 S 4014.29 W 10800.0 21.43 106.98 10900.0 20.98 105.19 11000.0 20.58 103.98 11100.0 '16.31 100.24 11200.0 18.03 101.60 11300.0 16.29 103.56 11400.0 17.20 103.07 11500.0 16.07 100.28 11600.0 11.31 95.45 11650.0 9.86 97.35 .82 8840.4 -2946.6 4947.9 233.6 .79 8933.6 -2910.4 4926.0 233.2 .58 9027.1 -2875.0 4903.9 232.9 .43 9121.9 -2843.5 4883.4 232.6 .77 9217.4 -2814.2 4863.8 232.4 1.84 9312.9 -2784.7 4845.0 232.1 .92 9408.7 -2756.0 4827.0 231.8 1.38 9504.5 -2727.5 4808.6 231.6 4.90 9601.6 -2704.2 4792.5 231.4 2.98 9650.7 -2695.1 4786.0 231.3 2939.60 S 3979.97 W 2949.63 S 3945.22 W 2958.56 S 3910.89 W 2965.31 S 3880.02 W 2970.91 S 3851.03 W 2977.31 S 3822.24 W 2983.94 S 3794.21 W 2989.75 S 3766.19 W 2993.16 S 3742.81 W 2994.17 S 3733.69 W Final Station Closure: Distance: 4785.97 ft Az: 231.27 deg. MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: thru.: Blair E Wondzell Petr Insp Supervisor from: ~oohn Spaulding Petr Inspector date: file: sub)ecL; August 13, 1993 072293,doc BOP Test UNOCAL-Bruce Platform Granite Point Field, Well 42-2 PTD 93-73 Thursday, July 22, 1.993: I traveled to Baker Platform rig to witness a BOP test. As noted on the attached AOGCC BOP test form, all functions tested well. On the previous test the gas_ defection system alarms were worki.n.g but the warning lights on the rig floor were not. I tested these lights and they had been repaired. Summary: I witnessed a BOP test on Baker Platform Rig with 0 failures; 3 1/2 hour test length. ~ f attachments MEMORANDUM Oil and Gas Conservation Commission TO: David Johnston, Commissioner TBRU: Blair Wondzeil, P. I. Supervisor DATE: FILE NO: TELE. NO: State of Alaska 279-1433 FROM: John Spaulding, SUBJECT: Petroleum Inspector FIELD REPORT · '-T~b / ~'/;:/~-~ ,-x.~.-.-' . .... . ; / / / ,~' : - .':'/ :-:- ,.-/ ~ i~. ,'.' · .. STATE. OF ALASKA OIL AND GAS CONSERVATION 'COMMISSION BOPE Test Report OPERATION: Drlg: ~""~' Workover: DATE: OrlgContllctor: '~4:::)O L._ //~c/-~ RigNo. PTD# ~-7.? RigPhJ Ol~mtor: Well Name: ~ ~:/../~:~:~ ~ -/~ TesC Initial , Weekly / Other _ :~. ~..~.~::.~?...~. · .:,~... :,.....(.~.....,).,. :.. · ......1 ............:. :-.-?,.-:"-:.-:4 ..'. :',..'.'...-: · ."-': *. ~ 4..,,:,: ..~::....:- ..:. :.1: ;-:.'::: · -.: :: ,: :.:.~::. :?:,~.4i!~11/,'1 ,; ~ i~ ~.¢¢.-.:,: :,~c.:c-:.¢..--;.:.,...':...~.,,.; ....................... III II II I ......... II I II Teat MISC. INSPEC~ONS: FLOOR SAFETY VALVES: quan. P/F Location Gen..' ~ ~,, Weft Sign ~ Upper Kelly (.~/.~ Lower Kelly / Housekeeping: ,~/~ (Gen) Drl. Rig -~ ~ I '-ii Reserve ~ f//,, Bail T~lx Inside BOP / P Test BOP STACK: : qua. Prem~ P/F CHOKEILN~OLD: HCR Yelv~ / Kill LJne Valves ~. F" ACCUMULATOR SY51'EM: Check Valve ~/~ System Pressure Pressure After Closure , MUD SYSTEM: Light Alarm 200 psi Altained After ~ Trip Tank ~/ ~.~ System ~ Attained . =~ minutes ~. Pit Level Indicators ~--- , ~ , Blind Switch Covers: MiwMr:. Flow IK[icator / . ~ Nilgn. airs: '/-/' ¢ ~ , Oas Detectors / ",.--- .:::?¢.y~.. , .. Psig. ; , .. i' ~: ~' X """ "' ''"' ,' I ~- ..... ..~C,_~C,~C~' ...... -'-" ':' '~":' ~~' "' '" :'~:::~.~ ~~~~ _:~,~~, · - .......... ~- ....-- ... :., ..:~ ~..:;. :.>-.. :;.~,.,.:.:. · · ..- -.~;:...... - .., -.-.~:/...- -:/:.:::.:, :- :.-.....::...,- ..~....~. ~, .:. -... · . ....;:::-..-..-..::.- :.' . .. .-.- , . ~ - . ~. .... ...... ~'~} .... ~-- ~~ :~.c~::..~.. ~. ~ X~..'.'.: Number of Failume ~ Test Time .~ '/~_ Houm Number of valve~ tempi ~ / . RepMr or Replmmnent of Failed j Equipment'tall be made ~ dly~. Notify the lrmpectm on duty and follow with WdUen or [the'AOOCC C~mmis~n Office M: Fex No. 27~-7M2 InspeGtor North ~lope Pmger No. i~.360T 1 If your c~ll is not returned by the impector within 12 houm ple~e contact the P. I. 8upen~mor ~t 2T~1433 REMARKS: · ii i i i i i · i i · i i i i · orig.-Well File c - OperJRig c - Database c - Trip Rpt File c- Inspectar STATE WITNESS REQ~JIRED? YES ~--"~- NO 24 HOUR NOTICE GIVEN YES ~.