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Home My WebLink About182-100DATE 12/27/18 18100 Seth Nolan Hilcorp Alaska, LLC 3 0 2 1 3 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Fax: 907 777-8510 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 CD 1: . Hilcorp_MPU_B-09A Tubing_9Nov18 FINAL 11/5/2018 9:13 AM Please include current contact information if different from above. File folder RECEIVED JAN 0 7 2019 AOGCC Please acknowledge fpcgipt by_� gning aqd returning one copy of this transmittal or FAX to 907 777.8337 BY: / / //' L, W \ l I Date: • !r7 p q;;c.. R �a v STATE OF ALASKA 3yT.F`(' ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 0 3 2019 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations Ll Fracture StimulateLi Pull Tubing ✓ UG -12& Lj Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well[] Re-enter Susp Well ❑ Other: R&R Gas Lift Completion ❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hiloorp Alaska LLC Development Q Exploratory Ell 182-100 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6. API Number: AK 99503 50-029-20748-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0047437 MILNE PT UNIT B -04A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 9,500 feet Plugs true vertical 7,280 feet Junk Effective Depth measured 8,969 feet Packer true vertical 6,887 feet feet g Length Size 8,969 MD Conductor 80' 20" 8,821 80' Surface 2,300' 13-3/8" 6,782 2,300' Production 9,467' 7" Burst 9,467' 'ation depth Measured depth See Schematic feel True Vertical depth See Schematic feet 3 (size, grade, measured and true vertical depth) 8,160psi 3-1/2" rs and SSSV (type, measured and true vertical depth) 7" x 3-1/2" TNPerm emulation or cement squeeze summary: N/A als treated (measured): N/A vent descriptions including volumes used and final pressure: N/A measured NIA feet measured 8,969 feet measured 8,821 feet true vertical 6,782 feet TVD Burst 80' N/A 2,300' 1,661 psi 7,256' 8,160psi 29# / L-80 / EUE See Above or 8,916' N/A Collapse N/A 5,380psi 7,020psi 6,850' N/A Prior to well operation: 0 0 0 1 100 0 Subsequent to operation: 148 2,319 542 1 960 388 14. Attachments (required per 20n C 25.070, 25.o7t, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-472 Authorized Name: Bo York Contact Name: Stan Porthole S7 f Authorized Title: Operations Manager Contact Email: sporhola(ODhilcorp.COm 7 Authorized Signature Date: 1/2/2019 Contact Phone: 777-8412 RBDMS- JAN 0 7 2019r Forth 10-404 Revised 412017 Submit Original Only K EHIMM Alaska. LLC Orig. DF Elev.: 59.0'/ GL Elev.: 35.0' (Nabors 27E) 20' SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU B -04A Last Completed: 12/13/2018 PTD: 182-100 Tree 3-1/8" 5M CIW 8RD Tree Cap Size Tbg Adapter 11"x 3-1/8" SM CIW Wellhead Tbg Hgr. 11" x 3-1/2" IBT Conductor 3" CIW-H BPV Profile OPEN HOLE/CEMENT DETAIL Td -State `_ ,Arctic Pack 20" Cemented to Surface in 30" Hole Casing Patch - 13-3/8" 3600 sks Permafrost Cement in 17-1/2"Hole 1,000 sks Class "G", 300 sks Class "C" & 7 200bbis of Arctic Pack ina 8-1/2" Hole CASING DETAIL 2 3 V DV Tool 2094' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 94/PE/N/A N/A 0 80' 13-3/8" Surface 72 / K-55 / BTC 12.347" 0 101' 72 / L-80 / BTC 12.347" 101' 2,300' 7" Production 29 / L-80 / BTC 6.184" 0 9,476' TUBING DETAIL 4 3-1/2" Tubing 9.3/L-80/EUE 2.992' 0 8,916' WELL INCLINATION DETAIL KUP @ 2,200' 5 Max Hole Angle = 58 deg. @ 4,900'— 5,200' JEWELRY DETAIL 6 7 CBL TOC 6 $014 / 7/20/82 9 It 10 11 t 12 RII Tagged 13 @8,969' RKB 5/21/14 KLPG1 KUP 8-7 Fish: Van Perforating gun, Calculatedtop ! @9,305'MD 'K -P B-6ScWd 7 TD= 9,500 (MD) / TD = 7,2W(TVD) PBTD = 9,382 (MD) / PBTD= 7,191'(TVD) No Depth Item 1 2,103' STA#10: PATCO GLM / DGLV 1.5" RK (12/24/18) 2 2,790' STA#9: PATCO GLM / LGLV 1.5" RK (12/24/18) 3 3,446' STA#8: PATCO GLM (dummy valve installed )1.5" RK (12/13/18) 4 4,293' STA#7: PATCO GLM / LGLV 1.5" RK (12/24/18) 5 5,199' STA#6: PATCO GLM (dummy valve installed ) 1.5" RK (12/13/18) 6 5,982' STA#5: PATCO GLM / LGLV 1.5" RK (12/24/18) 7 6,796' STA#4: PATCO GLM / S/O GLV 1.5" RK (12/24/18) 8 7,451' STA#3: PATCO GLM (dummy valve installed )1.5" RK (12/13/18) 9 8,139 STA#2: PATCO GLM (dummy valve installed )1.5" RK (12/13/18) 10 8,767' STA#1: PATCO GLM (dummy valve installed ) 1.5" RK (12/13/18) 11 8,821' 7" x 3-1/2" Halliburton TNT Permanent Packer 12 8,872' Halliburton'XN' Nipple, Min ID=2.750" 13 8,914' WLEG (Btm @ 8,916') PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Date Status KUP C-1 8,936' 8,954' 6,864' 6,877' 18 8 11/18/85 Open KUP B-7 8,960' 8,994 6,881' 6,902' 30 12 7/26/82 Open KUP B-6 9,182' 9,184' 7,042' 7,043' 2 4 7/17/82 Squeezed GENERAL WELL INFO API: 50-029-20748-01-00 Sidetracked and Completed by Nabors 27E-7/22/1982 Attempted Recompletion by Rol'n' 4-9/24/85 Casing Repaired by Nabors 27E -11/2/1985 Recompletion by ASR 1-12/13/2018 NOTE: A wobble washer and spring are lost in the wellbore. MIT -IA to 2,500 psi (passed) on 12/14/2018 Revised By: JCM 12/25/2018 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-04A ASR / Slickline 50-029-20748-01-00 182-100 11/1/2018 12/14/2018 Daily Operations. 10/31/2018- Wednesday No activity to report. 11/1/2018 - Thursday Begin nippling up BOPE to wellhead and spotting Company Rep trailer and Dog house into position. Hook up power to Co Rep trailer and Doghouse. Backing incident occurred with NES tractor driver making contact with guard rail on Diesel tank. Code Blue called on the radio. Crew instructed to stand down until further notice. Stand down until all clear on the radio is given. Continue to R/U BOPE on MP B-04A. Spot equipment into place. Utilize crane to place well but over well and rig floor on well hut. Cont. With Rig up Process, Spot Rig on the mud boat. RU over the hole, rig up work floor and tbg equipment, run bope lines, Rig up 11-1/16" spools with 6" diverter flow line, Run 6" flow line, Heat trace all pump lines, Prep for BOPE test @ 3,000psi/ 2,500 annular. 11/2/2018 - Friday Continue to R/U in prep for testing BOPE. Set catwalk in working position. Attempt to perform shell test on BOP stack. Kill valve # 5 leaking at the stem. Change out O-ring seal on valve stem. Re-test and get good shell test. AOGCC rep Brian Bixby on location to witness testing. Perform BOPE test as per Sundry w/ 3-1/2" test joint to 250psi low f/ 5 charted mins and 3 000psi high f/ 5 charted mins. Test annular to 250psi low, 2,500psi high f/ 5 charted mins w/ 3-1/2" test joint. Bleed down system and blow down all fluid lines. Prepare to pull TWC. Gas underneath TWC, bleed gas through the check valve until comfortable we can safely pull valve. Cont. to bleed down tbg pressure threw TWC while crews change out and check fluids on all equipment. Make up 3.5" x 2-7/8" IF work string landing jnt. BOLDS, Pull into tbg hanger. Took 85K to unseat hanger form bowl. Picked up to 150K string wt. did not come out of SBR seals. Work tbg string from 90K to 150K in attempt to work free from SBR seals but were unsuccessful. Tried to pump down tbg with bag closed in attempt to gain some hydraulic force again unsuccessful. We were getting a 3/4 bbl/min inject @2,500psi. Prep. to rig up CSG jacks. rig up CSG Jacks with 3.5" EUE 8 rnd landing jnt. Warm up hydraulics on CGS Jacks. Pick up with rig to 145K Take over with Jacks and bring up the 180K continue to try to work tbg free. Unsuccessful in working tbg free . land tbg back in well head. Start to rig down CSG Jacks. 11/3/2018 -Saturday Continue to wait on SLB E-line. Crews clean and service rig. Decision made to R/U Halliburton slick line and attempt to drift bent GLV in GLM # 7 (4,310'md). Unable to get by w/ 2.0" drift. POOH w/ drift. P/U modified cutter, RIH and attempt to break/shear GLV. Unable to get through GLV. POOH w/ modified cutter, P/U blind box and attempt to beat through GLV. No success. Finish Up with Slickline trying to cut through the GLV, RD Slickline. R/U E-Line with CCL & Chem Cutter.Pick up to 73K and set in the tbg slips. RIH, Correlate depth and make cut @ 4,292', Pick up on tbg 6' string wt. @ 41K re-land tbg and POOH with E-line . RD E-line. Unland TBG, Break off & lay down the tbg hanger. Run 1/4" cap line/W armor through sheave. Start POOH from 4,292'w/ 3.5" 9.3lb/ft, L-80 DSS-HTTBG. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig I API Number Well Permit Number Start Date End Date MP B -04A ASR / Slickline 1 50-029-20748-01-00 182-100 11/1/2018 12/14/2018 Daily Operations. 11/4/2018 -Sunday Continue to POOH w 3.5" 9.3# L-80 DSS -HT TBG. Issues getting the control line to spool properly. Swap out smaller spool on spooling unit for larger spool. Clean and clear rig floor. Load and tally Baker fishing overshot BHA, consisting of overshot, bumper sub, oil jars, (6) 4-3/4" drill collars, x -over back to 3.5" work string. M/U Baker fishing overshot BHA. M/U all connections to 10k ft -lbs and RIH to—206'md. RIH w/ Baker fishing overshot BHA f/ 206'md on 3.5" work string. Fill hole every hr and monitor fluid volume to fill hole. Staying consistent @ 20bbl/hr. M/U work string to 7,800 ft -lbs TQ. Cont. RIH w/ 3.5" work string. Fill hole every hr and monitor fluid volume to fill hole Get parameters 50K up wt. 33K down. Tag up @ 4,284', Make up 20' pup sub. Swallow Fish and come up to Check Fish latch. Getting 10k over pull. Start to jar on Fish Make 6 licks @ 40K over, Move up to a 70K over pull for 6 Licks, move up to 90K over pull for 47 Licks. Fish came free with an up wt. of 120K and 50K down wt., w/ total of 59 licks. Move string down hole 20' past tag indicating that the packer has released and is free. Allow PKR to relax f/ 10mins. No indication of fluid change. Try to bull head the csg but pressured up to 800psi and held w/ the pump off, bleed dwn, LD 20' pup and 4 jnts of 3.5" tbg. seeing wt indicator fluctuations as we move up hole. Try to bull head again but system pressured up again and held without pumps. Rig up and circ down the TBG. 140 bbls taking returns to tiger tank. (No major signs of gas). Start laying down 3.5" work string. packer elements not relaxing. swabbing the well coming out. Try to work packer through tight spot in attempt to get packer elements to relax. Attempt to bullhead again, pressure system up to 1000psi and turn off pump. Pressure still holding steady. Bleed off. and continue out of hole. 11/5/2018 - Monday Continue to POOH w/ production PKR on 3.5", 9.3#, DSS HT TBG to "7,900'md. TBG swabbing out of the hole. Attempt to bullhead down the IA, system pressured up to 2,500psi and held w/ pumps off. Bleed off and attempt on bullhead TBG side. Same result. Bleed off and continue to POOH looking for any tight spots to work PKR across. TBG pulling tight after laying down joint 65 of work string ("7,100'md). See 10klbs drag. Work pipe up and down across tight spot, seeing over pulls up to 30klbs and slack off weights taking 15klbs off string weight. Work pipe until fluid level at surface begins to fall out of stack below wellhead. Close bag and bullhead 150 bbls F/W without catching circulation. Continue POOH w/ 2-7/8" work -string and Baker Fishing BHA, pull to 4,700' and rig crew noticed hydraulic leak from rig carriage drive motors. Necessary to shut down rig and evaluate for repairs, monitor well pumping 30 bbls every hour with no indication of pressure, continue pumping 30 bbls every hour while evaluating rig repairs. Well stable with no show of pressure. Continue troubleshooting hydraulics on rig top drive carrier. Install hanger and land tubing hanger. Hang off with 6 joints work -string, Fishing BHA, and fish consisting of 4,300 feet tubing with packer. Continue with diagnostics on hydraulic motors in top drive carrier. 11/6/2018 -Tuesday Continue troubleshooting and diagnostics on top drive carrier. Determined that hydraulic motor has blown seal thus flooding gear box on top drive carrier and bursting gear box seal creating the leak. Necessary to remove and replace the failed motor and gearbox on top drive carrier. SIMOPS: R/D ASR carrier and move to VMS to allow for top drive carrier removal. R/D all support equipment and begin staging at A pad. N/D BOP's and N/U old production tree while continuing to R/D and stage ASR support equipment for deployment to L -pad upon completion of repairs to ASR. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B -04A ASR / Slickline 50-029-20748-01-00 182-100 11/1/2018 12/14/2018 Daily Operations. 12/5/2018- Wednesday No activity to report. 12/6/2018 - Thursday No activity to report. 12/7/2018 - Friday No activity to report. 12/8/2018 -Saturday MIRU ASR rig. Bled down IA from 675psi to 275psi in prep to kill well, Pumped 150 bbls 8.3 produced water @ 7.81apm at 750psi, swapped to 8.7 ppg NaCl brine, pumping 290 bbls 8.7 brine @ 7.8bpm @ 850psi. S/d at 290 bbls pumped with IA pressure @ 68psi and climbed to 130psi stabilized. Ordered 290 bbls 9.2 ppg NaCl brine as per plan with engineer. Continue MIRU ASR rig and standing by to pump and kill well with 9.2 brine upon arrival. Cont. Move forward with getting eq. mobed to B pad while waiting for fluid. Fluid arrived R/u had starter issue on pump, repair same. Bleed down check pressures, IA 285psi, pump 7.85 BPM, ICP @ 15 bbls pumped 130psi, pump 284 bbls ( last 60 bbls down annulus & tubing) FCP=888 tubing / 820 annulus, s/d & monitor, well went on vac both sides, f/5 min then started building pressure 54 tubing 50 annulus. Freeze protect lines, r/d & release vac truck & LRS monitor well. Well pressure @ 170 annulus/ 23 tubing, bleed gas off annulus to -0, tubing 4psi. Shut in monitor well, safety valve actuator relief leaking valve closed, call well support get parts & repair same. Bleed well down f/ 23 tubing & 140 annulus, t/Opsi, monitor install BPV, monitor well tubing 0. Prep & spot mud boat, setup crane, spot well house, cont. prepping eq. for r/u 12/9/2018 -Sunday Continue MIRU ASR rig, monitor well backside pressure bleeding off pressure every 2 hours. Starting pressure was 25psi. Every time bleed off well pressure falling on build up. At 4:30pm pressure was below 5psi with 2 hour build up, bleed off well and continue to monitor and bleed off. Cont. R/U , prep & stand mast, r/u accumulator lines, function test BOPE, run & winterize surface lines, spot catwalk, 12/10/2018 - Monday Shell test ROPE, repair leaks as needed. Test good. Pro -star completed program for elevator opening sequencing, blow down lines, download program & test same, make adjustments as needed until satisfied, re -test functioning several times, good. Re -flood surface eq. install 3-1/2" test jt, repair leaks on same. Test BOPE as per Hilcorp & AOGCC requirements, Witness waived by AOGCC inspector Bob Noble, test 250/ 3,000 with 3-1/2" TJ,. R/D test eq. Blow down lines, spot heater. Unwrap & work on re- orientating service loop. 12/11/2018 -Tuesday Perform fluid checks on all equipment, begin operations to straighten out hydraulic line service loop in derrick, prep to start pulling hanger. Check backside pressure @ 50psi, bleed off and pump 80 bbls 9.4 brine, shut down pumps and monitor backside pressure @ 0 psi. Continue with service loop repairs. Continue with service loop repairs. Monitoring well. Backside psi - 5psi. Pump 80 bbls 9.4 brine and monitor well @ Opsi, Unlock and pull hanger @ 55K up weight. POOH laying down 6 joints 3.5" work -string, and fishing BHA. Monitoring well at 0 psi Swap out elevators and prep to lay down 3.5 inch DSS -HT tubing Pump 10 bbls 9.4 brine down backside @ Opsi. Cont. POOH I/d 9.3# L-80 3 1/2" DSS -HT completion, recover 140 jts, 1 -cut jt, 6 GLM. Change out handling Eq as needed to I/d - slick stick w/overshot, packer, 3 jts 9.3# L-803 1/2" BTRS Tubing, Nipple, MTR (full recovery). Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig I API Number Well Permit Number Start Date End Date MP B -04A ASR / Pumper 1 50-029-20748-01-00 182-100 11/1/2018 12/14/2018 Daily Operations. 12/12/2018- Wednesday Check all fluid levels, move out all DSS -HT tubing and fish, move in 3.5" work -string, tally work -string, swap out lift gear and prep to run 3.5" work -string w/ 7" casing scraper with 6" tri -cone bit. Pumped 12 bbls 9.4 brine into well @ Opsi. RIH w/ 3.5" work -string with 7" casing scraper and 6" tri -cone bit - pumping 10bbls 9.4 brine every hour t/8,939', up wt 95k, do wt 48k. Pump 65 bbls down hole @ 4 bpm 0 pressure, no returns. POOH t/ surface, L/D scraper BHA. 12/13/2018 - Thursday Check all fluid levels in equipment, move in and lay out completion jewelry and tubing, change out lift gear and prep to run completion. P/U and run 3.5" 9.3# L-80 Tubing with completion equipment placed as per sundry. Pumping 10 bbls every hour 9.4 # NaCl brine down backside @ Opsi Currently at 6,166', up wt 53k, do wt 30k. Cont. rih w/ 3-1/2" 9.3# L-80 completion tubing t/8,882', up wt 87k, do wt 39k. M/U Hanger & landing joint. Mix & spot packer fluid @ 4 BPM, 0 PSI. Land hanger placing tubing tail @ 8,915.74', up wt 87k, do wt 39k, RI L/D pins, pack off seals t/6,800 psi good. Drop ball & rod, fill tubing, pressure up t/ 3,600psi set packer @ 8,820', cont. hold pressure 30 min (tubing test) good. Fill annulus, test packer t/ 2,500psi f/30 min, Good Test - Bleed off tubing and shear valve in top GLM, bleed of pressure to 0. 12/14/2018 - Friday MIRU Little Red and circulated 60 bbls diesel around backside and up tubing to freeze protect well. Complete circulation and RDMO Little Red. Bleed off well to 0 psi and monitor well with no flow. Install BPV and start RDMO ASR Rig. RDMO ASR rig to L-55. N/D BOPE, N/U tree & test 250, 5 min, 5k f/ 20 min GOOD, Pull BPV. Cont. R/D & move eq. t/ L pad 12/15/2018 -Saturday No activity to report. 12/16/2018 -Sunday No activity to report. 12/17/2018 - Monday No activity to report. 12/18/2018 -Tuesday No activity to report. THE STATE °fALASKA GOVERNOR BILL WALKER Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU B -04A Permit to Drill Number: 182-100 Sundry Number: 318-472 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www,aogcc.a[aska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French A; Chair DATED this Z -S day of October, 2018. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 �J;S l2,s/i 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q - Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: R&R Gaslift Completion Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 182-100 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-20748-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No Q MILNE PT UNIT B -04A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0047437 MILNE POINT/ KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,500' 7,280' 8,969' 6,887 2,940 8,82T 8,969' (Fill) Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Surface 2,300' 13-3/8" 2,300' 2,300' 1,661 psi 5,380psi Production 9,476' 7" 9,476' 7,256' 8,160psi 7,020psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3-1/2" 9.3# / L-80 / DSS -HT 8,916' Packets and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FHL Packer and Carrico TRDP-I-AENC SCSSSV 8,842(MO) / 6,797(TVD) and 1,889(MD) / t,889(TVD) 12. Attachments: Proposal Summary Q Wellbore schematic r 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/30/2018 OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: So York Contact Name: Stan Pothole Authorized Title: Operations Manager Contact Email: S Orh018 hilcor .corn Contact Phone: 777-8412 Authorized Signatur Dater Z d 1� Z V �N COMMISSION USE ONLY Conditions of approval: Ni5tify Commission so that a representative may witness Sundry Number: I —1 4I Plug Integrity 11? BOP Test �Mechanical Integrity Test ❑ Location Clearance 13/G Other: y Soo(-) !1 103• �L� 1' 1e -s r Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes El) No V Subsequent Form Required: 16 -4o-f APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I tiu / Form 10-403 Revised 4/2017 ORIGINAL i' iD-2<4V Submit Form and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate U R"e Alaskm LU Well Prognosis Well: MPU B -04A Date: 10/18/2018 Well Name: MPU B -04A API Number: 50-029-20748-01 Current Status: Sl Oil Well [Gaslift] Pad: B -Pad Estimated Start Date: October 30th, 2018 Rig: ASR #1 Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 182-100 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907) 444-2881 (M) AFE Number: 1824462 Job Type: Recompletion Current Bottom Hole Pressure: 2,640 psi @ 7,000' TVD (Last BHP measured 7/06/2018; 7.25 ppg EMW) Maximum Expected BHP: 2,640 psi @ 7,000' TVD (No new perfs being added) MPSP: 1,940 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU B -04A was drilled in 1982 using Nabors 27E and completed in the Kuparuk sands. During the initial completion in September 1985, it was found that the 7" casing was collapsed at 8', 182', and 222', as well as the 13-3/8" casing at 8'. The 7" casing was repaired and a patch set across the 13-3/8" using Nabors 27E in November 1985, with Arctic Pack located between these strings. The well was isolated with an XX plug in a profile to deal with high gas break thru in June 2014. Slickline and coil tubing have been unable to pull the plug due to debris in the plug, and the fishing neck has been damaged enough to prevent retrieval thru-tubing. The XX plug has a minor leak through the olue. but not enough to allow for sufficient hydraulic communication to pump at a high enough rate to effectively kill the well. Notes Regarding Wellbore Condition • Tubing has a XX plug at 8,816' MD stuck in the F -profile set on 6/05/2014. • Casing last tested to 2,500 psi for 30 min down to 8,842' on 6/05/2014 as part of a CMIT-TxIA. • Max angle 58.0" @ 5,000' MD. • Deviation at perfs is 45.0°. Objective: The purpose of this work is to pull the existing gaslift completion and packer and run a new gaslift completion and packer. Pre -Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 4,000 psi. 5. Circulate at least one wellbore volume with 8.7 ppg brine down tubing, taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. Brief RWO Procedure: Atzl Well Prognosis Well: MPU B -04A Date: 30/18/2018 10. MIRU Hilcorp ASR t#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.7 ppg brine prior to pulling BPV. Set TWC. annular to 250 each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 3-1/2" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: (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.) a. 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 test. 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.) 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. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ 8.7 ppg brine as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The estimated PU weight is 100K lassuming some friction while pulling the SBR seals). b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion ubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 3-1/2" tubing. Tubing will be junked. Lay down SBR seal assembly. a. Junk all joints of 3-1/2" tubing. b. Junk all gaslift mandrels and SCSSV and control line. c. Keep SBR seal assembly for visual inspection. d. Note any sand or scale inside or on the outside of the tubing on the morning report. 