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Home My WebLink About167-084David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 08/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: GP ST 31-23 Perf (PTD 167-084) FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. 37' (6HW Received By: 08/30/2021 By Abby Bell at 3:28 pm, Aug 25, 2021 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 7/16/2021 To: Department of Natural Resources Resource Evaluation 550 W. 7th Ave. Suite 1100 Anchorage, AK 99501 DATA TRANSMITTAL GP ST 31-23 (PTD 167-084) Caliper Log 05-21-2021 Please include current contact information if different from above. 37' (6HW By Abby Bell at 12:23 pm, Jul 16, 2021 STATE OF ALASKA Reviewed By: 74f?` OIL AND GAS CONSERVATION COMMISSION P.LSuprv�}I�x.� �7 BOPE Test Report for: GRANITE PT ST 31-23 ✓ Comm Contractor/Rig No.: Hilcorp Gestalt , Operator: Hilcorp Alaska, LLC Type Operation: WRKOV Sundry No: Type Test: INIT 321-107 - PTD#: 1670840 . DATE: 6/20/2021 - Inspector Adam Earl - Operator Rep: John Perl/Rich Burnett Rig Rep: Ron Holmes Insp Source Inspector Test Pressures: Inspection No: bopAGE210623082538 Rams: Annular: Valves: MASP: 250/5000 ` 250/3500 " 250/5000 528 Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: P/F ACCUMULATOR SYSTEM: 0 NA - P/F 0_- Visual Alarm Ball Type Time/Pressure P/F Location Gen.: P Trip Tank P - P - System Pressure 2900 - P Housekeeping: P Pit Level Indicators - P -P -- Pressure After Closure _1950_ '_ P__- PTD On Location P Flow Indicator P P - 200 PSI Attained 3 - P - Standing Order Posted P Meth Gas Detector P P_ ` Full Pressure Attained 35 P - Well Sign P - H2S Gas Detector P P Blind Switch Covers: All Stations P - Drl. Rig P MS Misc 0 NA Nitgn. Bottles (avg): 2(&2400 P Hazard Sec. P FP ✓ Inside Reel Valves I- - ACC Misc 0 NA Misc NA Check Valve 0 NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly 0 NA - Lower Kelly 0_- NA" Ball Type 2 - FP . Inside BOP 0 - NA- FSV Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 1 2 3/8"_- -- -P No. Valves 11 - P - Annular Preventer 1 7 1/16" - P Manual Chokes 1 -_ P- #1 Rams 1 ' blind/shear - P Hydraulic Chokes l - P- #2 Rams 1 _ 2.3/8" ps P -" CH Misc 0 NA #3 Rams 1 vbrs P #4 Rams 1 2 3/8"_ps ' #5 Rams 0 _- __P__ NA_ INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves - 1 - 3 1/8" - P - Quantity P/F HCR Valves 2 - 3 1/8" " FP ✓ Inside Reel Valves I- - Kill Line Valves 1 ` 3 1/8" P Check Valve 0 NA BOP Misc 2 ' 2 1/16" - P Number of Failures: 4 Test Results Test Time 9 Remarks: Both kill and choke HCR's had to be serviced, one of the two TIW valves falied and had to be re -built, one the first shell test the Annular flange ea a an had to a tig tened. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,200 feet 11,147 feet true vertical 9,897 feet N/A feet Effective Depth measured 11,094 feet 9,799 feet true vertical 9,813 feet 8,742 feet Perforation depth Measured depth 9,860 - 11,176 feet True Vertical depth 8,794 - 9,878 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 10,199 MD 9,078 TVD 9,799 (MD) 319 (MD) Packers and SSSV (type, measured and true vertical depth)Hyd Iso Pkr 8,742 (TVD) TRSV, NE-SLIM 319 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 11,220psi Daniel E. Marlowe Operations Manager Burst Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,540psi3,090psi 907 777-8376 5,750psi 603 3,665 7,287 9,894 604 3,933 Conductor Surface 8,530psi 3,090psi 18" 13-3/8" 8,062 Size 204 Production Casing Structural Liner 3,329 Length Intermediate N/A Junk 5. Permit to Drill Number: 0 Granite Point Field / Middle Kenai Oil PoolN/A measured 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 300 N/A Oil-Bbl 173 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-107 0 Authorized Signature with date: Authorized Name: 0 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 167-084 50-733-20072-00-00 Plugs ADL0018761 Granite Pt St 31-23 Other: G/L Completion / Prep for CTD lateral measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 40 Representative Daily Average Production or Injection Data 8234 Casing Pressure 7" 8,062 MD 604 3,933 11,196 TVD measured true vertical Packer 9-5/8" Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:55 am, Jun 09, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.06.08 15:35:05 -08'00' Dan Marlowe (1267) DSR-6/9/21 RBDMS HEW 6/9/2021 BJM 11/12/24 SFD 6/18/2021 _____________________________________________________________________________________ Revised By: JLL 06/07/21 SCHEMATIC Granite Point Platform Well No: GP 31-23 Completed: 04/29/21 ADL: 18761 PTD: 167-084 API: 50-733-20072-00 CASING DETAIL Size Wt Grade Conn ID Top Bottom 18" Surf. 604’ 13-3/8" 61 J-55 DV Tool 12.515” Surf. 2,230’ 13-3/8” 61 J-55 Buttress 12.515” 2,230’ 3,933’ 9-5/8" 40 N-80 Buttress 8.835” Surf. 295’ 40 N-80 LTC 8.835” 295’ 3,801’ 43.5 N-80 LTC 8.755 3,801’ 5,173’ 43.5 S-95 STC 8.755 5,173’ 8,062’ 7" 29 P-110 X-line 6.184” 7,867’ 11,196’ TUBING DETAIL 4-1/2" 12.6 L-80 IBT 3.833 Surf. 9,783’ 4-1/2" 12.6 L-80 IBT 3.833 9,799’ 10,199’ Jewelry Detail #Depth (MD) Depth (TVD)ID OD Item 1 319’ 319’ 3.813 5.960 TRSV, NE-SLIM (Halliburton) 2 2,604’ 2,509’ 3.958” 7.000” GLV #1 – IPO-15 4,784’ 4,416’ 3.958” 7.000” GLV #2 – IPO-15 6,364’ 5,800’ 3.958” 7.000” GLV #3 – IPO-15 7,384’ 6,687’ 3.958” 7.000” GLV #4 – IPO-15 8,203’ 7,408’ 3.958” 6.000” GLV #5 – IPOC-1 8,926’ 8,006’ 3.958” 6.000” GLV #6 – IPO-1 9,644’ 8,612’ 3.958” 6.000” GLV - Orifice 3 9,783’ 8,729’ 4.000” 6.000” 15' 5.000 PBR w/ 4 1/2 LTC Pin 9,799’8,742’4.000”5.870” 7 x 4 1/2" 23-32# Hydraulic Isolation Packer 4 9,873’ 8,805’ 3.810” 5.820” X Nipple 5 9,886’ 8,816’ 3.810” 5.500” Sliding Sleeve (Open Up) 6 10,199’ 9,078’ 3.960” 5.170” WLEG Perforations Top(MD) Btm(MD) Top(TVD) Btm(TVD) Detail 9,860’ 9,861’ 8,794’ 8,795’ Squeezed 9,866’ 9,867 ‘ 8,799’ 8,800’ Water Shut Off 9,911’ 9,921’ 8,837’ 8,846’ Open 9,941’ 9,971’ 8,863’ 8,888’ Open 10,100’ 10,101’ 8,996’ 8,997’ Squeezed 10,254’ 10,260’ 9,124’ 9,129’ Open 10,260’ 10,275’ 9,129’ 9,142’ Open 10,275’ 10,280’ 9,142’ 9,146’ Open 10,280’ 10,445’ 9,146’ 9,281’ Open 10,561’ 10,578’ 9,376’ 9,390’ Open 10,654’ 10,681’ 9,452’ 9,474’ Open 10,730’ 10,731’ 9,515’ 9,515’ Squeezed 10,895’ 10,897’ 9,650’ 9,651’ Open 10,897’ 10,987’ 9,651’ 9,725’ Open 11,014’ 11,016’ 9,747’ 9,749’ Open 11,016’ 11,176’ 9,749’ 9,878’ Open KB: 105’ MWL PBTD = 11,147’ TD = 11,200’ 5 18” 2 3 4 9-5/8” 6 1 13-3/8” 7” CBL 4/25/21 EST TOC 6,740’ Clean out to 11,094’ 04/25/21 TOL 7,867’ Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 Mobilize jacks for skidding rig. Work on hardware for clamps. Prepare decks for next boat load. Assist welder on miscellaneous rig projects. Offload boat with rig components: tool conex's, offshore baskets, etc. Gave 48 notice of BOPE test to AOGCC. Pull grating from around well head. Apply gasket remover to graylok clamp bolts. Remainder of crews arrived from Grayling. Repair pancake grippers for skidding rig. Skid rig over well center GP 31-23. Disconnect and stow power packs. Skid racking base beam into place. Hook up hoses on mud pump to pits. Raise mast, spool up tugger and man rider lines, string up blocks, fill pits with diesel, set choke house and accumulator into place. Slip 2 full layers of drill line onto drawworks drum. Set stairs on front of carrier, secure lines, lower mast and safe out rig. Install pump-in sub on tree and R/U 2" line from pump to tree for killing well. Hold PJSM on well kill operation with all participants. Flood suction lines and circulate diesel to pits to verify pump is fluid packed. Line up on hole and start to pump when drive chain for rod wash and gear lube broke. Put heat on mud pump and rod wash while replacing drive chain. Run mud pump to verify proper alignment and tension on chain. Mobilize partial crew from Grayling Platform to Granite Point Platform for rig move. Hold orientation. Clean and organize west drill deck of miscellaneous production equipment prior to setting up rig 404. Spot racking beam. Spot double base beam. Spot single base beam. Bolt up yellow support braces. Center carrier support brace on single base beam. Spot carrier. Set drawworks and bolt to carrier. Install A-leg on carrier. Set landings on ODS of carrier. Level carrier for A-leg. Bolt up drive line to drawworks. Clear deck for mud pump and pits. Unload pits and pumps from boat and spot. Unload tool conex. Unload stairs, racking board, hydraulic power pack and drilling line spool. Pick derrick off boat and pin to carrier. Untie and lay out derrick lines. Work boat: offload miscellaneous equipment. Install DS landings on side of carrier. Hook up temporary power to tool conex. Remove crown side transport beam from derrick. Install drillers console on side of derrick. Spot drillers doghouse. 04/06/21 - Tuesday 04/05/21 - Monday Gave 48 notice of BOPE test to AOGCC Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 04/08/21 - Thursday Monitor well: long string on vacuum, short string and IA on vacuum. Waiting on XO's for e-line. Housekeeping and maintenance on rig. Rig up Pollard e-line. RIH with AD2 lower stop and set at 270' on LS. RIH and set pack-off and upper slips. Shoot fluid level and found to be at +-3800'. Attempt to fill LS with FIW for test. Plug not holding. Pollard move plug uphole to 200' and set. Fill with FIW and test at 3000 psi on chart for 5 minutes (good test). Pollard rig up on short string and set plug at 215'. Fill with FIW and attempt to test w/ 3000 psi (would not hold pressure). RIH w/ slick line to pull and redress plug. RIH and set plug @ 205'. Fill with FIW and attempt to test w/ 3000 psi (Pressure bleeding off). RIH w/ slick line to pull and redress plug. RIH and set plug @ 173'. Fill with FIW and attempt to test w/ 3000 psi (Would not hold pressure). RIH w/ slick line to pull and redress plug. RIH and set plug 15' below hanger. Fill with FIW and test at 3000 psi on chart for 5 minutes (good test). Rig down wireline, tools and lubricator. Nipple down and remove tree. Prep well head - Clean and dress threads in hanger. Clean hub flanges and clamps. Lower 13 5/8" riser through top deck and N/U to wellhead. Fluid lost to hole today: 0 Total fluids lost to hole: 255 bbl Diesel. 04/07/21 - Wednesday Pump 140 bbls diesel down short string at 4 BPM/0 psi. Monitor tree. Tubing on vacuum and annulus on vacuum. Check every 30 minutes. No change. Mobilize e-line crew to platform. Shut in master and swab valves on short string. Continue with miscellaneous rig up projects and assisting welder as needed with stairs. Remove Bowen circulating tee off of short string and install tree cap with gauge and sample port. Rig up circulating hoses from annulus to production header. Boat arrived with Pollard e-line unit without tool unit. Mobilize same. Check accumulator bottles. Offload work boat. Rig up Pollard e-line. M/U tools and lubricator on long string. RIH w/ guns to packer @ 7801'. POOH to 7755'. Perforate 2 7/8" tubing F/7755' to 7758', 10 shots, 1/4" diameter) No noticeable change on either tubing or annulus pressures. POOH and R/D e-line. Pump diesel down long string lined up to take returns out annulus and to production header. Pumped 115 bbl @ 4 bpm w/ 0 psi. Shut down pumping w/ well on a vac w/ no returns. Monitor well while filling pits w/ diesel. Due to crane issues we are unable to switch out e-line unit for slick line unit in order to set slick line plugs in the short and long strings. Wait on crossover from the beach to run slick line tools on e-line. Choppers on hold due to weather. Blow down and rig down circulating lines to well head from pump. Work on cleaning up Grayloc clamp bolts on wellhead. Housekeeping and maintenance. Pump diesel down long string lined up to take returns out annulus and to production header Pump 140 bbls diesel down short string at 4 BPM/0 psi. Monitor tree. Tubing on vacuum and annulus on vacuum Pumped 115 bbl @ 4 bpm w/ 0 psi. Shut down pumping w/ well on a vac w/ no returns Monitor well: long string on vacuum, short string and IA on vacuum Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 Lay down test joint. Rig up and pump out stack. Prepare to nipple down stack from tubing spool. Pull center plate. Nipple down circulating head. Pull drip pan. Mobilize endless slings from warehouse rated for stack weight. Lift stack and change out API ring gasket (used coated gasket) and install graylok clamp. Make up 2 7/8" test joint. Fluid pack stack. Attempt to test against annular preventer with no joy. Rapid bleed off. Double block choke and kill lines and tested against pipe rams with same result. Change out test joints to 3 1/2". Attempted to test at 3000 psi with same result, rapid bleed off with no observed leaks on surface. Contacted Jim Regg (AOGCC) and received permission to perform rolling BOP test at 15:30 hrs. Change out test joints back to 2 7/8" with blanked and ported sub with bottom port plugged off to eliminate possibility of tubing plug in long string leaking. Perform Rolling BOPE pressure test to AOGCC and Hilcorp standards. Test annular to 250 psi low and 2500 psi high, rams and valves tested to 250 psi low and 3000 psi high. Test witnessed by AOGCC inspector Austin Mcleod. Test pump failure on last high pressure test w/ 3 1/2" test joint. Inspected the fluid end and found issues. Attempted to test and again had issues @ 2200 psi. Removed belt guard and back cover plate. Rolled pump by hand observed play in center connecting rod on crankshaft. Got with production and rigged up their pressure pump. Perform last pressure tst on 3 1/2" test joint. Had 2 F/P during test. 1: Choke line flange at choke house leaked on annular test and had to be tightened for test. 2: Test pump failure while testing pipe rams on 3 1/2" test jt. R/D test equipment and blow down lines. R/U Pollard slick line. Make up lubricator to long string and test w/ 1500 psi. RIH to retrieve plug. Fluid lost to hole today: 0. Total fluids lost to hole: 255 bbl Diesel 04/09/21 - Friday Nipple up mud cross and double gate. Nipple up choke and kill lines and torque all. Remove stripper head from annular preventer. Install shorter studs. Set drip pan on top of annular to get marks for welder. Remove drip pan and circulating head. Nipple up annular preventer. Make up accumulator lines. Torque all bolts to specs. Secure stack. Set drip pan on annular preventer. Secure drip pan to annular. Prepare derrick to be raised. Repair air hose on hydraulic switch. Raise and scope up derrick. Secure guy lines. Set doghouse in place. Unable to rig up floor due to drip pan clearance. Lay down drip pan for modifications. Install drip pan, rig floor and stairs from carrier to floor. Run and connect gas buster, kill and mud line hoses to standpipe manifold. N/U circulating head. Close in cellar area and run heater hose to warm up BOPE. Charge and function test accumulator. Hang beaver slide. Continue enclosing cellar area. Rig up power tongs and hydraulic unit. Make up 2 7/8" test joint assembly. Make up test joint into 2 7/8" long string on tubing hanger. Thaw out production FIW line on top deck and fill BOP stack for testing. R/U to perform shell test on BOPE. Pressure up to 2500 psi on annular, kill and choke line valves. Pressure bled off rapidly upon shutting down test pump. No leaks observed on equipment or through annular. Top off fluid in BOPE and line up to attempt test against pipe rams. Fluid lost to hole today: 0. Total fluids lost to hole: 255 bbl Diesel 04/10/21 - Saturday Contacted Jim Regg (AOGCC) and received permission to perform rolling BOP test at 15:30 hrs. Test annular to 250 psi low and 2500 psi high, rams and valves tested to 250 psi low and 3000 psi high. Test witnessed by AOGCC inspector Austin Mcleod. Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 04/11/21 - Sunday Pollard RIH with prong and retrieve plug at 200' in long string. Rig up on short string with landing joint and lubricator. Pull plug in short string at 15' below tubing hanger. Rig down Pollard slick line. Pump 5 bbls down well. Well on vacuum. Reinstall drip pan under rig floor. Button up cellar wind barrier. Install stripper head. Rig up floor windwalls. Make up landing joint. Open annulus and bleed off same to production header. Back out LDS. Pull hanger off seat @ 78k. Work pipe and pull free of packer seals @ 120k. Pull hanger to rig floor. Pumping 5 bbl diesel down back side every 20 min. Break off landing jt and L/D same. Remove safety valve from landing jt and make up x/o on it for 3 1/2 butt threads. Pull and l/d top jt 3 1/2" short string w/ hanger. Pumping 5 bbl diesel down back side every 20 min. POOH laying down 3 1/2" short string completion to 6407'. PUW 65k, SOW 35k. Pumping 5 bbl diesel down back side every 20 min. Cont. POOH laying down 3 1/2" short string completion f/ 6407' to 4061'. PUW 50k, SOW 30k. Pumping 5 bbl diesel down back side every 20 min. FluFluid lost to hole today: 250 bbl. Total fluids lost to hole: 505 bbl Diesel 04/12/21 - Monday Continue POOH laying down 3 1/2" short string completion f/ 4061' to 1165'. Pumping 5 bbl diesel down back side every 20 min. Continue POOH laying down 3 1/2" short string completion f/ 1165' to end'. Change out handling equipment. Make up landing joint with spear. Spear into tubing hanger log string. Pull hanger off seat at 78K. Work up hole 6.5 pulling up to 130K several times with no further movement. Discuss options with engineers. Decreased hole fill to 5 bbls every hour. Mobilizing e-line crew to cut pipe above packer @ 7801'. Release from tubing and lay down spear assembly. Prep floor for e-line. M/U 2 7/8 landing jt. and make up into long string tubing hanger. Stage e-line unit. R/U e- line unit. Hang sheaves and line from blocks. M/U tool string. Issues with computer/warrior panel in unit. Trouble shoot computer/Warrior panel issues with e-line unit. Perform housekeeping around the rig and center bay. Mobilize replacement computer and Warrior panel from Pollard shop to rig. Install new computer and boot up system. M/U and arm RCT. RIH to 7850'. Set depth to packer @ 7801'. Pull up hole and cut pipe @ 7773'. Log back down and verify cut (Good). POOH w/ e-line. Fluid lost to hole today: 329 bbl. Total fluids lost to hole: 834 bbl Diesel Pumping 5 bbl diesel down back side every 20 min. Open annulus and bleed off same to production header. Continue POOH laying down 3 1/2" short string completion f/ 1165' to end Pull up hole and cut pipe @ 7773 Pump 5 bbls down well. Well on vacuum Spear into tubing hanger log string POOH laying down 3 1/2" short string completion Pumping 5 bbl diesel down back side every 20 min. Pumping 5 bbl diesel down back side every 20 min Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 04/13/21 - Tuesday Make up landing joint with spear. Spear into long string. Work pull up to 130K. String came free with +-90K string weight. Pull tubing hanger to rig floor and lay down same. Pull 10 bbls diesel into well. Cont. POOH l/d 4 joints, started pulling jt #5 pulled heavy, attempt to go down hole with no joy. P/U single for more working room, cont. working pipe with no movement. Consult with engineer, plan forward cont. working pipe, until e-line is back on board, rig them up to make cut. Cont. work pipe while waiting on arrival of e-line crew.L/d single & R/U e-line. M/U tool string with CCL & RCT. RIH t/~7730' WLM, Logged uphole found packer & kick from previous cut attempt, logged into position placing cutter @ 7675' WLM, (4' below last attempted cut) fire cutter, had good indication of cut, POOH & r/d e-line. POOH l/d remaining 2 7/8" concentric tbg. f/ 7676' to 7530'. C/O handling tools t/2 7/8". Cont. POOH l/d 2 7/8" long string completion tubing f/ 7530' to 3592'. PUW 28k , SOW 24k. Cont. POOH l/d 2 7/8" long string completion tubing f/ 3592'. L/D cut