----~ NO Waived By:. W~essed By:. Fk021L.XLT Rev. 1/93 June 8, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 G. Russell Schmidt Regional Drilling Manager UNOCAL P O Box 196247 Anchorage, AK 99519 Re: Granite Point Well No. 42 UNOCAL Permit No: 93-73 Sur. Loc. 2000'FSL, 1952'FWL, Sec. 31, TllN, RllW, SM Btmhole Loc. 978'FNL, 2030'FEL, Sec. !, TiON, R12W, SM Dear Mr. Schmidt.' Enclosed is the approved application for permit to drill the above referenced well. Your application for a variance to set the conductor pipe required by 20 AAC 25.030(c)(2) to 1023'BML is hereby approved. For this well UNOCAL is also approved to utilize a 20" BOP stack to drill below the 18-5/8" conductor in variance from 20 AAC 25.035(c)(2). The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. Sincerely, Russell A. Dougla~ Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. '~:~ prh~fed or~ recycled [),'tu~r b y -~, f'). ..... STATE OF ALASKA "--- ALASKA AND GAS CONSERVATION COk. PERMIT TO DRILL SION 2O AAC 25.005 la. Type of work Drill E~ Redrill [-] 1 lb. Type of well. Exploratory [~ Stratigraphic Test ~ Development Oil ~ Re-Entry ~ Deepen ~]I Service ~ Development Gas ~ Single zoneE~ Multiple Zone E~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (UNOCAL) 115' feet GRANITE POINT 3. Address 6. Property Designation MIDDLE KENAI P.O. Box 196247, Anchorage, AK 99519 ADL 18742 4. Location of well at surface PLATFORM BRUCE, 2000' FSL 7. Unit or property name 11. Type Bond (SEE 20 A0025.025) 1952' FWL, SEC. 31, T11 N, R1 lW, SM GRANITE POINT United Pacific Ins. Co. At top of productive interval (10,485') 907' FNL, 8. Well number Number 2206' FEL, Sec. 1, T10N, R12W, SM WELL #42 U62-9269 At total depth (12,555') 978' FNL, 2030' FEL, 9. Approximate spud date Amount SEC. 1, T10N, R12W, SM JUNE~, 1993 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (Me a,dTVD) property line 3800' feet 4' @ surface feet 5060 12,555'MD/10,437' TVD feet 16. To be completed for deviated wells 17. Anticipated Pressure(see 20AAC2~.03~ Kickoff depth 876 feet Maximum hole angle 50 dec_ M~m,ms,~o~ 1873 psig At total depth ('rVD) 10,437' psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) O. 30" WELDER 156' 45 45 200 200 ~ .~ ,/°/~.z.~ / 22" 18-5/8" 87.5# K55 QTE-6O 1157' 43 43 1200 1200 200 BBLS (surface) 17-1/2" 13-3/8" 72# N80 BU'Ff' 5957' 43 43 6000 4763 800 BBLS (surface) 12-1/4" 9-5/8" 53.5# N80 BUTT 12513' 42 42 12555 10437 500 BBLS (4000') 8-1/2" 5-1/2" 15.5# K55 BU'I-F 1225' 10,730 8650 11955 9826 NONE 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural 80~;cUec.Or ~ ~ E F IV ~ D I nterm ed late Production i~ l~ ¥ I '~ · .~ :. ~ ~.~,,.~.~ Liner Alaska Oil & Gas O0ns. O0mmissio~ Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee ~: Property plat E~ BOP Sketch~: Diverter Sketch I--1 Drilling program I~ Drilling fluid pr~ogram ~: Time v~depth plot E~ Refraction analysis i-I Seabed report E~ 20 AAC 25.050 requirements '21 .I hereby ccLl~ tl~~~ol~9 i~,~ tr~CrC"jcg?rect to the best of my knowledge N... ' Signed G. RUSSELLSCHMIDT Title REGIONAL DRILLING MANAGER Date 5/5/93 Commission Use Only Permit Number I API number Approval date See cover letter '~ -~ ' ?¢2t 50-/%Z ,S - 2 o rg.',ff' / for other requ rements Conditions of approval Samples required ~ Yes ~ No Mud Icg required ~ Yes..~ No Hydrogen sulfide measures ~ Yes ::~ No Directional survey required .'~ Yes E~ No Required workingpressureforBOPE ~ 2M; [~ 3M; ~ 5M; ~ 10M; ~] 15M Other: Ut'~,,.~,?~AL SIGNED BY by the order of Approved by :' !~SELL A. DOUGLAb-"S Commissio~er~ the commission Dateg ....- <~-'"z Form 10-401 Rev. 12-1-85 Submit in triplicate" Unocal North Americ; Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region May 5, 1993 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 PLATFORM BRUCE ADL 18742 WELL ~ 42 Dear Mr. Johnston In the attached permit to drill you will find<that Unocal is requesting approval to drill and produce a well with two ultimate bottom hole locations. The first bottom hole location was listed in the permit as: BHL #1: 978' FNL, 2030' FEL, SEC 1, T10N, R12W, SM A sidetrack is planned and both the original wellbore as well as the sidetrack are expected to be productive wellbores. The second bottom hole location is: BHL #2: 880' FNL, 2436' FEL, SEC 1, T10N, R12W, SM Also in the permit to drill you will find that Unocal is requesting approval to drill to 1200' with a flow nipple and then place a 20" BOP stack on the 18-5/8" casing that is planned to be set and cemented at 1200'. It has been the practice on the Bruce platform to drill to +/- 600' with a riser, run and cement conductor casimg, install a diverter and drill to +/- 3000'. Several wells on the platform: 17586 #5, 17587 #5, 18742 #18, #20, & #31, were drilled to +/-1600' with a riser where casing was set and BOPE installed. RECEIVED MAY1 1 i99,3 , laska .0il & Gas Cons. Comrnission Anchorage The 1200' casing point was chosen as it is well above any indications of gas and is in a competent siltstone. It is anticipated that the formation fracture gradient will be 0.95 psi/ft. The formation fracture pressure at the 18-5/8" shoe is 1140 psi (1200' x 0.95 psi/ft). This is well above the potential hydrostatic pressure incurred with maximum expected surface pressure of 990 psi (see the MSP calculations in the permit to drill). Since the casing shoe will not break down in a kick situation and the setting depth is above any indications of gas we feel that this is a prudent design. Sincerely, G. Russell Schmidt Drilling Manager Alaska Oil & Gas Cons. Commission Anchoraga · · · · · · · · · 10. 