18. Contingency: (if unable to pull the SBR seal assembly.) a. MIRU E -line. Well Prognosis Well: MPU B -04A Hileora Alaska, LG Date: 10/18/2018 b. RIH w/ 3-1/2" chemical cutter and cut tubing at+/- 8,805' MD (just above XX plug). c. RDMO E -line. d. PU overshot and jar BHA for 3-1/2" tubing. e. RIH with overshot on 3-1/2" workstring to top of 3-1/2" cut tubing at±8,805' MD. f. Engage tubing stub and attempt to pull the SBR seal assembly free up to 160k. g. POOH and lay down the SBR seal assembly. i. Contingency: (If unable to pull the SBR seal assembly free.) ��s I 1. RU Casing Jacks. 2 Attemptensilet 3 PI'SBR G se workstring). assembly free using jars and keeping pull below 215k (80% 3. Once free, pull 3 stands to confirm SBR seal assembly is free. 4. RD Casing Jacks. 5. POOH and lay down the 3-1/2" workstring. Lay down SBR seal assembly. 19. PU slickjoint overshot and jar BHA for 3-1/2" tubing. 20. RIH with slickjoint overshot on 3-1/2" workstring to top of slickjoint at ± 8,816' MD. 21. Engage fish and attempt to pull the slickjoint and packer and tail pipe free up to 160k. Attempt to rotate free if unable to pull free. 22. Pull 1 stand to confirm the packer is free. Circulate the well clean with 8.7 ppg brine to clear any gas from below the packer. Contingency: (If unable to pull the slickjoint and packer free.) a. RU Casing Jacks. b. empt to pull the slickjoint and packer free using jars aid,�k,eeping pull below 21 (80% tensile of 3-1/2" G-105 workstring). �_ &P� J f)L c. Once free, pull 3 stands to confirm the packer is free. U d. RD Casing Jacks. 24. POOH and lay down the 3-1/2" workstring. Lay down slickjoint and packer and tail pipe. a. Keep slickjoint and profile for inspection. 25. RIH with casing scraper BHA for 7" 29# casing to work down to above the top perforations at ± 8,936' MD on 3-1/2" workstring. 26. Circulate the well clean with 8.7 ppg brine. 27. POOH and LD 3-1/2" workstring and casing scraper assembly. 28. PU completion and RIH on 3-1/2" tubing. a. Tubing is 3-1/2" 9.3# L-80 EUE (Range 2). b. GLMs spaced out per the proposed schematic. c. Packerat±8,840'MD d. 3-1/2" XN (2.750" Min ID) at±8,875' MD. [Pre -load RHC plug body] e. 3-1/2" tubing tail at ± 8,910' MD 29. Circ inhibited 8.7 ppg brine packer fluid and freeze protect fluid. 30. Drop ball and rod. Pressure up and set Packer (start 2,000 psi/final 3,500 psi). 31. Pressure test tubing to 3,500 osi for 30 min and chart Rlppd tiihina to 1 S00 -psi. 32. Test inner annulus to 2,500 psi for 30 min and chart. Monitor tubing for packer leak. 33. Bleed tubing to 0 psi. Pop shear valve from annulus to tubing (2,000 psi differential). H ua. P am,ta. LU Well Prognosis Well: MPU B -04A Date: 10/18/2018 34. Freeze protect annulus and tubing. 35. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 36. Set BPV. Rig down ASR. Post -Rig Procedure: 37. RD mud boat. RD ROPE house. Move to next well location. 38. RU crane. ND BOPE. 39. NU existing 3-1/8" 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 40. RD crane. Move 500 bbl returns tank and rig mats to next well location. 41. Replace gauge(s) if removed. 42. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO Changes Form 0 Hilrnru Alaew. LLC Orig.DF Elev.: 59.9/ GL Elev.: 35.9 (Nabors 27E) 20' T r i -S t at e•� Arctic Pack 351ng Patc d i ]3-3/8' Fish:XX-Plug @ 8,827 CTM Equalizing Port Open E Milne Point Unit Well: MPU B-O4A SCHEMATIC Last Completed: 11/8/1985 PTD: 182-100 TREE & WELLHEAD Tree 3-1/8" 5M CIW 8RD Tree Cap 13-3/8" Tag Adapter 11" x 3-1/8" 5M CIW Wellhead Tag Hgr. 11" x 3-1/2" IBT Type 3" CIW-H BPV Profile OPEN HOLE / CEMENT DETAIL 20" Cemented to Surface in 30" Hole 13-3/8" 3600 sks Permafrost Cement in 17-1/2" Hole 7„ 1,000 sks Class "G", 300 sks Class "C" & Type 200bbls of Arctic Pack ina 8-1/2" Hole 2 3 4 DVTool 2,094 Item @8,969' RKB CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 94/PE/N/A N/A 0 80' 13-3/8" Surface 72 / K-55 / BTC 12.347 0 101' 72 / L-80/ BTC 12.347 101' 2,300' 7" Production 29 / L-80/ BTC 6.184 0 9,476' TUBING DETAIL 3-1/2" Tubing 9.3/N-80/DSS-HT 1 2.992 0 8,916' 5 WELL INCLINATION DETAIL KOP @ 2,200' 6 Max Hole Angle JEWELRY DETAIL 7 8 I CBLTOC 8,014' 7/20/82 9 10 14 Fill Tagged �15 Item @8,969' RKB 1,889' Camco TRDP-I-AENC SCSSV-Locked Out 9/3/1999 - ID= 2.812" 5/21/14 16 KLP G1 3 2,787' KUP &7 Fish: Van 3,455' i Perforating gun, 4,310' ' Calculated top 5,203' !� @9,305, MD 6,032' STA#5: Camco 3-1/2" KBUG GLM's w/ 1" LGLV set 4/03/11 8 6,802' KUP 885' 9 7,444' STA#3: Camco 3-1/2" KBUG GLM's w/ 1" LGLV set 4/03/11 TD=9,509 (MD) TD 7,2801M) PBTD = 9,387 (MD) / PBTD= 7,19fMO) No Depth Item 1 1,889' Camco TRDP-I-AENC SCSSV-Locked Out 9/3/1999 - ID= 2.812" 2 2,117' STA#10: Camco 3-1/2" KBUG GLM's w/ 1" LGLV set 4/03/11 3 2,787' STAN: Camco 3-1/2" KBUG GLM's w/ 1" Dummy 4 3,455' STAN: Camco 3-1/2" KBUG GLM's w/ 1." Dummy 5 4,310' STA#7: Camco 3-1/2" KBUG GLM's w/ 1" LGLV set 4/03/11 6 5,203' STA#6: Camco 3-1/2" KBUG GLM's w/ 1" Dummy set 6/28/05 7 6,032' STA#5: Camco 3-1/2" KBUG GLM's w/ 1" LGLV set 4/03/11 8 6,802' STAN: Camco 3-1/2" KBUG GLM's w/ 1" Dummy (No Latch) 6/28/05 9 7,444' STA#3: Camco 3-1/2" KBUG GLM's w/ 1" LGLV set 4/03/11 10 8,117' STA#2: Camco 3-1/2" KBUG GLM's w/ 1" Dummy 11 8,790' STA#1: Camco 3-1/2" KBUG GLM's w/ 1" OGLV set 5/27/15 12 8,816' Otis'X' Nipple, ID= 2.813" (Stuck & Damaged XX Plug set 6/05/14) 13 8,816' Baker SBR Seal Assembly, 3' above Packer (seals over 3-1/2" slick joint) 14 8,842' Baker FHL Packer ID= 3.00" 15 8,878' Camco'D' Nipple, Min ID= 2.750" 16 8,916' Tubing -Fail (Min ID=2.750"@ Mech Tbg Release) PERFORATION DETAIL Sands Top (MD) Btm (MD) Tap (TVD) Btm (TVD) FT SPF Date Status KUP C-1 8,936' 8,954' 6,864' 6,877' 18 8 11/18/85 Open KUP B-7 8,960' 8,990' 6,881' 6,902' 30 12 7/26/82 Open KUP B-6 9,182' 9,184' 7,042' 7,043' 2 4 7/17/82 Squeezed GENERAL WELL INFO API: 50-029-20748-01-00 Sidetracked and Completed by Nabors 27E -7/22/1982 Attempted Recompletion by Rol'n' 4-9/24/85 Casing Repaired by Nabors 27E -11/2/1985 NOTE: GLM STA #4 has a DV with no latch attached. The wobble washer and spring are lost in the wellbore. CMIT-TxIA to 2,500 psi (passed) on 6/05/2014 Revised By: TDF 11/8/2017 K llik,ora Alaska, LLC Orig.DF Elev.: 59.0(/ GL Dev.: 35.0' (Nabors 27E) 3-1/8" 5M CIW 8RD Tree Cap Wt/ Grade/ Conn Tbg Adapter 11" x 3-1/8" 5M CIW Wellhead Tbg Hgr. 11" x 3-1/2" IBT 20" 3" CIW-H BPV Profile 94/ PE / N/A N/A 0 80' 13-3/8" Surface 72 / K-55 / BTC 12.347" 0 101' 72 / L-80 / BTC 12.347" 101' 2,300' 7" Production 29/L-80/BTC 20" 0 9,476' STA#3: PATCO GLM (dummy valve installed )1.5" RK 9 ±8,125' STA#2: PATCO GLM (dummy valve installed) 1.5" RK 30 ±8,775' STA#1: PATCO GLM (dummy valve installed )1.5" RK Tri-State ±8,840' 7" x 3-1/2" Halliburton TNT Permanent Packer 12 r /ucdc Pads Casing Pav_ 13 ±8,910' WLEG 13-3/8' 1 2 DV To Z�, 3 4 s s CBLTOC g 8,014' 7/2_0/82 Fill TaggedV 13 @ $969' RKB 5/21/14 Fish: Van Perforatinggun, Cakulated top @9,305' MD 7' PROPOSED TREE & WELLHEAD Milne Point Unit Well: MPU B -04A Last Completed: Proposed PTD: 182-100 Tree 3-1/8" 5M CIW 8RD Tree Cap Wt/ Grade/ Conn Tbg Adapter 11" x 3-1/8" 5M CIW Wellhead Tbg Hgr. 11" x 3-1/2" IBT 20" 3" CIW-H BPV Profile OPEN HOLE / CEMENT DETAIL 20" Cemented to Surface in 30" Hale 13-3/8" 3600 sks Permafrost Cement in 17-1/2" Hole 7„ 1,000 sks Class "G", 300 sks Class "C" & 200bbls of Arctic Pack ina 8-1/2" Hole CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 94/ PE / N/A N/A 0 80' 13-3/8" Surface 72 / K-55 / BTC 12.347" 0 101' 72 / L-80 / BTC 12.347" 101' 2,300' 7" Production 29/L-80/BTC 6.184" 0 9,476' TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE 2.992" 0 8,910' WELL INCLINATION DETAIL KOP @ 2,200' Max Hole Angle = 58 deg. @ 4,900'- 5,200' JEWELRY DETAIL No Depth Item 1 ±2,100' STA#10: PATCO GLM (2,000 psi shear out valve installed )1.5" RK 2 ±2,800' STA#9: PATCO GLM (dummy valve installed 11.5" RK 3 ±3,450' STA#8: PATCO GLM (dummy valve installed ) 1.5" RK 4 ±4,300' STA#7: PATCO GLM (dummy valve installed ) 1.5" RK 5 ±5,200' STA#6: PATCO GLM (dummy valve installed) 1.5" RK 6 ±6,000' STA#5: PATCO GLM (dummy valve installed) 1.5" RK 7 ±6,800' STA#4: PATCO GLM (dummy valve installed) 1.5" RK 8 ±7,450' STA#3: PATCO GLM (dummy valve installed )1.5" RK 9 ±8,125' STA#2: PATCO GLM (dummy valve installed) 1.5" RK 30 ±8,775' STA#1: PATCO GLM (dummy valve installed )1.5" RK 11 ±8,840' 7" x 3-1/2" Halliburton TNT Permanent Packer 12 ±8,875' Halliburton'%N' Nipple, Min ID= 2.750" 13 ±8,910' WLEG PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Date Status KUPC-1 8,936' 8,954' 6,864' 6,877' 18 8 11/18/85 Open KUP B-7 8,960' 8,990' 6,881' 6,902' 30 12 7/26/82 Open KUP B-6 9,182' 9,184' 7,042' 7,043' 2 4 7/17/82 Squeezed GENERAL WELL INFO KLP G1 API: 50 -029 -20748 -01 - KIP 13-7 Sidetracked and Completed by Nabors 27E -7/22/1982 Attempted Recompletion by Rol'n' 4 -9/24/85 Casing Repaired by Nabors 27E -11/2/1985 TI) =9,5W (MD) /TD =7,2WMO) PBTD = 9,387 (NA) / PBTD = 7,191'(TVD) NOTE: GLM STA #4 has a DV with no latch attached. The wobble washer and spring are lost in the wellbore. CMIT-TAA to 2,500 psi (passed) on 6/05/2014 Revised By: STP 10/18/2018 Milne Point ASR Rig 1 BOPE Il:l.orp A4.4.. I.IA; 2018 11" BOPE Om Stripping Head 1 IIN IMP 5. jjmBlind 2 1/16 5M Kill Line Valves 1 2 1/16 5M Choke Line Valves I71 III ilI Iil III �� 1 r I�1.111 Updated 5/14/2018 Manual HCR MPU B EXISTING TREE/WELLHEAD Wellhead/Tree Hilcnrp Ala»kn. r.Lc Milne Point Unit Tree C Tree Valve 3 Tree Cross 3 SSV 3-1/8' Tree Valve 3-1/ Tubing Ad Tubing Hee 11"5MTop x11" Casing Hea 11"5M Top x11" Tree Valve 3-1/8" 5M UHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: October 16, 2018 Subject: Changes to Approved Sundry Procedure for Well MPB-04A Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first calf' engineer. AOGCC written approval of the change is required before implementing the change. HAK HAK AOGCC Written Step Page Date Procedure Change Prepared Approved Approval Received B Initials B Initials Person and Date Approval: Prepared: Operations Manager Date Operations Engineer Date Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Wednesday, October 24, 2018 4:23 PM To: Schwartz, Guy L (DOA) Subject: RE: [EXTERNAL] B -04A RWO (PTD 182-100) Guy, Yes. Pulling the bottom valve to circulate and kill the well. The rate through the plug is more of a slow leak off. No real sustainable injection rate. Just a slow bleed. About 150 psi in 10 minutes. Stan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, October 24, 2018 3:57 PM To: Stan Porhola <sporhola@hilcorp.com> Subject: [EXTERNAL] B -04A RWO ( PTD 182-100) In your procedure are you going to pull the bottom OV in order to circulate fluids to kill well? (with SL before rigging up BOP?) What kind of rate can you pump through the leaking XX plug? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(sl. It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz@olaska aov). RECE1V � `�2_- °0 "jig JUN 19 2011 • 2�3�� BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY ACCACdtjlin Alaska Inc. BP Exploration (Alaska) Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED Co/t.4/2017 WELL NAME B-04A 900 E. Benson Blvd. M.K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE May 30,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares(a�bakerhughes.com TODAYS DATE June 16,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF, META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO* LOGS LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OFPRINTS #OF PLAIN IS #OF COPIESI #OF COPIES #OF COPIES V V V v V V 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. SCANNED JUN 2 ' cult. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 \,.y4 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 0 0 'Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 11 6 BP Exploration(Alaska)Inc. 0 0 0 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Behrooz Raessi TOTALS FOR THIS PAGE: 0 3 4 0 STATE OF ALASKA AN6KA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate LJ Pull Tubing A Operations shutdown LI Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑✓ ❑ Fill Clean-out Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other: Pull Plug w/Coil ❑✓ 2. Name: 4.Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska,LLC Development ❑i Exploratory ❑ 182-100 3.Address: Stratigraphic❑ Service Li 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-20748-01-00 / 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047437 ` MILNE PT UNIT KR B-04A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 9,500 ' feet Plugs measured N/A -feet Z E','V „`D true vertical 7,280 + feet Junk measured 8,612&9,305 feet IEC 082015 Effective Depth measured 8,612 feet Packer measured 8,842 feet true vertical 6,638 feet true vertical 6,797 feet AOGGC" Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Surface 2,300' 13-3/8" 2,300' 2,300' 1,661psi 5,380psi Production 9,467' 7" 9,467' 7,256' 8,160psi 7,020psi Perforation depth Measured depth See Attached Schematic Y;. aor ° STP 1 9 2016 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80/DSS-HT 8,916' 6,850' 8,842(MD) 1,889(MD) Packers and SSSV(type,measured and true vertical depth) FHL Packer TRDP-1-AENC SCSSV 6,797(TVD) 1,889(TVD) 12.Stimulation or cement squeeze summary: N?A Intervals treated(measured): N/A 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: 0 0 0 500 152 Subsequent to operation: 0 0 0 500 0 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑i Exploratory❑ Development E ' Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ • Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 315-539 Contact Stan Porhola Email sporhola(CD.hilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date ti' r)t 1 .c 7,6 /2 -1 5.---"/ /-/L4 7/r RBDM � SEC 1 1 2015 Form 10-404 Revised 5/2015 Submit Original Only H . Milne Point Unit Well: MPU B-04A SCHEMATIC Last Completed: 11/8/1985 Ihlioru Alaska,,LLC PTD: 182 100 TREE&WELLHEAD Orig.DF Elev.:59.0'/GL Elev.:35.0'(Nabors 27E) Tree 3-1/8"5M CIW 8RD Tree Cap Tbg Adapter 11"x 3-1/8"5M CIW Wellhead Tbg Hgr.11"x 3-1/2"IBT 20' 3"CIW-H BPV Profile OPEN HOLE/CEMENT DETAIL n 20" Cemented to Surface in 30"Hole " ' Arctic Pack 13-3/8" 3600 sks Permafrost Cement in 17-1/2"Hole 1,000 sks Class"G", 300 sks Class"C"& 200bbls of Arctic Pack ina 8-1/2"Hole 0 2 CASING DETAIL 13-3/8" 1 Size Type Wt/Grade/Conn Drift ID Top Btm BPF 3 DVTool 20" Conductor 94/Pelp/N/A N/A 0 80' 0.355 2,094' 13-3/8" Surface 72/L-80/BTC 12.347 0 2,300' 0.148 7" Production 29/L-80/BTC 6.184 0 9,476' 0.0372 4 TUBING DETAIL 3-1/2" Tubing 9.3/L-80/DSS-HT 2.992 0 8,916' 0.0087 WELL INCLINATION DETAIL 5 KOP @ 2,200' Max Hole Angle=58 deg.@ 4,900'-5,200' 6 ' JEWELRY DETAIL No Depth Item 1 1,889' Camco TRDP-1-AENC SCSSV-Locked Out 9/3/1999-ID=2.812" 7 GLM Detail-Camco 3-1/2"KBUG w/BK Latch,1"Dummy Valve&2.875"ID 2 2,117' ST 10:TVD=2,117',Dev.=0 3 2,787' ST 9:TVD=2,786',Dev.=9 • 4 3,455' ST 8:TVD=3,394',Dev.=34 N 8 5 4,310' ST 7:TVD=3,992',Dev.=51 6 5,203' ST 6:TVD=4,507',Dev.=57 7 6,032' ST 5:TVD=4,994',Dev.=52 • 8 6,802' ST 4:TVO=5,491,Dev.=48: aj 9 9 7,444' ST 3:TVD=5,901',Dev.=53 10 8,117' ST 2:TVD=6,318',Dev.=50 11 8,790' ST 1:TVD=6,760',Dev.=45 Fish:XX-Plug @ • 12 8,816' Baker SBR Seal Assembly w/2.813"HES'X'Nipple ±8,827'CTM a 10 13 8,842' Baker FHL Packer ID=3.00" 14 8,878' 3-1/2"OTIS'X'Nipple,ID=2.813" 15 8,916' Tubing Tail 11 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Status 12 MK-1 8,936' 8,954' 6,864' 6,877' 18 8 Open s 7-74 8,960' 8,990' 6,881' 6,902' 30 12 Open 13 MK-2 9,182' 9,184' 7,042' 7,043' 2 4 Squeezed 1' '69 / 14 GENERAL WELL INFO API:50-029-20748-01-00 15 nM 1 Sands Drilled,Cased and Completed by Nabors 27E -11/2/1985 nx-2 Sands NOTE: Van SPM#4 has a DV with no latch attached. The wobble Perforating gun, washer and spring are lost in the wellbore Calculated top @9,305MD �► r NK 2 Squeezed TD=9,5(XY(MD)/TD=7,280'(1VD) PBTD=9,382'(MD)/PBTD=7,191'(TVD) Revised By:TDF 12/1/2015(V) • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-04A CTU 50-029-20748-01-00 182-100 11/13/15 11/16/15 Daily Operations: 11/11/2015-Wednesday No activity to report. 11/12/2015-Thursday No activity to report. 11/13/2015- Friday Hold safety meeting. Discuss job procedure and daily objectives. Review and discuss potential hazards and mitigation measures.MIRU CTU 4.Spot support equipment.Vac truck from rig emptied upright. Bed truck move upright to Baker pad. Fill upright with 150 bbls of leftover safe lube.Vac truck to grab 150 bbls of 80 degree seawater from CPF1. CTU rigging up. Coil crew had issues with wellhead flange bolts being rusted.Start BOPE test with 60/40 methanol.Test all rams and valves to 250psi low/4,500psi high. Draw down test on accumulators completed. BOP test passed and completed. Secure location. Crews off location.Venturi lined up for 0700 hrs. Pad operator notified. 11/14/2015-Saturday Fire equipment. Hold safety meeting. Discuss job procedures. Review SLB JSA.Talk about hazards associated with making up tools. Discuss temperature of-15 and wind chill of-30. Pick injector head. Stab 20 ft lubricator. Make up internal dimple connector. Pull test to 25K. Make up DFCV,disconnect. Pressure test 250psi low/4,500psi high. Good PT. Bleed down. Make up x-over ventrui junk basket.Tools as follows: Internal Dimple OD 2", DFCV OD 2.13", BiDi Jars OD 2.15", Hydraulic Disconnect 2.125",X over OD 2.13",Venturi Junk Basket OD 2.625",dressed with scalloped Mule shoe loaded with dual debris traps. Had troubles opening SSV. SSV open. (pressure trapped between swab and SSV). Flood up sea water from upright.Circulate 60/40 out to holding tank. Corrected coil depth to RKB. Input depth at coil zero of 18'. Swap to open top.82 degree sea water flooded up. IA pressure 180psi.WHP 300psi.Swab master 18 turns. RIH.Weight check at 4,000'. 14.5k. RIH wt 11k. RIH wt 15k at 8,500'. Pickup weight 26.5k. Clean. RIH.Stack 5k at 8,790'. Mechanical says 8,787'. Pick up off fish at 27.5k at 1.0 bbls/min. Pick up to 8,767'. Increase rate to 1.9 bbls/min 3,300psi circ 90psi whp. RIH to start venturi run.Stack weight at 8,790.6'.6k down increase circ pressure from 3,300psi to 3,600psi. Previous runs SL tagged at 8,793'. Pick up off fish 20 ft at 2bbls/min 3,670psi.Stack at 8,789'. Sit for 3 minutes. Pick up 50 ft. RIH 30ft/min stack 8k. 2 bbls/min 3,587psi.Wait 3 minutes. POOH to surface. 3 attempts on top of fish. While POOH noticed leak at tank threaded pipe fitting. Run back in hole to bottom. Shut down pump.Attempt to tighten fitting. Isolate choke. Close P subs.Open choke. Blow down line to tank. Fitting fixed. POOH.Online 1.5 bbls/min. Tagged up. Swab master closed 18.5 turns. Lined up on 60/40 freeze protect coil. 264 bbls pumped. Break down tools. Check venturi.Small dixie cup full of scale. Break down tools to connector. Tool hand off location. Install nozzle. Stab on well. Pressure test stack to 250psi low/4,500psi high. Bleed down. Open up to RIH to freeze protect wellbore @ 2,500 ft. Pumping 12 bbls of 60/40 for bottoms up. POOH to surface. Master swab closed blown down to OT. Pop off well. Set injector on back deck. Install night cap on BOPs. V Location secure.Total BBLS pumped for venturi run 264 bbls. r • S • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-04A CTU 50-029-20748-01-00 182-100 11/13/15 11/16/15 Daily Operations: 11/15/2015-Sunday Discuss rig up of MHA motor/mill. Review1SA. Pick injector head. Make up MHA. Pt 250psi low/3,500psi high. Good PT. Make up motor mill. BHA description. Internal dimple connector 2.0" OD, DFCV 2.14"OD,G Force jars 2.25" OD, FAU disco 2.13"OD, DACS 2.13" OD, Mud Motor 2.123"OD,specialty mill 2.8" OD. BHA length 20.72'. Pressure test lubricator 250psi low/3,500psi high. IA pressure 296psi. Column of Gas. Coil zero corrected depth to RKB. Input depth of 18'. Open master swab 18 turns.RIH, 51psi whp. RIH with choke closed. Pressured up wellbore to 1,000 psi. Stop coil. Pressure holding. Confirmed XX plug and tubing integrity. Bleed down to OT.Continue RIH. Passed through min id at SSSV. Online with seawater down CT.Zeroed totalizer 33 bbls away. 27.6K wt chk. Parked at 8,478'. Circulating out 60/40 Meth with 95 degree seawater @ .7 bbls/min.741psi pump pressure. 299psi IA pressure. 16.5 RIH wt. @ 8,697'. 60/40 circulated out. Down on pump for dry.Tag at 8,832.5' 30k. Come online 1.5 bbls/min.2,700psi freespin at 1.5 bbls/min. Headed down to fish.8,830.5 stall motor. Pick up heavy 35k back on line 1.5 bbls/min 2,500psi. Headed back down to fish. Milling at 8,830.4'.200psi increase. milling 8,830.6'. 300psi motor work. 8,831.4' milling 400psi motor work. 3,100psi circ pressure. 8,831.4' motor work not breaking off. Pick up off fish. Pressure dropped 8,829.3'. RIH milling 8,831.2'.Stacking 4k. 500psi over. RIH at .3ft/min.Could possibly be spinning plug. 8,832.7'.Pick up out of fish. 8,830.7 up wt 30k normal start pulling over 35k. Weight broke back to normal 30.5k. Online with pump 1.5 bbls min. RIH at 5 ft a minute attempt to stall motor. RIH wt 15.3k,attempt to spud into xx to stall motor. 8,831.6 stall motor. Pick up 20 ft. RIH at 10. Stack 700psi motor work. 5k down on fish. NO stall. Pick up 8,798.7'. RIH dry tag 8,832.7'. Stack 4k down. Going to surge pump to 4k psi to attempt to spin off bull plug. 5k down. Ramp pump up to 3,800psi. Hard shut down. Pick up out of fish 8,820'. Online 1.5 bbls/min. RIH 25 ft/min attempt to hard stall. POOH to check mill. Stacked to 8,835.2'.Attempt injection test. Pressure up to 1,000psi on tubing. Pressure and coil dropped of together. POOH to check bit. At surface. Master swab closed. Break down mill and motor. Good marks on mill. Looks like we made it into the fishing neck and atop bull plug.Send pictures to town. Install 3in GS spear.Stab on well. Pressure test stack 250psi low/3,500psi high. Open well RIH at 5,353'. Close choke in. Attempt to pressure up wellbore while RIH and pumping.7 bbls min. 1,400psi on wellhead.Slowly dropping.Steady bleed down. Communication with formation. NO change in IA pressure 300psi IA. Bleed down.Continue to RIH. Circulate 60/40 meth into CT string for freeze protect. RIH, pick up weight at 8,500'. 28K clean. 15k RIH weight. 8,840' stack 10k down. Stack 15k down. Pick up. 29K. No over pull. Lined up 60/40 down back side @ 48 bbls away started pumping down back side. Pressure bleed of the same prior to attempting to latch xx plug. Rih stack 15k down. Pressure 1,384psi. Slowly dropping. RIH stack 17k down. POOH to surface see what we have. No indication of overpull. All three stacks at 8,840', 8,840.1', 8,841.6'.Tagged up at surface.Swab master closed 18 turns. Blow down stack. Pop off well. 272 bbls pumped. No Plug at surface. Break down tools. No signifcant marks on GS nose. Stack down lubricators to swap pack offs. Location secure. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-04A CTU 50-029-20748-01-00 182-100 11/13/15 11/16/15 Daily Operations: 11/16/2015-Monday Arrive unit. Check oil. Fire equipment. Pick injector head,stab 2 10'joints of lubricator. Make up BHA.Slim CC 2.0"OD, 2.13" DFCV, 2.125" BiDi Jars, 2.125" FAUT disco, 3.0" GS spear, baited sub with 3"SL Super GS spear with Grip teeth on colletts. Stab on well. Corrected to RKB. Entered depth of 18'on CCAT.BHA 10.76'. Baited sub 1',SL GS.9'. Pressure test down back side with 60/40 methanol. 