jt and clear floor. Fluid lost to hole today: 142 bbl. Total fluid lost to hole: 976 bbl 04/14/21 - Wednesday Finish clear floor, c/o handling tools. Service rig. M/U 4 1/2" & 2 7/8" test joints, work on retrieving tool for hanger Parent bowl. Attempt to retrieve parent bowl, unsuccessful getting below to lift, modify tool retry getting ahold of parent bowl, unable to lift with tugger. R/d tool. Prepped test plug & r/u to test BOPE, filled stack & surface eq. w/test water, shell tested good. Test BOPE as per Hilcorp & AOGCC requirements, this test follows the rolling test performed on 4-10/4-11 as requested by AOGCC Jim Regg. Tested Annular w/ 250 psi low / 2500 psi high, all other BOPE compoents tested to 250 psi low / 3000 psi high. All tests held for 5 min ea. and charted. Tested with both 2 7/8" and 4 1/2" test joints. R/D test equipment and blow down surface lines. Pulled seals on test plug and dropped it 6' to top of parent bowl several times in an attempt to loosen same. C/O handling equipment to 3 1/2" and m/u YellowJacket tool on a joint of 3 1/2" PH-6 pipe. RIH to parent bowl and orient tool to catch on bottom of bowl in the center. Pull on bowl starting at 5k and working up in 5 k incrments to 30k of pull. NO JOY. Discuss options going forward with engineer in town. L/D pulling assembly and p/u 4 1/2" test joint w/ test plug. Drop test joint onto the parent bowl trying to loosen it in the wellhead. Alternate between hammering on bowl with test jt. and soaking it with penetrating oil. Wrap wellhead with plastic and run heater ducting to same trying to use heat to loosen bowl. Pick pulling tool assembly back up and attempt to pull parent bowl working up in 5 k increments to 30k overpull. NO JOY. Leave 30k tension on tool while heating up wellhead. Fluid lost to hole today: 89 bbl. Total fluid lost to hole: 1065 bbl. POOH l/d 2 7/8" long string completion tubing f/ 3592'. L/D cut jt Test BOPE as per Hilcorp & AOGCC requirements, this test follows the rolling test performed on 4-10/4-11 as requested by AOGCC Jim Regg. Prepped test plug & r/u to test BOPE Pull 10 bbls diesel into well placing cutter @ 7675' WLM, (4' below last attempted cut) fire cutter, Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 Cont. hold 34k on parent bowl, cont. heating wellhead while waiting on eq. for next stage. Unload boat & stage eq. cont. holding 34k on bowl, decision made to run vibrating type tool next, mobbing tools out. L/D pulling tool M/U Tempress vibrating tool assembly. RIH engage tool assy. to parent hanger bowl, pump @ varying rates f/ 2-3.3 BPM, 500-700 psi, tool was working but not getting good vibration appeared we did not have enough back pressure, ordered up a sub for more restriction. Change out McCoy power tongs for Gills on rig floor. Work on Hawk Jaw. Assist crane crew with off loading boat and staging equipment. Make up ported blanking sub on Temptress vibrating assembly. Bush port down from 1/2" to 1/4" as requested by Quadco rep. Engage tool assembly in parent hanger bowl. Pump @ 2.5 bpm w/2750 psi and blew pop-off on pump. Reset pop-off and resize port to 3/8". Pump @ 3.4 bpm w/1692 psi. Pull Temptress assembly and change out hanger for Yellowjacket pulling tool. Engage the parent bowl with pulling tool, pull 32k on bowl while pumping @ 3.7 bpm w/ 1940 psi. NO JOY, Break and l/d Temptress assembly, clean and clear rig floor. Blow down surface lines. M/U 2' spacer spool to top of stripper.PJSM. P/U casing jack and bring to rig floor. Set jack on spacer spool and bolt to top of spacer spool. M/U hydraulic lines and control panel on rig floor. M/U Yellowjacket pulling tool and x/o's to 10' pup jt. of 4 1/2 " CDS -40 drill pipe and 1 full jt. of 4 1/2 " CDS -40 drill pipe.Fluid lost to hole today: 121 bbl. Total fluid lost to hole: 1186 bbl. 04/16/21 - Friday Finish rig up to pull on parent bowl, warm up jack, stage pulling weight up t/154k w/ no joy. R/D jack. L/D fishing assy, P/U wear bushing & running tool, RIH & land same. Clear floor & prep for milling operations, clean & cut holes in drip pan for static lines, spot swivel, M/U milling assy, BHA, remove 2' spool from stripping head. RIH w/ milling assy, turn assembly with Gills look to est pattern & observe if bowl would turn, appeared to be level. R/U power swivel and M/U to milling assy. Mill on parent bowl w/ 1-2k wt. 60-80 rpm, 500-750 ft/lb tq. POOH w/ milling assy. and inspect mill. Observed wear on outside edges and begining to see wear accross all blades. Mill on parent bowl w/ 1-2k wt. 80-100 rpm, 750-1000 ft/lb tq. Stopped operation due to welhead hand observing loose bolt on hub clamp from wellhead to riser.Tighten bolt on hub clamp and check all bolts on riser and BOPE. Resume milling on parent bowl w/ 1-2k wt. 80-100 rpm, 750-1000 ft/lb tq. Lost all torque and tool dropped 1 1/2 - 2". Setting on something solid. P/U and measure 6" from starting point of milling. POOH w/ milling assembly. Pick up wear bushing running tool, back out LDS and pull wear bushing. Can see center cut on parent bowl and what appears to be center cut out of bowl setting on top of the 9 5/8" pickoff. Call to mobilize a magnet to retrieve center bowl section. L/D wear bushing and puller assembly. R/D power swivel and L/D milling assembly. Clear floor and blow down surface lines. Housekeeping /rig maintenance while waiting on arrival of magnet. Fluid lost to hole today: 6 bbl. Total fluid lost to hole: 1192 bbl. 04/17/21 - Saturday 04/15/21 - Thursday psi and blew pop-off on pump Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 04/18/21 - Sunday Cont. POOH standing back 3 1/2" PH-6 wk string, having to work through most casing collars w/packer f/7585'-5661'. Cont. POOH standing back 3 1/2" PH-6 wk string, t/3117' at packer, 6332' to projected end of fish. String came wet. Called out for e-line to punch holes & r/u mud bucket but it was not 100% effective. Spot e-line unit, rig up vac unit, clean rig floor & drip pan, layout & strap more work string for next run, complete derrick inspection, serrvice rig. R/U e- line, m/u 1 9/16" tubing punch w/8- .1/4" shots & ccl. RIH t/4895' tag. P/u placing bottom shot @ 4890', fire punch, good indication fired, had weight gain & tubing went on vac. POOH r/d e-line. Cont. POOH standing back 3 1/2" PH-6 wk string to BHA. Stand back 4 3/4" DC. L/D Accelerator Jar, Bumper Sub and Oil Jar. Cut through 2 7/8" X/O on bottom of packer with hacksaw. L/D Overshot w/ 1 jt. 2 7/8" tbg. and packer. Clear floor, change out handling equipment and R/U to L/D 2 7/8" tbg. Single out of hole L/D 2 7/8" tbg. to CT Gas Lift String @ "N" nipple. Heavy scale (1/4" - 3/8" thick) on last 20 jt. of 2 7/8" tbg, had to clean pipe in order to set slips and get elevators on. C/O handling equipment, R/U safety jt and clear floor. Single out of the hole L/D 1 1/4" Gas Lift Assy. Fluid lost to hole today: 87 bbl. Total fluid lost to hole; 1279 bbl. P/U "J" hook T-bar. IH set down on parent bowl shoulder take measurement, set down on center milled section, results show parent bowl still intact, engage t-bar hook, attempt to pull with tugger, no joy. M/U running tool set wear bushing on parent bowl for stability, POOH, c/o to yellowjacket retrieval tool. RIH engage parent bowl, pickup had some movement approx. 1.5', started pulling tight, set back down disengaged & pushed down on it. R/U tongs re-engaged, started rotating slowly rotated up & out of wellhead, cont. pulling made it to blind ram cavity but unable to pass, top edge of wear bushing tagging on top, worked with no joy. Ran in L/D pins, lowered & set parent bowl on pins, POOH. C/O to wear bushing running tool. RIH retrieved wear bushing. Housekeeping & rig maint while welder is fabricating retrieval tool. M/U retrival tool, RIH engage & pull out of hole retrieving Parent hanger bowl. Break down assembly. Clear floor & change out handling eq. to p/u Fishing BHA. P/U Fishing BHA (8-1/8 Cut Lip Guide, 8-1/8 Overshot Bowl, Top Sub, X/O, Bumper Sub, Oil Jar, 6 ea. 4-3/4 DC, 4-3/4 Accelerator Jar, X/O = 230.63'). Change out handling equipment to p/u 3 1/2 work string. Single in the hole w/ BHA on 3 1/2" PH-6 , 12.95#, P-110 workstring. Tag top of fish @ 7624' PUW= 100k , SOW= 78k. Work over fish and begin jarring operations w/ 130k pull working up to 165k. Fish came loose after 34 licks on jars. POOH standing pipe back in derrick f/ 7624' to 7056'. Pulling slowly and work fish through 9 5/8 casing couplings. PUW 123-160k, SOW 80k Heavy scale (1/4" - 3/8" thick) on last 20 jt. of 2 7/8" tbg, had to clean pipe in order to set slips and get elevators on String came wet Change out handling equipment to p/u 3 1/2 work string. Tag top of fish @ 7624 m/u 1 9/16" tubing punch w/8- .1/4" shots & ccl. RIH t/4895' tag. P/u placing bottom shot @ 4890', fire punch Cut through 2 7/8" X/O on bottom of packer with hacksaw Single out of the hole L/D 1 1/4" Gas Lift Assy r/u mud bucket but it was not 100% effective Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 Cont. POOH w/e-line, OOH all shots fired on punch. L/D e-line r/u t/pull, c/o handling eq. Pull one stand t/10065', pipe not draining, up wt 138k. House keeping & rig maintenance, service rig, while mobbing out larger hole punch. Load guns & r/u e-line, RIH w/3/8 hole punch, CCL, correlate t/middle of last joint above BHA 9812' WLM, fired hole punch, tubing went on vac, POOH r/d e-line. POOH standing back work string and drill collars (wet). Lay down BHA #2: casing scraper and boots baskets. Make up test packer assembly. RIH with test packer assembly to 2927'. RIH with test packer assembly from 2927' to +-9840'. Did not see TOL at 7867'. Set packer at 9840'. Mix diesel baracarb/LCM pill. Fluid lost to hole today: 72 bbl. Total fluids lost to hole: 1351 bbl. 04/21/2021 - Wednesday Cont. Build 50 bbl, Diesel Cal, carb LCM pill. Pump pill, 43 bbls, chase w/28 bbls diesel. Fill annulus w/ 191 bbls diesel. PT casing surface t/9840' 1750 psi 30 min good. C/O handling eq. blow down lines, pump 19 bbls down tubing catch pressure, pressure up t/1100psi, bleed down in 4 min. POOH f/9840', standing back 3 1/2" PH-6 wk string. Stand back drill collars and lay down packer. Make up 3 1/2" test joint. Fill stack and shell test at 2500 psi (good). Test BOPE on 3 1/2" and 4 1/2" test joints at 250 L/3000 H. Troubleshooting blind ram test failure. Fluid lost to hole today: 219 bbl +43 bbls diesel baracarb LCM pill. Total fluids lost to hole: 1570 bbl. 04/19/21 - Monday Cont. POOH l/d CT gas lift stiring. L/D safety joint, Clean & clear floor, c/o handling eq. P/U BHA #5 - 6" roller cone bit, 7" casing scraper, bit sub, 3- boot baskets, bumper sub, oil jar, 6 ea 4 3/4 DC, xo = 233.29. C/O handling eq. & tih w/3 1/2" PH-6 wk string from derrick t/7678', up wt 106, dn wt 70. Prep to p/u 3 1/2" wk string, wait while loading boat. Single in the hole w/ 3 1/2" PH-6 wk string f/7678' to 9384' up wt 124k, dn wt 80k, Cont. to single in f/ 9384 to 9900', taking wt. Working through tight spot f/ 9849' to 9910'. Started w/ 60k dn and 150k up. Worked pipe free going down w/ 80k to 10,221', not able to pull free up - max pull 160k. R/U and pump down pipe. Pumped 20 bbl to fill pipe and pressured up to 1390 psi. Pipe plugged off. Bled off pressure. Worked pipe and jar up to 150 k w/ no progress working up. R/U power swivel. Notified town engineer of situation and plan forward. Mobilize e-line crew to pop holes in work string. Back ream out of hole f/ 10,221' to 10,190'. No pump, 80 rpm w/ 7000 ft/lb tq. 125k up. Pipe free @ 10,200', No pump, 80 rpm w/ 4500 ft/lb. tq 125k up. Pull up to 10,124' with no rotation. 138k up, 100k dn. R/D power swivel. Clear floor and move power swivel power pack. Spot and rig up e-line unit. M/U tools and RIH to top of collars. Pull up to 9867' and shoot guns- No indication of guns firing at surface. POOH w/ e-line. Fluid lost to hole today: 0 bbl. Total fluids lost to hole: 1279 bbl. 04/20/21 - Tuesday POOH l/d CT gas lift stiring Test BOPE on 3 1/2" and 4 1/2" test joints at 250 L/3000 H. all shots fired on punch Pull up to 9867' and shoot guns- Set packer at 9840'. pipe not draining PT casing surface t/9840' 1750 psi 30 min good. tubing went on vac RIH w/3/8 hole punch Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 04/23/2021 - Friday Rig up power swivel, install TIW valve, run circulating line for rev. circulation, re-spot power swivel power pack for controls to reach driller station, install stripping head. Wash & ream f/ 10,095' t/10,164' circulating long, @ 1.75bpm, 100 psi, up wt 138, dn wt 80, rot wt 110, tq-3500-4700. Attempt to reverse circulate had leak on stripping head, closed annular, pulled & reset stripping head. Reverse circulated 1 1/2 tubing volume @ 3.3 BPM, 560 psi. Cont. Wash & ream f/10164' t/10,780', wash & ream 60-90' circulating long, @ 1.75bpm, 85 psi, up wt 138, dn wt 80, rot wt 110, tq-3500- 4700 reverse circ clean between cycles 1 1/2 tubing volume, @ 3.25bpm , 560-600 psi, up wt 138k, dn wt 85k, rot wt 110k, tq-3500-4700, getting scale returns while reversing. Finish reverse circulating cycle. Connection came wet while breaking out. Screw back in and reverse circulate an additional 35 bbls. On breaking out connection still wet. Attempt to retorque PH6 connection would not make up completely and fluid still coming out of connection. Torque up several times with no joy. Reverse circulate 177 bbls to balance u-tube. Consult with engineer about options to proceed and maintain well control. Mobilize spear. Break connection above TIW valve and check for flow (static). Rig down power swivel. Pick up and make up spear. Check well (static). Break out TIW valve and saver sub cross over. Engage spear. Pull and lay down damaged joint. Fluid lost to hole today: 0 bbls 43 bbls diesel baracarb LCM pill. Total fluids lost to hole: 1594 bbl. 04/22/2021 - Thursday Cont. Troubleshoot, finding blind rams leaking, install test joint to finish remaining valve tests good. Run in L/D pins on hanger, blow down stack, pull blind ram blocks & inspect, flip blocks, re-install, fill stack w/test fluid re-test blinds good. Blow down surface eq. pull test plug (hanger). Slip & cut drill line, 45'. Service rig, prep floor for P/U BHA. P/U cleanout BHA- 6" roller cone bit, 3 each boot baskets, bit sub, bumper sub, oil jar, burst disk (set 3k) 6ea, 4 3/4" drill collars, xo sub = 232.29. RIH with clean out assembly to +-9900'. Begin mixing diesel baracarb LCM pill. Finish mixing LCM pill. Pump 40 bbls LCM pill. Caught pressure at 10 bbls pumped with 3 BPM/240 psi. Returns to surface. Shut down and shut in. Rig up 3" diaphragm pump to CMV #10 to take returns to pits. Found that 4 trash pumps were inoperable. Repair same. Pump +-25 bbls diesel out of mix pit to ISO. Drain leaking vac unit into pits. Reverse circulate 35 bbls LCM pill back into mixing pit at 3 BPM/380 psi. Caught pressure at 14 bbls pumped. Pump out stack. Rig down floor valve. String on vacuum. Annulus static with fluid at ram level. RIH with 3 stands out of derrick to 10,095'. Install stripper head. Rig up power swivel. Fluid lost to hole today: 24 bbl 43 bbls diesel baracarb LCM pill. Total fluids lost to hole: 1594 bbl. Consult with engineer about options to proceed and maintain well control. Attempt to retorque PH6 connection would not make up completely and fluid still coming out of connection Break connection above TIW valve and check for flow (static finding blind rams leaking flip blocks, re-install, fill stack w/test fluid re-test blinds good. getting scale returns while reversing On breaking out connection still wet Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 POOH standing back PH6 work string to BHA. L/D BHA. Clean & clear floor, m/t boot baskets, service tongs, spot e-line unit. R/U e-line P/U tools, run 7" CBL log from 9900' up/t/liner top @ 7867'. Rig hands, clean out mix tank, service mud pump fluid end, housekeeping. R/U e-line P/U tools, run 9 5/8" CBL log from liner top @ 7867' to above TOC at 6340'. Rig down e-line. ETOC 6740'. Pick up packer assembly and tailpipe. RIH with packer assembly with stands out of derrick to 7680' (1 minute per stand). Fluid lost to hole today: 26 bbls 43 bbls diesel baracarb LCM pill. Total fluids lost to hole: 1650 bbl. 04/26/2021 - Monday RIH with packer assembly with stands out of derrick from 7680' to 10,200' (1 minute per stand). up wt 118k, dn wt 83k,Line up fill hole, pumped 34 bbls down tubing before catching pressure, shut down. R/U & dropped ball & rod, pressured up t/3800 psi setting packer @ 9804', & tubing tail @ 10,200', pull 20k over & set 20k down verify packer set, good. Fill annulus, r/u & test packer/casing t/1500psi f/30 min good. R/D circulating line, set string in neutral, rotate 14 turns to the right to release packer running tool, P/U 112k free, POOH t/10,080' cleaning & l/d 3 1/2" wk string. String started U-tubing, circulated a tubing volume, with no success, circulated 2 more tubing volumes checked well balanced, OD tugger locked up. Troubleshoot same, ordered out a replacement. Removed bad tugger. Continue POOH f/10,080' to 5025'. Cleaning & l/d 3 1/2" work string, (sucking wiper ball through each joint on vac stand). Replaced bad tugger. POOH from 5025' to +-1200'. Cleaning & l/d 3 1/2" work string, (sucking wiper ball through each joint on vacuum stand). Fluid lost to hole today: 95 bbls 43 bbls diesel baracarb LCM pill. Total fluids lost to hole: 1745 bbl. 04/24/2021 - Saturday Rig up power swivel. Cont. Wash & ream f/10,780', t/10939 wash & ream 60-90' circulating long, @ 1.75bpm, 180 psi, up wt 141k dn wt 85, rot wt 110, tq-3500-4700 reverse circ clean between cycles 1 1/2 tubing volume, @ 3.25bpm , 560- 600 psi. Make connection, attempt to circulate but was packed off wk pipe get rotation but unable to circ. L/D joint, wk free with little effort, pick up t/ 10 920' regain circulation, circ. 90 bbls. Cont. Wash & ream f/10939' t/ 11094' wash & ream 31' circulating long, @ 2bpm, 220 psi, up wt 141k dn wt 90, rot wt 112, tq-3500-4700 reverse circ clean 1 1/2" tubing volume after washing down @ 3.25bpm, 600 psi, getting scale returns while reversing. Circulate clean @ 3.25 BPM, 5 80-600 psi. Lay down single joint. Rig down power swivel. Allow well to u-tube back to pits while rigging down. Rig up vac unit and handling equipment. POOH laying down 34 joints of PH6 work string to 10,040'. POOH standing back work string to +-5620'. Fluid lost to hole today: 30 bbls 43 bbls diesel baracarb LCM pill. Total fluids lost to hole: 1624 bbl. 04/25/2021 - Sunday String started U-tubing, run 7" CBL log from 9900' up/t/liner top @ 7867' getting scale returns while reversing test packer/casing t/1500psi f/30 min good run 9 5/8" CBL log from liner top @ 7867' to above TOC at 6340' Allow well to u-tube back to pits while rigging down setting packer @ 9804 Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 04/28/2021 - Wednesday Continue to RIH w/ 4 1/2 12.6# L-80 IBT completion from 8950' to 9782'. PUW 115k, SOW 73k. Saw seals enter PBR and locater sub taking wt. L/D 2 jt.s tbg. M/U hanger and thread control line through same. M/U landing jt. and land hanger in wellhead. Run in Lock Down Pins. Rig up and pressure test tbg. w/ 3600 psi f/ 30 min. Charted (Good Test, lost 100 psi over 30 min). Tbg full of diesel. Used test pump and water to pressure up. Rig up and pressure test ann. w/ 1500 psi f/ 30 min. Charted (Good Test, lost 50 psi over 30 min) R/D test equipment. Ann full of diesel. Used test pump and water to pressure up. R/U Pollard SLU. RIH to retrieve prong. Taking wt @ 9812' WLM (~61' high) sit down several time and observe overpull on pick up each time. POOH. w/o prong. Change out bell guide on tool f/ 3.55" to 3.4" and RIH to 9886' WLM. (saw tight spot @ 9812' but was able to work through) POOH w/o prong. RIH