11. 12· 13o 14. 15. 16. 17. GRANITE POINT 18742 #42 DRILLING PROCEDURE SKID RIG OVER LEG #4, SLOT #3, PLATFORM BRUCE DRILL 22" HOLE TO 1200' (500'/DAY). RUN AND CEMENT 18-5/8" CASING. INSTALL 20" BOPE AND TEST TO 3000 PSI. DRILL 17-1/2" HOLE TO 6000' (500'/DAY), THIS SECTION TO BUILD TO A 50 DEG ANGLE. RUN AND CEMENT 13-3/8" CASING. INSTALL 13-5/8" BOPE AND TEST TO 5000 PSI. DRILL 12-1/4" HOLE TO 12,555', THE LAST PORTION OF THIS SECTION IS TO RUN PARALLEL TO THE C-7 SANDS. LOG WITH A STANDARD SUITE AND AN FMS. RUN AND CEMENT 9-5/8" CASING SET A RETREIVABLE PACKER AND WHIPSTOCK AT 10,714'. DRILL 8-1/2" HOLE TO 11,955', PARALLEL TO THE C-5 SANDS. RUN 5-1~' ~LINER FROM TD TO 10 730' AND SET IN OPEN HOLE WITH AN INFLATABLE PACKER. RECOVER THE WHIPSTOCK AND PACKER. RUN A DUAL 3-1/2" HYDRAULIC COMPLETION WITH HANG OFF CASING GUNS. PUMP THE HYDRAULIC PUMP TO ACHIEVE AN UNDERBALANCE. PERFORATE THE C-7 AND C-3 OIL SANDS. TIME: 87 DAYS GRANITE POINT 18742 WELL NO. 42 Anticipated Pressures for the 22" hole: Mud weight = 9.0 ppg = .468 psi/ft Total Depth of 22" hole is 1200' MD, 1200' TVD Pore Pressure Gradient = 0.450 psi/ft Maximum Surface Pressure cannot exceed maximum bottom hole pressure: 1200' * 0.450 psi/ft = 540 psi Anticipated Pressures for the 17-1/2" hole: Mud weight = 9.3 ppg = 0.484 psi/ft //~ 12~ Shoe is proposed to be at 1200' MD, 1200' TVD Total Depth of the 17-1/2" hole is 6000' MD, 4763' TVD Estimated Fracture gradient._(l~7~'' shoe) = 0.90 psi/ft ,--~rore Pressure Gradient = 0.450 psi/ft Gas gradient (assume worst case) = 0.0 psi/ft Assume 1/2 of the wellbore volume is gas and 1/2 is mud during a kick situation. Maximum Surface pressure = (4763 ft * 0.450 psi/ft) -0.5 (4763 ft * 0.484 psi/ft) -0.5 (4763 * 0 psi/ft) = 990 psi Anticipated Pressures for the 12-1/4" hole: ~/eMud weight = 10.4 ppg = 0.541 psi/ft it)7~ ~' Shoe is proposed to be at 6000' MD, 4763' TVD Total Depth of the 12-1/4" hole is 12,555' MD, 10,437' TVD Estimated Fracture gradient (13-3/8" shoe) = 0.95 psi/ft Pore Pressure Gradient = 0.530 psi/ft through the C-2 and C-3 sands (base at 10,600'MD, 8680' TVD) Gas gradient (assume worst case) = 0.0 psi/ft Assume 1/2 of the wellbore volume is gas and 1/2 is mud during a kick situation. Maximum Surface pressure (case 1): (10,437 ft * 0.450 psi/ft) - 0.5 (10,437 ft * 0.541 psi/ft) -0.5 (3750 * 0 psi/ft) = 1873 psi Maximum Surface pressure (case 2): (8680 ft * 0.450 psi/ft) - 0.5 (8680 ft * 0.541 psi/ft) -0.5 (3750 * 0 psi/ft) = 1558 psi 'Aiask,p Oil & Gas Cons. .AnchoraaE~ GRANITE POINT WELL 18742 WELL NO. 42 MUD PROGRAM MUD TYPE: Low solids/Non Dispersed/Gel DEPTH: 200' - 1200' MUD PROPERTIES: Weight (Lbs/gal) = 9.0 - 9.3 Funnel Viscosity (Sec/Qt) = 80 - 250 Plastic Viscosity (cps) = 10 - 20 Yield Point (#/100 Cu ft) = 15 - 30 pH = 9.0 - 10.0 API Fluid Loss < 30 cc MUD TYPE: Low solids/Non Dispersed/Gel DEPTH: 1200' - 6000' MUD PROPERTIES: Weight (Lbs/gal) = 9.3 - 9.5 Funnel Viscosity (Sec/Qt) = 42 - 80 Plastic Viscosity (cps) = 10 - 20 Yield Point (#/100 Cu ft) = 10 - 30 API Fluid Loss (cc) = 10 - 12 pH = 9.0 - 10.0 Drill Solids (Lbs/bbl) < 50 MUD TYPE: Low solids/Non Dispersed/Gel (Parent Hole) DEPTH: 6000' - 12,555' MUD PROPERTIES: Weight (Lbs/gal) = 9.5 - 10.4 Funnel Viscosity (Sec/Qt) = 42 - 80 Plastic viscosity (cps) = 10 - 30 Yield Point (#/100 Cu ft) = 10 - 30 API Fluid Loss (cc) = 4 - 10 HPHT Fluid Loss (cc) = 8 - 20 (500 psi @ 200 Degrees F) pH MBT (Lbs/bbl) Drill Solids (Lbs/bbl) = 9.0 - 10.0 < 25 < 3O R ECE!VED MAY1 1 Alaska. ,'.')il & ~as Sons. MUD TYPE: Polymer/Brine (Genric Mud #2) DEPTH: 10,714' -11,955' (Lateral Hole) MUD PROPERTIES: Weight (Lbs/gal) = 9.0 - 9.5 Plastic Viscosity (cps) = 7 - 10 Yield Point (#/100 Cu ft) = 25 - 35 API Fluid Loss (cc) < 8.0 HPHT Fluid Loss (cc) < 25 (500 psi @ 200 Degrees F) pH = 9.0 - 10.0 Drill Solids (Lbs/bbl) < 25 PLATFOR.M BRUCE DRILLING STACK [ PITCHER NIPPLE- 16° ID WI10" FLOWLINE ANNULAR BOP 'NL ,.SHAFFER' ------ 13 5/8' 5000 PS! BX-160 ASSY WT. 13,650 LBS. DBL GATE BOP "NL SH-AFFER' 13 5/8' 5000 PS! BX-160 ASSY WT. 16,500 LBS. MUD CROSS- 13 518' BORE WI4' 5000 PSI VALVES SGL,. GATE BOP "NL SHAFFER° 13 518' 5000 PSI BX-160 ASSY WT. 9100 LBS. ------ RISER 18'OD 13 5/8'5000 FLG LOWER RISER 11' ID W/lO' SO00 PSI Fbi, FILL-UP FLOW KILL LINE ANNULAR BOP 21 ~'2000 psi I I ~ PIPE RAMS 20a/4Y 3000 -psi BI/ND RAMS 20s/~' 3000 psi [?