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183-001
REceIVED } STATE OF ALASKA ) ALASKA 01L AND GAS CONSERVATION COMMI~SION IAN 2 6 WELL COMPLETION OR RECOMPLETION REPORT AND LOG .. 2006 Alaska Oil & Gas Cona Com . . A- - . mISSIon nello,,,,, 1 b. Well Class: - o Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 183-001" 305-241 13. API Number 50- 029-20891-00-00 " 14. Well Name and Number: No. of Completions 1 a. Well Status: 0 Oil D Gas 0 Plugged 181 Abandoned D Suspended D WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: DIL-BHCS-SP-GR, NML, LDT-CNL-NGT, EPT, TDT, ML CASING, LINER AND CEMENTING RECORD BElTING - DEPTH MD BElTING - DEPTH-WD HOLE '~ OP ~OTTOM 'lOP bOTTOM SIZE Surface 115' Surface 115' 26" Surface 2500' Surface' 2302' 17-1/2" 2150' 5095' 2150' 4816' 12-1/4" 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4450' Set 9-5IS" EZSV with 60 Bbls 'G', 15 Bbls on top, 45 Bbls below 3905' Set 9-5IS" EZSV with 47 Bbls 'G', 15 Bbls on top, 32 bbls below 2140' Set 13-3/8" Bridge plug capped with 30 Bbls 'G' 250' Set 13-3/8" Bridge plug capped with 37 Bbls ASI PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A OIL -BBL D GINJ D WINJ D WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1917' FNL, 1546 FEL, SEC. 23, T13N, R10E, UM / Top of Productive Horizon: N/A Total Depth: 2172'FNL,2773'FEL,SEC.23,T13N,R10E,UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 564272 / y- 6021136.-' Zone- ASP4 TPI: x- y- Zone- Total Depth: x- 563048 y- 6020870 Zone- ASP4 ~-~------------------------ ._--.----.------------------ .----------- ---------- 18. Directional Survey DYes 181 No 22. CASING SIZE WT. PER FT. 94# 72# 47# GRADE H-40 L-80 L-80 20" 13-3/8" 9-518" 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD ~,_---{t"'b..~"_ ~~\G;;~l' \i!~\N :1\ 1 2006 ~\'¡¡i~.'t1l~O~t:,;¡¡.~' d t' d' '>:.J.I 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED ........ OIL -BBL Press. 24-HoUR RATE"'" 27. Zero Other 5. Date Comp., Susp., or Aband. 12/22/2005 / 6. Date Spudded 01-27-1983 7. Date T.D. Reached 02-02-1983 8. KB Elevation (ft): 58.0' 9. Plug Back Depth (MD+TVD) 5099 + 4820 10. Total Depth (MD+ TVD) / 5099 + 4820 11. Depth where SSSV set N/A MD 19. Water depth, if offshore MSL 24. SIZE N/A TVD GAs-McF W ATER-BBL MPA-03 15. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands ' Ft Ft 16. Property Designation: ADL 047437 ".- 17. Land Use Permit: GAs-McF W ATER-BBL 20. Thickness of Permafrost 1800' (Approx.) CEMENTING RECORD 345 sx Permafrost 'C' 2000 sx Arco Fondu, 500 sx PF 'C' 950 sx 'G', 250 sx PF 'C', 130 Bbls Arctic Pac AMOUNT PULLED TUBING RECORD DEPTH SET (MD) PACKER SET (MD) CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Abtu';'fIl~f- -_ . None RBDMS 8Ft JAN3 0 2006 Lf:~?;.~:;:g_'5 ,~. Form 10-407 Revised 12/2003 l) I \ I l " ¡- I: \ " ",' L ' ' . \ I \ CONTINUED ON""REVERSE SIDE G 28. ) 29. ) t=ORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". GEOLOGIC MARKERS NAME MD TVD KA MA NA NB NC ND NE OA 4016' 4265' 4508' 4536' 4556' 4575' 4584' 4665' 3730' 3978' 4230' 4247' 4267' 4297' 4575' 4387' None 30. List of Attachments: Summary of Daily Drilling Reports, Pre Rig Work Summary and a Well Service Report Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra SI(';'~~{Dr-- Tl1Je Technical Assistant Date 0 I - J.. Lj -C'ÁQ MPA-03 183-001 305-241 Prepared By Name/Number: Sandra Stewman, 564-4750 Well Number Permit No.1 Approval No. Drilling Engineer: David Reem, 564-5743 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ) ) Well: Field: API: Permit: MPA-03 Milne Point Unit I Kuparuk River Sands 50-029-20891-00-00 183-001 PRE-RIG WORK 08/11/2005 PREP FOR P&A ATTEMPT TO PULL BPV, AS SOON AS WE SAT DOWN VALVE EQUALIZED. CONFER WI COMPANY REP AND WELL SUPPORT LEAD. DECIDE TO RIG DOWN UNTIL FURTHER INVESTIGATION CAN BE CONDUCTED 08/16/05 PULLED A 2-9/16" FMC BPV THRU TREE. 08/17/05 SET DOWN AT 3700'SLM. NO IMPRESSION RAN 1.75" BAILER TO 3703' SLM. 08/19/05 PUMP DOWN TBG. TBG PRESSURED UP TO 3000 PSI @ .5 BBLS. BLEED PRESSURE DOWN TO 600 PSI. FWP=6001010. 08/22/05 ATTEMPT TO PUMP DOWN TBG, lA, & OA. TBG, lA, & OA PRESSURED UP. BLEED PRESSURES DOWN TO 0 PSI. 08/24/05 PULL TOP TUBING STOP @ 3704' SLM. PULL UPPER PACK OFF @ 3727' SLM. PULL TOP TUBING STOP @ 3704' SLM. PULL UPPER PACK OFF @ 3727' SLM 08/25/05 PULL BOTTOM TUBING STOP @ 37391 SLM. RIH WI 2.25 CENT AND SB. TAG TD @ 4816' SLM. PUMP 125 BBLS PRODUCED WATER @ 180* DOWN TBG. FREEZE PROTECT TBG WI 12 BBLS 60/40 METH. PUMP 5 BBLS 60/40 METH DOWN lA, THE FLUID LEVEL APPEARS TO BE BE DEEP. 08/26/05 PUMP 14 BBLS DIESEL DOWN 4.5" ANNULUS, WHILE TAKING RETURNS FROM 9 5/8 ANNULUS. 08/28/05 MADE STATIC PRESSURE AT 42401 AND SET BAKER 2.13" IBP ATMID ELEMENT DEPTH OF 4240' IN TWO RUNS. PRESSURE WAS 1702.2 PSI AT 42401. 08/29/05 PRESSURE UP ON BRIDGE PLUG TO 1500 PSI WITH .5 BBLS OF DIESEL. HOLD PRESSURE FOR 30 MINUTES. BLEED TBG PRESSURE DOWN TO 0 PSI. ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPA-03 MPA-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Date From-To Hours Task Code NPT Phase 9/2/2005 18:00 - 00:00 6.00 MOB P DECOMP 9/3/2005 00:00 - 01 :30 1.50 RIGU P DECOMP 01 :30 - 03:30 2.00 RIGU P DECOMP 03:30 - 04:30 1.00 KILL P DECOMP 04:30 - 06:00 1.50 KILL P DECOMP 06:00 - 07:30 1.50 KILL P DECOMP 07:30 - 09:30 2.00 KILL P DECOMP 09:30 - 11 :30 2.00 KILL P DECOMP 11 :30 - 12:30 1.00 KILL N DPRB DECOMP 12:30 - 14:00 1.50 KILL N DECOMP 14:00 - 16:00 2.00 KILL N DECOMP 16:00 - 16:30 0.50 KILL N DECOMP 16:30 - 20:00 3.50 KILL N DECOMP 20:00 - 21 :00 1.00 KILL P DECOMP 21 :00 - 22:00 1.00 BOPSUP P DECOMP 22:00 - 00:00 2.00 BOPSUP P DECOMP 9/4/2005 00:00 - 01 :30 1.50 BOPSUP. P DECOMP 01 :30 - 02:30 1.00 BOPSUR P DECOMP 02:30 - 04:00 1.50 BOPSUP P DECOMP 04:00 - 04:30 0.50 PULL P DECOMP 04:30 - 06:00 1.50 PULL P DECOMP 06:00 - 07:00 1.00 KILL P DECOMP 07:00 - 07:30 0.50 KILL P DECOMP 07:30 - 10:00 2.50 PULL P DECOMP 10:00 - 10:30 0.50 PULL P DECOMP 10:30 - 11 :00 0.50 BOPSUPP DECOMP 11 :00 - 12:30 1.50 BOPSUR P DECOMP 12:30 - 13:00 0.50 WHSUR P DECOMP 13:00 - 14:30 1.50 BOPSUR P DECOMP 14:30 - 15:30 1.00 BOPSUF P DECOMP Start: 9/2/2005 Rig Release: 9/10/2005 Rig Number: Spud Date: 1/27/1983 End: 9/10/2005 DescriptionofQpërätions Move from MPJ-24 and spot rig at MPA-03 Raise and scope derrick Hook up Tigar Tank and Lines to 9-5/8" x 4-1/2" on tree. Wait on Sea Water. Accept Rig at 01 :30 hrs. Fill Pits with 130* seawater R/U GPB I DSM lubricator I Pull BPV I RID lubricator Rig up and test lines to Dual string Tree. PJSM with all. Circulate hot Sea Water down 41/2" x 2 7/8" Annulus. Take returns from the 9 5/8" x 4 1/2" Annulus to the Tiger Tank. Circulate until clean at 3.0 bpm800 psi. (total 335 bbls). Monitor Well. Open 2 7/8" Tubing. Well flowing up the 2 7/8" Tubing String. Recovered 8 bbls diesellwater. Flow continues. Attempt to circulate the 4 1/2" x 2 7/8" Annulus and take returns up the 2 7/8" Tubing. No-Go. Bullhead down the 2 7/8" Tubing and into the formation at 2 3/4 bpm/1000 psi. IBP set in the 4 1/2" Tubing String at -4,240' elm has failed. Continue to Bullhead 2 7/8" Tubing vol. shut down pump. Monitor pressure drop to 70 psi. Call SWS and BOT to set a second IPB. Finish Bullheading the remaining Casing vol to bottom perforation while WO SWS to arrive. SWS and BOT arrive on location. Rig-up SWS E-line Unit. R/U ElL with IBP Test lubricator 3500 psi good test RIH to 4,280' (40 ft below where 1 st was set at). Did not tag I BP. Log on depth with 4 Jts below seal bore at 4186' Drop to 4230' and set IBP packer POOH Test Packer 1500 psi for 15 min. Good Test RID ElL Set FMC ISA BPV Nipple down Tree Nipple up BOPE Nipple up BOPE PulllSA BPV and set FMC TTP Test BOPE 250 psi low 3500 psi high as per BP AOGCC procedures Test witness waived by C. Sheve with AOGCC. Test witnessed by Tool Pusher and Company Rep. Pull FMC TTP Make up Baker spear on 3-1/2" DP Stab into 2 7/8" Hanger and pull to surface. Circulate 2 7/8" Tubing taking returns from the 4 1/2" x 27/8" Annulus until clean. Monitor Well. Slight flow from 4 1/2" x 27/8" Annulus. Open 9 5/8" x 4"1/2" Annulus. Flow from 4 1/2" x 2 7/8" Annulus stopped. Monitor Well dead. TOH with 130 Jts 2 7/8" CS Hydrill Tbg, 1 Pup Jt, Seal Assembly. 27/8" Completion recovered complete. Rig down 2 7/8" Floor. Clear and Clean. Drain BOP Stack. Set 4" ISA BPV in 41/2" String. Test. Nipple down BOP Stack and Double Flange Adaptor. Remove 2 7/8" Tubing Head Adaptor. Nipple up BOP Stack. PulllSA BPV. Install Test Plug. Test BOP Body break at 250/3500. Good. Drain Stack. Pull Test Plug. Printed: 9/12/2005 10:04:39 AM ) ) Legal Well Name: M P A-03 Common Well Name: M P A-03 Spud Date: 1/27/1983 Event Name: PLUG+ABANDON Start: 9/2/2005 End: 9/1 0/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/1 0/2005 Rig Name: NABORS 4ES Rig Number: Date From-To Hours Task Gode NPT Phase Descri ptionofOpe rations 9/4/2005 15:30 - 16:30 1.00 PULL P DECaMP BOLDS. Plant Spear in 41/2" Tubing. Pull Tubing Hanger to Floor at 56K. Slick Stick was not pinned to Packer. Lay down Spear and Tubing Hanger. 16:30 - 18:30 2.00 PULL P DECaMP Circulate Well at 6.0 bpm/250 psi. Bullhead Casing volume. Monitor Well. 18:30 - 22:30 4.00 PULL P DECaMP POOH Lay Down 4-1/2" Tbg Total 142 Jts Measured Seal Bore Receptical O.D. 5.688" 1 I.D 4.125 Call out for 4-1/8" Grapple for over shot. Both IBP Packers where in lower 4-1/2" Tbg 22:30 - 00:00 1.50 PULL P DECaMP Rig Down 4-1/2" handling Equip. 1 Rig Up 3-1/2" Handling Equip. Clear and Clean Rig Floor 9/5/2005 00:00 - 02:30 2.50 FISH P DECaMP Pick up and make up BHA and drill collars wait on 4-1/8" Grapple 02:30 - 03:00 0.50 FISH P DECaMP Make up 4-1/8" Grapple in overshot RIH BHA 03:00 - 07:00 4.00 FISH P DECaMP Single in with 126 jts 31/2" Drill Pipe from Pipe shed. 07:00 - 07:30 0.50 FISH P DECaMP Pick-up Kelly. PUW:= 77K. SOW:= 65K. Tag TOF at 4,322'. Latch Fish with Overshot. Pull to 11 OK. Unload Jars one time. Packer came free. Work Packer up/down. 07:30 - 08:30 1.00 FISH P DECaMP Circulate Bottoms-up at 5.0 bpm/700 psi. Some gas in returns from bottom. Continue to circulate until Well clean. Monitor Well dead. 08:30 - 11 :00 2.50 FISH P DECaMP POOH and stanb back Drill Pipe and Drill Collars. 11 :00 - 11 :30 0.50 FISH P DECaMP Lay down BHA #3. Recovered Packer and Tailpipe complete. 11 :30 - 12:00 0.50 CLEAN P DECaMP Make-up BHA #4...Bit and Casing Scraper. 12:00 - 13:30 1.50 CLEAN P DECaMP Trip in Hole with BHA #4 and 3 1/2" Drill Pipe. Tag Fill at 4,826' 13:30 - 14:00 0.50 CLEAN P DECaMP Wash remainder of Joint down to 4,837'. 14:00 - 18:00 4.00 CLEAN P DECaMP Reverse bottoms up. Heavy amount of Formation fine silt causing screens to blind off. Reverse a 30 bbl Hi-Vis Sweep. 18:00 - 19:00 1.00 CLEAN P DECaMP Injectivity test 1 bpm - 230 psi, 2 bpm - 500 psi, 3 bpm - 900 psi. Formation did give flow back fluid 19:00 - 20:30 1.50 CLEAN P DECaMP POOH with BHA #4 20:30 - 21 :30 1.00 CLEAN P DECaMP Lay down BHA #4 21 :30 - 00:00 2.50 PXA P DECaMP PIU Halliburton EZSV RIH 9/6/2005 00:00 - 01 :00 1.00 PXA P DECaMP RIH with EZSV on 3-1/2" DP to 4450' 01 :00 - 01 :30 0.50 PXA P DECaMP Set packer with straight pull up in inciments to shear of 120K 1 Slack back on packer 15K Inject in well at 1 bpm 230 psi 01 :30 - 03:00 1.50 PXA P DECaMP PJSM Test lines to 4000 psi Pump 5 bbl fresh water followed with 60 bbls 15.8 class G cement Displace with fresh water. Squeeze 45 bbls below EZSV, UnSting from EZSV and displace 15 bbls on top Retainer 03:00 - 04:00 1.00 PXA P DECaMP POOH 258' Close annulars, Pressure up to 1500 psi @ 42 stks and shut in, well bleed back to 800 psi Attempt to pressure up and pump 204 sts shut down. NO TEST 04:00 - 04:30 0.50 PXA P DECaMP Monitor well 1 Well continues to drop Monitor 30 minutes and leveled off at 500 psi 04:30 - 07:00 2.50 PXA P DECaMP POOH with 3-1/2" Drill Pipe and Halco Stinger Tool. 07:00 - 08:00 1.00 PXA N DFAL DECaMP Make-up 31/2" Mule Shoe. TIH to 4,000' Park Muleshoe. 08:00 - 11 :30 3.50 PXA N DFAL DECaMP wac to reach compressive strength. WO AOGCC Rep to return to location to witness tag and pressure test. 11 :30 - 12:00 0.50 PXA N DFAL DECaMP Continue in hole with 31/2" drill Pipe. Tagged TOC at 4,259' (calculated expected TOC was 4,246'). 12:00 - 12:30 0.50 PXA N DFAL DECaMP Attempted to pressure test lower cement plug. No-Joy. Have a casing problem up hole. Injection rate := 1.0 bpm/1200 psi. 2 Printed: 9/12/2005 10:04:39 AM ) ) BPE)(PLORATION O¡R~"atiqrn~·Stlmmary,··Rel3()rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M P A-03 M P A-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 9/2/2005 Rig Release: 9/10/2005 Rig Number: Spud Date: 1/27/1983 End: 9/10/2005 Date From'-To Hours Task COde' .'NPT Phase Descriþtionof Oper(itions 9/6/2005 12:00 - 12:30 0.50 PXA N DFAL DECaMP bpm/1250 psi. 12:30 - 13:30 1.00 PXA N DFAL DECaMP Discuss plan forward with Anch Eng. Order out Halco 9 5/8" RTTS Packer. Clean Floor. 13:30 - 15:00 1.50 PXA N DFAL DECaMP POOH with 3 1/2" Drill Pipe and Muleshoe. 15:00 - 15:30 0.50 PXA N DFAL DECaMP Pick-up Halco 9 5/8" RTTS Packer. 15:30 - 17:00 1.50 PXA N DFAL DECaMP RIH with RTTS Packer and 3 1/2" Drill Pipe. 17:00 - 18:30 1.50 PXA N DFAL DECaMP Set RTTS Packer at 4,192' (67' above tagged TOC at 4,259'). Attempt to pressure test cement plug. No-Joy. Inject at 1.0 bpm/1200 psi. Attempt to test Annulus. Annulus above Packer also taking fluid. Release and move Packer down to 4,250' and set. Attempt to test Cement Plug still injecting. 18:30 - 21 :00 2.50 PXA N DFAL DECaMP Release Packer and pull up hole to 3716' Test Csg. to 1500 psi Charted. Confer with AOGCC Lou Gramaldi / State will require a retainer set above leak with volume of Csg below + 5.0 bbls squeezed and 15 bbls above tested to confirm isolation. Confer with Anch Eng. RIH with RTTS and set at 3900' Test 9-5/8" Csg 1500 psi 30 min Charted. Release RTTS. 21 :00 - 22:30 1.50 PXA N DFAL DECaMP POOH with RTTS on 3-1/2" DP / Plan forward is to set EZSV at 3900' and pump 30 bbls below, and spot 15 bbls above and test. 22:30 - 00:00 1.50 PXA N DFAL DECaMP DS Cementers to arive 06:00 hrs for next phase. Wait on Cement Equipment. 9/7/2005 00:00 - 03:00 3.00 PXA N DFAL DECaMP Continue to wait on Cement Equipment. 03:00 - 06:00 3.00 PXA N DFAL DECaMP Make up Halco 9-5/8" EZSV Cement Retainer. Run in hole and set EZSV at 3,905' Perform injection test at 3.0 bpm/1300 psi. 06:00 - 08:00 2.00 PXA N DFAL DECaMP Cement Equipment arrives on Location. Rig-up. 08:00 - 08:30 0.50 PXA N DFAL DECaMP PJSM with All. 08:30 - 09:30 1.00 PXA N DFAL DECaMP Pressure test lines at 3,000 psi. Pump 5 bbls Fresh Water, 47 bbls of Class "G" 15.8 Ib/gal Cement. Displace with Fresh Water. Pumped 32 bbls below retainer of which 7 bbls were squeezed behind pipe. Un-sting and pump a 15 bbl balanced plug on top of Retainer. Pull up to 3,642'. Reverse Circulate Drill Pipe x 3 at 6.0 bpm/850 psi. Recovered> 1 bbl. Calculated TOC = 3,714' 09:30 - 10:00 0.50 PXA N DFAL DECaMP Flush Choke Manifold and clear Valves. Call-out SWS E-Line. 10:00 - 10:30 0.50 PXA N DFAL DECaMP Pressure test 9 5/8" Casing to 1,600 psi/30 min. Good. Cement Plug and pressure test witnessed bt AOGCC...Lou Gaimaldi. 10:30 - 12:00 1.50 PXA N DFAL DECaMP Trip out of Hole with 3 1/2" Drill Pipe and Halco Stinger Tool. 12:00 - 17:00 5.00 PXA N DECaMP Wait on SWS services 17:00 - 17:30 0.50 PXA P DECaMP Safety Meeting with Schlumberger and Rig personnel 17:30 - 19:00 1.50 EVAL P DECaMP R/U SWS and test to 500 psi RIH with Ultrasonic Imaging Tool Gamma Ray I CCL Log for cement bond from 3052" up to 1936'. Find 13-3/8 Shoe to be well cemented. TOC logged at -2,240'. POOH R/D 19:00 - 00:00 5.00 PXA P DECaMP PJSM M/U Baker 9-5/8" multi-string cutter, DC, and RIH on 3-1/2" DP Make cut @ 2150' good indication of cut 9/8/2005 00:00 - 02:00 2.00 PXA P DECaMP POH and lay down with 3-1/2 DP UD BHA #5. 02:00 - 02:30 0.50 PXA P DECaMP Clear and Clean Rig Floor 02:30 - 03:00 0.50 PXA P DECaMP R/U PE Open Top Tank Lines 03:00 - 03:30 0.50 PXA P DECaMP Safety Meeting with Little Red and Rig personnel 03:30 - 07:00 3.50 PXA DECaMP Recover Arctic Pack. Pump 20 bbls Hot Diesel, 20 bbls Fresh Printed: 9/12/2005 10:04:39 AM -) ') Legal Well Name: MP A-03 Common Well Name: MPA-03 Spud Date: 1/27/1983 Event Name: PLUG+ABANDON Start: 9/2/2005 End: 9/1 0/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/10/2005 Rig Name: NABORS 4ES Rig Number: Date From ~ To Hours Task Code NPT Phase DescriptionofOþe rations 9/8/2005 03:30 - 07:00 3.50 PXA DECOMP Water/w Safe-Surf-O (soap), 20 bbls Hot Diesel, 20 bbls Fresh Water/w Safe-Surf-O. Displaced with 300 bbls 160 deg Fresh Water. 07:00 - 08:30 1.50 PXA P DECOMP Nipple Down BOPE, DFA, and 11" x 13-3/8" Spool 08:30 - 10:00 1.50 PXA P DECOMP PJSM. Safe out Cellar. Inspect, Clean, Slips and tack weld to 9-5/8" Csg 10:00 - 12:00 2.00 PXA P DECOMP Nipple Up Spool and BOPE Stack, Test 1500 psi 12:00 - 13:00 1.00 PXA P DECOMP Make Up BHA #6 9-5/8" Spear PackOff, 9-5/8" Spear, Exrension, Stop Sub, Bumper Sub, X/O, 1 Jt. 3-1/2" dp 13:00 - 18:00 5.00 PXA P DECOMP RIH 19' Spear 9-5/8", Attempt to pull 9-5/8" Csg with straight pull and bumping Max pull 195K Not coming. Unlatch Spear. Ordered out jars 18:00 - 18:30 0.50 PXA P DECOMP Lay Down BHA #6 18:30 - 19:00 0.50 PXA P DECOMP Make Up BHA #7 as follows 9-5/8" Spear Pack Off, 9-5/8" Spear, Bumper Sub, Jars, X/O, 2 x 6-1/4" Collars, X/O, 10' X 4-1/2" Pup 19:00 - 20:30 1.50 PXA P DECOMP RIH 19' Spear 9-5/8", Jar on 9-5/8" x 16 licks and 9-5/8" came free POH 20:30 - 21 :30 1.00 PXA P DECOMP Lay Down BHA # 7 21 :30 - 00:00 2.50 PXA P DECOMP POOH 9-5/8" Csg, with Centralizers and lay down 9/9/2005 00:00 - 06:00 6.00 PXA P DECOMP Finish POOH with 9 5/8" 47 Ib/ft Casing. Recovered a total of 51 Joints and cut-off. Clean cut. 06:00 - 08:30 2.50 PXA P DECOMP Break-out Spear from top Joint. R/D 9-5/8" Handling Equip. Clear and Clean Rig Floor. 08:30 - 09:00 0.50 PXA P DECOMP Make-up BHA #8 as follows: 121/2" Bit, !3 3/8" Casing Scraper. 09:00 - 09:30 0.50 PXA P DECOMP Trip in hole to 1,066'. Circulate hole. Recovered a small amount of Arctic Pack. 09:30 - 10:30 1.00 PXA P DECOMP Finish tripping in hole. Tag top of 9 5/8" Cut-off Stump at 2,150'. 10:30 - 12:30 2.00 PXA P DECOMP Mix 40 bbls Safe-Surf-O Sweep. Pump Sweep. Displace to surface at 5.0 bpm/600 psi with Hot Sea Water. Total bbls pumped = 325. Return clean. 12:30 - 13:30 1.00 PXA P DECOMP POOH with 3 1/2" drill Pipe and BHA. 13:30 - 14:30 1.00 PXA P DECOMP Lay down Drill Collars. Lay down Bit and Scraper. 14:30 - 15:00 0.50 PXA P DECOMP Clear and Clean Rig Floor. 15:00 - 15:30 0.50 PXA P DECOMP Make-Up Halco 13 3/8" EZSV Bridge Plug. 15:30 - 17:30 2.00 PXA P DECOMP RIH 13-3/8" EZSV to 2,140' on 3-1/2" DP 17:30 - 18:30 1.00 PXA P DECOMP Set EZSV at 2,140' Test to 1500 psi/30 min. Record on Chart. Good Test. 18:30 - 19:00 0.50 PXA P DECOMP Hold Safety meeting with Schlumberger, Halliburton, Nabors and Company Rep 19:00 - 19:30 0.50 PXA P DECOMP Test Lines 3000 psi, Mix and Pump 30 bbls Class G Cement, Displace with 11 bbls fresh water 19:30 - 20:00 0.50 PXA P DECOMP P/U above balanced plug 1880' and Reverse Circulate. Calculated TOC = -1935'. 20:00 - 21 :00 1.00 PXA P DECOMP TIH to 1900' Displace well with 9.8 Brine 21 :00 - 22:00 1.00 PXA P DECOMP POOH and Lay Down DP 22:00 - 22:30 0.50 PXA P DECaMP Clear and Clean Rig Floor 22:30 - 23:30 1.00 PXA P DECOMP Make Up Halco 13-3/8" EZSV Bridge Plug 23:30 - 00:00 0.50 PXA P DECOMP RIH 250' and set EZSV at 250' 9/10/2005 00:00 - 01 :00 1.00 PXA P DECOMP POH and lay down 3-1/2" DP 01 :00 - 01 :30 0.50 PXA P DECOMP Clear and Clean rig floor Printed: 9/12/2005 10:04:39 AM ') ) BPE2XP[C>BATION Opêråtiiøn:s>Sl.irTIrnaryFlêþort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/10/2005 M P A-03 M P A-03 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES From- To HoUrs Task Code NPT Pha.se 01 :30 - 02:00 0.50 PXA P DECOMP 02:00 - 02:30 0.50 PXA P DECOMP 02:30 - 03:00 0.50 PXA P DECOMP 03:00 - 03:30 0.50 PXA P DECOMP 03:30 - 04:30 1.00 PXA P DECOMP 04:30 - 06:00 1.50 BOPSUPP DECOMP 06:00 - 08:00 2.00 WHSUR P DECOMP 08:00 - 08:30 0.50 WHSUR P DECOMP 08:30 - 09:00 0.50 WHSUR P DECOMP Start: 9/2/2005 Rig Release: 9/10/2005 Rig Number: Spud Date: 1/27/1983 End: 9/10/2005 Descri ption of. Opera.tions RIH 2-7/8" EUE 8 rd Tbg to top of EZSV Bridge Plug at 250' Safety Meeting with Schlumberger, Peak, Nabors, FMC and Co-Rep Pump 37 bbls of 15.7 ppg Artic Set 1 Cement POH 2-7/8" EUE 8rd Tbg and lay down Rig -down Cementer. Rig-down lines. Nipple down BOP Stack. Clear Cellar. WO 13 3/8" x 11" Spool. Nipple up Spool and Dry Hole Tree. Pressure test Tree to 1,500 psi. Good. Secure Cellar. Rig Released at 09:00 hrs. Printed: 9/12/2005 10:04:39 AM (If, . ! ,~! WELL SERVICE REPORT ') WELL MPA-03 DATE 12/22/2005 COST CODE PLUS MSP335092-D ) JOB SCOPE PLUG AND ABANDON DAILY WORK PLUG & ABANDON PERFS KEY PERSON VEC-IVESON MINID 0" UNIT UNKNOWN DAY SUPV O'MALLEY NIGHT SUPV UNKNOWN TTL SIZE 0" I DEPTH OFT DAILY SUMMARY GUrUle 20ò"êõndüctôr'ancf ihêT§:^3ï8"'ï3'urfaC'e"caslng^ at"4i'below' tundra fevë'L"w^êïded a' cap onto ·fhê"iû^p'õnhë"sfü'bs. P&A was witnessed by John Crisp of the AOGCC. ****** ***** **** *** ******** *** **TH E END *********** ****** ***** ****************** JOB COSTS SERVICE COMPANY - SERVICE ......"m___...... . DAILY C()$I . . . CUMUL TOTAL AES ....--..--- ",,'".. " $1,600 ., . $1 ,60() GBR . ......^ .. .. " $2,000 $2,OqO PEAk" . '$9,600 $9,600 ,_'"__"_''''~."__,_.,,''_,,...'''''w_,,._''''''..''M''.''__''''__~_..__~'''''-·-~-"~-"''''-'''''TÕTA'[..FfË'[lrEŠTïMA TE:'''''..-'''''''"'''"-,,·...._''''''....''^'..'''''''''"·'''·$T3~2ÕÕ' '-'''----'''---'''--'''------$13,2ÕÖ- .,. e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, '\/ a Û(7jfJ- P. I. Supervisor~~ l t """'lib DATE: December 22,2005 FROM: John Crisp, Petroleum Inspector SUBJECT: BPX MPU A-03 Surface Cement & cut off PTD 1830010 December 22.2005: I traveled to Milne Point Units A-03 Pad to witness casing cut off & cement to surface in all casing strings. A-03's conductor & surface casing had good hard cement in both casing strings, verified after casing strings were cut off more than three feet below tundra level. Well marker plate was placed on the outer most casing string & was ready to be welded in place. Summary: I witnessed final cut off & cement to surface on MPU A-03. Attachment: Photo's of cut off & cement in casing strings. NON-CONFIDENTIAL 2005-1222_ SurC Abandon _ MPU _ A-03 jc.doc Cut> 3 feet Below Tundra Level Recovered w/Cemented Ann uli Stub Cement to Surface Marker Plate - MPU A-03 2005- ') State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg T2. . 