250psi low/3,500psi high. Bleed down to OT Open well 18.5 turns master and swab. Initial WHP 0 psi. Open well RIH.Start building WHP at 1,882', 525 psi. Slowly bleeding down. Perform weight check at 8,500', 23k(coil void from yesterdays run). RIH wt. 12k, wt chk @ 8,820', 23k, 22.5-22.9 break over weight. RIH to tag fishing neck. 3k down @ 8,827.4'. PU off fish 24k, 1k over pull.RIH tagged @ 8,827.4'. PU 23.5k, no indication of overpull. Lined up 60/40 down CT annulus.Attempt to inject. Pump 3 bbls down back side. Wellhead pressure climbed to 1,000psi. Bleeding down same as previous attempts. Stack 2k down.950 on choke. Dump pressure to OT fast.Stack 7k. Pick up 27k, 4k overpull. Parked at 8,612'.Attempt to inject down back side 500psi. Shut down pumps. Still not injecting. Dump back side pressure. RIH to stack on fish one more time. 12k RIH wt. RIH 60 ft/min stack 12k down. PU. POOH to surface. OOH. Close swab and master 18.5 turns. Blow down to OT. Pop off well. No xx plug. Break down tools. Start Rigging down. Ticket closed out. Moving to S-35. 11/17/2015-Tuesday No activity to report. WON OF 771• :4,��w1s7 THE STATE Alaska Oil and Gas �,�; ofA LAsKA Conservation Commission s =_--=- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFLAS*3 Fax: 907.276.7542 iktk"C`` r '" www.aogcc.alaska gov Stan Porhola j o b Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 95503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR B-04A Sundry Number: 315-539 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this of September, 2015 p Encl. RECEWED STATE OF ALASKA AUG 3 1015 ALASKA OIL AND GAS CONSERVATION COMMISSION YT.S `U / f-s APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing ❑ 'Fill Clean-out Q Plug for Redril❑ Perforate New Pool ❑ - Repair Well ❑✓ Re-enter Susp Well 0 - Other: Pull Plug w/Coil ❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC - Exploratory ❑ Development 2 - 182-100 - 3.Address: Stratigraphic 0 Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-20748-01-00 7 If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.432C • Will planned perforations require a spacing exception? Yes ❑ No ❑., ✓ MILNE PT UNIT KR B-04A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047437 - MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured). Junk(measured): 9,500 • 7,280 - 8,969 ` 6,887 - 9,382' 8,969'(Fill) Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Surface 2,300' 13-3/8" 2,300' 2,300' 1,661psi 5,380psi Production 9,476' 7" 9,476' 7,256' 8,160psi 7,020psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80/DSS-HT 8,916' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft). Baker FHL Packer and Camco TRDP-1-AENC SCSSSV -8,842(MD)/6,797(TVD)and 1,889(MD)/1,889(TVD) 12.Attachments: Description Summary of Proposal Q 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: 9/15/2015 Commencing Operations: OIL Q . WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: N/A GAS 0 WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: N/A GINJ 0 Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporhola@hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature kned---- Phone 777-8412 Date 8/31/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Ck Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 12( Subsequent Form Required: (p y 011 APPROVED BY Approved by:aie, __ COMMISSIONER THE COMMISSION Date.9—g -/ J y_ 1.2•1s` liql lull's rialr pliN Lfe g Duplicate Form and Form 10-403 Revised 5/2015 o i V lid r 12 moot ��m the date of approval. Attachments in Du licate Well Prognosis Well: MPU B-04A Hilcorp Alaska,Lb Date:8/28/2015 Well Name: MPU B-04A API Number: 50-029-20748-01 Current Status: SI Oil Well [Gaslift] Pad: B-Pad Estimated Start Date: September 15th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 182-100 _First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,967 psi @ 7,000' TVD (Last BHP measured 7/20/2012) Maximum Expected BHP: 1,967 psi @ 7,000' TVD (No new perfs being added)l Max.Allowable Surf Pressure: 0 psi (Based on SBHP taken 7/20/2012 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000'ND of oil cap) Brief Well Summary: MPU B-04A was drilled in 1982 using Nabors 27E and completed in the Kuparuk sands. The well was isolated with an XX plug in a profile to deal with high gas break thru in 2014. Slickline has been unable to pull the plug due to debris in the plug. Notes Regarding Wellbore Condition • Tubing has a XX plug at 8,816' MD stuck in the upper X-profile set on 6/05/2014. • Casing last tested to 2,500 psi for 30 min down to 8,842'on 6/05/2014 as part of a CMIT-TxIA. Obiective: The purpose of this work/sundry is to pull the XX plug in the upper X-profile and clean out fill. Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 2. RIH w/2.00"coil w/2.5"wash nozzle and cleanout to top of XX plug+/-8,816' MD. POOH. a. Min ID is 2.813"thru X-profile. 3. RIH w/2.00"coil w/GS pulling tool and pull XX plug+/-8,816' MD. POOH. `V 4. RIH w/2.00"coil w/2.5"wash nozzle to TOF(top of fish)at+/-9,305' MD. POOH. V 5. RD Coiled Tubing. 6. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic Milne Point Unit • II Well: MPU B-04A SCHEMATIC Last Completed: 11/8/1985 Hilcorp Alaska,LLC PTD: 182-100 CASING DETAIL Orig.DF Elev.:59.0'/GL Elev.:35.0'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm L 4t ` 1{ ih 20" Conductor 94/Pelp/N/A N/A 0 80' ti , .�,4 13-3/8" Surface 72/L-80/BTC 12.347 0 2,300' 217 # t - 7" Production 29/L-80/BTC 6.184 0 9,476' r 'KV 1?fi, ,, TUBING DETAIL '*Lr 4< Arctic Pack 3-1/2" Tubing 9.3/L-80/DSS-HT 2.992 0 8,916' 1 l; ft : 4 ( 1 �t'$ JEWELRY DETAIL r , .,, I ' ,. No Depth Item 2 1 1,889' Camco TRDP-1-AENC SCSSV-Locked Out 9/3/1999-ID=2.812" l 2 2,117' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" 3/ga r� k • 3 2,787' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" 3 DV Tool 2 4 3,455' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" p ' 5 4,310' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" F 6 5,203' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" 4 t x 7 6,032' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" lij 8 6,802' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" ` r 9 7,444' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" 4 5 10 8,117' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" 11 8,790' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" 12 8,816' Baker SBR Seal Assembly w/2.813"HES'X'Nipple'XX'plug stuck w/fill i $4, 13 8,842' Baker FHL Packer ID=3.00" %. 6 5.1 14 8,878' 3-1/2"OTIS'X'Nipple,ID=2.813" 15 8,916' Tubing Tail A 67 PERFORATION DETAIL 7 1 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Status 1 MK-1 8,936' 8,954' 6,864' 6,877' 18 8 Open .R r` MK-2 8,960' 8,990' 6,881' 6,902' 30 12 Open A 8 9,182' 9,184' 7,042' 7,043' 2 4 Squeezed u WELL INCLINATION DETAIL e. KOP @ 2,200' 9 A Max Hole Angle=58 deg.@ 4,900'-5,200' tkle TREE&WELLHEAD Tree 3-1/8"5M CIW 8RD Tree Cap 10 Tbg Adapter 11"x 3-1/8"5M CIW Wellhead Tbg Hgr.11"x 3-1/2"IBT 3"CIW-H BPV Profile l° 11 OPEN HOLE/CEMENT DETAIL ,ç. ,(. T'" 20" Cemented to Surface in 30"Hole - 'IIII--4J P 13-3/8" 3600 sks Permafrost Cement in 17-1/2"Hole 12 �[ T 1,000 sks Class"G", 300 sks Class"C"& F Pi ►_4rA 13 �` 7 200bbls of Arctic Pack ina 8-1/2"Hole P fGENERAL WELL INFO J14 API:50-029-20748-01-00 A. Drilled,Cased and Completed by Nabors 27E -11/2/1985 E" 15 4IvI(1sands NOTE: ,.' ��N1<2 Sands SPM#8 has a DV with no latch attached. The wobble Fish:Van u ,4 washer and spring are lost in the wellbore Perforating gun, #t Calculated top , !e @ 9,305 MD MK 2 Squeezed tie 11,1.7 Ins ID=9,500'(MD)/TD=7,280111/D) (TVD) PBTD=9,382'(MD)/PBTD=7,191'(TVD) Revised By:STP 8/28/2015 Milne Point Unit • Well: MPU B-04A PROPOSED SCHEMATIC Last Completed: 11/8/1985 'blear')Alaska,LLC PTD: 182-100 CASING DETAIL Orig.DF Elev.:59.0'/GL Elev.:35.0'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 94/Pelp/N/A N/A 0 80' 4 + 4 1 k 13-3/8" Surface 72/L-80/BTC 12.347 0 2,300' 20' +# 7" Production 29/L-80/BTC 6.184 0 9,476' TUBING DETAIL ` ` =Arctic Pack 3-1/2" Tubing 9.3/L-80/DSSHT 2.992 0 8,916' ' �, -7i ''= JEWELRY DETAIL ' '"ct 1 t `,,:�. No Depth Item 01:41` „ 1 1,889' Camco TRDP-1-AENC SCSSV-Locked Out 9/3/1999-ID=2.812" 2 It. 3' '' 2 2,117' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" 13-3/8" . 3 2,787' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" :'3 I DV Tool c'�, 2 4 3,455' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" fir, 5 4,310' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" ar I r+. 6 5,203' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" ka 4 7 6,032' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" :' 14 8 6,802' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" 1 9 7,444' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" 0" tk 10 8,117' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" 0 5 q�*1 0 11 8,790' Camco 3-1/2"KBUG GLM's Loaded w/1"Dummy,ID=2.875" 1! 12 8,816' Baker SBR Seal Assembly w/2.813"HES'X'Nipple 13 8,842' Baker FHL Packer ID=3.00" 6 14 8,878' 3-1/2"OTIS'X'Nipple,ID=2.813" 15 8,916' Tubing Tail PERFORATION DETAIL 7 a Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Status MK-1 8,936' 8,954' 6,864' 6,877' 18 8 Open MK-2 8,960' 8,990' 6,881' 6,902' 30 12 Open 8 9,182' 9,184' 7,042' 7,043' 2 4 Squeezed kw WELL INCLINATION DETAIL oPi I KOP @ 2,200' e Max Hole Angle=58 deg.@ 4,900'-5,200' k1 tx ' I Tree 3 TREE&WELLHEAD � -1/8"5M CIW 8RD Tree Cap 010 A Tbg Adapter 11"x 3-1/8"5M CIW ta Wellhead Tbg Hgr.11"x 3-1/2"IBT 3"CIW-H BPV Profile i" 11 OPEN HOLE/CEMENT DETAIL 20" Cemented to Surface in 30"Hole ‘- 13-3/8" 3600 sks Permafrost Cement in 17-1/2"Hole V 12 ° t S' 7„ 1,000 sks Class"G", 300 sks Class"C"& .? 17:4 r•-: 13 200bbls of Arctic Pack ina 8-1/2"Hole i 14 II ;r GENERAL WELL INFO API:50-029-20748-01-00 Ija Drilled,Cased and Completed by Nabors 27E -11/2/1985 $ 15 NK-1 Sands NOTE: M NK-2 Sands Fish:Van / SPM#8 has a DV with no latch attached. The wobble ,, -- C.0 k �'5 washer and spring are lost in the wellbore Perforatinggun, ? , Calculated top x @ 9,305 MD Is > ` l � NK-2 Squeezed TD=9,5W(MD)/TD=7,280'(TVD) PBTD=9,382'(MD)/PBTD=7,191'(TVD) Revised By:STP 8/31/2015 Milne Point Unit 11 COIL BODE MPU B-04A 08/28/2015 Har„rI+ lla.la,LI t. MPU B-04A 20 X 13% X7 X3% Coil Tubing BOP Lubricator to injection head 1 iiF IE. 1.75"Tandem Stripper II 1 1 I•',I, Blind/Shear.— II III 1/16 10 Blind/Shear 11111 ARUM I 1 t,". _. 11111I Blind/Shear se. ,,,e, ./mi Blind/Shear MIN 0641. €_ — Slip �_- Slip 111111.11�11 C —, [gl•III. Pipe �� Pipe !MIN Mud Cross ill 4 1/16 10M X 4 1/16 10M Outlet a € w/2-2 1/16 10M full ,, ,, opening FMC valves - c potom IMO 0 11 El I Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M Li) or 2 1/16 10M 2 1/16 10M Crossover spool Fe Lu 4 1/16 10M X 31/8 5M Valve,Swab,WKM-M, 41. �\c' "�F� 3 1/8 5M FEtwooPf.° a • �aAsiei „vis5 op,,_ I f • r, Valve,Upper Master,Baker, 3 1/8 5M FE,w/Hydraulic 0 si 1 ILI/ ILO Valve,Lower Master,WKM-M, 3 1/8 5M FE «. Tubing Adapter,3 1/8 5M 101( illi 05/20/08 ~chlumber~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth won i.,h ~ ~~~` ~~ JUI~9 ~ ~ 20~ NO.4712 Company: State of Alaska Alaska Oil & Gas Cons Comm //~~ //~~ Q'~~ I V V Attn: Christine Mahnken 333 West 7th Ave, Suite 100 ((JJ s O ~ /~ a H .,_._ Anchorage, AK 99501 MPB-04A 12021150 MEM PROD PROFILE ~ 04/17/08 1~ 1 MPG-13 12021151 MEM INJECTION PROFILE =G 04/18/08 1 1 Z-26A 11978454 MEM GLS ~(j(p-U 04/23/08 1 1 Z-29 11978453 MEM GLS 04/22!08 1 1 Y-36 12005204 MEM GLS ~/ 0?Ji?J08 1 1 4-14A/S-37 12031471 _ PRODUCTION PROFILE W/FSI 04/12/08 1 1 Y-07A 11966254 SCMT / 05/02/08 1 1 02-01 B 11966257 LDL _ ~ (p 05/10/08 1 1 X-16A 11975771 USIT L .- C 05/14/08 1 1 07-26 12061688 USIT _ 05/16/08 1 1 05-34 11966251 USIT .- 04/13/08 1 1 05-23A 118966257 USIT ~ 05!13/08 1 1 S-33 11962596 USIT 04/15/08 1 1 V-223 12061688 CH EDIT PDC GR (USI `~ - / 03/23/08 1 V-220 40016600 OH MWD/LWD EDIT 'gyp _ 03/03/08 2 1 4-14A/S-37 40016545 OH MWD/LWD EDIT ~n~.-U ( / 02/18/08 2 1 05-228 11628800 MCNL 10/22/07 1 1 05-136 12021140 MCNL ~ 01/31/08 1 1 Z-10 12066520 RST G 04/10/08 1 1 D-10 11975766 RST 04/25!08 1 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ° iy Anchorage, Alaska 99508 Date Delivered: ~ ;, c, `'s'. I ~~ i;.'~ ~. - Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • ~\ RE: Success of Bright Water e e Subject: RE: Success or Bright Water From: "Ohms, Daniellc H" <OhmsDH@BP.com:> Hate: Tuc, 06 Dcc 2005 \1 :21 :20 -0900 To: Thomas Maunder <tom maundcr@admin.statc.ak.us.> - ". Tom, k ~ \"C¿ \7 O\..,~ r:> - 0 ~ ~ I've worked with Steve Cheung on BrightWater (as BP and Chevron are in the consortium developing the technology) and sorry I missed the SPE lunch yesterday. I'm on the slope this week. Jennifer McLeod and I are just reviewing some of the welltest results from B-04 and B-03 which are offsets to the well we pumped BW in, B-12i. I can't say we've seen any conclusive production results so far, but have a few pieces of surveillance data that are encouraging. We are still monitoring and hopeful that oil production increases will result. We are in the process of reviewing data with the company experts so really don't have much to share at this point. Our well spacing is considerably larger than the one Steve may have talked about in the Indonesia pilot, and the MPU wells have had some periods on and off production and injection, delaying results. I'll do my best to keep you posted as we come to more conclusive results (though don't hesitate to ask again in a few months if I haven't gotten back) . Danielle -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, December 05, 2005 2:42 PM To: Ohms, Danielle H Subject: Success of Bright Water Hi Danielle, I attended the SPE lunch today. The speaker was from Chevron and he discussed profile modification techniques and mentioned Bright Water. How has the application of this technology gone in Milne. Thanks in advance for the reply. Tom Maunder, PE AOGCC . . I" (0 1.'. é.' 2.D Q5 SÇANNEU uE, ,Ie) 1 of 1 12/8/2005 2: 18 PM . . . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Oi7:J DATE: July 12, 2000 Commissioner' tf /10/0(.;) THRU: Blair Wondzell, <a~ P. I. Supervisor . êt"1(óa FROM: Jeff Jone~, I::!t¡ SUBJECT: Safety Valve Tests Petroleum I sp c r Milne Point Unit B & C Pads Julv 9. 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap a-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. . SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '3 JvO... r.Q...~$+- 21 well houses were inspected, no failures. .". Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc: NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc . . Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Submitted By: Date: Field/Unit/Pad: Kuparuk River/MPU/B-Pad Separator psi: LPS 140 HPS N/A 7/9/00 Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones ~ ...) ~ ~;~X:~,::Weiiij/itbf#~~~~~~ ~;~~~~~~~;F~,~t:¡ti~~:~{/piiiiii~:~.~:' :,i::)!r*~~*i.t.~~~ IfJ-S~;t:~. I:~ SS'¥;:; li'.~~~~~~~;V~~~:~.:~ ~" I. . ... '-- .' ..., ".' ;;".i,.,,'.';:'~~I.' ~~.~ ,'''''. . . . ."~ ;"'.~:. '" ..W~lJ;~1!fpt!:r,-~:. Well Permit Separ Set LIP Test Test Test I Number Number PSI PSI Trip Code Code Code Oil, WAG, GINJ, GAS or CYCLE B-02 1811420 B-03 1820560 140 100 115 P P OIL B-04A 1821000 140 100 95 P P OIL B-06 1850130 140 100 90 P P OIL B-07 1850620 B-09 1850340 140 100 95 P P OIL B-10 1850170 140 100 90 P P OIL B-13 1850930 B-15 1851210 140 100 95 P P OIL B-16 1851490 B-19 1852300 B-20 1860050 140 100 95 P P OIL B-21 1860230 140' 100 95 P P OIL B-22 1853020 140 100 100 P 4 OIL B-23 1890160 9 Components: 18 Failures: 1 Failure Rate: 5.5% 090 Day Wells: Remarks: Three well SV's recorded slow closing times; B-04A(3:20), B-03(3:03),B-06(3:30). Some of the wells on this pad do not have well signs on them. Larry Niles, theBP representative, said he would have these items corrected. R/7/00 Page 1 of 1 Vvo43m 1 t.xls 1. Operations performed: 2. Name of Operator CONOCO INC. 3. Address P. O. Box 340045, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~,_,,ON 0 ~ REPORT OF SUNDRY WELL OPERATIONS Operation shutdown __ Stimulate ~ Plugging __ Pull tubing __ Alter casing __ Repair well __ Prudhoe Bay, AK 99734 4. Location of well at surface 165' FNL, 1158' FWL, Sec. At top of productive interval N/A 5. Type of Well: Development __ Exploratory __ Stratigraphic .__. Service __ At effective depth N/A At total depth 1475' FNL, 3514' 19, T13N, RilE, U.M. FEL, Sec. 24, T13N, RllE, U.M. 12. Present well condition summary Total depth: measured 9476' true vertical N/A feet feet Effective depth: measured 9382 ' feet true vertical N/A feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 16 IN Plugs (measured) N/~ Perforate __ Junk (measured) N/A Length Size Cemented 20" 13 3/8" Other __ 6. Datum elevation (DF or KB) KDB 59 feet 7. Unit or Property name Milne Point Unit 8. Well number B-4A 1! measured 8960'-8990'; 8936'-8954' true vertical 6880'-6902'; 6863'-6876' Measured depth 115' 9. Permit number/approval number 10. APl number 50-- 029-20748 Tubing (size, grade, and measured depth) 3 1/2" , Packers and SSSV (type and measured depth) Baker Camco 2300' 9476' 9.3# L-80, DSS-HT, 2.992" ID "FHL" Packer @ 8842' TRDP 1-AENC @ 1889' 11. Field/Pool Kuparuk River Field True vertical depth 13. Stimulation or cement squeeze summary See Attached lntervalstreated (measured) 8960 ' -8990 '; 8396 ' -8954 ' Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operation Oil-Bbl Gas-Mcf Water-Bbl 241 180 18 675 156 39 CasingPressure 960 1200 Tubing Pressure 240 180 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is irue and correct to the best of my knowledge. Signed /.~-2 /~'~ Title Senior Foreman Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ACIDIZING WELL ACTIVITY B-4A · 1. RIG UP COILED TUBING 2. PRESSURE TEST TO 4000 PSI. SMALL LEAK UNDER BOP, REPLACE O- RING. LEAK IN OTIS CONNECTION, REPLACE O-RING. TEST OK. 3. PUMP 1 BBL/MIN NH4CL. TAGGED SOMETHING AT 4888, WASH THROUGH OBSTRUCTION AFTER SEVERAL TRIES. S/D PUMP AND RIH TO 8820'. PUMP 1 BBL/MIN OF NH4CL TO 8956'. PULL BACK AND SPOT AT 8926' . 4. SPOT ZYLENE IN PLACE. PUMP 1 BBL/MIN. 5. CLOSE WING VALVE AND CHOKE MANIFOLD. PUMP 10 BBL'S OF XYLENE AT 1 BBL/MIN. 6. PUMPED 34 BBL'S ACETIC ACID WITH DIVERTER AT 1.3 BBL/MIN. 7. PUMPED HCL 10% AT 1 BBL/MIN. 302 BBLS 8. PUMPED MUD ACID, 122 BBLS AT 1 BBL/MIN. FINAL PUMP PRESS WAS 1440. WELL HEAD 402 PSI 9. PUMPED NH4CL + U66 AT 1 BBL/MIN. (27 BBL'S) 10. PUMPED ZYLENE AT 1 BBL/ MIN; 24 BBLS. 11. POOH 12. RIG DOWN COIL TUBING, FLOW BACK ACID TO ATMOSPHERIC TANK AND TEST WELL 13. PUT WELL BACK ON PRODUCTION RECEiVEE, OR STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIU5ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown m Re-enter suspended well m Alter casing __ Repair well ~ Plugging __ Time extension ~ Stimulate X__ Change approved program __ Pull tubing __ Variance __ 2. Name of Operator CONOCO INC. 3. Address .~¢1'1 r:..~;T_; ~TF ~rIN_ ANCHNRARIr qqRN3 4. Location of well at surface 165' FNL, 1158' FWL, Sec. 19, T13N, At top of productive interval N/A At effective depth N/A t total depth 1475' FNL, 3514' FEL, Sec. 24, T13N, 5. Type of Well: Development __ Exploratory __ Stratigraphic Service '-~ R11E, U.M. R11E, U.M. 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length measured 9476 ' feet Plugs (measured) N/A N/A feet 9382 ' feet Junk (measured) N/A N/A feet Perforate ~ Other __ 6. Datum elevation (DF or KB) KDB 59' 7. Unit or Property name 8. Well number B-4A feet POINT UNTT 9. Permit number 82-100 10. APl number 50-- 029-20748 11. Field/Pool Kuparuk River Field Size Cemented Measured depth True vertical depth 20" 115' 13 3/8" 2300' 7" 9476' 8960'-8990'; 8936'-8954' 2.992" ID truevertical 6880'-6902'; 6863'-6876' Tubing (size, grade, and measured depth) 3 1/2", 9.3# L-80, DSS-HT, Packers and SSSV (type and measured depth) Baker "FHL" packer e 8842'; Camco TRDP-1-AENC @ 1889' 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation ¢I7/1R/Rq 16. If pro'pos~l was verbally approved Name of approver Date approved 15. Status of well classification as: Oil .-X- Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~. 2- x~'~ Title Senior Prod. Foreman FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Date JApproval No. Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequentform required 10- ~ Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY lflNNIE C. SMITH Commissioner SUBMIT IN TRIPLICATE ACIDIZING PROCEDURE B-4A 1. RIG UP COILED TUBING 2. PRESSURE TEST TO 4000 PSI 3. PUMP ACID DOWN COILED TUBING CHEMICAL BBLS ZYLENE 17.5 10% ACETIC 34 10% HCL 302 MUD ACID 122 NH4CL 27 XYLENE 24 4. RIG DOWN COIL TUBING, FLOW BACK ACID TO ATMOSPHERIC TANK AND TEST WELL 5. PUT WELL BACK ON PRODUCTION Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production' operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There are 19 active and 5 inactive production wells at Mi!ne Point. ACTIVE: . B-~.~, B-6, B-9, ~-i0, B-i~ B-lo B-15 B-16 C-i, C-2, C-3, C-4, C-5A C-7 C-9 C-13 C-14 C-16 S~IC: B-20, B-91,_ B-2~ C-i7, ~- ~ 18 All active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. The annular fluid levels will be monitored for leaking gas lift valves, if necessary the production casing annulus will be displaced with = diesel:oil mixture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Milne Point Unit. ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and 'no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-i; CFP-1 Water source wells will be freeze protected by diSplacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPV£ will be set and all wellhead valves will be closed. The E-2 gas storage 'well has been shut-in since July 1986 due to a tubing teak. The we!ibore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:~'ater mix will be used to carry the inhibitor. if you have any questions on ~he shutdo~ procedure please contact Don Girdler at 564-7637. ~ Yours very truly, "-' STATE OF ALASKA ALASI OIL AND GAS CONSERVATION COMM,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown _. Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other,.~7~ 2. Name of Operator 5. Datum elevation (DF or KB) Conoco Inc. 59' KB feet 3. Address 6. Unit or Property name 3201 C Street, Ste. 200, Anchorage, Alaska 99503 Milne Point Unit 4. Location of well at surface 165' FNL, 1158' FWL, Sec. 19, T13N, RllE, U.M. At top of productive interval 1495' FNL, 3136' FEL, Sec. 24, T13N, R10E, U.M. -At effective depth At total depth 1475' FNL, 3514' FEL, Sec. 24, T13N, R10E, U.M. 7. Well number B-4A 8. Permit number 82-100 9. APl number 50-- 029-20748-01 10. Pool Kup aruk River 11. Present well condition summary Total depth: measured true vertical 9500 feet Plugs (measured) 7222 feet Effective depth: measured N/A feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth Structural Conductor 80 ' 16" To Surface 115' Surface 2265' 13 3/8" 3600 Sxs 2300' Intermediate Production 9440' 7" 1000 Sxs 9476' Liner Perforation depth: measured 8936'-8954' true vertical 6863'-6876' Tubing (size, grade and measured depth) 3~", L-80, 8916' Packers and SSSV (type and measured depth) T.R. SCSSV @ 1889"; Ret. Pkr. @ 8842' ~ue Verticaldepth 115' 2300' 7262' 12.Attachments Description summary of proposal, Detailed operations progra~ ~ CELOI~s¢~ :~e~h[] 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Alaska 0ii & Gas Cons. Date approCerJ~h°rage 15. I hereb,¥_c.~rtify that the foregoing is true and correct to the best of my knowledge Signed~ ]~~..~ :~.~)0.c.,.-, Title 5£.'"