-...I/~rb.. ~ SPOOL 4" 5000 psi ii II 4" 5000 PIPE RAMS 20s/i 3000 psi RISER 2o ~4" 3000 psi GRANITE POINT CHOKE psi LINE~~:> aI, ,~; o ,-,:,... . .. ae .'.,. 0il ,,:: ':.~,-,o Co;':3. BOPE~ STACK 21 h' 2000psi/20h" 3000psi g 2800 32OO 44O0 56OO _ J 58oo V7200 7600 9600 looOO 102,00 Structure : BRUCE Platform Well: 42-2 Field : Granite Point Field 4.00 ~ 8.00 18 5/8" Csg Pt 12.00 16.00 ~ BUILD 2 OEO / 100' 20.00 24.00 ,~ 28.oo 32.00 36.00 40.00 44.00 48.00 EOC iCreated by : jones ~!Date plotted : 27-Apr-95 ',Plot Reference is 42-2 Version #6. Conductor Coordinates are in feet reference slot #4-5a iTrue Vertical Depths are reference wellhead. BAKER HUGHES INTEO 4500 4050 3600 J I I [ I I NOTE: PLOT INLCLUDES PLANNED SIDE'TP4CK MAXIMUM ANGLE 49.83 DEG 13 5/8 "Csg Pt Begin Drop & Turn 20E6 / lOO' oocL£¢ Location : Cook Inlet, Alaska ' WELL PROFILE DATA i .... Point .... MD Inc Dir Tv~ North i'1% on 0 0.00 0.00 0 0 IKOP 876 0,150 O.O0 876 0 iEnd of Build 35r~ 49.83 239.18 3065 -521 '~End of Hold 7~80 49.83 239.18 5653 -2092 iTorget 10484 16.96 107.26 8415 -2916 iEnd of Hold 1135,5 18.98 107.28 9248 -2992 '.End of Drop 11740 7.D0 280,00 9628 -3004 iEnd of Hold 12555 7.00 280J~ 10437 -2987 <-- West 3150 2700 2250 1800 1350 900 450 0 450 II II II II II II ] ] I I ] 450 0 " 45O - _ gOO _1350 ISOO I - V _2700 S ,54.95 DEG W 4975' (TO TD) - _3600 46.48 42.63 38.80 55.00 31.24 27.55 23.94 20.48 17.23 14.55 12.12 10.92 11.10 12.60 15.04 TARGET - T/ C-~' TARGET - T/C-7 (Begin Final Turn) 6.2t OEO / I00' D06LEO 6.07 End Drop & Turn 6.41 · TD - CSG PT Sidetrack / Tie-In Point End Build & Turn EBegin Angle Drop nd Angle Drop ID - Csq Pt FINAL ANGLE ? DEG East1 0t 0i -873j -3506j -41581 -3915J -5987.j 0 i i i i I i i i I i i i i i i i i i i i I i i i i i i 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 Scale1 : 200.00 Vertical Section on 254.95 azimuth with reference 0.00 N, 0.00 E from slot #4-3 i 56o0 UNOCAL BRUCE Platform 42-2 stot #4-3 Granite Point Field Cook Inlet, Alaska PROPOSAL LISTING by Eastman Te[eco Your ref : 42-2 Version #6 Our ref : prop744 License : Date printed : 27-Apr-93 Date created : 23-Mar-93 Last revised : 27-Apr-93 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 59 36.731,w151 18 33.112 Slot location is n60 59 56.512,w151 17 53.529 Slot Grid coordinates are N 2559377.495, E 269563.574 Slot [oca[ coordinates are 2009.00 N 1952.00 E Reference North is True North UNOCAL BRUCE PLatform,42-2 Granite Point Field,Cook InLet, ALaska PROPOSAL LISTING Page 1 Your ref : 42-2 Version #6 Last revised : 27-Apr-93 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 0.00 200.00 0.00 N 0.00 E 0.00 0.00 Conductor 500.00 0.00 0.00 500.00 0.00 N 0.00 E 0.00 0.00 876.00 0.00 0.00 876.00 0.00 N 0.00 E 0.00 0.00 KOP 900.00 0.48 239.22 900.00 0.05 S 0.09 W 2.00 0.10 1000.00 2.48 239.18 999.96 1.37 S 2.30 W 2.00 2.67 1100.00 4.48 239.18 1099.7-/ 4.48 S 7.52 ~ 2.00 8.73 1200.00 6.48 239.18 1199.31 9.37 S 15.72 ~ 2.00 18.25 18 5/8" Csg Pt 1300.00 8.48 239.18 1298.45 16.04 S 26.90 ~ 2.00 31.23 1400.00 10.48 239.18 1397.08 24.48 S 41.04 ~ 2.00 47.66 1500.00 12.48 239.18 1495.08 34.68 S 58.13 W 2.00 67.50 1600.00 14.48 239.18 1592.32 46.62 S 78.15 ~ 2.00 90.75 1700.00 16.48 239.18 1688.68 60.29 S 101.07 ~ 2.00 117.36 1800.00 18.48 239.18 1784.06 75.68 S 126.86 ~ 2.00 147.32 1900.00 20.48 239.18 1878.33 92.77 S 155.50 ~ 2.00 180.57 2000.00 22.48 239.18 1971.38 111.53 S 186.94 W 2.00 217.09 2100.00 24.48 239.18 2063.10 131.94 S 221.15 W 2.00 256.82 2200.00 26.48 239.18 2153.37 153.98 S 258.10 ~ 2.00 299.72 2300.00 28.48 239.18 2242.08 177.62 S 297.72 ~ 2.00 345.74 2400.00 30.48 239.18 2329.13 202.84 S 339.98 ~ 2.00 394.81 2500.00 32.48 239.18 2414.41 229.59 S 384.82 W 2.00 446.89 2600.00 34.48 239.18 2497.81 257.85 S 432.19 ~ 2.00 501.90 2700.00 36.48 239.18 2579.24 287.59 S 482.03 ~ 2.00 559.78 2800.00 38.48 239.18 2658.59 318.77 S 534.28 ~ 2.00 620.46 2900.00 40.48 239.18 2735.7/ 351.34 S 588.88 ~ 2.00 683.86 3000.00 42.48 239.18 2810.69 385.28 S 645.76 ~ 2.00 749.92 3100.00 44.48 239.18 2883.25 420.53 $ 704.85 ~ 2.00 818.54 3200.00 46.48 239.18 2953.36 457.06 S 766.07 W 2.00 889.64 3300.00 48.48 239.18 3020.94 494.83 S 829.36 ~ 2.00 963.14 3367.59 49.83 239.18 3065.14 521.02 S 873.27 ~ 2.00 1014.13 EOC 3500.00 49.83 239.18 3150.55 572.87 S 960.16 ~ 0.00 1115.04 4000.00 49.83 239.18 3473.07 768.63 S 1288.28 W 0.00 1496.07 4500.00 49.83 