1((1./ OS P.I. Supervisor 1'1C( ) MEMORANDUM THRU: DATE: September 6,2005 SUBJECT: Plug & Abandonement MPA-03 BP Exploration Kuparuk River Field Milne Point Unit 183-001/305-241 FROM: Lou Grimaldi Petroleum Inspector Section: Lease No.: Operator Rep.: Hinkle/Felder NON- CONFIDENTIAL Township: Drilling Rig: Nabors 4ES Range: Rig Elevation: 19.8 Meridian: Total Depth: 5099' Casin!:l/TubinQ Data: Conductor: 20" 0.0. Shoe@ 115' Surface: 133/8" 0.0. Shoe@ 2500' Intermediate: 0.0. Shoe@ Production: 95/8" 0.0. Shoe@ 5020' Liner: 0.0. Shoe@ Tubing: 0.0. Tail@ Type Plug Open Hole Perforation Annulus Casing Stub Surface Retainers (2) set at 4450' and 3905' due to casing leak at old squeezed perf's between 4016'-4290'. First pressure test failed, set second retainer and filled and squeezed void (32 bbl's) between two retainers and laid 14 bbl's on top of top retainer. Type PluQ (bottom up) Perforation Founded on Bottom Founded on: Bottom Bridge plug Balanced Retainer ~ Distribution: orig - Well File c - Operator c - DNR/OOG c - Database c - Rpt File c - Inspector Rev.:5/28/00 by L.R.G. Casing Removal: Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Bottom of Cement 5095 PluQQinQ Data: Top of Cement Depth Verified? 3714 (est.) No Pressure Test Applied Yes 1500 psi Mud Weight above plug 8.6 Verified? Drillpipe tag Wireline tag C.T. Tag No ~CANNEu NOV () 3 2005 Attachments: Plug and Abandon MPU A-03 09-06-05 LG.xls 9/12/2005 '~.'. ,~.. .;:;. ,.-..;J ;!"'.11.' '''-J ',F ·.'1''''':) \.,~~o.J!¡ ! Ii' \ ¡I' .! ":\"\. ,!; i 'I \\ I! !::J ,'\ '\' ,', - " .!:' n '.' ': ~:-'\ I I I \ ,I \~ U LJL.l L1 L:=J i!,·,~..\ II? , : 'I' ;, ': ',' ,1 II .1, :1 '-' J J' " ' ',"¡'i" "r í ' :!t¡, ~ u ~ "',' '~,:¡~ '/~: .ìl i-\ "~;;-', .;: i\ ~\ 'II J ;\ \ I -' iL\il /11' ,'" L/~u L6 !../-G C~Li: /T\ /jj\ FRANK H. MURKOWSK', GOVERNOR /j U 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 AI1A~KA. OIL AND GAS CONSERVATION COMMISSION David Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 \ lb a-5Ð/ .......,.~- "-.--- . Re: Milne Point MPA-03 Sundry Number: 305-241 BCJ1,N~\1ED ,QUG 2 2 2005 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision t perior Court unless rehearing has been requested. ~Si er. DATED thisi!1day of August, 2005 Encl. " o~ . Cflì- 8-/9 -¿;5 ALASKA ~ILAND ~~;~g~S~~~ON C~MI''fON RECEIVEDk APPLICATION FOR SUNDRY APPROVAL AUG 1 8 2005 <6/\1 20 MC 25.280 Þdasku Oii & G,:E~ Ccm~L Commission (\peÌlùn~£e 1. Type of Request: II Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Other _________________u____ o Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension , 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: D Development D Exploratory o Stratigraphic D Service 5. Permit To Drill Number 183-001 6. API Number: 50- 029-20891-00-00 99519-6612 58.0' 9. Well Name and Number: M P A-03 8. Property Designation: ADL 047437 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 5099 4820 NI A MD. T\lD,' Burst Junk (measured): 4933 Collapse 11. Total Depth MD (ft): 5099 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 4820 Length Size 115' 2500' 20" 13-3/8" 115' 2500' 115' 2302' 1530 4930 520 2670 5095' 9-5/8" 5095' 4816' 6870 4760 Perforation Depth MD (ft): Perforation Depth TVD (ft): 4508' - 4754' 4230' - 4475' Packers and SSSV Type: 9-5/8" Baker FHL Hydraulic Packer Tubing Size: 4-1/2", 12.6# Tubing Grade: N-80 Packers and SSSV MD (ft): 4354' Tubing MD (ft): 4369' 12. Attachments: !HI Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: D BOP Sketch 13. Well Class after proposed work: D Exploratory D Development 0 Service 16. Verbal Approval: Commission Representative: 17. I hereby cert' that the foregoing is true and correct to the best of my knowledge. Printed Na e David Reem Title Drilling Engineer r~~ August 26, 2005 Date: 15. Well Status after proposed work: DOH DGas DWAG DGINJ D Plugged DWINJ !HI Abandoned D WDSPL Contact David Reem, 564-5743 Phone 564-5743 ·····CÞmÔ1i$øiqijlj$eQ.hly'··. Date 8""/1"'05 Prepared By Name/Number: Sondra Stewman, 564-4750 Conditions of approval: Notify Commission so that a representative may witness ~IUg Integr~y ~OP Test 0 Mechanical Integrity Test 0 Location Clearance RBDMS 8Ft A UG .2 2 2D/15 Other: '-~~<.o.(.-'-~~ k ~,"ðR12.~\TL~~S ~\'''~Ù~~~''\. ~&.,. ~ I~ T ctC t" ('-..C1 ~ '\£. ~ ......; ,.\ t'.(?c;.<;, ( \' \-.c ~ S Q.\ I.C..\,).\ (:,.\..ç. ~ 'V\o.\t: ~\'> 1~ SAupbSperoQvUee70Fyrfu R qui, : / APPROVED BY Date t?' / q / ~ , D,. COMMISSIONER THE COMMISSION f?' /; 11_ Fonn 10-403 ,~ I GIN A L !u'b~it In Duplicate ( ( Project: Permanently Plug and Abandon MP A-03. MP A-03 was a Conoco Schrader Bluff ~est well. Provide AOGCC field inspectors 24-hr notices as required to witness plugging operations. 1. MIRU 4ES. Pull BPVs, set and test TWC in 4.5" tubing hanger. ND tree and adapter flange. NU BOPE. Test annular to 250 psi (low)/3500 psi (high), remaining BOPE to 250 psi (low)/3500 psi (high) per BP and AOGCC regulations. 2. Kill Well 3. Pull 2-7/8" CS-Hydril tubing inner string. 4. Pull 4.5" tubing and FHL retrievable packer. 5. Run 8" bit and 9.625" scraper and clean wellbore to -4,850'md. ./ 6. Set 9-5/8" EZSV cement retainer at -4,300'md. Squeeze -45 bbls cl. G cement below retainer, un sting from retainer and place -200' ft of cement on top of retainer (-15 bbls). '-+ \~I.S ~~\"> ~1w\ 7. Lay in kill weight brine from top of cement to surface. PT wellbore to 1500 psi. 8. Run cement bond log to determine top of cement in 9.625" x 13.37~" annulus.--2Ir \OC.~Ol~..;)(t1 ~\d 9. Cut & pull 9-5/8" casing from -50' above top of logged cement. ~ \~~/&S~Q d5"CX') JIv 10. Run 12-1/4" bit and 13-3/8" scraper to top of 9-5/8" stub. Circ out all Arctic-Pack. with seawater. - '/ 11. Set 13-3/8" CIBP just above 9-518" stub. PT plug to 1500 psi. Lay in 30 bbls cl. G cement (-200' linear feet). 12. Set 13-3/8" CIBP at -250'md. Lay in 15.7 ppg Arctic Set 1 celnent to within 3 ft of original ground level. 13. RDMO 4ES. 14. Excavate around well as needed and cut all casing strings per AOGCC regulations and weld on marker plate. v/ ( WELL No. A-3 COMPLETION SKETCH MILNE POINT UNIT (P) API No.: 50-029- 20891 PERMIT No.: 83-1 COMPLETED: 12/10/83 LAST WORKOVER: N / A NOTFS: 1. ALL MEASUREMENTS ARE FROM KDB OF NABORS RIG NO. 27E KDB - SL = 59' KDB - GL = 35' 2, MAX. ANGLE = 3.30 @ 1200' 3. K.O.P. = 500' 4. SLANT HOLE: YES 5. MIN. ANGLE = O' @ 4900' . 6. TREE TYPE: CAMERON DUAL 5000# WELLHEAD, 2 9/16" x 2 1/16", FMC VALVES, W/ 3.13~ &= 2.6" TAPE MEASURED BULLPLUGS IN TREETOP CONNECTION 7. MIN. RESTRICTION IS 2.375" 2 7/8" TBG 8. COMPLETION FLUID: 9.5 PPG BRINE 9. STIMULATION: ACIDIZED 9-19-83 71 BBLS KCI 1500 BBLS 1570 HCI 10, A GRAVEL PACK WAS RUN 8/27/83 AND REMOVED 10/28/83 11. PERFORMED SQUEEZED 4016'-4049' 125 SX COLD SET I 4265'-4290' 755 SX COLD SET I PERFORA TlONS: 12 SPF, 60' PHASING GO 5" HOLLOW CARRIER GUN .MIl 00 4508'-4514' 4219'-4225' 4536'-4542· 4247'-4253'· 4556'-4562' 4267'-4273''- 4575'-4580' 4286'-4291' 4584'-4602' 4295' -4313' 4657'-4694' 4368'-4405'''''' 4728'-4754' 4439'-4465' CONOCO INC. ANCHORAGE DIVISION ~ /4 1/2", 12.6 N, N-80, BTRC, TUBING (3.96" 10) ~ t'Î..---'! \ Š ~ /<;; ~ d:':' 00 \ J2- "11 2 7/B", 6.5#. N-BO, CS-HYDRIL TUBING (2.375" 1.0, 4169' 4 1/2", BTRC, PERFORATED PUP JT. 4186' BAKER SEAL BORE (80-32) ~ 4196' 4JTS, 12.6#, N-BO, TUBING ~ 4323' BAKER SEAL RECEPTACLE ~ ,.¡ì...---- 4329' OTIS "X" NIPPLE (2.813") ~ - i 4329' BAKER 15' SUCK STICK ¡¡¡ - __ 4354' BAKER 9 5/8" FHL HYDRAULIC PACK[~ ~4369' TBG TAIL {õOõ\ ~ .~ - - /4933' MIUED-OUT DOWEU MODEL 18 PKR __ t5í ........- 5095' 9 5/8", 47#. l-80. B~C APPROVED BY: HDS DRAFTED BY: GKF DATE: 7/30/92 CAD FilE: WCOA3 .~' , ( ~' 1\TELL No. A-3 CASING SKETCH MILNE POINT UNIT (P) APi No.: 50-029-20891 PERMIT No.: 83-1 DRILLED: 2/2/83 ARCïlC PACKED: 2/6/83 OPERA TOR: CONOCO INC. SURFACE LOCATION: 1918' FNl, 1546' FEl, SEC 23, T13N, R10E, U.M. BOTTOM HOLE lOCATION: 2184' FNl, 2823' FEl, SEC 23, T13N, R10E, U.M. SPUD DATE: 1/27/83 .. '1'''.. .. ...::~.'...'.':'.':"."...' ...:-:::~. :::" ;;.;::~ ~;~';'. r" I._ .... ..... .... ;:~ ~:~:~. \~ ~~.:~ :'~"r-' &,:":'. ECP 4335' : " l6. ~~ ~ 1\~"'fS: ~''F ECP 4509' ~D ':~.... ....' ., :,: t.... __ EC::> 4647' ~'$t ~~--- _'.. ~.,~ '_ :.- C-=T - ¡;' '.:', ':."' 9 5/8, "-;r, _ 80, ~,RC, ..J._, @ :>09... '. ~"'-"'-~._.. C~MENT D'-'· 95C S\' ro' 'S5 ",," \"/"% ""-R 2 °3-:-J 5020' ~'~'~':"'>::,"'<'::'~"'~" 3;. N C. ~~;::":. """.-'" \" IIi I Ð ""', --, ...~:..............,. <....~......~.:... 10 a I ::J~'V'. . ~.:.... .:...... ......:. ...:...:.. . :-.,.,..=. .:.....::;..; , TJ 5099' :." .". '. ...: ...... '''. .. ~ . I. ,a: ~ .... ~:::.:.:.~ .1'. :., .. ".' :::.:: .....~.. ^' U '.. .'. < Q.. U 1= u a:: < ;:~'~'.< ..." .". FMC CSG SPOOL RKB=35' :·~~~:~:~~0 " :~.;~> .,:;~ .:.;~: ::;~ ~: ..,.. "" ~.. ".:.:..,.,.~t. '~ " :.,,". .::".... :. .. too ", ' ~ .,:.::~': ~ ..::....:~.. a.. .. ~.... -=. u 1= u a:: < 20', 94#, H-40, SET @ 115' CEMENT DATA: 345 SX PERMAFROST "c" ARCTIC PACK DATA: 250 SX PERMAFROST "C" 130 BBLS ARCTIC PACK 2250' EST 13 3/8", 72#. L-BO, STRC, SET 0 2500' CEMENT DATA: 2000 SX ARCO FONDU. 500 SX PERMAFROST "C· TOC 2815' (Cal) ECP 4011' ECP 4072' EC? 4264' :.. (c:onoco) ;\.,:É~~~~~~ :.!¡~'~:C:: -'~:J"""-", h""~ -. ':""""~...:-\ \. ,.' I :-"_ _ 7·: . ¡.. .. '... f'" .. .... -. .... ,. , ~ 1- - "\ ~ - .:....' =.: :" I· , :- ".Jh -:-t.:: . .~. ,.'9': ...,....- - ,. -. , ........ . . ~,""". . ..; ., ...~,,,.-._. ~ Proposed MPA-03 Plug and Abandonment 2, 150-ft Estimated 2,250-ft Estimated 2,500-ft 5,020-ft 5,099-ft 13.375-in Marker Plate 20.0-in Conductor 13.375-in CIBP Top of Cement 13.375-in Surface Casing 9.625-in Cement Retainer PBTD 9.625-in Casing BP EXPLORATION B-oool ARCO Alaska, Inc. ........... E N G-A~,~-~ To' From: David W. Johnston Chairman Alaska Oil & Gas Commission Steve Horton, Drlg Mgr Shared Services Drilling Date: 09131 'ST/ :ILE Subject: Suspended wells Compliance with regulations in response to your letter dated August 15, 1994 regarding suspended wells attached are lists detailing well status and criteria for maintaining these wells in a suspended status. Plans for well inspections are in place for October 1 through October 3, 1994 as discussed with Blair Wondzell and John Spaulding. Updated reporting has been filed with the commission as listed. Yours Sincerely, Steve Herren Drilling Manager CC. Bill Bredar Patrick Collins Jim Farnsworth Mike Miller Bruce Policky Scott Sigurdson Marian Sloan RECEIVED OCT 1 4 1994 Alaska 0il & Gas Cons, Commission Anchor~a Suspended Wells, ReQuest to retain suspension status The following wells are listed as suspended by the AOGCC under 20 AAC 25.110. These wells are requested to remain suspended for the reason(s) as indicated. Site inspections should be conducted as soon as possible. MPA-01; 029-20376-00 79-,¢'04 Potential recompletion in the Kuparuk C and/or B sand as a water injector. Decision hinges on 1994/95 development drilling results (E-13)in this area. MPB-02; 029-20662-00 81-/¢/1 42 This well is scheduled for initial completion in the Schrader Bluff late this year or early next year. MPA-03; 029-20891-00 83-~001 Future utility as a Schrader Bluff producer with producing utility when surface infrastructure is installed on A pad. MPN-01 B; 029-21053-02 84-0013 N-01B is a usable well in the Schrader Bluff, with producing utility when surface infrastructure is installed on N pad. The well should be retained in a suspended status until that time. MPC-16; 029-21364-00 85-0110 C-16 has recompletion potential in the Kuparuk "C" sand .and/or the Schrader Bluff horizons. Although additional evaluation must be performed to quantify reserves and production potential, C-16 is believed to be a viable workover and/or sidetrack candidate. NWM#1; 029-22231-00 91-0145 Northwest Milne #1 should remain suspended until the Northwest Milne Point development is better defined. The wellbore is strategically located on a gravel island and may possess utility in either production or injection operations. DNR recently certified this well as capable of production. No Point #1; 029-22450-00 94-0027 No Point #1 will be utilized in the upcoming F- Pad development. Expectations are to complete the Kuparuk "A" zone and commence production 4Q95. Niakuk #4, 029-21217-00 84-0200 Niakuk #4 is requested to remain suspended until the viability of the well for monitoring is defined. Niakuk #5, 029-21290-00 85-0027 Niakuk #5 should remain suspended for observation purposes at this time. Sag Delta #33-12-16, 029-201 76-00 75-0058 Area being drained by 1994 Alapah well NK-26 (HAW). Potential use as a monitor well for this new reservoir Would have to truck oil across winter ice road if resume production Produced 186 MBO in 1985 2 month production' test. Sag Delta #5, 029-20527-00 8O-O 129 Area being drained by L5-26 (high gas well), L5-28, and L5-36 from south to west. Well tests indicated fairly tight, but productive rock; perhaps inadequate stimulation? Costs prohibitive for eventual tie-in to L5 (? via Heald Point). Potential for gas cap monitor well Sag Delta 31-11-16, 029-20011-00 69-0014 Area being drained by L4-36, 80 Acre offset to NW. Potential for service well (water injection?) Well is capable of production, but most Lisburne in water leg and costs likely prohibitive for tie-in to L4. Sag Delta #2A, 029-20234-01 77-0069 South of Sag Delta #1, in water leg of Alapah oil accumulation in NK-26 well. Remote potential for pressure monitoring of Alapah offtake and the effect on the Alapah aquifer; though, costs would likely be prohibitive. Sag Delta #8, 029-20519-00 80-0121 Z-32A, 029-21924-01 93-0113 S-10A, 029-20765-01 91-0123 Sag Delta #8 should remain suspended until the development plan for the area is better defined. This well may possess utility for production or as an observation well. Z-32 was shut in due to high water production in 1992. In 1993 it was sidetracked to a new location. The oil column at the new location was less than prognosed and was not considered economic and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. S-10 was sidetracked in 1992. Drilling difficulties were encountered while drilling through a fault in the Kingiak and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. The West Sak formation, a non unitized formation in the PBU license area, is reachable from this wellbore. Work in ongoing on a facility sharing agreement. In the case that a satisfactory agreement is reached, this wellbore could be used to access oil in this formation. Y-22A, 029-21558-01 88-0115 Y-22 was sidetracked in 1988. The sidetrack was suspended due to drilling difficulties. There is oil in the region that can be reached as a new sidetrack from this well. A location has not been worked on but we wish to retain this wellbore for a future sidetrack. U-01, 029-22244-00 92-0011 There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. PR 33-12-13, 029-20047-00 69-0104 The well penetrates The West Sak and Ugnu formations in the aquifer. Work in ongoing on a facility sharing agreement with subsequent appraisal of the formations. This well could be used to test the aquifer properties. These wells are listed as suspended, action items are detailed. Ak Island #1,289-20018-00 81-0119 Alaska Island #1 was abandoned in 1988. The completion notice has been refiled with AOGCC on 9/15/94. The site is ready for inspection (priority 1 ). Niakuk #lA, 029-20156-01 76-0028 Niakuk #lA was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1 ). Niakuk #2A, 029-20180-01 76-0O79 Niakuk #2A was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). PBU H-01, 029-20099-00 71-0015 The well was drilled in 1971 and hit a down thrown fault block with only 20ft of oil bearing Ivishak. This was not economic at the time. It was left suspended without tubing. Recent success in fraccing the Sag formation indicated that it might be an economic well. A rig workover was completed in April 1994 and the well was put on production 9/94. It is not necessary to inspect this site. Kemik Unit #1,223-20006-00 70-0060 Kemik Unit #1 is scheduled to be abandoned in the near future. Abandonment planning is now in progress. Site inspection will not be necessary at this time most likely should be scheduled for Spring of 1995. P2-59, 029-22096-00 90-01 40 Arco Alaska Inc. is the operator of this well, they will be addressing the question of suspension. Sag Delta #3, 029-20233-00 79-0080 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. Sag Delta #4, 029-20245-00 77-0015 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. The following wells are not under BP Exploration ownership. A letter requesting the owners to respond regarding their wishes for these wells was sent on 9/30/94. MP 03-10-12, 029-20483-00 80-0066 MP 33-11-12, 029-20504-00 80-0092 CHEV 18-11-12, 029-20511-00 80-0108 Term C 03-11 - 12, 029-20356-00 78-0102 MP 22-31-11-13, 029-20545-00 81-0010 MP 43-31-11-13, 029-20536-00 80-0139 MP 30-11-13, 029-20546-00 80-0152 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David~ DATE: Chairman THRU: Blair Wondzell, ..~3~ FILE NO: P. I. Supervisor '~/z'e FROM: John Spaulding,&, SUBJECT: Petroleum Insp. ~;,l~A~ October 2, 1994 2991jbbd.doc Suspended Wells Inspection North Slope, Alaska .Oc. tober, 1,2&3, 199..4.: I accompanied Marian $1oan BPX representative on an inspection tour of BPX suspended wells at various North Slope locations. Travel was by pickup and helicopter. Marian Sloan Informed me that BPX is drafting a program with reasons for leaving wells listed below as suspended, this program will be available to the AOGCC in the very near future Oct. 1,1994 Y-22A / PBU / PTD 88-115;. well head on configuration, no pressure on tubing or annulus, area very clean, well is located on a producing drillsite. S-10A / PBU / PTD 91-123; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. U-01 / PBU / PTD92-11; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. Z-32A / PBU I PTD 93-113; wellhead on configuration, no pressure on tubing, 750 psi on inner annulus, 0 pressure on outer annulus, area clean, well is located on producing drillsite. Chevron 18-11-12 / PTD 80-108; wellhead on configuration, no pressure on tubing or annulus, area clean. MP 22-31-11-13 / PTD 81-10; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. MP 32-30-11-13 / PTD 80-152; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. Oct. 2, 1994: A-01 / MPU / PTD 79-40; wellhead is removed with casing hanger still on, area clean, well is located on a active drillsite. A-03 / MPU / PTD 83-01; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a active drillsite. B-02 / MPU / PTD 81-142; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite, C-16 / MPU / PTD 85-116;. wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. N-01B / MPU / PTD 84-13;. wellhead on configuration, no pressure on tubing or annulus, area clean with timbers covering the cellar area and well guard around the wellhead. No Point #1 / MPU / PTD 94-27; wellhead on configuration, area clean, unable to land helicopter to check wellhead for pressures, No Point #1 is scheduled to become part of the F- pad construction at MPU. NW Milne #1 / MPU / PTD 91-145; wellhead on configuration, area clean, island is suffering from severe erosion on the North side. Oct. 3, 1994: Sag Delta 31-11-16 / PTD 69-14; wellhead on configuration, area clean, has wooden location marker, no pressure on tubing or annulus. ..Sag Delta #3 / PTD 76-80; wellhead on configuration, area clean no pressure on tubing or annulus. Sa.q Delta ~4 / PTD 77-15; wellhead on configuration, area clean, no pressures on tubing or annulus. Sa.q Delta #2A / PTD 77-69; wellhead on configuration, no pressures on tubing or annulus, timbers and cellar box material, reserve pit open. Sa.q Delta #5 / PTD 80-129; no wellhead; bell shaped affair was covering the supposed well surface location, area clean. Sag Delta #8 / PTD 80-121; wellhead on configuration, timbers and well guard, island is eroding. · Alaska Island #1 / PTD 81-119; unable to land, area appeared clean from the air, marker post visible on South side of island. Niakuk #4 / PTD 84-200; wellhead on configuration, concrete river weights, cellars open, island eroding. · Niakuk #5 / PTD 85-27; wellhead on configuration, concrete river weights, cellars open, island eroding. Location Clearances; Niakuk #lA / PTD 76-28; area is clean, no visible marker post, island is eroding as planned. (;Niakuk #2A / PTD 76.-79; ..area -is-clean;--no-visible-marker-post; .island.-.is-eroding as planned. I recommend that the AOGCC consider Niakuk lA & 2A for final abandonment and location clearance. · Summary: I inspected locations of 28 BPX suspended wells. I also inspected 2 wells for final abandonment and location clearances. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 15, 1994 Steve Horton, Drlg Mgr BP Exploration (Alaska) Inc ? O Box 196612 (MB12-1) Anchorage, AK 99519-6612 Re: Suspended Wells Compliance with regulations Dear Mr. Horton: BP Exploration and the predecessor Sohio companies have several suspended wells as shown on the attached lists: BP SUSPENDED WELLS PRIOR TO 1980 and BP SUSPENDED WELLS SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above, or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as ~qu~ by 20 AAC 25.110(e), must have well site inspections ~is ye~o snow covering the locations. David W.{-..Johnston ~ ..... Chairman Attachments c: Blair Wondzell bew/llbpsusp '15/94 PERS~IT 79-0040-0 80-0066-0 80-0092-0 80-0108-0 80-0121-0 80-0129-0 80-0139-0 80-0152-0 81-0010-0 81-0119-0 81-0142-0 83-0001-0 84-0013-0 84-0200-0 85-0027-0 85-0110-0 88-0115-0 90-0140-0 91-0123-0 91-0145-0 92-0011-0 93-0113-0 94-0027-0 API NUMBER 029-20376-00 029-20483-00 029-20504-00 029-20511-00 029-20519-00 029-20527-00 029-20536-00 029-20546-00 029-20545-00 089-20018-00 029-20662-00 029-20891-00 029-21053-02 029-21217-00 029-21290-00 029-21364-00 029-21558-01 029-22096-00 029-20765-01 029-22231-00 029-22244-00 029-21924-01 029-22450-00 BP SUSPENDED WELLS SINCE 1980 AUGUST 1994 WELL WELL WELL NAME CLASS STATUS MILNE POINT UNIT A-01 EXP SUSP PRUDHOE BAY U~IT 3-10-12 DEV SUSP PBU MP 11-33-11-12 I DEV SUSP PRUDHOE BAY UNIT TR 18-11-12 DEV SUSP SAG DELTA 8 EXP SUSP SAG DELTA 5 EXP SUSP PRUDHOE BaY UNIT 31-11-13 DEY SUSP PBU MP 32-30-11-13 1 DEV SUSP PBU MP 22-31-11-13 2 DEV SUSP ALASKA ISLAND I EXP SUSP MILNE POINT UNIT B-02 DEY SUSP MILNE POINT UNIT a-03 DEV SUSP MILNE POINT UNIT N-01B DEV SUSP NIAKUK 4 EXP SUSP NIA~U~ 5 ~XP SUSP ~ILNE POINT U~IT C-16 DEV SUSP PRUDHOE BAY UNIT Y-22A DEV SUSP PT MCINTYRE P2-59 EXP SUSP PRUD~OE ~AY TJ~IT S-10A DEV SUSP NORTHWEST MILNE I EXP SUSP PRUD~OE ~AY U~IT U-01 D~V SUSP PRLTD~OE ~A~ UNIT Z-32A DEV SUSP NO POINT 1 DEV SUSP STATUS DATE 4/15/80 10/11/80 4/29/81 12/24/80 4/15/81 4/13/81 2/20/81 1118181 2/14/81 6/08/82 5/27/82 12/lO/83 4/27/84 2/17/85 4/18/88 lO/27/93 lO/29/88 12/22/9o 11/o6/91 3/30/92 3/16/92 8/31/93 4/08/94 S~ACT 23 33 33 07 27 36 05 30 30 11 19 23 30 25 25 10 33 14 35 25 18 19 06 TWP 131~ 11N 11N 11N 12N 12N 10N 11N 11N 10N 13N 13N 12N 12N 13N 12N 12N 11N 11N 13N 010E 012E 012E 012E 016E 01BE 013E 013E 013~ 022E 011E 010E 010E 015E 015E 010E 013E 014E 012E 009E 013E 012E 010E PAGE MER U U U U U U U U U U U U U U U U U U U U U U U '15/94 BP SUSPENDED WELLS PRIOR TO 1980 PAGE 1 AUGUST 1994 PERMIT 69-0014-0 69-0104-0 70-0060-0 71-0015-0 75-0058-0 76-0028-0 76-0079-0 76-0080-0 77-0015-0 77-0069-0 78-0102-0 API NI/MBER 029-20011-00 029-20047-00 223-20006-00 029-20099-00 029-20176-00 029-20156-01 029-20180-01 029-20233-00 029-20245-00 029-20234-01 029-20356-00 WELL WELL WELL NAME CLASS STATUS SAG, DELTA 31-11-16 EXP SUSP PRUDHOE BAY I/NIT 33-12-13 DEV SUSP KEMIK UNIT i DEV SUSP PRUDHOE BAY UNIT H-01 DEV SUSP SAG DELTA 33-12-16 EXP SUSP NIAKUK 1-A EXP SUSP NIAKUK 2-A EXP SUSP SAG DELTA 3 EXP SUSP SAG DELTA 34633 4 EXP SUSP SAG DELTA 28337 2-A EXP SUSP PRUDMOE BAY UNIT TER/V/ C DEV SUSP STATUS DATE 4/28/69 12/20/69 6/17/72 6/22/71 4/28/76 4/30/76 3/30/77 3/23/77 3/22/78 12/27/77 4/25/79 SECT 31 33 17 21 04 26 26 35 35 10 03 TWP llN 12N 01N 11N 11N 12N 12N 12N 12N 11N 11N RNG 016E 013E 020E 013E 016E 015E 015E 016E 016E 016E 012E MER U U U U U U U U U U U John R. Kemp Conoco Inc. Manager of Alaskan Operations 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 September 12, 1985 Harold Hedland Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hedland, Attached are completed 10-403 forms for Milne Point A-3, D-i, N-lB, L-I, M-lA and Gwydyr Bay State #2A. Ail of the above are classified as suspended wells. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the wells is suspended. Please contact Jim Dosch at (907) 564-7649 if you should have any questions. Very truly yours, John R. Kemp ~ ~ Manager of AlaSkan Cfperations RECEIVED Alaska 0JJ & Gas Cons, CommJssJorl Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL ~] OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 83-1 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, Alaska 99503 50- 029-20891 .. 4. Locatiom of We~ 1918' FNL, 1546' FEL, Section '23, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 56' KB 6. Lease Designation and Serial No. ADL 47437 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point A-3 11. Field and Pool Kuparuk River Field Upper Cretaceous 12. (Submit in Triplicate) Perforate [] 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). Request one year extension for a suspended well. 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 Milne Point Unit. Work to reactivate this well should begin in late 1986. EiVED Alaska Oil ~ Uas Coils. p. O0Bl~is~,i0ri Anch0ra!.~e 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. $igne~~ ~~'~ The space below for Commissio/use Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy Returned jo.q-g5 By Order of the Commission Date /o-"1-25 Form 10-403 R~.v_ 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 August 28, 1984 Ms. Frances L. Jones Alaska Oil and Gas Commission 3001 Procupine Drive Anchorage, Alaska 99501 Dear Ms. Jones, Please find enclosed two copies of the Milne Point Unit A No. 3 As Built. This data is being sent to you in fulfillment of A.O.G.C.C. Regulations and in response to your request. If you have any questions please call me at 279-0611. Yours very truly, Engineering Technician tt RECEIVED AUG 2 9198 Alaska Oil & Gas Cor~s. Commission ~nch.~rage N 0 R T H VICINITY MAP : / / / 1"=2 MILES* / / / // .~/.~ '$ /~~. ~/~~, NOTE "- I. '~ATE PLANE COORDINATES ARE ZONE 4. ~ / ~-~' / / ~ ~ / ~ ~7~* / ~ ~ 5~/ / ~ ~ ~ BA~D ON P~OTRACTED VAL'JES OF THE ~ Y , ~~~ ~ SE~ION COENER POSITIONS. LOCATION ,N ~vT!0N STATE PLANE C00RDS. GEODETIC POSITION A-~ ! l~17 I ~47 6,021,155.~J 56~,2,,.50 7~28 05.60 N 149 28~.60 334© Arctic .~ou!evard, Suite 201, Anchorage, Alaska 99503 SCALE iI.JO~ NO. I": :~00' 82024 i J , VED ,.,----.-' ,'__ L ' " --- ' THIS PLAT REPRESENTS A LOCATION SURVEY ll.l~l",~r~, eme''~'- -'~l?®®.'mr~/~ ~_ ~ MADE BY ME OR UNDE, MY SUPERV,S,ON. AND ~__. THAT ALL DIMENSIONS AND OTHER DETAILS ';~su,v~ ~0,: ~onoco) A PAD -- "-. ~ .-,-.. ~-- ;[Oll ( ;( Suspended Well and Location Report 20 AAC 25/ ARTICLE 2 ;~;: FILE INFORMATION: O:pera tor Address;¡.s r ¿) C ;qí[?e ;~~a;ioï/\\:¡el}S~ Ft. F G L seé.:2.i-, TJ3L.J,L, R-'-9L, ~M. Uni t or Field & '\ /2-JCJ.~8;3 e rm i t No. API No. 5OÙir-~~91 Lea se Name &¡/ We.. I.. vJell, No. hl- J' Pool I/7I/We., P , Condi tion of Pad bL condition of pits D.Pe~ , ~'lell head All outlets plugged § No Well s~gn - Attached to we I 1 head Yes No Attached to well guard ~ No Attached to Info roo tion correct @ No Cellar - OF€ned Yes No Ra tHole Op3n Yes No Filled @ No Filled Yes No Covered es No Covered ~ No Wa tert'¡ell - Plugged off Cappe d Open Explanation /1/J/J r Explana ton ~e \vork to be done to be acceptable -A)l)~e classified as 1 9 8.s- . Inspected by: Date: g -It --t<J . / Revi sed 8/24/82 (¡,:;,-'(r\/\\r~W~Q[t::~,!,'"",' OCt'" 1:1,) fR,) 2nn~)} ~JJvb'"'t!1 \1 ¡: '\'J &:.v...,; , r:. t, u) 'UI !J IJJ '- ~- . H. D. Haley Manager of Alaskan Operations Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 July 16, 1984 C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Procupine Drive Anchorage, Alaska 99501 Subject- Well Completion Report - MPU A-3 Dear Mr. Chatterton. EnClosed is the original and a copy of the subject report. Please refer any questions to Jim Fox at 279-0611. Yours very truly, H. D. Ha ley Manager of Alaskan Operations SHB/tt cc- A. E. Hastings, (4), w/attachment L. A. Dinges, W/attachment J. B. Fox, W/attachment Well File RECEIVED JUL ! 81984 Alaska Oil & Gas Cons. Commission~ Anchorage '-':~ STATE OF ALASKA ~ ,~ ALASK .)IL AND GAS CONSERVATION(. MMISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG } 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED ~X ABANDONED [] SERVICE [] / :2. Name of Operator 7. Permit Number ' Conoco Inc. 83-1 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 5o-029-20891 _ 4. Location of well at surface 9. Unit or Lease Name 1918' FNL, 1546' FEL, Section 23, T13N, RIOE, U.M. . Milne Point Unit At Top Producing Interval ~ LOCATIONS 10. Well Number 2191' FNL, 2778' FEL, Section 23, T13N, RIOE, U,~i~lvERIFIED,.~ A-3 At Total Depth 1 sur{"-~--''- 11.F,eld and Pool 2184' FNL, 2823' FEL, Section 23, T13N, R10E, U.II~..H.~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial ~-~ Upper Cretaceous 58' KB APL 47437 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 1-27-33 2-2- 83 12-10-83I -- feetMSLI one 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 5099~?-_ 4809' 4892' - 4602' YES ~ NO []I N/A feetMDI -----1800 22. Typ--~eCtric or Other Logs Run DIL-BHCS-SP-GR, NML, LDT-CNL-NGT, EPT, TUT, HL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 O' 115' 26" 345 sks. Permafrost S O' 13 3/8" 72# L-80 O' 2500' 17½" 2000 sks. Arco Fondu O' 500 sks. Permafrost 9 5/8" 47# L-80 O' 5095' 12¼" 950 sks. Class G O' 250 sks. Permafrost :& 130 BBL Arctic Production IMD+TVD of Top and B/ot~d 25. TUBING RECORD 24. Perforations open to ~¢N'~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 4016' -4049' Sqz, 125 sks. Cold Set ! Cem~ 4265' - 4290' Sqz. 75 sks. Cold Set T Cem~ "'~ 4694' ~ ~ 4657' - Acidize w/1500 gal. 15% HCL 2Z~I PRODUCTION TESTg£CEIVED D~ First Production I Method of Operation (Flowing, gas lift, etc.) See attachment No. 2 Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE ~)t~,~OILRATIO TEST PERIOD I1~ l~/~8~f~,~.k~ ~Ol~l~. Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCr WATER-BBL OIL GRAVI-~; 28. CDR E DATA · Brief description of lithology, Porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core No. Depth (MD) Recovery 'Lithology Frac. t.u. res& Dips 0il-Gas-H20 One 4117'-4147' 5.5' of 30' Unconsolidated Patchy Oil Stains Sand W/some Shale Horizontal w/tar Droplets Two 4289'-431.8' 11.6' of 29' Unconsolidated Abundant Black, Fine Grained Sand Tarry, Free Oil W/occassional Thin clay beds. Hurl zontal Three 4665'-4695' 12. ' of 30' Unconsolidated ............ Horizontal ,.Ratchy..-....,L,i .q_ht. ~.~t° Da~,.,; Pac nt nt k Form 10407 frown ~ ~ ~ca~d Rev. 7-1-80 CONTINUED ON REVERSE SIDE Sandstone w/Slightly Some Live Oil' 29. KA MA NA NB NC ND NE OA NAME GEOLOGIC MARKERS MEAS. DEPTH 4016 4265 4508 4536 4556 4575 4584 4665 TRUE VERT. DEPTH 373O 3978 4219 4247 4267 4286 4295 4376 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS Attachments 1, 2, and 3 See Attachment No. 2 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 og 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 (G L) 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". Form 10-407 Attachment No. 1 Completion Report - Milne Point A No. 3 Item No. 24 - Perforations Depth bm TVD -- ,, 4508'-4514' 4536'-4542' 4556'-4562' 4575'-4580' 4584'-4602' j4657'-4694' 4728'-4754' 4219'-4225' 4247'-4253' 4267'-4273' 4286'-4291' 4295'-4313' 4368'-4405' 4439'-4465' Perforated using Gearhart 5" hollow carrier with Super Pack charges at 12 JSPF. Hole entry diameter of .63 inches. Attachment No. 2 MILNE POINT A NO. 3 WELL COMPLETION REPORT AND LOG PRODUCTION TEST DATA Interval Tested (M.D.) Production Test No. 1 4657'-4694' Date of Test 8/2-4/83 Method of Operation Flow Hours Produced 30.5 Oil Produced (BBL) 177 Gas Produced (MCF) 29.9 Water Produced (BBL) 0.8 GOR (CF/BBL) 169 Choke Size 2" Flowing Tubing Pressure (PSI) 20 Flowing Bottomhole Press. 1700 (PSZO) Average Production Rates: BOPD 139 BWPD 0 MCFPD 24 Oil Gravity (°API) 18.6 * After gravel pack. LW = Load Water Production Production Test No. 2 Test No. 3 4657'-4694' 4657'-4694' 8/16-20/83 9/10-13/83 FloW Kobe * 118 89.5 1035 283 303.3 48.6 0 39 (LW) 293 172 12/64"-1" NA 70-80 NA NA NA 211 76 0 11 62 13 18.7 18.5 RECEIVED JUL 1 81984 Alaska 0/I & Gas Cons. Commission Anchorage Attachment No. 2 MILNE POINT A NO. 3 WELL COMPLETION REPORT AND LOG PRODUCTION TEST DATA Production Test No. 1 Production Test No. 2 Production Test No. 3 Interval Tested (M.D.) 4657'-4694' 4657'-4694' 4657'-4694' Date of Test Method of Operation Hours Produced Oil Produced (BBL) Gas Produced (MCF) Water Produced (BBL) ooR Choke Size 8/2-4/83 8/16-20/83 9/10-13/83 Flow FI. ow Kobe * 30.5 118 89.5 177 1035 283 29.9 303.3 48.6 0.8 0 39 (LW) 169 293 172 2" 12/64"-1" NA 70-80 NA NA NA Flowing Tubing Pressure (PSI) 20 Flowing Bottomhole Press. 1700 (PSIG) Average Production Rates: BOPD 139 BWPD 0 MCFPD 24 Oil Gravity (°API) 18.6 * After gravel pack. LW = Load Water 211 76' 0 11 62 13 18.7 18.5 RECEIVED JUL 1' 8 Alaska 0/I & Gas Cons. Commission Anchorage Attachment No. 2 MILNE POINT A NO. 3 WELL COMPLETION REPORT AND LOG PRODUCTION TEST DATA Production Test No. 7 Interval Tested (M.D.) 4508'-4754' Date of Test Method of Operation Hours Produced Oil Produced (BBL) Gas Produced (MCF) Water Produced (BBL) OOR (CF/BBL) Choke Size 11/9-18/83 Flow 206 3041 792 59 (LW) 200-354 -NA Flowing Tubing Pressure (PSI) 36-42 Flowing Bottomhole Press. 1284-1584 (PSIG) Average Production Rates: BOPD 355 BWPD 7 (LW) MCFPD 73 Oil Gravity (°API) 18.3 NOTE: Downhole pressures are reported at gauge depth. LW = Load Water RECEIVED JUL 8 Alaska Oil & Gas Cons. Commission Anchorage 1-24 1-25 1-27 1-28 1-29 1-30 WELL HISTORY Milne Point Unit A-3 Move rig f/A-2 to A-3. Rig up on A-3. Accept rig for operations @ 9:00 a.m. N/U diverter spool; mix spud mud & change shaker screens. Test diverter system & P/U BHA. Expect to spud between 6-8 p.m. POOH @ 1058', made 942'. P/U BHA. Spud @ 7:15 p.m. Drlg. f/l16' to 509'. POOH & L/D steel collars. P/U DynaDrill & Teleco co]_lar & TIH. Break circ., orient DynaDrill & ran survey. DynaDrill f/509' to 1058'. POOH & change bit. Survey - Dev: 2.6° S74.5W @ 607' 5.6° S72.3W @ 729' 9.2° S75.5W @ 850' 11.5° S74.4W @ 973' Drlg. @ 2084', made 1026'. TIH, break circ. & orient DynaDrill. Drill f/1058' to 2000', POOH & L/D DynaDrill. M/U packed hole BHA. Slip & cut drlg. line. TIH, spot ream to bottom, no fill. Drill f/2000' to 2084'. Survey - Dev: 14.4° S82.2W @ 1094' 18.2° S77.3W @ 1215' 21.9° S75.5W @ 1343' 25.7° S74.1W @ 1471' 29° S74.1W @ 1599' 31.6° S74.1W @ 1758' 35.4° S76.2W @ 1915' RECEIVED J U L 1 81984 Alaska Oil & Gas Cons. Commission Anchorage POOH @ 2529', made 445'. Drill f/2084' to 2529'. Circ. cond. mud; 15 std short trip. Bridge @ 2275', 25' fill; mix & pump hi-vis sweep around. POOH, L/D stabs. R/U & run 63 jts. 13-3/8" 72# L-80 Butt csg with B&W shoe @ 2500', B&W collar @ 2419'. R/U & run stab in tool on D.P. Stab into float collar & circ. Test lines to 3000#. Mix & pump 2000 sks. Arco Fondu cmt. @ 11.7 to 12.0 ppg, followed w/500 sks. Permafrost Class "C" cmt. @ 15.6 ppg.; disp. w/42 bbls. mud, 234 sks. Arco Fondu, returns to surface. Float held, cmt. mixed @ 7-8 bpm; disp. @ 6 bpm. C.I.P. @ 4:45 p.m. POOH w/stab-in tool. Yield of Arco Fondu - 1.92 ft3/sk. Survey - Dev: 36.1° S74.4W @ 2081' 34.4° $74.8W @ 2304' 33.7° S75.5W @ 2463' Depth - 2529'. Cmt. to 2500', made 0'. N/D diverter, tag cmt. 2' down; install slips; cut csg. & remove diverter; final cut csg. N/U 20" x 13-5/8" csg. spool, N/U BOP. R/U to test BOP, leaking between stack & csg. head. N/D, replace API ring, N/U BOP. Test annular to 3000#, pipe rams, blind rams, choke & kill manifold w/5000#. Test approved by State of Alaska. M/U BHA, TIH & break circ. Tag cmt. @ 2418', test csg. f/30minutes w/1500#. Drill cmt. 2418', float collar 2419', cmt. to shoe @ 2500'. Mud Wt. - 8.6# Visc. - 38 - l - QNFIDEHT_iA .: 1-31 Coring @ 4147', made 1618'. C.O. rathole to 2529', drlg. ahead f/2529' to 2555'. Circ. & cond. mud to 8.7 ppg. Shoe leakoff test: 470 psi w/8.7# mud = 12.6 ppg-EMW. Drill & survey f/2555' to 3798'. Circ. & cond. mud. POOH to shoe @ 2500', L/D 36 jts. D.P. Hole swabbing at times, circ. @ shoe. TIH, bridge or fill @ 3708', C.O. to 3798'. Drill f/3798' to 4021'. Circ. bottoms up. Measure out, correction 96'. Above fill was new hole; driller depth off, actual T.D. 4117'. L/D Teleco collar, P/U & dress core barrel. TIH w/core barrel, break circ. & drop ball. Cut core #1 f/4117' to 4147'. Surveys - Dev: 32.8° S76.2W @ 2564' 28° S78W @ 2723' 24.7° S79.4W @ 2850' 21.4° S79.4W @ 2978' 18.1~ S79.7W @ 3105' 15.6~ S81.8W @ 3230' 13° S83.9W @ 3357' 10.5° S85.3W @ 3486' 8.6° S89.2W @ 3614' 7° N89.4W @ 3742' 5.3° N85.9W @ 3965' 5.4° N88.7W @ 4061' Mud Wt. - 9.1# Visc. - 36 2-1 POOH @ 4665', made 518'. POOH w/core barrel, recovered core #1, 6' or 20% recovery. Redress core barrel, L/D same. M/U 12¼" BHA & TIH. Drlg. f/4147' to 4282'. Circ. following drlg. break & POOH. P/U core barrel & TIH to 4282'. Break circ., drop ball. Cored, no bottom. Bottom firms up @ 4289'. Core #2 f/4289' to 4318'. POOH w/core barrel, recovered core #2, 11.6' or 40% recovery. Redress core barrel, L/D same. M/U 12¼" BHA & TIH. Drlg. f/4318' to 4665'. Circ. drlg. break, & drop survey. POOH, recovery survey. Survey - Dev: 4° N81.5W @ 4589' Mud Wt. - 9.1# Visc. - 37 2-2 Circ. @ 5099', made 434'. POOH. R/U core barrel & TIH to 4665'. Break circ. & drop ball. Cut core #3 f/4665' to 4695'. POOH, rec. core #3, 12' or 40% rec. L/D core barrel. TIH, reamed core hole f/4665' to 4695'. Drld. f/4695' to 5099'. Circ. Drop survey, short trip, retrieved survey. Circ., mix magnetite & circ. Survey - Dev: 3~° N79~W @ 5036'. Mud Wt. - 9.1# Visc. - 42 2-3 Logging @ 5099'. Pump pill and POOH. R/U Schlumberger & log. Ran DIL-BHCS-SP-FR, NML, LDT-CNL-NGT, EPT. R/D Schlumberger Mud Wt. - 9.1# Visc. - 36 2-7 R/D, move rig off of "A" pad. THIS WELL WILL TEMPORARILY BE DROPPED FROM THIS REPORT UNTIL TESTING IS STARTED AT A LATER DATE. - 2 - 7-27 7-28 7-29 7-30 7-31 8-1 8-2 8-3 8-4 8-5 Move in and assemble rig. Mix 486 bbls., 9.2 ppg brine. Remove FMC spool, TIH w/20' tbg. Circulate diesel to tank. Dress up csg. POOH. Install FMC spool, pressure test to 3700 psi 10 min. Install. spool and BOP's. Change out rubbers on 3~" rams. Pressure tested BOP's. Hydrill rubber split at 1800 psi. Pressure tested BOP'$ and manifold to 2500 psi. TIH w/8~" csg. scraper and 53 jts. tubing. TIH, tag fill @ 4988' KB. Mix 10 bbls. HEC pill. Reverse pill & 490 bbls 9.2# filtered brine. Solids in samples on spin-outs were too minute-to get accurate percentage. POOH~ Working on Hydril. Replace Hydril rubber. Pressure test Hydril to 2500 psi. R/U Gearhart & pressure test lubricator to 1000 psi. Run CBL-VDL-CCL-Gamma Ray. Est. cement top 2814' KB. R/U to run perforating guns. Close Hydril to test lubricator, no pressure on Hydril. Water in hydraulic reservoir, seals on Hydril leaking. Repair Hydril & accumulator and test. R/U bubble tester. RIH w/GO wireline & perf'd f/4665'-4694' (DIL) w/5" Superpack @ 12 spf. Fluid level @ surface. M/U DST string & run 915' in hole. Secured well for night. Opened up well, standing full w/0 psig. RIH w/DST string & 2500' diesel cushion. Set pkr. @ 4635'. R/U flow cross & tied in to test system. Opened tubing string, slight blow. Released annular pressure to close DST string & RIH w/Otis wireline. Verified location of tool string depth. Opened tool string & tagged fill @ 4965'. POOH w/wireline & R/U to swab. Well began flowing diesel cushion with oil to surface @ 1640 hrs. Continued flowing well. After cleanup, 9 hr. average: 150 bopd, 3 bwpd, .1% B.S. Flowing wellhead temp. ranges 320-29° w/29 psig wellhead pressure, gravity 19°API. Flowed 88 bbls. in 15 hrs. at an average rate 140 BOPD, gravity 18.4° @ 60. TP-20 psi. Turned in to separator, raised TP to 40 psi. Flowed at a rate of 110 BOPD to 120 BOPD for 4 hrs., GOR 147. Shut well in for bottomhole pressure build-up. Ran Schlumberger to obtain bottomhole sample. Made 2 runs, could not get below 2000 feet. RDMO Schlumberger, no samples obtained. Ended buildup and circ. out oil & gas w/filtered brine. POOH & L/D DST tools. Run 10 stds. in hole. R/U Otis wireline & tagged fill @ 4955'. POOH w/slickline & secured well. Opened well, on vacuum. Fluid level approx. 110' from surface. POOH w/kill string. RIH slowly w/Baker pkr. on workstring. Set @ 4583', tested backside 500#/5 min., O.K. Released f/pkr. & POOH. Changed BOPE to 4~" rams & tested BOP stack. P/U & RIH w/4%" kill string. - 3 - £ONFIDEN_T. IAF 8-6 8-7 8-8 8-9 8-10 8-11 8-12 Opened well, fluid level @ surface, no psi. Adapted H.P. gauge to mandrell carrier. RIH w/BHA & H.P. gauge. Lost signal at approx. 300', POOH. Tallied pipe, prepared to run 4~" & 2-7/8" strings, cleaned threads & assembled wellhead equipment. M/U BHA per program including two 0-4000# Amerada gauges & one 0-250° gauge. P/U 4~" BTRC tbg. & RIH to pkr. assembly @ 4583'. Tagged "slick stick", spaced out, landed tbg. & installed BPV. Changed pipe rams & racked 2-7/8" tbg. Prepare to raise righ working floor to accomodate intermediate spool. Well on vacuum; fill hole w/2 bbls., raise table. N/D BOP's, install FMC intermediate spool. Test spool to 5000 psi, N/U BOP's, retrieve B.P.V. Change over to run 2-7/8" tbg., tally, drift. TIH w/BHA & 116 jts. 2-7/8 Hydril. Close in well. Well dead; pump 8 bbls. to fill casing. TIH w/remaining 2-7/8" Hydril. Space out, sting in with locator sea]. assy. Pressure test 4~" x 9-5/8" annulus to 1000 psi. Install BPV. Circ. 26 bbls. diesel down 2-7/8" tbg. Land tbg. hanger. N/D BOP's & N/U wellhead. Test wellhead to 5000 psi. Retest 4~" x 9-5/8" annulus to 1000 psi. R/U lubricator to retrieve BPV. Retrieve BPV & install stabbing valve. Shut down rig. R/U circ. lines from Kobe system. Circ. out 273 bbls. 9.2# brine water with fresh water down 4~" up 9-5/8". Continue circ. w/180° fresh water. Tie in flowline from 2-7/8" tubing on wellhead to separator. Open well. Flow testing to prod. tank bypassing separator. Recovered 10.6 bbls. diesel, well died. R/U swab line and lubricator. Start swabbing. Swabbed back a total of 25 bbls. diesel, turn to water. Swabbing back 100% 9.2# brine water. Shut down rig. Left well open to production tank. Resume swabbing. Fluid level at 400', good gas blow on bleeder hose. First swab run 80% oil, 20% water. Remaining swab runs 98% water, 2% oil. Water recovery 43 bbls. Circ. with Kobe pump 38 gpm down 4½" up 9-5/8". Temp in 154°, return 112~. Flow line temperature 92~ during swabbing operations. Swabbing. High percentage water, emulsified fluid. Shut down swabbing, checking to see if well will flow. Did not flow. Resumed swabbing. Swabbing heavy, emulsified fluid. Water cut decreasing. Shut down swabbing. Left well open to prod. tank. Resumed swabbing. Flowing well to prod. tank, well surging. Swabbed and flowed 74 bbls. oil and 103 bbl. load brine (92,000 ppm chlorides) in 30 hours. Well now flowing and heading. Last cut 9% water. Flow testing well. Well died, resumed swabbing with intermittent flowing periods. Flowing well. Swabbing, shut down fresh water circulation. Flow testing well. Flow rate averages range from 0 to 370 BPD w/water cuts ranging from 0-8%. Wellhead PSI 20, temp. 50°. -4- 8-13 8-14 8-15 8-16 8-17 8-18 C I:I D E'N'!IAL Continue flow testing well. Discontinued annular circulation of wellbore to let water coo]. down. Trying to establish stable oil flowing temp. Circ. annulus; shut down annulus circulation. Continue circulating remainder of day. Flow rates are ranging from 225 BOPD to 375 BOPD with zero water cut and a trace of B.S. TIH w/H.P, gauge set at 4562' K.B. Decrease in oil flow while TIH w/H.P, gauge. BHP 1400 PSI. Start decreasing choke setting to increase BHP. Samples - 100% oil, 0% water, Trace B.S. Well shut in. Recording BHP buildup 1715 PSI. Circ. water in 135°, out 95°. Well shut in, recording BHP, build up 1718 psi. POOH w/HP gauge. R/U Schlumberger & run fluid sampler: Run #1 - Gradient section of tool failed w/ sampler @ 4630', flowed well 6.8 bbls. & took sample, BHP 1729 psi; rec. 650 ml water w/90,O00 chlorides; Run #2 - Gradient section of tool failed, w/sampler @ 4603', took sample, BHP 1745 psi, rec. 650 ml oil, 0 water, trace BS; Run #3 - water/oil interface @ 4622' w/sampler @ 4603', took sample, BHP 1748 psi, transferred sample under pressure to D.O.T. container; Run #4 - water/oil interface @ 4622' w/sampler @ 4603', took sample, BHP 1748 psi, transferred sample under pressure to D.O.T. container. R/D Schlumberger. Flow well, initial wellhead pressure 75 psi, choke 12/64", press. 140-160 psi, temp. @ flowline 100~; 100% oil, 0% water, trace BS. 36 bbls. produced in 5 hours. Calculated rate - 174 BOPD. R/U to fill separator. Flow testing well. R/U & RIH w/HP gauge to 4570'. Wellhead pressure: 70-80 psi; flowline temp: 80°-90°. Samples: 100% oil, 0% water, tr % BS. BHP: 1630 psi decreasing to 1487 psi. Total fluid volume 180 bbls. last 24 hours. Shut down Roll'n camp. Choke Size Rate 12 145 16 230 20 290 24 300 28 Not Available Yet Flow testing well w/HP gauge @ 4570'. BHP: 1520-1470 psi; Wellhead Press: 60-80 psi; flow].ine temp: 120°-85°F; Samples: 100% oil, 0% water, tr % B.S. Total produced fluid last 24 hours: 218 bbls. Choke Size Rate GOR 24 270-200 175-200 Flow testing well w/HP gauge @ 4570'. BHP: 1495-1515 psi; wellhead Press: 75-80 psi; flowline temp: 85°-90°F. Samples: 100% oil, 0% water, tr % B.S. Total produced fluid last 24 hours: 178 bbls. Choke Size Rate GOR 24 190-205 175-200 -5 - 8-19 8-20 8-21 8-22 8-23 8-24 8-25 ONI:ii).