-~-~. ~4~¢Z. Commission Use Only ORIC i'iAI. SIGNED Approved by JJY l.i~fINIE I~. illilJ Form 10-403 Rev 12-1-85 Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance _~®prove¢- ~et,u r neCJ/. Oommi88ioner Date J Appr°valN°~/y¢ by order of / ' Date ." ~(..,./~:~' the commission /.,~/.../ F~_ Su'b~it in'triplicate ""'. ' ~ STATE OF ALASKA ~ -" ALASK,. DIL AND GAS CONSERVATION'q,t;'M MISSION - WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL r~ GAS [] SUSPENDED [] ABANDONED I~ SERVICE [] ~. Name of Operator 7. Permit Number Conoco Inc. 82-100 3. Address 8. APl Number 3201 C Street, Ste., 200, Anchorage, AK 99503 50- 029-20748-01 4. Location of well at surface 9. Unit or Lease Name 165' FNL, 1158' FWL, Sec. 19, T13N, RllE, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 1497' FNL, 3135' FEL, Sec. 24, T13N, R10E, U.M. B-4A At Total Depth 11. Field and Pool 1475' FNL, 3514' FEL, Sec. 24, T13N, R10E~ U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB 59'I ADL 47437 Kuparuk River 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions I I 6-27-82 7-12-82 7-22-82 feet MSL 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 9500'MD(7281'~VD) 9382'MD(7190'TVD) YES I~ NO [] feet MD 1800+ 22. Type Electric or Other Logs Run SP-DZL-SFL-GR-Son-i c-NGT-CNL-FDC-HDT- SWC ' s-CFL-VDL-CCL-GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9'~ ' 9/,76 ~ 1 Of]f) .~k.q lq, 1 a.q.q 7" 2_ # ;,-80 0' ' 9NH hhl ~ Awp_ P~ 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3%" 9.3t; 8916' a849' 8960'-8990' 12 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 3112'-3553' Plug back w/300 sks. Class G 2588'-3150' Plug back w/250 sks. Class G 9182'-9184' Sqz. 200 sks. Class G 9182'-9184' 2nd Sqz. 2/150 sks. Class G 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 12-1-85I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO 12-28-85 6 TEST PERIOD I Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 225 ' 1070' . 24-HOUR RATE I~ 516 181 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ....... ~ lOQ~ Alaska 0il & Gas Cons. v .... Aachorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate~/ ~- / 1~ .. 29. " 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Schrader Bluff 4112 3876 West Sak 5062 4438 Middle Kuparuk 8935 6857 Lower Kuparuk 9238 7071 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _~~"~"~,,/~~'~ Title S/~)~" ~/~/~.,~ Date /- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 -and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). · Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator Conoco Inc. 3. Address 3201C Street, Suite 200, Anchorage, Alaska 4. Location of Well 99503 7. Permit No. g2-100 8. APl Number ~o_029-20748-01 9. Unit or Lease Name OTHER [] 165' FNL, 1158' FWL, Sec. 19, T13N, R11E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 59' KB I 6 . Lease Designation and Serial No. 47437 12. Milne Point Unit 10. Well Number B-4A 1 1. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other ~] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as an oil should be removed. producing well on 11-18-85 and its suspended statusI 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. S ig n~.~.~~~,~ d~T~---J - Title ' The ~;-15ace b.,~/d'w for Commission use Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate CONOC,~ ~: ING SCHLUMbERGEr OFFSHORE SERVICES A Division of $chturroerger Limited HOUSTON. TEXAS 77001 lo/16/85 Pouch 340069 Prudhoe Ba~, AK 99734 ATTN: Marcia Sherburne 3__201 "C" S:reec, Su.ite 200 /- ~ Anchorage, Alaska 99503 ~ ~ A~emtion~ ~ke Bradshaw ~~ ~ . Enc{osed are 3 BL~rintsofth~~~ LOG, RUN 1, 9~6./fl5 Common', CONOCO ~N~ / _,We~, . B-4A ' .'~ ' F~e~d MiLNE PO~N~ ( ,Coun~ NORTH SLOPE State ~~ AdditJon~ DrJ~s are being ! ZL crf~ts & I~ 1 BL p~ W:_sc Coast & Alaska Division uaevron USA INC ~'~ ~ ~p_~ ~ourt, Suite ~$4 P 0 Box 107839 Vennur.], CA 93003 AnchoraKe, A!as~ 99510 AT~I~: Phil Salvador ATTN: J. L. Weaver i BL prints & iRF _'-%. :S_~_2C~ r..',,J~_~e. ~~ 2197 _ Ho~sn~n: Tax 772~7 ~ ..... Gerald __~_~: ~et % George Lamb ~'~'~'~ iNC P 0 Bex 1267 Ponca City, 0K 7~603 L prints & 1RF ska Oil & Gas ( 300~ ~arcup~ne ~~TN: Willim~ Van Alan The film is RETURNED TO CONOCO We appreciate the privilege of serving you. I BL Drints & 1RF Chevron USA. INC San Ramone. CA 94583 ATTN: George Webb ~. Ln~i.~ ~lnnsky ~-__~rints & IRF Ghamplin Petroleum Company 0 Box 1257 Eng!ewood~ CO 80150 ATTN: James T. Laws Jeff DeJarnett ! BL prints & 1RF Readin~ & Bates Petroleum Co -- 3200 Mid Continent Tower Tulsa: OK 74103 ATTN: C_E_ g~ry, .Ir Alaska Oil & bas Coris. OommJssi0n Anchorage Ve~ truly y~rs, SCHLUMBERG~ OFFSNORE SERWCES Chari'es R. Merriman I~ I $'i'~ {CT MANAGER Page 2 of 2 SCHLUMBERGER OFFSHORE SERVICES a Division of Schlumberger Limited HOUSTON. TEXAS 77001 [o/[6/85 CONOCO, INC 320[ "C" Street ~Lnchor ?.ge, Alaska 99503 Attenticr.: Mi k~, Brad-~h~_w Pouch 340069 Prudhoe Bay, AK 99734 ATTN: Marcia She~burne Gentlemen: Erc]osed are_ Compc. ny CONOC, n; TFiC Field MIT, NE POTNT prints of the ACOUSTIC CAL LOG, RUN 1, 9/26/85 : Well B-4A ,Coun~ NO~m~ SLnP~ Store AT.ARI~_A Additional prints are being sent to: 1 BL prints & 1RF Cities Service 0il & Gas Cor. p P O Box 9~9 Bakersfield, CA 93302 ~m~: 5~eil Buttram m) ~ im "' ~i ~n prints prints ~rints prints _ prints prints The film is We appreciate the privilege of serving you. SCHLUMBERGER OFFSHORE SERVICES r!;.,:/..~, Ou a 6as Cons, C0mmJssJ0~ OISTR ICT MANAGER Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 October 14, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached is a Sundry Notice for the Milne Point B-4A well. Conoco intends to move the Nabors 27-E drilling rig onto the subject well, recover and replace collapsed 7" casing, and repair or replace damaged 13 3/8" surface casing. After the remedial work is completed, the tubing will be re-run with gas lift mandrels and a subsurface safety valve and the well will be perforated for production in the Middle Kuparuk (MK-1) zone. If you have any questions, please call Kent Stolz at 564-7641. Very trUly yours, Manager-Engineering KJS/vv cc: MPU B-4A File RECEIVED o c ? 4 Alaska Oil & Gas Cons. CommiSsion Anchorage " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WE .S 1. DRILLING WELL [] COMPLETED WELL:~ ' % 2. Name of Operator 7. Permit No . %~ '~ ~-'~ 3. Address 8. APl Number 3201 "C" Street-, Suite 200, Anchorage, AK 99503 50-029-20748-01 9. Unit or Lease Name 4. Location of Well Milne Point Unit 10. Well Number Milne Point B-4A 165' FNL, 1158' FWL, Sec. 19, T13N, RIlE, U.M. 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 59' KB I ADL 47437 Kuparuk River 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105~170), The B-4A well was completed as a delineation well in the Middle Kuparuk Formation to be a producer. Initially, the well was completed with a packer and no gas lift mandrels. The Roll'n 4 completion rig was moved onto B-4A on September 24, 1985 to pull the tubing and re-run the tubing with gas lift mandrels and a subsurface safety valve. While pulling the tubing, the SBR hung up at 359' and subsequent work revealed collapsed 7" casing at 8', 182', and 222', and collapsed 13 3/8" casing at 8'. The Roll'n 4 was rigged down after setting an Otis 'X-X' plug in the X-Nipple immediately below the packer and sanding back over the top of the packer for pending work to be performed with the Nabors 27-E drilling rig. Conoco proposes to move the Nabors 27-E drilling rig onto B-4A after completing the B-19 well to recover and replace the damaged 7" casing to at least 400' MD and repair or recover and replace the 13 3/8" casing. Arctic Pack will be circulated behind the 7" casing after the remedial work is completed. Following the remedial casing work, the Middle Kuparuk zone (MK-i) will be perforated 8936'- 8954', 8 SPF, with through tUbing 2 5/8" guns. 14. I-hereby certify tha~t the foregoing is true Signed ~ /~. ~ The space below for C~mmission u~-~ and correct to the best of my knowledge. Title Production Engineer D~--09--85 Conditions of Approval, if any: Approved by. BY LOH~I[ C. SM!TII kFq3roved C~.:~. !~ 5.. By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-76OO September 23, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are Sundry Notices for the Milne Point B-3 and B-4A wells. Conoco intends to move completion rigs onto the subject wells and pull tubing in order to install gas lift mandrels. After rerunning the tubings with gas lift mandrels and safety valves the wells will be suspended until the production facilities are ready. If you have any questions, please call Dan Robertson at 564-7635. Very truly yours, R. J. Francis Manager-Engineering DIR/vv B-3 sundry letter cc: MP B-3, B-4A Files RECEIVED Gu ~ 6:~ Cons. Cornmissior~ A P, chorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL:~ OTHER [] 2. Name of Operator CONOCO: INC. 3. Address 320] "C" Street-, Suite 200, Anchorage, AK 99503 4. Location of Well 165' FNL, 1158' FWL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 59' KB 19, TI3N, RllE, U.M. 6. Lease Designation and Serial No. ADL 47437 7. Permit No. 82-100 8. APl Number 50-029-20748-01 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point B-4A 11. Field and Pool Kuparuk River 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Conoco intends to move a completion rig onto the subject well and pull tubing in order to install gas lift mandrels. After rerunning the tubing with gas lift mandrels and a safety valve the well will be suspended until the production facilities are ready. NOTE: Verbal approval to do this work was received from Mr. Lonnie Smith, AOGCC on Friday, 9-20-85. RECEIVED Alaska 0il & Gas Cons, O0rnmJssJ0n Anchorage 14. I hereby certify that the foregoing is-true and correct to the best of my knowledge. Signed ~'~C'~f ~-' ~~~ __~TitleManager of Alaskan Operations The space below for Commission use J. R. Kemp Da~-I9--85 Conditions of APproval, if any: Approved by ,~.pproved J~turn~:~ _ By Order of COMMISSIONI=R the Commission Form 10-403 Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subseouent Reports" in Duplicate Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 November 6, 1984 Mr. Jim Trimble Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-I, A-2, B-I, B-2, B-3, B-4A, B-5, C-I, C-2, C-3, D-l, L-I, M-lA, N-lB, and Gwydyr Bay State 2A. Ail of the above are classified suspended wells. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the wells are suspended. Please contact Jim Dosch at 279-0611 if you have any questions. Yours very truly,~, / /~anager of Alaskan Operations JTD/ks Attachments RECEIVED NOV 0 9:1984 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ---. ALASK. OIL AND GAS CONSERVATION ~_ JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 8~-100 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50- 029-20748-01 4. Location of Well 165' FNL, 1158' FWL, Section 19, T13N, RllE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 59' KB 12. I 6 . Lease Designation and Serial No. ADL 47437 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point B-4A 11. Field and Pool Kuparuk Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pu, II Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended we].].. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the well is suspended. This well will be utilized in the phase I development of the Milne Point Unit. Work to re-activate this well will begin prior to production in early 1986. RECEIVED NOV 0 9 Alaska Oil & Gas Cons. commission Anchorage 14. I her~~goZ~ and cor~rect to the best of my knowledge. Manager of Alaskan Operations ST~ :~ ac~l oi~' ~oTC/o;m%n ~us~ Title Condigns ~ ~pmvaL ff ~y: Date Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate THRU: Lonnie C. Smith~/~% Commissioner FROM: Bobby Foster~-~· Petroleum Inspector. M EMORA..~'DUM sta;'~ of Alaska A~SV~~~ ~AS co v ~ ~o~~o~ ~ T~ C- V.~ ~Mt~ton - DAT~ Au~st 22, 1984 Chai~ . mtt~ D.31.52 -. TELEPHONE NO:. SUBJECT Inspect Suspended Wells and Locations at Conoco Sites. ..Thursday, August 16, 1984: I traveled this date to Prudhoe Bay~-and met with Jerry Fritch and Jim Dosch, Conoco representatives, to' inspect the suspended drill sites and wells listed below. Gwyder Bay .2A Milne ~Point N-lB Milne Point M-iA Milne Point L-1 Milne Point Pad A (4 wells) ' Milne Point Pad C (4 wells) ~ Milne Point Pad B-~ Milne Point Pad D . I recommend to the CommisSion that these wells and drill sites be' accepted as suspended. Pictures attached. O2-OO1A(Rev. 1017g} Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE Condition of Pad O~. Condition of Pits Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard Attached to - Information correct No Ye s No No Cellar - Opened Yes No Rat Hole Open Yes No Fil led Yes No Fil led Yes No Covered ~ No Covered ~ No WaterWell - Plugged off Capped Open Explanation ~/~ P~to~~~ taken 2to verify abo~ conditions ~ ~o ~ Work to be done to be acceptable ~_ _~~_ This well and location is (a~eptable) (u~aGceptable) t0 be cla~ssified as riod of ...... suspended for the pe__ ~y/~-_~ , ~thru ~'7/& 1 Ins~cted by:7~~~ ~- ~~~ - 7 ...... Date :~ Revised 8/24/82 '---- H, D, Haley Manager of Alaskan Operations Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 October 17, 1983 Mr. Jim Trimble Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-i, A-2, B-i, B-2, B-3, B-4A, C-l, C-2, C-3, C-4, D-l, and Gwydyr Bay State #2A. All of the above are classified as suspended wells, and Conoco will be contacting one of your representatives to conduct an inspection of these wells each year as long as the wells remain under this status. Also attached is a completed 10-407 form requesting a change in status for Milne Point B-5 from plugged and abandoned to suspended. You will also find photographs enclosed covering the cleanup operations that took place subsequent to this year's inspection of Gwydyr Bay State #1 and #2A. Photographs are also included that show the new signs mounted on Milne Point C-4 and D-2A. Please contact J. T. Dosch if additional information is necessary or if you should have any questions. H. I). I-Ialey Manager of Alaskan Operations JTD / kp cc: A. E. Hastings, Anchorage "-' STATE OF ALASKA ALASKA ~,IL AND GAS CONSERVATION CU,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ 2. Name of Operator Conoco :[nc. OTHER [] 7. Permit No. 82-100 3. Address 2525 C Street, Suite 100, Anchoraqe, Alaska 99503 4. Location of Well 165' FNL, 1158' FWL, Sec. 19, TI2N, R11E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 59' KB I 6 . Lease Designation and Serial No. ADL 47437 12. 8. APl Number 5o-029-20748-01 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point B-4A 11. Field and Pool Kuparuk Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other (X]X Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. DesCribe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year until the well has a plugged and abandoned status. 14. I herebyj~l~ th~,t.~he foregoing is true and correct to the best of my knowledge. /- Si.ned I~--~'~¢~,~.,~, ;~ T~t~eManager of Alaskan Operations The space below for Commission use H. D. Hale.v Date ~0-19-83 Conditions of Approval, if any: Approved by ORIGINAL SIGNED BY LONHIE C. SMITH Approved Cop?' Returned By Order of COMMISSIONER the Commission Oa,e Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANDUM State of Alaska September 2, 1983 10SA:J8 FROM: Haro!d Ro ~awkins Petrole~a Inspector ~'~fi ~-'-~ SU BJ ECT: Cleanup Inspection for Extension of Suspended Status, Conoco, Milne Point B-4A, Surf. Loc. 165' FIqL, 1158 ' FWL, Sec. 19, T13N,9.11E,UM, Permit ~7o. 82-100. Wednesday., A_ug~t !.7, 1783: I finished inspecting Milne Point No. B-3, subject of another report and inspected B-4A for exten- sion of suspension. I took a picture of the well and. sign for verification. Location is free and. clean of debris. I also filled out an A.O.G.C.C. report which is attached.. In .st~mary, I inspected Conoco's Well No. B-4A and found all requirem, ents of A.O.G.C.C. regulations are met. I recommend extension of suspension be approved-. Attachments "'-~ ~) ... y .,' (~<' c:" Suspended \'¡ell and Location Report : 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator Lt'9VOrO Address Surface Location of Well 16 f Ft. F)./ L, / / S q' Ft.F fI.-/ sec.~, TL3-~, R~ ~,1L-M. Unit '\ Da te S us pe nde d I{ -;z :( - ð".2.... Pe rmi t No. ~ :l.. - / ð 0 L API No. 50 or Lease Name }f1¡" Þ¿ I'ð/p'r vJel1 No. B - 17 A Field & Pool . Condition of pad/ I;-~/ conditi on of Pi ts t'(J ~ f) Well head - All outlets plugged 11 sign ~""A,ttached to we 11 head . At'tâêhëd .to wéll(ýUa~ Attachéd to eJ No Yes @ No Nö Inforrra ti on correct 8 No Cellar - Yes Yes Œ?J . /~ Capped No No .No °Fened J~~~~d) Wa terWell - PI uggè d of f Open Rat Hole Open Yes No ~QA\ Yes NO coverei) C§' No ExplaI?-a tion Photographs taken to verify above conditionsB No Exp la na ton Work tobedorié to be a.cceptab Ie þ" ô pE- rHI5 15 11 classified as 19~. I ?;l.PffY Revised 8/24/82 H. D. Haley Manager of Alaskan Operations June 9, 1983 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Milne Point Unit Injectivity Study Dear Mr. Chatterton: Enclosed please find two copies of a Sundry Notice concerning the operations and results of the Milne Point Unit Injectivity Study. Also enclosed are two sets (one blueline print and one sepia print per set) of injection profile logs. This information is being sent to you in compliance with the Requests and Regulations of the Alaska Oil and Gas Conservation Commission. As always, this information is "CONFIDENTIAL" and should be handled accordingly. If you have any questions on this matter, please contact Gary Merriman at 279-0611. Very truly~yours, H. D. Haley /~/ Manager of Alaskan Operations JBF/kr Enclosure cc: Gary Merriman, Anchorage, w/o Enclosure Injectivity Study File STATE OF ALASKA ALAS .... OIL AND GAS CONSERVATION .,~OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Conoco Ibc. See Attachment No. 1 3. Address 8. APl Number 2525 C Street, Suite 100 Anchorage, Alaska 99503 50- See Attachment No. 4. Location of Well See Attachment No. 1 5. Elevation in feet (indicate KB, DF, etc.) See Attachment No. 1 6. Lease Designation and Serial No. ADL 47438 9. Unit or Lease Name Milne Point Unit ,0. Well Number-,~ [-~ Water Injectivity 'test 11. Field and Pool Kuparuk River Field Kuparuk River Pool 12. Perforate Stimulate Repair Well . [] Change Plans [] Repairs Made Pull Tubing i [] Other [] Pulling Tubing (Note: Report multipl~ completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] -. Perforations [] Altering Casing [] Abandon [] Stimulation [] Abandonment [] Other ~[~ Water Injectivity Test 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of s~rting any proposed work, for Abandonment see 20 AAC 25.105-170). As proposed in the Notice of Intent dated August 2, 1982, a short term injectivity test was performed within the Milne Point Unit. In brief, this test consisted of rigging up a temporary injection facility and injecting 68,120 bbls of water, produced from the Milne Point Unit B No. 1 Upper Cretaceous water sands, into the Middle Kuparuk formation through the Milne Point Unit B No.'4A well. Step rate tests, pressure fall- off tests,'and a pressure parting test were all performed on the injection well. Also, due to a decrease in formation injectivity, the injection well was stimulated with a biocide and an acid treatment. Pressure responses created by the water injection were monitored in three offsetting Milne Point wells (B No. 3, C No. 1, and D No. 1). The produc6ion performance of the water source well was also monitored. For the pu.rpose of this report, the following explanations of operations will be divided into three sections; the Water Source Well, the Injection Well, and the Pressure Observatioh Wells. 14. I hereby certify that the foregoing is true and correct to the best of mv knowledge. · . ~ SignedThe space b ~ Title r~,ff r' ,, (~i~~ ~, ~Date_ Conditions of Approval, if any: CONFIDENTIAL INFORMATION Furnished By Conoco InD. Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate CONFIDENTIAL I FORMATION Furnished By Conoco Inc, 13. The Water Source Well (Milne Point Unit B No. 1) was equipped with a Gould six-stage turbine pump run inside the 9-5/8" casing on 16 joints of 4~" tubing. The pump suction port was located at a depth of 485' GLM. Before water injection was initiated, the 150 bbl diesel pad was flowed to surface. Approximately 2000 bbls of water was pumped to surface to clean up the wellbore, test the producibility, and check the flow meters. A maximum rate of 5800 BWPD, with 63 psi surface tubing pressure, was measured at this time. Once injection was initiated, production rates varied according to the injection requirements. The overall average 'rate was 1400 BWPD. Water was produced from the first week in September to the first week in November. By the end of the test the maximum attainable production rate decreased to 2400 BWPD. The decrease in producibility is attributed to decreased pump efficiency. Following the end of the injection test the downhole pump and the tubing were retrieved. The casing (9-5/8") was displaced with diesel to a depth of 2000', and the wellhead was secured. The Water Injection Well (Milne Point Unit B No. 4A) was prepared for water injection by pulling the back pressure valve and retrieving a tubing plug at the depth of 8816'. Flowlines were installed from the injection facilities to the wellhead (for details of injection facilities and layout please refer to Attachment Nos. 2 and 3). Water injection commenced at 4:00 a.m. September 13, at a rate of 410 BWPD. The rate was increased at 400 psi increments to an assigned maximum surface tubing pressure of 1700 psi. The rate corresponding to this pressure was initially 1880 BWPD. This rate decreased to 500 BWPD within 64 hours. On September 23, the injection well was treated with 80 bbls of 320 PPM glutaraldehyde biocide. After allowing the biocide to soak at the sand face for several hours, 2000 gallons of 15% HC1 was pumped into the formation in four 500 gallon stages. Injection was resumed at a rate of 660 BWPD (680 PSIG surface tubing pressure) and was increased at roughly 400 BWPD increments to a final rate of 1990 BWPD (1150 psi surface tubing pressure). The rate was then dropped to 250 BWPD and held constant for several days. Thereafter; the rate was increased to 2150 BWPD and maintained (with some fluctuation) for the remainder of the injection period. During this time the snrface tubing pressure increased proportionately with the injection rate with an additional slight increase with time. The final surface tubing pressure of 2760 PSIG was the maximum pressure recorded throughout the test. Injection was terminated at 12:42 p.m. on November 1, with a cumulative volume of 68,120 bbls injected. Following the final pressure fall-off test; the tubing was displaced with diesel to a depth of 8000', a "X-X" plug was set in the tubing at 8878', a back-pressure valve was installed, and the wellhead was secured. The maximum injection rate of 4300 BWPD (surface tubing pressure= 2630 PSIG) was established for a short time on October 9, while attempting to pressure part the formation. There was no indication of pressure parting throughout the entire injection test. For specific injection rates and pressures please refer to Attachment No. 4. Two injection profile surveys were run in the B No. 4A well. A spinner survey was performed on September 15, and a temperature survey was -2- CONFIDEi INFORMATION Furnished By Conoco Inc. performed on October 7. In addition, periodical pressure fall-off tests were performed on the injection well. For the resulting fall-off pressures please refer to Attachment No. 5. The Pressure Observation Wells consisted of Milne Point Unit B No. 3, C No. 1, and D No. 1. Kavearak Point No. 32-25 was originally proposed as an observation well but was found to be unsuitable. A wireline survey indicated that the tubing in 32-25 was collapsed several hundred feet below surface, and that there was pressure communication between the tubing and the tubing/casing annulus. Milne Point Unit B No. 5, also proposed as an observation well, was not available as it was never completed. The tubing strings in Milne Point Unit B No. 3, C No. 1, and D No. 1 were re-entered; all back pressure valves were removed, safety valves opened (not applicable in B No. 3) and all tubing plugs retrieved. The tubing in Milne Point Unit C No. 1 was perforated from 6918' to 6920' when the "X-X" plug (6921') could not be unseated. Prior to injection, three Hewlett-Packard pressure gauges were run inside the tubing of B No. 3' and D No. 1. A third H.P. gauge was run in the tubing of C No. 1, 343 hours after injection was started. The pressure gauges were run to a depth of 6000' (WLM) on wireline and monitored pressures continuously throughout the injection period (with the exception of several short interruptions required for switching gauges and maintaining surface equipment). The pressure gauge was retrieved from B No. 3, 337 hours after the initiation of injection. This pressure gauge was then used to monitor fall-off test pressures in the injection well. The pressure gauge in C No. 1 and D No. 1 were retrieved after the injection period ended. Once the gauges were retrieved; tubing plugs were set, safety valves were closed, back pressure valves were installed, and the wellheads were secured. Detailed pressure responses for each well are listed on Attachment No. 6. -3- ATTACHMENT NO. 1 WELL TO BE USED DURING TEST B-1 B-3 B-4A C-1 D-1 PERMIT NO. 80-75 82-56 82-100 81-143 81-144 CONI-~-'"'ENTIAL INFORMATION Furnished By Conoco Inc, MIDDLE KUPARUKWATER INJECTIVITY TEST MILNE POINT UNIT WELL LIST API NO. 50-029-20490 50-029-20732 50-029-20748-01 50-029-20663 50-029-20664 LEASE DESIGNATION AND SERIAL NO. ADL 47438 ADL 47438 ADL 47438 ADL 47434 ADL 47437 FUNCTION Water Source Well Pressure Observation Well Water Injection Well Pressure Observation Well Pressure Observation Well -4- ATTACtIMENT NO. 3~--~ SCALE' i": ~:)0' CONFID,-.'ITIAL INFORMAl'iON Furnished By Conooo Ino, I-lq B4 A (INJECTION) PLAN SCALE' r' = 3000' POINT UNIT -6- CC "!DENTIAL INFORMATION I-urnished By Conoco Inc. ATTACHMENT NO. 4 MILNE POINT UNIT INJECTION TEST INJECTION WELL PRESSURES RATE CUM. DATE (BPD) BBLS. *SURF. RATE CUM. SURF. PRESS. DATE (BPD) BBLS. PRESS. 