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• 0 _ ._PIVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 18 2016 la.Well Status: CO❑MPLETGO❑N OReRr ❑ECOMPLAbandoned ❑ETIOuNeRnded EPORT lb.Well cANP 20AAC 25.105 20AAc 25.110 Development ❑ Exploratory❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service 0 • Stratigraphic Test❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 10/3/2016 182-084/316-024/ • 3.Address: 7.Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 6/3/1982 50-029-20755-00-00 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 768'FNL,788'FEL,Sec 33,T12N,R10E, UM 6/13/1982 KRU 1H-07 ' Top of Productive Interval: 9.Ref Elevations: KB:85 17.Field/Pool(s): 2117'FSL,988'FWL,Sec 27,T12N, R10E,UM GL: 50 BF:56 Kupurak River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2370'FSL, 1291'FWL,Sec 27,T12N, R10E, UM 8194/6867 ADL 25639 • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 549560 y- 5979935 Zone- 4 8300/6959 ALK 464 TPI: x- 551311 y- 5982831 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 551611 y- 5983087 Zone- 4 N/A 1597/1599 5. Directional or Inclination Survey: Yes ❑ (attached) No (] 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A SCANNED .APR 2 5 2012 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16 62.5 1H-40 30 80 30 80 24 315 sx AS II 10 3/4 45.5 K-55 29 2365 29 2340 13 1/2 1000 sx AS III&250 sx AS ll 7 26 K-55 29 8274 29 6937 8 3/4 962 sx Class C 24.Open to production or injection? Yes ❑ No E 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3 1/2 7642 7573 All Perfs Squeezed off 241,.$06N .. :;.- 1' t T 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No E 1011162 Per 20 AAC 25.283(i)(2)attach electronic and printed information ,::,:"•'F r` DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED - cement squeeze from 7665-7889 20 bbls 15.8 cement 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period — Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate li. g Form 10-407 Beni ed1j/20j5 5 v77- 4/7 1//v CONTINUED 7 PAGE 2 RBDMS t- NOV t 3 2010ubmit ORIGINIAL onl • 0 28.CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No 2 If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Ill Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1597 1599 Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports,per 20 AAC 25.071. Formation at total depth: N/A N/A 31. List of Attachments: Daily Operations Summary,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report •roduction or well test results.ger 20 AAC 25.070. 32. I hereby certify th-``the foregoing is ,ue a • •„rect to the best of my knowledge. Contact: Ron Ph'1,s •• 265-6312 IP Email: ron.l.phillips(cilcop.com Printed Name: G.Eller \- X Title: Lead CTD Engineer Signature: Phone: 263-4172 Date: \\ lo N � INSTRUCTIONS General: This form and the required ttachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well co letion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: 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 lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis, paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only r 1 H-07 • 10/2/16 DRILLING Pick up Baker whip-stock, BHA#1, RIH, tie into K1 marker, performed jewelry log and SIDETRACK set top of whip-stock at 7842'. POOH, lay down BHA#1, Replace damaged washers and bolts on drillers side storage reel hub. PU tubing window milling assembly, BHA#2, RIH, tag whip-stock @ 7840.7' Time mill window. 10/3/16 DRILLING Mill 2.80" exit window in 3.5" tubing @ 7841', LD BHA#2, PU 2.80"window milling SIDETRACK assembly, BHA#3, RIH. Time Mill 2.80" exit window in 7" production casing. 10/4/16 DRILLING Finished milling window, back ream and dry drift. Trip out and lay down BHA#3, Pick SIDETRACK up BHA#4, trip in to bottom, displace hole over to new mud and drill A-Lat build section from 7866 ft to 8360 ft with Baker AKO 2.13° motor and re-built HCC 2.74 x 3.0" Bi-Center bit. Circulate hi vis sweep, trip out with BHA#4, perform jog near surface and bump-up. 10/5/16 DRILLING Laydown build section BHA#4. Make up Weatherford motor with 0.53°AKO with re- SIDETRACK built HYC 2.7 x 3.0" bi-center bit, pressure deploy BHA#5, Trip in, minus 7 ft correction at K1, sat down in build section at 8180, 8195, 8216, and 8218'. Worked thru tight area at low pump rate and 50 FPM. Drilled as per geo from 8360' to 9143', made wiper trip at 8860' to 8240, staying below tight area per town. At 9143', unable to pull up hole with coil, circulate bottoms up. 10/6/16 DRILLING Working to free stuck coil at 9143 ft, pumped 6.5 BBLS of LVT200, pipe came free. SIDETRACK Long tie-in wiper trip to window, made +10 ft correction at K1. Ran in to clean up build section, working through 8256 ft to 8274 ft. Circulate a BU after taking 300 to 400 ft bites to 9143 ft. Circulate new mud and drill A-Lateral to 9378 ft. Decision made to set anchored billet at 8450' While POOH, coil became stuck and packed off at 8168 ft. Worked free and attempted to clean hole to 8450'. Getting large pieces of shale from —8150 ft to 8280 ft. Clean and wiper hole with four 5 x 5 Lo/Hi Vis sweeps staying above 8150 ft. Pulling out at 5500 ft to change BHA as of midnight. 10/7/16 DRILLING LD BHA#6, PU BHA#7 with BOT anchored billet, tie-in to K1 for a -8.5' correction, SIDETRACK set top of billet at 8096 ft. LD BHA#6. PU BH #7 with 2.3+AKO motor and RR HYC bit. Tie-in to K1 for a -11' correction, tag top of billet at 8096', KO from anchor billet at 8117 ft as of midnight. 10/8/16 DRILLING Kicked off from anchored billet at—8100 ft(TOB at 8096 ft), unable to get BHA to build SIDETRACK with 2.3+ AKO motor, at 8132 ft consult with town engineers, drilled to 8138 ft and drilled into PB1. POOH and L/D BHA#7. PU BHA#8 with 2nd anchored billet, -12 ft correction at K1, set top of billet at 8045 ft, set down 0.9K and pushed billet down to 8056 ft. POOH and L/D BHA#8. PU BHA#9 with 3rd anchored billet, -14 ft correction at K1, set top of billet at 8100 ft, set down 4.4K, good set. POOH. 10/9/16 DRILLING Layed down Baker-10 setting tool, BHA#9. Picked up BHA#10 with 2.3° AKO build SIDETRACK section motor with a RB HCC bi-center bit, tied in to K1 marker, -13 ft correction. Dry tagged top of billet at 8000 ft. Kicked off from billet at 8002 ft and drilled build section to 8330 ft, maximum DLS was 46.6°. Tripping out at 6800 ft to lay down BHA#10. 10/10/16 DRILLING Layed down BHA#10. Picked up BHA#11 with 0.53°AKO motor with RB HCC 3.0" SIDETRACK bi-center bit. Drilled 8330 ft to 9011 ft, made 300 ft trips at 8630 ft and 8923 ft, with BHA wipers in between. Coil became stuck at 9010 ft. Appears to be differentially stuck above the BHA. Pumped LVT and let soak as of midnight. 