with 3.4" bell and retrieve prong. RIH with 4" GS, tag and retrieve plug. Rig down Pollard wire line. Simops: blow down surface lines, clean and demob mud pump. Rig down choke manifold. Lay down landing joint. Set BPV. Rig down slide and rig floor. Rig down drip pan. Prepare to scope down mast. Remove ODS stairs, floor center piece, hole covers. Pull stripper head. Disconnect accumulator hoses and stow. Scope down and lay mast over. Power wash miscellaneous equipment. Prepare to N/D BOPE. Fluid lost to hole today: 0 bbls 43 bbls diesel baracarb LCM pill. Total fluids lost to hole: 1755 bbl. 04/29/2021 - Thursday N/D BOPE, install caps on all components except riser. Prep and N/U tree. Test void to 5000 psi for 10 min - Good test. R/U and shell test tree to 5000 psi for 10 min- Good test. Pull TWC and install tree cap. Turn well over to Production. All tree tests performed by VAULT rep. 04/27/2021 - Tuesday POOH laying down 3 1/2" PH6 work string and packer running tool. Clean and clear floor, organize decks, unload completion from boat, prep completion to pick up. Change out handling equipment to pick up 4.5" completion. P/U seal assembly, RIH w/ 4 1/2 12.6# L-80 IBT completion to 3880'. RIH w/ 4 1/2 12.6# L-80 IBT completion from 3880' to 6300'. RIH w/ 4 1/2 12.6# L-80 IBT completion from 6300' to 8950'. Fluid lost to hole today: 10 bbls 43 bbls diesel baracarb LCM pill. Total fluids lost to hole: 1755 bbl. Rig up and pressure test ann. w/ 1500 psi f/ 30 min. Charted (Good Test, Rig up and pressure test tbg. w/ 3600 psi f/ 30 min RIH w/ 4 1/2 12.6# L-80 IBT completion Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 05/13/2021 - Thursday Fly to platform. PJSM, Platform orientation & permit. Spot ELU equipment on well. MU lubricator & WLV. Fly ELU computer & lubricator X-over out from beach. BOT Tech inspects whipstock & running tool. HES inspects & surface tests GR/CCL tools. Lay down lubricator on drill deck prepping to MU tools suite while laying down on drill deck. MU HES running tool suite to RS (7/2 tie). Fire check HES Anchor sub, Power Swivel joint & Accelerometor. Surface test HES Voltage Protection module. CCL-to-bottom of HES ruuning tool suite = 14.72'. MU HES tool suite to Baker 10 setting tool & Baker 4-1/2" X 7" whipstock. Bottom of HES tool suite to Top of Whipstock = 6.45'. Total OAL CCL-to-Top of Whipstock = 21.17' (6.45 + 14.72). Baker & HES Techs verify that Whipstock = 79* ROHS. Suck up whipstock & running/setting tool suite inside of ELU lubricator & install lubricator bottom cap. Have crane hoist lubricator/tool suite to vertical. Move lubricator to well hatch opening. Remove lubricator bottom cap. Lower lubricator thru well hatch opening. Tool suite falls out of lubricator to well room floor. Stop all operations. Stand back for platform safety meeting. Re-issue JSA & permit for laying down lubricator & recovering tool suite from well room. Lay down Lub & recover tools w/o further incident. RS (7/2 tie) failed allowing tools to fall. Baker Tech inspects whipstock and verifies that whipstock is fit for purpose. HES Tech tests all GR/CCL, Anchor sub, Power Swivel joint, Accelerometor & Voltage Protection module - All Tool Tests PASS. EL Operator performs cable maintenance test on 7/32" cable & cuts back 30' of cable - Failed Test. Cut back 30' & re-test - Fail. Cut back 20' & re-test 7/32" ELU cable - 100% PASS. Tie new RS (7/2). SDFN. Job in Progress. Tool suite falls out of lubricator to well room floor Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 05/14/2021 - Friday Simops mtg w/ production. PJSM & permit. MU tools suite w/ lubricator laying on drill deck. MU HES running tool suite to RS (7/2 tie). Fire check HES Anchor sub, Power Swivel joint & Accelerometor. Surface test HES Voltage Protection module. CCL-to-bottom of HES ruuning tool suite = 14.72'. MU HES tool suite to Baker 10 setting tool & Baker 4-1/2" X 7" whipstock. Bottom of HES tool suite to Top of Whipstock = 6.45'. Total OAL CCL-to-Top of Whipstock = 21.17' (6.45 + 14.72). Baker & HES Techs verify that Whipstock = 43* ROHS. Suck up whipstock & running/setting tool suite inside of ELU lubricator & install lubricator bottom cap. Have crane hoist lubricator/tool suite to vertical.Position lubricator over well hatch cover & remove lubricator bottom cap. Remove well hatch cover. Lower tool suite to top of WH. Lower lubricator to top of WH & MU lubricator to WH bowen companion flange. PT lubricator & WLV = 250/1500. Change out leaking WLV needle valve & re-test - PASS. Open swab valve & RIH w/ 4-1/2" x 7" Delta Whipstock & running/setting tool suite. RIH to 11020' CCL depth, taking back weight. Log up to 10596' CCL, 500# overpull off bottom. Send log file for correction / verification. Correct -2'. RBIH to 11020' CCL, taking back same weight. Repeat w/ Pass #2 to 10600' CCL. Send log files for correction verification. Correct -2', RBIH to 11020' CCL, Repeat w/ Pass #3 to 10598' CCL. Send for correction/verification. RBIH to 11020' CCL. Pull Pass# 4 to 10580' CCL, heavy tension swings coming off bottom smooth out as tool suite continues to PUH. Send log files. RBIH & to same & pull Pass# 5 to 10588' CCL. @ 30 FPM. Send files Correct +14'. RBIH to 11020' CCL, still taking back weight @ same. Pull Pass# 6 to 10,598' CCL @ 30 FPM. Geologist calls w/ decision made to suspend ELU whipstock set & POOH. CTD unit to set whipstock. PUH to 10,200' RKB, end of tubing, unable to re-enter tubing. Suspect multiple logging passes have failed brass pin that retains top of whipstock tray to wire line adapter kit. Phone call to Geologist. RBIH logging down to 11,010' CCL. Send files. Correct -19'. Log up up to 10,750' CCL. RBIH logging down to 11,020' CCL. Send files. Correct +5' & log up to from 11016' CCL to 10750' CCL. Send files. RBIH to 11020' CCL. Log up to 11003.8' CCL depth to put Top of Whipstock on depth @ 11025' MD (11003.8' + 21.2'). Set anchor sub. Rotate to orient window to 15 degrees LOHS. Power off running tools & switch to firing panel for setting tool. Fire to set 4-1/2" x 7" Delta Whipstock. Wait in hole 5 minutes for Whipstock to set in place. PUH clean & log up for 200'. POOH. 10,100' back into 4-1/2" tubing clean. Continue to POOH. OOH, close swab. Tool weight & movement in lubricator indicate that possibly have returned to surface w/ whipstock. Secure ELU. RD off WH and check for tool suite for whipstock set in morning after crew sleeps. SDFN. Job in Progress. Tool weight & movement in lubricator indicate that possibly have returned to surface w/ whipstock CTD unit to set whipstock Geologist calls w/ decision made to suspend ELU whipstock set & POOH. Set anchor sub. Rotate to orient window to 15 degrees LOHS. Power off running tools & switch to firing panel for setting tool. Fire to set 4-1/2" x 7" Delta Whipstock Rig Start Date End Date HAK 404 / Eline 4/5/21 5/21/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 31-23 50-733-20072-00 167-084 05/21/2021 - Friday Fly to Platform. PJSM & permit. Boat arrives. Offload ELU & toolbox. Wait on helicopter green deck. RU ELU. RU lubricator section from drill deck to WH. MU lubricator & WLV. PU 1.69" OD GR/CCL tool suite. Surface test GR/CCL - PASS. CCL to bottom of tool string = 5.30'. Move to WH. PT Lub & WLV = 250/1500. Open swab. Tubing = 0 psi. RIH w/ GR/CCL tool suite to 11075' CCL (+ 5.3' = 11080' RKB) tag depth. Log up in 7" casing, pulling into 4-1/2" tubing @ 10,200', and continue logging up the 4-1/2" tubing to 9500'. POOH. OOH, Close swab & verify 0 psi @ lubricator. Break off WH & lay down GR/CCL tool suite. MU Caliper tool suite. Surface calibrate & test Caliper tool suite - PASS. Fingers to Bottom of Tool = 5.0'.Move back to well. Open swab. Tubing = 0 psi. RBIH w/ 24-Fingered Caliper tool suite to 10325' ELM. Start log & log up to 10050' ELM for tie back to Rig 404 Final Completion Tubing Tally. Stop log & RBIH to 11074' ELM (+ 5.0' = 11079' RKB) tag depth. Log up to 9500' ELM. Stop log. Download caliper log files & send for Rush Processing. Send GR/CCL & raw caliper log to town for QC review. POOH. OOH. Close swab & verify 0 psi on lubricator. Break off lubricator & lay down EL logging tools. Lay down lubricator. RD ELU. Secure well, well room & drill deck. Fly crew to the beach. Job complete. 05/15/2021 - Saturday ELU crew resting. PJSM & permit. Break off lubricator from WH & have crane PU lubricator. 4-1/2" x &' Delta Whipstock returned to surface. LD lubricator and break down whipstock & running tool suite. BOT Tech inspects whipstock, all shear pins/bolts intact w/ full whipstock to running tool suite integrity. HES Tech tests Anchor Sub, Power Swivel Joint, Accelerometor & Voltage Protection Module. All HES tools pass surface function tests.Test Firing Head thru HES tools suite. Firing Head test good. Inspect Baker 10 setting tool w/ Baker 10 fit for purpose. No obvious tool failures, all tools passing test & inspections. Call Operations Engineer to report whipstock was not set and returned to surface & all whipstock tool suite equipment fit for purpose w/ passing surface tests & inspections. Decision to suspend whipstock setting operations while waiting for caliper tool. Will conduct Caliper/CCL/GR log of 7" casing. RD ELU & tools. Move to Well# 44-14. Job Suspended. 4-1/2" x &' Delta Whipstock returned to surface. RBIH w/ 24-Fingered Caliper tool suite Decision to suspend whipstock setting operations while waiting for caliper tool. Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/04/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL GP 31-23 (PTD 167-084) TUBING CUT 04/13/2021 Please include current contact information if different from above. PTD: 1670840 E-Set: 35218 Received by the AOGCC 06/11/2021 06/11/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/04/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL GP 31-23 (PTD 167-084) TUBING PUNCH 04/07/2021 Please include current contact information if different from above. PTD: 1670840 E-Set: 35217 Received by the AOGCC 06/11/2021 06/11/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/10/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL GP ST 31-23 (PTD 167-084) TBG-PUNCH 04/18/2021 Please include current contact information if different from above. PTD: 1670840 E-Set: 35108 Received by the AOGCC 05/10/2021 05/10/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/10/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL GP ST 31-23 (PTD 167-084) CEMENT BOND LOG 04/25/2021 Please include current contact information if different from above. PTD: 1670840 E-Set: 35107 Received by the AOGCC 05/10/2021 05/10/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/10/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL GP ST 31-23 (PTD 167-084) TBG-PUNCH 04/18/2021 Please include current contact information if different from above. PTD: 1670840 E-Set: 35108 Received by the AOGCC 05/10/2021 05/10/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/10/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL GP ST 31-23 (PTD 167-084) CEMENT BOND LOG 04/25/2021 Please include current contact information if different from above. PTD: 1670840 E-Set: 35107 Received by the AOGCC 05/10/2021 05/10/2021 Number of Failures: 1 Test Results Test Time 4 Remarks: 2-7/8" & 3-1/2" joints. Rglliwsest done due to leakin hanger. CH mist is choke line flange leak-tightented for a pass. While on TPR & manual choke on mudcross the test pump locked up -3-1/2" joint. I left location before they completed that test and test time/date reflects the same. PLB - Operator BOPE test filed not imported. , STATE OF ALASKA Reviewed By: 391L OIL AND GAS CONSERVATION COMMISSION P.I. Suprym —<24 BOPE Test Report for: GRAN IPE PT ST 31-23 Comm Contractor/Rig No.: Hilcorp 404 PTDN: 1670840 DATE: 4/10/2021 Inspector Austin McLeod - Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Brumley/Min Rig Rep: Johnson/Reed Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopSAM210413064206 "ll321-107 Rams: Annular: Valves: MASP: Type Test: OTH 250/3000 250/2500 - 250/3000, 528 ' Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P - Trip Tank NA __ NA System Pressure _3000 - _P Housekeeping: P- Pit Level Indicators P P _- Pressure After Closure 1700 _P PTD On Location P Flow Indicator NA NA 200 PSI Attained 17 _P Standing Order Posted P Meth Gas Detector P P_- Full Pressure Attained 85 _ _ _ P Well Sign P H2S Gas Detector P P Blind Switch Covers: All stations _P Drl. Rig P MS Mise NA NA Nitgn. Bottles (avg): 4(&,2125 . P - Hazard Sec. P ACC Misc __ 0 NA Mise NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly _0_____ _ NA_ Stripper 0 - NA No. Valves 10 - _P Lower Kelly 0 __NA_ Annular Preventer 1 - 13-5/8" - P _ Manual Chokes 1 - P - _ Ball Type 1 P- #1 Rams 1 - 2-7/8"x5-1/2"- NT ✓ Hydraulic Chokes I - P ' Inside BOP 1 P- #2 Rams 1 - Blinds P - CH Mise 1 _FP ✓ FSV Mise 0 NA #3 Rams 0 NA_ 44 Rams 0 NA _ INSIDE REEL VALVES: #5 Rams 0 NA #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 - 2-1/16" - NT, Quantity P/F HCR Valves _ 2 - 2-1/16" - NA P " Inside Reel Valves _ 0—NA Kill Line Valves 2 " 2-1/16" . P - Check Valve 0 NA BOP Mise 0 NA Number of Failures: 1 Test Results Test Time 4 Remarks: 2-7/8" & 3-1/2" joints. Rglliwsest done due to leakin hanger. CH mist is choke line flange leak-tightented for a pass. While on TPR & manual choke on mudcross the test pump locked up -3-1/2" joint. I left location before they completed that test and test time/date reflects the same. PLB - Operator BOPE test filed not imported. , 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): Granite Point Field / Middle Kenai Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,200'N/A Casing Collapse Structural Conductor Surface 1,540 psi Intermediate Production 3,090 psi Liner 8,530 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: G/L Completion 9,897'11,147'9,855'528 psi 3,329'7" 7,287'9-5/8" 11,196' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 4/1/2021 3-1/2" & 2-7/8" Daniel E. Marlowe Otis RDH Hyd Pkr and N/A 9,860 - 11,176 8,062' 7,801 (MD) 7,058 (TVD) and N/A Tubing Grade:Tubing MD (ft): 8,794 - 9,878 Perforation Depth TVD (ft): 9,894' 9.2# / N-80 & 6.5# / N-80 3,933' 8,062' Perforation Depth MD (ft): 3,665' 604' 3,933' 18" 13-3/8" 604' TVD Burst 7,811 & 11,065 5,750 psi 11,220 psi Tubing Size: MD 3,090 psi 603' 167-084 50-733-20072-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Granite Pt St 31-23 N/A COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018761 Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 11,147' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:59 pm, Mar 04, 2021 321-107 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.03.04 13:38:36 -09'00' Dan Marlowe (1267) Submit separate sundry for post-drilling recompletion. BJM DSR-3/4/21 X DLB 03/05/2021 X BJM 3/26/21 10-404 Prep for CTD lateral CTD whipstock BOP test to 3000 psi, annular test to 2500 psi. - Implement plan to monitor benzene exposure and ensure worker protections from exposure to diesel prior to workover operations. dts 3/26/2021 3/26/21Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.03.26 14:49:47 -08'00' RBDMS HEW 3/26/2021 Well Work Prognosis Well: GP 31-23 Well Name:GRANITE PT ST 31-23 API Number: 50-733-20072-00 Current Status:G/L Producer Leg:Leg #1 West Estimated Start Date:April 1, 2020 Rig:HAK 404 Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:167-084 First Call Engineer:Katherine O’Connor 907-777-8376 214-684-7400 Second Call Engineer:Karson Kozub (907) 570-1801 Current Bottom Hole Pressure:1107 psi @ 8837’ TVD 0.125 psi/ft based on SIBHP 2/21 Maximum Expected BHP:1107 psi @ 8837’ TVD Maximum Potential Surface Pressure: 528 psi SITP 2/21 - less than 0.1 psi/ft gradient per 20AAC25.280(b)(4) Brief Well Summary GP 31-23 is an online producer making 50 bopd. This well will be sidetracked with CTD. CTD will drill new lateral sections in the C7 and C5. The perforations open now will not be abandoned and will be produced after drilling with the new laterals. The broad steps of this overall program are to pull the current dual completion, run in with a 4-1/2” tubing work string. This work string will be set up with a TRSSSV and gas lift valves to allow for production after drilling. Post drilling and initial production tests, the 4-1/2” tubing may be swapped for a more permanent 2-7/8” GLV completion. Procedure: Phase I 1. RU SL pressure test lubricator to 250psi low/1500 psi high a. Pull center set GLVs in short string b. Drift to TD to determine if cleanout is needed in short string c. Set plug in short string @ ~300’ MD and pressure test (do not have ability to set BPV) d. Drift long string e. Set plug in long string @ ~315’ MD (do not have ability to set BPV) and pressure test 2. MIRU 404 3. Circulate KWF to kill well 4. ND Wellhead. 5. NU BOP and test to 250psi low/3000psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 6. Monitor well to ensure it is static. 7. RU SL pressure test lubricator to 250psi low/1500 psi high a. Pull plugs out of long string and short string 8. Pull 3-1/2” short string x If unable to pull, RU EL and cut above the packer 9. Pull 2-7/8” long string & packer x Makeup 2-7/8” x 1-1/4” safety joint to have on hand for pulling long string extension 10. Pick up workstring and RIH to cleanout 9-5/8” and 7” to TD. POOH w/ all but ~500’ of work string. 11. Land hangar and test to 3000psi x If test passes, pull hangar The perforations open now will not be abandoned and will be produced after drilling with the new laterals. T 7.b. Circulate KWF down short string and long string to ensure well is dead. Monitor to ensure well is static. What are specs on the workstring? Superseded - BJM Well Work Prognosis Well: GP 31-23 x If test fails set storm packer, pressure test, and install new tubing spool, retest BOP stack & tubing spool. Pull storm packer. 12. POOH w/ rest of workstring 13. RU EL CBL logging tool. Log from ±9860 to surface. 14. RIH with 4-1/2” gas lift completion (dummy valves), SSSV, and packer assembly. See proposed schematic for details and set depths. 15. Set Packer / Pressure test completion x MITIA to 2500 psi chart for 30 min 16. ND BOPE and NU tree and test. 17. Rig down and move HAK 404 off location 18. Eline: Set 4-1/2” x 7 whipstock at 11,031’ at 15 deg LOHS ***Remaining Procedure to be included on the Permit to Drill for the sidetrack*** Phase II General sequence of operations pertaining to drilling procedure: (informational only) 1. Resume operations with Coiled Tubing Unit 2. MIRU Coiled Tubing Drilling Equipment 3. NU BOP and test 4. Swap well to drilling fluid. 5. Kick off whipstock and drill C7 lateral 6. Run slotted liner with kick off billet 7. Drill L1-01 lateral 8. Run slotted liner back to window 9. Set whipstock @~10284’ MD 10. Kick off whipstock and drill C5 lateral 11. Run slotted liner with kick off billet 12. Run slotted liner back to tubing tail 13. Swap to completion sundry. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing – HAK 404 5. Fluid Flow Diagrams – HAK 404 6. RWO Sundry Revision Change Form Superseded - BJM _____________________________________________________________________________________ Revised By: JLL 02/10/2021 SCHEMATIC Granite Point Platform Well No: GP 31-23 Completed: 04/1968 PBTD = 11,147’ TD = 11,200’ 5 7 18” 2 3 4 Otis RDH Hydraulic Packer 7,801’ 9-5/8” C DE F G H J I 6 8 9 1 13-3/8” 7” TOL 7,857’ TOC Unknown Fill Tagged 11,104’ A B XOXOXOXOXXXOXOX XOXOXOXOXOXXXO XOXOXOXOXXOXXXO XOXOXOXXXOXOXO ADL: 18761 PTD: 167-084 API: 50-733-20072-00 KB: 105’ MWL CASING DETAIL Size Wt Grade Conn ID Top Bottom 18" Surf. 604’ 13-3/8" 61 J-55 DV Tool 12.515” Surf. 2,230’ 13-3/8” 61 J-55 Buttress 12.515” 2,230’ 3,933’ 9-5/8" 40 N-80 Buttress 8.835” Surf. 295’ 40 N-80 LTC 8.835” 295’ 3,801’ 43.5 N-80 LTC 8.755 3,801’ 5,173’ 43.5 S-95 STC 8.755 5,173’ 8,062’ 7" 29 P-110 X-line 6.184” 7,867’ 11,196’ TUBING DETAIL Short String 3-1/2" 9.2 N-80 Butt 2.992” Surf. 7,811’ Long String 2-7/8" 6.5 N-80 8RD 2.441” Surf. 11,065’ Jewelry Detail # Depth ID Item Short String 1 300’ 2.75” Otis Ball Valve 2 2,205’ 2.75” Otis CX Concentric GLM 3 3,751’ 2.75” Otis CX Concentric GLM 4 4,821’ 2.75” Otis CX Concentric GLM 5 5,723’ 2.75” Otis CX Concentric GLM 6 7,068’ 2.75” Otis CX Concentric GLM 7 7,697’ 2.75” Otis CX Concentric GLM 8 7,809’ 2.625” Otis Q Nipple 9 7,811’ Otis Catcher Sub Long String A 315’ 2.313” Otis Ball Valve B 9,859’ 2.225” Otis Type N Landing Nipple C 9,860’ 2.25” No-Go D 9,894’ XO E 9,895’ GLM / GLV F 9,896’ XO G 10,496’ XO H 10,497’ GLM / GLV I 10,498’ XO J 11,065’ Check valve Perforations Top(MD) Btm(MD) Top(TVD) Btm(TVD) Detail 9,860’ 9,861’ 8,794’ 8,795’ Squeezed 9,866’ 9,867 ‘ 8,799’ 8,800’ Water Shut Off 9,911’ 9,921’ 8,837’ 8,846’ Open 9,941’ 9,971’ 8,863’ 8,888’ Open 10,100’ 10,101’ 8,996’ 8,997’ Squeezed 10,254’ 10,260’ 9,124’ 9,129’ Open 10,260’ 10,275’ 9,129’ 9,142’ Open 10,275’ 10,280’ 9,142’ 9,146’ Open 10,280’ 10,445’ 9,146’ 9,281’ Open 10,561’ 10,578’ 9,376’ 9,390’ Open 10,654’ 10,681’ 9,452’ 9,474’ Open 10,730’ 10,731’ 9,515’ 9,515’ Squeezed 10,895’ 10,897’ 9,650’ 9,651’ Open 10,897’ 10,987’ 9,651’ 9,725’ Open 11,014’ 11,016’ 9,747’ 9,749’ Open 11,016’ 11,176’ 9,749’ 9,878’ Open _____________________________________________________________________________________ Revised By: KGO 2/5/2021 PROPOSED Granite Point Platform Well No: GP 31-23 Completed: FUTURE ADL: 18761 PTD: 167-084 API: 50-733-20072-00 Jewelry Detail #Depth (MD) Depth (TVD)ID OD Item 1 ±350’ ±350’ 3.813 TRSSSV 2 ±2,595’ ±2,501’ 3.833” 6.141”/7.063” GLV 3 ±4,765’ ±4,399’ 3.833” 6.141”/7.063” GLV 4 ±6,364’ ±5,800’ 3.833” 6.141”/7.063” GLV 5 ±7,398’ ±6,699’ 3.833” 6.141”/7.063” GLV 6 ±8,199’ ±7,405’ 3.833” 5.984” GLV 7 ±8,916’ ±7,998’ 3.833” 5.984” GLV 8 ±9,631’ ±8,601’ 3.833” 5.984” GLV - Orifice 9 ±9,794’ ±8,738’ 5” 5.875” PBR/15’ Seal Assembly 10 ±9,809’ ±8,751’ 4” 5.875” Packer 11 ±9,885’ ±8,815’ 3.812” 5” X nipple 12 ±10,195’ ±9,075’ 3.958” 5” WLEG CASING DETAIL Size Wt Grade Conn ID Top Bottom 18" Surf. 604’ 13-3/8" 61 J-55 DV Tool 12.515” Surf. 2,230’ 13-3/8” 61 J-55 Buttress 12.515” 2,230’ 3,933’ 9-5/8" 40 N-80 Buttress 8.835” Surf. 295’ 40 N-80 LTC 8.835” 295’ 3,801’ 43.5 N-80 LTC 8.755 3,801’ 5,173’ 43.5 S-95 STC 8.755 5,173’ 8,062’ 7" 29 P-110 X-line 6.184” 7,867’ 11,196’ TUBING DETAIL 4-1/2" 12.6 L-80 IBT 3.833 Surf. ±9,794’ 4-1/2" 12.6 L-80 IBT 3.833 ±9,809’ ±10,195’ Perforations Top(MD) Btm(MD) Top(TVD) Btm(TVD) Detail 9,860’ 9,861’ 8,794’ 8,795’ Squeezed 9,866’ 9,867 ‘ 8,799’ 8,800’ Water Shut Off 9,911’ 9,921’ 8,837’ 8,846’ Open 9,941’ 9,971’ 8,863’ 8,888’ Open 10,100’ 10,101’ 8,996’ 8,997’ Squeezed 10,254’ 10,260’ 9,124’ 9,129’ Open 10,260’ 10,275’ 9,129’ 9,142’ Open 10,275’ 10,280’ 9,142’ 9,146’ Open 10,280’ 10,445’ 9,146’ 9,281’ Open 10,561’ 10,578’ 9,376’ 9,390’ Open 10,654’ 10,681’ 9,452’ 9,474’ Open 10,730’ 10,731’ 9,515’ 9,515’ Squeezed 10,895’ 10,897’ 9,650’ 9,651’ Open 10,897’ 10,987’ 9,651’ 9,725’ Open 11,014’ 11,016’ 9,747’ 9,749’ Open 11,016’ 11,176’ 9,749’ 9,878’ Open PRE CTD DRILLING KB: 105’ MWL PBTD = 11,147’ TD = 11,200’ 5 7 18” 2 3 4 Top of whipstock 11,016’ MD 11 9-5/8” 10 6 9 8 1 13-3/8” 7” TOC Unknown Fill Tagged 11,104’ TOL 7,857’ Granite Point Platform 31-23—current 02/16/2020 18'’ 13 3/8'’ 9 5/8'’ Granite Point GPP 31-23 18 X 13 3/8 X 9 5/8 X 3 ½ x 2 7/8 Unihead, OCT type 2-emegency, 13 5/8 5M API hub top X 21 ¼ 1M hub bottom, w/ 2- 2'’ LPO on lower section, 2- 2 1/16 5M SSO on upper section, IP internal lockpin assy Valve, WKM-M, 2 1/16 5M HWO, AA trim Valve, OCT-20, 2'’ LPO, HWO, AA trim Starting head, OCT, 21 1/4 2M Hub x 24 ¼ 1M Hub w/ 2- 2'’ LPO, prepped f/ 18'’ EN hanger Conductor housing, 24 ¼ 1M Hub X 24'’ Buttweld Control line x 2 Adapter, OCT-Dual, 13 5/8 5M API clamp X 3 1/8 5M 5 bolt x 2 9/16 5M 5 bolt, prepped on 5 9/16 centers, 2- ½ control line exits Valve, Dual, Masters, OCT-20, 2 9 1/6 5M 5 bolt x 3 1/8 5M 5 bolt FE, R trim Valve, Dual, Swabs, OCT-20 and WKM-M, 3 1/8 5M 5 bolt x 2 9/16 5M 5 bolt FE, R trim Tree cap, 3 1/8 5M 5 bolt X 3 ½ EUE 8rd x 2 9/16 5M bolt x 2 7/8 EUE 8rd Tubing hanger, OCT-UHD-2C, 13 5/8 bowl adapter bushing Short string mandrel 3 ½ IBT lift and susp w/ ¼’’ CL, 3'’ OTIS-WT BPV profile Long string mandrel, 2 7/8 EUE 8rd lift and 2 7/8 IBT susp w/ 2 1/2'’ OTIS WT BPV profile, Prepped for Drilco Concentric SSSV, 5 9/16 centers 2 7/8'’ 3 ½’’ Granite Point Platform 31-23—Proposed 02/27/2021 Valve, Master, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, Swab, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, SSV, Wing, WKM-M, 3 1/8 5M, w/ 15'’ OMNI oper Tee, stdd, 4 1/16 5M X 3 1/8 5M BHTA, Bowen, 4 1/16 5M FE X 7'’ Bowen Valve, Master, WKM-M, 4 1/16 5M FE, HWO, EE trim Adapter, FMC-A5P, 13 5/8 5M API clamp X 4 1/16 5M, w/ 6.250'’ extended neck pocket, 2- 1'’NPT control line ports 18'’ 13 3/8'’ 9 5/8'’ Granite Point GPP 31-23 18 X 13 3/8 X 9 5/8 X 4 ½ Unihead, OCT type 2-emegency, 13 5/8 5M API hub top X 21 ¼ 1M hub bottom, w/ 2- 2'’ LPO on lower section, 2- 2 1/16 5M SSO on upper section, IP internal lockpin assy Valve, WKM-M, 2 1/16 5M HWO, AA trim Valve, OCT-20, 2'’ LPO, HWO, AA trim Starting head, OCT, 21 1/4 2M Hub x 24 ¼ 1M Hub w/ 2- 2'’ LPO, prepped f/ 18'’ EN hanger Conductor housing, 24 ¼ 1M Hub X 24'’ Buttweld Control line x 2 4 ½’’ Tubing hanger, FMC-UH- TC-1A-EN-CCL, 13 5/8 5M X 4 ½ 8rd EUE lift and susp, w/ 4'’ type H BPV, 6.250'’ EN, 2-3/8 npt control line feed-thru Granite Point Platform 31-23—Proposed 02/27/2021 Valve, Master, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, Swab, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, SSV, Wing, WKM-M, 3 1/8 5M, w/ 15'’ OMNI oper Tee, stdd, 4 1/16 5M X 3 1/8 5M BHTA, Bowen, 4 1/16 5M FE X 7'’ Bowen Valve, Master, WKM-M, 4 1/16 5M FE, HWO, EE trim 18'’ 13 3/8'’ 9 5/8'’ Granite Point GPP 31-23 18 X 13 3/8 X 9 5/8 X 4 ½ Unihead, OCT type 2-emegency, 13 5/8 5M API hub top X 21 ¼ 1M hub bottom, w/ 2- 2'’ LPO on lower section, 2- 2 1/16 5M SSO on upper section, IP internal lockpin assy Valve, WKM-M, 2 1/16 5M HWO, AA trim Valve, OCT-20, 2'’ LPO, HWO, AA trim Starting head, OCT, 21 1/4 2M Hub x 24 ¼ 1M Hub w/ 2- 2'’ LPO, prepped f/ 18'’ EN hanger Conductor housing, 24 ¼ 1M Hub X 24'’ Buttweld 4 ½’’ Tubing hanger ,Cactus-TC- 1A-EN-CCL, 11 5M X 4 ½ 8rd EUE lift and susp, w/ 4'’ type H BPV, 6.250'’ EN, 2-3/8 npt control line feed- thru Adapter, Cactus-EN-6.25'’, 11 5M stdd x 4 1/16 5M stdd top, w/ 2- 1'’npt control line exits Isolation Sleeve Completion spool, Cactus, 13 5/8 5M API hub x 11 5M top Granite Point Platform 2019 BOP Stack (404) 01/21/2019 CIW-U 2.26' Riser 13 5/8 5M FE X 13 5/8 5M API hub 19.83' in length Variable rams 2 7/8-5 4.54' 4.67' Choke and Kill valves 2 1/16 5M CIW-U 13 5/8-5000 Mud Cross 3 1/8 5M EFO Blind Rams 4.30'Hydril GK 13 5/8-5000 DSA 3 X 2DSA 3 X 27'’ casing rams 2.83' Why 7" casing rams? Superseded Valve Position(O/C)Standpipe PumpManifold1(PM1) OManifold PumpManifold2(PM2) OPumpManifold3(PM3) CPumpManifold4(PM4) OPumpManifold5(PM5) CMud KillLine1OCross KillLine2OHCRvalve(ChokeLine1) CChokeLine2OChoke ChokeManifold1(CM1) OManifold ChokeManifold2(CM2) CChokeManifold3(CM3) OChokeManifold4(CM4) CChokeManifold5(CM5) OChokeManifold6(CM6) CChokeManifold7(CM7) OChokeManifold8(CM8) CChokeManifold9(CM9) CChokeManifold10(CM10) OSuperChoke CManualChoke CRigFloor SafetyValve O Valve Position(O/C)Standpipe PumpManifold1(PM1) OManifold PumpManifold2(PM2) CPumpManifold3(PM3) OPumpManifold4(PM4) CPumpManifold5(PM5) OMud KillLine1OCross KillLine2OHCRvalve(ChokeLine1) CChokeLine2OChoke ChokeManifold1(CM1) OManifold ChokeManifold2(CM2) CChokeManifold3(CM3) OChokeManifold4(CM4) CChokeManifold5(CM5) OChokeManifold6(CM6) CChokeManifold7(CM7) OChokeManifold8(CM8) CChokeManifold9(CM9) CChokeManifold10(CM10) OSuperChoke CManualChoke CRigFloor SafetyValve O Rig 404 BOP Test Procedure Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program – Oil Producers, Gas 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. x 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 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.) NA - Plugs will be set in tubing - BJM Rig 404 BOP Test Procedure Attachment #1 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 joint 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- RIH with test plug on joint of tubing. Install a pump-in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 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 (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1 st valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross, open 1st valve of standpipe, close valves 3, 4 & 9 on choke manifold, open valves 1 & 2 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. 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 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve / open outside valve on kill side of mud cross, close valves 5 & 6 / open valves 3 & 4 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke / open valves 5 & 6 on choke manifold. Pressure up to ~ 1200 psi and bleed off 200 – 300 #s recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. f) Close HCR (outside valve on choke side of mud cross), open manual & super choke. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. NA - Plugs will be set in tubing - BJM Rig 404 BOP Test Procedure Attachment #1 g) Close inside valve / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7 & 8 / open valve 10 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. 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 2 nd 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. Document both the rolling test and the follow up tests. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Granite Pt St 31-23 (PTD 167-084)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date Well Work Prognosis Well: GP 31-23 Well Name: GRANITE PT ST 31-23 API Number: 50-733-20072-00 Current Status: G/L Producer Leg: Leg #1 West Estimated Start Date: April 1, 2020 Rig: HAK 404 Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 167-084 First Call Engineer: Katherine O’Connor 907-777-8376 214-684-7400 Second Call Engineer: Karson Kozub (907) 570-1801 Current Bottom Hole Pressure: 1107 psi @ 8837’ TVD 0.125 psi/ft based on SIBHP 2/21 Maximum Expected BHP: 1107 psi @ 8837’ TVD Maximum Potential Surface Pressure: 528 psi SITP 2/21 - less than 0.1 psi/ft gradient per 20AAC25.280(b)(4) Brief Well Summary GP 31-23 is an online producer making 50 bopd. This well will be sidetracked with CTD. CTD will drill new lateral sections in the C7 and C5. The perforations open now will not be abandoned and will be produced after drilling with the new laterals. The broad steps of this overall program are to pull the current dual completion, run in with a 4-1/2” tubing work string. This work string will be set up with a TRSSSV and gas lift valves to allow for production after drilling. Post drilling and initial production tests, the 4-1/2” tubing may be swapped for a more permanent 2-7/8” GLV completion. Procedure: Phase I 1. RU SL pressure test lubricator to 250psi low/1500 psi high a. Bullhead KWF to kill well b. Set plug in short string @ ~300’ MD and pressure test (do not have ability to set BPV) c. Drift long string d. Set plug in long string @ ~315’ MD (do not have ability to set BPV) and pressure test 2. MIRU 404 3. ND Wellhead. 4. NU BOP and test to 250psi low/3000psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). Must test with non-compressible fluid (not diesel). - BJM 5. Monitor well to ensure it is static. 6. RU SL pressure test lubricator to 250psi low/1500 psi high a. Pull plugs out of long string and short string @ ~315’ MD b. Set plug in long string below packer c. Punch long string above packer, circulate KWF into the annulus d. Pull plug, RD SL 7. Pull 3-1/2” short string x If unable to pull, RU EL and cut above the packer 8. Pull 2-7/8” long string & packer x Makeup 2-7/8” x 1-1/4” safety joint to have on hand for pulling long string extension 9. Pick up workstring and RIH to cleanout 9-5/8” and 7” to TD. POOH w/ all but ~500’ of work string. Workstring is 3-1/2” 12.95# P-110 PH-6 -BJM 10. Land hangar and test to 3000psi Well Work Prognosis Well: GP 31-23 x If test passes, pull hangar x If test fails set storm packer, pressure test, and install new tubing spool, retest BOP stack & tubing spool. Pull storm packer. 11. POOH w/ rest of workstring 12. RU EL CBL logging tool. Log from ±9860 to surface. 13. RIH with 4-1/2” gas lift completion (dummy valves), SSSV, and packer assembly. See proposed schematic for details and set depths. 14. Set Packer / Pressure test completion x MITIA to 2500 psi chart for 30 min 15. ND BOPE and NU tree and test. 16. Rig down and move HAK 404 off location 17. Eline: Set 4-1/2” x 7 whipstock at 11,031’ at 15 deg LOHS ***Remaining Procedure to be included on the Permit to Drill for the sidetrack*** Phase II General sequence of operations pertaining to drilling procedure: (informational only) 1. Resume operations with Coiled Tubing Unit 2. MIRU Coiled Tubing Drilling Equipment 3. NU BOP and test 4. Swap well to drilling fluid. 5. Kick off whipstock and drill C7 lateral 6. Run slotted liner with kick off billet 7. Drill L1-01 lateral 8. Run slotted liner back to window 9. Set whipstock @~10284’ MD 10. Kick off whipstock and drill C5 lateral 11. Run slotted liner with kick off billet 12. Run slotted liner back to tubing tail 13. Swap to completion sundry. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing – HAK 404 5. Fluid Flow Diagrams – HAK 404 6. RWO Sundry Revision Change Form GPP Platform 2021 BOP Rig 404 03/18/2021 Shaffer SL 13 5/8 5M 2 7/8-5.5 variables Blinds 2.26' 19.83' 4.54' 2.83' Choke and Kill valves 2 1/16 5M Mud Cross 4 1/16 5M EFO 4.30' Hydril GK 13 5/8-5000 DSA 4 X 2DSA 4 X 2Riser 13 5/8 5M FE X 13 5/8 5M API hub 19.83' in length Shaffer SL 1 Carlisle, Samantha J (CED) From:Katherine O'connor <Katherine.Oconnor@hilcorp.com> Sent:Monday, March 22, 2021 1:56 PM To:McLellan, Bryan J (CED) Subject:RE: [EXTERNAL] Granite Point St 31-23 (PTD 167-084) Attachments:GP 31-23 AOGCC Decomplete Procedure Update 03.22.21.docx HiBryan Iclarifiedthestepsaroundkillingthewell&circulatingtheannulus.Itookoutthestepsarounddriftingtheshortstring andpullingthosecentersetGLVsbecausetheycomplicatemattersandarenotnecessaryinthegrandschemeofour goals.Thenkilldownthetubinginstepone,andaftertheBOPsareriggedup,haveSLpunchandcirculatetheannulus throughthetbgpunch. 1. RUSLpressuretestlubricatorto250psilow/1500psihigh a. PullcentersetGLVsinshortstring b. DrifttoTDtodetermineifcleanoutisneededinshortstring c. BullheadKWFtokillwell d. Setpluginshortstring@~300’MDandpressuretest(donothaveabilitytosetBPV) e. Driftlongstring f. Setpluginlongstring@~315’MD(donothaveabilitytosetBPV)andpressuretest 2. MIRU404 3. NDWellhead. 4. NUBOPandtestto250psilow/3000psihigh.(Note:NotifyAOGCC48hoursinadvanceoftesttoallow themtowitnesstest). 5. Monitorwelltoensureitisstatic. 6. RUSLpressuretestlubricatorto250psilow/1500psihigh a. Pullplugsoutoflongstringandshortstring b. Setpluginlongstringbelowpacker c. Punchlongstringabovepacker,circulateKWFintotheannulus d. Pullplug,RDSL 7. Pull3Ͳ1/2”shortstring x Ifunabletopull,RUELandcutabovethepacker Thanksandletmeknowifyouhaveanymorequestions. KatherineO’Connor From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Friday,March19,20214:42PM To:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Subject:RE:[EXTERNAL]GranitePointSt31Ͳ23(PTD167Ͳ084) Thanks,Katherine.Ihopeall’swellwithyoutoo.It’snicetocrosspathsagain. I’dliketounderstandhowyouareplanningtopullthedualstring.Let’stouchbaseonMondaytotalkbrieflyaboutit. BryanMcLellan 2 SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 From:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Sent:Friday,March19,20213:48PM To:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Cc:JuanitaLovett<jlovett@hilcorp.com> Subject:RE:[EXTERNAL]GranitePointSt31Ͳ23(PTD167Ͳ084) HiBryan, Ihopealliswell!MyrepliesareinredbelowandanupdatedBOPschematicisattached. Thanks, Katherine KatherineO’Connor CIOOperationsEngineer Katherine.oconnor@hilcorp.com W:(907)777Ͳ8376 C:(214)684Ͳ7400 From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Wednesday,March17,20213:17PM To:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Subject:[EXTERNAL]GranitePointSt31Ͳ23(PTD167Ͳ084) HiKatherine, I’mreviewingtheDecompletionsundryforGPS31Ͳ23andhaveacouplequestionsforyou. 1. InPhaseI,step3,whatisyourcirculationpathforKWF?Wewillbebullheadingfluid(perforationsaregoingto remainopen) 2. Whatfluidtypeanddensitywillyouusetokillthewell?Planningonusingdiesel6.8#,possiblywithsome weightedwaterpillsifneeded. 3. PhaseI,step10,Whatarethespecsoftheworkstringyouarerunning?Workstringwillbe3Ͳ1/2”12.95#PͲ110 PHͲ6 4. PhaseI,step13:HowwilltheresultsoftheCBLimpactyourplansfortheDecompletionorsidetracks?The CBL log results will not affect plan for the decomplete or drill well, it is just information we like to have on hand at Hilcorp and the decomplete presents a good opportunity to obtain that information. 5. YourBOPdiagramshows7”casingramsinthelowerpiperam.Isthatcorrect?Thatisnotcorrect.Sorry,an outdatedBOPschematicwasattached.Theupdated2021BOPschematicforGP31Ͳ23isattachedinthisemail. Thanks BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov 3 +1(907)250Ͳ9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Carlisle, Samantha J (CED) From:Katherine O'connor <Katherine.Oconnor@hilcorp.com> Sent:Thursday, March 25, 2021 3:50 PM To:McLellan, Bryan J (CED) Subject:RE: [EXTERNAL] Granite Point St 31-23 (PTD 167-084) HiBryan, OnGP11Ͳ13RD(PTD191Ͳ133)Hilcorpexecutedaworkoverin2015inwhichdieselwasusedtofinishpullingthe completion.On6/30/2015filledtheholewithdiesel,pulled3Ͳ1/2”tubingandpacker,perforated,andthenRIHwiththe newcompletion.In2014onGPͲ54(PTD196Ͳ013)HilcorpusedacomboifFIWanddiesel.On1/15/2014theyswapped thewelltodieseltopullthecompletionoutofthewell.Inbothwells,dieselwasusedbecauseofopenornew perforationsandconcernforreservoircompatibilityissues.Ifthisreservoirseesaqueousfluid,itplugsupandtotally losesproductivity. Hilcorpandtheresponsiblecontractcompanywillensurecontrolsareinplacetocomplywithindustryregulations.In thedieselHilcorpuses(fromtheTesoro/Marathonrefinery)thereisnobenzene.Theplatformissecondary containment.Hilcorpandassociatedcontractcompanyhavebeendiscussingtheextraprecautionsrequiredwhen pullingequipmentoutofthegroundwhenusingdieselasworkoverfluid–therewillbeextratarpsandTyveksuitsto protectworkersandtheenvironment.Further,whilethereissomecirculation,extendedcirculationisnotplannedas partofthistubingchangeͲout. Feelfreetocallwithquestionstodiscussasneeded. Thanks! Katherine From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Wednesday,March24,20214:05PM To:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Subject:RE:[EXTERNAL]GranitePointSt31Ͳ23(PTD167Ͳ084) Katherine, DoyouhavesomeexamplesofwhereHilcorppulledtubingoutofawellusingdieselasthecompletionfluidduringa RWO? Thanks BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 From:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Sent:Tuesday,March23,20212:20PM To:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Subject:RE:[EXTERNAL]GranitePointSt31Ͳ23(PTD167Ͳ084) 2 HeyBryan ItisnotunusualintheGranitePointfield.Thesesandsareextremelysensitivetowater,sodieselisgenerallythe completionfluidusedwhenopenornewperforationsareinvolved.SeeGPͲ53RD(sundryattached)completionasthe mostrecentexampleIcanthinkof. Thebenzeneexposureriskisexpectedtobelowgiventhepitsareopentoatmosphereoutside.Aspecificprocedureis indevelopmenttomonitorbenzenelevelsandensureworkerprotection;itwillbeinplacepriortobeginning operations. Thanks Katherine From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Tuesday,March23,20211:26PM To:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Subject:RE:[EXTERNAL]GranitePointSt31Ͳ23(PTD167Ͳ084) Katherine, Justacouplemorequestions. x IsitunusualtoperformaRWOwithdieselintheCookInletregion? x DoyouhaveanyprocedurestomonitorforbenzeneexposurefortherighandsduringtheRWO? Thankyou BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 From:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Sent:Tuesday,March23,20217:37AM To:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Subject:RE:[EXTERNAL]GranitePointSt31Ͳ23(PTD167Ͳ084) Mudpitsareopentopoutside. Thanks, Katherine From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Monday,March22,20214:37PM To:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Subject:RE:[EXTERNAL]GranitePointSt31Ͳ23(PTD167Ͳ084) IstheMudpitenclosedorisitoutside? BryanMcLellan SeniorPetroleumEngineer 3 AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 From:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Sent:Monday,March22,20214:07PM To:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Subject:RE:[EXTERNAL]GranitePointSt31Ͳ23(PTD167Ͳ084) Thedieseliskeptinbeamtanksontheplatform.Itwilltransferfromplatformtankstoopentopmudpitthe404uses andthengetpumpeddownthewell. Thanks Katherine From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Monday,March22,20213:20PM To:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Subject:RE:[EXTERNAL]GranitePointSt31Ͳ23(PTD167Ͳ084) Katherine, I’mnotfamiliarwiththemudpitsystemonthisrig,butareyouplanningtohavemudpitsfullofdieselforthis workover?Ifso,arethepitsenclosed? Thanks BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 From:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Sent:Friday,March19,20213:48PM To:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Cc:JuanitaLovett<jlovett@hilcorp.com> Subject:RE:[EXTERNAL]GranitePointSt31Ͳ23(PTD167Ͳ084) HiBryan, Ihopealliswell!MyrepliesareinredbelowandanupdatedBOPschematicisattached. Thanks, Katherine KatherineO’Connor CIOOperationsEngineer Katherine.oconnor@hilcorp.com W:(907)777Ͳ8376 C:(214)684Ͳ7400 4 From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Wednesday,March17,20213:17PM To:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Subject:[EXTERNAL]GranitePointSt31Ͳ23(PTD167Ͳ084) HiKatherine, I’mreviewingtheDecompletionsundryforGPS31Ͳ23andhaveacouplequestionsforyou. 