9-13 880 880 9-14 849 1729 9-15 613 2342 9-16 134 2476 9-17 54 2530 9-18 191 2721 9-19 253 2974 9-20 149 3123 9-21 182 3305 9-22 128 3433 9-23 172 3605 9-24 393 3998 9-25 377 4375 9-26 248 4623 9-27 253 4876 9-28 248 5124 9-29 830 5954 9-30 1212 7166 10-1 1211 8377 10-2 1205 9582 10-3 1567 11149 10-4 2204 13353 10-5 1733 15086 10-6 2008 17094 10-7 1511 18605 10-8 935 19540 10-9 1349 20889 10-10 1963 22852 10-11 2238 25090 10-12 2120 27210 10-13 2161 29371 10-14 2159 31530 10-15 2133 33663 600 610 630 950 1030 1050 1090 1590 1590 1650 1650 1590 1600 1990 2100 2180 2230 2300 2350 2370 10-16 2196 35854 2400 10-17 2091 37950 2430 10-18 2131 40081 2400 10-19 2116 42197 2440 10-20 1894 44091 2230 10-21 1939 46030 2350 10-22 2010 48040 2400 10-23 2028 50068 2510 10-24 2085 52153 2550 10-25 2088 54241 2590 10-26 1847 56088 2420 10-27 2027 58155 2560 10-28 2075 60190 2630 10-29 2092 62282 2660 10-30 2076 64358 2700 10-31 2157 66515 2730 11-1 1601 68116 2760 Pressures were being recorded by an "HP" gauge set at 6000' MD, 4950' TVD. -7- ATTACHMENT NO. 5 CONFiT-:NTIAL INFORMA'RON Furnished By Conoco Inc. PRESSURE FALL-OFF DATA Milne Point Unit B No. 4A Pressure Fall-Off Test No. 1 September 14, 1982 Cumulative Water Vol. Injected= 1370 bbls Time Pressure (Minutes) (PSIA) Time (Minutes) Pressure (PSIA) 0.0 1590 0.005 1560 0.10 1500 0.15 1440 0.20 1380 0.25 1320 0.50 1220 0.75 1130 1.0 1060 1.5 990 2.0 2.5 3.0 3.5 4.0 5.0 6.0 10.0 12.5 15.0 950 885 85O 835 820 8O5 790 760 730 720 Pressure Fall-Off Test No. 2 September 15, 1982 Cumulative Water Volume Injected= 2044 bbls Time Pressure (Hours) (PSIA) Time (Hours) Pressure (PSIA) 0.000 3882.7 0.002 3821.9 0.005 3650.2 0.008 3528.4 0.011 3423.8 0.014 3355.3 0.017 3299.1 0.019 3257.0 0.022 3223.0 0.028 3173.1 0.033 3137.5 0.039 3110.7 0.044 3089.6 0.050 3072.4 0.056 3057.9 0.064 3040.0 0.072 3025.4 0.089 3002.6 0.106 0.122 0.139 0.155 0.172 0.189 0.222 0.256 0.289 0.322 0.356 0.389 0.422 0.489 0.556 0.589 2985.3 2971.9 2961.0 2951.5 2943.4 2936.3 2924.2 2914.3 2905.9 2898.9 2892.4 2886.7 2881.7 2872.8 2865.5 2862.1 -8- COb,'- )ENTIAL INFORMATION Furnished By Conoco Inc. PRESSURE FALL-OFF DATA (continued) Milne Point Unit B No. 4A Pressure Fall-Off Test No. 3 October 5, 1982 Cumulative Water VOlume Injected= 15,066 bbls Time Pressure Time Pressure Time Pressure (Hours) (PSIA) (Hours) (PSIA) (Hours) (PSIA) 0.000 3736.6 0.213 0.001 3562.9 0.221 0.006 3384.2 0.230 0.011 3330.9 0.239 0.015 3305.2 0.248 0.019 3284.9 0.257 0.024 3270.0 0.266 0.029 3258.6 0.275 0.034 3249.4 0.283 0.038 3241.7 0.292 0.043 3235.2 0.301 0.048 3229.5 0.310 0.052 3224.4 0.318 0.057 3220.6 0.335 0.061 3216.5 0.352 0.066 3212.7 0.369 0.071 3209.3 0.386 0.076 3206.2 0.404 0.080 3203.3 0.421 0.085 3200.5 , 0.438 0.090 3198.0 0.455 0.098 3193.7 0.473 0.106 3190.0 0.490 0.115 3186.3 0.506 0.124 3182.9 0.524 0.133 3179.7 0.541 0.142 3176.8 0.558 0.151 3173.9 0.575 0.160 3171.3 0.593 0.169 3168.8 0.610 0.178 3166.2 0.627 0.186 3163.8 0.644 0.195 3161.5 0.661 0.204 3159.3 0.678 3157.1 3155.1 3153.2 3151.4 3149.7 3148.2 3146.7 3145.2 3144.0 3142.7 3141.5 3140.2 3139.1 3137.0 3135.0 3133.0 3131.2 3129.4 3127.7 3126.0 3124.4 3122.8 3121.3 3119.8 3118.5 3117.2 3116.0 3114.8 3113.7 3112.4 3111.3 3110.2 3109.1 3108.0 0.695 0.713 0.730 0.747 0.775 0.817 0.860 0.901 0.946 0.991 1 .O3O 1.091 1.143 1. 203 1.258 1.317 1.373 1.428 1.490 1.545 1.629 1.715 1.800 1.884 1.969 2. 100 2.220 2.35 2.48 2.65 2.77 2.94 3.10 3.27 3.44 3.61 3.78 3.94 4.11 4.17 3107.0 3105.9 3104.9 3103.9 3102.3 3100.0 3097.8 3095.7 3093.5 3091.4 3089.7 3087.I 3085.0 3082.7 3080.~6 3078.5 3076.5 3074.7 3072.6 3070.8 3068.3 3065.7 3063.4 3061.0 3058.8 3055.6 3052.6 3049.6 3046.7 3043.2 3040.5 3037.5 3034.3 3031.4 3028.5 3025.6 3022.9 3020.2 3017.7 3016.8 -9- .-:IDENTIAL INFORMATION Furnished By OohOi~O iflC. PRESSURE FALL-OFF DATA (continued) Milne Point Unit B No. 4A Pressure Fall-Off Test No. 4 October 8, 1982 Cumulative Water Volume Injected= 20,000 bbls Time Pressure Time Pressure Time Pressure (Hours) (PS IA) (Hours) (PS IA) (Hours) (PS IA) 0.000 4553.1 0.002 4225.0 0.394 3157.1 1.511 0.011 3700.0 0.423 3152.1 1.545 0.020 3522.5 0.429 3151.1 1.579 0.029 3436.5 0.462 3146.1 1.612 0.038 3390.2 0.463 3145.7 1.646 0.046 3359.3 0.496 3140.7 1.680 0.055 3338.6 0.531 3136.7 1.714 0.064 3320.7 0.564 3131.8 1.748 0.073 3306.4 0.597 3127.8 1.782 0.081 3294.2 0.631 3123.9 1.816 0.090 3233.7 0.655 3120.4 1.849 0.099 3274.5 0.699 3114.9 1.883 0.108 3266.3 0.733 3112.8 1.917 0.117 3258.9 0.767 3110.7 1.951 0.125 3251.9 0.801 3108.8 1.984 0.135 3245.5 0.834 3105.1 2.018 0.143 3240.0 0.868 3102.5 2.052 0.152 3234.6 0.902 3100.0 2.086 0.161 3229.4 0.936 3097.6 2.120 0.170 3224.6 0.969 3095.3 2.154 0.179 3220.1 1.003 3093.1 2.188 0.187 3215.9 1.037 3091.0 2.222 0.196 3211.9 1.071 3088.9 2.256 0.205 3208.1 1.105 3086.9 2.289 0.214 3204.6 1.139 3085.2 2.306 0.226 3199.9 1.173 3083.2 2.357 0.242 3194.7 1.207 3081.4 2.391 0.260 3189.0 1.241 3079.7 2.424 0.277 3184.0 1.274 3078.1 2.458 0.293 3179.4 1.308 3076.5 2.492 0.314 3174.2 1.342 3074.9 2.526 0.327 3171.1 1.376 3073.5 2.560 0.351 3166.0 1.409 3072.0 2.594 0.361 3163.7 1.443 3070.6 2.627 0.387 3158.6 1.478 3069.2 2.661 2.695 ...... ~ ~:i.~ ~'~i~ 2.763 '~' 2.797 3067.8 3066.5 3065.2 3064.0 3062.7 3061.6 3060.4 3059.3 3058.2 3057.1 3056.1 3055.0 3054.0 3053.0 3052.0 3051.1 3050.2 3049.3 3048.4 3047.4 3046.6 3046.7 3048.9 3044.0 3043.3 3042.5 3041.7 3040.8 3040.1 3039.8 3038.6 3037.8 3037.2 3036 3035 3035 3034 3033 3033 3032 3031 .5 .8 .1 .4 .7 .1 .5 .8 -10- COi"-"qENTIAL INFORMATION Furnished By Conoco Inet. PRESSURE FALL-OFF DATA (continued) Milne Point Unit B No. 4A Pressure Fall-Off Test No. 5 November 1, 1982 Cumulative Water Volume Injected= 68,116 bbls Time Pressure (Hours) (PSIA) Time (Hours) Pressure (PSIA) 0.000 4793.0 0.001 4445.1 0.006 3929.7 0.010 3851.8 0.015 3819.1 0.019 3798.1 0.024 3782.6 0.028 3770.5 0.033 3760.6 0.041 3745.2 0.050 3733.5 0.059 3723.9 0.073 3712.8 0.082 3706.8 0.091 3701.5 0.099 3696.6 0.109 3692.4 0.122 3686.8 0.135 3681.8 0.149 3677.4 0.162 3673.4 0.176 3669.4 0.209 3661.6 0.243 3654.7 0.276 3648.9 0.309 3643.9 0.343 3639.5 0.376 3635.6 0.410 3631.9 0.483 3624.4 0.521 3621.7 0.605 3614.9 0.689 3609.1 0.773 0.895 0.983 1.13 1.25 1.37 1.48 1.60 1.77 1.95 2.13 2.29 2.47 2.54 2.80 2.99 3.26 3.67 4.04 4.31 4.80 5.31 5.81 6.31 6.82 7.32 7.82 8.32 8.82 9.32 9.82 10.33 10.83 11.33 11.83 12.33 12.83 13.33 14.33 15.33 16.08 3603.8 3596.9 3592.5 3585.7 3580.5 3575.9 3571.9 3567.9 3562.5 3557.5 3552.4 3548.3 3544.0 3540.0 3536.5 3532.5 3527.2 3519.6 3513.1 3508.8 3500.8 3493.9 3487.1 3480.7 3474.8 3469.2 3463.7 3458.6 3453.7 3449.0 3444.5 3440.2 3436.0 3432.0 3428.1 3424.4 3420.8 3417.3 3410.6 3404.3 3399.9 -11- CO, ' DENTIAL INFORMATION Furnished By Conooo Ino. ATTACHMENT NO. 6 MILNE POINT UNIT INJECTION TEST OBSERVATION WELL PRESSURES ( OURS) TIME B-3 C-1 D-1 TIME B-3 C-1 D-1 -10 3025.24 0 .26 10 .28 20 .28 30 .30 40 .34 50 .38 60 .44 70 .54 80 .62 90 .78 100 .92 110 3026.10 120 .24 130 .38 140 .50 150 .62 160 .76 170 .88 180 3027.06 190 .20 200 .32 210 .44 220 .58 230 .76 240 .90 250 3028.06 260 .20 270 .38 28O .48 290 .64 300 .76 2613.10 310 The monitor- .30 320 lng of the .36 330 C-1 well .38 340 was delayed .40 350 because of 360 equipment 370 malfunctions 380 2613.18 390 .36 400 .56 410 .84 420 .90 430 .94 440 .96 450 .84 460 .74 470 .80 480 .88 490 .94 500 2614.00 510 .06 520 .10 530 .04 540 .08 550 .30 560 .2O 57O .00 580 .06 590 .10 600 .22 610 .26 620 3028.90 3029.06 .24 Monitoring of B-3 is terminated because of obvious com- munication and the need for the pres- sure gauge in the B-4A well 3154.80 .74 .68 .66 .84 .80 .84 .70 .70 3155.00 3154.96 .96 .94 .84 .84 .96 3155.04 3154.70 .80 3155.00 3154.60 3155.00 3154.80 .90 .80 3155.00 .10 .00 2614.32 .20 .18 .24 .30 .38 .40 .52 .58 .70 .74 .68 .80 .84 .80 .74 .74 .70 .70 .90 2615.00 .04 2614.90 .80 2615.00 .20 .40 .44 .42 .30 2615.00 .20 -12- CONFIL ,TIAL INFORMATION Furnished By Conoco Ino. OBSERVATION WELL PRESSURES (continued) (HOURS) TIME B-3 C-1 D-1 TIME B-3 C-1 D-1 630 640 650 660 670 680 690 700 710 720 730 740 750 760 770 780 790 800 810 82O 830 84O 850 860 870 88O 89O 9O0 910 920 930 940 95O 3155.20 2615.60 960 .44 .50 970 .20 .36 980 .10 .40 990 .O4 .4O 1000 .10 .50 1010 .00 .50 1020 .60 .66 1030 3156.40 .60 1040 .20 .64 1050 3155.60 .50 1060 .00 .30 1070 .10 .60 1080 .30 .60 1090 1100 Replace the Time cable and spent run gauge working deeper on surface equipment ~2941.25 .50 2940.00 .25 .75 3154.80 2941.00 3155.40 .25 .35 .50 .16 .60 .04 .60 .18 .50 .30 .60 .00 .40 3155.20 .80 3156.00 3155.30 .30 .30 .26 .24 .32 3155.18 2941.20 .80 2942.50 2941.50 .20 .20 .50 .00 .00 .20 -13- -: ;; (conoCo); ,, : ~ 'onoco inc. To [] Under Separate Cover Subject hq If-. I'"t ~ ?0 { ~ T [] Enclosed O,",,T ~ Plo qA '-%ecord of Shipment of ' ~onfidentiai Information From Date Wa ht~qr-ID -P~c~v~c¢,O--~ ?-ow C°~-~oeO I I"t,)ErCTlQt't --P~(~IC~__7 LxjG5 Quantity Contents. "~ -~(s ¢.~ UT{C_) hi Transmittal Approved By Date ].-~structions: Please ac-knov~ledge receipt promptly by signing and 4~e_tuming carbon copy. 5:~eceJ v e d By Date : Remarks Transmittal Copy Only To 13-98 PCX1, 7-79 NORiCK OKLA, CITY PRINTED IN U.S.A- H. D. Haley Conoco lnc. Manager of Alaskan Operations October 1, 1982 2525 C Street Suite 100 Anchorage, AK 99503 Mr. Jim Trimble Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble- Attached are completed 10-403 forms for: Milne ?oint A-l, B-l, B-2, B-3, B-4A, C-1, C-3, D-l, Kavearak Point 32-25; and Gwydyr Bay State #2A. All of the above are classified as suspended wells and Conoco will be contacting one of your representatives to conduct an inspection each year until the wells have a plugged and abandoned status. Also attached is a completed 10-407 form requesting a change in status for Gwydyr Bay State #1 from suspended to plugged and abandoned. You will also find the photographs you requested concerning the recent inspections of Gwydyr Bay State #1, #2A, and Milne Point A-1. Please contact J. T. Dosch if additional information is necessary or if you should have any questions. Yours very truly, H. D. Haley Manager of Alaskan Operations JTD/tt cc- G. A. Merriman - w/o attachments A. E. Hastings - w/o attachments STATE OF ALASKA ALASKA ~..,L AND GAS CONSERVATION CC,,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L L)/C~ OTHER [] 2. Name of Operator Conoco Tnc. 3. Address 2525 C Street, Suite 100, Anchorage, Alaska 99503 4. Location of Well 165' FNL, 1158' FWL, Sec. 19, T13N, R11E, UM 5. Elevation in feet (indicate KB, DF, etc.) 59' KB 6. Lease Designation and Serial No. ADL 47437 7. Permit No. 82-100 8. APl Number 50- 029-20748-01 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point B-4A 11. Field and Pool Kuparuk Field 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other XX] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. Conoco will contact one for your representatives to conduct an inspection each year until the well has a plugged and abandoned status. Signed Title Manager of Alaskan Operations The space below for Commission use J Date 10-6-82 Conditions of Approval, if any: Approved Copy/ An inspection will be necessary by August 1983. BY W. By Order of Approved by i-;U RLER COMMiSSiONER the Commission Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Receipt of the following material _k,~-~ .,~-~.-~ .~/,;1~'~ - QUANT I TY RE: which was transmitted via is hereby acknowledged: DESCRI PT ION DATED: Copy sent/~ sender YES ~/~ NO September 10, 1982 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton. Enclosed are the following subsequent Sundry Notices' - Wireline re-entry, Kavearak Point 32-25 - Perforations, Miqne Po..i-fiti.:-B~- - Cement squeeze, Milne Point B-3 - Gravel pack completion, Milne Point B-1 If you have any questions, please call either Don Girdler or me at 279-0611. Very truly yours, Gary A. Merriman Supervising Production Engineer tt cc: R. J. Francis, w/attachments A. E. Hastings, w/attachments D. R. Girdler, w/attachments We~I Files - 32-25: B-4A:B-3:B-1, w/attachments CONF/DENTIAI ~,. , ,- STATE OF ALASKA ~" ~LASKA v,L AND GAS CONSERVATION GL ..,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER Suspended 2. Name of Operator Conoco Inc. 7. Permit No. 82-100 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50-029-20748-01 4. Location of Well FWL, Sec. 19, T13N, R11E, U.M. 165' FNL, 1158' 6. Lease Designation and Serial No. ADL 47437 5. Elevation in feet (indicate KB, DF, etc.) 59' KB - Ns] 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point B-4A 11. Field and Pool Kuparuk River Field Kuparuk River Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] '- Perforations Stimulate [] Abandon [] StimuFation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. . . Signed , Tit~eSupervi si ng Produc-ti on Enqi neer Date The spa/below ~r Commission use 9-3-82 Conditions of Approval, if any: By Order of 'Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Conoco Inc. september 13, 1982 2525 C Street Suite 100 Anchorage, AK 99503 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subject: Monthly Report - Milne Pt. B No. 5 Completion Report -!Milne Point B No. 4A-' Enclosed are two copies each of the subject reports. If you have any questions, please Contact Don Girdler at 279-0611. Very ~u~y yours, R. J. Francis Manager - Engineering SHB/kr Enclosures cc: R. J. Francis, Anchorage, w/Attachment A. E. Hastings, Anchorage, w/Attachment G. A. Merriman, Anchorage, w/Attachment D. R. Girdler, Anchorage, w/Attachment Well File - B-4A Well File - B No. 5 ' ? STATE OF ALASKA ALASKA AND GAS CONSERVATION' MlSSl " WELL COMPLETION OR RECOMPLETION REPORT AND LOG - 11. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED~] ' ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Conoco Inc. 82-100 3. Address : 8. AMI Number 2525 C Street, Suite 100, Anchorage, AK 99503 50-029-20748-01 ~-o~%t~;)~lALbwell at surface LOCATiONS'~ 165' FNL, 1158' FWL, Sec. 19, T13N, RllE,U.M. 9. Unit or Lease Name , Milne Point Unit AtT°p~r°el~c' ~lnterva11497' FNT. & 3135' FET., Sec. 24; T13N, R10JE,U.lVjLo 10. WellNumber iSurf.~ Milne Point B-4A -.-~A~.T _~_~t~D~. th 1475' FNL & 3514' FEL, Sec. 24, T13N, R10E, U.M. 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Pool KB = 59'I ADL - 47437 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116. No. of Completions I I 6/27/82 7/12/82 7/22/82 feet MSL -17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD}! 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9500'MD (7281'TVD) 9382'MD (7190'TVE YES I~ NO I~]I feetMD 1800+ 22. Type Electric or Other Logs Run SP/DIL/SFL/GR, Sonic, NGT/CNL/FDC, HDT, SWC's CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED . .. 7" 29# L-80 0' '9476' ~.. o7 1000 sks. Class G 300 sks. Permafrost 200 bbls. Arctic Pac 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3½" 9.3~ 8916' 8849' 8960~ - 8990' 12 SPF ' : 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED " 3112' - '3553' ~lUg Back w/300 8ks. ClaSs-G 2588' - 3150' ?lug Back w/250 sks. Class G _ . ..... 9182 ' . 9182' - 9184' ~nd Sqz. w/150 sks. Class . _ . 27. PRoDUcTION TEST Date First ..... Production ::: , I-Method. --,.:,°fOperati°n (Flowing, gas lift,, etc.) . . Date of Test Hours Tested PRODUCTION FOR OIL-BBL ~GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I , TEST PERIOD I~ . _ . GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow:Tubing Casing Pressure CALCULATED__ OIL~BBL Press. : -24-H~DUR RATE"F _ - 28. CORE DATA . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . None taken. :;'~ .. : ' : '-' ' "' ' '~cI~OL · . - '4~sk~ Oil & Gas Cons. Co~r~r//i,,¢.~;,''' Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Schrader Bluff' 4112 3876 West Sak 5062 4438 Middle Kupar uk 8935 6857 Lower Kuparuk 9238 7071 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". MILNE POINT NO. B-4A WELL COMPLETION REPORT AND LOG PRODUCTION TEST DATA Listed below are representative test data on Milne Point B-4A: Production Test No. 1 Interval Tested (M.D.) Date of Test Method of Operation Hours Produced Oil Produced (BBL) Gas Produced (MCF) Water Produced (BBL) GOR (CF/BBL) Minimum Surface Flow Restriction Flowing Tubing Pressure Casing Pressure Downhole Pressure Gauge Depth (MD), Flowing Bottomhole Pressure (PSIG) Final Bottomhole Buildup Pressure , (PSIG) Average Production Rates: BOPD BWPD MCFPD Oil Gravity (°AP1) , Initial Bottomhole Pressure (PSIG) 8960' - 8990' 7-28-82 Flow to Separator 13.5 575 BBL 173 MCF Nil (0.01%) 301 24/64" 540-580 NA 8874' (6819' TVD) 2831-2916 3427 (Initial Buildup) 1022 Nil (0.1BPD) 308 23° 3431 Production Test No. 2 8960' - 8990' 8-2-6-82 Flow to Separator 18.0 800 BBL 217 MCF Nil (0.01~) 271 24/64" 695-510 NA 8838' (6794' TVD) 3073-2771 3399 1067 Nil ( 0.1 BPD) 289.3 22° 3416 Pressures reported @ gauge depth SEP l ~ Gas Cons. Co~nmissior~ /~nchorafie. · i! 5'e~:~-r Ynnn Gu~ A~ C'OM1%ETIO H L~.MG'rH O. -/z/ z · 1.1~ 50.06' o o0~ 1.5'1' RE£EIVEF SEP 1 ~ ~' L982 Gas Cons. Comrnis f~,~chorago O'pgcT~or~ .1657 /'I~.Z. Z. 99Z" .~. 875' '/on Z.99Z" z.815" z.qq£ Z- 75"* I As proposed with the Sundry Notice dated September 14, 1982, Milne Point B-4A has been completed in the Middle Kuparuk Formation and suspended. The following lists the sequence of operations performed: MILNE POINT NO. B-4A COMPLETION AND TESTING REPORT WELL HISTORY DATE OPERATION 7/16/82 7/17/82 -4nChora~ ' 7/18/82 After Milne Point No. B-4A was drilled and the production casing was cemented in place, a 6" Mill. was run in the hole to drill out cement from 9338' (landing baffle) to 9382' and the hole was circulated clean. A Gyro Survey was run from 9325' to surface, and a cement bond log (CBL) was run from 9365' 'to 6100'. Evaluation of the CBL indicated poor cement bond below the pay zone. A two foot interval (9182'-9184') of casing was perforated with 4 JSPF. A 7" EZSV squeeze packer was run in the hole and set at 9140'. A 10 BBL water preflush was pumped, followed by 100 sacks of 15.8 PPG Class G cement w/l% CFR-2, 0.2% HR-7, 3% KC1 and displaced with drilling fluid at a rate of 2BPM (3400 psi) to 1BPM (3000 psi). An estimated 31 BBL of cement was pumped through perforations. A 6" Mill was run in the hole and the cement and EZSV was drilled out from 9140' to 9382'. The squeeze perforations were pressure tested to 1500 psi resulting in a slow leak-off. While displacing the drilling fluid, a slow influx of fluid was observed. The hole was then displaced with 9.9 PPG drilling fluid to kill. the well. An EZSV squeeze packer was run in the hole and set at 9112'. A 10 BBL water preflush was pumped, followed by 150 sacks of 15.8 PPG. Class G cement w/l% CFR-2, 0.2% HR-7, 3% KC1, and displaced with drilling fluid at a rate of 1BPM for the first 18 BBL (3150 psi), ½BPM for the next 7 BBLS (2950-3250 psi), and ~BMP for the next 6 BBLS (3000-3500 psi). The pumps were shut down for 10 minutes and then two ½ BBL stages were pumped with a 10 minute 7/19/82 712o182 7121182 7~22/82 7/26182 S£P i N~ska_ Oil & Gas Cons, Commissior~ interval between stages. An estimated 29 BBLS of cement were pumped through perforations. A 6" Mill was run in the hole to drill out the EZSV and cement from 9112' to 9382'. Squeeze perforations were pressure tested to 1500 psi. A CBL was run form 9362'-6300'. This log indicated a substantial improvement in the cement bond surrounding the squeezed interval. A mill and scraper was run in the hole and the drilling fluid was displaced by fresh water. The well was observed for flow with no formation fluid influx observed. A 20 BBLS caustic sweep, 10 BBLS water, and 10 BBL gel pill was circulated to clean the well bore. A Vann completion assembly was run in the hole on 3½" DSS-HT, 9.3#/ft tubing. A GR-CCL was run inside the tubing from 9100' to 8800' for depth correlation. The tubing was spaced out and landed in the tubing hanger. The hole was then displaced with diesel. Several unsuccessful attempts were made at setting the hydraulic packer by pressuring up against the downhole check valve. The check valve would not close, and therefore the packer could not be set. The casing and squeeze perforations were pressure tested to 2000 psi and held. A back pressure valve was installed and the BOP stack was nippled down. A tree was then nippled up to the well head and was pressure tested to 5000 psi. The drilling rig was moved off the well. In order to set the hydraulic packer (located @ 8849') an Otis "XX" plug was run in the hole on slickline, set in the "X" nipple located at 8878', and hydraulic pressure applied to the tubing. After setting the packer, the "XX" plug was retrieved with the slickline. The well was then perforated (8960'-8990') by dropping the Vann detonating bar and opening up the well to flow. The well was allowed to flow for one hour, on a choke 7/28/82 7/29/82 Gas Cons. Commfssior~ setting of 1 inch. Flowing wellhead pressure and temperature was 95 PSIG and 76°~ F. Ail produced fluids were flowed directly to the production tanks. The well was shut-in, and an Otis locking mandrel/pressure gauge receptacle was run in the hole and located in the "X" nipple located at 8878'. A Hewlett-Packard (H.P.) pressure gauge, Otis temperature gauge and Otis shut-in tool was run downhole on electric line and was set in the receptacle at 8878'. The well was flowed for a 10.5 minute period and then shut-in downhole for a 100.5 minute build-up period. This initial flow was made through a 1" choke and then flowed to the production tank. Following the initial build-up period, the well was allowed to flow for a time period of 13.5 hours. Flow conditions were maintained in a constant manner to create stable production rates and stable bottomhole flowing pressures. There was a slight increase in wellhead and bottomhole pressures as well as a slight decrease in production rate with respect to time due 'to a suspected plugging off of the variable choke. The choke setting was 24/64". Please refer to page___for test results. Thirteen hours into the final flow period and attempt was made to shut the well in downhole. The well was shut-in for approximately 3 minutes when the wireline was pulled out of the rope socket while pulling additional tension. Without wireline tension, the shut-in tool opened up and the well was allowed to flow for another 25 minutes before shutting the well in at the surface wing valve. This ended production test No. 1. Three attempts were made at fishing the downhole gauges and shut-in tool with the electric line without success. Before running the second fishing tool, the well was flowed for one hour with a full bore choke (2"). 