10/11/16 DRILLING Continue to work coil free from 9011', Work coil free and pull up through window, Tie SIDETRACK in for+10', Well unloading shales, Make wiper trip to swab, 10/12/16 DRILLING Complete wiper trip to swab, RBIH to clean open hole. Clean out down to 8389. Hole SIDETRACK producing shales. Trip out for anchored billet 10/13/16 DRILLING M/U BHA#12, Anchor billet. RIH tied in for-14', clean pass through window and down SIDETRACK to set depth @ 7981.7, TOB @ 7970. Orient to 30 ROHS. Pumps on and see tool shift @ 4200 PSI. Set weight down on anchor. At 2000Lbs billet started moving down hole. Ran down to 7997 where 1400 Lbs WOB observed. Pull off billet. Come to surface. P/U BHA# 13 HES caliper. Trip in and tie in for-14.5', Log 7975 to 7230. Trip out and analyze data 10/14/16 DRILLING Set Anchor bi' t @ 7936 Oriented to 30° ROHS, Trip out .8 PPG Brine. SIDETRACK Complete ful PE test, Witnessed by Chuck Sheve, AOMPt. M/U BHA 15, kick off billet, 10/15/16 DRILLING Mill off anchor billet @ 7936, Complete build /turn to 8615'. Trip out for lateral BHA SIDETRACK 10/16/16 DRILLING Complete PD BHA#16, A lateral BHA with .5°AKO motor and HYC Bi Center, Trip in, SIDETRACK Tie in for-15', Work pipe to 8607', Unable to get to EOB TD. Start drilling @ 8609'. Pull wiper from 8790. Unable to get turned back in hole. Pull wiper up through window, Circ bottoms up, Tie in for+7'. RBIH. Work pipe to 8607'. Unable to pass. Consult town. Drill ahead from 8609 to 8659'. Pull wiper to 8090, Poor conditions. Work pipe back to 8659 and drill ahead to midnight depth @ 8726, Swapped to new mud system 4 @ 8723', 15:00 10/17/16 DRILLING Drill 8726 to 9260'. On wiper from 9260 unable to get below 8509. Trip out for D-331 SIDETRACK with gauge cutters and 1.2° motor 10/18/16 DRILLING Trip in with D-331 mill + 1.2°AKO motor. Cleaned up hole down to TD @ 9,263'. SIDETRACK POOH. Decision made to PU drilling BHA#18 instead of liner to continue drilling 1 H- 07A lateral. RIH with BHA#18 (HCC RR bit+ 0.5° AKO motor). Swap from 11.8ppg K- formate brine back to 8.6ppg FloPro at the window. 10/19/16 DRILLING Finished fluid swap to FloPro. Cont RIH towards TD, stack out @ 8,531'. Worked SIDETRACK pipe, but could not pass. Swapped fluid back to beaded liner pill &completion fluid while POOH. Flow check. LD BHA#18. MU liner assembly and RIH. Hard tag @ 8,057'. Worked liner, but could not pass. POOH. Flow check. LD BHA#19 and 14 jnts liner. 10/20/16 DRILLING LD liner. MU clean-out BHA#20. RIH, swapped to FloPro mud. Tag up @ 8,090'. SIDETRACK Worked down and reamed to TD of 9,263'. PUH to window, work down to TD twice more. POOH pumping beaded liner pill followed by completion fluid. LD BHA#20, MU liner assembly with bent sub and torque through sleeve to allow orientation. RIH to 6077'. 10/21/16 DRILLING Cont RIH and work liner to setting depth of 9,079' (184' shy of TD). TOL @ 7,654'. SIDETRACK Swap well to SW while POOH. FP last 2,500' w diesel. PUD liner running tools (BHA #21). Lubricate BPV in. Blow down reel, stack, rig lines in prep for rig move. 10/22/16 DRILLING Rig move SIDETRACK 10/23/16 SBHP/FBHP TAG LINER TOP @ 7654' RKB W/2.75" MAGNET. MEASURED BHP @ SAME. JOB SURVEY COMPLETE. 10/26/16 DRILLING RIH WITH BALL DROP NOZZLE TO 7650' CTMD, PUMP A 10 BBL LINER SUPPORT- RUNNING PILL MADE OF SLICK SEAWATER WITH 4% SAFE LUBE AND 1 PPB CAPITAL ALPINE BEADS, LAY IN ANOTHER 15 BBL'S OF LINER PILL IN TBG UP TO 5900' CTMD, RIH WITH BOT HIPP TRIPPER AND BLIND BOX, TAG LINER TOP AT 7658' CTMD AND VIBRATE DOWN TO 7663.9' CTMD, NO MOVEMENT AFTER 3 HOURS OF TRYING, TRIED RAMMING IT AT 100 FPM, F/P TBG TO 3000' RKB, JOB COMPLETE. 10/28/16 PUMPING INJECTIVITY TEST TRACKING MAX PRESSURE 3000 psi. ONLY 50 BBLS DIESEL DOWN TBG JOB COMPLETE 11/13/16 ANNCOMM (PRE-SW) : MIT-IA PASSED TO 3000 PSI. Operations Summary (with Timelog Depths) 0 1H-07 ConocoPtvillips :d.-ska Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MO) End Depth(ftKB) 9/30/2016 9/30/2016 6.00 MIRU MOVE RURD P Finish ND and secure BOP.Methanol 0.0 0.0 06:00 12:00 in XMT,function valves.Disconnect PUTZ.Prepare rig for move. 9/30/2016 9/30/2016 9.00 MIRU MOVE MOB P Move pit sub away from drilling sub, 0.0 0.0 12:00 21:00 hook up sow.SI adjacent wells,move drilling sub away from well row.Move off 3F pad @ 14:45.Stopped at Oliktok Y for change out. 9/30/2016 10/1/2016 3.00 MIRU MOVE MOB P Spot drilling sub over well followed by 0.0 0.0 21:00 00:00 pits sub. 10/1/2016 10/1/2016 5.00 MIRU WHDBOP NUND P NU BOP.Connect PUTZ. 0.0 0.0 00:00 05:00 Note:Valve crew greased tree prior to rig arrival. 10/1/2016 10/1/2016 4.50 MIRU WHDBOP RURD P Prepare for initial BOP test.Take on 0.0 0.0 05:00 09:30 SW,fill stack,shell test. **Rig Accept @ 09:30(after stack filled)` 10/1/2016 10/1/2016 10.00 MIRU WHDBOP BOPE P Initial BOP Test 250/3500 psi(annular 0.0 0.0 09:30 19:30 2500 psi),witnessed by AOGCC Inspector,Johnnie Hill. Leaking Tango 1 valve during Test#8, continue on with BOP test. Leaking Romeo 3 valve during test#10, serviced,pass.While testing lower 2" pipe rams(test#15),swab 1 &2 started leaking.Carry on with BOP test. Note:Both swab 1 &2 had passed earlier during tests#1 and 2. 10/1/2016 10/1/2016 2.00 MIRU WHDBOP BOPE P Valve crew came out two separate 0.0 0.0 19:30 21:30 times during BOP test to service Tango 1 and then,swab 1 &2. Passing test against swabs,continue on with BOP test. 10/1/2016 10/1/2016 1.00 MIRU WHDBOP BOPE T Continue BOP test.During draw down 0.0 0.0 21:30 22:30 test,new high pressure N2 manifold hose ruptured. Repaired and restarted test,pass. Note:Nabors 1 hour NPT 10/1/2016 10/1/2016 1.00 MIRU WHDBOP RURD P Fluid packed reel,lined up to reverse 0.0 0.0 22:30 23:30 circulate and tested Inner reel valve/ stripper,pass. 10/1/2016 10/2/2016 0.50 MIRU WHDBOP MPSP P Un Stab injector, PJSM,RU valve 0.0 0.0 23:30 00:00 crew lubricator to pull BPV 10/2/2016 10/2/2016 1.50 MIRU WHDBOP MPSP P Pull BPV,PJSM,RD Valve crew 0.0 0.0 00:00 01:30 lubricator and release crew. 10/2/2016 10/2/2016 2.00 SLOT WELLPR PRTS P PJSM,Pressure test PDL's and TT 0.0 0.0 01:30 03:30 line,blow down same,CO stripper packing. Install floats in UQC. 10/2/2016 10/2/2016 2.00 PROD1 RPEQPT PULD P PJSM,Pick up Baker whipstock on 0.0 81.0 03:30 05:30 10#J hydraulic setting tool,BHA#1. Open EDC. 10/2/2016 10/2/2016 1.50 PROD1 RPEQPT TRIP P RIH with BHA#1. 81.0 7,510.0 05:30 07:00 Page 1/23 Report Printed: 10/25/2016 '0 Operations Summary (with Timelog Depths) >,at ►lir 1 H-07 ConocoP hillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/2/2016 10/2/2016 1.50 PROD1 RPEQPT DLOG P Tie in to K1,minus 12'correction. 7,510.0 7,834.0 07:00 08:30 PUW=38k.Log CCL @ 16 FPM to bit depth of 7,844'(CCL 62'behind end of BHA;CCL log obtained down to 7,782';60'from planned set depth of whipstock due to pre-rig cement mill/reamed depth).Discuss with town engr.Correct depth+1'based on CCL compared to caliper log. 10/2/2016 10/2/2016 0.50 PROD1 RPEQPT TRIP P RIH to set depth.Close EDC.PU 30k. 7,834.0 7,851.5 08:30 09:00 Set whipstock,set down 3k WOB.PU and line up for swap to mud. 10/2/2016 10/2/2016 0.75 PROD1 RPEQPT DISP P Swap out SW for used 8.7 ppg FloPro 7,851.5 7,817.0 09:00 09:45 (milling fluid). 1.4 BPM. 10/2/2016 10/2/2016 1.25 PROD1 RPEQPT TRIP P POOH BHA#1. 7,817.0 67.0 09:45 11:00 10/2/2016 10/2/2016 0.50 PROD1 RPEQPT OWFF P Flow check/30 mins.Dead well. 67.0 67.0 11:00 11:30 10/2/2016 10/2/2016 1.00 PROD1 RPEQPT PULD P PJSM,LD BHA#1. 