£N_TIA Flow test well w/H.P, gauge @ 4570'. BHP: 1495-1440 psi Wellhead Press: 75-80 psi Flowline Temp: 85°-90°F Rate: 220 BPD GOR: 230 Choke Size: 24 Samples: 100% oil, 0% water, Trace-BS BHP 1440 psi dropping to 1410 psi. Ail surface pressures, temps., rates, & GOR increasing. BHP: 1410-1320 psi Wellhead Press: 175 psi Flowline Temp: 98° Rate: 343 BPD GOR: 390 Choke Size: 24 Samples: 100% oil, 0% water, Trace-BS Total produced fluid last 24 hrs: 258 bbls. Flow test well w/H.P, gauge @ 4570'. BHP: 1293 psi building to 1446 psi Wellhead Press: 170 psi dropping to 0 Flowline Temp: 90°F Rate: 219 BPD average GOR: 293 average Choke Size: 24, @ 0330 open to 28, @ 0345 open to 64 Samples: 100% oil, 0% water, Trace-BS Well died @ 0400 hrs, observed no flow & shut well in f/buildup @ 0445 hrs. Well shut-in, BHP: 1446 psi building to 1490 psi. Total produced fluids last 24 hrs: 201 bbls. Well shut-in f/buildup. BHP 1490 psi to 1657 psi. Well shut-in f/build up. BHP: 1657 psi increasing to 1723 psi Tubing Press: 160 psi Continue pressure buildup survey. BHP: 1759 psi Final recorded BHP 1760 psi. POOH w/H.P, gauge. Wait on rig crew to arrive. Well shut-in. Opened well to stock tanks. Flowed 30 bbls. on 24/64" choke @ 80 psi. Initial tbg. psi = 200#. Shut well in. Wait on crew to arrive. Begin rig operations @ midnight. Pumped 25 bbls. brine down 2-7/8" tbg @ 100 psi. Installed BPV & ND tree. N/U BOPE & recover BPV. 8-26 8-27 8-28 8-29 8-30 8-31 9-1 POOH & L/D 2-7/8" tubing. Installed 4~ BPV & N/D intermediate spool. N/U BOPE & changed rams. POOH & L/D 4~" tbg. & breakdown tools. Changed BOP rams. RIH w/3½" workstring, latched on Baker FHL pkr, released & begin POOH. Finish POOH w/Baker FHL pkr. Lost additional 20 bbls. brine 8.9 ppg. RIH w/workstring open-ended & tagged fill @ 4982'. Lost approx. 100 bbls. brine in 10 min. Spot 10 bbl. HEC pill @ 4630', POOH. R/U GO & made gauge ring run. RIH w/Dowell Model 18 sump pkr. & set 4698'. Mix brine & prepared to RIH w/gravel pack equipment. M/U gravel pack screen & blank & RIH. M/U gravel pack screen & RIH on 3~" workstring. Spaced out, selected & marked pkr. positions. Acidized workstring. Scoured tbg. with sand/gel pill & circ. clean. Disp. tbg. w/filtered 9 ppg. brine. Mixed gravel pack slurry. Pumped 15.6 bbls. slurry & displaced w/45 bbls. filtered brine. Attained screen out pressure of 1500#. Standby. Tested pack to 1500#, o.k. POOH w/3~" workstring, Dowell running tool & washpipe. L/D Dowell packer & 2-1/16" Hydril. Change over to run dual. string. Fill hole with 18 bbls. brine. R/U Weatherford equip- ment. TIH w/14 jts. 2-1/16" Hydril. TIH w/Kobe pump cavity 700' of 4~" & 2-1/16" tbg. - 2-1/16" tbg. x-over parted. POOH & replace x-over. Fill hole w/16 bbls. brine. P/U & TIH w/2400' of 4~" butt. tbg. & 2-1/16" Hydril tubing. Fill hole w/10 bbls. brine. Approx. 40 bbls. brine lost to formation last 24 hours. Continue TIH w/dual tubing string. Tag top of packer w/Kobe cavity @ 4294' KB. String weight 60,000#, puli_ weight 84,000#. Space out tubing. Load 4~" & 2-1/16" tubing with brine, pressure test to 500 psi. O.K. land tubing, 2-1/16" tail pipe set @ 4716' K.B. Bottom Kobe cavity set at 4284' K.B. R/D Weatherford Equipment. N/D BOP. Add FMC concentric spool. N/U BOP. Change over to run 2-7/8" tubing. Tally pipe. Tested FMC spool to 5000 psi, O.K. TIH w/2-7/8" CS Hydril tubing. Tag top of pup joint @ 4250' K.B. Total of 24 bbls. brine used to fill hole last 24 hours. Space out, screw into 2-7/8" pup joint, puli. test 5000# over string weight, land tbg. N/D BOP. Install FMC wellhead & pressure test to 5000 psi. O.K. Retrieve BPV. Install lines to wellhead. Pressure test tbg. 1000 psi. Pump 24 bbls. fresh water "Power Fluid" down 2-7/8" tbg. R/U Kobe lubricator w/Kobe jet pump 7A inside. Pump jet pump down 2-7/8" tbg. seat in Kobe pump cavity. Start test. Continue testing well w/Kobe pump. 2% oil, 98% water, no B.S. Chlorides 17,000. Fluid recovered 244 bbls. water,, 5 bbls. oil in 13 hours. Continue test with Kobe jet pump. Rec. 33 bbls. produced fluid, 1% oil, 99% water, no B.S. Chlorides 12,600. Last hour power fluid & production rates equal, indication of jet pump malfunc- tion. Shut down test. Pump Kobe jet pump to surface. Inspect Kobe jet pump, O.K. Indication of plugged standing valve. R/U - 7 - 9-2 9-3 9-4 9-5 9-6 9-7 CONFI'DEN!!AL sandline. TIH w/Kobe retrieving tool. Did not retrieve standing valve. Bull nose on retrieving tool indicated tool was not entering standing valve completely. Remodified too].. Made 5 more trips with modifications on tool, did not retrieve standing valve. Pump Kobe jet 7A down tbg. into pump cavity. Pump pressure 2300 psi, had returns, pressure dropped to 500 psi. Pumped pump in and out of cavity several times. Still could not get pump pressure above 500 psi. Retrieve Kobe pump. Circ. down 4~" tbg. up 2-7/8" tbg. Circ. power fluid down 4~" returns 2-7/8". Drop Kobe jet pump. Seat in cavity pressured to 1500 psi, dropped to 1000 psi. Retrieve pump. R/U swab equip. Swabbing, getting good entry through standing valve. Rec. 105 bbls. water. Fluid level last run was at 3100'. R/D swab. TIH w/Kobe retrieving tool. POOH w/standing valve. Repair, TIH, seat standing valve. Fill tubing strings w/42 bbls. power fluid. Drop jet pump, seat pump in cavity. Could not get over 1000 psi; retrieve pump. Weight up brine to 9.1# ppg. Circ. around 300 bbls. brine. TIH w/bull-nosed shear assembly. Shear out equalizing plugs in standing valve. POOH. Remove FMC wellhead, install BOP's. Unland 2-7/8" tbg. P/U on tbg, did not gain weight over pickup weight' of 40,000#. Shear pins on shear out assembly already sheared. POOH w/2-7/8" tbg. N/D BOP's. Remove FMC concentric head. N/U BOP's, install 4½" - 2-1/16" rams. R/U Weatherford equipment. Close well in. Rec. 60 bbls. less fluid than amount circulated to kill well. Unland 2-1/16" & 4~" tbg. POOH w/3000' of tbg. Shut well in. POOH w/remaining dual string. L/D Kobe pump cavity. Remove x-overs and pup joints on cavity and put on second cavity along with bottom half of J-latch assembly. Wait on modifications to be done on 5~" pup joint. TIH w/pump cavity and 800' of dual tubing string. Shut well in. It took 30 bbls. of brine over displacement of tubing strings to fill hole. Continue to TIH w/dual production string. Pressure testing tubing to 1000 psi every 1000' w/3800', pressure bled off. Torque up tubing strings. Re-test, pressure still bleeding off. Shut well in. TIH w/Kobe retrieving tool on sandline. Retrieve standing valve. POOH, repair standing valve. TIH & seat standing valve. POOH. Ball in standing valve was partially fluid cut and small amount of sediment inside standing valve. Pressure test to 1000 psi. Still bleeding off slowly. POOH w/7 jts., found loose collar. Pressure to 1000 psi., held O.K. TIH w/remaining tubing. Pressure testing to 1000 psi, held O.K. Install tubing hanger & FMC BPV, land tubing. Tailpipe set at 4716', bottom Kobe cavity set @ 4284'. N/D BOP's, N/U FMC concentric head. N/U BOP's. Test FMC head to 5000 psi, O.K. Change over to run 2-7/8" tubing. -8 - 9-8 9-9 9-10 9-11 9-12 9-13 9-14 9-15 COHFID£H!!AL Well dead. TIH w/top section of J-latch assembly and 2-7/8" tbg. Space out & install FMC BPV. Latch into bottom assembly, ].and tbg. N/D BOP's. Install FMC wellhead. Pressure test to 5000 psi, O.K. Remove BPV. Instal]. flowlines to wellhead & pressure test same to 2500 psi. Circ. 54 bbls. power fluid. Drop Kobe 7A jet pump. Pump to bottom, pump in cavity. Pressure increased to 2500 psi. Begin testing well. Testing well with Kobe 7A jet pump. Power Fluid Discharge - 2500 psi; Power Fluid Temp. - 150°; Prod. Return Temp. - 128°; Total Produced Fluid Recovered - 240 bbls. Water; 100% water, trace oil in 12 hours. Fluid level @ 5:00 a.m. - 1800'. Continue testing w/Kobe 7A jet pump bypassing separator. Triplex Pump Pressure 2450 psi, power fluid temp 122°, commingled fluid temp 114° csg. psi 58, fluid level 2523' from surface. Total net volume produced last 24 hours - 150 bbls., 5% oil, 95% water, Tr. B.S., chlorides 6860 ppm. Continue testing w/Kobe jet pump 7A, net volume produced 11 bbls. Retrieve jet pump w/sandline. Repair surface lines. Drop piston pump, pump to bottom, seat in cavity begin piston pumping. Testing w/Kobe piston pump. Triplex pump pressure: 1800 psi; csg. pressure: 40 psi; fluid level: 3721' from surface 5:30 a.m.; samples: 82% oil, 18% water, Tr B.S. Average rate: 102 BOPD, 24 BWPD, chlorides 55,500 ppm. Continue testing w/Kobe downhole piston pump. Total produced fluids last 24 hours through separator: Oil 69.6 bbls., water 25.5 bbls., chlorides 41,800 ppm, fluid level 3970', triplex discharge psi 1900, power fluid temp 126°, power fluid rtn temp. 94°, produced fluid temp 108°, GOR 177. Crew released and rig on standby as of 9-12-83. Continue testing w/Kobe piston pump. Fluid level from surface 3904'. Production last 24-hours: 63.3 bbls. oil, 7.9 bbls. water, 9.9 MCF (22~ hr.), 166 GOR (22% hr.) 36,100 ppm chlorides. Power fluid lost - 8.3 bbls. Continue production test w/Kobe pump. Production rates (24-hour rates on 17 hours run): 68.2 BOPD (48.3 - 17 hrs.), 10.3 BWPD (7.28 - 17 hrs.). Power fluid loss (17 hrs.) - 5.92 bbls. Last chlorides - 34,000 ppm. Power fluid returns appeared in produc- tion system & none up 2-1/16" string. Pressure tested strings, communication apparent between 4~ & 2-7/8" strings. Pumped Kobe pump out of hole & checked on surface, O.K. Circulating power fluid in production strings while waiting on rig crew. Fluid level @ 7 a.m. - 2495' from surface @ 5 psi. Circulating power fluid. Temperature in 180°, temperature out 54°° -9- 9-16 9-17 9-18 9-19 9-20 9-21 _QNFIDENTIAL Fluid Levels: Time Feet to Fluid WHP 0720 2495' 5 psi 0930 2435' 5 psi 1130 2346' 5 psi 1330 2228' 5 psi 1430 2197' 5 psi 1630 2197' 5 psi 2130 1901' 5 psi 0530(9-16) 1723' 5 psi Roll'n crew on location. Operations to begin 0700 on 9-16. Set 2-7/8" BPV and N/U BOPE. Confirmed 2-7/8" was ].atched into Otis assembly. Released "J" latch & circ. 9.1#/gal. down 2-7/8" & around 4½". POOH w/2-7/8" tbg. Ail o-rings (4) gone from latch, otherwise no signs of washing. Delivered "J" latch to machine shop for modifications. Prepared rig equipment for swabbing operations. RIH w/Otis "J" latch tool modified w/Chevron rings. Unable to latch into recepticle. POOH. Re-modified "J" latch to shorten length of sealing section. RIH w/latch tool & latched into recepticle. N/D BOPE & N/U tree. Swabbed load water & oil to stock tanks. Took approx. 120 gal. clean untreated oil samples. Total fluid rec. - 73 bbls. RIH w/sandline & pulled standing valve from Kobe cavity. Run Kobe "Blanking Tool" into cavity & pressured up on 4~" tbg. to 1000#, O.K. Fluid level in annulus - 1574' to fluid. Filled annulus with oil. from stock tanks & prepared lines for acid job. R/U Dowell for acid job. 9-5/8" annulus full with oil. Spot potassium chloride to end of 2-1/16" tailpipe, close in 9-5/8" annulus; pump remaining potassium chloride, total 71 bbls. @ 1 bpm & 900 psi. Pump 1500 gals. 15% HCL @ 1 bpm & 1000 psi. Displace w/30 bbls. diesel @ 1 bpm & max. of 1500 psi. Shut well in, R/D Dowell. Let acid soak. R/U swab. Swab back total of 115 bbls. Last run 20% water, 80% oil, PH 4. Shut down swabbing operations due to darkness. Left well open to slop tank. Fluid level 1400' from surface last run. Resume swabbing @ daylight. Fluid level 1200' from surface. Continue swabbing operations. Swabbing oil & acid & water to slop tank. Swabbed back 171 bbls. total. Fluid level @ 0600 hrs - 1200'; fluid level 1900 hrs - 2700'; last grind out - 12% water, 88% oil, PH 5. Resume swabbing operations. Fluid level @ 2400'. Continue swabbing operations. Swabbing oil, water & acid to s].op tank. Total recovered - 76 bbls. in 7 hrs. Fluid level @ 0600 hrs. '2400', @ 0800 hrs. 1700', @ 1300 hrs. 3000'. Grind out - 10% water, 90% oil, 4.5+ PH. TIH w/fishing too]., retrieve blanking tool & POOH. TIH w/standing valve, seat S.V. in seating nipple & POOH. Fill tbg. strings w/42 bbls. power fluid. Drop Kobe piston pump & pump to cavity w/23.4 bbls. power fluid. Start pumping w/piston pump by-passing separator. Power fluid & production fluid going to production tanks. Turn production & power fluid - 10 - 9-22 9-23 9-24 9-25 9-26 FIDEN I'i_AL into separator. Total production produced with piston pump - 87.8 bbls. Power fluid pumped - 225.2 bbls. Fluid level @ 0530 hrs. - 3720'. Note: Fluid level before dropping piston pump - 2494', csg. psi - 110. Continue production test with Kobe piston pump. 0600-1200 hrs. power fluid return going through separator. 6-hour meter reading total - 41.4 bbls. oil, 95.0 bbls. water. 1200-0600 hrs. produc- tion fluid only going in separator. 18-hr. meter readings: 70.4 bbls oil = 94 BOPD, 1.2 bbls. water = 1.6 BWPD. Fluid level: 0200 hrs. - 3720' pumping 38 SPM; 0530 hrs. - 3779' pumping 44 SPM. Produced fluid temp - 116°, csg. psi - 30. Before separator grindouts - 98.2% oil, .5% water, 1.3% emulsion. After separator grindouts - 99.3% oil, .0% water, .7% emulsion. Gravity 18.1 @ 61°. Released rig crew and support personnel. Continue production test with Kobe piston pump. Fluid level at 0530 - 3801', pump strokes - 56 SPM, power fluid discharge - 2000 psi, power fluid temp - 132°, power fluid return temp - 82°, production return temp - 104°, csg. pressure - 25 psi. Before separator grindouts: 85% oil, 13% water, 2% emulsion; after separator grindouts: 99% oil, 0% water, 1% emulsion. Separator meter readings: 78.3 BOPD, 14.6 BWPD. Tank strap measurements, total fluid 91.34 bbls. Power fluid lost in 24-hours - 9.45 bbls. Continue production test with Kobe piston pump. Fluid level at 0530 - 3861', pump strokes - 54 SPM, power fluid discharge - 2000 psi, power fluid temp - 134°, power fluid return temp - 96°, production return temp - 112°, csg. pressure - 25 psi. Before separator grindouts: 81.0% oil, 17% water, 2% emulsion; after separator grindouts: 99% oil, 1.0% water, 0% emulsion. 0530 hrs: chlorides 26,000 ppm. Separator meter readings: 78.9 BOPD, 13.3 BWPD. Tank strap measurement, total fluid - 85.83 bbls.. Power fluid lost in 24-hours: 8.7 bbls. Continue production test with Kobe piston pump. Fluid level - 38.31' from surface; produced oil: 74.7 bpd; produced water: 12.9 bpd; power fluid loss: 7.9 bbls. Tank straps show fluid gain of 78 bbls. Triplex data: Strokes/Min - 54, discharge - 2000# @ 134°, return (PF) - 40# @ 94°, production - 32# @ 110°. Grindouts @ 0600 hrs. (9-26-83): before separator - 84% oil, 15% water, 1 emulsion; after separator: 99.2% oil, .1% water, .7 emulsion; chlorides: 28,000 ppm (slight rise over prior test). Continue testing with Kobe piston pump. Fluid level - 3891'; produced oil: 75.75 bpd; produced water: 12.5 bpd; power fluid loss: 9.96 bbls. Tank strap - 79.27 bbls total. Triplex data: Strokes/Min - 54, discharge - 1200 psi @ 134°, return (PF) - 15 psi @ 98°, production - 33 psi @ 106°. Grindouts @ 0500 hrs. (9-27-83): before separator - 83% oil, 14% water, 3% emulsion; after separator: 99.2% oil, 0% water, .8% emulsion; chlorides: 18,500 ppm @ 2100 hrs, 17,200 ppm @ 0100 hrs (9-27), 23,400 ppm @ 0500 hrs. R/U to pump Kobe piston pump to surface. Roll'n crew on location. -- ll -- 9-27 9-28 9-29 9-30 10-1 10-2 10-3 10-4 TIH w/sand line & recovered Kobe piston pump. RIH to recover standing valve, lost portion of pulling tool. Recovered standing valve on third run. Circ. brine through production strings. Set 2-7/8" FMC BPV & N/D tree. N/U BOPE. Release 2-7/8" Otis "J" latch & POOH. Set 4½" FMC BPV & N/D BOPE. Removed intermediate spool & N/U BOPE. Changed rams to 4% x 2-1/16 blocks. Note: 720 bb!s. 9.0#/gal brine mixed & filtered through D.E. filter to fill brine tanks & rig tanks. R/U Weatherford dual slips & elevators. Kill well w/9.0#/gal. filtered brine. POOH w/dual string breaking out pup jts. in 4~" string. L/D 2-1/16" & 4~", pulled 2346', secured well. Continue POOH w/4½" & 2-1/16" strings. L/D Weatherford dual string equipment & changed to 3%" BOPE rams. RIH w/Dowell "BA" plug on 3% btrs. Located Dowell pkr. @ 4294'. Snapped in, sheared off & tested to 1000#, o.k. Circ. hole clean w/filtered brine 8.8#/gal. Pulled 10 stds, secured well. Finished POOH w/3~" workstring. R/U GO Int'l. & perfed 4268'-4288' w/5" superpak 12 spf. POOH. Fluid level @ surface. M/U Halliburton DST string. RIH 2000' & fill w/diesel. Finish TIH w/3~" workstring. Fill w/diesel. Set RTTS packer, @ 4135'. Pressure test annulus to 800 psi. R/U flowline to tbg. Pressure annulus to 1750 psi, open Halliburton LPR valve. Small blow at surface, liquid to surface 20 minutes. Checking for flow. R/U to swab, pull 400' of fluid per run, second to last run fluid level @ 3100'. Last swab run could not get past 3300' due to heavy viscous fluid. Swabbed back 34.65 bbls. Left well open to production oil tank, strong blow on tbg. Last grind out: 61% oil/diesel, 32% emulsion, 6% water, 1% heavy emulsion, no sand. Well open to production oil tank, small blow on tbg. Made I dummy run w/sinker bars to 2700', fluid level @ 1900'. Made 3 swab runs, slow entry due to heavy viscous oil. Depth of swab run into fluid - 150'-200' each run. Rec. total of .78 bbls. fluid. Fluid level last run 2000'. Spinouts: 72% oil, 25.5% water, 2.5% sediment. Chlorides: 56,000 ppm. Gravity: 12.1° G1 84°F = 11.0° W 60°F. Well open to production oil tank, no blow. Bled off annulus pressure, closed LPR valve. Recording BHP buildup. Continue shut-in for BHP buildup. Open bypass valve, had strong blow after opening. Filled annulus w/3% bbls. brine, pressured up to 8000 psi, left pressure on annulus, 150 psi drop in 2 hrs. Increased pressure at 100 psi increments, at 1150 psi broke circ., pressure dropped to 50 psi, reverse circ. oil to separator. While closing bypass valve, packer released-end of BHP buildup at 1730 hrs. Reset packer & tested annulus to 500 psi. R/U swab, swabbed down to 2300'. Chlorides - 44,200 ppm; grindout - Oil 56%, Water 42%, Sediment 2%; gravity - 13.3 @ 86°F = 12.0° @ 60°F. Swabbed fluid down to 4000'. Pressure annulus to 1500 psi, open APR valve, had slight blow at surface immediately after valve -19- 10-5 10-6 10-7 10-8 10-9 opened. Estimated entry into tbg. in 5 hrs. 1259' or 10.95 bbls. Pressure annulus to 3500 psi. Opened Halliburton circ. valve & begin reverse circ. fluid out of tbg. Initial fluid at surface after pumping 24.2 bbls, had slight trace of oil. Remaining fluid in tbg. was water with chlorides, count @ 62,700 ppm. Reverse circ. total of 400 bbls. of 120° brine water. Release RTTS packer, POOH w/2300' of tbg. Well on vacuum, fill hole w/7.4 bbls. of 8.8# brine. POOH w/remaining tbg., L/D Halliburton DST tools. P/U Dowell BA plug retrieving tool. TIH w/3½" tbg. workstring, tallying tbg., tag sand fill @ 4290' KB (pipe meas.). R/U circ. lines, reverse circulating out fill, 1.5' of fill, clean out to top of packer. Latch onto Dowell BA plug, reverse circ. total of 420 bbls, 120° 8.8# brine. R/D circ. lines, unlatch from BA plug. POOH w/3600' tbg. Sample taken while reverse circ., after bottoms up had approx. 1" of sand on bottom of 1 gal. container. Install adapter head on Kobe cavity. Check Kobe cavity by inserting Kobe jet pump. Pressure test cavity to 2500 psi 5 min. - O.K. M/U x-overs & pup joints on Kobe cavity. Fill hole with 3.5 bbls. 8.8# brine, amount lost to formation overnight. POOH w/remaining 600' of 3~" workstring & Dowell J-Latch retrieving tool. Change out BOP rams to 4½". R/U to run 4½" tbg. TIH w/2 jts. 2-7/8" 8rd tubing - 63.44' for tail, BHA & 4050' of 4~" butt. tbg. Tallied on racks. P/U & TIH w/remaining 4~" tubing. Tag top of B.A. plug 4290' KB. R/U circ. lines. Reverse circ. out 295 bbls. 8.8# brine w/fresh water. Rev. circ. fresh water @ 3 bbl. per minute with rig pump, 1170 bbls. total. Changed over to rev. circ. w/Kobe triplex. Pumping @ 38 gal/min. Circ. 590 bbls. w/Kobe, final temp. in 135°, final temp. out 108°. Circ. 95 bbls. of diesel (130°F) to perfs. @ 4268' to 4288'; close in annulus; squeeze diesel into perfs @ ~ bpm & 1200 psi; displace diesel w/fresh water. Tubing & annulus flowing back fresh water & diesel. Displace tubing & annulus w/fresh water using 100-150 psi back pressure on choke, well dead. Pull up & land 4~" tubing in hanger. Kobe cavity @ 4139'; 2-7/8" tubing tail @ 4219'. N/D BOP, install intermediate spool. N/U BOP & change rams. RIH w/2-7/8" tbg. to "J" latch @ 4133'. Latch into "J" & land 2-7/8" tbg. in hanger; N/D BOP & N/U tree. RIH & seat standing valve, drop & seat jet pump. Pump well w/jet pump. Rates: Power fluid in - 23 gpm, gross fluid out - 45 gpm. Pump surface pressure: 2500 psi, chlorides: 4500 ppm. Pumping well w/Kobe jet pump (open system) by-passing separator. Occasional shut downs to shoot fluid levels. Total Produced Fluids - 77.2 bbls 20 hrs., water - 99.8%, oil - .1%, sediment - .1%. Chlorides: Power fluid in - 3000-4000 ppm; produced fluid out - 4000-5500 ppm. Rates: Power fluid in - 25 gpm; produced fluid out - 27-32 gpm. Pressures: Tubing - 3000 psi; casing - 40 psi. - 13 - 10-10 10-11 10-12 10-13 10-14 .O_NFIDEN!.I.AL._. Pumping well w/Kobe jet pump, no produced fluids last 3 hrs. Pump jet pump to surface. Drop piston pump #1 & pump into cavity. Press. up to 3000 psi, would not pressure up or pump. Retrieve piston pump #1 w/sandline. Drop & pump down piston pump #2 & seat in cavity. Pressure up & begin pumping w/ll00 psi. Pumping well w/piston pump #2; produced a net of 18.5 bbls. fluid in 1 hr. Lowered fluid level in annulus from 520' to 790'. Pump press. increased rapidly from 1100 psi to 3000 psi shutting down pump. Unseated pump & re-seated into cavity twice. Pressured up to 3000 psi each time & pump would not pump. Attempt to unseat & pump piston pump #2 out of hole; pressure built to 3000 psi & pump would not unseat. Made 3 attempts to pull pump w/sandline, could not latch onto fishing neck w/overshot. R/U & swab 2-7/8" tbg. to top of pump. Attempt to pump piston pump out of cavity, would not unseat w/3000 psi. R/U & make 2 runs to top of pump w/Camco (2-1/8") sand pump. Rec. no sand or fill. RIH w/overshot, could not latch fishing neck on piston pump. R/U & fill 9-5/8"x4½" annulus w/water & pressure up to 1850 psi. Bled off 50 psi in 5 min., could not unseat pump by pumping through standing valve. Bled off pressure & blow down lines. Shut in well overnight. Kobe Pump Teardown Report: Jet Pump #1 - Normal interval wear, no external problems. Piston Pump #1 - Engine side of pump totally sanded up & external seal rings gone. Set FMC back pressure valve in hanger. N/D tree, N/U BOP. Release 2-7/8" tbg. from "J" latch, could not pull pipe. Work pipe & slowly work up throug 16' of fill in 2-7/8"x4½" annulus. R/U & rev. circ. 16' of sand fill out to top of "J" latch using 180° water. R/U & begin swabbing 2-7/8" tbg, could not get swab assembly past 2500'. Made run w/wireline overshot. Worked past 2500' & on to bottom. M/U swab assembly & made two more runs, could not get past 2500'. POOH w/2-7/8" tbg. looking for obstruction & found none. Tbg. was clean on I.D. & O.D. No sign of sand or heavy oil, however, stinger on "J" latch assembly was missing the top 3 seal rings. Shut well overnight. RIH w/2-7/8" tbg. to 3953', circ. 140° water to heat annulus. Swabbed concentric strings to 3700' & POOH w/2-7/8" tbg. Changed over to pull 4½" tbg, N/D BOPE, remove intermediate spool & N/U BOPE. POOH w/4½" tbg. Hit fluid after 1300'. Fluid diverted to slop tank. Pulled 2038' of tbg. 110 bbls. 8 8#/gal. brine added for displacement 4½" tbg. Finish POOH w/4½" tbg. Approx. 