127 BBLS of oil were produced in that time. The calculated flow rate = 3048 BOPD. During the third attempt at fishing the 7/30/82 - 8/1/82 8/2/82 8~3~82 downhole gauges and shut-in tool, the well was allowed to flow for 15 minutes on a 24/64" choke. 19 BBLS of oil were produced. The electric line was replaced by the slickline in an effort to retrieve the fish. Several attempts were made at latching onto the fish with an overshot before having any success. Once the fish was engaged, a variety of wireline tensions and tubing pressures were tried. In an attempt to obtain greater wireline tension it was decided to try a braided wireline. The slickline would not shear free of the fish. A cutter bar was dropped in order to shear the line free thereby leaving a cutter bar and a set of fishing tools on top of the fish. The cutter bar was retrieved with the braided line. An overshot was run on the braided line and was latched onto the fish. After applying several combinations of wireline tension and tubing pressure, the fish popped free and was retrieved. The braided line was again used to run in the hole and retrieve the gauge receptacle and shut-in tool. The spent Vann perforating guns were dropped off the tubing by dropping a ball down the tubing and pressuring up against the ball to 3300 psi (2400 psi over S1WHP). A sudden drop in the wellhead pressure indicated that the guns had dropped off. The Otis locking mandrel/shut-in tool receptacle was run inside the tubing and set in the "X" nipple at 8842'. The Hewlett-Packard pressure gauge, Otis temperature gauge, and Otis shut-in too]. was run in the tubing and set in the receptacle at 8843'. Production test No. 2 was initiated by opening the surface wing valve to begin the flow period. The well was allowed to flow for 18.0 hours through a 24/64" choke into a separator and then to the production tanks. As before, the flow conditions were maintained in a constant manner to create stable production rates and bottomhole pressures. After several 8~4~82 814182 - 8~6~82 8~6~82 hours of flow, it was realized that a significant rise in wellhead and, bottomhole pressure, accompanied by a decrease in production rate was being caused by a plugging of the variable choke. This problem was alleviated by gently tapping the choke adjustment periodically. The choke setting was 24/64". For test results please refer to page-~a After flowing the well for 17 hours, several unsuccessful attempts were made at shutting the well in downhole with the Otis shut-in tool. After 18 hours of flow, the well was shut-in by closing the surface wing valve. A 48 hour pressure build-up survey was run, during which time, downhole shut-in pressures and temperatures were recorded. After completing the 48 hour pressure build-up survey, the downhole gauges and shut-in tool were retrieved. A slickline was then used to run in the hole and recover the locking mandrel/shut-in tool receptacle located at a depth of 8842'. An Otis "XX" plug was run in the tubing and set in the "X" nipple at a depth of 8842'. A Cameron, Type "H" back pressure valve was then located in the tubing head. The wellhead was secured and operations suspended. WELL HISTORY MILNE POINT B NO.4A 6-26 - Accepted rig @ 12:00 p.m. P/U test jt. & test BOP - Hydril to 250# & 2500#; tested rams, choke manifold, inside BOP, safety valve, upper & lower Kelly to 500# & 5000#. Install wear bushing. Caliper & P/U BHA. 6-27 - P/U HWDP & TIH, tagged cmt. @ 2186'. Circ. & cond. mud; tested 13-3/8" csg. w/1500# for 30 min. C.O. cmt. f/2186' to 2400' & circ. POOH & L/D 23 stands excess D.P. f/Derrick. Make-up DynaDrill BHA & TIH. Ran survey f/2400' to 2745'. Survey - Dev: 1° N14.5W @ 2356', 1° N33.5W @ 2410', 2° N82W @ 2505', and 3° N70.5W @ 2601'. Mud Wt. 9.6#. Visc. 45 6-28 - Drlg. @ 3277', made 532'. Ran survey @ 2745', stuck survey took pulled out of rope socket. POOH w/DynaDrill & L/D, retrieved survey. TIH w/jet drlg. assembly. Jet drill & surveyed f/2745' to 3277'. POOH & change BRA & bit. TIH, circ. pressure too low; POOH, looking for washout. Found jet missing from bit, redress bit & TIH. Survey - Dev: 4.25° S64W @ 2697', 5.25° S50.5W @ 2793', 7.5° S55.5W @ 2889', 9.5° S57W @ 3017', 11.5° S58W @ 3176'. Mud Wt. 9.5#. Visc. 43 6-29 - Drlg. @ 4254', made 977'. TIH, drill & survey f/3277' to 3928', unable to build angle. Circ. & POOH. L/D stabs, P/U DynaDrill & TIH. Orient DynaDrill, survey f/3928' to 4254'. Surveys - Dev: 14° S64W @ 3370', 16° S63.5W @ 3498', 17-3/4° S62.5W @ 3625', 30~° S69W @ 4075', 33° S69W @ 4140'. Mud Wt. 9.3#. Visc. 36 6-30 - WOC Depth - 4347', made 93'. Ran survey & POOH: L/D 1½° kick sub & changed out DynaDrills. M/U 2° kick sub & TIH. Ran survey f/4254' to 4347' & POOH. TIH open-ended to plug back. Circ., R/U Halliburton & plug back f/3215' to calculated cmt. top @ 2774' w/300 sks. Class "G" cmt. w/2% CaC1 and 1% CFR-2 mixed at 16.2 ppg. Survey - Der: 34° S67W @ 4203', 35° S68W @ 4227', 35° S69W @ 4257', 35° S75~W @ 4300'. Mud Wt. 9.6#. Visc. 35 7-1 - POOH, PBTD 2700'. Circ. pipe clean & POOH. P/U BHA, TIH & WOC. Tag cmt. @ 3112', drilled cmt. to 3150' & circ., POOH. TIH open-ended to spot plug, W/O Howco. Spotted plug w/250 sks. "G" cmt. w/2% CaC1 and 1% CFR-2 mixed @ 16.2 ppg & drilled cmt. to 2700'. Circ., pump pill & POOH to P/U Dynadrill. Mud Wt. 9.6#. Visc. 38 7-2 - Drlg. @ 3398', made 698'. POOH, P/U DynaDrill & TIH. R/U wireline side door entry sub & TIH w/steering tool. DynaDrilled f/2700' to 3134'. Ran survey @ 3072', POOH; attempted another survey, pipe plugged. L/D 15 jts. D.P. P/U 14 jts. H.W.D.P. & TIH w/building assembly. Survey - Dev: 4¼° S64W @ 2697' 10° S65W @ 2810' 13° S66W @ 2851', 14½° S66W @ 2894', 16° S66W @ 2925'' 17-3/4° S66W @ 2¢57' 19° S66W @ 2989' 20½° S6~Wz~-~ ~ Oil & Gas Cons. Colnrnissiori 3020' 22° S65~W @ 3052' 23¼° S65½W @ 3083' 27° S75½W @ 3211' 29½° S75W @ 3307' . 7-3 - Drlg. @ 4119', made 721'. Drlg. & surveying to 4064'. POOH, pull wear bushing & test BOPE. Reinstall wear bushing, cut drlg. line & TIH to 3077', hit bridge. Attempt to circulate, bit plugged. POOH & installed 3-16's in bit. TIH & checked for circulation. Drlg. to 4119'. Survey - Dev: 34° S73~W @ 3466', 39¼° S72½W @ 3626', 43-3/4° S72½W @ 3784', 47° S73W @ 3948', 49° S73W @ 4013'. 7-4 - Drlg. @ 5434', made 1315'. Work on mud pumps. Drill & survey to 4973'. Drop survey, pump pill & POOH. Change bits & BHA & TIH, no fill. Drlg. to 5134' & work on mud pumps. Drlg. & surveying ahead. Survey - Dev: 51~° S73W @ 4326', 53~° S73W @ 4676', 57½° S77W @ 4894', 56½° S77W @ 5230'. 7-5 - TIH - Depth @ 5667'. Surveyed & POOH to P/U DynaDrill. Change BHA & TIH. Orient DynaDrill & survey f/5453' to 5667'. Pump pill & POOH. L/D DynaDrill & P/U packed BHA. TIH w/packed BHA & bit #25. Survey - Dev: 55-3/4° S77½W @ 5388', 55° S77~W @ 5455', 54° S74½W @ 5518', 55° S71W @ 5582', 54~° S69~W @ 5616'. TVD 4749', V.S. 1948', Coord. S536', W1873'. Mud Wt. 9.6. Visc. 40 7-6 - Drlg. @ 7099', made 1432'. Fill pipe & ram DynaDrilled hole. Drlg. & surveying f/5667' to 6974'. Pump pill & POOH; change bits & BHA & TIH w/bit #26 & 30' drilling assembly. Drill f/6974' to 7099'. Survey- Dev: 53° S66W @ 5910', 57° S66W @ 6230' 50° S65W @ 6546' 48° S65W @ 6864' · , · Mud Wt. 10.0# Visc. 38 7-7 - Drlg. @ 7702', made 603'. Drlg. & surveying f/7099' to 7338'. Pump pill & POOH, no tight spots, P/U new BHA & bit & TIH, no fill. Drlg. & surveying w/packed hole assembly & bit #27. Drop survey, pump pill & POOH. Change bits & run BHA in hole. Survey - Dev: 48~° S65W @ 7056', 52° S67W @ 7246', 53° S65~W @ 7436', and 53° S67~W @ 7607'. Mud Wt. 10.4#. Visc. 46 7-8 - Drlg. @ 8412'· made 210~. Cut & slip drlg. line. TIH w/bit #28. Fill pipe & break circ., no fill. Drlg. & survey f/7702' to 8412'. Drop survey, pump pill & POOH. Survey - Dev: 52° S67½W @ 7852', 50~° S68½W @ 8107', 50° S68~W @ 8327'. ~ Mud Wt. 10.3#. Visc. 39 7-9 - Drlg. @ 8958', made 546'. Finish POOH, change bits & BHA, TIH w/bit #29 & 10' . Pump pill pendulum· no fill. Drlg. & surveyed f/8412' to 8958' & POOH. Change bits`& BHA & TIH w/packed hole assembly & bit #30. Surveys ~i- Dev: 47½° S78W @ 8679' 45° S85W @ 8869' ~'~'~7-10 - Drlg. @ 9430', made 472'. Finish TIH w/bit #30. Ream 20' under- ~'gau§e hole. Drl§. ~/8958' to 9430' Drop survey, pump pill & POOH Test BOPE & TIH w/bit #31. Survey - Der: 40° N88½W @ 9360'. 7-11- Logging. Drilled to 9500', made 70'. TIH, break circ., ream 10' undergauge hole to bottom. Drlg. f/9430' to 9500' Circ. & cond. mud & hole f/logs. Short trip 25 stands & circ. POOH f~logs. R/U Schlumberger -2 - & log, first log stopped @ 7986', added more sinker bar and went to bottom. Loggers T D - 9478' Driller' . . , s T.D. - 9500'. Mud Wt. 10.4#. Visc. 42 7-12 - Logging @ 9500'. Ran SP-DIL-SFL-GR & NGT-CNL-FDC-GR. Currently running dipmeter. Mud Wt. 10.4#. Visc. 46 7-13 - L/D drill pipe. T.D. - 9500'. Finish running dipmeter, shot sidewall cores, R/D Schlumberger. TIH w/bit #32, 15' fill. Circ. & cond. mud and hole to run csg. Short trip, 20 stands. Circ. & L/D drill string. Mud Wt. - 10.4 Visc. - 38 7-14 - L/D drill string & kelly. Change pipe rams, pull wear bushing, & R/U casers. Run 242 jts. 7" 29# L-80 buttress csg. to 9476', pipe stuck while installing circ. head. Circ. & cond. hole to cmt. Cmt. 1st stage w/1000 sks. Class "G" w/l% CFR-2, .3% Halad-9, & 5% KCL. Good returns during cementing. Mud Wt. - 10.5 Visc. - 42 7-15 - Cementing. Displace cmt., bump plug, floats held, C.I.P. Drop bomb & open D.V. @ 2094'. Displace 7"x13-3/8" annulus w/water; pump 200 bbls. 9.3 ppg Arctic Pack, followed by 300 sks. Permafrost "C" cmt, displace & close D.V. collar, C.I.P. Nipple down BOP, hang-off & set slips on 7" csg, cut off csg.N/U tbg. spool & test w/5000#. N/U BOP stack, change f/7" csg. rams to 3-1/8" pipe rams. Test BOP stack; choke & kill lines w/500# & 5000#. D.V. collar @ 2094', Cmt. baffle plate @ 9354', float collar @ 9397', 7" csg. shoe @ 9476'. ............... Mud Wt. - 10.5 Visc. - 44 7-16 - Install bore protector; P/U kelly, BHA, & 3½" D.P. & TIH; tag D.V. collar @~93'. Drill out D.V. collar & circ. Pressure test D.V. & csg. w/2000#~/~ min. P/U 3~"2 D.P. & TIH, tag cmt. @ 9338' . Drill out landing baffle & cmt. 9338' to 9382' , circ. clean & POOH. R/U Sperry Sun, orient & run gyro survey. 7~17 - Ran gyro survey f/9325' to surface, R/D gyro. R/U Schlumberger, run CBL-VDL-CCL-GR w/lO00 psi on csg. f/9365' to 6100'; POOH & evaluate log. P/U perf. gun & TIH. Shot 4 SPF f/9182' - 9184', POOH & R/D Schlumberger. Make up 7" 29# EZSV squeeze pkr., TIH & set pkr @ 9140'. R/U Halliburton. Test lines, breakdown & establish injection rate of 1 bpm @ 3200 psi; pumped 10 bbls. of water, followed by 100 sks. Class "G" w/l% CFR-8, .5% Halad-9, 4% KCL, followed w/lO0 sks. Class "G" mixed w/l% CFR-8, .2% HR-7, 3% KCL; mixed @ 15.8 ppg. Disp. w/mud @ 2 bpm 3400# to 3900# Final inj @ 1 bpm 2900# to 3000# C I.P 10:15 a m. Reverse out D.P., est. 31 bbls. cmt. out perfs. Circ. & cond. mud. POOH, & L/D tools. WOC. ~!?~7-18 - M/U mill & scraper, cut d~lg. line, TIH & tag EZSV @ 9140'. Mill up ~ZSV @ 9140'; c.o. to 9382', had no hard cmt. below EZSV. Test squeeze perfs w/1500#, held o.k. Pressured up to 3000#, had slow leak-off, held 1500# again. Disp. hole w/fresh water; slow influx of fluid into well; disp. hole w/9.9# mud; well dead; had trace of oil in water on B/U. POOH. Make up 7" 29# EZSV squeeze pkr. Mud Wt. - 9.8 Visc. - 39 -3- 7-19 - TIH, set EZSV squeeze pkr. @ 9112'. R/U Halliburton & test lines w/5000 psi. Breakdown @ 4800 psi. Establish injection rate of 2 bpm @ 4200 psi. Pumped 10 bbls. water; mixed 150 sks. Class "G" w/l% CFR-2, .2% HR-7, 3% KCL, mixed @ 15.8 ppg. Disp. w/mud @ i bpm, 3150 psi (first 18 bbls.); ½ bpm 2950 to 3250 psi (next 7 bbls.); ¼ bpm 3000 to 3500 psi (next 6 bbls.). Shut down for 10 min., pressure dropped to 2300 psi. Staged w/½ bbl. 2300 to 2950 psi, shut down for 10 min. & pressure dropped to 2650. Staged w/½ bbl. 3550 to 3400 psi, shut down, pressure dropped to 2950 psi. Cement in place. Reverse out, est. 29 bbls. cmt. out perfs. POOH, L/D tools. WOC. Make up mill & csg. scraper; TIH, tag EZSV @ 9112'. Mill on EZSV & drill. Mud Wt. - 9.8 Visc. - 42 7-20 - Mill on EZSV pkr. @ 9112', c.o. cmt. below pkr. & TIH to PBTD 9382'. Circ. clean. Test squeeze perfs w/1500 psi - o.k., POOH. R/U Schlumberger; run CBL-VDL-CCL-GR f/9362' to 6300', R/D loggers. TIH w/mill & scraper. Displace mud w/fresh water; check for flow, well dead; pumped 20 bbl. caustic sweep, 10 bbls. water & 10 bbls. gel pill. R/U & POOH, L/D 3~" D.P. 7-21 L/D 3~" . . - 2 D.P & BHA Pull bit guide; R/U & TIH w/completion assembly on 3½" DSS-HT 9.3# Tbg. R/U Schlumberger; attempt to run CCL-GR, tool failed. Worked on tool. Run CCL-GR f/9100' to 8800'. Space out tbg. string & perf. guns, land tbg. on hanger. R/U & displace w/diesel. 7-22 - Displaced well w/diesel. Attempted to set pkr. w/pressure, surges, fluid hammer. Check valve in Vann assembly would not close. Test csg. w/2000# psi, o.k. L/D landing jt. & install back pressure valve. N/D BOP stack, N/U tree, test tree w/5000 psi. Released rig @ 6 a.m. on 7-22-82. Move rig to B-3. -4- :~OF CURVATURE ; ' : ........ ' i :'- -, . ..... . ', .... . , MASNETIC SINGLE:- SHOT- ~ JULY .12~ Ig82 ' - -. - ..... . -. . 800 ' / I ' ~.-~. ~ - ~ :- . ~ - : ~ ; ~ . ~ · ; - . · , ; : : ; . .. : ; · , i ~ _ ...... ' ~ .] -. . , : : .... . - , & Cons. ., - -~ .. _ ; .:. ~ -. ..nOnlZu,~_T~L_.I.VIE~/~':'.;'-L'i-;-r, ]'7;-:;-d'; - .' - , ~ - ' -' ' '. : i I . ~ - · i . ~ ; : , ' ~ . , ~: : ' ' ;' '; ~ , ' ~'i ~ '7-'~-' :. .... -' - --- ~ .... '-:- -~ ;- ~1~ POI'NT-B4~-~-Lj ~ ~ : i ~-. ;-~ i.~ ; : ~ ~ '.: .... - = . - = , · , . , - . ' · ; · ; i . ' ' : '-'; : i I'; ! : RADIUS OF'CURVATUREs- i i ' ~ ' ; : ' ; .... ~.-... - _.~._ ;__;__~LL'.__L'-.J _~.:._. '- =_~.aULY.. 12., 198g L; _~_'..__.~ ' -:_~ ..... ~. ~.- .... ; .... L.~ : .... ~ .. , .i =._: ...... ~ ..... v- - . ~ . -- : .t ,-- - · - ' ,· :- ": ;'' :' ,-- ' ~ ' i : ' i ~ , · . : . . . . '} . : i ~'. :', r ~-- - - - ' ', ; ....... : "i'; ' . .......... ..... ~ - . ...... : ~ ' , ~ ; ~'~ ~ ....... '-':-: '-'~- f-. ,-.! ' : -: ,' ~ ....... :- ' - '~ ~' ~ ' - ~ - . , =: i . . - - ~ ........... ~ ; '· --;' - - ; .......~ ~ - ~ ..... -, ........ 1 - ; .... ' - ~ ' : , i: ' : ~ - ~ · · '- I ,' ' ' i ' ' ' ' ' · - , - ; ..... '; ~ i , . ' ~ · i ~ ..... : ', ' ~ . ' : ''1 ; ' ; ' , ' ~ · , ; - , . . ........ : '. ~ .. . . . . . - ~ ; - = ...... I . ~ '~ ' ' ., . ~ .... : . . . : I - , I , ~- · : ~ .... + ~ -~- ~ ..... I - - ~-.[ - ~ . - - , .. · ' I ..... ~ · , , , : '. ', ' · , ; i ~ : · ~ i .' I . , , , i , . -' .~ ........ ! ..... , ; ' - I ' :' ; ~ -~ - i -~ ....... t-4-- ~-~' " '- ' - i~ ~ ' -'' ' ' ' · ~ '~ - - ' : '~ ' " ' ' - t '~ i '-'~ .... ~ '--~- --; .... ," -:-1 - - - r'-~--'~' - ~ ~ ~' i ~ ' ......... ' '1 ~' ' ~- - -, .... .- - ~ ' · .... ~ -~ .... ~. -' , - · - ; ---~-- ~- --g : -d ...... ! ..... ; , - , · ..... .... ~-' ~ ........ : . · - : .... ~- ~--: -~ ...... i'-~ '- 't-~ ~- - .- + -~.: .... ~- -- l ~ -- · .... i ' - . · .... " ~':-TV-: ', ': : '~ r": ' -; ' '-- : ; : .... :' '~" -;'i-~ -~'; .... ' ...... ~ ...... : - ' ~ ' '; · : ..... ' ....... ' _;_ . ~_- - - ~ _ _ , :_ . . ._ : . _ t_ , . . , '_ _~ _ : ' . ..... '] ~ i :' -' ~ ' ; -i-__i-'~--~_.~ ';-.._i-'Ei-'iT~ ;_ [ i'_; ; ] I'~" _.'~ ~.: i-~ ~. :~ ~o0 ~ ' : ' ' - .... ' ' ~ , : [ ~ i": ' ~ ' i'; !-// i ! ~ i ~ ' ' ' ' ~ ' '" ~0 ' :'-i '~'5600 ' , "' .... ..... , .- ..... :-: . - :- --~:- - ...... ~-t ..... : .... :--~--I";--~-:'-' ~- - ~ ~ ~ - uo-: ~: ~ ~--:- i - . , ~ = , - - - ~ · ; - : i : ~ ~ , ; ' , , : ' ' . ~~ .... :_.. j · . ........... ·, : ._ ,_. _ l, ,,~-~~ ~ ,.. · : : : '; : - - : ~ j . f i ~ : _ . . ~ ~ - · ' ~ ~ ; · I ' : ' : ' I ~t ; ' ' ' ~ ' ' ;.. .I ~ ' , - .'. · - ~ i .- ' '~ . -. ' 14 . - ' ~ ~.. i: ' : : _ '. ) ! .; . : i . ' ' ' I : . i ' . : · . ; , ..... ~ : -~ .;-: ......... i- -~VD= 7E~'I ' ;~.'-~; .... ' ....... i ".-; i-'*--TM -~"' , ~ - .. . . , · - ...... '"~ ...... ;-'' ['; i'~'~ ~ ..... - '~ ;'-i-; ~" ......... - ~. -: ;-': :"'~-'- :, "' "' ; ........ ; .... ~-' :' -' - -"~ .... ~': ' ' ] : ......... ~ 7 ~ : ' ,' .' "': : .... · , ~ . t , ' : ' ..... ' ~ '[ .... ;" -': ': ' ; " :- ' "- ~ ,-i ' ' ' , . ' '' I . ..... ; =.~ . ..: . , ~ :-: , ~ :-~ . ;_ . ~ ... [ ~ . ~ . ~ [ ~ ..... - ........ - : .~ ........... , ..... , _ _ .j _.: _[ ....~ . _, ~ ......· ............ , ........... ' ' ' ' ; : = ' i' ; ~ : ; ' ~ ~ ; ~ ' '· 'I ~ ' . ; '~ I ' ~ ' ' ~ , ' ' ' - ; ' ~ ' ' [ : ' · : ; ; ; ; : i ·i ' : - ,t': ' , ' ' i : ' , ' ~ ' . . . [ ' · , :.'_/~. i ._; .~'. ~. t.-,. ~'-~.; ~. _,/_'. ~ __.; ~-'i-'-i/ ~ '~-' .i '. '-'-.-i iI ALL-DEPtHS SHOWN.'[ ' ~ ' ' .... '. -:. TVo ' '~:- "i ' -: i ]- ~" f-t ~ ~'-: ' ' ' :" . -- -r - : ......... * -;- -r .... ~ - - --: ...... .. ~ ._; , ...... :... ;.-~.. ; ........ ---: .... ~ .... : - : ...... ~'i " ..... --'-T-~ ...... I ................. --~ ~"~--'~ ....... .-: .... ~'~-'1'-~ ...... ' ...................... '"-=-" · , . . .......................... ' ...... ' .~ _! ,._ -; _ :_: ........... ; ...... - ....... '~ ~ . ~ ~. ' ~ , I : - · , , , · . ' . ~ ~ ...... ~. · . ~ . .: ........... ; , ~ .... ~ ~ ............... . . . ~ ~ . . ~ ; . ~ . . , .... ~ ~ ........ ~ ' ' ' -] ..... ~- -'i .... ~"~ .... -~'~ ' ' ...... I' ; ': ~ ....;'~'--,'' ~ .......... ~ ' " ~ ....... t-' ..... ' ......... ~ ..... ; '' .... ' · "-i~,!-~ i ~ ~'-' 'i ~--' i-;-~'-- !" '~i. ~; ~-~-'I'-;'~-~~ ,-'i-i-~ : : :-~ .... :' : ~ ..... .... · -' -~ t ...... ~ - ~ ,,' ~, ........ . , ~ ~ . ~ ' --- . ~- . -t - , ~ ' , ~ . ' ' ~ ! ' ' .... - ~ - . , ~ ~ , = , · . , - :· - ' / - . - - : · . i , , ~ - , ' - : - - -- i .... ~ · '-! . ~-*- ~ ~ -- ~ ~ ~ - ~ ...... ! -- ~ · - t-. ~- ........ · ! _ · , , - ~ ~ . ~ i i i i .. COHPUTED ON 7/12/82 USING RADIUS. OF CURVATURE TECHNXQUE FROH SURVEY DATA TAKEN 7-10-82 FINAL CLOSURE DIRECTION $ 70,22 g SS 6REATLAND ])TRECTIONAL DRILLIN6 CONPLETION REPORT SEP 1 1882 A!~,sk~ Oil & Gas Oons. RECORB DF SURVEY Anchor~g~ (UELL ASSUHED 9ERTXCAL TO 2266.0) HEAS, DRIFT TRU VERT SUB SEA SECTION DIRECTION DEPTH DE6 HN DEPTH DEPTH DISTANCE AN6LE 0 0 0 0,00 -59.00 0.00 0,00 RELATIVE COORDINATES FROH DELL-HEAD 0,00 0,00 CLOSURE DISTANCE BE6 HN SEC 906 LE6 SEVERITY 2266 0 0 2266.00 2207.00 0.00 0,00 0.00 0.00 0.00 0 0 0 0.000 2356 I 0 2356,00 2297.00 2410 I 0 2409.99 2350.99 2505 2 0 2504.95 2445.95 2601 3 0 2600.86 2541,86 2697 4 15 2696,67 2637,67 2810 10 0 2808,75 2749,75 2851 13 0 2848.92 2789,92 2894 14 30 2890.69 2831,69 2925 16 0 2920.59 2861,59 2957 17 45 2951,21 2892.21 2989 19 0 2981.58 2922.58 3020 20 30 3010,76 2951,76 3052 22 0 3040.58 2981.58 3083 23 15 3069.20 3010.20 3211 27 0 3185.06 3126.06 3307 29 30 3269.62 3210.62 3466 34 0 3404,79 3345.79 3626 39 15 3533.16 3474.16 3784 43 45 3651,46 3592,46 3984 47 0 3791,94 3732,94 4013 49 0 3811.34 3752.34 4326 51 30 4011.47 3952,47 4676 53 30 4224.52 4165.52 4894 57 30 4347.98 4288.98 5230 56 30 4530.97 4471.97 5388 55 45 4619.04 4560.04 -0.07 N 14,50 -0.00 N 33,50 1.48 N 82.00 5.51 S 70.50 11.56 S 64.00 25.50 S 65,00 33.65 S 66,00 43.84 S 66,00 51.97 S 66,00 61.24 S 66,00 71,30 S 66.00 81.74 S 65,50 93.30 S 65.50 105.18 S 65,50 159.45 S 75.50 204.71 S 75.00 288.15 ' S 73,50 383.45 S 72,50 488.04 S 72,50 630.22 S 73,00 651.75 S 73.00 892.09 S 73.00 1169.43 $ 73,00 1348.39 S 77.00 1628,21 S 77.00 1758.40 $ 77.50 0.76 N 0.20 1.62 N 0.58 2,91 N 2.62 2.49 N 6.75 0.14 N 12.34 5.89 S 24.99 9.28 S 32.42 13.43 S 41,76 16,75 S 49,21 20,53 S 57.69 24.63 S 66.91 28.93'S 76.46 33.74 S 87.01 38.69 S 97.86 56.80 S 149,02 68.37 S 192,96 91.08 S 273,46 118.97 S 364.71 150.45 S 464.53 192.65 $ 600.46 198.95 S 621.06 269.31 S 851.18 350.49 S 1116.71 396.97 S 1290.17 460.35 S 1564.74 489,31 S 1692.69 0.00 0 0 O' 0.000 0,79 N 14 29 59 g 1,72 N 19 40 18 g 3,91 N 42 2 11 g 7.19 N 69 44 33 g 12.34 N 89 19 58 25.67 S 76 44 24' g 33,72 S 74 1 57 g 43.87 $ 72 10 Olt 51.98 S 71 12 4 la. 61,24 S 70 24 48 g 71.30 S 69 47 81.75 S 69 16 20 93.33 S 68 48 14L'U rh ~ 105.23 S 68 25 4?Lil'L 159.48 S 69 8 2 il':, 204.71 S 70 29 20 288.23 S 71 34 47"11" 383.63 S 71 55 58 488.29 .S 72 3 16g', 630.60 g 72 12 41:#i: 652.15 S 72 14 15'g. 892.77 8 72 26 35 g 1170.42 S 72 34 30 il: 1349.86 S 72 53 5'1 il' 1631.05 S 73 36 21'U 1761.99 S 73 52 37 g 1.111 0,011 1,054 1,045 1.303 5.089 7.318 3,488 4.839 5,469 3,906 4.843 4.688 4,032 3.343 2.607 2,846 3.291 2,848 1.630 6,897 0.799 0,571 2.252 0.298 0.522 ), HILNE POIIIT D-4R · DRTA X#TERPOLRTED FOR EVE# 100 FEET OF SUDSEA DEPTH HEA$. TRU VE'R,T DEPTH DEPTH ..SU~SER 'DEPTH :.,3~00 ,~3700 ~'4000 "4100 ~4200 i 3oo 4500 4600 4700 4BO0 ?oo 5000' "5t00 5200 5300 5400 5500 5600 )5700 5800 5900 6000 6100 6200 630O 6400 6500 ,66oo :&700 6800 6900 ?000 3795 3659 393.7 3759 4088 3859 4244 3959 4404 4059 4568 4159 4737 4259 4914 4359 5098 4459 5280 4559 5458 4659 5630 4759 5800 4859 5967 4959 6130 5059 6290 5159 6448 5259 6603 5359 6755 5459 6907 5559 7057 5659 7214 5759 7376 5859 7542 5959 7707 6059 7871 6159 8030 6259 8188 6359 8344 6459 8496 6559 8648 6659 8794 6759 8934 6859 9070 6959 9205 7059 HD-TVD VERTICAL DIFF. CORRECT. 136 34 178 42 229 51 285 56 345 60 409 64 478 69 555 77 639 84 721 82 799 78 871 72 941 70 1008 67 1071 63 1131 60 1189 58 1244 55 1296 52 1348 52 1398 50 1455 57 1517 . 