67.0 0.0 11:30 12:30 SIMOPS:Replace washers/bolts on reel hub. 10/2/2016 10/2/2016 1.00 PROD1 WHPST PULD P PU BHA#2,Baker diamond mill& 0.0 70.0 12:30 13:30 reamer,Baker Xtreme motor. Window mill 2.80"no go, Sring mill 2.79"no go SIMOPS:Replace washers/bolts on reel hub. 10/2/2016 10/2/2016 0.50 PROD1 RPEQPT RGRP T Replace washers and bolts that attach 70.0 21.0 13:30 14:00 the reel to the hub on driller's side. Secure well-PU BHA with tugger,SI master valve. 10/2/2016 10/2/2016 4.50 PROD1 RPEQPT RGRP T Replace washers and bolts that attach 21.0 14:00 18:30 the reel to the hub on driller's side. 10/2/2016 10/2/2016 2.20 PROD1 WHPST PULD P 21.0 74.3 18:30 20:42 PJSM,Change out UQC,surface test, good,pick up 3.5"milling assembly BHA#2,on well,open EDC,test tools. 10/2/2016 10/2/2016 1.80 PROD1 WHPST TRIP P RIH W BHA#2,K1 Tie in-13' 74.3 7,491.0 20:42 22:30 correction Close EDC. 10/2/2016 10/2/2016 0.70 PROD1 WHPST TRIP P RIH,wt ck @ 7820,37.5k lbs,RIH 7,491.0 7,840.7 22:30 23:12 Wt16.5 k lbs,Tag TOW 7841'. PU Wt 40 k lbs bring pumps up to 1.5 bpm, up weight 33k lbs,CT 3343 psi,WH 84 psi, IA 463 psi,OA 254 psi, 10/2/2016 10/3/2016 0.80 PROD1 WHPST WPST P Tag up,7840.7' CT wt 15k lbs,CT 7,840.7 7,841.1 23:12 00:00 3388 psi,WH 86 psi,WOB.33 K lbs. 10/3/2016 10/3/2016 4.50 PROD1 WHPST WPST P Milli 2.80"window @ 7841'330 7,841.1 7,847.0 00:00 04:30 ROHS, CT wt 10.6k lbs,CT 3580 psi, WH 85 psi,WOB 3.7k lbs. Stall#1 at 7843.46,PU Wt 42k lbs,#2, @7841.6', PU Wt 40k lbs. Page 2/23 Report Printed: 10/25/2016 • 410 ,rill 0 Operations Summary (with Timelog Depths) 1H-07 ConocoP'hillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/3/2016 10/3/2016 1.00 PROD1 WHPST WPST P Attempt to RIH past TOW dry,stacked 7,841.1 7,843.5 04:30 05:30 weight 7841.3' PU,40k lbs Attempt to RIH past TOW pumping 0.5 bpm-2 fpm stacked weight at 7841.4' Attempt to RIH past TOW pumping 0.3 bpm-5 fpm stacked weight at 7841.9' PU Wt 40.5 K lbs Consult with Baker and town. Go back to milling. 10/3/2016 10/3/2016 2.00 PROD1 WHPST WPST P Milling ahead from 7,841.4'to 7,842.6' 7,843.5 7,842.6 05:30 07:30 increasing WOB to 3.2k.Motor work --1000 psi diff.No head way made with 3.2k WOB after 20 mins. Pumping 1.4 BPM.CTSW 13k. 10/3/2016 10/3/2016 3.25 PROD1 WHPST WPST P PU just passed breakover,still below 7,842.6 7,846.7 07:30 10:45 TOWS.Increased rate from 1.4 to 1.8 BPM.RBIH,milling ahead.WOB 1.6k, 1.8 BPM,CTSW 14.3k,motor work 585 psi. Motor work increased @ 7,846', potential contact with 7"casing. 10/3/2016 10/3/2016 0.50 PROD1 WHPST REAM P Backream up to TOWS 3 times. 7,846.7 7,846.0 10:45 11:15 PUW=37k. 1.8 BPM.PUH,dry drift to 7,846. PU,open EDC. 10/3/2016 10/3/2016 1.50 PROD1 WHPST TRIP P POOH BHA#2. 7,846.0 62.0 11:15 12:45 10/3/2016 10/3/2016 0.50 PROD1 WHPST OWFF P Flow check/30 mins. 62.0 62.0 12:45 13:15 10/3/2016 10/3/2016 1.00 PROD1 WHPST PULD P LD BHA#2. 62.0 0.0 13:15 14:15 10/3/2016 10/3/2016 1.00 PROD1 WHPST PULD P PU BHA#3. 0.0 76.0 14:15 15:15 10/3/2016 10/3/2016 2.50 PROD1 WHPST TRIP P Test MWD.RIH BHA#3.PUH to 76.0 7,505.0 15:15 17:45 check injector after stop @ 236'.Cont RIH. 10/3/2016 10/3/2016 0.20 PROD1 WHPST DLOG P Tie in to K1,minus 12'correction. 7,505.0 7,532.0 17:45 17:57 10/3/2016 10/3/2016 0.10 PROD1 WHPST TRIP P Cont RIH.Dry tag @ 7,847.7'. 7,532.0 7,847.7 17:57 18:03 10/3/2016 10/4/2016 5.95 PROD1 WHPST MILL P Time milling ahead per schedule @ 7,847.7 7,851.0 18:03 00:00 345 ROHS.PUW=39k, 1.8 BPM @ 4241 psi.BHP 3609 psi. 10/4/2016 10/4/2016 1.50 PROD1 WHPST MILL P Time milling ahead per schedule @ 7,847.7 7,852.0 00:00 01:30 345 ROHS 10/4/2016 10/4/2016 2.00 PROD1 WHPST MILL P Increase WOB to 2k lbs,ROP 5 fph. 7,847.7 7,866.0 01:30 03:30 CT Wt 11.3 k lbs,WB 3.3 k lbs,ROP 9.4 fph,CT 4332 psi,WH 84 psi. Sample from the shaker,15%sand, 16%metal. 10/4/2016 10/4/2016 1.42 PROD1 WHPST REAM P Make back reaming/reaming passes 7,866.0 7,836.0 03:30 04:55 holding original tool face up and down then+/-30 up. Dry drift clean 10/4/2016 10/4/2016 1.00 PROD1 WHPST TRIP P POOH,Open EDC above window. 7,866.0 72.0 04:55 05:55 10/4/2016 10/4/2016 0.50 PROD1 WHPST OWFF P At surface.Observe well for 72.0 72.0 05:55 06:25 flow zero flow observed Page 3/23 Report Printed: 10/25/2016 0 ¶erations Summary (with Timelog Depths)110 1 1H-07 ConocoPhitlips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/4/2016 10/4/2016 1.00 PROD1 WHPST PULD P Lay down BHA#3,Window Milling 72.0 0.0 06:25 07:25 BHA ***Note:2.80"Window Mill No- Go'ed at 2.80" 10/4/2016 10/4/2016 1.70 PROD1 DRILL PULD P Pick up BHA#4,Drill Build and Turn 0.0 72.2 07:25 09:07 BHA w/2 3/8"X-Treme motor and HCC 2.7"X 3.0" Bi-Center Bit. 10/4/2016 10/4/2016 1.58 PROD1 DRILL TRIP P Trip in hole with the Drill Build and 72.2 7,500.0 09:07 10:42 Turn assembly 10/4/2016 10/4/2016 0.14 PROD1 DRILL DLOG P Tie in for K1 Marker at 0.0 7,526.0 10:42 10:50 7,500' make correction of- 2.5' 10/4/2016 10/4/2016 0.28 PROD1 DRILL TRIP P Continue RIH 7,526.0 7,803.0 10:50 11:07 10/4/2016 10/4/2016 0.17 PROD1 DRILL TRIP P At 7,803' stop offline with 7,803.0 7,866.0 11:07 11:17 pump close EDC RBIH online with pump at 1.62 bpm 10/4/2016 10/4/2016 1.14 PROD1 DRILL DRLG P At 7,866.0 start 7,866.0 7,930.0 11:17 12:25 drilling checking everything out before swapping to new 8.6 fluid at 7,868.0 start pumping new drilling fluid ROP =38 fpm, WOB=1.36 second stall at 7,896' PUH and RBIH continue drilling pumping at 1.79 bpm, ROP=83 fpm, WOB=1.67, BHP= 3,843, WHP=323 ""Note; New mud at bit at 7,898.0' 10/4/2016 10/4/2016 0.25 PROD1 DRILL WPRT P At 7,930.0' PUH to sweep hole 7,930.0 7,500.0 12:25 12:40 and log K1 Marker and RA PUW=32K 10/4/2016 10/4/2016 0.10 PROD1 DRILL DLOG P At 7,500.0' RBIH logging the K1 7,500.0 7,534.0 12:40 12:46 Marker and RA Reduce pump rate to.33 bpm while RBIH logging make correction of +.5' RA shows a depth of 7,860.0' 10/4/2016 10/4/2016 0.33 PROD1 DRILL TRIP P Continue RIH slow down 7,534.0 7,930.0 12:46 13:06 through newly drilled build section TOWS is at 7,840.5' 10/4/2016 10/4/2016 4.15 PROD1 DRILL DRLG P At 7,930.0 8,120.0 13:06 17:15 7,930.0' BOBD Pump Rate= 1.75, CP=4,244, BHP= 3,863, WHP=338, ROP=101, WOB=1.82 10/4/2016 10/4/2016 4.50 PROD1 DRILL DRLG P At 8,120.0'and drilling ahead in the 8,120.0 8,360.0 17:15 21:45 turn and build section Pump Rate=1.75 bpm, CP=4,492, BHA =3,953, WHP=397, ROP=46 fpm, WOB=2.22. Call build section TD at 8360'. 10/4/2016 10/5/2016 2.24 PROD1 DRILL TRIP P At 8360',8 BBL Hi Vis sweep at 8,360.0 72.2 21:45 00:00 nozzel,chase sweep at 50 FPM,trip thru window per plan at 15 FPM,slow pump rate to.4 BPM,no issues. Open EDC above window,POOH per MPD trip schedule,jog at surface from 100'to 420',bump up. Page 4/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) 1H-07 Con0 ocoPhillips r.i hk, Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/5/2016 10/5/2016 3.75 PROD1 DRILL PULD P Bump up,trap 1025 psi WHP,hold 72.2 0.0 00:00 03:45 PJSM,PUD BHA#4 and lay down Baker X-Treme motor. 