24' of sand inside 4½" on top of Kobe cavity. RIH w/3½" Btrs. tbg. Tally pipe in hole & tagged sand @ 4238'. Cleaned out sand to 4268'. Circ. hot water (in @ 110°, out 85°) until returns warm. POOH w/3½" tbg. M/U 9-5/8" 47# Baker Model "C" retrievable bridge plug & RIH. Circ. out approx. 60 bbls. oil @ sand cleanout. Continue RIH w/Baker 9-5/8" 47# Model "C" retrievable bridge plug. Set @ 4208'(WLM) & tested to 1000#, o.k. Spotted 4 sks. sand on bridge plug. Changed well over to clean, filtered 8.8#/gal. brine. POOH w/3½" workstring. R/U Gearhart to perforate. Shot -lA- 10-15 10-16 10-17 10-18 12 spf w/5" Superpak. From 4016'-4049'(KB) (33') slight vacuum after first shots. M/U Halliburton DST string w/Camco press/temp gauges. RIH. Finish RIH w/Howco DST tools & 1750' of diesel cushion. Set pkr. @ 3938'(WLM). R/U swab equip. Open "LPR" valve @ 8:20 a.m. & slight blow @ surface for approx. 3 hrs. Made several swab runs & rec. diesel cushion & thick viscous oil. Unable to get swab below 2700'±. Made runs through heavy oil w/sinker bars but unable to pass either 3~" or 2-7/8" swab cups. Closed "LPR" valve & opened bypass. Circ. approx. 300 bbls. fresh water. Temp in - 143°, temp out - 102°. Opened "LPg' & begin swab operations. Continue attempting to swab. Thick viscous gritty oil rec. on tool string. Most swab fluid is water bypassing oil on way to surface. Unable to get tools pass 500'. Pressured up on annulus to shear Howco "M-2" sampler. Released pkr. & POOH after circ. clean, filtered brine (8.8#/gal) to kill well. Approx. 40 bbls. lost to formation on POOH. Breakout Howco tools, Camco press/temp recorders & rec. approx. 2 pint sample from "M-2" sampler. RIH w/3½" tbg. Approx. 5' of perfs, covered w/fill @ 4044'. Circ. & prepare to clean out fill. Tagged fill 4044' (WLM) & circ. out thick oil & formation sand. Fell through sand bridle. TIH to 4189' (WLM). Mix visc. gel pill & swept hole. Hooked up hot oil truck & spotted 40 bbls. diesel in tbg. Let soak 90 min. & reversed to slop tank. Re-filtered brine used during cleanout. Repair Hydril. WOO. WOO. POOH w/3~" workstring. Dropped 10 sks. 20/40 sand down csg. Let settle & RIH w/3½" tbg. & tag sand @ 4168' (WLM). Pulled tbg. tail to 4060' (WLM) & wait for B.J. Hughes to rig up. R/U Hughes & connect lines. Established breakdown. 2 bpm @ 950#. After 3 bbls. pumped, press, stabilized @ 800# @ 2 bpm. Spotted 125 sks. "Cold-Set 1" cmt. & displaced w/32 bbls. of brine. Cmt. weight 15-15.5 ppg. Pulled 15 stds. tbg. to 3136' (WLM). Time from end of spotting displacement to squeeze - 25 minutes. Filled hole w/2 bbls. more than pipe displacement. Closed pipe rams. Initial Squeeze rate 1.5 bpm @ 500#: BBLS. Disp. PSI Rate-BPM 3 500 1.5 4 800 1.8 5 1100 1.75 6 1400 1.44 7 1800 1.2 8 1900 .75 8.5 2000 .5 9 2100 .25 10 2275 .25 Squeezed additional 1.5 bbls. using hesitation method. Total displacement volume: 11.5 bbls. Estimated volume of cement out: 11.5 bbls (69 sks). Estimated top of cement: 3934'. Shut well in w/500 psi & WOC. - 15 - 10-19 10-20 POOH w/3~" workstring. RIH w/security S33S, 8½" bit, 6 & 4-3/4" drill collars & 3~" tbg. Tagged cmt top 3891' (WLM) cleaned out cement to 4057' (WLM) continue to 4140' (WLM) & test csg to 1000 psi/15 min. Test good. POOH & M.U. bit & scraper. RIH to clean sand off bridgeplug. Continue RIH w/bit & scraper. Reverse out sand & cmt. debris. POOH, stand back collars, changed bales. RIH, tally pipe. Tagged sand @ 4146'. Reverse out sand thru Baker retrieving tool. Circ. down to retrieving head, latched Baker model C bridgeplug, released & POOH. Found considerable perforating debris on bridge- plug. RIH w/8~" bit & scraper to 4274' (WLM). Circ. hole clean & POOH. Making up BA retrieving tool @ report time. Brine wt 8.8#/gal; viscosity 40-45. 10-21 10-22 TIH w/"BA" retrieving tool, tag top of plug @ 4290' WLM. R/U circulating lines. M/U 15 bbl. gel pill w/8.8# brine, visc. 60-70. Reverse circ. 15 bbls. gel pill & 300 bbl. 8.8# brine. Lower retrieving tool 3', latch onto BA plug while circ. Static tbg. weight 36,000#, P/U weight 40,000#. P/U to 42,000#. Rotate 12 turns to right, P/U additional 8000#, tool did not release. Rev. circ. 80 bbl. brine while working tool. "BA" plug released @ 68,000# pickup weight. POOH w/tbg, retrieving too]. & BA plug. L/D BA plug, retrieving tool. R/U Gearhart & TIH w/3.62" junk basket & CC1, & tag top of Otis "XN" nipple 2.75" I.D. @ 4379' WLM. POOH. TIH w/3.62" jet cutter, CCl& shot tbg. @ 4365' WLM (packer tagged @ 4294' WLM). POOH & R/D Gearhart. P/U & tally 4.75" O.D. spear, bumper sub, & jars. TIH w/above plug 6 4-3/4" drill collars & 3~" work string. Sting into Model 16E packer, spear did not grab internal bore of packer. Start out of hole w/tbg. Lost 26 bbls. brine to formation last 24 hrs. Finish POOH w/tbg, collars, bumper sub, jars & spear. Add 4' extension onto top of spear. TIH w/4.75" O.D. spear, bumper sub, 6 4.75" O.D. drill collars & 5½" tbg. Latch into internal bore of pkr. Static tbg. weight 46,000#, P/U weight 52,000#. 48,000# above P/U, needed to shear pins on pkr. to release. Started jarring on pkr. @ 100,000# pull, no indication of releasing, gradually increased pull to 120,000#. Tried bumping down on pkr., rotating to right & ].eft, could not, released spear from pkr. POOH. R/U Gearhart. TIH w/1.75" sinker bars & CCL, stacked out @ 4377' WLM. Debris from previous jet cutter shot lodged above x-over & Otis "XN" nipple. POOH. TIH w/2.43" jet cutter, 100 gram charge & CCL. Fired cutter @ 4370' WLM & POOH. Jet cutter malfunctioned @ 4200' & POOH. Change out CCL & TIH. Fire jet cutter @ 4321' WLM & POOH. R/D Gearhart. P/U 4.34" O.D. spear, bumper sub, jars, 4 additional 4.75" drill collars & accelerator jars. TIH w/above and workstring & latch into pkr. Jarring on pkr. w/120,000# pickup, no results, P/U to 130,000# jar once pkr. & blank released. POOH. L/D fishing tools, Model 16E pkr., 10' of 5~" pkr. extension, 9~' of 4~" shot off blank. Bottom flared out to 6" O.D. One area 2~" long was not cut by jet cutter but sheared from jarring. - 16 - 10-23 10-24 10-25 10-26 10-27 C'ONFIDENTIAL Break apart fishing tools, extension & sub from Model 16E pkr. Tally & caliper Baker Model "C" bridge plug, retrieving tool & retrievamatic pkr. & M/U same. TIH w/Baker equip & 3½" workstring & tally. Set bridge plug @ 4311' WLM, release from bridge plug & set pkr. @ 4292' WLM. Pressure test bridge plug to 1000 psi, o.k. Release pkr. Mix up 51 bbls. 8.8# brine & circ. down tbg. L/D 1 jt. Spot 5 sks. 20-40 sand top of bridge plug. Lower tbg. & tag sand @ 4302' WLM. POOH w/4 stds. tbg., set pkr. @ 4062' WLM. Test annulus 500# for 15 min., o.k. R/U BJ, pressure test lines to 3500 psi. Establish injection rate at 2 bpm, 1200 psi w/lO bbls. fresh water. Pump 12.5 bbls. "Cold Set 1" 15.2#-15.5# slurry (75 sks.). BBLS. Disp. PSI Rate BPM 5 1200 2 15 900 2 25 900 2 35 1000 2 40 1200 2 44½ 1250 1 Pump additional 1½ bbls. using hesitation method. Final squeeze pressure 2000 psi. Total displacement volume: 46 bbls. Estimated top of cement: 4210' WLM. POOH. L/D Baker retrievamatic pkr. TIH w/Security 8½" bit, six 4-3/4" drill collars & 3½" tbg. Tag cmt. top @ 4202' WLM. Circ. hole, mix Barazan in 8.8# brine to raise viscosity to 42. Cleaned out cmt. to 4290' WLM. Continue down to 4300' WLM, tag sand. Pressure test to 700 psi for 15 min. Test o.k. POOH. TIH w/8~" bit, csg. scraper, two 4-3/4" drill collars & tbg. to 3200'. Clean up mud tanks. Finish cleaning out mud tanks. Mix up 600 bbls. 8.8# brine. Continue TIH w/bit & scraper to 4300' (WLM). POOH. TIH w/tbg & retrieving tool for Model C bridge plug. Tag sand fill @ 4300' WLM. R/U circ. line and reverse circ. out sand to top of bridge plug @ 4311' WLM. Release bridge plug. POOH & L/D bridge plug & retrieving tool. TIH w/hollow mill, grapple, bumper, sub, jars, & ten 4.75" drill collars. Tag top of cut off blank tbg. @ 4321' WLM. Clean up top of tbg. Lower down 8' & latch onto tbg. Pulled 10,000# over pickup weight, grapple slipped off fish. POOH. Wait on 3' extension from Tri-State. TIH w/4½" grapple, bumper sub, jars, ten 4-3/4" drill collars, excelerator jars & tbg. Latch onto fish. Jarring on fish, pulling 130,000-140,000# pull. Worked fish loose. POOH, L/D fishing tools, ten 4½" blanks plus cut-off joint, two 20' 5½" gravel pack screens and Mode]. 18 seal unit. TIH w/ 8½" bit, scraper, tbg. & two 4-3/4" drill collars. Tag sand fill @ 4678' WLM. Clean out to top of packer @ 4698' WLM. POOH. TIH w/taper mill, ten 4-3/4" drill collars & 3000' of tbg. Est. 85' of gravel pack sand outside of grave], pack screen. Finish TIH. Top of Model 18 pkr. @ 4698' WLM. Milling on pkr. - 17 - 10-28 10-29 10-30 10-31 11-1 Continue milling on pkr. POOH. Top connection of pkr. stuck to outside of mill. TIH w/8~" taper mill, ten 4-3/4" drill collars & tbg. R/U kelly. Mill on pkr. until bottom set of slips released. Push remainder of pkr. to 4898' WLM. Clean out rig mud tanks. Mix up 1100 bbls. 8.7#+ brine & filter through DE filter. Circ. hole w/310 bbls. 8.7#+ filtered brine. POOH. L/D drill collars & taper mill. R/U Gearhart & perforate following intervals w/5" scalloped guns w/12 jspf 120° phasing & super pac charges: Run #1 - Tagged fill @ 4892' WLM, shot 4734'-4754', no misfires; Run #2 - 4728'-4734' BTM gun, no misfires, 4695'-4687' top gun no misfires; Run #3 - CCL failed & cablehead had to be reheaded; Run #4 - 4602'-4584', no misfires; Run #5 - 4580'-4575' BTM gun, no misfires, 4562'-4556', top gun, no misfires; Run #6 - 4542'-4536' BTM gun, no misfires, 4514'-4508' top gun, no misfires. M/U Halliburton DST tools w/Camco pressure gauges & temp. gauges below RTTS pkr. Pressure gauges - 0-4000 psi, temp. gauges - 00-250°, 144 hr. clocks. TIH & tally, drift 3~" workstring, fill 1450' of tbg. w/12.5 bbls. diesel. Set pkr. @ 4386' WLM, bottom re-entry guide @ 4415' WLM. Test annulus to 500 psi. Open Halliburton Ful-Flow-Hydrostatic valve. Strong blow @ surface, fluid to surface 1 hr. 20 min. Total produced fluids 133 bbls. 6 hrs.50 min. Oil: 98%, Water: 1.9%, Solids: .1%. Wellhead: Temp 24°, Pressure 60 psi, GOR 271. Closed Ful-Flow Hydrostatic valve (released prematurely loc-closed bypass). Weight up 8.7# brine to 9.4# brine. Rev. circ. 9.4# brine 350 bbls. Circ. down tbg. 40 bbls. diesel. Open Ful-Flow valve. Flowing well to production oil tank. Wellhead: 3 psi, 47°, flowed back 12.6 bbls. diesel. Lost 90 bbls. 9.4# brine to formation when loc-closed bypass opened. Made 10 swab runs. Recovered diesel & approx 79 bbls. brine. Well flowing through heater to stock tanks @ 40-60 psi @ wellhead. Directed flow through separator. Separator @ 20 psi, wellhead 40-60 psi, 37°F. Prod. Data: Avg..,, Range BOPD 424 324-528 BWPD 12.5 0-52.8 GOR 187 167-198 MCF/D 76.6 66.3-98.1 Total Fluid Produced: 394 BBLS. including swabbing. Produced water chlorides dropping - 29,000 P.P.M. @ report time. Continue flow test of "N" and "0" series. Production Data: Average Range BOPD 331 265-386 BWPD 0.7 MCF 66 57.2-80.0 GOR 197 169-209 Total Production: 331 bbls./24 hours. Flowing WHP = 56 psi; WHT = 35°F. Gravity = 19.2° AP1. - 1R - 11-2 11-3 11-4 11-5 11-6 CON[IPENTIAL Continue to flow well & obtained several oil samples. Average BOPD 311 BWPD 0 MCF 62.1 GOR 200 Total volume produced: 46 bbls./4 hours. Attempt to close "Hydro-spring" tool in DST string. Unable to close. After several cycles of tool, pkr. unseated & 48 bbls. 9.4#/gal brine lost to formation. Reset pkr. Made several attempts to open "loc closed bypass" above Hydro-spring. An apparent malfunction in RTTS bypass or Hydro-spring prevented rev. circ. Lost 121 bbls. to formation. Sheared tubing sensitive sub @ 1800# & gained circ. (Hydro-spring apparently closed). Reversed out oil & 9.4#/gal brine w/8.7#/gal filtered brine. POOH w/Howco DST string. Found sand on top of Hydro-spring. Tools sent to shop for teardown & repair. TIH w/Baker Model "C" bridge plug (9-5/8" 47#). Set @ 4630' WLM. POOH. P/U Howco DST tools, Camco pressure & temp recorders & TIH. Set 9-5/8" 47# RTTS @ 4388' WLM. Opened loc. closed bypass valve. Mix brine to 9.4#/gal. & displaced out 8.7#/gal. brine. Displaced tbg. w/40 bbls. diesel & shut circulating valve. Opened well to test system @ 2240 hrs. Flowed back 23 bbls. diesel in 3 hrs. Well dead. R/U to swab. Tbg. volume - 38 bbls., rathole 15.8 (btm. perf). Total recovery @ 6:00 a.m. 168.5 bbls. 95,000 ppm chlorides. Fluid level approx. 1000' from surface. Swab runs f/1300'-1500'. Showing trace of oil & beginning to gas. Prod. testing "N" series sands. Avg. Range BOPD 366 288-442 BWPD 0 0-25 MCFD 67 54-83 GOR 186 160-220 Wellhead pressure - 39 psi. Wellhead temp - 41°. Separator pressure - 18 psi. Fluid produced last 24 hrs. - 316 bbls. Flow rates @ 6:00 a.m.: 288 BOPD, 9 BWPD, 188 GOR, 54 MCFD. Gravity corrected to 60° = 18.5° to 18.8°API. Continue flowing well through separator: Avg. Range BOPD 289 264-336 BWPD 0 0-25 MCFD 54.7 53.8-56.9 GOR 190 169-204 Wellhead pressure - 38 psi. Wellhead temp. - 48°F. Volume produced this period - 9 bbls. Well shut in @ surface @ 12:05 p.m. for pressure buildup. Continue pressure buildup survey. Bled tbg. pressure off (280 psi @ surface). Attempt to close "Ful Flo Hydrospring". Unable to do so. Opened "Loc closed bypass" but unable to circu].ate, or to shear tubing sensitive shear sub. Lost approx. 120 bbls. 9.4#/gal. brine during these attempts. Unseat RTTS & circ. - 19 - 11-7 11-8 11-9 11-10 CON[JPEN]'iAj. 8.7#/gal brine. POOH w/DST string & L/D tools. RIH w/Baker retrieving tool. Tagged fill @ 4572' WLM. Cleaned out to Baker Model "C" bridge plug @ 4630' WLM & circ. out sand, oil & considerable gas. POOH w/bridge plug. P/U Baker "FHL" Pkr. & expanda-joint & RIH @ report time. Note: Add'l. 85 bbls. 8.7#/gal brine lost during clean out. Continue TIH, set Baker "FHL" packer @ 4354' (WLM), reentry guide @ 4370' WLM. POOH. R/U to run 4~" tbg. TIH w/Baker expanda joint, 4½" pup joint, 4 its. 4~" seal bore extension, 4~" perf. pup joint & 4~" tbg. Locate slick stick, space out & land 4~" tbg. w/8' of expanda jt. over s].ick stick. Install FMC BP¥. N/D BOP's & install concentric spool. N/U BOP's & pressure test spool to 5000 psi, O.K. Remove BPV. P/U Baker seal bore locator & assembly. TIH. Continue TIH, sting into seal bore extension & space out. Install FMC BPV & land tubing. Top of seal bore extension @ 4186' WLM, bottom of seal assembly @ 4196' WLM. Seal assembly length 14.70'. N/D BOP's, install wellhead & pressure test to 5000 psi, o.k. Retrieve BPV. R/U to swab, displacing 8.7#/gal brine in 9-5/8", 4½" annulus w/8.33#/gal water. Total displacement 255 bbls. Swabbing. Fluid level 500'-800'from surface. Pulling swab from 1500'-2000'. Swab recovery 278.77 bbls. water/oil. Well flowing, bypass separator until 0430 hrs. Total volume rec - swabbing/flowing 297.42 bbls. At report time: 90.75% oil, 9% water, .25% solids. Circ. temp.: In 108°, out - 91°. Continue flow testing "N" and "0" series sands through separator. Total production in 24 hours: Oil 368.1 bbl., water 47.7 bbl., gas average over last 4 hrs. 130 MCF/D. Range: Oil rate 137-470 BOPD, gas rate last 4 hrs. only 111 to 142 MCF/D , water rate 0-156 BWPD. Heated circ. fluid, temp. at wellhead: In 98° to 130~, Out 75° to 104°. Total circ. fluid in 24 hrs = 994 bbls. Produced fluids: WHP 16 to 40 psi, WHT 86 to 120~F. Chlorides: 77,000 to 104,000 ppm. API gravity 16.7° to 18.7°, corrected to 60°F. Released both rig crews, 1 man left for rig watch. Continue flow testing "N" and "0" series sands. Total oil produced 19 hrs. of flow 299.4 bbls. Total water = 7.3 bbls. Ave. Oil Rate: 378.2 BPD Wtr Rate: 9.2 BPD Gas Rate: 123 MCF/day GOR: 315 CF/bbl Range 0 to 487.2 BPD 0 to 28.8 BPD 0 to 149 MCF/day 230 to 384 CF/bbl Circulating fluid temp: In = 102~ to 133°F Out= 93° to l14OF Circulating fluid rate = 29 GPM. Produced fluid WHP = 10 to 34 PSIG. Produced fluid WHT = 98° to 120°F. Chlorides = 77,800 PPM to 95,600 PPM. API gravity.= 17.7~ to 18.9°. TIH with H.P. gauge 2300 hrs to 2400 hrs. Flow rate started decreasing while TIH. At 2400 hrs well died. H.P. gauge depth 4270' WLM. POOH w/H.P. - 20 - 11-11 11-12 11-13 gauge. Well open to separator. Steady blow at surface. Flow rate - none. Shut well in TIH/H.P. gauge to 4280' WLM 3993' TVD. Initial pressure 1559.43 PSIA. Well dead - Recording BHP buildup. Final BHP @ 4280' WLM - 1591 PSIA. POOH to 4080' WLM - 1522 PSIA. 3580' WLM - 1378 PSIA - well flowing. Well flowing - TIH w/H.P, gauge to 4280' WLM 3933' TVD. Bypassed separator until 1120 hrs. Total fluid produced - 21 hrs. = 418.7 bbls. Total oil produced - 18 hrs. = 345.6 bbls. Total water produced - 18 hrs. = 2.2 bbls. Avg. oil rate = 460.8 B/W. Range of oil rates = 276 to 583 B/O. Avg. wtr rate = 2.9 B/O. Avg. gas rate = 142.3 MCF/day. Range of gas rates = 120 to 165 MCF/day. Avg. GOR = 304.8 CF/bbl. Range of GOR's = 266 CF/bbl to 350 CF/bbl. Circulating fluid temp: In - 132° to 140° F, Out - 114° to 120°F. Circulating fluid rate: 24 GPM. Flowing bottomhole pressure = 1281PSIA to 1377 PSIA. WHP = 18 to 36 PSIG. WHT = 120° to 130~ F. Oil gravity = 18°. Chlorides: 53,500 - 100,400 PPM. Note: No circulating fluid lost last 24 hrs. Continue production flow test of the "0" & "N" series sands thru separator. Total oil produced past 24 hrs. = 401.5 bbls. Total water produced past 24 hrs. = 0.8 bbls. Avg. gas measured past 24 hrs. = 125.6 MCF/D. Avg. GOR calculated past 24 hrs. = 298.4 CF/bbl. Avg. heated circulating fluid rate = 24 GPM. Range of bottomhole flowing pressures = 1280 to 1322 PSIA. Range of WHP = 14 to 36 PSIG produced fluids. Range of WHT = 128° to 132~ F. Temp. of heated circulating fluid: In = 131~ to 140° F. Out = 112° to 118° F. Range of oil rates = 257 to 523 BOPD. Range of gas rates = 87.8 to 158.6 MCFD. Range of GOR - 258 to 318 CF/bbl. Oil gravity 18.3~ API. Grind outs before separator 0.0% B.S. 0.1% H~O 0.9% Emul. 99.0% oil. Note: No circulating fluid lost in pas~ 24 hrs. Continue prod. testing of "0" & "N" series sands, thru separator: separator psi: 11-15 PSIG. Averaged flow rate: 359 BPD. Flowing BHP: 1270 - 1336 PSIA. WHP: 24-32 PSIG. WHT: 128~ - 132° F. Power fluid circulated @ 138~ in/120~ out. Increased separator pressure to stabilize operation & obtain gas rate. Slowly increased to 18 PSIG. Well died - FBHP - 1393 PSIA. Bypassed separator & flowed 46 bbls. to stock tanks. Reduced FBHP to 1273 PSIA. Returned prod. thru separator @ 18 PSIG. Reduced power fluid circ. temp. to 110° in/100° out. Well died 1930 hrs. @ 1425 PSIA FBHP. Well open to stock tanks (~ back pressure). Slight gas flow FBHP increased to 1584 PSIG @ 0500 hrs. Well beginning to flow. FBHP @ 1564. Circ. temp: 99° in/97° out. Total fluid produced 24 hrs: 163.6 bbls. Produced oil gravity: 18.3~ @ 60~. Wellhead cuts show trace of emulsion & water. No BS. - 2] - 11-14 11-15 11-16 11-17 Continue prod. testing "O" & "N" sands. Rates: (Averaged) BOPD: 362.5 BWPD: 0.6 MCFD: 71.3 GOR : 200 FBHP: 1340 PSIA Mechanical problems w/primary pump necessitate std by pump use. Circ @ 1 bpm. Temp in: 86°. Temp out: 82°. No fluid lost. Wellhead data: W.H. pressure 42 PSIG W.H. temp 80° F Separator pressure: 30 PSIG. Wellhead & separator cuts 99.8% oil., 0.2% emul. Trace solids occasionally. Gravity: 19° AP1. Continue prod. testing "0" & "N" sands. Rates: BOPD: 281 BWPD: ~ MCFD: 57.3 GOR : 204 FBHP: 1343 PSIA (approx. 20 psi fluctuations). Wellhead pressure: 42 PSIG (separator = 30 PSIG). Wellhead temp: 88° (@ 0500 hrs & rising). Circulating fluid: 96° in/84° out @ 30 gpm rate. (meter) (tank strap) Fluid produced last 24 hrs: 281 bbls 296 Fluid produced this test: 0600 hrs 11-9-83, 0600 11-16-83 2260 bbls (tank strap measurement) Note: Use of standby circulating pump for power fluid has caused less precise control of power fluid temp. Problems have been solved as of report time, but some fluctuations may occur in temp. until primary circ. pump is repaired (expected today). Continue testing "O" & "N" sands. Rates: BOPD: 272 BWPD: ~ MCFD: 57.4 GOR : 211 FBHP: Range 1337 - 1356 PSIA. Wellhead pressure: 42 PSIG. Wellhead temp: 92° Shut well in while POOH w/pressure bomb. RU Schlumberger & RIH w/spinner, gradiomonometer, temp. tool, gamma ray & CCL. Truck failed - POOH. Wait on Schlumberger. RIH to 4420'. Temp. tool failed. Made several static passes & opened well to stock tanks initially, then thru sep. Rates thru sep. approx. 408 BOPD. POOH & chg'd temp. element. RIH. Total fluid this 24 hrs. - 188 bbls. Total fluid from 11-9-83 - 11-16-83 2448 bbls. Continue running Schlumberger logs & flowing well as conditions permit. R.D. Schlumberger & RU Conoco wireline. RIH w/H.P, gauge - 9? - 11-18 11-19 11-20 11-21 11-22 COHFID_EN!IAL w/well shut-in. Flow well bypassing separator initially. Flow well thru separator. Rates: BOPD: 316.45 BWPD: ~ MCFD: 65.45 GOR : 202 FBHP: 1327 to 1338 PSIA Wellhead psi: 44 PSIG Wellhead temp: 85° Circulating power fluid w/triplex @ 0.5 bpm. Temp in: 98°. Temp out: 86°. Fluid produced 24 hrs: 265 Fluid produced to date: 2713 (11-9-83 11-18-83 0600 hrs) Continue production test of "0" & "N" sands. Rates: BOPD: 290 BWPD: ~ GOR : 206 MCF/bbl FBHP: 1314 - 1340 PSIA Wellhead Pressure: 42 PSIG Wellhead Temp: 84° - 88° Circ. Fluid Temp: 96/86 Fluid produced 24 hfs: 290 bbls Accum. production: 3003 bbls Well shut in for buildup @ 0600 hrs 11-19-83 Shut in for pressure buildup. FBHP @ shut in - 1314.6 PSIA. SIBHP @ report time - 1614.0 PSIA. Circulating fluid: @ start of buildup - 960/88°, @ 0600 hrs - 96°/81°. Rate - 0.5 bpm. Continue shut-in for pressure buildup. SIBHP @ report time - 1657.49 PSIA. Circulating fluid - 97° F in, 88° F out. Rate - 0.5 bpm. End of shut-in for pressure buildup. POOH with H.P. gauge. Lay down lubricator. R.U. Schlumberger TIH w/sampler - sampled downhole fluid at 4790' WLM. POOH sampler contained 9.1 ppg brine. Pumped 10 bbl 9.1 ppg NaCL brine followed with 30 bbls of crude oil. TIH w/TDT-M, tag fill at 4850' WLM. Made 5 passes w/TDT-M over 4800' to 4450'. Made one stationeary measurement at 4682' WLM. Made two passes over 4600' to 4450' WLM. Made two stationary measurements at 4560' and 4518' WLM. POOH. TIH w/H.P. pressure gauge/thermometer. @ report time depth of H.P. gauge 4400' still tripping in hole. Note: tbg.-tbg. & csg.