1. InPhaseI,step3,whatisyourcirculationpathforKWF?Wewillbebullheadingfluid(perforationsaregoingto remainopen) 2. Whatfluidtypeanddensitywillyouusetokillthewell?Planningonusingdiesel6.8#,possiblywithsome weightedwaterpillsifneeded. 3. PhaseI,step10,Whatarethespecsoftheworkstringyouarerunning?Workstringwillbe3Ͳ1/2”12.95#PͲ110 PHͲ6 4. PhaseI,step13:HowwilltheresultsoftheCBLimpactyourplansfortheDecompletionorsidetracks?The CBL log results will not affect plan for the decomplete or drill well, it is just information we like to have on hand at Hilcorp and the decomplete presents a good opportunity to obtain that information. 5. YourBOPdiagramshows7”casingramsinthelowerpiperam.Isthatcorrect?Thatisnotcorrect.Sorry,an outdatedBOPschematicwasattached.Theupdated2021BOPschematicforGP31Ͳ23isattachedinthisemail. Thanks BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed 5 above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA AAA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other El Add 1,206' to long Performed: strino Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other 0 Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development D Exploratory 0 167 -084 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic Service 0 6. API Number: Anchorage, AK 99503 50- 733 - 200720 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018761 Granite Pt St 31 -23 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): v Granite Point Field / Middle Kenai G Oil Pool 11. Present Well Condition Summary: Total Depth measured 11,200 feet Plugs measured 11,147 feet true.vertical 9,886 feet Junk measured N,A feet Effective Depth measured 11,147 feet Packer measured 7,801 feet true vertical 9,855 feet true vertical 7,058' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 604' 18" 604' 603' Surface 3,933' 13 -3/8" 3,933' 3,665' 3,090 psi 1,540 psi Intermediate Production 8,062' 9 -5/8" 8,062' 7,287' 5,750 psi 3,090 psi Liner 3,329' 7" 11,196' pp�� 9,894' q{� 11,220 psi 8,530 psi Perforation depth Measured depth See Schematic feet SC N�NED AP n 13 True Vertical depth See Schematic feet 3 -1/2" 9.2# / N -80 7,811' (MD) 7,067' (TVD) Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.5# / N -80 11,065' (MD) 1,062' (TVD) Packers and SSSV (type, measured and true vertical depth) Otis RDH Hyd Pkr 7,801' (MD) 7,058' (TVD) RECEIVED 12. Stimulation or cement squeeze summary: APR S y 2 2013 Intervals treated (measured): J N/A GC Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 45 55 40 245 80 Subsequent to operation: 55 75 35 290 110 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory0 Development El ° Service 0 Stratigraphic 0 Daily Report of Well Operations X 16. Well Status after work: Oil CI Gas ❑ WDSPL❑ GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP0 SPLUGO 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: Contact Ted Kramer Email tkramer@hilcora.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature Phone (907) 777 -8420 Date 4/12/2013 Form 10 -404 ReviseRENDMS APR 15 2013 4W1 / 1 ( -- /.513 / Submit Original Only • • Granite Point Platform .14 SCHEMATIC Well No: GP 31 -23 Hilcorp Alaska, LLC Completed: 04/1968 1 I 1______I KB: 105' MWL ADL: 18761 PTD: 167 -084 API: 50- 733 - 20072 -00 1 18" 1 A CASING DETAIL Size Wt Grade Conn ID Top Bottom 18" Surf. 604' 13 -3/8" 61 J -55 DV Tool 12.515" Surf. 2,230' 13 -3/8" 61 1 -55 Buttress 12.515" 2,230' 3,933' 40 N -80 Buttress 8.835" Surf. 295' 40 N -80 LTC 8.835" 295' 3,801' 9 -5/8" 43.5 N -80 LTC 8.755 3,801' 5,173' 43.5 S -95 STC 8.755 5,173' 8,062' 13 -3/8" - 7" 29 P -110 X -line 6.184" 7,867' 11,196' L TUBING DETAIL Short String 3 -1/2" 9.2 N -80 Butt 2.992" Surf. 7,811' 2 1 � � Long String 2 -7/8" 6.5 N -80 8RD 2.441" Surf. 11,065' 3 a- Jewelry Detail # Depth ID Item Short String 4 I' 0 1 300' 2.75" Otis Ball Valve 2 2,205' 2.75" Otis CX Concentric GLM 3 3,751' 2.75" Otis CX Concentric GLM roc 4 4,821' 2.75" Otis CX Concentric GLM Unknown 5 5,723' 2.75" Otis CX Concentric GLM 5 1 ' 0 6 7,068' 2.75" Otis CX Concentric GLM 7 7,697' 2.75" Otis CX Concentric GLM 6 r 0 8 7,809' 2.625" Otis Q Nipple I 0 9 7,811' Otis Catcher Sub Otis RDH Hydraulic Long String Packer 7,801' A 315' 2.313" Otis Ball Valve 8 , B 9,859' 2.225" Otis Type N Landing Nipple 9 0 C 9,860' 2.25" No -Go D 9,894' XO E 9,895' GLM /GLV F 9,896' XO G 10,496' XO ' p" H 10,497' GLM / GLV . I 10,498' XO 1 11,065' Check valve roe 7,857' " " Perforations 9 5/8 " • ■ Top(MD) Btm(MD) Top(TVD) Btm(TVD) Detail 9,860 Squeezed 9,866' Water Shut Off 9,911' 9,921' 8,837' 8,846' 9,941' 9,971' 8,863' 8,888' 10,100' Squeezed MIR B ■ c 10,260' 10,275' 9,129' 9,141' D 10,280' 10,445' 9,146' 9,281' F Ir. 10,730' Squeezed G 451. 10,897' 10,987' 9,651' 9,725' H 1' 11,015' 11,175' 9,748' 9,877' Fill Tagged 1 la 11,104' , lig 7 dei " .� Revised By: JLL 04-12-2013 PBTD = 11,147' TD ;11,200' • • . H Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 31 -23 50- 733 - 20072 -00 167 -084 3/7/2013 3/13/2013 Daily Operations: 03/07/13 - Thursday MIRU slickline equipment. Installed BHA with a 2.30" gauge ring. NU lubricator and Pressure Test to 1000 PSI. Tested Good. RIH sat down at 275' WLM unable to work through. POOH Bumped up. Unstab lub. install 2.35" paraffin scratch, restab lubricator and RIH. Cleaned up area above and below 275' WLM (Otis ball valve located here) and POOH. OOH installed 2.30 gauge ring. RIH sat down at 2,180' WLM, unable to work through, POOH install 2.35" paraffin scratcher worked through tight area continued in hole and tagged Otis "N" nipple at 9,817' WLM (9,856' MD) POOH. OOH installed 2.18" gauge ring. RIH tagged bottom at 11,065' WLM (11,104' MD) POOH. RD unit for night. Well turned back over to production for night. 03/08/13 - Friday Install BHA with "N" nipple test tool. Wait for production to open well. RIH with "N" nipple test tool. Hit tight spot at 2,180' WLM able to work down to 2,397' WLM and stopped. Sheared off of test tool. POOH. OOH RU 1 -5/8" RB retrieval tool. RIH, unable to latch prong. POOH RU 1 -1/2" GG retrieval tool, latched prong POOH w /prong. RU 2 -1/2" RS retrieval tool. RIH latched test tool, POOH. RU and RIH with paraffin scratcher while pumping fluid to wash down. Worked tight area till nothing seen. POOH. RU and RIH with test tool again, still unable to get past tight spot at 2,397' WLM. Sheared off test tool. POOH. RU and RIH latched prong with same tool as earlier. RIH and retrieved test tool. POOH. RU and RIH with 2.30 LIB tagged tight spot at 2,397'. POOH and check impression. Had scale markings on one side of block with a small impression on top corner of block by scale markings. RU and RIH with 2.25 gauge ring to 3,200' WLM tight spots @ 2,397', 2,790' and 3,035' WLM able to work through each one. POOH. Called Pollard and had 2.25" and 2.30" Broach tools sent to platform on evening chopper. OOH lay down lub. Rehead retie knot and add more weight bar. Shut down for night. Well turned over to production for night. 03/09/13 - Saturday RU and RIH with 2.30" broach tool to clean area from 2,397' to 3,180' WLM. Continued on down to 9,800' WLM. Pulled back up to 3,200' WLM and work up to 2,380' WLM, making several passes thru this area POOH. RU and RIH with N test tool. Set down on N nipple (9,817' WLM) released tool and POOH, SI pressure on tubing 420 psi. Pressure up tubing with gas to 1000 psi. held for 1 hr. Pressure stable, no decrease on tubing string. Bled pressure down to 520 psi to leave tubing overbalanced to pull prong. RIH pull prong with 1 -1/2" GG. POOH with prong. RU and RIH with 2.5 JDC. Could not latch. POOH. RU and RIH with 2.5 RS, latched tool and POOH. Layed down lube, shut down for night. Well turned over to production. 03/10/13 - Sunday Start assembling BOP's and moving support equipment into work area to begin RU. Continued assembling BOP stack. NU BOP assembly on WH assembly. Hooked up accumulator to BOP stack and function tested blinds, and pipe rams. Cycled both sets twice, operated properly. No hyd. leads on BOP stack or accumulator. Set up work stand over WH assembly and secured BOP stack to legs of stand. SD operations for night. Well secured and production flowing well. 03/11/13 - Monday Complete RU of work stand, including all safety rails and ladder. Move pipe and lay out on pilings to number and tally. Measured length of all joints 31' 4 ". Talked to Reid Edwards and only running 38 joints (1,190.66') All XO's, Gas mandrels and check valve are 16'. Total length of string being RIH is 1,206'. (This will leave string 40' off bottom). Expro wireline RU and RIH with new spool of braided line to lube and straighten line. After 1,000' noticed a bad area in wire. POOH cut wire above bad area, re head wire, and RIH again. Production bleeding well down. Operations shut down for night. Well bleeding down. 03/12/13 - Tuesday Put together gas lift mandrel assembly and tighten all joints. RU elevators and bowl slips. Started RIH. Installed check valve on first joint in hole. Ran 18 joints, installed 1st gas lift mandrel between this joint and #19. Continued to RIH to joint #37. Installed gas lift mandrel between 37 and 38 joint of pipe. String is NU on Otis N nipple at 9,817' WLM using a 2.25" No Go with 2.30" packing stack and a G style fishing neck standing up. Total length of gas lift string from N nipple (1,206'). Once string was put together at surface___ with crane, braided line unit was hooked to it, crane lifted whole assembly out of slips, removed slips, NU WL Lube and RIH with string to N landing nipple. POOH. RIH with tubing slip stop. POOH. Left lube hanging on crane or mg ue o wind. Well SI for night. ST RD in morning. 03/13/13 - Wednesday RD wireline equipment. ND WH stack and prepare equipment to be shipped to shore. Well secure and turned over to production. . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg (P.I. Supervisor) Petroleum Engineer ,¡ L. /'1 '111L.\\.,\¿) L;i(f ¿l '\ Vi,,' \ i. DATE: June 23, 2006 THRU: FROM: Lou Grimaldi Petroleum Inspector ~SE? ~82GÚ~ SUBJECT: No Flow test GP 31-23 (short string) Granite Point Platform Granite Point Field PTD 167-084 I witnessed a No-Flow test on Chevron's well GP 31-23 (Short string) aboard the Granite Point platform. The test was somewhat long due to needle valves in the test fixture which was holding back pressure on the well. These were removed and the test was began again. .y~' I ran a shut-in and bleed sequence three times with similar results (as noted below). The well seems to level off at a sustained rate of 550 scf at 0 psi wellhead pressure. 0 . ..Ç.. .. _ This well appears to meet the No-Flow criteria. !\€;J¿::;;t- c' ¡'\C~lvlC4L::'~\Jé' ~+ d:J\1¿. c,!¿¿':;'!L:- Time Pressure Flow Rate Comments~J ' Kt''iti (psi) (scf) 19:00 1.5 200 Well flowing through flowmeter, Needle valves present ahead of meter. Gather equipment to rerig. Continue to take readings until equipment gathered. 19:30 1.5 200 Shut-in well to rerig meter assy. 20:00 4 SI Open well to Flow meter, Initial flow @ 1000 scf. Hose downstream of flowmeter to small (3/8"), Gather equipment to increase hose size. Cont. to take readings. 20:05 1.5 850 Flowing through meter. 20:45 >0 850 Flowing through meter. 21:00 >0 850 Flowing through meter. 21:15 0 450 Flowing through meter. 21:30 >0 700 Flowing through meter. Flow increased. Shut-in well to change hose to 1". 21:50 1.5 SI Open well to Flow meter, I nitial flow @ >1800 set. Throttle flow to keep from over ranging meter. 21:55 >0 825 Flowing through meter. Change to new meter. 22:00 >0 800 Flowing through meter. 22:15 >0 650 Flowing through meter. 22:30 >0 750 Flowing through meter. Shut-in well. 23:00 2 SI Open well to Flow meter, Initial flow @ >1800 scf. Throttle flow to keep from over ranging meter. 23:02 1.75 1800 Flowing through meter. 23:04 0.5 1350 Flowing through meter. 23:06 0.25 1100 Flowing through meter. 23:08 >0 950 Flowing through meter. 23:10 >0 850 Flowing through meter. 23:12 >0 700 Flowing through meter. 23:14 0 625 Flowing through meter. 23:16 0 625 Flowing through meter. 23:18 0 625 Flowing through meter. 23:20 0 625 FlowinQ throuQh meter. Shut-in well. 23:50 1.5 SI Open well to Flow meter, Initial flow @ >1800 scf. Throttle flow to keep from over ranging meter. 23:52 0.75 1600 Flowing through meter. 23:54 >0 1250 Flowing through meter. 23:56 >0 1000 Flowing through meter. Page1 of 2 No Flow GPF GP 31-23 06-22-06 LG.xls 6/23/2006 . . Time Pressure Flow Rate Comments (psi) ( set) 23:58 >0 850 Flowing through meter. 0:00 >0 825 Flowing through meter. 0:02 >0 800 Flowing through meter. 0:04 >0 825 Flowing through meter. 0:06 >0 850 Flowing through meter. 0:08 >0 850 Flowing through meter. 0:10 >0 825 Flowing through meter. 0:20 0 600 Flowing through meter. 0:22 0 600 Flowing through meter. Shut-in well. 0:54 1.5 SI Open well to Flow meter, Initial flow @ >1800 scf. Throttle flow to keep from over ranging meter. 0:56 0.75 1800 Flowing through meter. 0:58 0.5 1300 Flowing through meter. 1:00 >0 1025 Flowing through meter. 1:02 >0 900 Flowing through meter. 1:04 >0 850 Flowing through meter. 1:06 >0 850 Flowing through meter. 1:08 >0 825 Flowing through meter. 1:10 >0 800 Flowing through meter. 1:20 0 550 Flowing through meter. 1:30 0 600 Flowing through meter. 2:00 0 550 Flowing through meter. Shut-in well, conclude test and turn well back over to production Page2 of 2 No Flow GPF GP 31-2306-22-06 LG.xls 6/2312006 IIseo fJ-'l ' ,I r y~ <{ M~-r-e\ . 300 Airport way Kenaí, AK 99611 Phone (907) 283;'4230 Fax (907) 283-7766 E-mail iisco3@ptialaska.net STATEMENT OF PERFORMANCE Pressure Standards Referenced to NIST File TN822-256610-96, TN838-256609-96, P-8523 --. -".'- -----.-..--. ---.--.- DATE: CERTIFICATE NUMBER: PERFORMED FOR: PURCHASE ORDER NUMBER: MANUFACTURER: IISCO NUMBER: SERIAL NUMBER: DESCRIPTION: RANGE: Test meter Model: MANUFACTURER: SERIAL NUMBER: -.-. -TYP-E:-·--.._·- METER NUMBER Test Meter Readin @AVERAGE 56 psig, 70°F 360 SCFH 540 SCFH 720 SCFH 900 SCFH 1080 SCFH 1260 SCFH 1140 SCFH 1670 SCFH 1800 SCFH 03-21-06 032106A UNOCAL M2 ERDCO N/A No Flow Tester 1.8-18 SCFHxl00 --~-_._---,-_._~---- FQ10 BARTON 1239 TURBlNEn 7450-3273 NO-Flow Meter Reading @AVERAGE 56 psig, 70°F 550 925 900SCFH 1080 SCFH 1225 SCFH 1350 SCFH 1440 SCFH 1440 SCFH CFH _ U'_' n_____._____ , . II/} .-,,,",",, / r l'Oil''\.'{.j IIseo 300 Airport way Kenai, AK 99611 Phone (907) 28J-4230 Fax (907) 283-7766 E-mail iisco3@ptialaska.net STATEMENT OF PERFORMANCE Pressure Standards Referenced to NIST File 1N822-2566 10-96, 1N838-256609-96, P-8523 DATE: CERTIFICATE NUMBER: PERFORMED FOR: PURCHASE ORDER NUMBER: MANUFACTURER: nsco NUMBER: SERIAL NUMBER: DESCRIPTION: RANGE: Test meter Model: MANUFACTURER: SERIAL NUMBER: TYPE: METER NUMBER Test Meter Reading 02-13-06 021306A UNOCAL M2 ERDCO N/A No Flow Tester 1.8-18 SCFHxlOO @50 psig, 70 Deg ,F @50 psig, 70 Deg F Increments of 10% full scale Data from Meter under Test 180 SCFH Belo\¥ scale 260 SCFH Below scale 540 SCFH 400 SCFH -, 715 SCFH ---- 720 SCFH 900 SCFH 1100 SCFH 1080 SCFH 1800 SCFH FQI0 BARTON 1239 TURBINE 7450-3273 NO-Flow Meter Reading Flow t~st was halted for flows over I o~ potential over range of meter under test.. , " Attested b Rich Vin Zant MEMORANDUM TO: Julie Heusser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 10, 2001 THRU' Tom Maunder, P. !. Supervisor FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Granite Point Platform Granite Point Field May 10, 2001; I traveled to UNOCAL's Granite Point Platform and witnessed the semi annual safety valve system testing. I found a very clean platform with sign's of regular maintenance and much fresh paint in evidence. The Safety Valve Systems were tested. 9 wells and 26 components were tested with two failures. Ted Medley lead operator conducted the testing today, he demonstrated good test procedure and was a pleasure to work with. The 'SSSV on GP-50 failed to close. This is a repeat of the previous tests failure; lexpressed the AOGCC's concern for the repair & retest of the failures. The AOGCC test report is attached for reference. SummarY; I witnessed the semi annual Safety Valve System testing at UNOCAL's Granite Point Platform in the Granite Point Field. Granite point Platform, 9 Wells, 26 components 2 failures. 7.7% failure rate. Attachment: SVS Granite Point Pit. 05-10-01jc NON-.C .0. NFIDENTIAL SVS Granite Point Pit. 05-10-0 ljc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unoca~ Operator Rep: Ted Medley. ,, . ,, AOGCC Rep: John Crisp _~. Submitted By: John Crisp Date: Field/Unit/Pad: Granite Point Field &Plt. Separator psi: LPS 60 HPS 5/10/01 ii . i i ..i I i I iiii ii ii ii . ii I . . ~ .... Well Permit Separ ~ Set L~ Test Test Test Date ~ WAG, G~J, _Number ,,Number PSI PSI ~ Trip Code Code Code Passed GAS or CYC~ ~-~3~ ~9~i350 .... go "' ~0 33 p' " :~.~4.~:." P ....... OIL 'i'3-i'~ 1670210 60 40 ~' ' 40" 'P"' P' P .......... 0IL 31'13 1660550 - ,.,, , , , .~ t.. ,, , , ,, ,~ , , , .. ~ ,~ i ~ ,~.,., , 31-14~2 1002660 '~r2~}..:,~ ~ 1670840 60 ' 40 '.' ' 40' ' P '."'..~.p - ' ' .' ... ' 0IL 32-13~ 1920200:' "60'. ' ' 40 40 P P P OIL ~2-23~ 1951450 60 ' '~0' 34 ' p ~' p p ...... OiL . . ., . ~, ~ ,, , , ,,~ , , , ~, ., ..,, , ,,. ,., 44-14 1670620 60 40 36 P P P OIL 50 19204i'0" 60" ' 40 33~ ..... p ~ ' 8: ....... 0IL 5t 1920720 "60 .... ~0 "~35 .... P ..... P' " ~ .... OIL 54 : ...... 