10/5/2016 10/5/2016 3.90 PROD1 DRILL PULD P PJSM, PU/MU Weatherford motor with 0.0 74.7 03:45 07:39 0.53°AKO and re-built HYC 2.7 x 3.0" bi-center bit. PD BHA#5, 10/5/2016 10/5/2016 1.14 PROD1 DRILL TRIP P Trip in hole 74.7 7,480.0 07:39 08:47 10/5/2016 10/5/2016 0.37 PROD1 DRILL DLOG P Tie in to K1 Marker make 7,480.0 7,536.0 08:47 09:09 correction of-7' 10/5/2016 10/5/2016 0.38 PROD1 DRILL TRIP P Continue to RIH stop at 7,813' 7,536.0 8,180.0 09:09 09:32 and close EDC 10/5/2016 10/5/2016 0.79 PROD1 DRILL TRIP T At 8,180' tag PUH a 8,180.0 8,218.0 09:32 10:19 little sticky Continue RIH tag again at 8,195' PUH again and again the weights are erratic and a little heavy....PUH again to 7,947' RBIH Tag at 8,210' PUH 40'and RBIH tag at 8,218' 10/5/2016 10/5/2016 0.19 PROD1 DRILL TRIP T PUH to window 8,218.0 7,900.0 10:19 10:31 10/5/2016 10/5/2016 0.20 PROD1 DRILL TRIP T RBIH at 40 fpm pumping at.34 bpm 7,900.0 8,216.0 10:31 10:43 10/5/2016 10/5/2016 0.23 PROD1 DRILL TRIP T Tag at 8,216' PUH again and 8,216.0 8,358.3 10:43 10:57 try RIH pumping at.18 bpm and RIH at 50 fpm make it past last tag confer with town again and decision made to stay on bottom and drill instead of coimng back up again 10/5/2016 10/5/2016 0.39 PROD1 DRILL DRLG P BOBD Pump Rate=1.70 bpm, 8,358.3 8,404.0 10:57 11:20 CP=4,879,BHP=3,967, Differ= 1,135, ROP=123, WOB=1.70 10/5/2016 10/5/2016 0.05 PROD1 DRILL DLOG P PUH to conduct a survey as per 8,404.0 8,390.0 11:20 11:23 DD 10/5/2016 10/5/2016 5.70 PROD1 DRILL DRLG P RBIH BOBD Pump Rate 8,390.0 8,860.0 11:23 17:05 =1.72 bpm, CP=4,869,BHP= 3,890, Differ=1,275, ROP=205, WOB=2.22 Note;A lot of vibration motor,bit,formation? Pump 5/5 Hi/Lo Vis Pill as we get closer to doing a wiper trip 10/5/2016 10/5/2016 0.30 PROD1 DRILL WPRT P At 8,860' begin wiper trip up to 8,860.0 8,240.0 17:05 17:23 8,240.0'with gamma 10/5/2016 10/5/2016 0.30 PROD1 DRILL TRIP P At 8,240.0' trip back in 8,240.0 8,861.0 17:23 17:41 hole 10/5/2016 10/5/2016 5.82 PROD1 DRILL DRLG P At 8,861' BOBD Pump Rate 8,861.0 9,143.0 17:41 23:30 =1.72 bpm, CP=4,732,BHP= 3,972, Differ=1,063, ROP=62, WOB=1.76. Drill per geo,build to 96°,BHA wipers at 8858',PUW=45K and 9070',PUW=50K,try different pump rate due to vibration, 1.6 bpm, CP=4580,BHP=4093,Differ= 1026. Attempt BHA wiper,work up to 60K,coil not moving. Page 5/23 Report Printed: 1 0/2 512 01 6 • • imo 0 Operations Summary (with Timelog Depths) 1H-07 Cot ocoPhiiiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(MKB) 10/5/2016 10/6/2016 0.49 PROD1 DRILL WPRT T Circulating a BU at 1.5 bpm,CP= 9,143.0 9,143.0 23:30 00:00 4583, attempt to move coil,pull up to 60K,3X.no movement 10/6/2016 10/6/2016 2.50 PROD1 DRILL WPRT T Finish circulating BU,able to rotate 9,143.0 9,143.0 00:00 02:30 orienter,working stuck pipe at 9143', alternate with pumps on and off,allow BHP to relax to 3350 psi(ECD=10.1 ppg),progressively work coil WT to 73K,confer with town,prep to pump LVT. 10/6/2016 10/6/2016 0.50 PROD1 DRILL WPRT T Wait for Vac truck to arrive to offload 9,143.0 9,143.0 02:30 03:00 42 bbls of Lo-Vis from Pill Pit 2. 10/6/2016 10/6/2016 1.50 PROD1 DRILL WPRT T Load Pill Pit 2 and pump 7.5 bbls 9,143.0 9,143.0 03:00 04:30 LVT200,LVT at nozzle at 04:28,all out and pipe came free 10/6/2016 10/6/2016 1.23 PROD1 DRILL WPRT T Long wiper trip to 9,143.0 8,210.0 04:30 05:43 TBG hanging up and pulling heavy 10/6/2016 10/6/2016 0.63 PROD1 DRILL WPRT T At 8,210'and hung up 8,210.0 7,806.0 05:43 06:21 again tryning different pump rates and speeds having difficulty getting past 8,205,now finally pull free and continue PUH 10/6/2016 10/6/2016 0.04 PROD1 DRILL WPRT T At 7,806' Open EDC 7,806.0 7,806.0 06:21 06:24 10/6/2016 10/6/2016 0.54 PROD1 DRILL TRIP T Circulate with open EDC and 7,806.0 7,822.0 06:24 06:56 RBIH tied into RA and made a+10'correction 10/6/2016 10/6/2016 0.05 PROD1 DRILL TRIP T At 7,822 Close EDC 7,822.0 7,822.0 06:56 06:59 10/6/2016 10/6/2016 2.29 PROD1 DRILL TRIP T RBIH get back into build 7,822.0 9,143.0 06:59 09:16 section...start stacking weight at 8,256' through 8,274' work through this area after PUH several times confer with town engineer and decision made to start taking bites (300'to 400')after leaving build section and circulate a bottoms up after each bite until back on bottom (9,143') circulate in new mud with 1%Lo-Torque, 1%776, 1%Drill Zone 10/6/2016 10/6/2016 6.74 PROD1 DRILL DRLG P At 9,143'with new mud system w/1% 9,143.0 9,378.0 09:16 16:01 776, 1%Lo-Torque and 1%Drill Zone BOBD Pump Rate =1.42 bpm, Circ Press=4,377, WHP=95, BHP=4,064,ROP=52 fph, WOB=1.65 k We expierenced bad vibration for about the first 45'of drilling a couple of times had to PUH to get a survey vibration is gradually getting a little better at least good enough to capture multiple consecutive surveys still some sticky drilling/weight transfer issues occasionally having to PUH for a short ways from time to time after new mud has circulated in the weight transfer is better now(after 9,200') Page 6/23 Report Printed: 10/25/2016 ;,,Ilos Operations Summary (with Timelog Depths) 0 1H-07 Coeroce3'niHHips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/6/2016 10/6/2016 0.05 PROD1 DRILL WPRT P At 9,378' Receive a call from Ron 9,378.0 9,378.0 16:01 16:04 and Gary to POOH pumping at 75 gpm and to"jog"through build area making note of any difficult areas to be passed on to Ron.Weatherford motor will be released and Inteq motor used on next drilling run.Anchored Billet will be set at 8,450.We have stopped drilling 10/6/2016 10/6/2016 0.43 PROD1 DRILL TRIP T POOH pumping at 1.7 bpm chasing 9,378.0 8,168.0 16:04 16:30 returns to surface 10/6/2016 10/6/2016 1.75 PROD1 DRILL TRIP T Start pulling heavy and packing off at 8,168.0 7,780.0 16:30 18:15 8,180'. Stuck at 8,166',unable to orient,come off pumps,dump CP, relax pipe,came free,PUH thru window at 7840' 10/6/2016 10/6/2016 1.00 PROD1 DRILL TRIP T Open EDC,circulate and PUH while 7,780.0 7,485.0 18:15 19:15 building Lo Vis pill. Pump 5x5 Lo/Hi vis sweep. 10/6/2016 10/6/2016 0.25 PROD1 DRILL DLOG T Tie-in for+6.5'correction at K1 7,485.0 7,526.0 19:15 19:30 10/6/2016 10/6/2016 0.25 PROD1 DRILL TRIP T RIH to clean at 50 FPM,circulate thru 7,526.0 8,456.0 19:30 19:45 build section at min rate,at EOB bring rates 1.4 bpm,packing off at 8420', sat down-10K at 8456'. Pull up to 66K,to get moving 10/6/2016 10/6/2016 1.75 PROD1 DRILL WPRT T Pulling stickey up to 8110'. First 8,456.0 7,900.0 19:45 21:30 sweep at nozzle at 8086',start second 5x5 Lo/Hi vis sweep,wiper up to 7900', First sweep at surface,plug choke A with large shale sloughings. Confer with town,continue hole cleaning and wipers above 8150'. 10/6/2016 10/6/2016 1.25 PROD1 DRILL TRIP T Pump sweep#3 and run back to 7,900.0 8,150.0 21:30 22:45 8150',cleaner this time,still getting back shale,smaller size particles. Decision made to set KO billet above 8150',pump final 5x5 sweep and clean hole above 8150'. 10/6/2016 10/6/2016 0.75 PROD1 DRILL WPRT T Wiper up to window,open EDC 8,150.0 7,808.0 22:45 23:30 10/6/2016 10/7/2016 0.50 PROD1 DRILL TRIP T Trip out per MPD schedule.... 