62 1583 66 1648 65 1712 64 1771 59 1829 58 1885 56 1937 52 1989 52 2035 46 2075 40 2111 36 2146 35 7/12/82 RELATIVE COORDINATES FROH gELL-HEAD 152.68 S 471.62 182,65 S 567,87 215,47 8 675,10 250.62 S 790,04 287,23 $ 909,80 325.29 S 1034.29 364,44 S 1163.98 400.80 S 1306,80 435.51 S 1457.13 469,72 S 1605.55 501.82 S 1749,12 542.08 S 1882.96 591.58 S 2011.73 644,92 S 2134.63 697.08 S 2251,78 747.98 S 2365,90 798,21S 2476.44 848.37 S 2584,48 897.11 $ 2689.00 944,97 S 2791,65 992.39 S 2893.32 1041,40 S 3002,57 1092.56 $ 3120.50 1146.28 S 3241.14 1196.88 S 3362,52 1246,42 S 3482,14 1293.44 S 3597.84 1338,30 S 3711.33 1382.09 8 3822.65 1419.52 $ 3931,42 1448,52 S 4040,80 1467,82 S 4145,72 1477,39 S 4244.66 1482.67 S 4338.15 1484,90 S 4429,37 DATA ZNTERPOLRTED FOR EVEN 100 FEET OF SU:BSEA DEPTH 7112/82 HEAS. TRU VER'T SUD SEA HD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT. ~ m..~mmmmm 9341 7159 2182 36 9472 7259 2213 31 RELATIVE COORDINATES FROH gEL:L-HEAD 1484.20' $ 4518,17 1481.27 $ 4601.40 g DATR INTER~LATEB FOR EVEN 100 FEET OF SUDSEA DEPTH HEAS. TRU VERT 'SUB,SEA HD-TVD VERTICAL DEPTH DEPTH .~EPTH DIFF. CORRECT. 159 259 359 459 559 659 . 759 859 959 1059 1159 1259 1359 1459 1559 1659 1759 1859 1959 2059 2159 2259 2359 2459 2559 2659 2760 2861 2965 3o 2 3 82 3295 3412 3534 3661 159 259 359 459 559 659 759 859 959 1059 1159 1259 1359 1459 1559 1659 1759 1859 1959 2059 2159 2259 2359 2459 2559 2659 2759 2859 2959 3059 3159 3259 3359 3459 3559 7/12/82 500 600 '700 '800 900 1000 1100 1200 1300 1400 1500' 1,600 1'700 1800 .1900 :2000 2100 ':2200 2300 '2400 2500 ,26oo 2700 2800 29OO 3000 3100 3200 '3300 3400 mmwmmmmmmm, mmmmmm--mmmmmmm RELATIVE :COORDINATE8 FROH UELL-HEAD 0 0 0.00 0 0 0.00 0 0 0.00, 0 0 0.00 0 0 0.00 0 0 0.00 0 0 0.00 0 0 0,00 0 0 0.00 0 0 0.00 0 0 0.00 0 0 0.00 0 0 0.00 0 0 0,00 0 0 0.00 0 0 0,00 0 0 0.00 0 0 0,00 0 0 0.00 0 0 O.OO 0 0 0.00 0 0 0.00 0 0 0.81 0 0 2,36 0 0 2.91 0 0 1.23 1 1 2,64 2 1 10,24 6 4 21 13 7 36,90 23 10 53,28 36 13 66.85 53 17 82,83 75 22 102.25 102 27 125.61 0.00 0.00 0,00 0,00 0.00 0,00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0,21 g 1,35 U 4,77 g 9.94 U 18.11 W 34.58 tJ 60.00 U 93,93 U 136,63 U 187,25 g 245.11 U 310.68 # 385.75 U ) ) HILNE POTNT B-4A HEAS. DRIFT DEPTH DES HN 5455 55 0 5518 54 0 5582 55 o 5910 53 0 6230 51 0 6546 50 0 6864 48 0 7056 7246 7436 7602 53 0 7852 52 0 8107 50 30 8327 50 0 8679 47 30 8869 45 0 9360 40 0 9500 39 0 TRU VERT SEA DEPTH ':DEPTH 4657.t1"; "ii4598.11 4693, .i:i~4634.69 4730.1 ~671.86 4923.64 4864.64 5120.64 :::/'. 5061.64 5321.64, :' 5262.64 5530.26 ..: '::.i:~5471.26 48 30 ' 5658.10'" ""',",;5599.10 52 0 5779, §8':viT. r.:5720,58 53 0 58?5.24:': 5836,24 5995,14 ':::,'5936 · 14 6147 · 33 ,'"'i';'~,,6088 · 33 6306 94 6447.61 ::~;:.:i':",6388.61 6679 69 6811.06" ;:.&752.06 7172.95 13 · 95 , 7280 · 98 7221 . 96 RECORD OF SURVEY SECTION DIRECTION RELATIVE COORDINATES CLOSURE DISTANCE ANGLE FRON UELL-HEAD DISTANCE DES HN SEC 1813,09 S 77,50 g 501,24 S 1746,51 1864,11 S 74,50 g 513,64 S 1796.27 1916,16 S 71,00 U 529,09 $ 1846,02 2181.30 5 66,00 U 626.31 S 2092.82 2432.76 S 66.00 U 728.87 S 2323.18 2675.76 S 65.00 U 829.98 S 2545.05 2914.75 S 65,00 U 931.41 S 2762.55 3057.40 S 65,00 U 991,94 S 2892,37 3203.06 S 67.00 g 1051,35 S 3025,80 3353.42 S 65.50 g 1112,05 S 3163.76 3485,71 S 67.50 g 1164.9I S 3285,33 3683,82 S 67,50. U 1240,81 S 3468.57 3882,54 S 68,50 g 1315.31 S 3652.95 4051.61 S 68,50 g 1377.30 S 3810.33 4315.56 8 78.00 g 1453.48 S 4063.44 4450,06 S 85.00 U 1473.75 S 4199.08 4765.22 N 88.50 g 1483.87 S 4530.36 4847.77 N 87.00 U 1480.37 S 4619.34 1817,01 S 73 59 12 U 1868,27 S 74 2 31 U 1920,35 S 74 0 25 U 2184.53 $ 73 20 21 g 2434.83 S 72 34 52 ~ 2676,97 S 71 56 16 U 2915,34 S 71 22 5 U 3057,74 S 71 4 13 g 3203,24 S 70 50 22 g 3353.51 S 70 38 0 U 3485.75 S 70 28 35 U 3683.83 S 70 18 58 g 3882,54 S 70 11 51 g 4051.61 S 70 7 36 g 43!5.57 S 70 19 5 g 4450,20 S 70 39 37 g 4767.18 S 71 51 51 U 4850,75 S 72 13 50 g 7/12/82 DOG LEG SEVERITY 1,119 3.498 3.988 1.148 0,625 0,367 0,629 0,260 1.955 0.728 0,768 0.400 0,633 0,227 1.630 2.264 1,156 0.831 HILNE POINT D-4A DATA IN'TERPOt NEAS. DEPTH mmmmmm 1000 2000 3000 4000 5000 6000 7000 BO00 9000 ~TED FOR EVEN 1000 FEET OF NEASURED DEPTH 7/12/82 :i, ,SUB SEA .DEPTH, ' "": DEPTH 1000 2000 2992 3803 44'05 4978 5621 6239 6905 m 940 1940 2932 3743 4345 4918 5561 6179 6845 RELATIVE COORDINATES FROH UELL-HEAD 0.00 0.00 0.00 0.00 26.11 $ 70.22 196,10 S 611.75 417.04 S 1377.13 655,44 S 2158.24 974.24 S 2854.40 1284.63 $ 3575.90 1480.35 S 4290.39 ~ QI þ , ~f"~I,- S'Gi'ii"(¡ì-i'l-'---- ...: -- - .'- - u Ê : p. . ... -- .. ,- .. ...,.- .. .'.' -, :'.~,'.-.., " 'LU ~ ;. tj. .fø,~ ',' ,.. ¡.fíi; ~'- f.!;" ~-)Uh:'/l.. y ._:c~f GIr:.! ::-0 ~ "'::i'" . " ~Ó;, :~~~;;~~~C~~¡:~~ ..tt;,~;;;;!;~-~...,~. -.1,-.,. -,..,~,:-.. :,' - .-- !::::.:.Li... y H~.,!::-:;: H.~t;: L:,.r'/ h" - . .. "':'::" '," "~-:-:--"':'3". '..,' ,. " '. " !~JONRD£NTIA' l-_U'''''--'--'''Of !f.ttA:-f,GR ..::':.;Af';f.:õ:::;"J~.';';':;f.--"-'''' .-..., --, -, --, ..". - ..-----. ~~VERT rCAL SECT .rÓN "'¿~I-CU~~TEP ,'ALQNG, CLOSUHE ".':, ~ .' , .. . 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OF SURVEY .JUL Y 16.: 1 ~:;t;:;~ .. .¡:: - '-"'."""""--"'.'---'-- ¡::=";~f,;.t::"---:'f. .--.. ....-:. .- ..---.--. -"..- ..CONoea INC. .' . -B-4A.-.f"1f-'U'--( BEe I? T 1 ::'N R 11 t }. KUPARUf< F~ I \}EF~ FIELD ALAS'<:f:~ ---.---- - ----' . Cbtlr'Lfff~ATC' .--.---. JULY 19, 1982 JOB NUMBER BOS8-16087 CONFIDE"TlAL t~::~ì,_~~~' __~~1:3¡~i ~~~.. cl. .~~~~; ~': .' . ,'. '..' ... . .' " .-- . It ~--- ------L. 't:: 'r\i f.:Irl-::::if ¡" -t,:,:,'~j l.;;...:'--'U .. :~ICI' ' ~',:':" .~.~. .~~, ,...,. . :v. ':. . INTER~~LøTe;D, ~VALUES FOR EVEN 1'00 FEET (IF :.:.UB.-SE(4 D£PTH ..:~ :'"I .. u Ü !-:';'., -..-- --..-- ...n ---.. . . -- -.-..--... -.-... ..---- ....-- .. "..",.." . ,,'..... . ~ . . '",' . , . _.. - -.. . .. - --..... ... -~--~...~..-..--..'~-.-- TRUE MEASURED VERTICAL ::BE;PT~4 ------n~=nr SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES f:.JEP.:rti, ,NO~TH/6SUTH E(\ST !LJ~ST ;.. ," .. ",~" ',: ,':' "'~)¿..:'; ,,.,,,¡:,,':',:.' ',"~',;~,/..",'. 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'.":' ..~ ': >: .'. ::. ..': <:'::\ :.: .:.' " .~. .'~: <':,~~;~~:':': .~ <~.~.:~~: .' ..''\ :. . .':. ',.~' ." [f{)TE OF SlJRV~Y ..JULY 1. -::.:' ~ 9C::~ 19 T~::~N nfjr-) .' '. ", . 'COMrt.l1',\TION Ðffi"-E-------.--- ._..__n__..__'-.--.---.---.-----.. FIELD ,JUL Y 19, 1982 .jOB 1',lUI1BEH BOSS.., J. .~.C'.:.~i' I<[.:LL Y BUSH I i'.iG CL(~l,/, ~.: :~.=;.;. .. :)(" ~. " , . . . ::. '" .. ~-' '. ..' . CONfIDEMTIAL.-..-,--- ..'- ---_..--~ÜPfiRAror(=SANLi,;.,~Jl~,:L .._n -. .. .---.- n._.. -'--' . '.' ~~,... ,,' ~-:. : II '. '>,: ".:,~,.~", ~'~.: ~ .:' ,.:, :,~ '.;::' ."... .", ':: , INTEtJPO~~TEi:¡" VALUES ..FOR EVEN 1 00 FEL::. f IjF :=~Ut.l'~~f:{'~ DEr" fH ----___."_n_.. . . ': CCrNOCO I NC. . --B-4A-fs;~J { ::.~ ::C .<UF'~~HUj< .:;: 1 \,':::H AL/48Kf\ ---..- --.--------.---,...-.-.---- -..,...--.---------.--.... ..... --. .. .....-. ..-,. . TRUE SUB-SEA TOTAL .ME('~~~;UkE.l.) VEIiT I CAL VERT ¡ CAL R~CTAN~~IL¡:~R CO~H~ I_N~ ~~S N~-.~ '~~~~::'-"..' -. ~~R::~ 1 ~(~i-:- I C --IJEE'.IH.. --:------..Dœ.Tf-1 '.'..' ~H.." ~I~ rFi'.THt.$p~W-:-~:-~~*~...T~.-~J.~t::J:(t~r~.-¡;.,--~r~p~-:-:-,....,.. -- ._._--_.-:-:-~.-:-... ..._._,--....,.~---- ,,' ;': '705i~ 5659. 00 !:Ù¡cÓ().¡'o.q'"<:~ " .... 884.48; S 292:::.15 W139~:;.. o~? ~19"65 ~--.2.2.l.a 571:.":;9 0(1 c.7'.IQ' 00 99'2 '::;6' 9 303':. ' 97-W-..:..---1.451....,:a.~-- ~~1--- ......,- nu.- . ,-,-.--.- _m_... n__'__'-" 'l275 5859qÚO ~800_00 982.45 S 3159.41 W 1~16.18 64.32 75'1,0 5959.00 5900.00 1032.24 S :3281.49 W 1581.,6!::i 65.47 ~---7:¡Q~,-_._~OO ~(JOO_09 ,107~~..~Q, ~ 34Úl..~'y W , 1414-~,44.--'---:---4-;;;::"...7¥--"7---'''-'-'''''''' '_._-..--~,...._'_..__.:"'m'_--_' i:k: ,:1" 70é.5 6~59. 00 " bÙj~',¡'"OOI;:,'~' ':,:..'~ '(~5~ 08,:','$ , " 35l9~;~..5 W .' ~; ''1706. It:; 6'111 71 ,,~,'.;!" :=:025 6259.QÜ,:.~:" ~2o.~.OO" ~:," "."'~:.19~.,27"S,', :.36~~9.71 W, ;" 1'76é..39 '" é:°~f4: ~" 1 gb------éo~9 . ()O \ 6800. 00 '.' '1209 ~ J? è S" --,;37€i*,rO-1~ ' ~, , 1,f:~!~~'{~-- ' . '57 Iõ ;1:-1- ----,.._.:.._~ ,--':':"..-.i..._- 8338 '6459.00 6400.00 .1247.41 S 3864.43 W leJ9.~O 55.90 8492 6559.00 6500.00 . i282.87 S 3976.79 W 1933.95 54~55 ~~_~~I<1/ 6é!:?;'.. 00 ié:OO.OO" lZ.tO.. 6l£.:: .qO~6r19 W ,1-9-05..00----'-:---..._.€t-1'!I"'(J5..,.,u_~_.----,_... . ..- ,_.._.._-_u...__...__._-~_.,,' ;,:,~~:~,., 8789. 67',59'.,.00 '~~"':'~,.1'6iOO,~'oO'..:~~<i.~::,,,:'~'~t.m~'.1,~41";',Q.:..",,,,,.v,:"41~'á';:'69"',W"'.. ~',"2Ó:3'Ò"OO" " ":' "4S'öÖ . .."¡",.,, 'II , 'I' .' , , , , ~ ~" , ~(.:. ....~'" ~ ,., ~ ' ", ' , ,. , ' ':~II, , ' ..-:.. ,. .. :,::'í: '., 8930' 6135$1.. 00 ',":', I;." 9$OO:~90':'J' "~": ~,: ');~$ð'~', 70;,.:,S., ' .. 42a~~ Bß W' ,':~ :'''~ti.71.' ~:~6' " 41.3(:. ::.'. 907') 1959,00 '::., l:900~OO' " :, ;"1::'2"7.38 's ~~~:". 70' W,' :,,' :2111.'¿~-9- '., ' 39..,)~f .__._--.-"'-''''---'--------_.-C..~~ 9206 7059.00 7000.00 1323~2a S 4480.43 W 21~7.74 3~.45 9340 . 7159.00 7100.o"q 13'17 u 84 S' 4"5~8. 60 W 21S¡. 18 . 33ft 43 '~')¡,72 7259.00 72f:O.00 1:311. ~.:~ :;, -46€i-1,. 52 L~ 22it3rl:-6 <:~l.-9a--,.._..__...._._,--_._.__.,,,,-:.,-,---_._':-__.n_._. ::~I' 9500 7280" 10' '" 722i;'10"':<."'/1.31Ö~5-7 S' " '4é;.¿?"6~~ W :.,:,',~ 2219,,90 " : é'a 75 .. !,',~ '" .. , ,. , ' ", " " , . ': "'¡':'!"",' ,: ' ,.',,' ' , " , "." .' ,', ' TI~AbQl6ATrON PRü':"EDUí:E8 UðE " LIÞJEf\R' INT£Rr'OLnTIGN-B~+WE-E-N-----':"'--,-----_..__......._------------- lHE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS '. ~ \ ~ ' 'I ,. :: . \ ,'.' ~ ~, ,," ", ,,: ': ,~ :': ;:; i::'\ ~\'. ' :. :~<~>:,;~ ~:~':;~¡;;:: :~:;;r; :~" t '<;i..~::.::':;\::,;: ~, :. ' -------...,---.,.-...,....--.......--.--..-.....---- .......-,-..-..... ,--,--- .-..--,-...- , " .. ~';':",.~"'~" I ,"~' 1", ,¡, '.. : ",: ~ : '" , ~.' . ,,' I ~ I .' I 'I. .. , " , : '\' , . . '~', I " .. . .~, ' , , ' .. , . , , ... ,.~'., ,.' I ,'" i, ~ ,. . " , . ", " , , j ------ ... r-::----, __, , ~:~':, '.? ,:::',:t:~:~~z,: ,\:;\;;i:'~'~~ ;~i ::\'}P , :::::' ~,~" " :::,(: :~,:;!:".: \':: :~.:;':/'\" :~f ',; ,~:?Tj~:~'~'~\;"'-i,:j: ;-::-'7T7~~ ,:, ' ,'~>~'::..: ,;:,:~::, ':, ' . , :. . ~ ...~... ..",,:,'1;' --"IIII~~-"""'''_I.~----'8I'-......-..,..,..--...,r---.::r~''''''''''-''''''~'''''.'''''''''''~-IIIIJ.'''''.--.''''''''''''-~ .--..-.----..-.....-,............,- - Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 October 27, 1982 Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Gyroscopic Survey - Milne Point BNo. 4~ Dear Sir: Two copies of the subjeci~~ survey are attached as they were inadvertently omitted from the Well Completion and Log Report. Sincerely, W. M. Haskell Administrative Coordinator tt- Conoco Inc. Our Boss Gyroscopic Survey Job No.: Boss-16087 Well: B-4A MPU (SEC19 T13N RllE) Kuparuk River Field North Slope, Alaska Survey Date: July 16, 1982 Operator: Samec/Juul Scale: 1" = 2000' 0.(20 2000. O0 4000. O0 6000. O0 8000. O0 i 4852.96' @ S74° 19'W 49500 I 2000.00 40bO. O0 6000.00 VER T I Cf:IL PROJE C T I ON Conoco Inc. Our Boss GyroscOPic Survey Job No.: Boss-16087 Well: B-4A MPU (SEC19 T13N RllE) Kuparuk River Field North Slope, Alaska Survey E~te: July 16, 1982 Operator: Samec/Juul Scale: 1" = 1000' 1 -5000. O0 -~ooo. oo -~o~o. oo ~ h° - 9,~ HOR!ZONT~L TRUE NOHTH --lOQO. O0 -2000. O0 PROJE C T I ON (' \~' Suggested foxm to be inserted in ea,ch "Active" well folder to check for timely compliance with our regulations. ~ht1CO IYIdAœ ~/~ f ß-tl/J O~rator, WêllNaræ and Number. - . Reports and Materials to be received by: ~ - ;;¿l-f:~ Date REquired Date Received . Remarks Canpletion Rep::>rt Yes '1-/3-g;)... . , Well Histo:ry Yes _Samples Mud Log ...-- ~ ò (J - ~ COre. Chips es ... d-?~ 0 0 (); Inclinat.ion .. Survey () l~ /' prillSt§fu .. TgSt;. Repbî'ts Þrcx:1\lroonTest Rep::>rts Yes Digitized Data \es t-€~ 1- /3--- f=f 7-/'3'- ~7~ . . P, f? ¡ì(eT-eV August 9, 1982 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 Alaska Oil & Gas Conservation Commission 3001 Porcupine Anchorage, Alaska 99501 Attention- Lonnie Smith Attached is the Monthly Report of Operations for Milne Point B No 4A for the month of July 1982. W. M. Haskell Admi nstrati ve Coordinator tt cc' WIO's - all w/attachments E. L. Oshlo - w/attachments AL~.ck~ Oil & ~ Cons. C°i~n~i~Sion ~nchoraga · ----- STATE OF ALASKA ...-.. ALASKA L _ AND GAS CONSERVATION CC ,'IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~[X Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 82-100 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 5o-029-20748-01 4. Location of Well at surface 165' FNL, 1158' FWL, Sec. 19, T13N, R11E, U.M. 9. Unit or Lease Name Milne Point Unit 10. Well No. Milne Point B-4A 11. Field and Pool Kuparuk River Field Kuparuk River Pool For the Month of July ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth- 9500' MD. Two plugs were used to side track & kick-off when insufficient angle was obtained on the first side track attempt from B-4. First plug 3215' - 2774' w/300 sks. Class G. Second plug 3136' - 2785' w/250 sks. Class' G. 13. Casing or liner run and quantities of cement, results of pressure tests Si ze Wt. Type From -To 7" 29# L-80 BTRS Surface 9476' Tbg. 3½" 9.3# DSS-HT S'urface 8830' Cement 1st stage-lO00 sks. Class G 2nd stage-300 sks. Permafrost C 300 bbls. 9.6 ppg Arctic Pack in 7" X 13 3/8" annulus. 14. Coring resume and brief description NONE 15. Logs run and depth where run LOGS SP-DIL-SFL-GR NGT-CNL-FDC-GR Dipmeter & Sidewall Cores From To 9476' 2297' LOGS CBL-VDL-CCL-GR CBL-VDL-CCL-GR CCL-GR From To 9365' 6100' 9362' 6300' 9100' 8800' 6. DST data, perforating data, shows of H2S, miscellaneous data SPF From To 4 9182' 9184' Squeezed w/200 sks. Class G - didn't hold. Re-squeezed w/150 sks. Class G - OK. Prod. Perfs 12 SPF 8960' - 8990' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED -'~~'~~-/ '~ '~~" TITLE Drilling Supervisor DATE August 6, 1982 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 July 19, 1982 Lonnie Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r' '.Subject' Completion Reports, Milne Point Unit Well .Nos. B-3, C-3, B-4. Montly Report of Operations -. Nilne Point B No. 4A- The subject reports are attached. If you have any questions, please contact Gary Merriman at 279-0611. Yours very truly, W. M. Haskell Administrative Coordinator SHB/kp Attachment cc: Mr. E. A. Blair, Hamilton International, Denver, w/Attachments Mr. D. S. Motazedi, Champlin, Long Beach, w/Attachments Mr. Bryan D. Humphries, Cities, Houston, w/Attachments Mr. Glenn E. Wood, Reading & Bates, Tulsa, w/Attachments Mr. John W. Walker, Chevron, Concord, w/Attachments -Mr. Robert T. Anderson, Union, Anchorage, w/Attachments Mr. T. J. Jovin, Phillips, Denver, w/B-4A only Mr. L. B. Agers, Mobil, Denver, w/B-4A only Mr. L. A. Dinges, Offshore Expl., Adm., Houston, w/Attachments - .~-. STATE OF ALASKA ~-. ' ~;.~ " ALASKA ~ ' AND GAS CONSERVATION CC '~vIlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well X]X Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 82-100 3. Address 8. APl Number 2525 C Street, Suite 100 Anch0rage, AK 99503 50-029_20748_01 4. Location of Well at surface 165' FNL, 1158' FWL, Sec. 19, T13N, RILE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation ~'ndSer--'-~lq~o. 59' KB I ADL 47437 9. Unit or Lease Name Milne Point Unit 10. Well No. Milne Point B No. 4A 11. Field and Pool Kuparuk River Field Kuparuk River Pool For the Month of June ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth on 6/30 - 4254'. This well is a sidetrack to Milne Point B No. 4. operations began on June 26, 1982. Significant 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 6. DST data, perforating data, shows of H2S, miscellaneous data J U L 2 1 i982 Oil & Gas Cons. Commis~io~ Anchorag~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED/_~¥~-~~' TITLE/., '. Sup, Erlgi neer DATE ~///~,~//~ NOTE--F~p°rt orl/this form is required for each calendar mOnth, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Form 10-404 ~ Submit in duplicate Conoco Inc, 2525 C Street Suite 100 Anchorage, Al<: 99503 July 14, 1982 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re- Milne Point B-4A, Permit #82-100 Dear Mr. Chatterton- Enclosed are the original and two copies of a Sundry Notice showing Conoco'-s plans concerning the completion of Milne Point B-4A. If you have any questions on this matter, please contact either Don Girdler or me at 279-0611. Yours very truly, Gary A. Merriman Supervising Production Engineer tt cc' Corrsepondence file - MP #B-4A RECEIVED j U L I ~ i982 Alaska Oil & Gas Cons. Commission Anchorage ~'"' STATE OF ALASKA ALASKA ,.,iL AND GAS CONSERVATION CL.,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I~ COMPLETED WELL [] OTHER [] 2. Name of Operator 3. Address 4. Location of Well 165' FNL, 1158' FWL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) '59' KB 7. Permit No. Conoco Inc. . ~ ~ 82-100 ~ ;r"'~.,,~ I e. AP' Number 2525 C Street, Suite 100, Anchorage~Ala~a 5o-029-20748-01 . Y~ %~. I 9. Unit or Lease Name ~ Milne Point Unit ~9, T~3N, R~E, UN. ~ ~' ~0. WellNumber ~ ~. ~ B-4A ~9 '~ 11. Field and Pool ~-' Kuparuk Ri ver 6. Lease Designation and Serial No. ~, ADL 47437 $ 12. (Submit in Triplicate) Perforate X[~ Alter Casing [] ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The B-4A well is to be completed as a single oil well in the Hiddle Kuparuk sand. A Vann gun will be run so that the rig can be skidded before perforating. Once the rig is moved we will perforate then flow test the sand. Work should begin about the 16th of July. Proposed procedure: 1. After running cased hole logs, TIH w/6½" mill and clean out wellbore to PBTD (9420'+) (TD=9500') 2. Displace the drilling mud with fresh water. POOH 3. RU and TIH with the temporary completion string including a Vann gun for perforating. 4. Run a GR/CCL to position the packer at 8870'+. Displace the well with diesel. 5. Install the tubing hanger and land the 3½" tubing. Install BPV. NU and test the tre Rig down and move the rig to the B-3 well. 6. Rig up the testing unit and tie-in the flow line to the wing of the B-4A tree. 7. Detonate the Vann gun to perforate the Middle Kuparuk sand from 8960' - 8990' (30') After perforating release the guns using pressure actuated tubing release. 8. Test the B-4A well using a surface read-out pressure/temperature gauge (H.P.). Tes' as follows: A. 10 minute initial flow o__~_~ .... B. 100 minute initial shut-in C. 6 hour stabilized flow o~_-_~-,~:~. ~.,.~_.c~-~ ' D. 24 hour final shut-in -.. --OVER-- 14. I hereby ce, r, tify that the foregoing is true and correct to the best of my knowledge. Signed .~ ~ Title Supervising Production Enginee6~ate 7-14-82 The sp~ below f~'r Commission use Conditions of Approval, if any: Approved by Form 10~103 Rev. 7-1-80 Approved Copy Returned COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 9. Shut-in the well and install a positive plug in the tubing just below the packer (@ 8905'+). Bleed-off tubing pressure then install a BPV. Rig down. MILNE POINT WELL B-~A WELL BORE SKETCH CON DENTIAL lo o o -~ I ITeM DESCRIPTION LENGTH MIN. MAX. ! i ID , ' OD J 3~", 9.31riFt, N-80 DSS-HT Tubing I 2.992' 3.875" --- ' ........... /2 81~ ..... l__i_0~IS_'_'_xf~'' Nipples_~ _ 0.9' l~ : 3.875". 2 { 3½" BTRC Pin x 3¥' DSS-HT Box x-o ~ '0.5" !12'992" 3.90" 3--~, Baker Packer Bore Recepticle 26.58' 12.81" 5.75" 4J! Baker "FHL" Packer ! 4.57' i3.25" 5.687" ! 6 ! 4½" LT & C Box x 3~" BTRC Pin x-o 0.7' i2.992" 4.75" ........................ i ..... t 90" 7 ~i 3½" 9.3tt BTRC Tubing ' 31.0 ........ i_2_~.992" 3. 8._._.] 3½" EUE 8RD Pin x 3½" BTRC Box.x-o 0.5'', ! 2.9_9_2" 3.90" 9 i ~" 3 ~5 Mechanical Tubing Release 1.40' ! 2.75" .5" __~_ E. UE__ ...... s__u~ .............. ' 4.0' .12-992" 3.90" 12 On~ Way Vent Assembly , 1.3' j 3.5" 13 3¥' EUE Box x 2 3/8" EUE 8RDpinx-o 0.5' 1.995" ' 3.90" I 14 Kobe Bar Actuated Production Vent 1.7' 2.70" I__.,.15 -%--~/8" -L 7#, 8~ :~';~:~- .......... : 30' i~.995" 2.7o" EUE 16 No-Go w/Firing Head Extension i 8.0'~ 1.56" 2.70" Mechanical Firing Head ~ 1.65' ~:0" 3.37" ~ ,, - --: .... Z'~--{' ......... : ........ ~:' ....... 5 o" _18 i 5 Perforation Gu at 2 SPF ~ · ............... ~ 0.5' '0" 5.0" Completion Fluid: Rig Water Packer Fluid: Diesel Minim6m Restriction: OTIS Nipple (2.75" ID) @ 7310' Maximum OD: Packer Bore Recepticle (5.75" OD) 'Casing: 7", 29f~/Ft, L-80 BTRC (6.75" Drift) .JUL i ~ J982 Alaska Oil & Gas Con , s. Commission ~Chorago H. D. Haley Manager of Alaskan Operations July 2, 1982 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 RE: MILNE POINT B-4A, PERMIT NO.80-100 Dear Mr. Chatterton: Milne Point B-4A was intended to be a highly deviated redrill of Well B-4 to the northwest portion of section 24, T13N, RilE, UM. The directional plan included kicking the well in a S70°W direction and building hole angle at 2½°/100' to a maximum hole angle of 51°, however we have encountered problems in building and holding angle and at 4300' MD the well is 15±° below the angle required by our directional plan. At this depth a 60±° hole angle would be necessary to reach our location objective assuming that additional directional problems are not encountered. This letter serves as notification that a cement plug has been set in Well B-4A at a depth of 2800±', with the intention of using this plug to abandon the hole below 2800' and to kickoff the well to the location objective described in the Well B-4A permit to drill. If you have any questions on this matter, please call Don Girdler 279-0611. ' ............. Very truly yours, G. A. Merriman Supervising Production Engineer kr cc: T. S. Lucht, Anchorage D. R. Girdler, Anchorage L. A. Dinges, Offshore Explor, Houston Well B-4A File RECEIVED JUL- 1982 Alaska 0il & Gas Cons. C0mmj~j0r~ Anc,~mra.~e June 25, 1982 ~.;r, Gary A. ~{erriman Supervt sing Engineer 2525 C Street, Suite I00 Anchorage, Alaska 99503 Re: ~ilne Point Unit B-4A Conoco Inc. Per~_it No. 82-100 Sur. Loc. 165'FNL, 1158'F~/~, Bec 19, T13N, RIlE, ~. Bt~hole Loc. 1862'FNL, 3§58'FEL, Sec 24, T13N, Dear ~r. ~erriman:' Enclosed ia the approved application for pe~it to drill the above referenced wel I. Well sa~-.ples and a mud log are not required. A continuous di~ectionai survey is required a~ per 20 AAC 25.050(b)(5). .If available, a tape containing the digitized log tnfomuation ~hall be submitted on all logs for copying except e~cperin~ental logs, velocity ~arveys and dieter ~urveys. ~any ~iVers in Alaska and their drainage systems have been classified as i~portant for the ~pawning or migration of ~anadr~oU~ fish. Operations in these areas are ~ubjeet to AS 16.~5.$76 and the re~utati~ns promulgated thereunder (Title 5, AIa~ka'Ad~iniatratiYe Code). Prior to c~rnraencinc operation~ you m~y be contacted by the Habitat .Coordinator's Office, Department of Fish and ~ar~xe. Pollution of any ~aters of the ~tate ia prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal ~ater Pollution Control Act, a~ amended, Prior to e~mncing operation~ you may be contacted'by a representative ~f the Department of Environn}entaI Conservation. Mr. Gary A. Merri.,an Milne Point Unit -2- June 25, 1982' To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is s~dded. We would also like to be notified so that a representative of the C~ission-may bo present to witness testing of blowout preventer equipment before surface easing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a wi tness present. Very truly yours, C. V. Chatterton Chai m~an of Alaska Oil and'~PF~~~~~~!on Bric 1 o sure cc= Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC: be Conoco Inc. 2525 C Street Suite 100 Anchorage, Al<: 99503 June 21, 1982 Mr. C. 