1960130 60 " ~0' ' '34' 'P P " P ' " OIL ,, . , , , ~ ,, ,,, .,,,, , , , ~, . ,,, , . , , ,~ . ,, , ., ~, .i , ,, .., , , ,, ,, , ~ , , ~ ~ , Wells: 9 Components: 26 Failures: 2 Failure Rate: 7.69% [~ 90 Day Remarks: SSV on well 11-13 failed to ho.ld.D,p, ~ gate, v..alv,e.~wi~l. ~ ~..r~i,,'ce, d.&,re-tested. "'~n Well ~P'50' fa'il~d t° CloSe, Ted Medley will contact Unocal Supervisors about AOOCC,S eoncern for the repair.& re...tes.t of..OPSO,s sssv.. ........................... RJF 1/16/01 Page 1 ofl SVS Granite Point Pit. 5-10-01jo i! MEMORANDUM TO: THRU' Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation COmmission DATE: December 7, 2000 FROM' John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Granite Point Platform Granite Point Field December 7, 2000; I traveled to UNOCAL's Granite Point Platform and witnessed the semi annual safety valve system-testing. I found a very clean platform with sign's of regular maintenance and much fresh paint in evidence. The Safety Valve Systems were tested. 9 wells and 26 components:were teSted with two failures. Ted Medley lead operator conducted the testing today, he demonstrated good test procedure and was a pleasure to work with. The AOGCC test report is attaChed for reference. Summary:. I witnessed the semi annual Safety Valve System testing at UNOCAL's Granite Point Platform in the Granite Point Field. Granite Point Platform, 9 Wells, 26 components 2 failureS. 7.7% failure rate. Attachment: SVS Granite Point Pit. 12-07-00jc NON-CONFIDENTIAL SVS Granite Point Pit. 12-07-00jc.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: nocal Operator Rep: Ted Medley AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Granite Point Field & Pit. Separator psi: LPS 60 HPS 12/7/00 Well Permit Separ Set L/P '.Test · Test Test Date Oil, WAG, GIN& Number Number PSI PSI' Trip Code Code Code Passed GAS or CYC, LE ll-13RD 1911330 ' 60 40 33 ' P · ' P P OIL 13-13 1670210 60 40 37 P (5) P 12/8/00 0IL 31-13 1660550 '.-"-G~,~ ~ ~ ~.\ ~,~. .. ~l-14RD2 ! 1002660 · · , · .31-23 i:O ;--;~'? 60 40 35 P P OIL 32-13RD 1920200 · 60 40 · 35 P ' P P ' OIL 42-23RD 1951450 60 40 40 P P P OIL 44-14 1670620 60 40 35 ". P P P~ OIL 50 192041'0 60 "40 35 e P (8) f~w,"~l,o.t_k~.~,~, oIL ~1 1920720 . ' -60 40 - 35. 'P P~1~- OIL 54 1960130. 60l'. 40 36 P P P OIL .. , Wells: 9 Components: 26 Failures: 2 Failure Rate: 7.7% El9o var Remarks: Well 31023 isa no'flow. 12/13/00 Page 1 of 1 SVS Granite Point Pit. 12-07-00jc.xls ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOFY: (907) 276-7542 June 20, 1991 Mr. Bren Dehn District Operations Manager Unocal P O Box 190247 Anchorage Ak 99519-0247 Re: No Flow Test Granite Pt. Platform Weli G.P.St. ~t-23 .Granite Pt. Field Dear Mr. Dehn: On June 6, 1991, a no-flow test was conducted on the subject well. A review of the test data indicated that this well is no longer capable of unassisted flow of hydrocarbons to the surface. The Commission hereby authorizes removal of the subsurface safety valve from ~iiiwelI GPS 31-2~ on condition that should any subsequest operations be performed that may alter the unassisted flow condition of the well, another no-flow test would be conducted to verify continued no-flow status for that well. Sincerely, Lonnie O~ ~-mith Commissioner BY ORDER OF THE COMMISSION LCS/MTM cc: Unocal Corp./Prod Foreman Area Supt Attn: Granite Pt. 260A Caviar St. Kenai, AK 99611 Ala.~ca Reckon A.~ri! 16, !990 Alaska Oil & Gas C:nsarvation C=~ission 300! Porcupine Dr. Anckorage, AK 99504 At,n: Ms. Elaine Johnson I have attached surface survey locations of the "Legs" and conductors for the four platforms in t~ke Tradinq Bay Unit as we!! as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, C- o · Regional Orillin~ ~anager GSB / !ew .o GRANITE POINT PLATFORM FROM NW CORNER OF SECTION 13, TION, R12W CONDUCTOR Leg#l · Leg#2- Leg#3- Leg#4' "Y" COOR. "X" COOR. WELL # FSL 2,544,566.00 263,297.33 2,544,572.08 263,294.75 13-13 2371 2,544,572.41 263,299.33 44-14 2373 2,544,569.75 263,302.99 33-14 & RD 2371 2,544,565.34 263,303.99 31-23 2366 2,544,561.34 263,302.08 31-14 & RD 2362 1.& 2 2,544,599.42 263,297.83 44-11 & RD 2360 2,544,560.67 263,293.33 Open 2,544,564.50 263,290.83 12-24 2363 2,544,569.00 263,291.42 32-23 & RD#2 2368 2,544,610.00 263,364.00 Compressors 2,544,543.33 263,408.00 2,544,548.16 263,403.42 31-13 2382 2,544,549.91 263,407.59 22-13 ' 2379 2,544,548.66 263,412.00 MUC#I-1 2391 2,544,544.99 263,414.41 MUC#I-2' 2386 2,544,540.42 263,413.91 32-13, 33-13 2390 2,544,537.25 263,410.58 24-13 & RD 2392 2,544,537.00 263,406.09 42-23X, 31-23 2380 2,544,539.58 263,402.42 11-24 2383 2,544,544.08 263,401.42 11-13 2379 2,544,499.58 263,341.33 FEL ,, 1267 1262 1258 1256 1258 1261 1269 '1269 1370 1375 1379 1381 1379 1376 1371 1368 1375 Form REV. 1-10-73 Submit *'Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. O,L l'f-fl GAS ~ WELLI~/~J WELL OTHER NAME OF OPERATOR UNION OIL CO. OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE ALASKA 99501 4. LOCATION OF WELL .At surface 2380' S & 1371' E of N.W. corner, Sec. Leq 3, Conductor 7 13. ELEVATIONS (Show whether DF, RT, GR, etc.) K.B. 95, above MSL 13, TION, R12W, S.M. 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20072 _ 6. LEASE DESIGNATION AND SERIAL N~. ADL 18761 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME UNION-MOBIL STATE 9. WELL NO. GPS 31-23 10. FIELD AND POOL, OR WILDCAT GRANITE POINT - MIDDLE KENAI 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 23, TION, R12W, S.M. 12. PERMIT NO. 67-84 )ort, or,Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) CHANGE OF PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS _OPERATOR. SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE=-Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. FROM: TO' MOBIL OIL CORP. UNION OIL CO. OF CALIFORNIA RECEIVED OCT 2 Division 0[ 0tl 16. I hereby certify that the foregoln_g is true and correct SIG , ; ~ TITLE DISTRICT DRICLING SUPT. (This sPaCe-~o~rSta~[e office use) APPROVED BY, A////~~/~R~ CONDITIONS OF VAL, IF ANY: TITLE See Instructions On Reverse Side Approved Copy Refurned Fornl ~.a.." SUBMIT IN DUPLICA%. 3TATE OF ALASKA (Seeo~herh. Mructkms on OiL AND GAS CONSERVATION W~LL COmPLeTiON O~ ~COMPLETION ~EPO~T AND LOG* W~LL ~ Other b. TYPE OF COMPLE~ON: WgLL OVER EN BACK RESVR. Other 2. NAME 0F OPERATOR Mobil Oil Corporation _ 3.- ADDRESS OF OPERATOR P. O. Box 17'34'Anchorage, Alaska 99501 ~. LOCATIOX or WrLL (Report locatioa clearly and in accordaac¢ witk~ any State requirements)* .~t. sur~ace(Leg 3 slot 7)2380' South and 1371' East of the NW corner , Sec. 13 TION R12W, S.M. At top prod. interval reported below 3164's and 2769'W of surface location At total depth 3502's and 3410' W of surface location Bottom hole closure 4888' @ S44° 13' 50" W 13. DAT]E SPUDDF_JD ~14. DATE T.D. RE~CHED 115. DAT~ CO'iVIP SUSP OR ABAN-D. 1-11-68 I 3-31-68 j 4-19-68 16. F-J-J~VATIONM (DF, RKB, 105' RKB 5. API NUMZRICAL C0~DE 50-133-20072 6. LF-~E DI~3IGNATION J~ND SERIJ~L NO. State ADL 7. IF INDIA~, ~LLO'I'I'EE 01% TRIBE NAAL]B 8. UNIT,FA~RM OR LEASE NA/ViE Mobil-Union State #1 9. WELL NO, Granite Point State #31-23 · ;10, FIELD A~rD POOL, OR WILDCAT Grani~'e Point - Middle Kenai 11. SEC., T., lq,, M., (BOTTOM HOL~ OBJECTIVE) Sec. 23, TION, R12W S.M. 12. P~qRV~IT NO, 67 -84 ~., Ga, ~rc).J~. ~-'v. c~s~GHE~, I +65' _ 4 INTERVALSDRILLED BY CABLE TOOLS 23. WAS DIi%ECTIONA3~ ~ SURVEY MADE Yes 18. TOTAL DEPTH, ~LD & TVD~9. PLUG, B/~CK MD & TVDJ20, IF Ai-ULT~LE COiVIPL., J 11,200~, 9886 W 11,147~; 9846 I ~urzace to TD ~. P~ODUCINO INT~VAL(S), OF T}itS CO.J~P~TIO~TOP, BO~O~%, ~E (AID AND Middle Kenai Sands Top=9670' ~; 8625'~D -~ ~ 987i TVD Bottom -~1,!80' 24. Tx~PF~ Ei~ECTEIC ~'~D OTH~JY~ LOGS ~U~% InduCtion Log, Sonic Log~ Dipmeter, Gamma-Ray Neutron, CBL 25. C.%SiNC. ~ECO~D (~eport all st:':.nJs set ix, wcL) 670 sox I it~MOUNT PULLED r8 i 70.59 ~ B ;.7 ~55 22 9 .5/8 ', 43.5 E 40~ N-g0 ~ 8061 ~ 12 1/41 800 sox TUBING REOOP~ 28. PERFOR~kTIONS OPLN TO P~ODUC~O~ (inter~a], size and number) 9911 to 9921 = !0' 10,897 to 10,987 = 90' 9941'to 9971 = 30' il,0!6 6o 11,176 ' 1~5' 10,260 to 10,275 = 15' 1Q,280 to'10,445 = 165' PRODUCTION DATE FIRST P~ODUCTIO~' $ P~ODUCTION METI{OD (Flowh~g, gas lif~, 4-22-68 [ Flowing 4-27-68 ~ 24 [ 56/64Jl~S'r~>'~OO FLOW, WBING' J~CA~LyG p~S'SU~ ICkLC~TD OI~BBL. 155 ~ ;}~ -- -~[ 1667 31. DISPOSITION O~'~Sold, used 70 el, ven'~'ea, etc.) 7813 7801 29. AC~D, S~ffOT, FiI~CTURE, CF~d[ENT SQUEEZE, ETC, D~-~TIi IICI']gRVA~ (MD) J AMOUNT 2~ND I<!ND OF MA~TERIAL US]KD i' · II I II ~I I II I IIII pumping--size and type of pump) OIL--EEL. GAS--MCF. GAS--?vZC'P, JlVELL STA~JS (Producing or Producing VcA%q~I~-IB~L. i GAS-OIL j 2 I 1207/724 WA~BBL. J OIL GRAVITY-~I I 2 I 41.7 tTEST WITNESSED BY Used for fuel and vented 32. LIST OF ATTACii.MENTS · History Core Description% Drill stem tests; Completion Diagram; Diagram of Junk in Hole 2.3. I hereby ~ertil")T-t~ ~iored°ing and'attached 'l~fbrmati'&n fa compete and CDr'Peet a. d~/ermtned'from 'aflYavailable ree'ords / , . . .... '.... .// rz-' ,.. ,d-. zz ,. *(See Instructions and Spaces for Additional Dafaon Reverse Side) ' ':: ! ~ ~ '~ ~, ; ? ... ' '~ ' General: This form is designed fc~r'"submitti~g''a cSm:plete and CoFrect 'k, el) completion report afld log on all' types of lands and leases in Alaska. :"-"'-~ i ~ ! : "- '" itemi 16: India:ate which elevation' is used as reference (where not otherwise sh0~n) for depth measure- : ' .... . ments given in cther spaces on th'is form and in any attachmentS.. ~ i ..:.....: - . "' . . . ' - . , . - - . · ' ~ .. ;,,i, ii: Items 20,- and ~22:: If this' well is completed~ for separate produCtiOn_ fr6m m.o_re .titan''~ on~' i'nterval zone --- (multiple co'mptetion),.so state in item 20, and-in item 22 show the prc'ducin~ interval, oi' inter~,als, : ..top(s), bottq, m(s) and name (s). (if any).'for only. the interval, reported in item 30. Submit a separate report (page) on. this form, a:dequately identified, for each additbnal interval ~to be seperately produced, show- ' .- . ing the'ackJitional, data pertinent to such interval.:.. . : ~ ~ ; . .. .,.,, C ' ° ' ' ~ .L - . .F 'l.J'em26~' "Sacks Cement": Attached supplemental records f0i' this well 'should show the details of any mul- ~dple stage cementing:and the location of the cementing tool. ' ~- _ :-.. :. ,.:.-~ ~ ~' Item 28: Submit ~ Separate completior~ report, on this fc~rrri for~ each ir~ter:val":io be separately pr°du~'~l. !~'- (See instruction for items 20 and 22 above). :,::.~.! [ ~ f i ........~: :_: 34. SUMMAF~Y OF FOR~iA'I?ON TESTS INCLUDING ]NTERVAL TF.$TED, PRESSURE DATA AIN-D fl_ECOVERIES OF OIL. ~,VATER AND MUD 2 . See Attachments _ . i ."Itl. CORE DATA. A3'I'AC,I BlllEF DF~SCRIPITZO~NTS OF LITIIOLOGY, POROSITY. FRACTURF~. APPAt~NT-DIPS ' AND I)~I'ECTEI) SIIOWS OF OIL, G.A.$ OR ~VATETI. ' See Attachments 35. GEX~LOGIC MARK~ ,:i NAM7~ ~1~ V'glVi'. DEPTli Three Finger . Coal ,, MEAS. 6350 6331 i '_ CO 5228(9.62 ) WELL COMPLETION REPORT ORIGINAL DRILLING OPERATOR Mobil Oil Corporation WELL N0o Granite Point State 31-23 FIELD Granite Point SEC. , 13 T.ION R. 12W ! Alaska STATE COUNTY LOCATION Leg 3 Slot 7 Granite Point SM Platform - 2380' South and 1371' East of NW corner Sec. 13, TION, R12W, SM LAND OFFICE LEASE ELEVATIONS 105 (K.B.) (MAT) ENGINEER GEOLO(~iSTJ. Mey, er and H. Hixon / / COMMENCED DRILLING 1-11-68 GEOLOGICAL MARKERS 3-31-68 COMPLETED DRILLING TOTAL DEPTH 11,200 PLUGGED DEPTH 11,147 duNKOrininal Hole See Attached Sheet Side T ack Hole - Top @ 11,192', Bottom @ 11,200 4-22-68 - ON PRODUCTION FLOWING/GAS LIFT/PU~PING (CROSS OUT UNNECESSARY WORDS) DEPTH PRODUCT ON DATA PRODUCTION CLEAN OIL GRAVITY TOTAL CUT J TUBING CASING GAS _ ' CLEAN OIL ~, BEAN SIZE PRESSURE PRESSURE MCF PER DAY J INITIAL 1317 B/D 41.7 .52% 48/64 i 145 1153/875 GOR [AFTER5 DAYS 1667 a/D 41.7 .13% I 56/64 155 1207/724 GOR CAS NG RECORD (PRESENT HOLE) SIZE OF DEPTH i TOP WEIGHT MEW OR SEAMLESS GRADE -~Z£"OF iNO,OF SACKS DEPTH OF CEM. CASING(A.P.I.] OF SHOE OF CASING OF CASING SECONDHA~ID OR LAPNELD OF CASING HOLE DRILLED OF CEM. IF THRU PERF$. 18 604 +65 70.59 New Seamless ~; 22 670 13 3/8 - 3993 +65 61- New Seamless J-55 16 2435 I ' 9 5/8 8061 +65 40 & 43.5 New Seamless N-80 12 1/4 800 7 11,191 7867 29 New X-Line N-80 8 1/2 1~82 PERFORATIONS , , , 7" 9911 11,176 1/2" I 1 12" Schlumberger $calloo ~un ,,, .,, ,,, Santa Fe Drilling Co. ELECTRIC LOG DEPTHS 598 to 4056 and DRILLED BY 8064 to 11,196 using Rig # 71 MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR Mobil Oil Corporation FIELD Granite Point WELL NO. Granite Point State 31-23 Sec. 13 % ION R 12W S.M. Date !968 1/11-1/13 1/14-1/15 1/15-1/20 1/20-1/23 1/23-1/27 DATE Signed Title -- C. C. Woodruff Area Engineer DRILLING A MIDDLE KENAI ZO~E WELL This well was drilled by Santa Fe Drilling Company using Rig #71 positioned over Conductor #7, 'Leg #3 of Mobil's Granite Point Platform. All dep~h~refer to the Kelly bushing~ 105' above mean low low water. Drilling 12 1/4" hole and Opening to 22" 0'/612' Spudded in at 1:00 PM, January 11, 1968 and drilled 12 1/4" hole 0' to 633'. Ran in with 11" O.H. and opened hole to 612'. Opened 16" hole to 22" 283 '/612' . Running and Cementing 18" Casing at 604'~. Ran 14 joints,-606', of 18" 70.59~/ casing with Baker guide shoe on bottom and Baker duplex collar on top of first joint. Landed shoe at 604' and cemented with 670 sax Class "G" cement with 2% CaC12. W.O.C. 12 hours° Drilling 12 1/4''' Hole 612'/4050' ....... Ran a regular drilling assembly and drilled 12 1/4" hole 612'/1002'o Ran ° a Dynadril assembly and drilled 12 1/4" hole to 1002'/1219' ~ Ran a regular drilling assembly and drilled 12 1/4" hole to 1219'/1820'. /tan a Dynadril assembly and drilled 12 1/4" hole to 1820'/1899'. Ran a regular drilling assembly and drilled 12 1/4'~ hole to 1899'/4050'. Conditioned hole for logging. ..Running Schlumberger Electric Logs; Opened Hole to 16" 612'/4050' Ran a Schlumberger IES Log and a Borehole compensated Sonic Log, Opened 12 1/4" hole to 16" 612'/4050'. Prepared to run casing° Running and Cementing 13 1/3" Casihg @3993'~ Running Sperry-Sun Survey. Ran 96 joints 3974' of 13 3/8" 61# J-55 buttress casing. Cemented first stage with 735 cu.ft. Class "G" cement with 3/4% TIC. (118-120 lb slurry). Cemented second stage thorugh D.V collar at 2230' with 1700 cu.ft Class "G" cement with.3/4% TIC and 3% Cat12 (118-120 lb slurry). W.0.C. 24 hours. - 1 - MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR WELL NO. Mobil Oil Corporation Granite Point State 31-23 FIELD Granite Point Sec. 13 T ION R 12W S .M. Signed C. C. Woodruff DATE Title Area Engineer Date 1/27-2/16 2/16-2/18 2/18-3/7 3/7-3/8 C.O.C. to 3993'. Changed mud system to fresh water. Ran Sperry-Sun gyroscopic survey. 246'/3990!. · Drilling 12 1/4" Hole 4050'/10:159,' Ran regular drilling assembly and drilled 12 1/4" hole, 4050'/10,159'. Coring 10:159'/10~162'.. . ~ Drilling 12 1/4" Hole 10~162'/10~217''. , Coring 10~217 '/10~226' Ran 8 7/16 Christensen corehead and cored 10,159'/10,162' in 3 hours. · Pulled and recovered 2' of oil sand. Drilled 12 1/4" hole 10,162'/10,217'. Cut core f~2 10,217'/10,226' in 5 3/4 hours, recovering 1 1/2 of oil sand. Drilling 12 t/4" Hole 10~226'/10~833'~ Fishing Stuck Pipe Ran 12 1/4 bit on regular drilling assembly and drilled 10,226'/10,833' Stuck pipe at 9371' while tripping out. Drilled up 9371'/9235'. Drilled down 9235'/9440'° Drilled up 9235' to 8740'. Drilled down 8740' to 8781' and stuck drillcollars Ran Dialog, pipe free at 8676' Backed off at 8646', could not pull out. Screwed into fish at 8646' and backed off at 8601'o .Pulled out and ran in with drill assembly. Cleaned out to 8601' and ran washover assembly. Washed over 8601'/8610' and stuck'washpipe. Ran Dialog pipe free at 8328' Accidentally backed off drill pipe at 2000' · ° Cut Schlumberger-line and stipped through Kelly. Screwed into D.P. and backed off at 8313' Conditioned hole to run 9 5/8" casing. .R. unn..ing 9 5/8" Casing to 8062'. Ran 192 joints - 8021 71' - of 9 5/8" casing with details from bottom to top as follows: 70 jts.. - 2888' - 43.5~ S-95 ST&C with shoe at 8062' and Baker Model G differential float collar at 7974'. 38 jts. - 1572' - 43.5~ N-80 8RD LT&C 78 jts. - 3306' - 40~ N-80 8RD LT&C 4 jts. - 171' - 40~ N-80 (including crossove~ jr.) 1 jO. - 41' - 43o5~,N-80 Bu~ftress 1 jt~ - 41' - 40~/ N-80 LT&C Buttress pin x long collar 2' - OTC hanger 192 jts. - 8021o71' ]2~_anded 40' ~elow KB MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR Mobil Oil Corporation FIELD Granite Point WELL NO. Granite Point State 31-23 Sec. 13 T ION R 12W S.M. Signed C. C. Woodruff Date 3/8-3/24 3/11 3/24-3228 3/28-4/4/ DATE Title J rea Engineer Cemented casing at 8061.'71' as follows: Pumped 400 bbl thin mud, PH=~ti~ mixed with lf~/bbl Baroid coat C ~2415o Dropped bottom plug and pumped 10 bbl sea water mixed with 50 cu.ft. 14~ gal slurry followed by 800 sax Class "G" treated with 3/4% TIC - 118# to 12(~ slurry. C.I.P. @ 6:17 PM.'J W.O.C.~ Setting Plug at 8320'; Sidetracking 8085'/10~804' WoO.C. 24 hours. Drilled out hard cement and shoe and ran in to 8320'. Pumped 10 bbl. water mixed with 10 gal. CW7 followed by 20 bbl. fresh water and 345 sax Class "G" cement. W.O.C. 20 hours. Tagged top cement at 7853'. Drilled cement in stages till hard 7853/8085'. Ran a dynadrill assembly and drilled 8085/8133'. Ran a regular drilling assembly and drilled 8133'/10~581'o Dropped ballpean hammer in holeo Drilled intermittently on junk 10,581'/10,804' recovering parts of hammer in junk sub° Drilled 10,804' /10,882 ' stuck pipe 4' off bottom while reaming tight holeo Fishing Stuck Pipe at 10~882' Ran Diaglog, collars free at 10,760'o Backed off at 10,730'. Ran in with fishing string. Bakced off at 10~525' while working torque. Screwed into fish, fired string shot and backed off at 10,728' leaving X-over sub from fishing string. Ran washover string and washed over fish 10,728' to 10,817'. Sc=ewed into fish at 10,728'. Ran Dialog string shot, stopped at 10,734'o Ran spud tool with no success. Backed off at 10,728', ran washover assembly and washed over fish 10,728' to 10,877'o Screwed into fish at 10,728' jarred and pulled fish loose recovering entire assembly. Drilling 10~882/11,.200 TD; Fishing Stuck Pipe @ 11~200 Drilled 10,882/11,200. Stuck pipe while rotating and picking up off bottom. Ran Dialog, pipe free_@ 10,955'· Backed off at 10,911' leaving 289'of fish in hole Ran washover assembly and washed over fish 10,971/{1,040. Screwed into fish at 10,911 and circulated through bit @ 11,200. Ran string shot and backed off at 11,021. Washed over fish 11,021/11,195. Screwed into fish and jarred without success Ran stringshot and backed off at 11,192' leaving 8' of fish in hole Conditioned mud for logging. , · MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR WELL NO. DATE Mobil Oil Corporation Granite Point State 31-23 FIELD Granite Point Sec. 13 T ION R Signed C. C. WOodruff 12W Title Area Engineer S ,Mo Date 4/4-4/5 4/5-4/8 P~u .... zng Schlumberger Electric Logs~ Reaming 10~740'/11~192' Ran the following Schlumberger wireline services: D~al Induction Log, Gamma Ray-Sonic Log, and Dipmeter 8060'/10,775. Reamed 8 1/2" hole 10,740'/11,192' in preparation to run casing. Running and Cementing 7" Liner @ 11~191' Ran and cemented 7" liner at 11,191' with details as follows: 80'joints, 3324', 2~ 7" X-line liner shoe @ 11,191', liner hanger at 7909', top at 7867' 1 ! Pumped 100 cu ft water followed by 1300 cu ft cI~s-G cement with 3/4% TIC ! First 200 cu ft of slurry 206 to 21~J/ cu' ft the remainder 117 to ll~/cu, ft ~ W.O.C 23 hours t~agged top @ 7544' D O C~ t~ 7867'and tested lap with 3000 psi ~ OK. Ran HOWCO RTTS and Set pocker @ 7801' Tested lap with 5000 psi OK. 4/8-4/10 i D.O.C.; Running Schlumberger Logs and Sperry-Sun Survey ~ D O.C. to 11 191' Ran Schlumberger cement bond log 7860'/11 194 ~ Ran Schlumberger Gamma Ray-Neutron Log 9500'/11 194' Ran Sperry-Sun Gyroscopic ~ Survey 3700'/11 192' ' · 4/10-4/15 ~ R~nning W.S.O. ~ .'s @ 10~730'~ 10~100', 9860'. ~ and 9,866' WSO ~1 - Shot 4 1/2" holes @ 10,730', set packer at 10,691', opened tool for two hours w/gas to surface, recovered 19 bbl_ gas~cut oily mud. Squeezed with ~ 24 cu. ft. Class G. Cement, 5500 psi. · WSO ~2 - Shot 4 1/2" holes @ 10,100', set packer at 10,076'. Opened tool for two hours w/light blow, recovered 6 bbls. slightly gas cut mud w/trace of oil. ~ Squeezed with 34 cu. ft. Class G. cement, perfs, brok~ down w/4000 psi. ~ Squeezed w/57 cu. ft. Class G. cement, 6500 psi. -4- MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR WELL NO. DATE Mobil Oil Corporation Granite Point State 31-23 FIELD G~f'anite Point Sec. 13 T ION Signed C.C. Woodruff R 12W Title Area Engineer S,M. Date 4/15-4/i9 4/19 W.S.O. #3 - Shot 4 1/2" holes @ 9860"~ set packer @ 9825, opened tool for two hours w/weakblow recovered 35 bbls. of slightly gas cut mud and fresh water. Squeezed w/85 cu. ft. of Class G ~Cement, 5500 psi. Drilled out hard cement from 9783 to 9865. W.S.O. #4 - shot 4 1/2" holes @ 9866, set packer @ 9826, opened tool for two hours, blow died in 10 minutes for a dry test. D. O. C.