7,808.0 5,500.0 23:30 00:00 10/7/2016 10/7/2016 1.50 PROD1 DRILL TRIP T Continue to POOH,bump up and 5,500.0 74.7 00:00 01:30 space out,maintain 950 psi WHP. 10/7/2016 10/7/2016 2.00 PROD1 DRILL PULD T PJSM,Pressure undeploy and 74.7 0.0 01:30 03:30 laydown BHA#5 10/7/2016 10/7/2016 4.00 PROD1 STK PULD T MU BHA#6 2.60"Anchored KO billet, 0.0 73.4 03:30 07:30 PD BHA#6 10/7/2016 10/7/2016 1.68 PROD1 STK TRIP T Start RIH with Anchored Billet setting 73.4 7,490.0 07:30 09:10 BHA with open EDC pumping at minmum rate 10/7/2016 10/7/2016 0.25 PROD1 STK DLOG T At 7,490'.start slowing down and log 7,490.0 7,534.0 09:10 09:25 for K1 Marker and make a correction of minus 8.5' 10/7/2016 10/7/2016 0.13 PROD1 STK TRIP T Continue RIH with Anchor Billet Billet 7,534.0 7,821.0 09:25 09:33 setting BHA Page 7/23 Report Printed: 10/25/2016 0 Operations Summary (with Timelog Depths) 1H-07 ConocoPhillips . A,I.r.Aa Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (1KB) End Depth(ftKB) 10/7/2016 10/7/2016 0.06 PROD1 STK TRIP T At 7,821' offline with 7,821.0 7,821.0 09:33 09:37 pump close EDC perform a WTCK=32.5k 10/7/2016 10/7/2016 0.17 PROD1 STK TRIP T Continue RIH 7,821.0 8,106.3 09:37 09:47 10/7/2016 10/7/2016 0.23 PROD1 STK WPST T At 8,106.5 ft PUH to neutral 8,106.3 8,106.3 09:47 10:01 weight bring pump online release off billet....offline with pump anchored billet set with uphole anchor oriented high side,top of Billet at 8096 ft set down 2.5k and billet is holding 10/7/2016 10/7/2016 0.09 PROD1 STK TRIP T PUH several feet and open EDC 8,106.3 8,106.3 10:01 10:06 10/7/2016 10/7/2016 1.87 PROD1 STK TRIP T POOH pumping at 1 bpm. 8,106.3 61.8 10:06 11:58 10/7/2016 10/7/2016 1.74 PROD1 STK PULD T At surface. Pressure Undeploy BHA 61.8 61.8 11:58 13:43 #6 after PJSM. 10/7/2016 10/7/2016 0.93 PROD1 STK PULD T L/D BHA#6 61.8 0.0 13:43 14:39 10/7/2016 10/7/2016 2.80 PROD1 STK PULD T PJSM, P/U A Lateral KO/Build 0.0 72.2 14:39 17:27 Section BHA#7. Pressure Deploy BHA#7. 10/7/2016 10/7/2016 1.55 PROD1 STK TRIP T Trip in w/BHA#7 to 7500 ft 72.2 7,500.0 17:27 19:00 10/7/2016 10/7/2016 0.25 PROD1 STK DLOG T 7,500 ft,log K1 Marker and make 7,500.0 7,536.0 19:00 19:15 correction of-11 ft 10/7/2016 10/7/2016 0.25 PROD1 STK TRIP T Continue trip in,dry drift through 7,536.0 8,096.0 19:15 19:30 window, 1 bobble near BOW(2.31 AKO bend motor),dry tag KO billet at 8096 ft,3K WOB,38K PU,Bring pump online to 1.7 bpm,4400 CP, 4000 BHP,411 dP, 15K RIH CW 10/7/2016 10/7/2016 1.75 PROD1 STK KOST T Auto drill at 1 FPH, 13.4K CW,0.3K 8,096.0 8,100.0 19:30 21:15 WOB, 1.7 bpm,4360 CP,3981 BHP, 420 dP. After 1 hour not seeing WOB or dP change,PU,Off bottom parameters at1.5 bpm,3900 CP,3933 AP,350 dP. Continue to auto drill at 2 FPH„stall at 8100 ft,appear to be past the the billet. 10/7/2016 10/8/2016 2.75 PROD1 STK DRLG T Drill to 8117 ft at midnight 8,100.0 8,117.0 21:15 00:00 10/8/2016 10/8/2016 1.00 PROD1 STK DRLG T Continue drilling A-Lat build section, 8,117.0 8,132.0 00:00 01:00 trying to get BHA to build, not building, changed TF to high side,try pushing 4K WOB,slow pump rate to 1.5 BPM 10/8/2016 10/8/2016 1.25 PROD1 STK WPRT T Wiper to window,open EDC and 8,132.0 7,800.0 01:00 02:15 circulate. Consult with town engineer to continue drilling ahead,build is already-10'low. Decision to drill ahead,attempt build hole angle. 10/8/2016 10/8/2016 0.25 PROD1 STK TRIP T Close EDC,trip in,bobble at window, 7,800.0 8,131.0 02:15 02:30 dry drift past billet,tag at 8131 ft,36K PUW, 1.5 bpm, 13K RIH wt,3956 CP, 4082 BHP,392 dP,0 WOB Page 8/23 Report Printed: 10/25/2016 itOperations Summary (with Timelog Depths) 1H-07 Con000Phimtips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MB) 10/8/2016 10/8/2016 0.25 PROD1 STK DRLG T Start drilling at 8131 ft to 8138 ft,ROP 8,131.0 8,155.0 02:30 02:45 increased to 200+FPH appears to have entered PB1. 10/8/2016 10/8/2016 0.42 PROD1 STK WPRT T Wiper back through window,open 8,155.0 7,797.0 02:45 03:10 EDC,PUH slowly 10/8/2016 10/8/2016 1.00 PROD1 STK WAIT T Waiting on work direction from 7,797.0 7,802.0 03:10 04:10 town 10/8/2016 10/8/2016 0.07 PROD1 STK TRIP T Close EDC 7,802.0 7,802.0 04:10 04:14 10/8/2016 10/8/2016 0.52 PROD1 STK TRIP T Circulate in 5x5 Lo/Hi-Vis sweep, 7,802.0 8,075.0 04:14 04:45 RIH 10/8/2016 10/8/2016 0.40 PROD1 STK TRIP T At 8,075' start POOH 8,075.0 7,818.0 04:45 05:09 10/8/2016 10/8/2016 0.05 PROD1 STK TRIP T Open EDC 7,818.0 7,818.0 05:09 05:12 10/8/2016 10/8/2016 1.59 PROD1 STK TRIP T POOH 7,818.0 56.0 05:12 06:48 10/8/2016 10/8/2016 0.29 PROD1 STK DRLG T At surface.Space out. PJSM. 56.0 56.2 06:48 07:05 10/8/2016 10/8/2016 1.10 PROD1 STK PULD T Pressure Undeploy BHA#7 after 56.2 56.2 07:05 08:11 PJSM 10/8/2016 10/8/2016 1.14 PROD1 STK PULD T L/D BHA#7 all scribes and 56.2 0.0 08:11 09:19 motor bend OK 10/8/2016 10/8/2016 0.52 PROD1 STK BOPE P Function Test BOPE good test. 0.0 0.0 09:19 09:51 10/8/2016 10/8/2016 0.39 PROD1 STK PULD T Prep for BHA#8 for setting the 0.0 0.0 09:51 10:14 second billet 10/8/2016 10/8/2016 0.90 PROD1 STK PULD T P/U BHA#8 with PB2 Billet after 0.0 72.9 10:14 11:08 PJSM 10/8/2016 10/8/2016 1.40 PROD1 STK PULD T Pressure Deploy BHA#8,Test 72.9 72.9 11:08 12:32 MWD 10/8/2016 10/8/2016 1.67 PROD1 STK TRIP T RIH pumping at minimum 72.9 7,500.0 12:32 14:12 rate with EDC open 10/8/2016 10/8/2016 0.34 PROD1 STK DLOG T Log for K1 Marker and make 7,500.0 7,552.0 14:12 14:33 correction of minus 12' 10/8/2016 10/8/2016 0.18 PROD1 STK TRIP T Continue RIH. 7,552.0 7,820.0 14:33 14:43 10/8/2016 10/8/2016 0.06 PROD1 STK TRIP T At 7,820'.stop and close 7,820.0 7,820.0 14:43 14:47 EDC WT CK=32K 10/8/2016 10/8/2016 0.18 PROD1 STK TRIP T Continue RIH RIW=16.42 7,820.0 8,056.7 14:47 14:58 10/8/2016 10/8/2016 0.32 PROD1 STK WPST T At 8,056.77(Top at 8045 8,056.7 0.0 14:58 15:17 ft) PUH to neutral weight bring pump online at.63 anchored billet releases at 4,600 psi circ pressure try and set down weight billet starts moving with.9 k on it the top of billet is at 8,056.3' confer with town engineer.Decision made to pull off and then POOH to set another one higher 10/8/2016 10/8/2016 0.22 PROD1 STK TRIP T POOH pumping at.4 bpm 8,056.3 7,820.0 15:17 15:30 10/8/2016 10/8/2016 0.05 PROD1 STK TRIP T Stop here and open EDC EDC 7,820.0 7,820.0 15:30 15:33 open and pump online 10/8/2016 10/8/2016 1.50 PROD1 STK TRIP T POOH pumping MP trip 7,820.0 61.3 15:33 17:03 schedule Page 9/23 Report Printed: 10/25/2016 t z. • i ,u;1.2 0 Operations Summary (with Timelog Depths) 1H-07 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/8/2016 10/8/2016 0.45 PROD1 STK TRIP T At surface.Space out. PJSM. 61.3 61.3 17:03 17:30 10/8/2016 10/8/2016 1.75 PROD1 STK PULD T Pressure Undeploy,had trouble 61.3 0.0 17:30 19:15 getting BHA thru tree,L/D BHA#8 10/8/2016 10/8/2016 1.75 PROD1' STK PULD T PU BHA#9,pressure deploy Anchor 0.0 75.9 19:15 21:00 Billet,checked pack offs,MWD surface check,finish pressure deploy 10/8/2016 10/8/2016 1.75 PROD1 STK TRIP T Trip in with EDC is open,maintain 75.9 7,500.0 21:00 22:45 MPD trip schedule 10/8/2016 10/8/2016 0.25 PROD1 STK DLOG T Log for K1 Marker,make correction of 7,500.0 7,547.0 22:45 23:00 -14 ft,(corrected depth from 7547.35 to 7533.35 ft) 10/8/2016 10/8/2016 0.50 PROD1 STK TRIP T Continue RIH,at 7800 take PUW= 7,547.0 8,011.8 23:00 23:30 33.5K,stop and close EDC,pumps off,RIH,20 FPM 10/8/2016 10/8/2016 0.25 PROD1 STK WPST T At 8011.75,PU to neutral weight 28K, 8,011.8 8,011.8 23:30 23:45 bring rate to 0.45 bpm,sheared at 4500 psi,SO to 4.4K WOB,billet holding,PUW 36K***top of billet at 8000 ft**** 10/8/2016 10/9/2016 0.24 PROD1 STK TRIP T POOH follow MPD trip schedule. 