'V. Chatterton, Chairman Alaska Oil & Gas Conservation Conmission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill application for Milne Point B-4A. This well will be a redrill of ~51ne Point B-4 to a new bottomhole location. Also, attached to this letter is a check for $100 to fulfill the permitting fee requirement. If you have any questions, please call either Don Girdler or me at 279-0611. Sincerely, Supervising Engineer tt Alaska Oil & Gas Cons. Commission Anchorage ?" STATE OF ALASKA ALASKA ~.,~ AND GAS CONSERVATION CO,.,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~[] MULTIPLE ZONE [] 2. Name of operator Conoco Inc. 3. Address 2525 "C" Street, Suite 100, Anchorage, Alaska 99503 4. Location of well at surface 165' FNL, 1158' FWL, Sec. 19, T13N, RllE, UM At top of proposed producing interval ! ,~ ~ 1650' FNL, 2970' FEL, Sec. 24, T13N, Ri~IE, UM At total depth ! ~ ~' 1862' FNL, 3558' FEL, Sec. 24, T13N, Ri'I~E, UM 5. Elevation in feet (indicate KB, DF etc.) 59'-K.B. 6. Lease designation and serial no. ADL 47437 9. Unit or lease name Milne Point 10. Well number B-4A 11. Field and pool Kuparuk River Field Kuparuk River Pool 12. Bond information (see 20 AAC 25.025) Type Blanket surety and/or number 8086-- 15--54 Amount $200,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line Deadhorse, Southeast miles 1158 feet 16. Proposed depth (MD & TVD) 9670' MD & 7410' TVD feet 17. Number of acres in lease 2560 Acres 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2300 feet. MAXIMUM HOLE ANGLE 51 O l (see 20 AAC 25.035 (c) (2) I15. Distance to nearest drilling or completed B-3 we. 120 feet 18. Approximate spud date June 23, 1982 1400 psig@ 0 ~ Surface 4000 ,.psig@ 7410 ft. TD (TVD~ 21 Proposed Casing, Liner and Cementing Program Weight I 30" 94 17~" 2 72 29 22. Describe proposed program: SIZE Hole Casing 20" 13-3/8" 7" :ASING AND LINER Grade / Coupling ?lain-e~dLine~ L-80 ~ Butt L-80 / Butt Length ipe80' 2300' SETTING DEPTH MD TOP TVD 0 ~ 0 0 , 0 MD BOTTOM TVD 80' ~ 80' * 2300,' 12300' 9670' 17410' QUANTITY OF CEMENT (include stage data} In place In place 575 Ft (2000 ' Fill- Znd State: 1500 Ft See the attached supplemental data sheet, proposed surface and bottom hole location plat, and BOP sketches. NOTE: This well is a redrill of Milne Point Bz4. Milne Point B-4 has been plugged back to the base of the 13-3/8" surface pipe. ~i~iV~i)~?.,~.~ jUN 2 ~a.~'.',~.~,~=~_,~ 0il & Gss Cons. C0iTlrrlis~;i0[i, from ground level. 23. I hereby certi¢~ that the foregoing is true and corr~t to the best ~f my knowledge SIGNED , TITLE Supervis~g Eng~eer lhe spac}below fo~¢~mmission ~se DAT~Une 21, 1982 CONDITIONS OF APPROVAL Samples required I--~YES ~NO i Mud log required I Approval date 82-10.9'~ ~.~ .~/06'j~2 / i Directional Survey required ] APl number eYES •NO 50- 029-20748-01 SEE COVER LETTER FOR OTHER REQUIREMENTS Permit number APPROVED BY Form 10-401 ,COMMISSl ONER DATE by order of the Commission June 25, 1982/ Submit in triplicate SUPPLEMENTAL DATA SHEET FOR APPLICATION FOR PERMIT TO DRILL Conoco et. al. Milne Point No. B-4A Conoco Inc. 2525 "C" Street - Suite 100 Anchorage, Alaska 99503 I. CEMENTING PROGRAM IN PLACE: A. The 20" conductor was pre-set and cemented to the surface with permafrost cement. B. The 13 3/8" surface pipe was cemented at 2300' with 3600 sxs of permafrost cement mixed at 15.0 ppg. Cement returns were at the surface after pumping 2800 sxs. PROPOSED: A. The 7" production casing will be cemented in two stages. The primary cementing job will consist of 500± sacks of class "G" -cement pumped around the casing shoe (estimated 2000'± of annular cement, assuming an AHS=10"). The secondary cement job will consist of 200± BBL of Arctic pack cement followed by 300± sacks of permafrost _type "C" cement. The second stage will be pumped through a DV collar at 2100'± and will fill the 7" x 13 3/8" annulus. II. ANTICIPATED GEOLOGY 0-4500' Surface conglomerates, silt and sand sequences. Estimated based of permafrost at 1700'±. 4500 ' -TD Predominantly shale Until the .Kuparuk sands - expected at 6900'+. : III. FOR>rATION EVALUATION A. Standard mud logging equipment to be used. B. Wireline logs for the 8~"~ hole from T.D. to the 13 3/8" shoe will include: Dual induction laterolog; borehole compensated sonic-gamma ray; formation compensated density with CNL and GR0-caliper. IV. DRILLING FLUIDS 0-2300': A high viscosity gel-fresh water, (dispersed) system. 2300'-6000'±: Low solids non-dispersed gel/water mud syste~ 6000'-TD: Lignosulfonate mud system. PAD B SECTION 18 E~ 19, JUN 2 i9 A!3si¢. 0il & Gas Cons, ' Anchorage TI~N,, RIlE UMIAT MERIDIAN I PLANE COORDINATES STATE WELL ~ .ORTMING$ :. EASTIN;$ I i· ; 022 gli.70 j B72 05B.98 2 ; 5 02~ 121.76 : 571 989.77 '3 j 6 023 077.00 : D72 209.10 4 ; 6 022 960.76 : ~72 239.11 ~ ZON~ 4 · ; ....... J ......................'.............. GEODETIC POSITIONS e...---- .---o o------ · - ....... ----~j - ...... o o I~E1.L ; LATITUOE ...L..LONGITUDE ---'''''',''''''''''''''' ''' I -~ 70028. 22.~67' _: 149024'41.17'6' 2 i 7'0o28e 24.439' : 149°24'4~.151' ~ : 70° 28' 23.97'8" :, 149024':~6.714' 4. :' TO° 28' 22.82,2" · ! ! ' ; , CERTIFICATE OF SURVEYOR: ! HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA ~O THAT --- ' THIS PLAT- REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND SURVEYED R: FIELD ~K 3340 Arctic Boulevard, Suite 201. Anchorage, Alaska 99503 S~LE I '= 2~' ('7. x~ ~ o P ~-'T'Acl< J .. I jUN 2, i I CHOKE & KILL MANIFOLDS FOR 11 15~I~'& q OD CASING BOP STACK ~ ~Ro~ ~UD PU~ KILL MANIFOLD r ~ ~ssu~ Pu~ ~ ~ DRILLING SPOOL ~ HTOR~ULIC CONTROLLED - - REMOTE --- ... ~ ~~~ - ~ ;J k ; - ' I I ~!i il ~ I I -- ~fO ~fl~O~~[~1~ V Hydraulic 1 rc~otcly ~-ith 5COO psi Accu--.utator ~ 160 gaL: Rc..rrvo~r [ Auxi I iar~' En~r;y Source. ' ..~n Id plu~ variable Choke Con,roi to b,r locnteC on a~C ricer. Cla~s 55~ BOP :,;-'~;IFOLD LAYOUT CO;:OCO, l::C. CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE thru 8) ~(:9/ thru 11) (4) Casg~ 'thru 20) 1 (5) ~/(21 thr~ 24) I · · 3. 4. 5. 6. 7. 8. 9· · 3 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO Is the pemnit fee attached .......................................... ~__~__ Is well to be located in a defined pool ....................... .. · Is well located proper distance from property line ......... Is well located proper distance from other wells .......... Is sufficient .undedicated acreage available in this pool .. . Is well to be deviated and is well bore plat included ......... Is operator the only affected party ......................... Can permit be approved before ten-day wait ............ - ........ Does operator have a bond in force .................................. Is a conservation order needed ............................... Is administrative approval needed ..................................... Is conductor string provided ..................................... ...~~_~ Is enough cement used to circulate on conductor and surface ...... -- Will cement tie in surface and intermediate or production stringsii'' "~ Will cement cover all known productive horizons .................. Will sUrface casing protect fresh water zones .................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ..... , ...... Is old wellbore abandonment procedure included on 10-403 ...... ~.. Is adequate well bore separation proposed ......................... Is a diverter system required ...................................... Are necessary diagrams of diverter and BOP equipment attached ...... Does BOPE have sufficient pressure rating -Test to ~dp~~ .p 1.~~ .... Does ~he choke manifold comply w/API RP-53 (Feb.78).[[~.[[[[[ ~.g Additional requirements ,, Additional Remarks: REMARKS Geology: Engineering HWK LCS BEW~ 'WV~ J KT:, ;~~AD / rev: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 113~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. bis TAPE VERIFICATION LISTING LVP OIO.HO! V?,RIFICATION 'LISTING PAGE ** RE,.~L HEADER ~* SER¥ICE ~A, ME, :SER lC : DATE :82/07/22 PREVIOUS REEL CONM~NTS .R:E~b COMMENTS : SERVIC ORIGIN :107,0 TAPE NAM:E :65316 CONTINUATION ~ :0! PREVIOUS TAPE : CO MENTS :TAP COMME, N~$., ** FILE: HEADER:** FILE NAME: .S~sRV.IC,O01~ ~ SERVICE NA~E :: : MAXIMU~ LENGTH : 102,4 FILE TYPE : ~REVIOUS FILE : ** INFORMATION RECORDS MNEM CONTENTS CN : CONOCO INC, ~N : B-4 .A FN : KUPARUK ~ANG: 1! E TOWN: 13 N SECT: 19 COON: NORTH SLOPE STAT: ALASKA CTRY: MNEM CONTENTS PRES: DILOO1F ** RECORD TYPE 047 UNIT UNIT TYPE 000 000 000 000 000 000 000 000 000 TYPE 000 CATE 000 000 000 000 000 000 000 000 000 CATE 00o IZE 012 O06 0O8 OO4 O04 OO2 012 OO6 OO6 SIZE OO7 CODE O65 O65 065 O65 065 O65 065 O65 O65 CODE 065 LVP 010 }~01 V~sR.~PICATIO LISTING PAGE : ~:RECORD ,TYPE 047 COMPANY STATE ~ NORTH :S50P'E BOROtlG}~ JOB NUMBER ..... C ACC, 10707,6'5:316 RUN ~1, DATE L.]GGED: 13 JULY 9~ BOTTOM TOP DEPTM~1 TYPE ~LUID = LOW SOLIDS DENSITY = 10,4 LB/G VISCOSITY = 39"S ============== PAGE REPR CODE 166 ENTRI 73 60 65 .lin DATUM SPECIBIL, ATION },LOCKS ~ MNE~ SERVICE SER¥!CE 'UMIT AP~I API~FIbE SIZE D~~PT ID DRD~,R ~ LOG TYPE CLASS MOD NO. FT ~ 0 O:: 0 0 0 SFLUDIb ILO IbM OIL () SP OIL 'MV' 7 GR DIL~ DT BHC NCNb FDN NPHI F'DN RHOB FDN DRHO FDN CALI FDN SGR FDN NCNb FDN FCNL FDN NRAT FDN CGR NGT SGR NGT TMO~ NGT o oo 0 0 0 0 0 0 GAPI 7 3 ! 32 0 0 US/F 60 52 32 0 0 42 34 92 0 0 PU 42 68 2 0 0 G/C3 42 35 I 0 0 G/C3 42 44 0 0 0 IN 42 2~ 3 0 0 GAPI 42 0 0 0 0 42 34 92 0 0 42 34 93 0 0 42 42 1. 0 0 (;APl 0 0 0 0 0 GAPI 0 0 0 0 0 PP~ 0 0 0 0 0 PROCESS SAMPLE REPR LEVEL CODE 4 0 1 68 4 0 1 68 4 0 I 6~ 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 6B 4 0 1 65 4 0 1 68 4 0 1 65 4 0 1 6B 4 0 1 68 : : PU ,0 0 0 : 0 4 PP~ :: O: 0 0 0 0 4 GR BHC : 60 31 32 0 0 4 68 6~ 68, SP L-5:7.5'625 : G:R 1666.,000:0 ::DT 9.2,:0000 NPHi - '9991<~2500 '999,250'0 SGR ' ~ 99i9,2~00:::: NCNI~.: ~9:99~2500 :F:CN[ '999,2~00 CGR ~999,2500 SGR -999.~500THOR: -999.2500 GR 1666,:0000 NCNb POT!A 8P 46'31::25 GR' 166:6, "0 DT 92:,0:00~ NCNI. 8~R:NPH'I -999;2500 '999,2500 MCNL:' RHOB : : .:999..25:00: DRH:O 999,2500 .~500 ::F'CNL' -999.2:500 CGR :999.2500 .... SGP. : '999~:.25.00 THO~ -999.2:500 URAN 99:9~ 2500 ~ t666.0000 DEPT. 400,0000 SFLU SP -3~,:3.438 :~7,~750 DT 104,5625 N~I 46,7285 ~HOB : ~:~ :2,3:4~57 DR~O 0.00:78 SGR . 111 ,:50'00 NC~h 16:89,0000 FCNL CGR 83,1875 S~ U~AN 3.6895:: GR : 87,8750 : DEPT SP NPHI CGR DEPT SP NPHI URAN DEPT NPHI CGR U~.AN 29, 56, 2, 9200. 2 7~. 2. 9100, -40, 31, 84, 66, 9000. -2'3. 27. 90. 7~. CA5I NRAT POTA IL~ NCNb CALI NRAT POTA 000) SFLU 6 1172 ILD 0137 1562 .,,R 5:9.5'00:0 DT 9:5625 NCNb 32~6 RHOB 2,2 22 DRHO ,0498 NRAT 5898 NCNL 2578.7500 FCNL 86 ,0105 CALI 5557 SG~ 68. 5000 THOR 9.3359 PC)TA 1250 G~ 67.1094 0000 SFLU 4.6484 ILD 3.5703 5938 GR 78.6250 DT 87.0000 NCNb 5156 RHOB 2.4082 DRHO 0.0127 CALI 0996 NCNb 2308.0000 FCNL 778.0000 NRAT 1504 SGR 84.3125 THOR 10.7749 POTA 8638 GR 84,5625 0000 SFLU 7.2930 iBD 6.8672 ILM 343~ GR 75.1250 DT 92.3750 NCNb 4440 RHOB 2,3439 DRHO -0.0058 CALI 3~47 NCNL 26~3.6250 FCNL 796.~250 NRAT 3428 SGR 84,2500 THU~ 10,1299 POTA ~393 GR 75.I~50 0000 SFLU 6,9141 3125 GR 78.1250 DT 88.5625 NCNB 4263. RHOB 2.3948 DRHO 0.0078 CALl 8027 NCNL 2524.7500 FCNL 885,3047 NRAT 8594 SCR 89.4375 THOR 10.5684 POTA SP NPHI CGR 2.1797 .9992.1797 ,2500 '999,2500 -999:.25:00 -999.2500 2,3496 1689,0000 10i2266 ,8203 .7344 3.3457 2578.7500 8,~367 2. 733 1.5087 3.9746 2308.0000 10,0391 2,767S 2,1387 8.8320 2613.6250 8.8281 2.8632 1.8864 6.0547 2524.7500 9,2352 2.6287 2.2900 URAN D~IPT SP NPHI CGR URAN D'EPT SP NPH! ~U.RAN DEPT ' 8700 NPHI SGR 'i ~ , . '~I ~ 6328 :8~00 0000 $~LJ : 4,6914 I. LD 4~.593P G~ 7'4.0625DT' 7i .0000' NCNL 30,64:58: RHOB: : : :: :2,6:195 DRHO :0,0348 CALI 191:0,:3::750 FCN[, 56:.~'7813 NRAT 62,50.00 :$GR : 108,4375 :THOR 8.5234 POTA 3,:2656 74':06~5: 8800'0:000<'::::~:FI,U: 3.3906 I,LD 3.0~17 "sN G:R: ~ : :: 7~,0625 7~,3594 NC L 2.41:7:7 DRHO .019:5 C~LI: 999.00:00 598.6875 1:1:3:25625 TH:OR Ii-8906 POTA ,1,t5:1:2 2207: .RHOB : :2:,2793 D~H£ : 0 0,:176 CALI '93.75 'NCNiL: 167:0:'~0:00 FCNL 359 2500 NRAT ,2500 ..:$GR:: ~1:8 9375 :~0~. ~3.0313 ,6:016:G~ D EPT 8:~ 0 0 URAN 5 SP NPHI 43 ~GR 160 CGH 109 URAN 6 DEPT 8400 P -49 PHI 27 SGR 257 CGR 103 URAN 22 DEPT SP NPHI U~AN 83OO -65 41 139 103 4 8200 -73 41 D~PT SP NPHI ,0000 ::SFL[I 2,1,816: ILD ,5625: GR 11,5.25:00: DT ,7:305 'eHOB '2'3:027 DRHO 0000 .343~ SFLU . GR 134'3750 DT .8965 RHOS 2.3223 DRHO .3750 NCNb 1793.0000 FCNL .3750 SGR 160,3750 THOR .6328 GR 1~5.7@13 .0000 SFLU 4,0352 ILD ,0625 GR ~91.2500 DT .6855 RHOD 2.7441 DRH[) .0000 NCNL $250.0000 FCNL .6875 SG~ 274.7500 THOR ,28i3 GR 249,0938 .0000 SFLU 2.8281 ILD .1250 G~ 116'9375 DT .5039 RHOB 2.3906 DRHO 0000 NCNL 1923.0000 FCNL .3125 SGR 137,1~50 THOR .4023 GR 116,9375 .0000 SFLU 3.1602 ILD .3750 GR 127.5625 DT .9434 RHOB 2.4023 DRHO . 77o li[:oooo '0068 CALl 38.4,,7500 NRAT 12.4927 POmA ' 0547 IbM 0,0~51 CALl 441 . 5000 NRAT 14.6250 POTA 2.3516 ILM 76.7969 NCNL 0.0195 CALl 786.0000 NRAT ~9.9531 POTA 2.7793 IbM 106.1875 NCNb 0.0132 CALl 471.7500 NRAT 12.9844 POTA 3.033.9., 103.0000 0.0083 I L M NCNL CALI 2,666,0 1910 ' 3750 .9668 2.0996 2910 ,0000 6 8 5 4 0837 ,8320 1,3398 o: oooo 1~.,1797 0664 2.7832 2.3008 1664;0000 I0,2578 3.9355 ~.6779 2.9805 1793.0000 9,7109 3,6230 3.5156 2.3750 2250 0000 lo:ols6 2.7090 1.9531 2,6758 1923.0000 11.5391 3,5918 3.3691 2.9238 1807.0000 11.0000 BVP 010,HO1 VERIF:ICATION LISTING PAGF.. 6 SGR 1,,.2.0000, NC, Nb CGR 101 · 6975 SG'R URAN 5.2461 GR DEPT SP 8100.0000 8:FLU '43.0:938 NP:HI: 1B01,0000 ECNL ~ 490,2500 NRAT 142.0000 THOR 13,3281 POTA : 127.56:25. 38,9!09...:RM0:5 . i73:'1406 NCN[! 191:6~i:0I:6FCNL '3 101,:2 1:4 SGR !7~9..B7:5:0 THOR 10.2761 OR 14:4'984:4 ~009.0000 . SFLU DEPT NPHI URAN ,spDEP:T 7~ N~P~ I : :41: SG ! 27 DEPT 7800 SP '4:9 NPHI 35 SG~ 119 CGR 89 URAN 3 DEPT 7700 SP -46 NPHI 32 SGR 125 CGR 92 U~AN 3 DEPT 7600 SP -49 NPHI 34 SGR 109 CGR 88 URAN 3 DEPT 7500 SP -56 NP~I 34 GR 73 ~AN 2 2.3906 ILD 1:0~,~62:5: :D:T 1.8662 9~:,8516 NCNb ,:0654 CALI :650:..O000 NRAT 16,0313 :POTA U.0000 ::$FL .... :2.9117 ILD · 0625 eR I~0,~31:2SDT ' 500:0' FCN:L .2676 $:G:E: : 127,9375 THDR .O000SFL[1 2.6602 ILD ,62:5~. GR: 10~,4375 DT · 71:32:! RHO~ 2'4318 !!DRHO ,843~ NCNB 2126,8750 F:CNL ,81'25 S~R 117.1'875 T:MO:R .5566 GR 110.5625 .0000 SFLU 2,9531 ILD .8750 GR 95,7500 DT .8957 RHOB 2.3989 DRHO .914~ NCNb 2214.3750 FCNL .5000 SG~ 120.7500 THOR ,67~9 GR 95.7500 .0000 SFLU 2.6523 ILD 3438 GR 95.0000 DT :7229 RHOB 2,4~81 D~HO ,8926 NCNb 2133.1875 FCNL .0000 SGR 113.2500 THOR .2532 GR 90.6631 7400 DEPT .0000 SFLU 2.3945 ILD ,.0625 GR 83.5000 DT .1797 RHOB 2.3496 DRHO .g375 NCNb 2124 0000 FCN'L ,0000 SGP 9I:9375 THOR .4590 GR 92,7617 .0000 SF!,U 3.9375 ILO 1562IL' 3799 :NC~L 016.3 CALI 9687 NRAT 0762 POTA 2.94'13 IbM 9~,0000 NCNB '.02:56 CALl 579,2500 NRAT ~2.9062 POTA 3.2539 I.b~ 96.1875 NCNb 0,0078 CALI 660.1484 NRAT 11.8750 POTA 3.0078 IbM 97.2432 NCNb 0.0320 CALI 629,0498 NRAT 11.9141 POTA 2,7266 IbM 94.2617 NCNb 0,0137 C&LI 623,5000 NRAT 9.5938 POTA 3,5273 , .6016 ~.3203 1. 6084 22849 .0000 '6953 ,3418 11,2465 3;6034 2.3945 2. 8574 9531 3,2826 2'5879 3.1777 2214.3750 1 8093 311432 3. 0273 2.8594 2133,1875 11,9897 3.2303 2.8809 2.5918 2124.0000 10,6172 3.1562 2.3926 3,6172 LVP 010.H01 iVERIFiCA:TIOM'i:LISTING PAGE 7 SG~ - " T 3.0000 NCNb 51.,34:38GR :67.4375 D. 8 2:8,0:426:: RM:OE 2,:4.0:79:: ~D:RMD 0.01. i7 CALI 4' ~ * 2.12 T 2.:4:094 G:~ 7~00.0000: :SFLU 7:~:.734:4 .SG~ 1,6i592: G'~ ,3750:DT 2,3.67.:6. DRHO 2449.250'O'::FCNb 9:1,~875 80~875'0 3 ,3301 90,3750 NCNL ,81:2:5 NRAT 9.9285 POT DEPT :7200,0000 SFI!JU 2.3:633 : I:LD 2.6:426 ,5127 NCNb . :: ,7500 DT NPHI 35'9798::.: R~08 ~2 0o0329: C~bI b '82 7 , ~CNL 64:0.2~05 NR~I SG~ 93,4972 :NCN. :., 22::i~:93 :CG¢:: 73,25.0:0: SGR :' 8'42:19: ~POTA ORAN 2,68:1:6 : GR 80 8193 DEP~ 710:0,009:0 SP '4:9',06:2:5: GR NPHI 31,5430 R}.IOB S~ 8:6,0000 '~N:CN:L 228:2 R 86 ~:r~~ '~6'95 7930:i:LD :: ~i:'25~ :[~T :: ,:3535DRNO .0000 'FCN:L .0:000 THOR .$I~5 DEPT 7000.O0:00'SF,:L!J 2:.89:45 SP -56,1250:. GR., 78,3750 DT NPHI 32~2071 RHOB 2.3346:DR~D 8GR 87.7130N, CNL 2375,1875 FCNL CGR 71'7344 ' S'GR 87.8750 UR~N 2.1416 GR 81.1055 DEPT 6900.0000 SFLU 2.4785 ILD SP -40.3750 GR 77.2500 DT NPHI 32.8388 RH(]B 2.3547 DRHO SGR 85.3945 NCNL 2306.8750 FCNL CGR b8.0625 SGR 86.5000 THU~ ORAN 2.39~4 G~ 75.2656 D~PT 6800.0000 SFLU 2,9824 II, D SP -53.3125 GR 81.3750 DT NPHI 33.1.055 RHOB 2.3809 DRHO SGR 90.8125 NCNb 2306.0000 FCNL CGR 66.4375 SGR 90.3750 THOR URAN 3.1172 GR 75.0625 DEPT 6700. 0000 SFLU 2,5430 SP -51.0625 GR 85.3125 DT NPHI 33.8,379 RHDB 2.3496 DRH. 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FCNL ,8750:$GR' 6.6.31:25 THOR -'974.~ .GR 6':2.;87.50 .0000 SFL, U 3.017:6 I[,D 6250 GR: 7~.3750 DT ~619 RHOB ,.:3447~ DRHO .3137 NCNb 2242.1875 FCNL .5796 SGR 89.3].25 THOR .0166 GR 75.0859 0000 SFI,U 2.3945 ILO 7813 GR 82,8750 DT 215 RHOB 2.3652 DRHO 500 NCNb ~226.0000 FCNL 1250 SGR 89.7500 THOR 2031 GR 79.9062 0000 SFLU 2.6426 3750 GR 72,1875 DT 9556 RHOB 2.2925 DRHO 9624 NCNb 2128.3125 FCNL 1250 SGP 84,7500 THOR 6436 GB 75.7871 0000 SFLU 2.9~73 ILD 0625 GR 68.~875 DT 0820 RHOB 2.2754 ORHO 4375 NCNb 2278,0000 ~'CN[., 6200 -65 33 88 73 2 6100. -62. 34 65. 6000. -66. 36. 72, 1. 5~00 59~ 34. ~3. 2':8066 ibm 97,8496 NCNb 0:,0161 CALI . , ~ 610,50 0 : NRAT 110.~500 iPOTA 9.8359 POTA 2'6992 ILM ? 10Z.5625: :NCNb CALI N R A T 8.6797 P.OTA 3. 341~ 128 CALl 650. 3750 N~AT 8.$394 POTA 2.5508 I6M 98.1255 NCNb 0 0220 CALl 643:0000 NRAT 7.6094 POTA 2.77].5 ILN 107.7876 NCNb 0.0042 CAL! 586.0313 NRAT 9.1797 POTA 3.1504 100,9590 0.0107 659.5000 .) CALI 2.623:0 2202,0000 11.:t56:~ 2,7715 2205.3'984 I ~ ,7034. . :1:<59~ 1. 806.6 6:32:8 2139,8750 7349 ~6367 42:''8 1699 2 1 .5000 1 ! ,6211 3.5250 I .8066 3.2207 2242,1.875 10.7891 3,1328 2.6111 2.5137 2226.0000 11.4922 3.2012 2.1484 2.759~ 2128.3125 11,5156 3.3397 2,4414 3.0645 2278,0000 11.4219 3.1758 LVP OlO'MOI :VKRIF:ICATI:ON LISTING PAGE; 9 .500:0 .:SGR $3.4375 . THOR 9.3516 POTA 6~,SJ.:5:4:G'R 69..9805 DEPT 5800.0000 SFLU 2,75:20 :IbD 3'I035 IL~i S P 76,1250 G. : ~8,75.00 DT ::$~ 92.39~6 NCNb 2338,~250 CGR 69. 7500:S~GR 9:~'8:125: ::THOR 8,5('.)00 POTA URAN .2,873:0: GR: : :88. 7500 DEPT ~5700 SP '57 .NPHI 38 UR N DEPT {J R A I~ ,:0000 $?5U. 2. 3359ILD : 2,7070 · 3 ]8: los oooo 3:789., RHO::B , 2.32:42 ~RH[) :0.0~66 '0000NC:NL 20i:2:,00:00 :FCNL 529'O000NRA'r ,:375J ::o 89,:O00,0 THOR 8,7969 POTA .8:105:G 5:600.0000 SFLU 2 33:98IL:D 0,3~25 GR :7~ ~.:2030 ::~HO~ ~' '~ 594 NCN5 :~977,5000K:CN:L 75;0000 88'0000: 'T~OR 1.6895 . 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DRHO 0.0~29 CALI 5000 NCNL ~102 0000 FCNL 582.5000 NRAT 3750 SGR 99:5000 THO~ 7.56~5 POTA 5313 GR 86.6250 DEPT 5500 SP ':70 DEPT 5400 SP -67 NPHI 35 SGR 90 CGR 70 DEPT 5300 SP -65 NPMI 39 SGR 81 CGR 68 URAN 1 DEPT 5200 SP -72 NPHI 33 SGR 99 CGR 72 URAN 3 DEPT 5100 8P -95 0000 SFI..,t] 7,4727 IbD 6.7109 IL~ 6250 GR 5g"5625 DT 114.7407 NCNb 2.1973 3. 2402 2338.1250 12'.7212 3,2941 · 2949 , 2.6094 2012'0:000 12,0547 3 .4316 2,~484 2. 5723 1977 , 5000 l, 2.25:78 . 441 3.0176 1930.0000 1~,0547 ,5078 2.5879 3.3164 2096.0000 14,1094 3.3438 2,2949 3.5195 21.86,0000 13.7188 3,5234 2.0020 4,3047 2102.0000 14.4297 3.2227 2.8320 6.8008 2404'0000 5VP OiO.HO1 V~]RIFICATI!DN lISTING PAGE 10 NPHI 36:.9141: RMOB 2,2441. ~:~,HO : : :0,00:8.3 CALl SGR 63'2500NCNL :240:4:,0:6:0~ FCN[> 673'0000 NRAT 52,5313~GR 63.2500 THOR 7.3750 POTA I,:39B4: G9 59*8000 DEPT 5000.0000 SFLU 4.1836 :ISD 4.7578 :I:L~ 8 ~ ..... ~ ' 8. ~.0000 NCNL SP 6 :,3:105 DRHO NPMI 36.1328 RHOB 10 -0:200 CALI SGR 812:5 :594.0000 N~AT CGR 9:6:~7: :SGR URAN 674@ :GR 63':781::'3 SG ;:3125:: NCN 6~6,5000: N AT 3,056:6ILD 53;gO6~DT ; .2.0:8:9:8 :DR~O 5:8',31~25 53,9062 5.04:69 :ISD 2.9160 2~2090DRHO ,0059 2096,0000 FC:NL '602,0000 NRAT 60.5000 THOR 9~0~56 POTA: .77,7500 DEPT 4700,O090SFLU SP '112.0625: GR NPHI 40.4297RMOB SGR 68.1975 NCNL CG~ 58,4688 URAN 1.2646 GR '4,4141ILD 1~.2520 NCN5 ~:3.~437 DT I ,3848 II~M 2,2500 DRHO '0.0973 CADI ?~22:*0:000 FCN'L 6]9.0000 NRAT 68,1875 THOR 7.7227 POTA 60.0176 DEPT 4600.0000 SFLU SP "112 8125 GR NPHI 38:5498 RHOB SG~ 56.1328 NCNL CGR 44,5938 SGR U~AN 1.3~62 GR 11,4~19 ILO 3.7598 52,'7500 DT 114.3750 NCNL 2.17~1 DRHO -0.0041 CALI 2246.7500 FCNL 629.5996 NRAT 54.7813 THOR 7.3008 POTA 52.750Q DEPT 4500 0000 SFLU SP -1.32~8750 GR NPHI 38.9648 RMOB SGR 46.5938 NCNL CGR 37,3125 SG~ URA~ 1,2080 GR 5.4414 43.5938 DT 129.7500 2,0781 DRHO -0.0024 CALI 2362,0000 FCNL 666.0000 NRAT 46.5938 T~OR 6.2656 PDTA 43.5938 OEPT 4400.0000 SFLU SP -125,8750 GR NPHI 39.7051 RHOF SGR 40.2651 NCNL CGR 31.2031 SGR URAN 1.1182 GR 4.5273 ILD 1,8555 I~ 35.0000 DT 121.7866 NCNL 2.1010 DRHO -0.001~ CALl 2432,3750 FCNL 696.2'129 NRAT 39.7813 THOR 4.343~ POTA 34,4932 4688 2949 6602 4. 3320 216B,0000 1I ~ 9:609 ~3,306 6 .2695 : 1. 5957 240:6'0'00'0 ~,O0?B ' I9:I4 I. 7578 1074 209~.000 8:8280 0957 .6II3 . 5625 222 · 000:0 3418 2.0508 4.4766 2246 7500 3.2486 1.1719 2 1562 2362:0000 9 0000 1.0742 1.9687 2432.3750 8,7948 3.31.37 0.9766 . 0 ...... S ....... DEPT SP CGR U~AN -132.3759 3 ,i7875 D.f 109,3750 42 8.7 ti: R.H:OB .:2,,138::7 4279S70 NCNB 2378.0000 0000 .4561 .SG~ : 474,093~: THOR 3.3115 2 ~776 : : 7, i7875 DEP. .4200.0000 :S?LU 7: 04769 : ILD SP '94,0625 GR: 55,3750 DT :: : NPHI: 45. J. 1772 R:HDB 2. t78716 DRHO 79,0525 NCNb ::1903,0000 FC:NL 6o.43757 S:GN 79,0625 T~:O~ 2.4:258 G:R 755.737570 SGR CGR URAN 2656 ILD DEPT 4100.. 000:0 SFL'U :: sp .707.71 50 6:7soo CGR , URAN ,I478~ GR: 6.6992' lbD :5~.0313 DT: ,~I:33: · DRHO 0000 FCNL 250:0: TH:OR 0313 DEPT 4000.0000 S:FLI.J SP -8 5 '' NPHI · 8o s. ~GR 63,1434 NCN ~ 57, CGR 9 URAN 0.~604 GR 53. DEPT 3900. 4, SD '71. 5~' NPHI 43,6035 RHOB SGR 7.4.2500 NC.NL 1823. CGR 63,6875 SGR. 72, URAN 1.1758 GR 58. DEPT 3800.0000 SFLU 4. SP -84 3750 GR 47. NPH! 36:4649 RHOB 2. SGR 55.3535 NCNb 2427. CGR 44.9687 SGR 54. URAN 1.1787 GR 47. OEPT 3700.0000 SFLU 6. SP -84,8125 GR 52. NPHI 40.7642 RHOB 2, SGR 58.5984 NCNL 2242. 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NCNb CALI NRAT POTA 6.1914 ILg ,0000 ~C h 0820 PDTA 4.2773 IbM 2 1,~,5625 NCNb · :0034 CALI 602.4102 NRAT 6.2734 POTA 4,2773 IbM 113'0000 NCNb 0.0210 CALI 433.0000 NRAT 8.4509 POTA 4.3672 II.~ 127.3750 NCNb -0.0037 CALI 701.0625 NRAT 5.6133 POTA 5.4414 IbM 126.3750 NCNb 0,0039 CALI 585.8750 NRAT 6.0703 POTA 5.7227 134.0000 NCNb -0.0063 C~LI 574.0000 NRAT 6.0820 PDTA .5059 237 ,0000 ,640.6 3.4785 0 , 9387 6. 4453 oooo 9375 197~ .~. 5844 1, .5132 1.B066 4,4:648 2357.0000 3438 9375 6934 2.0020 4.3320 2427 4063 9~9187 3,2270 1.6602 5.4063 2242.6563 10.2169 3.4902 1.4648 5.8281 2234.0000 9.6484 3.4902 2'0996 DEPT 3509.000:0 SFLU : .: 4,035,2 ILD 4,9219 ILMj SP '65.562::5 GR: i i:73'4:375' DT 139'1:436 :N:CNI. NPMI 50: DRHO 0,0078 CAbI SGR 79 ~'CNL 410"7:50:0NRAT THOR : 7,3789 : POTA 0074 CALI 5498 FCN:b 596,7344 NRAT 5'3 : THOR 6:.:85:14 POTA URAN: ,7203 :~: '::: : : :::8'~;27'5:4 ' T S~ -t 0 g 38: D NPHI ]~797' DRHO :SGR 8 5000 ~NCN5 2~46.0000 FC L C~R 39 0938: :SG.~ 1.9375 GR 55,0938 , oo.oooo BP 70,5625 68:7:5 DT .NPHI 46.2678 RH08 2,1514 DRHO SGR 7't.8496 NCNb !71.814375 FCNL GH 58.6563 SGM 76.8750 THOM ~AN 2,3750 GM 71.6875 DEPT NPH! 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