239.18 3795.59 964.40 S 1616.39 g 0.00 1877.11 5000.00 49.83 239.18 4118.11 1160.17 S 1944.50 ~ 0.00 2258.15 5500.00 49.83 239.18 4440.63 1355.93 S 2272.61 W 0.00 2639.18 6000.00 49.83 239.18 4763.14 1551.70 S 2600.72 ~ 0.00 3020.22 13 3/8" Csg Pt 6500.00 49.83 239.18 5085.66 1747.47 S 2928.84 ~ 0.00 3401.26 7000.00 49.83 239.18 5408.18 1943.24 S 3256.95 ~ 0.00 3782.30 7380.06 49.83 239.18 5653.33 2092.04 S 3506.35 ~ 0.00 4071.93 Begin Drop & Turn 7400.00 49.44 239.05 5666.25 2099.84 S 3519.39 ~ 2.00 4087.08 7500.00 47.51 238.38 5732.54 2138.71 $ 3583.37 ~ 2.00 4161.79 7600.00 45.58 237.67 5801.31 2177.15 S 3644.95 W 2.00 4234.27 ~700.00 43.65 236.90 5872.50 2215.09 S 3704.04 ~ 2.00 4304.44 7800.00 41.73 236.09 5946.00 2252.51 S 3760.58-W 2.00 4372.21 7900.00 39.81 235.21 6021.73 2289.35 S 3814.49 W 2.00 4437.50 8000.00 37.90 234.25 6099.60 2325.56 S 3865.72 ~ 2.00 4500.24 8100.00 36.00 233.22 6179.51 2361.11 S 3914.19 ~ 2.00 4560.34 8200.00 34.11 232.08 6261.36 2395.95 S 3959.86 ~ 2.00 4617.73 8300.00 32.24 230.82 6345.06 2430.04 S 4002.66 ~ 2.00 4672.34 8400.00 30.37 229.43 6430.50 2463.33 S 4042.54 ~ 2.00 4724.11 Coordinates from slot #4-3 and TVD from wellhead (115.00 Ft above mean sea level) Vertical section is from wellhead on azimuth 234.95 degrees. Declination is 0.00 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teteco UNOCAL BRUCE Platform,42-2 Granite Point Field,Cook inlet, Alaska PROPOSAL LISTING Page 2 Your ref : 42-2 Version #6 Last revised : 27-Apr-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 8500.00 28.52 227.88 6517.58 2495.78 S 4079.45 W 2.00 4772.97 8600.00 26.69 226.13 6606.19 2527.37 S 4113.35 W 2.00 4818.86 8700.00 24.89 224.14 6696.23 2558.04 S 4144.20 ~ 2.00 4861.73 8800.00 23.12 221.87 6787.58 2587.76 S 4171.96 ~ 2.00 4901.52 8900.00 21.38 219.25 6880.13 2616.49 S 4196.60 ~ 2.00 4938.19 9000.00 19.69 216.19 6973.78 2644.21 S 4218.08 ~ 2.00 4971.69 9100.00 18.06 212.60 7068.40 2670.87 S 4236.38 W 2.00 5001.98 9200.00 16.51 208.33 7163.88 2696.44 S 4251.48 ~ 2.00 5029.03 9300.00 15.07 203.25 7260.11 2720.89 S 4263.35 ~ 2.00 5052.79 9400.00 13.76 197.17 7356.97 2744.19 S 4271.99 ~ 2.00 5073.25 9500.00 12.62 189.93 7454.34 2766.32 S 4277.39 g 2.00 5090.37 9600.00 11.72 181.45 7552.10 2787.25 S 4279.53 W 2.00 5104.14 9700.00 11.11 171.82 7650.12 2806.94 S 4278.42 ~ 2.00 5114.54 9800.00 10.83 161.40 7748.31 2825.38 S 4274.05 ~ 2.00 5121.55 9900.00 10.91 150.79 7846.52 2842.55 S 4266.43 ~ 2.00 5125.18 10000.00 11.34 140.66 7944.65 2858.42 S 4255.58 ~ 2.00 5125.40 10100.00 12.10 131.52 8042.58 2872.97 S 4241.50 ~ 2.00 5122.23 10200.00 13.11 123.60 8140.17 2886.19 S 4224.20 ~ 2.00 5115.67 10300.00 14.32 116.89 8237.33 2898.06 S 4203.73 ~ 2.00 5105.72 10400.00 15.70 111.28 8333.92 2908.57 S 4180.08 W 2.00 5092.40 10484.49 16.96 107.26 8415.00 2916.37 S 4157.66 W 2.00 10500.00 16.96 107.26 8429.84 2917.71 S 4153.35 W 0.00 11000.00 16.96 107.26 8908.10 2960.97 S 4014.09 ~ 0.00 11354.86 16.96 107.26 9247.53 2991.67 S 3915.26 W 0.00 11400.00 14.16 107.69 9291.02 2995.30 S 3903.71 ~ 6.21 5078.52 TARGET - T/ C-3 5075.76 4986.59 4923.31 TARGET - T/C-7 (Begin Final Turn) 4915.94 11500.00 7.96 109.72 9389.11 3001.36 S 3885.53 ~ 6.21 11600.00 1.84 125.35 9488.70 3004.63 S 3877.69 ~ 6.21 11700.00 4.52 277.13 9588.62 3005.07 S 3880.30 W 6.21 11740.12 7.00 280.00 9628.53 3004.45 S 3884.28 W 6.21 12000.00 7.00 280.00 9886.48 2998.95 S 3915.47 ~ 0.00 4904.54 4900,00 4902.39 4905.29 End Drop & Turn 4927.66 12500.00 7.00 280.00 10382.75 2988.36 S 3975.48 ~ 0.00 4970.72 12554.86 7.00 280.00 10437.20 2987.20 S 3982.06 ~ 0.00 4975.44 TD All data is in feet unless otherwise stated Coordinates from slot ~4-3 and TVD from wellhead (115.00 Ft above mean sea level) ~,..,'i/r~¥ ~ ~i ~"~"~ Vertical section is from wellhead on azimuth 234.95 degrees. ' ~'-~ Declination is 0.00 degrees, Convergence is -1 14 degrees Calculation uses the minimum curvature method. Presented by Eastman Teleco UNOCAL BRUCE Platform 42-2 slot #4-3 Granite Point Field Cook Inlet, Alaska PROPOSAL LISTING by Eastman Teleco Your ref : 42-2 Lat Version #2 Our ref : prop745 License : Date printed : 27-Apr-93 Date created : 23-Mar-93 Last revised : 27-Apr-93 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 59 36.731,w151 18 33.112 Slot location is n60 59 56.512,w151 17 53.529 Slot Grid coordinates are N 2559377.495, E 269563.574 Slot local coordinates are 2009.00 N 1952.00 E Reference North is True North UNOCAL BRUCE Platform,42-2 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : 42-2 Lat Version #2 Last revised : 