8,011.8 7,300.0 23:45 00:00 10/9/2016 10/9/2016 1.50 PROD1 STK TRIP T Continue trip out with BHA#9,Baker 7,300.0 75.9 00:00 01:30 10 setting tool,bump up and space out BHA. 10/9/2016 10/9/2016 1.50 PROD1 STK PULD T PUD and L/D BHA#9 75.9 0.0 01:30 03:00 10/9/2016 10/9/2016 1.00 PROD1 STK PULD T PU BHA#10 with 2.3+AKO motor,RB 0.0 72.2 03:00 04:00 HCC Bi-Center bit,scribe and check HS correction. 10/9/2016 10/9/2016 2.25 PROD1, STK PULD T PD BHA#10 72.2 72.2 04:00 06:15 10/9/2016 10/9/2016 1.00'PROD1 STK RGRP T PD finished. Wait on motorman to 72.2 72.2 06:15 07:15 take measurements of right angle motors,taking 1 hour for maintenance and to straighten out the String Manager 10/9/2016 10/9/2016 1.70 PROD1 STK TRIP T RIH with EDC open and pumping at.3 72.2 7,500.0 07:15 08:57 bpm 10/9/2016 10/9/2016 0.18 PROD1 STK DLOG T At 7,500' start logging for K1 7,500.0 7,532.4 08:57 09:07 Marker and make correction of minus 13' 10/9/2016 10/9/2016 0.32 PROD1 STK TRIP T Continue RIH pumping at minimum 7,532.4 7,822.0 09:07 09:27 rate. 10/9/2016 10/9/2016 0.22 PROD1 STK TRIP T Stop at 7,822'and offline with pump. 7,822.0 7,989.0 09:27 09:40 Close EDC.Online with pump again at minimum rate.Continue RIH 10/9/2016 10/9/2016 0.07 PROD1 STK TRIP T Offline with and dry tag top of 7,989.0 7,999.9 09:40 09:44 billet tag at 7,999.9' Page 10/23 Report Printed: 10/25/2016 s • t. ,„ 02, da 0 Operations Summary (with Timelog Depths) 1H-07 CcnocaPhitlips �,Lrka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log . Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/9/2016 10/9/2016 2.24 PROD1 STK SEQP T PUH a short ways and bring pump 7,999.9 7,826.0 09:44 11:58 online at 1.1 bpm,PUW=36.5K, Choke B is acting like it's partially plugged,switch to choke A. annular pressure stays the same open bypass and annular pressure stays the same decisiion made to go back to Choke B and start milling. Annular pressure rises,go back to an open bypass line still plugged offline with pump and troubleshoot problem. After much troubleshooting and much angst, finally determined that the MM6/MM7 valve line and the hose off the Annular bag is clogged. Able to get line clear. The pit watcher got a slug of shale and shale pieces about a 1/4"in diameter when line came free. Circulate fluid around to ensure all lines are clear before proceeding. 10/9/2016 10/9/2016 0.44 PROD1 STK SEQP T RBIH slowly and once again bring 7,826.0 7,827.0 11:58 12:25 pump online to minimum rate. At 7989'bring pump rate up to 1.6 bpm to check pressures free spin at 4.3k RIH slowly till motor work and WOB observed....Choke A clogging up again annular pressure rising. PUH above window and troubleshoot plugged chokes again 10/9/2016 10/9/2016 2.00 PROD1 STK SEQP T At 7,827' troubleshoot clogged 7,827.0 7,827.0 12:25 14:25 chokes repeat all steps previously tried. This time clogged area seems to be at both chokes. Isolated both chokes to disassemble and clean. Choke B had very little debris in it,but Choke A had a wire ball of small thin curly Q shavings and flat thin pieces,mostly magnetic looks like coil shavings and some window milling debris. 10/9/2016 10/9/2016 0.24 PROD1 STK TRIP T Close EDC and RIH to try and mill on 7,827.0 7,998.9 14:25 14:39 billet again 10/9/2016 10/9/2016 2.34 PROD1 STK KOST T On top of billet drilling at 1.45 bpm 7,998.9 8,000.4 14:39 17:00 with a ROP of 1.0'p/hr,CP=4,318, WHP=202,BHP=3,920, WOB=.05 10/9/2016 10/9/2016 1.00 PROD1 STK KOST T On top of billet drilling at 1.45 bpm 8,000.4 8,032.0 17:00 18:00 with a ROP of 1.0'p/hr CP=3,968, WHP=202, BHP=3,923, WOB =.05,6 motor stalls KO from billet at 8002',drill ahead to 8032'. 10/9/2016 10/9/2016 0.25 PROD1 STK REAM T Wiper up past billet,RIH to dry drift 8,032.0 8,032.0 18:00 18:15 past billet,increase pump rate to 1.72 bpm, 10/9/2016 10/9/2016 4.50 PROD1 DRILL DRLG T OBD at 1.72 bpm,45 to 55'/hr ROP, 8,032.0 8,306.0 18:15 22:45 4762 CP, 185 WHP,3937 BHP,692 dP. Control drill to limit DLS less than 45°.Pump 5x5 Lo/Hi Vis sweep Page 11/23 Report Printed: 10/25/2016 • • 0 4 Operations Summary (with Timelog Depths) 0. 1H-07 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/9/2016 10/9/2016 0.25 PROD1 DRILL WPRT T Wiper up to 8160',37K PUW,RBIH, 8,306.0 8,306.0 22:45 23:00 13.5K,off-bottom parameters 1.72 bpm,4834 CP,4108 BHP,559 dP,0 WOB 10/9/2016 10/9/2016 0.50 PROD1 DRILL DRLG T Drill to EOB at 8330' 8,306.0 8,330.0 23:00 23:30 10/9/2016 10/9/2016 0.25 PROD1 DRILL WPRT T Wiper up to 7800',jog down to 7826', 8,330.0 7,800.0 23:30 23:45 Open EDC 10/9/2016 10/10/2016 0.25 PROD1 DRILL TRIP T Tripping out at a depth of 6800'as of 7,800.0 6,800.0 23:45 00:00 midnight. 10/10/2016 10/10/2016 1.50 PROD1 DRILL TRIP T Finish tripping,at surface,bump up 6,800.0 72.2 00:00 01:30 and space out. 10/10/2016 10/10/2016 1.50 PROD1 DRILL PULD T Hold PJSM,PUD BHA#10,laydown 72.2 0.0 01:30 03:00 2.3°AKO motor,bit has 3 chipped cutters and 1 plugged jet. 10/10/2016 10/10/2016 1.75 PROD1 DRILL PULD T PU/MU A-Lateral 0.53°AKO motor 0.0 72.2 03:00 04:45 and RB HCC 3.0"bi-center bit,PD BHA#11 10/10/2016 10/10/2016 1.56 PROD1 DRILL TRIP T Trip in with EDC open,pumping MP 72.2 7,500.0 04:45 06:18 schedule.... 10/10/2016 10/10/2016 0.20 PROD1 DRILL DLOG T Logging for tie in to K1 Marker and 7,500.0 7,536.0 06:18 06:30 make correction of minus 14' 10/10/2016 10/10/2016 0.53 PROD1 DRILL TRIP T Continue RIH 7,536.0 8,330.0 06:30 07:02 10/10/2016 10/10/2016 1.07 PROD1 DRILL DRLG T At bottom PUH becuase weights 8,330.0 8,340.0 07:02 08:06 are a little sticky RBIH and start drilling 1.7 bpm,WHP 90 annular pressure starts climbing.Reduce pump rate to 1.5 bpm.WHP falls to 81 and eventually climbs back to 90 with choke wide open.Trouble shoot surface piping and chokes while drilling ahead.It appears we have some blockage downhole. Returns are pretty sticky and clay-like. 10/10/2016 10/10/2016 5.20 PROD1 DRILL DRLG T Something lets loose from downhole 8,340.0 8,530.0 08:06 13:18 and enters piping and slams into choke and works it self through the choke.Pressures are now back to normal WHP=256, BOP=4,025, Pick pump rate back up to 1.7 bpm work WHP back down to 170.ROP=29, WOB=2.45 Continue drilling ahead 10/10/2016 10/10/2016 1.02 PROD1 DRILL DRLG T At 8,530' Drilling ahead Rate 8,530.0 8,630.0 13:18 14:19 =1.7 bpm, CP=4,927, BHP= 4,014, WHP=134, ROP=78 fph, WOB=1.49 10/10/2016 10/10/2016 0.33 PROD1 DRILL WPRT T At 8,630' PUH for a wiper 8,630.0 7,890.0 14:19 14:39 trip 10/10/2016 10/10/2016 0.35 PROD1 DRILL WPRT T RBIH 7,890.0 8,630.0 14:39 15:00 10/10/2016 10/10/2016 2.50 PROD1 DRILL DRLG T At 8,630' BOB Drilling 8,630.0 8,923.0 15:00 17:30 ahead Rate=1.7 bpm, CP= 4,927, BHP=4,014, WHP=134, ROP=78 fph, WOB=1.49 10/10/2016 10/10/2016 0.35 PROD1 DRILL WPRT T At 8,923.0 PUH for a wiper trip to 8,923.0 8,025.0 17:30 17:51 8,025' 10/10/2016 10/10/2016 0.40 PROD1 DRILL WPRT T At 8,025' RBIH 8,025.0 8,923.0 17:51 18:15 Page 12/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) 0 1H-07 ConocoPhiiiips Pd,rks Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/10/2016 10/10/2016 0.75 PROD1 DRILL DRLG T At 8,630' BOB Drilling 8,923.0 9,011.0 18:15 19:00 ahead Rate=1.7 bpm, CP= 4,927, BHP=4,014, WHP=134, ROP=78 fph, WOB=1.49 10/10/2016 10/11/2016 4.99 PROD1 