-tbg. annulus filled w/9.3 ppg NaCL brine - 265 bbls. .End of production testing, preparing for injectivity test. Continue trip in hole. Run temperature survey across perforated intervals. Set Schlumberger H.P. gauge (measuring point) at 4292' WLM. Pump 30 bbls treated fresh water before step rate. Run water injection step rate test. - 23 - CQHFIDEHTIAL 11-23 11-24 11-25 11-26 11-27 Volume Test # Rate B/D BHP Pumped bbl WHP - 0 1702 - 1 302 1862 48.8 2 605 1937 29.9 3 970 2140 - 2210 190.6 4 1450 2425 - 2500 347.3 5 2140 2700 312.0 0 100 - 175 100 - 150 250 - 400 600 - 750 850 - 900 928.6 total pumped Injecting cold fresh water. WHP - 1000 PSI, WHT - 65°F, BHT - 67°F, Rate B/D - 2051. Total volume cold water pumped at report time - 299.20 bbls. Note: Total bbls fresh water pumped last 24 hrs. - 1257.80 bbls. Continue injecting cold fresh treated water. WHP - 1050 psi, WHT - 60°F, BHT - 62°F, Rate B/D - 2005. Shut down injection. Schlumberger ran 7 temperature surveys across perforated intervals. POOH. R/D Schlumberger. TIH w/Conoco H.P. gauge set @ 4300' WLM. Beginning BHP 1947.31 psia. Working on discharge line - Oilwell triplex. Injecting fresh treated water. Total injected 430.29 bbls. ½ hour downtime on injection. WHP - 725 psi, WHT 100°F, BHP - 2436.66 psia, Rate B/D - 1721. Total water injected 2147.33 bbls. Continue water injection "N" and "0" series sands. WHP - 850 psi, WHT 82°F, BHP - 2548.68 psia, Rate B/D - 1514. Total water injected last 24 hours - 1482.86 bbls. Total water injected - 3630.41 bbls. BBL volume is from tank strap measurement. Turbidity reading = 23 NTU. Iron = 4.4 mg/L. Injection down ~ hour - checking out transmission on Oilwell triplex pump. Inj. rate for 3-hour period was at 1000 B/D rate, when using Kobe triplex, while working on transmission of Oilwell triplex. Continue injection of treated water into "N" and "0" series sands. WHP - 900 psi, WHT 98°F, BHP - 2590.55 psia, Rate B/D - 1508. Total water injected last 24 hours: 1508.92 bbls. Total water injected: 5139.33 bbls. BBL volume is from tank strap measure- ment. Turbidity reading = 4.3 NTU. Iron = 4.0 mg/L. Note: Injection downtime 40 minutes. Installed Conoco's filter pot down stream of Dowell filters and put in 3 micron filters. Continue water injection into "N" and "0" series sands. WHP - 900 psi, WHT 80°F, BHP - 2600.95 psia. Total water injected last 24 hours - 1594.10 bbls. Total water injected - 6733.43 bbls. BBL volume is from tank strap measurement. Turbidity: 1.6 NTU. Iron: 3.4 Mg/L. Millipore: 0-200 - 39 sec.; 600-800 - 58 sec. No downtime last 24 hours. Continue water injection into "N" and "0" series sands. WHP - 900 psi, WHT 86~F, BHP - 2604.85 psia. Total water injected last 24 hours - 1539 bbls. Total water injected to date - 8272 bbls. - 24 - CQNI:iI)EN]'IAL 11-28 11-29 11-30 Turbidity: 1.5 NTU. Iron: 4 Mg/L. Millipore: 0-200 - 22.5 sec.; 600-800 - 63 sec. No downtime or operational problems. Continue water injection into "N" and "0" series sands. ~P - 900 psi WHT - 92°F BHP - 2606 psia Tank strap measurement: Water injected last 24 hours - 1559 bbls. Water injected to date - 9831 bbls Water quality: Turbidity: 1.6 NTU Iron: 4 Mg/L Millipore: 0-200 - 24 sec. 600-800 - 40 sec. No downtime or operational problems. Injecting fresh water into "N" and "0" series sands. WHP - 900 psi WHT - 78°-88°F BHP - 2610.91 psia Tank strap measurement: Water injected last 24 hours - 1596 bbls. Water injected to date - 11,427 bbls Water quality: TUrbidity: 1.3 NTU Iron: 3.8 Mg/L Millipore: 0-200 - 26 sec. 600-800 - 50 sec. No downtime. Continue injecting water into "N" and "0" series sands. POOH w/HP gauge. Injection continues. WHP - 1025 psi WHT - 96°F BHP - 2613.84 psia (midnight) Tank strap measurement: Water injected last 24 hours - 1541 bbls. Water injected to date - 12,968 bbls Water quality: Turbidity: 1.3 NTU Iron: 3.6 Mg/L 12-1 12-2 12-3 CONFiDENT_!AL Millipore: 0-200 - 24 sec. 600-800 - 38 sec. No downtime. Schlumberger on location & rigging up. Rig up & run Schlumberger tracer log. Encountered freezing problems with lubricator filled w/diesel. Attempt to rig up "warm sock" to provide lubricator heat, but heat loss on rig froze air control lines. Rig up to heat tape & insulate lubricator. Water injection continues on "O" & "N" sands. WHP - 1025 psi WHT - 74°F Tank strap measurement: Water injected last 24 hours - 1559 bbls. Water injected to date - 14,527 bbls Water quality: Turbidity: 1.1NTU Iron: 3.6 Mg/L Millipore: 0-200 - 25 sec. 600-800 - 67 sec. Fill lubricator with diesel. TIH w/TDT tool and make 5 runs while injecting fresh water. Mix up 500 bbls.of Boron water @ 3 lbs/bbl. Boron water Sigma = 73 capture cross-section units. Pump Boron water. Made 7 TDT log runs while injecting. Displace tubing with 29 bbls. of filtered fresh water. Shut down injection. Made 5 log runs w/TDT. Total water injected last 24 hours - 1315 bbls. Water injected to date - 15,842 bbls WHP - 975 psi WHT - 82°F Water quality: Turbidity: 2.8 NTU Iron: 3.6 Mg/L Millipore: 0-200 - 24 sec. 600-800 - 48 sec. Wellhead pressure - 800 psi after inj. shut-in. (At report time WHP 530 psi.) Finish making final TDT run with injection shut down. Start up injection. Schlumberger made 5 TDT log runs while injecting fresh hot water. POOH, R/D Schlumberger. Continue injecting fresh hot water into "0" and "N" series sands. TIH w/Conoco H.P. gauge & set gauge @ 4300' WLM. BHP 2580 psia. - 26 - 12-4 12-5 12-6 WHP - 950 psi WHT - 80°-96°F COHFiDEHT_IAL Water injected last 24 hours - 1448 bbls. Water injected to date - 17,290 bbls Water quality: Turbidity: 1.4 NTU Iron: 4.6 Mg/L Millipore: 0-200 - 24 sec. 600-800 - 28 sec. Note: 45 min. downtime - repairing discharge line off Triplex pump. Continue injecting fresh water into "N" and "0" series sands. WHP - 975 psi WHT - 82°-96°F BHP - 2635 psi Water injected last 24 hours - 1584 bbls. Water injected to date - 18,874 bbls Water quality: Turbidity: 1.2 NTU Iron: 3.8 Mg/L Millipore: 0-200 - 25 sec. 600-800 - 33 sec. No downtime. Continue injecting fresh water into "N" and "0" series sands. WHP - 975 psi WHT - 75°-92~F BHP - 2640.56 psi Water injected last 24 hours - 1611 bbls. Water injected to date - 20,485 bbls Water quality: Turbidity: 1.5 NTU Iron: 3.8 Mg/L Millipore: 0-200 - 22 sec. 600-800 - 28 sec. No downtime. Continue fresh water injection into "N" and "0" series sands. POOH w/Conoco H.P. gauge. Decreased water injection rate from 1600 BPD average to 900 BPD average. R/U Schlumberger & TIH 12-7 12-8 12-9 C_QNFiP.ENTIAL w/TDT. Make 5 log runs while injecting. Mix up 500 bbls. of boron water @ 3 lbs/bbl. Injecting boron water. WHP: 1600 BPD rate - 975 psi 900 BPD rate - 750 psi WHT: 84°-96°F BHP: Final pressure 1600 BPD rate - 2641.87 psia Final pressure 900 BPD rate - 2488.95 psia Water quality: Turbidity: 3.5 NTU Iron: 5.4 Mg/L Millipore: 0-200 - 24 sec. 600-800 - 61 sec. Total fresh water injected: 854 bbls. Total boron water injected: 220 bbls. Total water injected to date: 21,559 bbls. No downtime on injection. Continue injection of remaining 280 bbls. of boron water for a total of 500 bbls. injected. WHP: 900 psi WHT: 87°F Shut down injection. Schlumberger made 5 TDT log runs. Injected 809 bbls. cold fresh water. Displaced water in tubing w/24 bbls. diesel. Shut down injection. WHP: 950 psi WHT: 58°F - 62°F Total water injected last 24 hours: 1089 bbls. Total boron injected: 24 bbls. Water injected to date: 22,648 bbls. Water quality: Turbidity: 12.9 NTU Iron: 4.5 Mg/L Millipore: 0-200 - 30 sec. 600-800 - Filter plugged Schlumberger made 5 temperature surveys. Note: Rig crew arrived - activated rig. POOH w/temperature tool. R/D Schlumberger. Breakout and L/D 3~" tbg. in derrick. Circ. down 4~" tbg. up 9-5/8" annulus 16 bbls. diesel 232 bbls. 9.5 ppg. brine & 2.5 bbls. diesel. Disconnected rental spool & - ?R - 12-10 12-11 12-12 CONFIDENTIAL valves from BOP's and stood back BOP's. Clean out rig mud tanks. R/U Camco. TIH, set 2~" tbg. stop & POOH. TIH, set A-3 tbg. packoff & POOH. TIH, set 2~" tbg. stop & POOH. Test packoff. Held o.k. R/D Camco. Bottom stop set @ 3767' WLM, packoff @ 3737' WLM, top stop @ 3736' WLM. Installed FMC 2~" BPV. Preparing rig for teardown. Rig released @ 0300 hrs. 12-10-83. Rig down & stack rig on A-Pad. Proceeding in tear down of test equipment. Rig down test equipment. FINAL REPORT - 2q - CONFIDENI'IAL. t Eastman A PETROLANE COMPANY REPORT of SUB-SURFACE D IREC TI ONA L SURVEY CONCOC, INCo COMPANY Pad A, Well Number: 3 WELL NAME Milne Pt., North Slope, Alaska LOCATION JOB NUMBER TYPE OF SURVEY A0183D0063 Teleco/Directional Single Shot SURVEY BY B Glasscock OFFICE Alaska DATE 25-Jan-83 FORM 0-302 .z //.//? II I R E C T I 0 N :', :!.':.: 7r7 __~;I E C.~. 7 M!N, N REr-:OF;:D l~[::. SURVEY .... Rr~DII_IL.-; 01.": CI_.iRV~'.-':iTI_II:;:E ['IETHOD F::'/:.~ D Pi N,::. L ._ N O: :3 -F E'I F' ": - / D :""i::i:: P'I I L. N E f':' T. , N O R T H SI... (Z F* E, (-~ L .?..~:i:": t'::i (.:~ 5."'7 1 C:, '.? 4. :L :2 J. '.5 ,, 1:5:4:3 ,, :2:3 ,:."': .::, 76: ,::) 1.4 24..4:2 S; 79 ::?-"-t. k.I ...:.,:,, 1 5 zk,' ?-, 2/-, 5:: 7.'.'-I- .,.I ~ .,.,' , ~ ~ n 15c/ 1 ,':. ':', ! :::':',' ,' :;-.':4 3 ::34 1 ._,7, 1:322 '"'"", ,:, 4:30 .'~.":',._, 2; ~,. ]. ,-., .n ...... ~: ......' ;:o/ ..... 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Fl DIR I L L_ t IW E: D A Y :E; VAI_.I_ILE:i:; I..I:.::;E::KJ I:::'OF: I:)E:F:'TH ARE P1T-J W E ': F3 Fi't" 3 N E.: l 'f' (4E :: F:-;HT I.:5;.__ G1 VEN _ F:£F:.. !.,.'::<:.~,::} F'E~U!',!D::: Vr-"iL. LiE:E I_I:BIEK~ FOR DI:-ZF'Tt-.t r..%RE I"'ID 'I'F?LI=IF ........... C:C'~I..IR'.=:FVr.-....::RTIL.AL.-' ' VERTICAL R EE C: T A N G I_1 L A R C l_ I:l S L.I [? E I I-,'- .F. E,.. 1 I., FEET i 00. 500 ,, d:,00, 70(), ,Ar,!C.~L.E Ii ! Rr:FC:T I or, I I_bEi',IG T H D hl I:) P! F'E E"'I'. D ,'_=_' P T H S E C ]" I O N FEE'f' .. FEET C O 0 R fi I N A T E L:; D IS'I'Ar,.ICE D IF:;ECI-IC~N SEVER IT ....... FEET ........... FEET [! M DG/10C:'F O, 00 ()., 00 O. O 0 0 0 O, 0,'::, O. 00 ..... C!. 00 O. 0':) 0 0 O. 00 O. O<} O. ()O 0, C:O O 0 O, O,'} O, 51 '.:_; 1, ,':,7 W '~ . 75 ,.E; 7 :>.". (:: !'; :2:, 0 n ':' :2,6 '.~, .... ...... ,'. 71 W ':'. 07 '::' 7:':', O. ~ ':'. -'._, · .. 100. 7 'P'.'-.;' ,, 0 9 1 'F;, 5'7 10 0. :3';-.' 7. ::T:: 2 :3:5.4. 3 ]. F)O, '? 9 5 ,. 9:2,, ;5-I. ,. 7 0 t 0 <}. 1 C.)9:7..:, :.21 77, '74 ] 00. .1, 1 :::',':-'.:'. 14.1. 0 5.8 3 1 :::: ()0 ,, 1. 2 C.),:7' O, 2 t ,:::, 0., :2 2,::)O. .!.:=-..:'F', 10 :S 7?; :3.3 Ld .1. 7 21. :=:. :!i!: 7 ::: 7 3 :E,, !.,.~ '2;;:,F';,. 5'?; S 7,'-'-, 5':? W :.-:: 15.7 1'7]. C)/., !:.'.; ....."::" ::':4 t.J . . _ (:, ..::..,J. , ":.::'./', !5:=: '"',:=:'=' 75 t,',~ I';' ~ II~ ii 'I~ :I=; '7 'l .... 7'1:':":...,. I,..I ..... l_ ,., . ,2, ~'-"' ".'"1 l :2i ,t., 67 :::; 7':.-.'<"-., 1':",' ~.,.! :2.::2:7 (';',':', '=' '=:.,q '7 9'.=: IAI 0 ,, 50 (), :,.3" :; ',11%1 ,,:.. , Y ! 00, ]. 1 O0 ,. 1 O0., 100. '?675.60 '.::; '75i. 5; '..,I ..1i:)(:)4 :, ._,'="=;.. :::; 7~::.. ::..:: '~. I/). 1 <::)::::'.7',. '=""1. ':; 7:'";21 t.J :7: ,, '::~ 4 2, :2':':' :2:. 7'..: ,.:."". 0 :::': CONFIDENT_IAI:, i ill ................................ 'I'RL~E r'IL--.ASL.IRE[) I')RIF:'T DRIF'I' c:OURSE VERTIC':AL VERTICAL R E C: T A N G U L A R C: L r'~ S U R E [)L--.F'T!..I Ah. P31..,r:~ D IRECT!ON LEI'4GTH D:EP'TH :-::ECTIFh",I C 00 R D I N A T F' :3 DIS'F~NF:F DZREF:T ION :_=:EVER ! FEFT .D ['1 ..D...M ......... F. EET ...... FEET ............. FEET .............................. ..EEEJ ............. F!EE.iT ........ D. M ....... .. :3700, · -:., 121.70 :.:.: 21 '?. 42 :2::2: .1. 7,74 :2:.41 &, 5., 1 1 · OC O,. 5C O, :3:.-'.: O, 22 4 8(}0, "t.'?'00, !::: W f, 0.2!5 O. O. 7:3 O. 77 0 · .:,.-., 0, 2~ O, 1.5 (1 '="' I:' ! r...tr,l....C:I. C't:.]:I !I::'E .- D l I'":tEC:T I ON", I]I '.:;'t' A N C: E: : · -C ON.O £'; 0 ,':-1H O, ~.T · ~ASTM/~N UH~ST. OCK · cozDss .............. ...... ,~ .... .... ~O~,L, "AL-ASK^ ........ · I ' -- i ' Suggested form to be i~erted in~ each "A "well folder to dleck for timely ccmpliance with our regulations. - ' O~erator, Wel 1 Name' and ~'um~ . Reports and Materials to be received by: / --/~ ~ -- _~ Dance- Required Date Received Remarks · · Completion Report Yes Well History Yes 7'~/Z" ~t " ~ ~' · .. -$~~ //~ -?/ ~ ~ ,,, , _. · ~ ,. , , , R · C°re Descripti°n 7e~ · Registered Survey Plat /~ · Inclination Survey ~/d - Directional Survey ~~, --?l , Drill Stem Test Reports .-- , , , , ~. . ,, PrcddctiOn Test Reports y e ~.~ 7-~, ( ~-- ~ ~~ .Digitized Data , .. 7~D l~y 18, 1984 Mr. H.D. Haley Conoco, Inc. 2525 C Street, Suite 100 Amchorage, Alaska 99503 Re= ~ ~tm~.-~oim~ Unit Wells A~-~, M-i, M-lA, N-l, N-lA, N-lB Dear Mr. Haley: Available evidence indicates the referenced wells have either been suspended, abandoned, or completed. Our regulations require the submission of well completion reports, deviation ~urveys, logs, and other data within 30 days of the suspension, abandonment or completion of the well, whichever comes first. Please submit the required reports and data at this time. Sincerely yours, Harry W. Kugler Commissioner Ic~B.lg.8 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 December 22, 1983 Mr. Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Monthly Report of Operations - Milne Point A No. 3 The original and a copy of the subject reports are attached. If you have any questions, please contact Don Girdler at 279-0611. SHB/kr Attachment ,_~ ~ ~_:. STATE Or: ALASKA ~-, ~ ALASKA ( · AND GAS CONSERVATION CO ")IlSSION ~-- MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well )l~ Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 83-1 3. Address 8. APl Number 2525 C STreet, Suite 100, Anchorage, Alaska 99503 50-029-20891 4. Location of Well at surface 1918' FNL, 1546' FEL, Section 23, T13N, RIOE, 13. M. 5. Elevation in feet (indicate KB, DF, etc.) 56' KB 6. Lease Designation and Serial No. ADL 47437 9. Unit or Lease Name Milne Point Unit 10. Well No. A-3 11. Field and Pool Kuparuk River Field Upper Cretaceous For the Month of November ,1983 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Continue testing "N" & "0" series sand through 11/21. On injectivity testing of the "N" & "0" series sand, Water at months end, 11/22 begin water injection continuing 13. Casing or liner run and quantities of cement, results of pressur9 tests 14. Coring resume and brief description 15. Logs run and depth where run 1 6. DST data, perforating data, shows of H2S, miscellaneous data Production test data will follow on the completion report. 17. I here that the foregoing is true and correct to the best of my knowledge. ~ !~;!~-, .... ~1~:. SIGNED '~ _/~ .~'~'--- - TITLE Manager-Engineering DATE 12-22-83 NOTE--Repof/n 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 (~servation Commission by the 15th of the succeeding month, unless otherwise directed· Form10-404 AFE 10~7 ~ 1F)2z[ ar~_r-m /,~/ Submit in duplicate STATE OF ALASKA ALASKA ;_AND GAS CONSERVATION C(. MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL~( ,~ 1. O.T,,H E R [] 2. Name of Operator 7. Permit No. . '. Conoco Inc. 83-1 : 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 5o_029-20891 4. Location of Well 1918' FNL, 1546' FEL, Section 23, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 56' KB 12. I 6 . Lease Designation and Serial No. ADL 47437 9, Unit or Lease Name ~ Milne Point Unit - 10. Well Number A-3 11. Field and Pool Kuparuk River 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 X~ 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 last Sundry Notice for the A-3 well was approved by the State on October 27, 1983. In this notice we discussed (1) The proposed tests for the "0" series and "N" Series sands, (4) A proposed injectivity test~and (3) The proposed suspension of the well. Our production test have been completed and the water injectivity test will be finished-up by December 9. The change of plans that we proposing dealswith the suspension of the well. Rather than suspending the well as per step no. 6 of the previous Sundry Notice the following procedure is proposed. 1) 2) 3) 4) 5) Note At the conclusion of the final TDT log run, displace the top 3000'± of the 2 7/8" tubing with diesel. ~ With the well shut-in at surface, to prevent back-flow, RIH with a 2.1875" O.D. wireline bridge plug and set in the 2 7/8" tubing at 4000'±. Set a BPV in the 2 7/8" and close the master valve. Displace the 9 5/8" X 4½" and 4½" X 2 7/8" annulus with 9.6 ppg NaCL brine, then displace the 9 5/8" X4½" annulus with diesel to 500'± (26± bbl). While choking back returns up ~he 9 5/8" X 4½" annulus, displace the 4½" X 2 7/8" annulus with 500' of diesel (4± bbl). Place a pressure gauge on the casing head. Close all casing and tree valves. Rig down and release rig. · Verbal approval of this procedure was given by Mr. Chatterton on December 2, 1983. Date 12-5-83 14. I herebyp~.~ify that the foregoing is true and correct to the best of my knowledge. SignedL'~t4,..~/,{~,~ __~ ~~_~./~,~ Title Production Enqineer The space below for Commission use Conditions of Approval, if any: Bi' LI]I,I?,ii[ (~. S~IITli ' APproved Cop'S' Returned By Order of COMMISSIONER the Commission Approved by Form 10-403 Rev. 7-1~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~.~, STATE OF ALASKA ._~. ALASKA ,L AND GAS CONSERVATION C IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL []7~ Conoco Inc. ~~ 1918' FNk, 1546' 2. Name of Operator 3. Address 2525 C Street, Suite 100, Anchorage, AK 99503 4. location of Well Permit No. 83-1 Number , 5o- 029-20891 ! 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 56' KB I ADL 47437 i2. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data OTHER )[~ -9. Unit or Lease Name Milne Point Unit FEL, Section 23, T13N, RIOE, U.M. lO. Well Number 1~- A-3 Kuparuk River Field NOTICE OF INTENTION TO' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Water Stimulation Repair Well [] Change Plans [] Injecti vi t~epairs Made Tubing [] Other O(Test Pulling Tubing Pull SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other (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). As per the Sundry Notice approved by AOGC on November 18, 1983, the following oper- ations have been performed as part of the water injectivity test' 1) Log well with TDT tool (base run). 2) Run step rate test (no parting or fracturing was observed up to a rate of 2140 BPD and a pressure gradient of 0.673 psi/ft; this was maximum injection rate). 3)Inject 850 bbl cold water and log temperature recovery. 4) Inject water at reservoir temperature until the cumulative injected volume is 16,000 bbls (original notice called for injecting only 13,000 bbls at this point). 5) Log well with TDT tool (intermediate run). In the course of preparing for, and doing the intermediate TDT logging, 16,000 bbls were injected instead of the originally planned t3,000 bbls. The intermediate TDT logs indicate that an additional 9,000 bbls of wat. er_.i:njecti, on..are,~necessary'to:'/ verify that the oil saturations being measured by the TDT tool are residual oil saturations to water injection. _It. i~s__.n__ow pro. posed that the above referenced Sundry Notice be amended to reflect an addition21 9,000 bbls of water injection, which will result in a cumulative total injection volume for this test of 25,000 bbls. Remaining work will then consist of- 1) Inject 8,000 bbls of warm water (90°F)(cum volume=24,000 bbls). '2) While injectin'g, run radioactive tracer tool. --OVER-- 14. (he'by certif,,y that the foregoing is true and correct to the best of my knowledge. s~g " ~ ,~t~e Sr. Reservoir En§ineer Date 12-5-83 The space below for Commission use Conditions of Approval, if any: Approved by ,~,pproved Copy Returned By OrOer of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 AOGC (3), Wellfile, AEH Rev. 7-1 ~80. Continue proposed procedure: 3) Inject 1000 bbls of cold water and log temperature recovery. 4) Log well with TDT tool (final run). 5) Procede with suspension of well~ "-" STATE OF ALASKA ~ ALASKA LAND GAS CONSERVATION CC MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER)~ 2. Name of Operator 7. Permit No. Conoco Inc. 83-1 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, AK 99503 "' 50-029z20891· ' 4. Location of Well 1918' FNL, 1546' FEL, Section 23, T13N, R10E, 5. Elevation in feet (indicate KB, DF etc.) 56' KB 6. Lease Designation and Serial No. ADL 47437 9. Unit or Lease Name Milne Point Unit 10. Well Number A-3 11. Field and Pool Kuparuk River Field 12. Check ApprOpriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation - Water . , Repair Well [] Change Plans II ...... Repairs ~v~aoe ln3ecT,3vl Pull Tubing [] Other [~ ~. , ~llingTubing I.eST, (Note: Report multiple completions on Form 10-407 with a submitted-Form 10-407 for each completion.) (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). As per the Sundry Notice submitted to AOGC on October 27, 1983, the N and 0 Series sands have been perforated and production tested, The perforated interval is as follows' "NA" 4508' - 14'; "NB" 4536' - 42';"NC" 4556' - 62'; "ND" 4575' - 80'; "NE" 4584' - 4602'; "OA" 4657' - 94'; and "OB" 4728' - 54'. J.l~is now pro]~osed that a water injectivity test be conducted in this perforated interval. The g~lS-of the '{6st are' 1) Determine parting pressure; 2) Determine residual oil saturations to water flooding; 3) Determine injection profiles and coverage. The water source will be MPU B-1 (Prince Creek Formation with 3500 ppm TDS). Estimated start of proposed work November 21, 1983. Proposed Procedure' Z) I h,9.~eby certify that the foregoing is true and correct to the best of my knowledge. nedL~'~'kJ. ~~ Tit,e. Sr. Reservoir Engineer The space below for Commission use RECEIVED Log well with TDT tool (base run). !~uv !~. ~'¢ 2) Run step rate test in 100 BWPD increments. 3) Inject 1000 bbl. of hot water (160°F). Alaska Oil & Gas Cons. 4) Log temperature decay. Anchorage 5) Inject warm water (90°F) for seven days at a rate below parting pressure (estimated volume = 12,000 bbls; cum volume = 13,000 bbls). 6) Log well with TDT tool (intermediate run). Inject warm water (90°F) for three days at the same rate as' step 5 (~_stimat~_d volume_ -over- Date 11-17-83 Conditions of APproval, if any: Approved by COMMISSIONER Approved CoF¥ Returned Subsequent Work_ ~ ,~.,~Rep°rterl Dated By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 AOGC (3), ~'lel 1, Fi 1 e, AEH Continue #7 7) =6,000 bbls.; cum volume = 19,000 bbls). 8) While injecting, run radioactive injection profile tool. 9) Inject 1000 bbls of hot water (160°F) (cum volume = 20,000 bbls). 10) Log temperature decay. 11) Log well with TDT tool (final run). 12) Procede with suspending well as detailed by step 6 of Sundry Notice-of~'~October.27,~983. Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 November 11, 1983 Mr. Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Subject- Monthly Report of Operations - Milne Point A No. 3 The original and a copy of the subject report are attached. If you have any questions, please contact Jerry Fritsch at 279-0611. Very truly yours, Charles Taylor Administative Coordinator SHB'tt attachment MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well)~ Workover operation [] ~(~ 2. Name of operator 7. Permit No. Conoco Inc.: 83-1 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, AK 99503 5o- 029-20891 4. Location of Well at surface 1918' FNL, 1546' FEL, Section 23, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease D.esignation and serial No. 56' KB ADL 47437 For the Month of 'October ,1983 9. unit or Lease Name Milne Point Unit 10. Well No. ^-3 11. Field and Pool uparuk River Field pper Cretaceous 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Continue testing - final results will follow on completion report. 13. Casing or liner run and quantities of cement, results of pressure tests Squeezed perfs @ 4016'-4049' w/125 sks. Cold Set I cmt. on 10-18-83. Squeezed perfs @ 4268' - 4288' w/75 sks. Cold Set I cmt. on 10-23-83. 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE ).!::'!!. ,!j. 16. DST data, perforating data, shows of FI2S, miscellaneous data On 10/14 perforated f/4016' - 4049' (KB) w/12 SPF in the KA sand. On 10/29 perf. w/12 SPF; 4728' - 4754' 4695' - 4687' 4602' - 4584' 4580' - 4575' 4562' - 4556' 4542' - 4536', 4514'- 4508' in the OB, 0A, & N series sands. 17. I herebyce~hat the foregoing is true and correct to the best of my knowledge. SIGNED .~¢ U'~~~ TITLE Manager- Engineerinq DATE November 11:lag3 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 AOGCC (2~ AFF 1(117 Submit in duplicate Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 October 18, i983 Mr. Lonnie Smith, Commissioner Alaska Oil and Gas_ Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Commi s s i on Dear Sir- Subject' Mon%hly Report of Operations - Milne Point A No. 3 The original and a copy of the subject report are attached. have any questions, please contact Jerry Fritsch at 279-0611. Very truly yours, Charles Taylor Administrative Coordinator SHB'tt Attachment If you ~ STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION COMMISSION SUNDRY NOTIC $ AN D REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHERXtXl 2. Name of Operator Conoco Inc. ai~;, Oil &, (~,as Co~c;~ Com~:'-~Jssio/, 3. Address ~,iiCh,)~'5~, 2525 C Street, Suite 100, Anchorage, Alaska 99503 4. Location of Well 1918' FNL, 1546' FEL, Section 23, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 56' KB ADL 47437 12. 7. Permit No. 83-1 8. APl Number so029-20891 9. Unit or Lease Name Milne Point Unil; 10. Well Number A-3 11. Field and Pool Kuparuk River 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 [] 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). As per the Sundry Notice submitted to AOGC on July 14, 1983 the three Upper Cretaceous Formations have been evaluated. These sands were the; * "OA" 4694'-65' (29') "MA" 4288'-68' (20') "KA" 4049'-16' (33') I.t is now proposed that we perforate and test the "N" series sands at' 4508'-14' (6'); 4536-~42~(6'); 4556'-6'2' (6'); 4575'-4580' (5'); 4584'-4602' (18'). In addition the "OB" sand would also be perforated at 4728' to 4754' (26'). The 1) 2) 3) 4) 5) 6) followipg is a proposed sequence of events; Perforate all proposed intervals. RIH with a DST assembly and flow test the "0" and "N" sands (co-mingled). POOH with the DST assembly then run-in with a downhole pump and pump test the "0" and "N" sands. POOH. Set a bridge plug between the "0" and "N" sands. RIH with a DST assembly and flow the "N" sands for fluid samples and pressure data. Suspend the well by: a) Fill the well with kill fluid, e) Install.the Production Tree. b) Set a bridge plug at 2000'+. f) Set a BPV and close all surface valves. c) Fill the top 1800' of the well with diesel. d) Hang-off 1700'_+ of 4½" tubing. -over- 14. I herel~y~ertify t..hat._[the foregoing ~rue and correct to the best of my knowledge. Signed ~~'~.. Y ~' ~. ~.~) ,_ Title Production Engineer The space below for Commission use TM ~ '~'~-'- ~ Date10-27-83 Conditions of Approval, if any: Approved by. OR!~':HA[ S l,:1,q £D BY H~,R~¥ W. KIIGLEII Approved Copy . .~.r,..~ ~!" '' Return, e_d .... %fork Ileporte~ By Order of COMMISSIONER the Commission Date /~' Z 7-~ j c"~rm 10-403 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Note' An injectivity test ~is proposed for either the "0" or "N" sands. Dependent upon the results of the prodUction tests. * The "OA" sand was unintentionally perforated 8' high (4686'-4657'). It is proposed that the bottom 8' of the sand be perforated prior to the "0" and "N" sand test. STATE OF ALASKA MONTHLY ALASKA(' ". AND GAS CONSERVATION CO /IISSION REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well rX]X Workover operation 2. Name of operator 7. Permit No. Conoco Inc. 83-1 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 5o-029_20891 4. Location of Well atsurface 1918' FNL, 1546' FEL, Sec. 23, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 56' KBI ADL 47437 9. Unit or Lease Name Milne Point Unit 10. Well No. ^-3 11. Field and Pool Kuparuk River Field Upper Cretaceous For the Month of. September ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Continue testing the well completion report. in the 0A sand. Final results will follow on 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 ~;. DST data, perforating data, shows of H2S, miscellaneous data On 9-30-83 perforated 4268' - 4288' w/12 spf. in the MA sand. Isolated the "0A" perforations by setting a packer plug in the model 16 packer at 4294' 17. I hereby' certify that the foregoing is true and correct to the best of my knowledge. S,GNED ' .. _ T,TLE Manager-Engineering DATE , / ~, //7~'~ NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate h 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, Alaska 99503 September 21, 1983 Mr. Bill Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: In accordance with A.O.G.C.C. Regulations, Article 6, Section 536, please find attached a complete set of core samples from the Milne Point Unit Well A No. 3. This set consists of 30 core samples from the following intervals: 4117'-4122' 4289'-4300' 4665'-4676' Each core sample has a volume of at least one cubic inch and is packaged in a labeled cloth bag. It is our understanding that these core samples will be handled as confidential material for the remainder of the 24-month Confidentiality Period. re lease acknowledge receipt and content of this material by signing and turning the attached copy of this letter in the enclosed envelope. If there are any questions, please contact either Jim Fox or myself at 279-0611. Very t~ruly yours, R. J. Francis Manager - Engineering JBF/kr Attachment MEMORANDUM State of Alaska ALAS~~IL~,A~D -GAS CO~SERVATIO~ COMMISSIO~ TO: C.V./~a~er~on DATE: September 16, THRU: ~ie C. S~th C~mi s s ioner TELETHON E NO: 1983 FROM: Harold R. Hawkins ~ ~.--- SUBJECT: Petroleum Inspector Cleanup Inspection for Extension of Suspended Status, Conoco's Milne Point A-3, Sec. 23, T13~,R10E, U[~, Permit 83-1. Wednesday, August 1.7_, 1983: I left Conoco's Milne Point A-2 well tb C'6~oc~"s A-3 well.- The well sign was on location with all data okay. - 'The well and location cannot be approved .for cleanup or extension of suspended status, because Conoco has a w~rkover rig on well testing at this time ~and are using A Pad for a staging area. I took pictures to verify conditions attached to this report. I filled out an A.O.G.C.C. report which is attached. .In su~am~ry, w~en I inspected Conoco's ~Jilne-Point A-3 well and location, I found that Conoco had a workover rig on well performing test's. .h~s well is not in a sUsr~nded status. Attachments Suspended Well and Location 20 AAC 25, ARTICLE 2 Repor~ FILE INFORMATION: Operator' ~ ~/J~-.67 _ Addre s s Date Suspended Surface Location of Well /_~/~ Ft. F__~__n, 73-~/~ ..Ft. Sec.~], TJ~_ ~/, R~Z~ Ac , t) M- Permit No. ~--7 '~ L API No. 50 Unit or Lease Name well No. .A._ Field & Pool Condition of Pad_ Well head - Ail outlets plugged Well sign - Attached to well Attached to well Attached to ._ head guard Information correct Ye s No Ye s No No Cellar.- Opened ~ No Rat Hole ~ G No, Filled Yes No ed Yes. No Covered Yes No Covered Yes No WaterWell - Plugged off capped Open Exp la na ti on Photograph's taken to verify above conditions Yes No Explanaton c~. ~_/~_-F~xsJ _7 .,& ~f ~.~2 .7'~ ~ ?_,~_~_ / F/ £ ' .~.,.~_ _~. !~ ~ ,> E.~,_ _ _~? ~ ~ _,~ ~) . ~_~. -_Ez~L_.. ~ ~ ~_-~. ~_~ ~ Work to be done to be acceptable . P~_~~'_ ~,,~. ~ .!.5~o~ /z~.~ ~.~O~F)rn~,~ _~.~ TAt/_q u~.t,._, .................. This well and location is (acceptable)' ~p~able-)~to be classified as suspended for the period of 19 ---f~_ 19 . Inspected by: Revised 8/24/82 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 September 5, 1983 Mr. Lonnie Smith, Commissioner Alaska Oil and Gas. Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subject: Monthly Report of Operations - Milne Point A No. 3 The original and a copy of the subject report are attached. If you have any questions, please contact Jerry Fritsch at 279-0611. Very truly yours, ~~~s Ta~~ Administrative Coordinator SHB:tt At tachment '- ,'-" STATE OF ALASKA ALASK,, OIL AND GAS CONSERVATION ~ ;MMISSION , MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ( 1. Drilling well FT~ Workover operation [] 2. Name of operator Conoco Inc. 7. Permit No. 83-1 3. Address 8. APl Number 2525 "C" Street, Suite 100, Anchorage, Alaska 99503 50- 029-20891 23, T13N, R10E, U.M. 4. Location of Well at surface 1918' FNL, 1546' FEL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 17.4' ADL 47437 9. Unit or Lease Name Milne Pt. Unit 10. Well No. ANo. 3 11. Field and Pool Kuparuk River Field Upper Cretaceous For the Month of. August ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Flow testing and testing with Kobe pump assembly. Detailed test results will follow on completion report. The well was gravel packed at the end of the month. 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 Log CBL VDL CCL Gamma Ray From To 4980' 2500' 6. DST data, perforating data, shows of H2S, miscellaneous data Perforated 4665'-4694' with 12 spf 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~~ ~ ~~-'~'~-~z/J TITLE Senior Drilling Foreman DATE 9-2-83 NOTE--Rep on 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, Alaska 99503 August 15, 1983 Mr. Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subject: Monthly Report of Operations - Milne Point A No. 3 The original and a copy of the subject report are attached. If you have any questions, please contact Jerry Fritsch at 279-0611. Very truly yours, ~ Charles Taylor /~ Administrative Coordinator SHB:tt Attachment STATE OF ALASKA //~~ . ' ALASK/ 1LAND GAS CONSERVATION G /IMISSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIO · Drilling well ~ Workover operation [] _~. Name of operator 7. Permit No. Conoco Inc. 83-1 3~ Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50_029-20891 4. Location of Well atsurface ~918' FNL, 1546' FEL, Section 23, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 56' KB ADL 47437 9. Unit or Lease Name Milne Point Unit 10. Well No. ANo. 3 11. Field and Pool Kuparuk River Field Upper Cretaceous For the Month of. July , 19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks T.D. - 5099'. Begin moving completion rig to location on 7-27-83. 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 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, r§gardless of ti~e status of operations, and must be fired in dup~cate 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, Alaska 99503 July 7, 1983 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Sundry Notice to Complete and Test Milne Point A No. 3 (Permit 83-1) Enclosed for your approval are the original and two copies of the proposed Sundry Notice. If you have any questions, I can be reached at 279-0611. Yours very truly, D. R. Girdler Production Engineer tt enclosure · " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator Conoco Inc. ~¢V 3. Address YV 2525 C SCree¢, Su~¢e 100, Anchorage, Maska 99503 4. Location of Well ~, II M L~o'~ -- ~9}8' FNL, 1546' FEL, Section 23, T13N, R10E, ~.,.,. 5. filevation in feet {indicate KB, DF, etc.) ~ ~. ~ease Designation and Serial ~o. 56' KBI ~Dk 47437 12. Check Appropriate Box To Indicate ~ature of ~otice, ~eport, or Other Data 7' P~itlN°'- ~8. APl Number ~- 029-20891 ~W~lJnit or Lease Name Milne Point Unit 10. Well Number A-3 11. Field and Pool Kuparuk River NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~X 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.) 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). C~ U~/,~J ~ The Milne Point A-3 well was drilled a ~"t,vpe hole to a total depth of 5099' MD an "S" ~ (4809' TVD). The well was cased then~on February 2, 1983. It is now proposed that the well be re-entered for completion and testing operations in the Upper Cretaceous formations. There are three sands to be evaluated. 1) "0A" 4694' - 65' (29') 4376' TVD /-~ 5"ooo~ ~O¢,~L I1~11 I I I I } ' ' 2) 4290 - 65 (25) 3978 TVD ~_ _ a~ I_~ ~ .... ~~~r "~" 4049' 16' r33' ~ 3730' TVD ~~ 7-~~ ,' ~ ~ ~_~~.r ' , The general procedure for the completJon and testJng of ~aCh sand wJll be ~) Perforate overbalanced. 2) RiH ~Jth a DST assembly and surge the formatJon then swab to determJne the need for sand control. 3) Gravel pack the sand Jf necessary. 4) RIH ~Jth a do~nhole pump assembl~ and produce the sand for approxlmately four weeks then run a buJld-up for approxJmatel~ two weeks (a downhole pressure gauge ~Jth surface read-out wJ11 be used). 5) Isolate the sand and proceed to the next Sand up the hole. -OVeP- on F~ ~o. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 1~ _(9-~ ~x~ .~/~--~ ~p~_._ Title Production Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by ORIG:NAi. SIGNED HARRY W, KBGLER Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate The produced oil will be injected into ARCO's disposal well while the gas is to be flared over the reserve pit. The only variation from this general procedure will be a two week water injectivity (fresh water)/fall-off test proposed for the "MA"sand. The test is expected to begin the last week in July and extend for approximately five months. After testing the top sand the well will be~m~rari,y a~ar~~ 1) Filling the well bore with kill fluid. 2) Setting a bridge plug at 2000'+. 3) Fill the top 1900' of well with diesel. 4) Hang-off 1900' of 4½" tubing in the well. 5) Install a production tree. 6) Set a BF'V and close all surface valves. · -.. .¢ ¢ ;}% 'W.-, ?' <2: =%. March 18, 1983 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 Mr. Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Monthly Report of Operations - Milne Point A No. 3, D No. 2 & D No. 2A Sundry Notice - Milne Point D-2A The original and a copy of the subject reports are attached. If you have any questions, please contact Gary Merriman at 279-0611. Very truly yours, W. M. Haskell Administrative Coordinator SHB/kr Attachment Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA · ALASKA ?~-. AND GAS CONSERVATION CC 'MISSION MONTHLY REPORT DRILLING AND WORKOVER OPERATIONS '1. Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 83-1 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50-029-20891 4. Location of Well at surface 1918' FNL, 1546' FEL, Section 23, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 56' KB 6. Lease Designation and Serial No. ADL 47437 9. Unit or Lease Name Milne Point Unit 10. Well No. AND, 3 11. Field and Pool Kuparuk River Field Upper Cretaceous For the Month of February ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks T.D. - 5099'. Rig Released on 2-6-83. 13. Casing or liner run and quantities of cement, results of pressure tests Size Wt. Grade From To 9 5/8" 47# L-80 O' 5095' Cement 950 sks. Class G,downsqueezed 100 bbls. water, 250 sks. Permafrost C and 130 bbls. Arctic Pack. 14. Coring resume and brief description Core #1- 4117 - 4147 = 30'; rec. Core #2- 4289 - 4318 : 29'; rec. Core #3- 4665 - 4695 = 30'; rec. 5.5' (18%) Unconsolidated sand and shale. 11.6" (40%) Predominately unconsolidated sand w/minor mudstone and clay. 12' (40%) Predominately unconsolidated sand. 15. Logs run and depth where run LOGS From To DIL, BHCS, SP, GR 2497' 5095' LDT/CNL/NGT 2497' 5097' EPT 2497' 5083' NML 3050' 5087' LOGS From To Sidewall Cores 4020' 4750' (81 core., 6. DST data, perforating data, shows of H2S, miscellaneous data The well will be tested at a later date. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SlGNED.~~~~ T,TLE Drilling Supervisor DATE 3 ' /?- ~3 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 Rev. 7-1-80 AFE 1017 AOGCC (2) Submit in duplicate Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 February 18, 1983 Mr. Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subject: Monthly Report of Operations - Milne Point A No. 3 & A No. 2 The original and a copy of the subject reports are attached. If you have any questions, please contact Gary Merriman at 279-0611. Very truly yours, W. M. Haskell Administrative Coordinator SflB/kr Attachment Anchorage STATE OF ALASKA ~---. ALASKA C..~ AND GAS CONSERVATION CO, AISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well IX1 Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 83-1 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 5o-029-20891 9. Unit or Lease Name Milne Point Unit 4. Location of Well at surfaoe 1918' FNL, 1546' FEL, Sec. 23, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 56' KB 6. Lease Designation and Serial No. ADL 47437 10. Well No. A-3 11. Field and Pool Kuparuk River Field Upper Cretaceous For the Month of January ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud on 1-27-83. Depth on 1-31-83 - 4117'. 13. Casing or liner run and quantities of cement, results of pressure tests Size Wt. Grade From To 20" 94 PELP O' 80' 13 3/8" 72 L-80 O' 2500' Cement To Surface 2000 sks. Arco Fondu & 500 sks. Permafrost C. 14. Coring resume and brief description Coring just began at months end, a summary will follow next month, 15. Logs run and depth where run 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 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~,O4 AFE 1017 AOGCC (2) Submit in duplicate THRU: MEMOR -,NDUM Stale gLASKA OIL AND GAS CONSERVATION COMMISSION TO: :rton " FILE NO: FROM: Lonnie C. Smith Commi s s ioner Doug Amos Petroleum Inspector of Alaska TELEPHONE NO: SUBJECT: February 2, 1983 10 8A/M Witness BOPE Test on Conoco's Milne Pt. A-3 Well Sec. 23, T13N, R10E, UM Permit No. &3-01 on Nabors Rig No. 27E Sunday, January 30~, .1982 - The BOP test comiL~nced at 11:00 a.m. and w~s concluded, at 2:30 p.m. I filled out an A.O.C.C.C. BOP test report w~.ich is attached. There were no failures on this test. In summary, I witnessed the successful BOP test on Conoco's Milne Ft. A-3 wett. O&G 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Ope ra tor Location: Sec 2~ T/~/~Rto Drilling Contractor Date 5~F~; '~] 9 ~.~_ Wel 1 /~1'/~ Representative Permit ~ lB~sing Set Rig ~ Z7~ Representativ~ Location, General ACCUMULATOR S'YS TEI,~ Well Sign General Housekeeping Reserve pit Rig Full Charge Pressure....~.,0(30 psoig Pressure After Closure ]~.O0 psig 200 psig Above Precharge Attained: mia /~ sec Full Charge Pressure Attained: / min /Z~-sec N2 ~Z..~' Z/Z% ~Z~.% .... Zz~o psig ~ Controls: Master ~ Remote ~ Blinds switch cover ~ BOPE Stack Annular Preventer.. ~ Pipe Rams ~'~ Blind Rams'~/ Choke Line Valves H.C.R. Valve Test Pressure Kelly and Floor Safe_ty Valves Kill Line Valves Check Valve ~ / Test Results: Failures. Upper Kellz Lower Kelly ~/ Ball Type Inside BOP Choke Manifold No. Valves Test Pressure Test Pres sure Test Pressure Test Pressure / Test Pressure No. flanges 3~ Adjustable Chokes Hydrauically operated choke -- Test Time -~ hrs... Repair or Replacement of failed equipment to be made within InspeCtor/Commission office notified. Remarks: days and Distribution orig.' - AO&GCC cc - Operator cc - Supervisor Inspector ,; - *' ~" STATE OF ALASKA ~'"'-' ALASKA U,L AND GAS CONSERVATION CL,-,vlMISSION . SUNDRY NOTICES AND REPORTS ON WELLS . . . Conoco Inc. 83-1 Address ' ' ' 8 APl Number 2525 C S~ee~, Suite Z00, Anchorage, Alaska ~9503 . ~o-02~-2089~ L~ation of Well g. Unit or Lease Name 4. Milne Poin~ 1918' FNL, 1546' FEL, Section 23, T13N, RIOE, U.M. 10. Well Number A-3 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Desig.nation and Serial No. 56' KBJ ADL 47437 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Kuparuk River O [] 0 NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (StJbmit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing 0 ~ Perforations O Altering Casing Stimulate [] Abandon 0 '" Stimulation [] ' ~kbandonment Repair Well [-1 Change Plans D(1 Repairs Made [] Other Puli Tubing [] Other 0 Pulling Tubing O (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 Sundry Notice is being submit'ted for approval to change the bottomhole location of the proposed A-3 well and to drill the well as an "S" type hole. The new BHL would be- 220(~' FNL, 2500' FWL, Section 23, T13N, RIOE, U.M. Distance to the nearest lease line would be 3967'. The new T.D. would be' 5100' MD (4786' TVD). The setting depth of the 13 3/8" casing would also. be changed to 2300' TVD (.2504'MD). The revised cement volume will be' '3300+ CF (for 13 3/8"). The nearest that the proposed A-3 well bore will be to another well bore is at 2000' TVD where A-3 will be 90' North. of A-1. This takes the A-1 Gyro Survey into.. The supplement data will be the same as submitted with the drilling permit except for the directional program (see attached sketches). The BOP systems will not change. Signed ~,..~,-~--~..~- _.~_~.._~ ~ Title Engineer The space below for Commission use Date 1-13-82 Conditions of Approval, if any: Approved by BY LgNHIE C, SMITII - COMMISSIONER Approved Copy Returned BY Order of the Commission Date __ Form 10-403 R~v 7-1 -~0 Submit "Intentions" in Triplicate and "Subsequent Reporls" in Duplicate :'9 ::9 o~ old January 7, 1983 Mr. Dan Cirdler, Engineer Conoco, Inc. 2525 C Street, ~Suite 10.r) Anchorage, Alaska 99503 Re: -~;~ilne-Point Unit A-3 Conoco Inc. Pe~i~ No. $3-1 · Sur. Loc. 191$'Fhq~, i546'FEL, Sec. 23, T13}.,~, R10E, U~.~. ~tr_-~.ole Loc. 4429'r'~c]L, 456'FEL, Sec. 23, T13}:!, Dear ~r. Cirlder~ Enclosed is the a~proved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch oD. ir from, cae]', foot of recovered core is required. ~ampIes of well cutttnf~.'s and a nn~d log are not required, h continuous directional survey is required aa poe 29 AAC 25.05~(b)(5). If available, a tauo containin¢ the digitized log infom~ation shall be sub~.