27-Apr-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 10714.49 16.96 107.25 8635.00 2936.27 S 4093.60 W 0.00 10800.00 4.26 119.65 8718.88 2941.56 S 4078.86 W 15.00 10900.00 10.97 277.09 8818.40 2942.23 S 4085.11 ~ 15.00 10960.38 20.00 280.00 8876.53 2939.72 S 4101.02 W 15.00 11000.00 20.00 280.00 8913.76 2937.37 S 4114.36 g 0.00 5037.50 Sidetrack / Tie-in Point 5028.48 5033.98 5045.56 End Build & Turn 5055.13 11254.86 20.00 280.00 9153.25 2922.23 S 4200.20 ~ 0.00 11354.86 18.00 280.00 9247.80 2916.58 S 4232.27 W 2.00 11454.86 16.00 280.00 9343.42 2911.50 S 4261.06 W 2.00 11504.86 15.00 280.00 9391.60 2909.18 S 4274.22 ~ 2.00 11954.86 15.00 280.00 9826.27 2888.96 S 4388.92 ~ 0.00 5116.72 Begin Angle Drop 5139.72 5160.37 5169.81 End Angle Drop 5252.09 TD ALL data is in feet unless otherwise stated Coordinates from slot ~4-3 and TVD from wellhead (115.00 Ft above mean sea Level) Vertical section is from wellhead on azimuth 234.95 degrees. Declination is 0.00 degrees, Convergence is -1.14 degrees. Calculation uses the minimua curvature method. Presented by Eastman Te[eco UNOCAL BRUCE Platform 42-2 slot Granite Point Field Cook Inlet, Alaska CLEARANCE REPORT by Eastman Teleco Your ref : 42-2 Version #6 Our ref : prop744 License : Date printed : 27-Apr-93 ~' "' ' "~'.'~ Date created : 23-Mar-93 f' ~"~'~/~'~~h~r'"" Last rev~s~ : 27-Apr-93 ....... :~-~' ~ {~"~...~.,~ ~'''.~.;~'.'.~ ~ Fie~d ~s centr~ on ~0 59 36.~1,w151 18 33.112 Structure ~s centr~ on ~0 59 36.~1,w151 18 33.112 Slot location is n60 59 56.512,w151 17 53.529 Slot Grid coordinates are N 2559377.495, E 269563.574 Slot local coordinates are 2009.00 N 1952.00 E Reference North is True North Main calculation performed with 3-D minimum distance method Object wellpath MSS <2280-11500'>,,4,BRUCE Platform MSS <2020-11443'>,,6,BRUCE Platform MSS <6386-9613'>,,5,BRUCE Platform GMS <O-9550'>,,SRd,BRUCE Platform MSS <6386-10756'>,,5,BRUCE PLatform MSS <4828-6878'>,,5,BRUCE Platform MSS <529~-12200'>,,5,BRUCE Platform MSS <2168-11015'>,,3,BRUCE Platform MSS <2040-12033'>,,3,BRUCE Platform GMS <7000-10550'>,,20Rd,BRUCE Platform MSS <6990olO085,,>,,20,BRUCE Platform GMS <O-10060'>,,12Rd,BRUCE Platform MSS <2144-10480'>,,12,BRUCE Platform PGMS <O-12434'>,,6,8RUCE Platform MSS <2102-10087'>,,8,BRUCE Platform MSS <1020~-10518'>,,8,BRUCE Platform MSS <3970-12001'>,,8,BRUCE Platform PGMS <O-9931'>,,30,BRUCE Platform MSS <1970-10370'>,,lO,BRUCE Platform GMS <O-10585'>,,14,BRUCE Platform MSS <3225-10143'>,,16A,BRUCE Platform MSS <3225-7065'>,,16,BRUCE Platform MSS <0-9960'>,,18,BRUCE Platform GMS <0-10675'>,,31,BRUCE Platform GMS <0-10013'>,,34,BRUCE Platform MSS <5017-10905'>,,4,BRUCE Platform MSS <4220-11996'>,,40-2,BRUCE Platform Closest approach with Last revised Distance 19-Mar-9~ 99.7 22-Feb-93 80.7 5-Apr-93 8.0 4-Apr-9~ 8.0 4-Apr-93 8.0 3-Apr-9~ 81.6 ~-Apr-93 81.6 3-Apr-93 76.8 3-Apr-93 8.0 4-Apr-93 76.4 22-Feb-93 76.4 2-Apr-93 65.3 2-Apr-93 65.3 2-Apr-93 45.2 3-Apr-93 6.0 3-Apr-9~ 30.7 3-Apr-93 30.7 2-Apr-93 17.2 2-Apr-93 68.0 2-Apr-93 81.1 2-Apr-93 4.3 2-Apr-93 4.3 2-Apr-93 69.2 2-Apr-93 70.1 5-Apr-93 7.6 5-Apr-93 7.6 2-Apr-93 41.5 minim~ distance method M.D. Diverging from M.D. 876.0 11600.0 100.0 12320.0 300.0 11340.0 300.0 11320.0 300.0 11640.0 500.0 10261.5 500.0 12300.0 620.0 10484.5 100.0 11920.0 888.0 11740.1 888.0 11720.0 700.0 11720.0 700.0 11820.0 860.0 12280.0 100.0 11640.0 1100.0 10620.0 1100.0 11420.0 1466.7 11600.0 140.0 11720.0 860.0 11420.0 360.0 11180.0 360.0 2900.0 320.0 11700.0 260.0 11700.0 200.0 10940.0 200.0 11480.0 4200.0 12240.0 180 160 I I I 140 I 700 120 100 I I I 600 5OO '00 I0 ~00 Wesf 80 6O 40 I , ! I I , I 400 4300 100 300 3OO ,00 Scale 1 · 20.00 20 0 20 40 I I I I I I 4O 1000 1300 100 1100 )1000 .00 io0 1200 1100 1000 300 _ 20 _ 0 _ 20 _ 40 _ 60 _ 80 _lO0 _120 0 Wesf Scale 1 '50.00 1250 1 200 1150 )0 11 O0 1050 1000 950 900 850 800 750 700 O0 oW.o° 300 _8O0 _85O 0 I I V 1750 Wesf Scale 1 · 50.00 1700 1650 1600 1 550 1500 1450 1 400 1350 1500 1250 1200 I I I I 650 _ 700 75O 8OO 85O 9OO 4O0O 95O 0 41 O0 3300 _1000 _1050 CASING AND TUBING DESIGN WELL ~..~om,'~ ~r /P?P~ ~ CASING SIRING FIELD BOROUGH ~ ~,' STATE DAlE J-- G- P~ DESIGN BY ~", I. HUD wT. I 9'. J #/g, tiYD GR. I . /o, V psi/fL? MUD WT. II #/~ HYD. GR. II psi/ft. M.S.P. ps,(. CASING SIZE 1. I ~ ~-/~'' INTERVAL Bottom Top /~ oo 9.3 LENGTH DESCRIPTION Wt. Grade Thread ,,~z~ H-~' ~x ~-~o 72 /K- 8o J~, r/' WEIGHT TENSION MINIMUM W/ BF -top or SIRENGTtt W/O BFx_ section TENSION lbs lbs lDO0 lbs IDF COLLAPSE COLLAPSE PRESS. ~ RESIST. bottom tension psi psi CDF BURST PRESSURE psi INTERNAL MINIMUM YIELD psi BDF ~oo0 c/j £9-c7 tl sJJ' P 2 /.