DRILL WPRT T PUH so tool face can be 9,011.0 9,011.0 19:00 00:00 moved stuck pipe.Work pipe up to 60K,several times,pump a 5x5 Lo/Hi Vis Pill try pulling to 60K again with no luck.Confer with town engineer.Prep to pump LVT.Pump LVT and let soak contune to try pulling 10/11/2016 10/11/2016 1.75 PROD1 DRILL WPRT T LVT mineral oil on BHA. Alternate 9,011.0 9,011.0 00:00 01:45 work pipe and relax. Bleed WHP to 80 psi,SO to-5K and pull up 70K at 60 FPM,repeat and come up at 80FPM to 75K. 10/11/2016 10/11/2016 4.75 PROD1 DRILL WPRT T Resume pumping to move fluid, 9,011.0 9,011.0 01:45 06:30 circulate LVT to surface,LVT strung out no clear interface. Pump another 8 bbl LVT pill,stop pumping,let soak with 56K on coil. Work pipe to 70K. Consult with town engineer,decision to set down weight and allow BHP to falloff 10/11/2016 10/11/2016 1.25 PROD1 DRILL WPRT T Shut down pumping,bleed off CP to 9,011.0 9,011.0 06:30 07:45 280,SO weight to 5K. Work pipe 3 cycles,last cycle pull up at 100 FPM to 80K. 10/11/2016 10/11/2016 5.00 PROD1 DRILL WPRT T Allow pipe to relax while waiting for 9,011.0 9,011.0 07:45 12:45 LVT.Start sending mud to TT to make room for mud swap,Circulating at 0.81 bpm,2705 CP,3955 BHP, 11.5 ECD. Annular pressure is eratic, builds up 70 to 100 psi then breaks back. 10/11/2016 10/11/2016 0.50 PROW DRILL WPRT T Bring pump rate up slowly to 1.48 9,011.0 9,011.0 12:45 13:15 bpm,4512 CP,4672 BHP,start experiencing losses above 12.6 ppg ECD,bring rate down to.83 bpm, 3032 CP,4270 BHP, 12.4 ECD. Wait on returns truck to start transfering new mud. 10/11/2016 10/11/2016 1.75 PROD1 DRILL WPRT T Wait on returns truck to start 9,011.0 9,011.0 13:15 15:00 transfering new mud. 10/11/2016 10/11/2016 0.80 PROD1 DRILL WPRT T Start downhole with new mud system 9,011.0 9,011.0 15:00 15:48 3 10/11/2016 10/11/2016 0.20 PROD1 DRILL WPRT T Trap WHP,Work pipe down 3 times to 9,011.0 9,011.0 15:48 16:00 -5K,Work down and up-5 to 75K.No weight change on DHWOB,Able to orient normally 10/11/2016 10/11/2016 3.00 PROD1 DRILL WPRT T Hold pipe in tension,70K,Hook up 9,011.0 9,011.0 16:00 19:00 LVT Truck 10/11/2016 10/11/2016 1.60 PROD1 DRILL WPRT T Pump 20 BBIs LVT,stop and let 9,011.0 9,011.0 19:00 20:36 soakfor 30 min after 8 BBIs out,Pump only to maintain BHP,Work pipe-10K to 76K up.No weight change observed from DHWOB.Still able to orient normally 10/11/2016 10/11/2016 1.50 PROD1 DRILL WPRT T Pump 4 BBIs down coil,8 bbls LVT 9,011.0 9,011.0 20:36 22:06 still in coil,Soak and work pipe Page 13/23 Report Printed: 10/25/2016 is • 0 Operations Summary (with Timelog Depths) $:4 1H-07 ConocoPhiilips Alx ka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/11/2016 10/11/2016 1.20 PROD1 DRILL WPRT T Pull pipe free 80K during step wise 9,011.0 7,795.0 22:06 23:18 pressure reduction,500 PSI WHP, 10.2 ECD,Hole problems 9000 to 8800 and 8650 to 8480.Poor conditions to window 10/11/2016 10/11/2016 0.20 PROD1 DRILL WPRT T Open EDC,Continue up hole to tie in 7,795.0 7,495.0 23:18 23:30 10/11/2016 10/11/2016 0.10 PROD1 DRILL DLOG T Log K1 for+10'correction,Shales 7,495.0 7,514.0 23:30 23:36 coming over shaker,Geo call Kuparuk B shales with siltstone and sand 10/11/2016 10/12/2016 0.40 PROD1 DRILL WPRT T Consult with town for plan forward, 7,514.0 7,514.0 23:36 00:00 Pumping 1.8 BPM in,1.75 Out. 10/12/2016 10/12/2016 4.00 PROD1 DRILL WPRT T Continue wiper to swab.Started 7,514.0 72.0 00:00 04:00 unloading additional shales—1100' from surface.Pipe gouged @ 195' from coil connector,—.023"deep 10/12/2016 10/12/2016 0.20 PROD1 DRILL WPRT T Tag up,Reset counters, Down load 72.0 72.0 04:00 04:12 string data and restart job 10/12/2016 10/12/2016 1.80 PROD1 DRILL TRIP T Trip in well,EDC open,Pumping 1 72.0 7,500.0 04:12 06:00 BPM 10/12/2016 10/12/2016 0.50 PROD1 DRILL SFTY T Hold first CDR 3 SLT meeting. 7,500.0 7,800.0 06:00 06:30 10/12/2016 10/12/2016 1.90 PROD1 DRILL GLEN T Consult with town engineers about 7,800.0 7,830.0 06:30 08:24 plan forward. Transfer new mud to active sytem,viscosify Hi Vis pit 1, prep to clean hole 10/12/2016 10/12/2016 0.45 PROD1 DRILL TRIP T Close EDC,dry drift window,RIH at - 7,830.0 8,330.0 08:24 08:51 0.28 bpm thru build at 25 FPM,to 8330'EOB,saw-5K bobbles at 8056, 8087,8152,8162,8234' 10/12/2016 10/12/2016 0.40 PROD1 DRILL WPRT T Wiper trip back to window,turn around 8,330.0 7,830.0 08:51 09:15 pulling heavy 60K,and grabing motor from 8282 to Pull back through window and open EDC 10/12/2016 10/12/2016 1.75 PROD1 DRILL CIRC T PUH slow while circulate for 4 BU, 7,830.0 7,830.0 09:15 11:00 heavy cuttings and shales in the returns. Choke A show signs of plugging,bring rate to 2 bpm,swap to choke B,back flush choke A. RBIH to top of window 10/12/2016 10/12/2016 0.84 PROD1 DRILL TRIP T Close EDC,RIH at 25 FPM,pumping 7,830.0 8,322.0 11:00 11:50 1 bpm through build,sat down at 8194',PUW 50 to 55K. Sat down at 8075',8085',8278. PUW 55K,pull up to 8210',go back down to 8322',PUW 45 to 60K 10/12/2016 10/12/2016 0.25 PROD1 DRILL WPRT T Work pipe,pull up to 72K,got 8200' 8,322.0 7,811.0 11:50 12:05 weight back to 32K,wiper to window. Open ECD 10/12/2016 10/12/2016 0.75 PROD1 DRILL CIRC T Circulate hole at 2.4 bpm,heavy 7,811.0 7,500.0 12:05 12:50 cuttings and shale inreturns 10/12/2016 10/12/2016 0.25 PROD1 DRILL DLOG T Log K1,make+5.5'correction 7,500.0 7,523.0 12:50 13:05 10/12/2016 10/12/2016 1.90 PROD1 DRILL TRIP T RIH,close EDC,RIH at 25 FPM, 7,523.0 8,389.0 13:05 14:59 pumping 1 bpm,SD at 8345',PUW 40 to 60K,pull up to 8290, RBIH,SD at 8376'SD got hung up,pulled 62K,pull up at 10 FPM to 8200',RBIH,SD at 8345'pull up to 8283',RBIH,SD at 8389', Page 14/23 Report Printed: 10/25/2016 is • ll) Operations Summary (with Timelog Depths) rI 1H-07 Conocoehillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/12/2016 10/12/2016 0.75 PROD1, DRILL WPRT T Wiper up to 8279',stuck near BHA, 8,389.0 7,811.0 14:59 15:44 work pipe to 70K,able to orient, circulate at 1.5 BPM to get BU,got free,pull up,packing off near 8030'. Call from town to come out to set a KO billet.Pull up into window, 10/12/2016 10/12/2016 1.30 PROD1 DRILL TRIP T Open EDC,circulate a BU,pump 5 x 5 7,811.0 8,000.0 15:44 17:02 Hi/Lo vis sweep,close EDC,RIH to 8000'. 10/12/2016 10/12/2016 1.50 PROD1 DRILL WPRT T Wiper trip to surface,Open EDC 8,000.0 72.0 17:02 18:32 @7810 10/12/2016 10/12/2016 3.20 PROD1 DRILL PULD T At surface,Tag up and space out. 72.0 72.0 18:32 21:44 PJSM.PUD BHA#11,PD pre loaded BHA#12 Anchored Billet.M/U to coil and surface test 10/12/2016 10/12/2016 1.00 PROD1 STK SVRG T Complete coil fatigue update,tear 72.0 72.0 21:44 22:44 down MP choke A 10/12/2016 10/13/2016 1.26 PROD1 STK TRIP 'T Trip in hole,EDC open,Pumping.3 72.0 6,300.0 22:44 00:00 BPM 10/13/2016 10/13/2016 0.30 PROD1 STK TRIP T Continue in well with anchor billet 6,300.0 7,500.0 00:00 00:18 10/13/2016 10/13/2016 0.20 PROD1 STK DLOG T Log K1 for-14'correction 7,500.0 7,546.0 00:18 00:30 10/13/2016 10/13/2016 0.40 PROD1 STK TRIP T Continue in well,stop @ 7800'and 7,546.0 7,981.7 00:30 00:54 shut EDC,PUW=33K,Clean trip through window and down to set depth @ 7981.73,Anchor oriented to 30ROHS for HS kick off 10/13/2016 10/13/2016 0.40 PROD1 STK WPST T At set depth and orientation,Pumps 7,981.7 7,997.0 00:54 01:18 on.5 BPM,See tool shift @4200 PSI, set down on billet.At 2000 lbs billet started moving down hole with 300 to 900 Lbs DHWOB.Got up to 1500 Lbs @ 7997.Pulled off billet,PUW=36K, TOB @ 7985' 10/13/2016 10/13/2016 1.50 PROD1 STK TRIP T 7997,Trip out after billet mis set, 7,997.0 61.5 01:18 02:48 Open EDC @ 7795' 10/13/2016 10/13/2016 1.20 PROD1 STK PULD T At surface,Tag up and space out, 61.5 0.0 02:48 04:00 PJSM,PUD BHA#12 Anchor billet running tools 10/13/2016 10/13/2016 1.00 PROD1 STK PULD T Prepping to run memory caliper. 