~itted on all logs for copying except experimental logs, velocity surveys a~ dipr:~eter surveys. ~4:any rivers in Alaska and their, drainage syster-~s have been -classified as i~portant for the spa~ning or miL'ration of anadr~o,as fish. Operation~ in these areas are subject to AS i6.05.870 and the re~lations promulgated thereunder (~itle 5, Alaska Administrative Code). Print to con-,mencin~y opez'ati~ns you may ~e contacted by the !iabit~t Coordinator's Office, Department of Fish and Cac:~e. Pollution of any waters of the State is prohibited by AE 46, c~,.¢,~.a?ter ¢", .Article 7 an~' the formulations._, pro~;'~ul;.,.,~f~. ........ ted ++,are~)nder (~itle 18, A' "~ ,as,.a Administrative Code, Chapter 70) and rby thc Federal Water Pollution Control Act, as anqended. Prior to eo~;eneing operations you ~ay be contacted by a reure~entative .... ~.,.¢.tment oz Enviro~.~ ..... ntaI Conservation 5~o aid ,~s in scheduling field work, ?lease notify this .office prevention equipment so that a representative of the Con;~:;isaion t~Ir. Dan Girdler t~ilne Point Unit A-3 -2- January 7, 1983 may be present to witness t~sting of the equipment before the surface easing shoe is drilled. ¥~ere a diverter system is required, please also notify this office 24 hours prior to e~eneing equipment installation so that the Comraission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatterton Chai rn~an of .BY ORDER OF~ T~iE COMMISSION Alaska Oil and Gas Conservation Com~.,isston Ene 1 o sure ce: Department of Fish & Game, Habitat Section w/o enel. Department of Enviro~ntal Conservation w/o enel. CVC:be MAYOR'S OFFICE EXT. 211 ADMINISTRATION AND FINANCE EXT. 210 ASSESSING EX.T. 275 PLANNING DEPARTMENt EXT. 245 PUBLIC SAFETY EXT. 238 PUBLIC WORKS DEPARTMENT EXT. 250 HEALTH AGENCY EXT. 265 January 3, 1983 NOrTh SLOPE BorOUGh P.O. BOX 69 BARROW, ALASKA 99723 TELEPHONE (907! 852-2611 i (~,~1 LLER --jiCO.M · i CO,~.~M.T-~::~ ACCOUNTING EXT, 2-39 i i PURC,ASING OEP^R MENT EXT. 214 I ~ ~'~"" ~ ~ ~.: ;> '~ ENVIRONMENTAL SECURITY ~'] ¢~EO{. ' { PERSONNEL ~'3 GEOLC 7~-t. PHYSICAL PLANT ~AT T~ ~' EXT. ~~~-~-E ~._~. HOUSINGExT. 204 AGENCY Mr. H. D. Haley Manager of Alaska Operations Conoco 2525 "C" Street, Suite 100 Anchorage, AK 99503 Re: Conoco Milne Point A-3 Dear Mr. Haley : Pursuant to NSB 19.27.100, subsections G and H, the North Slope Borough has reviewed and granted final approval to the above referenced project. Accordingly, yoUr North Slope Borough Interim Zoning Orinance Permit application authorizing the proposed action is attached. By copy of this letter, we are advising the Division of Policy Development and Planning, and the Alaska Oil and Gas Conservation Commission of our final decision. If you have any questions regarding this final approval, please contact Tom Barnes at 852-2611, Ext. 2L~. . Sincerely, /. Warren Matumeak Interim Zoning Administrator cc: Ralph Andersen, NSB Mayor's Office Harold J. Curran, NSB Attorney Lester Suvlu, Director, NSB EPO John Lewis, NSB Public Works Jim Richards, NSB Public Utilities Shehla Anjum, NSB Permit Coordinator, Anchorage Wendy Wolf, DPDP Blair Wondzell, AOGCC, Anchorage WM/TB/mc o~. x~ ZO" O. 12. C~SIIVG i~ OF~ STACK AIOTE$ : (I) MEI_/££ LINES F, qOld TIlE DI~Itllt, I~ $?OOL. ~V'ItL B~ t~OUTEP TO A C~Qt~tP~ I, SI-{ DO &v"tVIAf'I/VD DI VEt~',~IOILt' ~) JAN 0 ? 1983 Alaska Oil & Gas Cons. Commission Anchorage. . . . , COMOCO, ~ ol - Af lLME POIN7 l~Ot~ STACK FOM ZO"CASi~ " COMOCO IIJC. Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 995()3 December 29, 1982 Mr. C. J. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Enclosed are the original and two copies of the Permit to Drill for Milne Point A-3 along with a $100 check for the filing fee. If you have any questions, please call Don Girdler at 279-0611. Very truly yours, W. M. Haskell Administrative Coordinator SHB/kr Enclosures cc: T. E. Davis, NAP, Houston, w/o Enclosures E. L. Oshlo, NAP, Houston, w/o Enclosures A. E. Hastings, Anchorage, w/Enclosures G. A. Merriman, Anchorage, w/Enclosures L. A. Dinges, Offshore Explor, Houston, W/Enclosures M. K. Bradshaw, Anchorage, W/Enclosures D. R. Girdler, Anchorage, w/Enclosures S. H. Berg, Anchorage, w/Enclosures STATE OF ALASKA .~-- ALASKA O,L AND GAS CONSERVATION CO,,.,vllSSION 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 E] 2. Name of operator Conoco Inc. 3. Address 2525 C Street, Suite 100, Anchorage, Alaska 99503 9. Unit or lease name Milne Point Unit 4. Location of well at surface 1918' FNL & 1546' FEL, Section 23, T13N, R10Ej ~J~ At top of proposed producing interval 3960' FNL & 660' FEL, Section 23, T13N, R10E, U iGc). At total depth 4429' FNL & 456' FEL, Section 23, T13N, R10E i~)(Y~ · 6. Lease designation and serial no. ADL 47437 10. Well number A-3 11. Field and pool Kuparuk 5. Elevation in feet (indicate KB, DF etc.) 56' KB 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 Amount $200,000 15. Distance to nearest drilling or completed A-2 well 120 feet 18. Approximate spud date January 7, 1982 13. Distance and direction from nearest town 14. Distance to nearest property or lease line Deadhorse SE miles33 4898 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 5843' MD (5000 TVD) feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 36 Ol (see 20 AAC 25.035 (c) (2) 21 SIZE , Hole Casing i30'' 20" 300 . psig@ 0 ' .Surface 2340 psig@5000 ft. TD(TVD) Weight 94~ 13-3/8" 72# 9-5/8" 47# L-80 Proposed Casing, Liner and Cementing Program CASING AND LINER SEITING DEPTH Grade Coupling Length MD TOP TVD MD BOTTOM TVD SA, , ' I ' 80' II PELP u 0 0 L-80 BTRC 2748' 0' II 0' 2748' I QUANTITY OF CEMENT (include stage data) 300 CF 3600+ CF (20½" AHS) 117½" 12¼" 80' 2500' 5843'15000' 1000+ CF (2000:':=+ Fillup: AHa = 13½") 22. Describe proposed program: IBTRC I 5843' 2nd Stg: 900± CF incl Arctic Pak See Supplemental Data Sheet, Proposed Directional, Surface Location Plat, and BOP sketches. R E C E IV E D DEC o Alaska 0il & 6.'as Coils. Ccmmissior~ Anchorage 23. I hereby certify that the fore,going is true and correct to the best of my knowledge SIGNED _~~:~..___...._)~%''~ ~__ TITLEEngineer The space below for Commission~'u~ DATE 12-27-82 Samples required I--lYES [~NO Permit number APPROVEDBY Form 10-401 CONDITIONS OF APPROVAL ' Mud Icg required Directional Survey required APl number []YES E~klO {~'-YES []NO 50--OL ~ '-Ld"rJc~/ ¢ Approval date '~,--/., SEECOVER LETTER FOR OTHER REQUIREMENTS I ~//~//"' -"'"'~ '~ ' ' ,~/""////~~~--~ ;OM M I SS, O N E R DATE ,.Tsnus. l~ 6 :~ 19 8 3 ~ ¢, L~/~ C~~~'~ by order of the Commission Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL I. CEMENTING PROGRAM Conoco et. al. - Milne Point No. A-3 Conoco Inc. ~j~ ¢/~'~ ~ 2525 "C" Street, Suite 100 ~ Anchorage, Alaska 99503 ~-~.~Y~ ~77~ A. The 20" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. B. The 13-3/8" surface casing will be cemented with 1600± sacks of Arco Fondu cement followed by permafrost cement which will be pumped until. good lead cement returns are obtained at the surface. Ce The 9-5/8" production casing will be cemented in two stages. The primary cementing job will consist of 900± sacks of class "G" cement pumped around the casing shoe (estimated 2000± of annular cement,~?~-f'~g assuming an AHS=13~"). The secondary cement job will consist of 150 sacks of permafrost type "C" cement followed by 135± barrels of Arctic Pack, pumped down the 9-5/8" x 13-3/8" annulus. II. ANTICIPATED GEOLOGY 0-4500' Surface conglomerates, silt and sand sequences. Estimated based of permafrost at 1700'±. 4500'-TD Predominately sand sequences until the Seabee Shale - expected at 4600'± subsea TVD. III. FORMATION EVALUATION A. Standard mud logging equipment to be used below the surface pipe. B. Cores to be taken as determined by onsight geologist. Ce Wireline logs for the 12¼" 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 GR-caliper. We do not plan to log the 17~" hole. IV. DRILLING FLUIDS A high viscosity gel-fresh water (dispersed) mud system Low solids dispersed gel/water mud system 0' - 2748' 2748' - TD V. DIRECTIONAL PROGRAM The well has a proposed KOP of 500' and will build angle in a south 23.5° east direction. The closest that the A-3 will come to another wellbore is at 1000'± where the proposed A-3 will be 110'± (N35°E) from the existing A-2 well. A Teleco tool is to be run while drilling the surface hole for directional control. DEC o 1982 ' ~ - -' ~::" ::::1:::-: : -:--:- :i. · i ' i i -- ......... , . " t , J- ' 'X'Z .... I;;;; ; ' ; . ' ' ' ] ; I~ - ; ........ ~ t ''' '~ I ~ ' ' I ~ i I ~ j I ~ ... : :l i~~ I : k~* · [ ...... ~: --: :' ~ -~' ' : ~ I ~ J ~ · · ' ~ , , I ~ ,, .~_cc:r:: : ~ ~: : ~., ·' x ~ ~ ,~ ~ ........ I ..... : . i ~ I ~ I .... I l ...... ~ .: ~c~: ~. :. I .... - I I _',~ ;::;j::':t: :.I : ~;:. I' ;: :' ~ I ~ ' I t-~r ..... J:i ' '/' ' ~ ' ~ ~" ' ~ i .......... ~ .... ~ ., , - ~ I ~ .... ,~, ~ ~ ........ . ........ ~ ~ . ' ': T ! : ~l ~ I~ , J --~ ................... ! ' I ~ .... i:' . ': :::: ::::,::: :.'.:,: L:I.-- ' ' ;' , .... ~ .... F ='"'"~' ~ ' · ~ **'4~-~:~i:*'~ .... :-. ~ :~.. : x,i ...... I U· ~ i a~.,., ~ ~ ~: ~ ..... ~.'~...:::. : , . j ....... . ' _:;. -' _ --FLO~LINE ALL ~ ! --; _.~ ........... ~ .... '.~.:x, ...... . ..... ....-, .... ~ 1 ,OP~TOIN~LUO~(5) STATIO~ ..... a ,,_ ~ ooo ~~ - ~- 5000 SI~E OUTLET3 ~ VALYE~ :~ '~ I !._~_~ ~ CAe~ ~O: ~0~ ~000 CASIMG ..... ~'":' ___-' -':~.~ ---~-: u: .... ~ -~000 FLAHGED ~TLET~ . .... ' - :'~ -" --'~-' ~::'. - - - "~:~.' ~.~. ' ~ ........................ CO~OCO~ ~ t ~t - ~IL~H ~OIH7 · -~. 't . .- .... .~ ~OtdTt~O(_ ~,'IANIP'O(_L~ LOCIITE'D OME ~ET OF ~LIMD ~A~S AMD T~O OF APPKOP~IAT~ '~IPE HAMS. AMD KIL~ ~AHIFO~DS Kill and choke manifolds to-meet AP I RP 53 Class 5 M standards. Kill Line- 2" 10,000 psi Choke Manifold- 3" -10,000 psi Vent Line- 4" 10,000 psi Accumulator' 3000 psi 180 gal w/Ni trogen back-up Note' Choke mahifold and c6ntrol for the adjustable choke are on the rig floor. ~aj. CJ~ok¢ CHOKE /t KILL MANIFOLDS FOR B3/8" /t ~/;/j'OD CASING BOP STACK ._ L ,.-- I II I ,CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No, ITEM APPROVE DATE (1) Fee (2) Loc ('2 thru 8) (3) Admin (9" thru 11) (4> Casg ~.~f (12 thru 20) ~(21--'t~ru 24) (6) Add: Geology: Engi~earing: rev: 12/06/82 1. Is the permit fee attached ,.~ ................. ' ........ . 2. Is well to be located in a defined pool ............... ' . 3. Is well located Proper distance from property line .... . 4. Is well located proper distance from other wells ...~..' 5. Is sufficient undedicated acreage'available in this' poo~ .. 6. Is well to be deviated and is well bore plat included . 7. Is operator the only affected party .......................... 8. Can permit be approved before ten-day wait .................. · 10. 11. 12. '13· 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO · .. ,,~,/~-,, .... · · · · e e · · ., . Does operator have a bond in fo,r~e, 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 strings .. 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 ~OO~P psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) ...... ' ............ ~ Additional requirements ............................................. ~. REMARKS INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry 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 APPENDIXi No special'effort has been made to chronologically organize this category of information. -: · .. .CONFIDENTiAE INFORMATION ._Furnished By Conoco Inc. VERI~'ICATION bI$I'I ~G YP 010,H02 YERIFICATION LISTING PAGE 1 ;* REEL HEADER ,ERVIC~ NA~E :SERVIC ,ATE :83/02/11 ~RIGIN : IEEL NAME :135241 :ONT1NUATION # 'REVIOU$ REEL ~OM~ENT8 :LIBRARY TAPE :* TAPE HEADER ** ;ERVICE NAME :SERVIC )ATE 83/02/11 )RIGI~ :6640 ~APE NAME :ONTINUATION # :01 ~REVIOUS TAPE :OMM~NT$ :LIBRARY TAPE EOF *****$**~* ~* FILE HEADER FILE NAME :$ERVIC,O01 ~ERVICE NA~E fERSION # : )ATE : ~AXIMU~ LENGTH : 1024 ~ILE TYPE ~REVIO[]S FILE INFORMATION RECORDS ** NE~ CONTENTS UNIT TYPE CATE SIZE CODE :N : CONOCO 000 000 012 065 ~N : NIL ~ 000000 000000 020 016 065 065 ~N : Mi. LNE PO lTA''~ N ~ RA G: IOE 000 000 003 005 roan: 13N 000 000 004 065 ~ ~ C T: 23 000 000 002 065 20UN': N, SLOPE; 000 000 008 065 5TAT: AbASKA 000 000 006 065 ,,:TRYc~MENtS *U'$'At 000 000 006 065 ******************************************************* ~******************************************** ~ , ,¥P O!O,tt02 VERIFICATION LISTING PAGE 2 : ALASEA COMPUTING CENTER * :OMPANY = CONOCO INC, tEGL = MILNE POINT NO 'IELD = MJbNE POINT UNiT :OUNTY [] NORTH SLOPE BOROUGH ;TA~E = ALASKA lOB NUMBER AT ACC: 66407 JUN #! DATE LOGGED: 2'FEB-83 · ,DP: 06HN ~SlNG ~YPE FLUID ~IT SIZE )ENSITY IlSCOSITY FLUID LOSS = 13 3/8" SUR~'ACE TO 2497 = NONDISPERSED = 12,25" = 9 1 LB/G =8.5 RMC = 10,0, C3 RM AT BHT 5,070 M 72,0 DF 4,430 ~ 72,0 DF 3,800 ~ 72 0 D F 3,365 0 1,1~, DF !ATRiX SANDSTONE ******************************************************************************** DATA FORMAT RECORD ** ~NTRY BLOCKS TYP~ SIZE REPR CODE ENTRY 4 I 6~ 8 4 73 60 ~ 65 ,lIN ~ 66 0 )ATUM SPECIFICATION BLOCKS ,VP OlO,B02 VERIFICATION LISTING PAGE 3 SERVICE SERVICE L~,NIT AP1 API APl API FILE SIZE PROCESS SAMPLE REPR ID ORDER # LOG TYPE CLASS MOD NO, bEVEL CODE )EPT FT 0 0 ;FLU [)IL OHM~ 7 0 [ L O D I b 0 H ~I ~', 7 12 ;P DIL MV 7 1 ;R DIL GAPI 7 31 )T BHC US/F 60 52 ;R BMC GAPI 60 ]1 4PM1 bDT PU 0 68 )RMO LDO' G/C3 0 44 ~HOB bDT G/C3 0 35 ~CNL LDT 0 34 ~CNL bDT 0 34 ~EF bDT 0 0 ~GR bDT GAPI 0 0 qRAT bDT 0 42 RNRA bDT 0 0 [HOR NGT PPM 0 0 ~OTA NGT PU 0 0 ~RAN NGT PPM 0 0 SGR NGT GAPI 0 0 CgR NGT GAPI 0 0 ~P5 EPT NS/M 0 0 SA EPT 0 0 8D EPT IN 0 0 ~ATT EPT DM/M 0 0 SR EPT GAPI 0 31 0 0 0 0 0 0 46 0 0 0 0 0 0 0 0 32 0 0 32 0 0 32 0 0 2 0 0 0 0 0 1 () 0 92 0 0 93 0 0 0 0 0 3 '0 0 0 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 0 0 32 0 u 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 ~ 0 4 0 4 0 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 I 68 I 68 1 68 1 68 ! 68 1 68 1 ~8 1 6,8 1 68 1 68 ,1. 68 1 68 ! 68 1 6~ 1 68 ** DATA ** DEPT FCNb NRAT URAN SA 51,1,5 0000 SFLU 94~4 UR~O 555 5000 PEF 4297 RNRA 3887 SGR: -999 25O0 HD OEPT SP FCNL NRAT URAN SA 5100,O000 SFLU -18'4688GR 41,8457 DRHO 297 3887 3475 s D DEPT 5000,0000 SFLU SP -19,4219 GR NPHI 39,9902 DRHO FCNL 508,2500 PEF , 82, -999, 3 5391 8125 [HTo~t 0151 R 3,1719ILD 61, DT '0 , R H 0 B 2,4043 CALI 4,2656 IbM I07,7500 GR , 7646 NCNL 1,2 500 SGR ,4922 POTA 87,9375 -999,2500 GR 4 2461, 7402 MCNL 1,~ SGR POTA 87,9375 TPL 264,6666 3,2187 2 9258 82 ~125 2o58 0000 98 4375 0 0298 -999 ~500 -999 2500 2 9238 82 8125 2058 0000 95 43'75 0 0298 18 8750 -1,76 8750 3,1855 61,~750 1960, 000 67,7500 ,¥P 010.}~.02 VERIFICATIO[4 LISTING PAGE 4 RAT !RAN ~EPT ~P 'CNb tRAT IRAN ~A ~EPT ;P IPHI 'CNL IRAT IRAN ;A )EPT 4PHI 4RAT JRAN ;1% )EPT ~P ~PHI ,~ N' C b ~RAT JRAN )EPT ~P ~lPHI FCNL qRAT ~J:RAN )EPT FCNL IgRAT DEPT SP 3.4824 RNRA 1,3730 SGR 0,6995 HD 4900 -30 39 489 3 0 0 .0000 SFLU .5156 GR ,1113 DRHO .0000 PEF ,4355 RNRA ,~214 SGR .7448 HD 4800 -37 41. 480 3 0 0 0000 8FLU 0313 GR 3574 DRHO 2500 PEF 5703 RNRA 6816 SGR 7448 HQ 4700 -42 4O 451 3 0000 SFLU 2813 GR 9180 DRHO 5000 PEF 5488 RNRA O5O8 SGR 9759 HD 4600 -47 43 427 3 0 1 0000 SFLU 031] GR 652 DR}~O 500 PEF 836 RNRA ~506 SG~ 3022 HD 4~00 51 44 448 0 0000 SFLU 0313 G:R 2871 DRHo 2754 9306 4~oo,o0oo .X~.oO0O ,1660 D~HO ,0000 ,7480$.GR ,0513 HD 4~00,0000 SFLU 89,I:875 GR 3.7935 THOR 67 7500 CGR 13~1893 EATT 2.7773 52.3125 DT -0.0249 RHOB 2,4180 CALl 3.8963 THOR 59.4J75 CGR 12.9373 EATT 3,6387 ILD 68,8125 DT 0.0000 RHOB 2,4453 CALI 3,9267 THOR 82,4375 CGR 12.9373 EATT 3 67 0 2 3 77 12 8379 ILD 3750 DT 0117 RHOB 6367 CALI 7647 THOR 0625 CGR 9310 ~ATT 7 46 0 2 3 5:2 12 2734 IDb 3750 DT 0288 RHOB 426 CA:bi 622 THOR 9~87 CGR 9814 EATT 3 7852 3 9453 ILD ::7~ 78 75 0 CGR 13 0392 EATT 3,3613 ILD 34'6250 DT 9.0469 POTA 57.3750 TPL 329.4497 GR 3,8027 IL~ 97,1875 OR 2,2383 NCNb 12.6797 SGR 8.8203 POTA 56.2500 TPL 301.4531 GR 3.4316 IbM 109.5625 GR 2.2988 NCNb 13.1641 SGR 10,6~75 POTA 77,2500 TPL 301,7500 GR 3.6055 IbM 107,5625 GR 2,3633 NCN5 13,2109 SGR g,O000 POTA 69,~250 TPL 307. 000 GR 5,7500 I[0H 112,5625 GR 2.242:2 NCNb .469 POTA 46,5:313 TPL 232.4167 GR 3 8672 IbM , 734 NCNb · POTA 287, 666 GR 4,2031 110,3750 GR 2,3418 NCNb 65,$000 TPL 307,0547 2,0996 ILS 13!0,0000 GR 0 0166 13i8254 64 O430 3.5996 52,3125 1936,0000 59,4375 0,0171 14,0425 59,3730 3.3457 b8,8125 1784.0000 82,4375 0,0244 15.1484 82.9375 3.6719 67 375O 1782 0000 77 0625 0 0225 14 5443 71 9375 5 8281 46 3750 1713 0000 5~ 9687 0156 13 0234 50 28~3 6~ 8340 8125 O00O 0625 0 01,51 15 0443 78 7500 4,1484 72,6250 1672,0000 78,7500 0,0200 14,3636 78,6318 2 2422 34:6250 ,VP OI.O,H02 VERIFICATION LISTING PAGE 5 IPHI 48,7793 i,)RHO 'CNL 378 7500 PEF IRAT 3,9805 RNRA IRAN O,BBB2 SGR ;A 1,1164 HD '0,0103 1,7617 4,2128 37 4063 13:2524 RHOB CALl THOR CGR EATT )EPT 4200 ;P -56 ~PHI 38 ,'CNL 549 ~RAT 3 IRAN 0 ½A 0 0000 SFLU 7813 GR 0371 DRHO 5000 PEF 3906 RNRA ,9014 MGR ,7448 HD 3,5176 45,6250 -0.0239 2.2227 3,7326 57.5313 13,1074 ILO DT RHOB CALl THOR CGR EATT )EPT 4100 ~p ,-81 ,}PHI 48 FCNL 391 ~{RAT iRAN 1 ,0000 SFi, U 8125 GR 6816 DRHO 0000 PEF 9766 RNRA 0264 SGR ,3475 HD 4 4336 37 9062 -0 0269 2 0332 4 2737 41 2813 13:5296 ILD DT RHOB CALl THOR CGR ~;ATT )EPT 4000 5P ~PHI 49 ?CNL 346 ~RAT 4 RAN 0 A 1 0000 SFLU '7813 GR 0723 DRHO 0000 PEF 0195 RNRA 6636 SGR 1056 HD 3 7324 7 4 3 65 3750 13 0183 DT RHOB CAb! CGR EATT DEPT 3900 SP -44 NPHI 46 FCNb 492 NRAT 3 URAN SA g 0000 SF[,U 7813 GR 6309 DRHO 7500 PEF 8594 RNRA ,3906 8GR ,6995 MD 3 62 13 8594 ILD 7813 DT 0313 RHOB 591 3HOR C~R EATT DEPH 3~00 sp 51 N,PHI 42 CNL 525 RAT 3 U:RAN ~ SA 0000 5FLU 2070 7902 HI) 5,4805 ILD 40., 000: DI '0,0571 RHOB ,7969 CAb . ~ 843~ THOR 4 : 8125 ,OR 1. ,5053 EATT DEPT 3700 SP -47 NPHI 38 FCNL 629 NRAT 3 URAN S~ 0 0000 SFLU 5313 OR 7207 DRHO 0000 ~,~ 06:I5 8GR 6995 ~D 6,3164 'IbD T ,0488 RHOB 4.9, CG 13, EATT 2,0605 13.2578 4.2031 30,6875 229.7917 2,8496 113,0000 2.2637 13,0000 6,6719 50.7188 220'3750 2,5195 121,7500 2,1406 13,2422 5,3750 33,5000 260,6250 3.5723 123,3750 2,0566 1~ 1953 1172 60 3750 118 1250 3 6602 122 5625 2 1738 12 9453 7 2852 52 25O 299 1666 4,9948 ;1250 13] ,0898 13,0234 5,8633 ~8~ 2~..3, 6875 5518 4258 6, ''0 12, , 289 1~,382s ,1055 50,0625 2~1.5000 NCNL POTA TPL GR GR i~Chb SGR POTA TPL GR IL~ GR NCNb SGR POTA TPL GR GR NCNb SGR POTA TPb GR IbM GR NCNb SGR POTA TPb GR IbM GR NCNL POTA TP£, GR 'ILM GR NCNb POTA 1560 0000 37:4063 0,0098 14,9948 44,0625 2,9941 45 0250 2072 0000 57 5313 0 0146 13 3932 59 2500 2,7871 37,9062 1698.0000 41,2813 0,0103 1~,1693 4 ,3125 3 5352 54 9375 1506 0000 0 0 22,6660 70 0938 3.7266 50,7813 2044,0000 62,6563 0,0146 14,1328 77.2500 9531 0000 o OOOO 81:25 0176 9316 6 3125 45 5313 2254 0000 49 5938 0 0156 13 9036 55 2:187 .VP 010.H02 VERIFICATION LISTING PAGE 6 )EPI 3~00.0000 SFLU ;P 45.2813 GR {PHI 40.2832 DRHO ~CNL 521.5000 PEF {RAT 3.5293 RNRA JRAN 1.1094 SGR SA 0.7448 HO )EPT 3500.0000 SFLU ~P -60.7813 GR ~PHI 40.0391 DNMO ~CNL 501.0000 PEF ~RAT 3.5020 RNRA JRAN '0,1191 SGR ~A 0.7139 HD )EPT 3400. ~P "60 qPHI 41 FCNb 467 ~RAT 3 JRAN 3EPT 5P FCNL ~RAT ~RAN DEPT 5P NPHI FC NL [iRAN SA DE:PT SP NRAT URAN DEPT 8P NPHI FCNL NRAT URAN 3300, -66 42 547 3 -0 O, 3200 -69 44 1 0 45 66 264 4 0 0 3000 -45 53 351 4 2 0000 SFLU 5313 GR 5527 DRHO 5000 PEF 5938 RNRA 2119 0213 HO 0000 SFLU 0625 GR I875 DRHO 0000 PgF 6465 RNRA 0176 SGR 6542 ND 0000 SFLU 7754 DRHO 5000 7695 RNRA 0566 8853 HO 0000 SFLU 5313 GR: 5039 ORHO 7500 9727 31.64SGR 5591 HD 0000 SFLU 2813 =R: :, 8086 DRH~ 7500 . E~ 2930 RNRA 7676 SG 4.4688 ILD ~7 4375 PT -0:0171 RHOB 1.9004 CALI 3.7622 THOR 55.1562 CGR 13.5674 EAST 11.1250 ILD 36.1562 DT 0.0000 RHOB 1.8838 CAbI 3.8443 THOR 41.6875 CGR 13.4135 EATT 8 51 -0 3 54 13 5781 ILD 3750 DT 0503 RHOB 0840 CALl 8930 THOR 062 CGR 644 EATT 10 40 -0 1 3 5313 ILD 0:938 DT 0527 RHOB 5879 CALI 9689 THOR 0625 CGR 7205 EATT 8 4453 ILl) 0439 RHOB 38 CGR i3 EATT 21 40 14 7813 ILD 2813:DT 02'25 R'HOB 8 4297 6875 CGR 6.1562 130.7500 2,1719 13,3906 7.2695 46.7500 255,6667 8.3125 157.7500 2,1035 12,8359 6,4883 42,5938 200,9375 7.6602 164 0000 2:0469 13.1641 7,7852 45,7500 257.05~6 10.9219 50 ,I3 7734 5:2344 43.I875 202.4141 9 9062 163 5000 2 0430 13 1562 4 3164 6602 I0.9453 '5 15~,2 0 .~475 I~,8281, .8242 38,5000 ~63.4166 6.7539 091,8 ?,2109 0469 45.7188 GR NCNb SGR POTA TPL GR ILM GR NCNb SGR POTA TPL GR GR NCNb SGR POTA TPL GR GR NCNb SGR POTA TPL GR GR NCNb SGR POTA GR GR NCNb TPL GR GR NCNL POTA TPL 5.6719 47.4375 1811,0000 55.1562 0.0127 13.9349 56.9375 8.4766 ~6.1562 1916.0000 41.6875 0.0132 13.4666 47.2~32 7.5195 51,3750 1858.0000 54,9062 0.0151 15,0465 58.9109 10.6172 40,0938 2150,0000 43,0625 0,01.61 13,~583 49. 602 9 6797 20~ 9375 0000 38 7813 0 0083 14 7754 40 4.668 1.0 ~13 2~ ~65b: 148 5000 40 8750 0 0093 16 6875 33 3125 6 6602 58 2187 1618 0000 66 68:75 0 0117 17 3073 iVP 010,H02 VERIFICATION LISTING PAGE 7 0,9759 MD ~EPT 2900.0000 iP -55,0313 [PHI 45.6543 'CNL. 421,7500 tRAT 3,8301 IRAN 2,1973 ;A 1,0711 )EPT 2800 ;P -61 {PHI 42 'CNL 492 {RAT 3 ;RAN 0 )EPT 2700 ]PHI 41 ~CNL 487 ~RAT 3 ]RAN 1 ~A 0 )EPT 2600 ~P -58 ~PHI 43 rCNb 463 ~RAT 3 3RAN 0 FA 0 3EPT 2500 SP "69 gPHI 50 ~I R .A T 1 4 JRAN SA 3 )EPT 2486 SP '99~ ~PHI '99 ~C~. -999 NR ~ -999 LIRAN -999 SA 0 SFLU GR DRHO PEF RNRA SGR 0000 SF'bU 5625 GR 2852 DRHD 7500 PEF 6523 RNRA 9971 SGR 7918 HD 0000 SFbU 3125 GR 7969 DRHO 0000 PEF 6367 RNRA 0400 SGR 7902 MD 0000 SFLU 1~52 DR~O 7500 PBF 7402 RNRA 1328 SGR 9759 HO 14,1282 gATT 7,8125 ILD 55,3438 -0.0059 RHOB 2.3418 CALI 4,1678 THOR 58,9375 CGR 13,6241 gATT 10 6875 47 1562 -0 0044 2 2910 3 9064 54 3125 13 9971 0 46 0 2 3 48 13 ILD DT RHOB CALX THOR gATT 7656 7813 0029 0410 8665 4375 7690 10 5OOO 5~ b875 0571 ~ '4609 0052 68 '4375 15 1048 ILD DT RHOB CArl THOR CGR gATT 0000 8FLU B 5625 7813 DRHO 5000 PEF ~ 0859 RN~A ILD DT RHOB CALl THOR 5547 9687 DT 0273 RHOB 0,488 4610 THO 5000 SF[,U -99'9 ,25 0: G~ '999: 2500 DRHO -999 ,25 0 P~F ,2500 RNRA ,2500 SGR 999 ,7'~4'8' HD 13 FILE NA~E :SERV'IC, 001 SER ICE NA~E 290,3333 GR 8 1719 155:0000 2.1797 13,4844 6.1211 42,2813 261.7656 I LM GR NCNb SGR POTA TPL GR 11,0469 140,3750 2.1309 13,7422 7,1914 46,7500 238,0078 GR NCNL SGR POTA TPL GR 11,4688 149.7500 2.1387 14,0859 6.3555 40,5625 214.4167 IbM GR NCNb POTA TPL GR I1,6328 146,~500 2.2324 5,2109 0,7188 67, 375 217'~750 GR NCNb SGR POTA TPb 2 12 4 286 9258 IbM 0000 GR 0918 NCNb 6094 SGR 9141 POTA -999,2500 :999,2500 GR 999,2500 ~CNb -999,~500 -999',2500 POTA -999,2500 TPL 575.0000 GR 79.1875 7.6680 55 3438 174!i0000 58 9375 0,0112 15,5833 61,2383 10,2266 47 1562 1915:0000 54,3125 0.0127 15,3908 56,4907 10 4609 46 7813 1886 0000 o 27 14 0807 '52 0000 1.0,7578 56,6875 1807.0000 68,4375 0.0176 15,0703 62.9375 4 9180 4 9687 139~ 0000 4~ 2500 0117 178'I -999 2500 :999 2500 999 2500 -999 2500 -999 2500 '~ 3906 VP 010,H02 VERIFICATION LISTING PAGE 8 ER$ION # : ATE : AXIMUM LENGTH : 1024 ILM TYPE : EXT FILE NAME : EOF * TAPE TRAILER ** ,ERVICE NAME ,ATE ~RIGIN ~6640 'APE NAME IONTINUATION # ~01 !EXT TAPE NAME IOMMENT$ :LIBRARY TAPE ~* REEL TRAILER ** ;ERVICE NAME JSERVIC ~ATE :83/02/11 ~RIGIN : iEEL NAME :135241 :ONTINUATION # ~01 IEXT REEL NAME : ~OMMENTS :LIBRARY TAPE *****:***** EOF **********