~ Running Strings of. 2 7/8" and 3 1/2" Tubing Drilled out cemenn and retainers 9997/11,19.1. Displaced mud with seawater and seawater with diesel. Ran 2 7/8" tubing string with details as follows: 312 joints of 2 7/8" 8R tubing including Otis R.D.H. 9 5/8", 2 7/8" X 3 1/2" hydraulic packer and 9 joints of concentric tubing. Ran with 67 joints - 2059' - below packer set at 7803. Placed ball valve at 315'. Tested string with 5000 psi O.K. . Ran 3 1./2" tubing string with details as follows: 248 joints of 3 1/2" buttress tubing including 3 - 6' pup joints, hangers, 6 mandrels and ball valve. Tested string w/5000 psi, O. K. Perforating For Production Perforated the following intervals w/Schlumberger 2'J scallop ~uns: 9911-9921; 10,260 - 10,275; 10~280 - 10,445; 10~897 - 10,987; 11,016 - 11,176. Rig released at 12:00 Noon 4/19/68 - -5- Mobil Oil Corporat. ion Well Granite Point State #33-14 Core #1 - "B" Zone Described by H. C. Hixson Interval Cored: 10,522' - 10,543' Weight: 20,000 lb; RPM: 60; Pump: 28 spm Drilling'Rate per Foot: 10,522 - 523 10,523 - 524 10,524 - 525 10,525 - 526 10,526 - 527 10,527 - 528 10,528 - 529 10,529 - 530 10,530 - 531 10,531 - 532 10,532 - 533 10,533 - 534 10,534 - 535 10,535 - 536 10,536 - 537 10,537 - 538 10,538 - 539 10,539 - 540 10,540 - 541 10,541 -' 542 10,542 - 543 20.minutes 8 minutes 9 minutes 12 minutes 13 minutes 8 minutes 6 minutes 8 minutes 17 minutes 34.minutes · 24 minutes 20 minutes 20 minutes 27 minutes 19 minutes 20 minutes 22 minutes 17 minutes 18 minutes 22 minutes 22 minutes GENERAL DESCRIPTION: Sandstone and conglomerite - light tan oil staining, no free oil; medium to. coarse sand with pebbles up to 1" diameter, conglomeratic zones composed primarily of well sorted pea sized gravel; sand and gravel subrounded to rounded; sorting fair porosity fair, permeability poor; hard; slightly friable; sand composed of 70% quartz and feldspar; 20% lithic fragments, 10% silt and clay. Very light tan cut blue white natural fluorescence bright canary yellow cut fluorescence. - 1 - 10,522' :L.: ..... ~' ........... 10,523 · ~'.. .:~ ;'~--i :" ~.) 10,526 ~' ..- . .'.~ ~.-~ x.....7 :.~} ~-~.--LC 10,527 0,s2s :,i'.- -.'~ 10 529 conglomeratic sand conglomeratic streak Pebbly sandstone - pebbles less than 1/2" DESCRIPTION OF INTERVAL 10,525' - 10,528' Sandstone: Light tan oil staining, fine to medium grained; subangular; sorting fair to good, porosity fair, permeabili- ty fair? (high % altered clay matrix, probably altered feld- spar), sand composed of 60% quartz and feldspar, 20% dark. volcanic's lithic fragments; 10% mica-primarily muscovite with some biotite 10% clay matrix. Sand is veined with Bitumen. In general this dandstone is not as clean as that in similar cores in the field. Pebbly sandstone - pebbles less than 1/2" some parts.are actually a fine comglomerate poorl~ sorted - 2 - 10,532 t0 533 10 534 107537 10~538 Conglomerate and conglemeratic sandstone some zones of pea sized pebbles° Ail pebbles well rounded. Conglomeratic. and sand - conglomerate composed of pea sized ~ebbles - Occasional thin layers of sand. Pebble size is very consistant and pebbles are well rounded° -3 - Mobil Oil Corporation Granite Point State 22-13 Core No. 1 - "B" Zone Described by: H. C. Hixson Cored Interval: Recovery: RPM = 50, Weight = 17,000, Pump = 35 pm Coring Rate - Min./Ft. 8792-8793 = 28 8795-8796 = 34 8793-8794 = 28 8796-8797 = 12 ~ 8794-8795 = 28 8797-8798 = 32 General Description 8798-8799 = 36 8799-8800 : 36 8800-8801 = 25 8801-8802 = 16 8802-8803 = 37 Conglomeratic sandstone; v/light tan oil staining with no free oil; grain size ranges from medium to course sand with included pebbles, interlayered with con- glomerate - pebble sizes range from less than 1/4"~to 3"+; fair sorting in sand intervals v/poor sorting in conglomerates; porosity fair; permeability fair to poor; subangular sand and sub rounded pebbles; hard, slightly friable; sand composed of 70% quartz and feldspar, 25% dark lithic component including chert~ volcanics and occasional siltstone; and 5%+ silt and clay matrix; non calcareous; slight Kerosine odor, bright pale yellow natural fluorescence; v/light brown cut, pale blue white cut fluorescence. 8792 I'~ .':o-'?-~:7. a'8793 o. :o. -.o. .:~. 8794 · ,~ -'.... , i'.¢ 3;..-.' ~~ 8795 I °.'.-~! I ~ .o:°'r.i 8796 '.:oo' ~oo0~ 8797 "'~'." ' 8798 ~'~ -' i' '~ '. '. : 'J" 8799 i' ~- '~x 0'2 "-'"~ ' d 8800 k0~.._A_~ ~_! 8801 o~° o o 8002 '~-"- 0 ' ~':* '?;'~'-"'-J 8803 conglomerate - poorly sorted, aver. size pebbles 3/4" Distinct bedding at contact Sandstone w/occasional 1/4''+ pebbles Distinct cong. - sand contact. Max. apparant dipt at contact 30° Clean well sorted sand w/very few pebbles. Portion of cobble larger than size of core Conglomerate w/pebbles 1''+ Interlayered sand and v/small pebbles max. apparent angle of bedding 30° GRANITE POINT #31-23 April 15, 1968 WSO TEST #1 Shot 4 holes at 10,730'. Ran HOWCO hydrosp;.-i;'~'- t~.:~..'~' on 3248' .of 3 1/2"DP and 7424' of 5" D.P. Set pack,,?.;~ at i0~691'. Test tools included an inside recorder at 10,686', an outside recorder at 10,700' with tailpipe to 10,704'. Opened tool at 2:30 PM for a two hour flow test. Had a strong blow with gas to surface at end of test. Reverse circulated recovering 19 bbl. of gas cut mud with a scum of oil. BOTTOM OUTSIDE RECORDER BOTTOM INSIDE RECORDER IH = 4694 IH = 4679 IF = 167 IF = 165 FF = 944 FF = 961 FSI = 3762 FSI = 3743 FHS = 4683 FH = 4667 'WSO TEST #2 Shot 4 holes at 10,100' Ran HOWCO hydrospring tester on 3248' 3 1/2" D.P. and 6808' 5~ D.P. Set packer at 10,076'. Test tools included top inside recorder at 10,066', bottom outside recorder at 10,085' with tailpipe to 10,089'~ Opened tool at 4:30 PM for a two hour test. Blead off hydrostatic - well dead. Blow began to build very-slowly. Had a very weak blow for first hour. Blow developed to medium strength at end of test, 6 lb. recorded at bubble hose with no gas to surface. Closed tool at 6:30 PM and reversed out a calculated 864''rise or 6 bbl. of slightly gas'cut mud with small amount of oil. Pressures recorder on bottom out side recorder. BOTTOM OUTSIDE RECORDER IH = 4396 IF = 111 FF = 389 FSI = 2602 FHS = 4369 GRANITE POINT #31-23 WSO TEST #3 Shot4 holes at 9860'. Ran HOWCO hydrospring tester on 3248' of 3 1/2" and 6557' of 5" D.P. Set packer at 9852'. Tools included a top outside recorder at 9815', bottom inside recorder at 9834' with tailpipe to 9838'. Opened tool at 8:55 PM for 2 hour test. Had a weak blow. Closed tool at 10:55 PM. Reversed circulated recovering 35 bbl. (by mud pit measurement) of slightly gas cut mud with slight scum of oil and a small amount of clean fresh water. BOTTOM OUTSIDE RECORDER BOTTOM INSIDE RECORDER IH = 4241 IH = 4253 IF = 55 IF' = 56 FF = 769 FF =~ 772 FSI = 4003 FSI = 4011 FH = 4186 FH = 4198 H. C. Hixson HCH:sw -2 - ........................................................................................ 5Ui~VEY,'TABU LATION"'SHEET : MEASURED CORRECTED DEPTH VERTICAL DEPTH TIME COURSE TOTAL DIRECTION OF INCLINATION OBSERVED CORRECTED N -E SHEET NO. SURVEY JOB NO. SURVEY DATE MEASURED COURSE DISPLACEMENT TOTAL DISPLACEMENT NORTH SOUTH EAST WEST .2.5 .o~ ( - DONE BY: iCK. BY: ~UI'~Vi'- Y I /:~UL~ I I{,JI'~ ~i-II=.l-- I N ~ELL ~0. 5-?A~F~ ~ I ~ ~~ w i~ sURVE, --,E-O ~ ~ ~,J ~'te--- ! ~ / ',. + ~ DATE / - ........ _ MEASURED DEPTH VERTICAL DEPTH ANGLE DIRECTION O? INCLINATION MEASURED (;OURSE DISPLACEMENT TOTAL DISPLACEMENT :ORRECTED OF COURSE TIME INCLIN- DEV. COURSE TOTAL COURSE TOTAL ATION OBSERVED CORR. CORR£CTED NORTH SOUTH EAST WEST NORTH SOUTH EASt WEST I I '~'-~°° '~3'q~ ~'~ /~ Z'~ ,,. ~ ........ , ..... ~_ , ~ ~, ~ c,,O .-, -{~]~--. ~ ' - -~'"--; ..... !o:~. !~ ~ ' >~,1~ ~.,~, DON E ~Y: CK. BY: ,,,,, ................ , ,, ,,,, , , ,, ' JOB NO. . MEASURED ,i i CORRECTED DEPTH VERTICAL DEPTH ANGLE DIRECTION OF INCLI NATION MEASURED COURSE DISPLACEMENT TOTAL DISPLACEMENT , OF COURSE _ TIME INCLIN- DEV. ~ TOTAL ~OURSE TOTAL ATION OBSERVED CO~. CORRECTED NORTH SOUTH EAST W~ST NORTH SOUTH EAST i WEST - ~ ........ ~. , ~, 4 &t58.~ ~:,7.:-~, .... , .... z~:~ Pt/ ~9,/~ : - .-.) ~. -~ 9, ~8 ¢~ -, l %.:/e, ,.,,,,, ......... ,. , ~, 9 :'~_ :, ,, . I .... ...... . .... , ,, ...... ..... , , ..... ~ ........ CK. BY: } -I · ~ORIL OIL CORPORATION " PAGE t r GRA'N'I TE' -~'O'I ~q~ ............................... ,"": ........... . .......................................... - ~,E'l~:['t ~'~C'-SECT ..... IoN C U~iP-GTifD'- ~L(;XO~'_ ELO~uRE ALASKA -- ..................... ] ............................................... & ..................................... - ............................ .... ' ................ ' .............................. . ...... z ..... 2 .................. ........................ ~8~ B_T___S.W~%. ~?E.~:_._¢~_~_v ~:Z~. ?"~ ~ ._ C0~.4 P A.~'~ ~ .......... SP--~_T_ ~ 6 2 ~ 1 .... . ...... · .......................... !1 ' 'TRUE INCLINATION DIRECTION DOG-LEG 'RECTANGULAR COORDINATES MEASURED VERTICAL SEVERITY VERTICAL DEPTH DEPTH DEG MIN DEG ' DEG/!O0 SECTIONNORTH SOUTH EAST' WEST ~000, 3718,7~ 26 45 S ~0 W 0,00 -12~7,98 -959,57 -803,~0 ..................... ~_~0.0.., ...... _3_8..9.:5.....9/¢_ ............. 2_¢_ .... o_ ............... _6._..& !.._>¢ ..................... O. ~ ¢ 8 ..... :: 1 ~ ¢~ p ..5 ~. .................................. ~ ~ 0 2.~..0¢ ............................. ,.8 5 . 4500, ' 4159,58' 28. 15 '.]' S 42 W '-'0,69 '-!483,48 - . -11~7,57 -q~8 16 ...................................................................... . ................................................ . .¢_? _ 4600, %247,67 28 15 'S 42 W 0,00 -1530,77 -1172,74 -989,d3 ~800,. 442~,85 28 15 S 42 W 0,47 -1625,39 ' ' -1242,53 -105~ 5000, 4600,85 27 30 S 42 W 0,68 -1718..~A~ ............ -1~11,18_.....~_ ............. -.1_~1_.6~.-(0 5100, 4689.14 28 0 S 41 W 0.68 176';.3 z ............................................................................ - p 4 -13+6.61 -1147,~0 z" ~2o0. · ~777.~,~ . ' ~'8- '0 .... : ....... -~--'~-4--';~' .............. f';'~'O ........ z'~-~-~-,--~-t .............................. ~-i-J~'d';-'~'~ ................... .--'z'fZ-~'O~'~ ~ ..................... ; .... ~ 5~00, 6875,32 . 28 SO 5 ~5 W 0,68 -.-~860,00 ' -Z6~6,~2. -Z2~,8~. 5/,_0_~_~, .... S_R~.~., _BP_ 'Z ....... ~.8__~ .............. ~_...S_~ __W__Z ....... ~..~_ ¢.~: ..... :.~ R_~_Z t_ ~.~ ............................ ~.~ ~_SZ..~_8.6 .................... ~ ~_Z Cf.Z.,_.~ t _._ 5500, 5040,87 28 45 5 46 W 0,54 -~9~.78 -Z~SZ~28 ............................ .~..¢_q_0_¢_ .......... k!z ~ ¢_ ~_% ........... ~.~_..g_ ........... ~ ~¢_.~ ................ R~ .Z.~ ...... .:..~P.¢'; ~.~ ¢. ......................... ~_! ~!.~.~.~_ ~_ ...................... :..!.~.' !.'~. ~_?.~ ........................ .................. _~...7 ~_ ¢_ ..... ~ ?.~ ~_ ,_.~ R ............... !R....!.~ .............. ~_.. ~. %. k., ........... P..~_.~.~, ...... : Z Q ~ .t. ~ P .......................... r.t ~.¢ %t.~.~ ........................... , Z.s s ~ · ~ z ~8o.o.. 5soz.6z 2~ so . s ~ w o.z~ -zzoz.s~ -~8~.sz -~s86.~ ................... .......................................................................... - ' 6000, 5677~2 ' 29 ~0 S ~5 W ' 0,69 -2200~06 -~¢-~. 6 00. 526 .9 9 +5 S 49 ~'1 t.99 -2249.51 ......... :'i5'8'g-,'5'~ ..................... :i-~9~':'~'8 ................. ........ <.L_ _:-. ......... : ....... ~ ............................................. J.~ L...:. 2JJ~.~_~..L ............ 2' ....................... L ..' ...... ~ .......... r,:U,~L r.j!L CORPORATION ..... : ' ~ ' ' P AG E 2 .............. GRANITE. ROINT.._STATE._31-23 ' APRIL 10 1968 ..... SURVEY'DATE .- GRANITE POINT . VERTICAL SECTION COMPUTED ALO.NG CLOSURE ...... ALASK,~ ................................................................... ' ] ............ : ....... ] .............. . .............. : .................................... _ : ....... ............................................................................. SPERRY. SUN ..WELL .SURVEYING COMPANY .......................... SU-3-16261 · ~._ RECORD_JOE .SU~VEY ........................................... L.T_RL;-: ........ INCLINAT_ION DI.RE~TION .... DOG-LEG ................................ 'RECTANGULAR COOP, DINAI'ES · . ..................... N"E.ASUf~ ED VERTICAL SEVERITY VERTICAL ...................... DER.IH .............. DEPTH ............. D EG ]M.I_N. ..............DEG. -DECZIO0 ...... SECTION ........ ~OR]'H SOUIH ..... EAST WEST .................. ,.36 ................... ul.756..~8 .............. -1562,29 .................... · 98 -1791.57 -1597,38 · 59 ........................ ~1.826.~6 ......................~!63.2._~_6 ................. ..59 ........ _-...1.. 2. 1' _ ................. 1667.82 _ ......... 85 0 ....... - _. · 53 -1896.1 . -1704.39 ..47 ........................... ~. ! 9 ~ 0_. 21 ......................... ~ _1_7 q. 0 · .~_ 5 ,41 · -196~,31 -1777 ........................ 63,00., ........ 5.7.3.7 · 7_9 ................. .39 ....... 0.- ............. .,.S....~.5..W ......... . ....... 0 ,.74 ....- 2.348 6400, 5824,61 29 45 S 45 W 0.24 -'-2397 ...... :_ ........ 6_5.0_0.,_ ......... 5_9..1_.!_:_ ~ 3_ ................. 2-_.9_ .._45 ............... '_S. __~.5_._!W ............... O :.. 0_0 _~. 'T 24 _47 ............... 6.600, ....... 5.99_8 :.0.3_ ................ _3_Q ....... 0_ ............. .S._45._?I ............O~ 24 ....i. 72497 6700, 6084,64 30 0 S 47 VI 0,99 -2547 .................... .6 800., ..... :.6.! 7.~...8_4 ........... ].._3..o~ ..... 0 ................... S_ ..~Z ..W ........ ~ ...... _o_. o o - 2 5 ~) 7_ 7000, 6~44o66 29 45 S 47 W 0.24 --2696,~8 -1998,15 -ljl$~,~'l · 7~'oo. 6~+s~,~ 2_.9_._$_~ ........... _S_~.>_~___W ..................... ~ ......... - ............................................................................. 1 10 r-2745,67 2030,21 ................................................................................ - ~_~_~ 0.~_s.~ ...................... ................ .7_2.QD_, ....6518,95. 29 30 S 47 W 1 O1 -2794 85. · -2063,79 -1886.70 ' 7400. 6694,08 · 28 45 S 50 W 0.99 -2891,~'9 .............................................. .r_~.!..2_ Z~...~ .5. .......................... .r ! ~ S.~._,_~ ~ ..................... , 7600. 6872.~6 26 0 S 42 W 2.~1 -2981.~ , -2192.07 .............. _7.8.0_0... ...... 2_0. 5~_.t. 0.5 .........2 L__i 5 .............. _~.__9. 2__Id___] ....... 1 _t 09 ..... r 3.071 · 40 ........................ r.225_8_ ~ ~. 5 ....................... r. 208. 3 ~ 2_ 1 ..................... ............. ~9_9q~ ....... Z.8.8.~,9~ 29 ~ s ~ w ~5o -3~s~,~5 -=:~,zv' . -2~5o,~'5 _ ................................................ ' 8100, 7312.12 30 30 S 39 W 2,61 -321q 90 -2367 63_ -2182.50 8200, 7397,8~ 3~ o 8800, - 7482,64 32 0 S.~W ' i,12 -3320,40 -2457,67 -2235.~2 .......... - ............................................................. ~ ........................................................................................... 8400, 7566,74 32 45 S 26 W 2.26 -3371.78 -2506.29 -2259.23 .......... -6'-~' 6o-: ..... -? ~ g'e-Th-9----- :"~-5-'-,q%- .......... &'-2-7"--W ...... ~"-i-: 'i4 ..... :'s4 ~. a 4 ........................ : '2-~- ~' 5 ] ? 9 ................... 8600, 7731,81 35 0 S 27 W i 25 -3479 63 · _ · -2606.90 .............. . _ ................. G.RA,{}_I_TE POI,'.LT ST._AT.t-~. 31.-__23 ................... ] ..........................................................AF?R.IL._I_O .1.958 .......... SU:~V[ZY GRANITE POINT , VER.'F. ICAL SECTION CO,";PUTED ALO,qG CLOsu',~E .............. ................ ALASKA. ..... ~_ ............................................. . '. . _ ............ . . ..................................................................... SP_E_R!-~Y__._SU~_.WELL .SLJ~F_E¥ I?!G. CO~,!~ANY ........................ 5_U_-_3-1626_1 ........................... · ....... : ................................................................... .R E.C O p, D_Q E._.S.U R !/EY .................................. ............... ' ............. i___TRUf ...... I__N_C__L__I_~.j_A.I_I_Q~! .... D_I._R.EC_T_IO~_. D0_G.'TL EG .. - ' .~E C_T.A_~ G uL A R_... COO il D I ~'_~AT.E S MEASURED VERTICAL SEVERITY VERTICAL DEPTH DEPTft DEG HIN DEG DEG/iO0 SECTION NO~TH SOUTH EAST WEST ............................................... -_ ................................................................. -_ ............... , .... · .......................................................... ...................... fi_7._00_: .......... Z_8..1_ .2.:_9.6 .............. _~5 ...~ % ............. _S_...29..._?.,' ........ :_ . _1., 37. .......-3526.,.0P ........................... ..-._ 2_6.58,00 - 2 ~ ~ ~, a 2 - 8800, 7893,35 36:30 S 30 W 0,95 -35<93,66 -2709.51 -2368,b6 ........ - ............ 8_9~.0..,_ ......... _7. 9._75.. , _2 6 35 0 S 32 W 1.90 -3649,71 -2758,15 -239~,9,5 ......................... 9 ~.0._0__.._ ...... _~_0..5__8.~.... ~+_ ~ ................. _3}_h..5 ................... ...s_~_~...._!,::1.~7 -.~70:+. 2 ~ -280~.75 9100, 8143,45 31 45 S 34 W .................~2-.0'/ "3':/5'~';99 ........................... -'28'~'~5,5'7' ......................... 9200, ,' '8228.02 '32 15 S 36 W '. 1o1-! -'3808,80 -2891,55 ' · .9300, "8312,82 32 0'3 S 39 W 1,61 -3861 58' 2932 73 2523 35 ............ r ....................................... - ............................ z._ ........................ $ ~ ...................................................... : ....................... ? ................................ :... 9600, ':8397.86 31 65 S 39 W 0,25 ~-3913,98 -2973,62 -'2555.47 ................... ?_5_.0_9...,_ 8482',20 32 30 . S ~1 W 1o30 -3907,6'2 ' -3014,11 -2591,72 ................................... ;"'.-7': ........................................................................................ ::,i ................ . ............. .... ' .......... ., .................................. Z .... i., ...................................... 9900. 8820.01 31 45 S 56 W 2.12 -4180.14 -315~.26 -2752.48 .............. 5 ..... tOb'O0'~ .... : ..... ~'b'o"~T~ 8--= ............ 7'Y5 ........ -o ................. ~--g'~-""N ................. ~'.-g4 ....... ~'a'S'~-.-o'-~; iOlO0. 898~,78 - 34 0 S 61 W i 93 -4286.58 -3210,23 10200 9070,I7 i 10~00. 9153'07 ............. 3-4--'6- ............. -S-64 w 0.7~ -4391.~+~ -.32'~-~'7§'6- ....................... ' 10500, 9316.40 34 45 S ~B W .......................... - .......................................................... ~,,99 -4500,74 ' -3'312.20 10600, 9398.31' ~ "0 ............. -~""~§'-'~,i'-7 ................ 