~ I. 9. .yg 63 UNOCAL - BRUCE ,::. x 3 - 5000 i J Il 1 I WP ! t "l 1_ ji j' ~/!"x !, 1 4 1 10 I1 14 15 11 18 19 1.00 4.00 7.00 1.00 2.00 2.0'3 1.00 1.00 1.00 1.00 l.O0 1.00 1.00 1.00 5.30 2.00 1.00 1.00 1,00 1.00 2.00 1.00 1.00 l.O0 5.00 ~0.00 4.00 32.00 72.(10 8.00 40.00 fi. OD 3' 5~ qale valve flanqed tee 413 h~d-choke ]' 10~ tan choke 3' 5~ drilled spacer drilled spacer 3' 5n I 2.1~8' ~3~ Y 5H ~ loft ~ 3.'~''~,., DSS 4' 5~ X 4.5* DSS 3' 5H X larQel fl~nqe 3' blind ilan,e ~' spool 3' 5~ flQ (."iL~O X 7 .,~"., spool ~' 5~10l tlnXsi~d ~pooi 3' 5BIlO~ tlqiflQ x34.525' ~u{ter tank 15' fl,l.X llanqed £ro~s 2' [lind llanue 2' 2' 5~ Qale v~lw 2' 5B X 2-2' LPI lrar, slllt~r fi~ 0-6000 ~si blind {|an~e 4' R-~q ~I rin~ ~-3{ ~Pl rinu BI-II, 5 APl riflq stud ,/ 2 nuts I 1/8I 7 1/2 stud s/ 2 nots I IiSX stud u/2 fiuts I I/4X 3 1/~ stud ~ ~/ nots I X 7 stud u/ 2 nuts I front VIeW Flow Line 6" £rm poorbo degasser Mud return · I 5?# rrm btm ' E . wlndow~q,, b~ Btm ~ ~nd Trap ~' { ' 156.8 bb~ ~-~ ~' I / ~'~ ~' : ......................... .6,8 bbl/in ~, -6~? bbl/in .f Opossum Belly 2~ Rever~e out ~-- 4" Floor drain ~-- Butterfly valve *.-- With riser 0 85" , -. · · Cuttings lg flc gates Rumba Shaker Trough Overboard .o .. #4 J.9 bbl/in 229 bbl ~_., ,~ 2 240 bBl ~ud Return-Leg ualizer Gun Walk Way Top Eq 6" 96"Frm Btm ' ua lzer Btm Equalizer 0" ~rm Btm Equalizer Btm Eq 0" Frm Btm #2 2 bbl/lu 240 bbl Gun Line Equalizer 1'9 bbl,/ln 229 bbl To Top Deck '-~. 1.54 bbl/i 184 bbl turn Le§s 5 & 4 4/ Pill P 3 Pill 1.54 bbl/ln 184 bbl Suctiont iLine Cmt Line U Top Eq 96" Frm Btm Po Top Deck _~ Hopper Re turn Biff Perry - Derrickman (~--Ball Valve (Gun Lines) t 5 25 6 ! 7 8 + -.F 17587 + + 18742 ~8 187, Z #34 17587 36 17586 17586 #5 1758( 18742 #6 17586 )NEK ST 17~ ~742T'~EK S~ · 28RD ~0 11 18742°~10 52 175,. .~5 "5¥ z 7 18742 ~14 5 3O g 4 #20 +31 ~D 18742 -F 52RDST1 TYONEK ST 175~ 2 ~ m 17587 #4 18742 ~12~,, I I V U OCAL Structure : BRUCE Platform Well : 42-2 Field : Granite Point Field Location : Cook Inlet, Alaska 32OO _ 3600 _ _ 4000_ 52O4} 84OO - 9600 _ 104300_ _ 10400_ Conductor iCreoted by : jones ::Dote plotted : 27-Apr-93 Plot Reference is 42-2 Version #6. iCoordinotes ore in feet reference slot iTrue Vertical Depths ore reference wellhead. KOP 4.00 ' 8.00 18 5/8" Csg Pt 12.oo 16.00 20.00 BUILD 2 DE(; / 100' tX 24.00 X 28.00 x,k 32.00 '~k 36.00 x~ 44.00 %, 48.00 EOC BAKER HUGHES INTEQ 4500 4050 3600 I I I I I NOTE: PLOT INLCLUDES P~D SIDETRACK 13 3/8 "Csg Pt % Begin Drop & Turn 2 DE6 / 100' DOCA. EG TARGET - T/ C-3' FINAL ANGLE 7 DEG TARGET - T/C-7 (Begin Final Turn) 6.21 DE(; / 100' BOGLE6 6.07 End Drop & Turn 6.41 TD - CSG PT i .... Point .... ilie on KOP !End of Build !End of Hold iTorqet !End of Hold iEnd of Drop !End of Hold 50 27OO 2250 I I I I I WELL PROFILE DATA .... UD Inc D;F ~ No~h Eost) 0 0.00 0.00 0 0 OI 876 0.00 O.OO 876 0 0t 3368 49.85 239.18 3065 -521 -873! 7380 49.83 239.18 5653 -2092 -3506! 10484 16.96 107.26 8415 -2916 -4158t 11355 16.96 107.26 9248 -2992 -3915{ 11740 7.00 280.00 9628 -3004 -5884{ 12555 7.00 280.00 10437 -2987 -59871 West 1800 1350 go0 I I I I { I I S 54.95 DEG W 4975' (TO TD) 46.48 42.05 38.80 55.00 31.24 27.55 23.94 20.48 17.23 1 4.35 12.12 10.92 11.10 1 2.60 15.04 Sidetrack / Tie-In Point End Build & Turn L[ Begin Angle Drop nd Angle Drop TD - Csg Pt 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 41~)0 5200 Scale 1 : 200.00 Vertical Section on 2.54.95 azimuth with reference 0.00 N, 0.00 E from slot #4-3 56O0 Scole 1 : 225.00 450 0 450 I I I I 450 0 450 goo 1550 _ _1800 _ _2250 _ _27O0 23150 - I I V Memorandum State of Alaska Oil and Gas Conservation Conmfission To: Commission June 4, 1993 Fm: Staff Subj: Granite Pt. No. 42 18-5/8" Conductor Setting Depth Variance In their permit application for GP No. 42, Unocal requested to set conductor pipe at 1200' MD. This setting depth is 1023' BML, whereas, 20 AAC 25.030 (c)(2) requires conductor to be set not more than 1000' BML. They cite five other wells drilled from the Bruce Plaffolm which have had conductor pipe set at depths of 1584 - 2517' MD between 1968 and 1978. Unocal also requested approval to utilize a 20" BOP stack to drill below the 18-5/8" conductor in variance from 20 AAC 25.035(c)(2). Staff discussions with Unocal persmmel in late April regarding GP No. 9 di~erte~;cBOP usage indicated there was no shallow gas based on recent drilling experience bom the Bruce Platfmrn. In addition, the operators estimated pressure at the shoe of the 18-5/8" casing indicate