0"; 24 ....... T/~555'. O~ ................................ ~.'3'3~"-§-'i' 24 ......................... 10700. 9460.2~ ~5 0 s 6~ w 0.00 -4~,0~.~<, 10800. 9562.14 35 0 $ 62 W 10900..9644,,06 B5 0 S 63 W 0.5'? "-L~'7-']~-2"~ ............................... --3417~"--..5-2 ........................ 11000. 9726,22 ~4 45 S 62 W 0.62 -4772,57 -3444.01 -3304.15 ._ . ................... . . · ............. GRANIT. E.PO!NT.._STATS2- 31-23 ' APi2. IL 10 1'968 GRANITE POINT VEi~TICAL' SECT [OF~ COv, PUTRD ALO,xG CLOSUi~ ............. ALASKA ..... :_.; ................................ : ..................................... : ........ ~ ........................... : ............... : ..................................... - : ............... SPERRY_. SUN ..WELL. SURVE.Y I ,~.""G . COMPANY · RECORD OF SURV. EY ......................................... :.._TRUE ......... I NCL.I :NAT I 0/'I .... D_I.RECT_I O.q DOG-LEG ....................................... ;..RECT A,NGULAR .COORD I HAT ES ~EASURED VERTICAL SEVERITY VERTICAL ...................... D.F.P T.H ............ D. EP_T.H ...........D F___G. L.~!. I ~ ................. DEG ............. DEG/_I O.0 ........SECT.IOF~ .......... NOR.IH ...... sO_ U.T.H .................. 1.1100 ........... 98D._7 · ! 2 ............... 3.6 .... 0 ............... S. ,62_ _W ................ 1 · 2(+ ..482.8 · 5.z~ ...................... _- 3 zk71 · 61 ..................... ,-_ :~. L~ 5.6, u~4 ................. 11200. 9885.65 38 15 S 60 W 2.55 -z+888.12 -~502.56 -~09.65 · *** THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THE TANGEN'F'IAL OR CHOP, D METHOD *~,:-** HORIZONTAL DISPLACEMENT = z~888,12 FEET AT SOUTH z,~+ DEG. 13 IX';I~N, WEST(TRUE) .. : ........................................................................................ . . _.. .................................................................................................................. ~:L..-.=_: .................. L~ ............ _' ..... ~_ ........................................................ - ............ .-- L~ T- A.P.I. CODE · 50-133-20072 Re}ease Date ~-19-70 _ . State of 'Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS' Petroleum Branch INDIVIDUAL WELL RECORD Sec._, ,(13;) 23 _,_, ,~ ,. _ _=_ _ _ - : · . -__ S Meridian Permit No. 67-84 Issued 12-18-67 , : : : . ._ _: - _ .- Leg 1, Slot 4, Operator Mobil 0il Corp.. Location (Surface) 2366' FI~ & 1256' ~,~L, Sec. 13 · = _ __ -:- _ _ _' ~. :~_ _ .. _ .: : _ Lease No'.' ==-' "ADL--i876i . - or O~r.,.,,~ ..... ~:a~ice.~_o1~c:scace__- Loc., (Bottom) 660~ ~'& ~980" ~E:,~ Sec. 23 Weli No. 31-23 Area Granite Point Field ~ PB~ 11,147 ~pa~ Date .... 1-11-68 Drll ling Ceased 3-31-68 Total Depth~ ~ ~=_=. · .... ~ ,-~, ,~ _~ _ ,~,, ~. i ._i .... , Suspended Abandoned Eleva[ion 106 ~-~ ~L : - - :~ := -~ -': _ -~" - ~ - - ' ~'-%'-~'~ -- ':' - -' - ~ -" ~ ~ - : ~ -- Completed (F-¢¢/¢~ 4-19-69 IP 1667 B/D, Grav 41.7° APl Cut 0.1 , Gas MCF/O, Bean 56 /Sq CP psi, TP i55 psi - - --- '== ~6~ 2~b-"-75' ~ 1'~'~80' -44~~; 18"-70.59f~ ' 606" 670 10,897"-987~ ~ ~ ~ ~ ~__: ~___ .:~:~ ........ -_ ~ : _ · - : = ::: :~ l_ _ ~ _ J ,,_ ,~,~_ _ ~ -: _' .... _~ .... 3993 ~700 ' ' 9 5/8"-43.5~0~ 8062' 800 . _ ~:- ~ -- _. - 7" liner · 11,196' 1182 , _ _ -~ ~ _ ~ ~ L~ ' -- :" - ':-: '' '~ -" ~' ]'~ - - 2 7/8~ · ' "-'9-860=~ on paCker~SO~ PRODUCTIVE HORIZ~S 3[" 'tbg'. , 7813~ o~ packe: 7801 Depth Contents'~ ,.., ,. ~ _ _ VELL STATUS Year Jan Feb~ ~r Ap~.. Hay June July Aug Sept Oct Nov Dec ' _~'~ r ...... . ~ - · -' ...... -' -7' -=%~ ":~- '"-~ " - =--:- : ]-- - : ~ ~-:- '- ~= '"-' ~- - ...... u' _ m, _ _,, , ~ _ ~ _ _~ - · · _T -' ~ ~ ~- , Con~rac~or: ~a Fe Drilling Co. T.D. 10,833'. Junk in hole: 12~" ..... 2' ;~' x'- 20 ' bO; ::~- ~k:~X= ~0 ~ -~C,' ' Z2% -:' -s-erv~-;=Z'7~::.- x--50: :~-S;::~-~pe~a ~g~rk.s: sub m~el 8881-850~~, ~0 3/~" ~0 shoe, 2 ~C~. ~0 3/~" ~a~h....p!p~_~, :~t~e_ ~%',; ~'-"~,~ ~--~O:."D~*'~',"~e~C° -'7~,,- X-90i: :~S"~ ~e~O'~-s~e-eve.-- 8610-83~3 '.. , . , . :. ~ ... ,. .- . . ; · Form P--3 STATE OF ALASKA, OIL AND GAS CONSERVATION COMMITTEE .. · 1~ RE~O~T OF "~)-~TLLtNG A~-[~.... WORKOVER OPERATION S .RAMI~ Ol~ OI~I~RA~OR o · .. 8.. AP.i NUMERtCAk COD~,. i" 'u 9. w~-l.,~ ;~o. · ,, : · · [0. ~I~LD AN~ ~)0I,~ 0~, WII, DC/'I' AOD[~B~ OF O~R&TOR 4. LOCA~[O.~ Or W$~-L (Re~ort lo¢~Lton clearly ~rtd in, acco~de, nce with Kny Stste requirements,* REPORT TOTAL'DEPTH A'~'"/'N'~"°F' MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERF'ORATION.rTESTS AND R'FSULTS~FISH1NG JOBS, JUNK IN HOLE AND SIDE' TRACKED HOLE AND ANY OTHER SiGNiFICANT CHANGES IN HOLE CONDITIONS, .( · · Form No. P--4 REV. 9-30-67 STATE OF ALASKA SUBMrr IN DEPLICATE O~L AND GAS CONSERVATION COMMITTEE ~MONTHLY RE!PORT OF 'DRILLING AND WORKOVER OPERATIONS 0IL ~ GAS [] W~LL WELL OTHER :~. N-~E OF O~TOR Mobil Oil Corporation 3. A~I~DRESS OF OPEI:~ATOR P. O. Box 1734, Anchorage, Alaska 99501 4. LOCATION OF WELL 2366' South and 1256' East of the NW Corner of Section 13, TION, R12W, S.M. AP1 NUS~ERICAL CODE 6. LEASE DESIGNATION AND SEi~IAL Granite Point ADL 18761 7. IF INDIAN. ALO t t E~ OR TRIBE NAME 8. LrNIT,FAi~M OR LEASE NAME Mobil-Union Granite Point 9. WELL NO. 31-23 10. FIELD AND POOL. OR WILDCAT Granite Point li. SEC., T., R., M., (BOT'FOM HOLE OBJECTIVE ) NW/4, NE/4, Sec. 23, TION, R12W~ S.M. 1~.. PER.MIT NO. 67-84 13, REPORT TOTAL DEP~mH AT END OF MONTH, CI-LA. NGES IN HOLE SI~E, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A1N-D VOLU1VIES USED, PERFORATIONS, TESTS ANT) RESULTS, FISHING JOBS, JLrNK IN HOLE A-ND SIDE-TRACKED HOLE AND A~NY OTHER SIGNIFICANT CI-tA~.F~ IN HOL~ CONDITIONS. APRIL 1968 Drilled 8 1/2" hole to 11,200'. Stuck DP. Back off at 10,911'. Wash over and recover all fish except 8 1/2" bit, bit sub, and roller reamer. (Total 8.92')~ Ran 7" liner and set at 11,191'. Top liner at 7867'. Cemented with 1300 cf Class "G" cement plus 3/4% TIC. CO to top liner at 7867' w/8 1/2" bit. Pressure tested top liner to 3000 psi. Clean out liner to 11,185' w/6" bit. Perf. 4/J at 10,730'. DST above perfs. Rec. 19 Bbls gas cut oily mud. Set cement retainer at 10,614'. Squeeze w/24 cf Class "G" cement. Squeeze with 14 cf into formation to 5500 psi. Perf.'4/J at 10,100'. DST above perfs. Rec. 6 Bbls slightly gas cut mud. Set cement retainer at 9995'. Squeeze with 34 cf Glass "G" cement. Cleaned holes. Squeeze with 57 cf Class "G" cement to 6500 psi. Perf. 4J at 9860'. DST above perfs. Rec. 35 bbls. slightly gas cut mud and fresh water. Set cement retainer at 9747'. Squeeze with 75 ~ax Class "G" cement Est. 60 sax into formation. Squeeze pressure 5500 psi CO to 9995' with 6" bit. Perf. 4/J at 9866'. DST above perfs. Rec. 60' drilling mud. Drilled & CO to 11,191'. Displace mud with diesel oil. Ran 2 7/8" and 3 1/2" tubing. Set dual packer at 7803' in 9 5/8" casing. Nippled up X-mas tree. Perf. the following intervals 9,911'-9,921', 9,941'-9,971, 10,260'-10,275', 10,280'-10,445', 10,897'-10,987', 10,016'-11,176', Total 475' with 4/S/Ft. Released rig and turned to production 12:00 Noon 4/19/1968 RECEIVED MAY 7 1968 DI¥1$1ON OF MINES & MINERAL~ ANCHORAGE 14. I hereby ce~,y t~ th~]o}%~g,_5~ue ct smm~ "f~ LL..-f/~' f-f-////l~./~. =w,.~. Area Engineer ~A','l 5-3-1968 NOTE--Report on this form is r d for each calendar month, regardless ot the status ot operations, anO must ~e filerJ in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form No. P---4 Y~-~V. 9-30-67 STATE' OF ALASKA OiL AND GAS CONSERVATION COMMI'I-I'EE SUBMIT IN DEPLICATE MQNTHLY REPORT OF 'DRILLING AND WORKOVER OPERATIONS "i, ' ; 2. NA1VfE OF O~Elq.~TOR Mobil 0il Corporation 3'. ADDRESS OF OPERJkTOR P. 0. Box 1734, Anchorage, Alaska 4. LOCATION OF V~ETJ. ' 2366' South and 1256' East of the NW Corner of Section 13, TION, R12W, S.M. AP1 NLr~IERICAI, CODE 8. LEASE DESIGNATION AND SEfilAL NO. Granite Point ADL 18761 7. IF INDIAN, ALOTTEE-OR TRIBE NAME 8. D~'IT,FA3~M OR LEASE NAAIE Mobil-Union Granite Point 9. %VELL NO. 31-23 10. FIF-/2) A-ND POOL. OR WILDCAT Granite Point 11. SEC., T., R., M.. (BOTTOM HOI.~E OBJECTIVE~ NW/4, NE/4, Sec. 23, TION R12W, S.M. 12. PER/VIIT NO. 67-84 13.REPORT TOTAL DEPTH AT END OF MONTH, CI'L~NGES IN HOLE SI~E, CASING AiW'D C~/IENTING JOBS INCLUDING DEPTH SET ~ VOLUMES USED, PERFOP~ATIONS, TESTS ~ ~SULTS, FISHING JO~, J~K ~ HO~ ~D SIDE-~CKED HOLE AD ~Y O~R SIGNIFIC~T ~~ ~ HO~ ~ITIONS. March 1968 ~fy, lP ~ [~:~; Stuck DP at 8686'. BO at 8601', Left 280' fish in hole (12 1/4" bit, 2-7 1/4" x 20' DC's, 7 1/4" x 30' DC's, 12 1/4" Servco, 2 7 1/4" x 30' DC's, KS~Wiper. Bumper Sub Mandrel). W0 to 8636'. Stuck ~ at 8610'. Back off at 8313' Left ~" ?7 fish in hole. (WO Shoe, 2 Joints, 1~ 3/~" W0 Pipe, Drive Sub, Bum~er Sub, Jars, X-~er, 12 1/4" Servco, 7 1/2" x 90' DC's, 12 1/4" Sedco, 7 1/4" x 90' DC's, Servco sleeve). Run and set 9 5/8" casing at 8062'. Cemented with 800 sax Class "G" cement. With OEDP set 345 sex OH plug at 832~'. K0 fish at 8085'. Drilled 8 1/2" hole to 10,882'. Stuck DP. Spotted oil. No success. B0 at 10,730'. WO and recovered fish. ~' 4/1/1968 Drilling 8 1/2" hole at 11,197'. · ,, SIGNEn %. ~,_. =TUE Area Engineer DA'rS, April 3, 1968 NOIE--Report on this form i~ req,~for each calendar month, regardless of the statu~ ot operation~, anO must ~e fileO in with the Division of Mines & Minerals ~y the 15th of the succeeding month, unless othe~ise directed. h OIL Form No. P---4 REV. 9-30-67 STATE OF ALASKA SUBMIT IN DEPLICATE O~L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2~ NAME OF OP~R~ATOR Mobil Oil Corporation 3. ADDRESS 'OF OPEP. ATOR P. O. Box 1734, Anchorage, Alaska 4. LOCATION O'F WELL 2366' South and 1256' East of the NW Corner of Section 13, TION, R12W, S.M. AP1 NUAIEHICAL CODE 6. LEASE DESIGNATION AND SERIAL AIO. Granite Point ADL 18761 ?. IF INDIAN, AIX)TTEE OR TRIBE NAIIE 8. LrNIT,FA3kM OR LEASE .~AAIE Mobil-Union Granite Point 9. WELL NO. 31-23 10. FIELD AND POOL. OR WILDCAT Granite Point i1. SEC., T., R., M.. (BOTTOM HOLE OBJ'fICTIVE) 1~/4, RE/4, Sec. 23, TION R12W, S.M. 19.. PER,MIT NO. 67 -84 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IA.NGES IN HOLE SI~E, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AN~ VOLI/MES USED, PERFORATIONS, TESTS A/ND llESULTS, FISHING JOB~, JUNK IN HOLE A~ND SIDE-TFL~CKED HOLE AND ANY OTHER SIGNIFICANT CH.A~ES IN HOL~ CONDITIONS. February 1968 Drilled 12 1/4" hole to 10,833'. 3/1/1968 Working DP out of hole at 8740'. ptVtStON ANc~oR~G?' /f,' 1~' ///9;~'~~'/' Area Engineer 3/4/1968 SIGNED # - - '~'~/-~'/ '~"~'~" ~"~-~' ,/ ~ ~T~ DATE NOTE--Report on this for for each calendar month, regardless of the status of operations, anU must be fUeU in duplicate with the Division of Mines & Min~ls by the 15th of'the succeeding month, unless othe~ise directed. Form No, P--4 I%EV. 9-30-6~ STATE O,F ALASKA O~L AND GAS CONSERVATION COMMITTEE SUBMIT IN DEPLICATE ~'~ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS t OIL ~ GAS ~-~ ~_. ~A~E OF OPm~TOR Mobil 0il Corporation 3. ADDRESS OF OPEllATO1R P. 0. Box 1734, Anchorage, Alaska LOCA~ON OF WRLL 2366' South and 1256' East of the NW Corner Sec. 13, TION, R12W, S.M. ~. API NLr~{ERICAL CODE 6. LEASE DESIGNATION A.'~'D SERIAL NO. Granite Point ADL-18761 7. IF INDIAN, ALOT r~JJi OR TRIBE .~AIlE 8. LrNIT,FAi~%'~ OR LEASE NA-%IE Mobil-Union Granite Point 9. WELL NO. 31-23 10. F~alLD A.ND POOL. OR WILDCAT Granite Point 11. Sl~-C., T., R., M., (BO~'TOM HOL~ OBJECTIVE) NW/4, NE/4, Sec. 23, TION, R12W, S.M. 1~-. PEI~MIT NO. 67 -84 13, REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CE1VIENTING JOBS INCLUDING DEPTH SET ANI) VOL~ USED, PERFORATIONS, TESTS ~ RESULTS, FISHING JOBS. JIINK IN HOLE AND SIDE-T]IACKED HOLE ANT) A/qY OTHER SIGNIFICANT CI-IAN~ES IN HOL~ CONDITIONS. Jan.u. a~ry 1968 Spudded 1/11/68. Drilled 12 1/4" hole to 633'. Opened 12 1/4" hole to 22" to 612'. Set 18" casing at 606' and cemented with 670 cf Class G cement.. Cement returm to surface. Drilled 12 1/4" hole to 4050'. Opened 12 1/4" hole to 16" to 4050'. Set 13 3/8" casing at 3993'. DV Collar at 2230'. Cemented 1st stage with 735 cf Class "G" cement. 2nd stage with 1700 cf Class "G" cement. Drilled 12 1/4" hole to 6306'. 2-1-1968 Drilling 12 1/4" h°le at 6306'. 14. I hereby cert~f~v that the fo_rego~ng is tfxte axed eot]re with the Division of Mines & Minerals b the 15th of the succeeding month, unless otherwise directed. ~anuary 18, 1968 Nob11 0~1 Corpoz~tou~ operator ~r. C. C. ~oodruf£ P. o. Box 173& Auehora~e, Alaoka 99~0X DeaE Kaclosed b your approved .copy of Sundr7 HorAce (F-3) for ~he above-e~l~Lonad woXl. Xa~l L. VonderAhe I~LV :~ay Form P---3 REV. 9-30-67 Submit "Intentions" in Triplicate & "Subsequent Reports" h~ Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE . SUNDRY NOTICES AND REPORTS ON WELL5 (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) 1. WELL WELL OTHER 2. NAME OF OPEILATOR Mobil Oil Corporation 3. ADDF~ESS OF OPERATOR P. O. Box 1734, Anchorage, Alaska 99501 4, LOCA~ON OF WELL Ats=~a~ (Leg 1, Slot 4) 2366' South and 1256' East from NW Corner, Sec. 13, TION, R12W, S.M. 13. EI~VATIONS (Show whether DF, RT, GlO, etc. 105 ' above MLLW (K. B. ) 14. (:beck Appropriate Box To Indi~.m~e Nmture of N~ti'ce, Re NOTICE OF INTBNTION TO: FRACTL'RE TREAT MULTIPLE COMPLETE 8HOOT OR ACIDIZ~ ABANDON° REPAIR %%1LL CHANOE PLAN8 '5. APl N~CAL CODE 50-133-20072 e. LEAS~ bESIGNATION AND S~IAL NO. State ADL 18761 7, IF INDIA. N. ~,-L,LO'I~I'~ OR TRIBE NA_NL~ $. UNIT, FARM OR LEASE NAME ,Union-Mobil State #1 9. WELL NO. Granite Point State #31-23 ' 10. FmL, D A~I~'POOL, OR WILDCAT "' Granite Point - Middle Kenai n. sec., T.. R., ~.. (SOT~OM HOL~ osJ~.C~r~vm Sec. z.~ TTON~ R12~, S.M. 12. PERI~T NO. 67 -84 tort, or Other Date SUBSEQUENT REPORT OF: FRACTURE TREATMINT ALTERING CA~ING SHOOTING OR ACIDIZING ABANDONMENTe (Other) Location Change (NOTE: Report results of multiple completion on Well tOther1 Completion or Reeompletlon Report and Lo~ form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Work Done: Change in Surface Location for Granite Point State #31-23 Previous Location: (Leg 3, Slot 7) 2380' South and 1371' East from NW Corner, Sec. 13, TION, R12W, S.M. Corrected Location: (Leg 1, Slot 4) 2366' South and 1256' East from NW Co~mer, Sec. 13, TION, R12W, S.'M. Verbal approval for above change received from Mr. Thomas Marshall, Division of Mines and Minerals, 1/12/1968. Note: The corrected location for well f~31-23 is the same as that used for well f~33-14. The latter well will be drilled at a later date from a new location. RECEIVED DIVISION OF 'MINE5 & MiNERAL~ .ANCHORAGE 16. I hereby certify thug'-the forei'~ing lq true and,(i~o~reet ' -,'his sPaCe for S--te o, ce~}./ APPROVED BY ./[ ' / '~' t ,-' c - ' ~-. CONDITIONS OF APPROVAL, ~ A~: ,. TITLE Area Engineer ',, See Instructions On Reverse Side DATE .... 1115/1968 , , ,,,, Mobil Oil Corporation 612 SOUTH FLOWER STREET LOS ANGELES, CALIFORNIA 90054 Northwest Producing Area P. O.Box 1734 Anchorage, Alaska 99501 December 27, 1967 State of Alaska Division of Mines & Minerals 3001 Porcupine Drive Anchorage, Alaska 99504 Attn: Mr. Thomas R. Marshall, Jr. RE: APPLICATION FOR PERMIT TO DRILL GRANITE POINT STATE NO. 31-23 PERMIT NO. 67-84 Dear Sir: As requested by your letter dated December 18, 1967, the following additional data are submitted to complete the P-1 Form on our Granite Point State No. 31-23. Item No. 14 Bond Information Type: Oil & Gas Lease Surety and/or No.: Pacific Indemnity Company No. 243305 (expires 8/18/71) Amount: $100,000 Item No. 23 Casing Size Grade 18" 5B Line Pipe 13 3/8" J-55 9 5/8" S-95 and N-80 Yours very truly, RECE!VED DIVISION OF MINES ANCHORAGE MJMEYER:sw lc: Grsntte Point State tP31-23 Mobil 0tl Corp., opet~or ~. c. c. lbodruff, Aree bSXuoer Hobtl 0~1 Corpor,~iou P. O. Boz I~ Anc~~, ~ 99S01 Znc.looed p~ find ~ epp~ epplica~tou for permit drill. ~b8 refe~J u~ll. lbll tmsples mad core chips for gm Very ~ruly yours, ?r .' ,. Thomas ~. Ifsrohall, FORM SA- 1B ,~,,,.~ ~ 125.5M 8/67 / \~ MEMORANDUM · TO; I-- FROM= State of_ Alaska SUBJECT; FORM SA - 1 B 125 .SM 8J67 /'~,,,,, ' ~ MEMORANDUM . TO: [- FROM: State of Alaska DATE : jJJlJlljlllJlllJ~ ~ J,~JJ7 SUBJECT, Mobil Oil Corporation NORTHWEST PRODUCING AREA P. O. Box 1734 Anchorage, Alaska 612 SOUTH FLOWER STREET LOS ANGELES, CALIFORNIA 90054 December 13, 1967 State of Alaska Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska Attention: Mr. Thomas R. Marshall, Jr. Gentlemen: Enclosed are three copies of our application to drill Union-Mobil Granite Point State #31-23 (State Form P-l), three location plats and our check in the amount of $50.00. This well will be spudded after receipt of your approval. Please sign and return to us the enclosed receipt. MJMeyer:sjs Enclosures Very truly yours C. C. Woodruff Area Engineer RECEIVED SEC lg 1967 DIVISIOhl OF MINES & MINEP~L,~ ANCHORAGE Form P--1 REV. 9'30-67 STATE OF ALASKA SUBMIT IN TRL ATE (Other instruetion~ on reverse side) OIL AND GAS CONSERVATION CO,MMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLuG BACK l~t. TYP~ OF WORK DRILL ~ 2. NAME OF OPERATOR MOBIL 0IL CORPORATION ~. ADDnmSS C~ oPm~o~ P. 0. BoX 1734, Anchorage, Alaska 99501 DEEPEN I--I PLUG BACK MULTIPLE ZONE 4. LOCATION O'F WELL ~t~urfac~Leg 3, Slot 7) 2380' South and 1371' East of the NW Corner, Sec. 13, T10N, R12W, S.M. At pro.posed prod. zone 660'8 and 1980'W from NE..Carner~of Sec 23 T10N .R12W~ S.M. "~' ' ~'- '' ~-~:' ' ' 13. DISTANCE IN MILES AND DIRECTION Fi~OM NEAREST TOWN OR.POST OFFICE* Cook Inlet - Approx. 11 miles ~outh of Tyonek Village 14. BOND INFOI~MATION: AP1 50-133-20072 6. LEASE DESIGNATION AND SERIAL NO. State ADL 18761 ~. IF INDIAN, ALLO~ OR TRIBE NAME 8. UNIT~FARM OR LEASE NAME Union-Mobil State 9. WELL NO. Granite Point State #31-23 10. PIELD AND POOL, OR WILDCAT Granite Point-Middle Kenai 11. SEC., T., R., M., (BOTTOM I-IO LE OBJECTIVE) Sec. 23, T10N, R12W, S.M. 12. Kenai, Alaska TYPE Surety and/or No. PROPOSED~ %"/ 15. DISTANCE FROM :-, 16; NO; ~OF ACRES IN LEASE NEAREST 3'300 ' LOCATION TO LEASE LIN:E!if ~T"'~- PROPERTY OR drig, unit,any) ( (Also tO nearest . . -. · . ! '5089' '~. DISTANCE FROM PROPOSED LO~i~TION* · ~': TO NEAREST WELL DRILLING~ ~OMPLET~, OR APPLI~ FOR, ~. 17. NO. ~ACRES ASSIGNED TO THiS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL STAHT* 106' MLLW (KB) Jan. 1, 1968 23. ' ' ' ..... ~ P~OPOSED cASING AND CElV[ENTING PROGRAM' T -. ~' _ , .. SIZE OF HOLE SIZE OF CASING] ~:~'~IGI-I'T'~g~ F~' ' , 24" 18" '[ 70,59 ' 600' CircUlat-~ ~d surface 16" 13- /8 ...... ~61,- - ~ 4000' St.ace. to eurfac~ w/a~ditipnal dependent on ~ - ~. c0mplet$on i.n. te rval. Well will be directionally drilled appCox. 4900', S45°W 'from the surface location to.~total depth of 12,500'~.M~D% (11,200'± V.D.) in order to reach the objective from the permanent platform. BOP Program: .600' to 40Q0': 20-3~4" Hydril "MSP" 2000 psi~WOG 400O':t0 TD~ : 13-3/~!" Hydril "GK" 5000 Psi W0G ~:~:~':- "~' ~3~-3/8'' Cameron "U" tripple~5000 psi W0G IN A. BOVE SPA. CE DESCRIBE PI~OPOSED PROGRAi~i If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If pr(~posal is to drill'.or .d~pen dire~t~onally, give pertinent data on m~bsurface locations and measuxed and true vertical depths. Give blowout preventer prograxrL 24. I hereby certif'~hat the Fo~regoing ~s True anc~ Cgrr~ct . (This space for S~ate oJi~e use)' - /~I~Di~0.NS OF ~ppR0v~ ~F ANY: Di~cTIoN~ SURVEY ~Vm~ ':~ !~'*,~.~. ~C~ COn" APPROVED _~ z ' _ ~.~'~ TITL~ Area Engineer December 18, 1967 A~:t'~ff,,~ ~.A .... Executive Secretary "~- I'' ;'""'"':'-'l · Il . "- ..,.~'., ' I' -i ' J '.-., :',:'.'. ~'-' T-'J~I:~''~w- i .'.,:};/ . .' ' ~.~N. i~.j~ w, : '....~.,,..~..,. ' "'."'"- ' ' - //:::':/ - .. ~'' ' -. '.1 : : · ~ ,' ...., I ~T ". : ; 2.6' ' . I ,,,~:'-/' ~5 ' ' I '" ~0 . . I .~. ?: ':'~'~., ~ ' ' ' ' " " ?' .... · . 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