the fmmation will not fi'acture ff the well should have to be shut in to control a kick. We recommend approval of both variances based on the lack of shallow gas and ability to control the well with a BOP while ddlling below the conductor. =State: Alaska Borough: Well: GR. PT. # 18 Field: Granite Point St. Perm Da~e 6/3/93 Engr: M. Minder GPtI42.XLS Casing Inte~al Interval Size Bottom Descriptionescriptionescription Tension Top Length lA 18.625 1200 43 1157 2A 13.375 4763 43 5957 3A 9.625 10437 42 12513 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Lbs Grade Thread lbs 87.5 K-55 C~ET60 0 72 N-80 BTC 0 53.5 N-80 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/ft psi/It 1B 9.3 0.484 0.384 2B 9.5 0.494 0.394 3B 10.4 0.541 0.441 4B 0.0 0.000 -0.100 519 0.0 0.000 -0.100 6B 0.0 0.000 -0.100 7B 0.0 0.000 -0.100 8B 0.0 0.000 -0.100 9B 0.0 0.000 -0.100 lOB 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 540 2250 4.2 4234 4980 1.2 4635 7930 1.7 0 0 #DIV/OI. 0 0 #DIV/O! 0 0 #DIV/0.1 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/O! Tension Strength K/Lbs K/Lbs 1C 101.2375 1244 2C 428.904 1661 3C 669.4455 1086 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 TDF 12.;L>9 8.87 1.62 0 #DIV/O! 0 #DIV/0! 0 #DIV/0! 0 #DIV/0! 0 #DIV/O! 0 #DIV/0.1 0 #DIV/0! Collapse Collapse Pr-Bot-Psi Resist. CDF 46O 68O 1.369 1877 2670 1.423 4601 6620 1.439 0 0 #DIV/O! o 0 #DN/O! 0 0 ~D~ 0 0 0 0 ~D~ 0 0 0 0 ~D~ GPT42CMT.XI_S State; Well: Field: State Permit GR. PT. #18 Granite Point 93-78 Engineer: Work Sheet: Date: Vol~.,m¢ 5/27/93 Casing Type Casing Size -Inches Casing Length- Feet Hole Diameter-Inches Cement-Sacks ti1 Cement- Yield111 Cement- Cubic t~: 111 Cement- Cubic fi 111 Cement- Sacks112 Cement-Yield 112 Cement- Cubic ti 112 Cement- Cubic It 1~2 Cement- Sacks113 Cement-Yield II3 Cement-Cubic It 113 Cement- Cubic tt 113 Cement- Cubic tt / Vol Cement- Fill Factor Conducto~ 18.625 1,157.000 22.000 0.000 0.000 0.000 1,123.000 0.000 0.000 0.000 0.000 1,123.000 1.298 Suftace 13.375 5,957.000 17.500 0.000 0.000 0.000 4,492.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 4,492.000 1.086 Liner 0.000 0.000 0.000 0.000 0.000 8.000 0.000 0.000 0.000 0.000 0.000 0.000 ~IV/0I Casing T~e Casing Size -Inches Casing Depth - Feet Hole Di~ete~ -lnct'~ Cement- Sacks111 Cement- Yield111 Cement- Cubic It 111 Cement- Cubic It 111 Cement-Sacks 112 Cement- Yield112 Cement- Cubic tt 112 Cement- Cubic It 112 Cement- Sacks113 Cement- YieldIi3 Cement- Cubic It 113 Cement- Cubic ft ti3 Cement- Cubic It / Vol Cement-Interval ft Top of Cement- Feet Intermediate 111 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIVfO! I~DIV/O! Intermediate 112 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/0! I:I:DIV/0! Production 9.625 12,555.000 12.250 0.00 0.00 0.00 2,807.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2,807.00 8,962.85 3,592.2 Ici easured Depth ** CHECK LIST FOR NEW WELL PERMITS ** iTEM APPROVE DATE Fee ££C LOC '~ ~~ [2 thru 8] (3) Admi n . [/~8~ ~/~,,,.~_/~ ~ 9. [9 thru 13] 10. /~f:'~~, ~-'-,P7 - P~. 11. [10 & 13] 12. : 13. E~ ~hru 22] ~5. [23 thru 28] (6) Other ,f2'~_ ~./~/.z//7.t 9 thru 31] [32] geo 1 ogy' DWJ RPC eng i nee r i rig' M . 'm_, -::.-.Z2" P. AD Jb BEW JDH,._:~ ~,,~ rev 12/92 jo/6.011 Company ///¢ ~ ~_~,r~ / Leases Well YES NO 1. Is permit fee attached ............................................... /~ ..... 2. Is well to be located in a defined pool .............................. /~, 3. Is well located proper distance from property line ................... 4. Is well located 'proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ ~ .... 16. 17. 18. !.9. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... /~ Is a conservation order needed ....................................... Is admin i strat i ve approval needed .................................... Is lease ntrnber appropriate .......................................... ~ Does well have a unique name & ntrnber ................................ z~ Is conductor string provided Will surface casing probect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on ~r-~surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of~bi~c~i!~-BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~O°~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... 29. 30. 31. 32. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ntrnber o¢ contact to supply weekly progress data ...... 33. Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA .~ SHORE Add i t i ona 1 ,,- ' UM MER ~ D fAN: SH REMARKS 0 'l-Z remarks' WELL TYPE' Exp/Dev Inj Red ri I 1 Rev