0.0 0.0 04:00 05:00 10/13/2016 10/13/2016 2.00 PROD1 STK WAIT T Wait on Halliburton Memory Caliper 0.0 0.0 05:00 07:00 Service to arrive from Deadhorse 10/13/2016 10/13/2016 2.50 PROD1 STK PULD T Load tools to rig floor,pre job meeting 0.0 0.0 07:00 09:30 to discuss job objectives,off load suction pit and and 50 bbls from shaker pit to vac truck,transfer K- Formate KWF all while PU/MU caliper tools Page 15/23 Report Printed: 10/25/2016 0 11 tz ex Operations Summary (with Timelog Depths) 1 H-07 Conoco hillips FLxk.3 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/13/2016 10/13/2016 1.50 PROD1 STK PULD T BHA#13 pre loaded in DS PDL,MU 0.0 0.0 09:30 11:00 Hallibuton 24-arm memory caliper tool,perform surface check,fuse on battery section appears to have blown, swap to back-up battery section, perform second surface check,tool started open sequence and stopped partially open,after several minutes, went fully open,then fully closed. Break down caliper to check, reprogram tool,MU caliper and perform a third surface check.Third check was good,""Batties Installed 11:17 AM,270 min to open'' 10/13/2016 10/13/2016 1.75 PROD1 STK PULD T PD BHA#13.... 0.0 61.6 11:00 12:45 10/13/2016 10/13/2016 1.50 PROD1 STK TRIP T Trip in with EDC open to K1 marker, 61.6 7,450.0 12:45 14:15 pumping 11.8 K-Formate KWF at minimumm rate 10/13/2016 10/13/2016 0.25 PROD1 STK DLOG T Log K1 marker,-14.5 ft correction 7,525.0 7,525.0 14:15 14:30 10/13/2016 10/13/2016 0.25 PROD1 STK TRIP T Trip in to window, 7,525.0 7,830.0 14:30 14:45 10/13/2016 10/13/2016 1.00 PROD1 STK CIRC T Stop at 7820'and cicrulate hole to 7,830.0 7,830.0 14:45 15:45 KWF,at 0.98 bpm,staring pressures 1642 CP,483 WHP,3874 BHP, 11.57 ECD,MiM In reading 11.74 ppg. After xxx bbls MM out showing ending pressures 10/13/2016 10/13/2016 0.50 PROD1 STK TRIP T Trip in and wait for caliper to open at 7,830.0 7,975.0 15:45 16:15 16:12 10/13/2016 10/13/2016 0.75 PROD1 STK DLOG T Log up at 35 FPM,tie in to K1 marker, 7,975.0 7,230.0 16:15 17:00 arms close at 17:00 10/13/2016 10/13/2016 1.00 PROD1 STK TRIP T Trip to surface 7,230.0 48.8 17:00 18:00 10/13/2016 10/13/2016 0.50 PROD1 STK OWFF T 30 min Flow check 48.8 48.0 18:00 18:30 10/13/2016 10/13/2016 0.50 PROD1 STK PULD T Lay down BHA#13 from dead well 48.0 0.0 18:30 19:00 10/13/2016 10/14/2016 5.00 PROD1 STK PULD T Break down caliper,Down load data to 0.0 0.0 19:00 00:00 town,Process and interpet caliper data 10/14/2016 10/14/2016 1.10 PROD1 STK OTHR T continue to analyze caliper data- 0.0 0.0 00:00 01:06 formulate plan forward 10/14/2016 10/14/2016 0.90 PROD1 STK PULD T M/U BHA#14 with non ported bull 0.0 116.0 01:06 02:00 nose,3 pups, 1 jt 2 3/8 STL Blank, and anchor billet,Make up coiltrack to coil and surface test 10/14/2016 10/14/2016 2.00 PROD1 STK TRIP T Trip in well,EDC open,pumping 116.0 7,570.0 02:00 04:00 minimum rate 10/14/2016 10/14/2016 0.10 PROD1 STK DLOG T Log K1 for-13.5' 7,570.0 7,594.0 04:00 04:06 Page 16/23 Report Printed: 10/25/2016 • • 0 11 Operations Summary (with Timelog Depths) 1H-07 Conoc hilliips �dxka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/14/2016 10/14/2016 0.70 PROD1 STK WPST T Continue in hole,set down in window 7,594.0 7,988.0 04:06 04:48 with anchor slips at bottom of window. Pull up5K over,RIH and stack out. Pull up to neutral weight on DHWOB and orient anchor,worked through window @ 200°.Continue in hole orient slipback to 30°ROHS.Start taking weight @ 7984-top of fish.Get to 2500Lbs DHWOB @ 7988.Slips @ 7943.2.Pumps on tool shifted @ 3200PSI set 2.5K down.Looks good, TOB=7933 10/14/2016 10/14/2016 1.70 PROD1 STK TRIP T Good Set POOH,PUW=41K 7,988.0 116.0 04:48 06:30 10/14/2016 10/14/2016 2.50 PROD1 STK PULD T Break down BHA#14,make up jet 116.0 0.0 06:30 09:00 nozzel,jet stack. 10/14/2016 10/14/2016 1.00 PROD1 STK BOPE T Flush Stack and reel 0.0 0.0 09:00 10:00 10/14/2016 10/14/2016 6.00 PROD1 STK BOPE T BOP Test 250/3500 psi(annular 2500 0.0 0.0 10:00 16:00 psi),witnessed by AOGCC Inspector, Chuck Sheve. Swab 1 &2 leaked. Carry on with BOP test. 10/14/2016 10/14/2016 1.25 PROD1 STK RURD T Lay down test joint,re-head ELine 0.0 0.0 16:00 17:15 (BHI),tested continuity was 1.6 M ohm,checked/cleand flow sub and retested,96 M ohm. Stab on to blow down stack and WC chokes. 10/14/2016 10/14/2016 0.75 PROD1 STK PULD T PJSM, P/U BHA#15,with 2.2°motor 0.0 72.2 17:15 18:00 and Hughes bit 10/14/2016 10/14/2016 0.50 PROD1 STK PULD T Crew change out/Valve check list 72.2 72.2 18:00 18:30 10/14/2016 10/14/2016 0.60 PROD1 STK PULD T PJSM, M/U injector to coil track and 72.2 72.2 18:30 19:06 suface test 10/14/2016 10/14/2016 1.40 PROD1 STK TRIP T Trip in well with BHA#15,Test HOT 72.2 7,510.0 19:06 20:30 while tripping in 10/14/2016 10/14/2016 0.10 PROD1 STK DLOG T Log K1 for-12'correction 7,510.0 7,519.0 20:30 20:36 10/14/2016 10/14/2016 0.10 PROD1 STK TRIP T Continue into well 7,519.0 7,550.0 20:36 20:42 10/14/2016 10/14/2016 1.60 PROD1 STK CIRC T Stop @ 7550',EDC open,displace 7,550.0 7,550.0 20:42 22:18 well back to 8.6PPG flo pro,Shut EDC,PUW=33K 10/14/2016 10/14/2016 0.30 PROD1 STK TRIP T Trip in hole,Clean pass through 7,550.0 7,936.0 22:18 22:36 window,Tag billet @ 7936,P/U 10/14/2016 10/15/2016 1.40 PROD1 STK KOST T Bring on pumps, 1.77 BPM @ 4350 7,936.0 7,938.6 22:36 00:00 PSI FS,BHP=3910,Call milling @ 7936.2 10/15/2016 10/15/2016 0.20 PROD1 STK KOST T Continue milling billet kick off, 1.77 7,938.6 7,939.0 00:00 00:12 BPM @ 4350 PSI FS,BHP=3910 10/15/2016 10/15/2016 0.50 PROD1 STK DRLG T Go to 10-20 FPH, 1.73 BPM @ 4200 7,939.0 7,946.0 00:12 00:42 PSI FS,BHP=3910 10/15/2016 10/15/2016 0.90 PROD1 DRILL DRLG T 7946',Drill ahead, 1.75 BPM @ 4200 7,946.0 7,975.0 00:42 01:36 PSi FS,BHP=3905 10/15/2016 10/15/2016 0.10 PROD1 DRILL WPRT 'T Drift billet area,PUW=36K,Clean 7,975.0 7,975.0 01:36 01:42 pass up and down 10/15/2016 10/15/2016 1.90 PROD1 DRILL DRLG T 7975',Drill, 1.75 BPM @ 4200 PSI 7,975.0 8,065.0 01:42 03:36 FS,BHP=3930 Page 17/23 Report Printed: 10/25/2016 • • !, 0 Operations Summary (with Timelog Depths) 1H-07 ConocoPttitliips 8lackn Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/15/2016 10/15/2016 3.00 PROD1 DRILL WPRT T 8065,DD Wiper,getting less then 8,065.0 8,065.0 03:36 06:36 expected DLS.Planned for 45's, Came off billet @ 43°,Last two surveys 28-33°.Now need 35's to skirt edge of polygon.Confer with rig Geo/Town engineer 10/15/2016 10/15/2016 5.90 PROD1 DRILL DRLG T 8065'drill ahead to 8104',come off 8,065.0 8,300.0 06:36 12:30 bottom and pull up to 8050',BHI tool glitch. Back to drilling at average ROP 30 to 50 FPH,made BHA wiper at 8250',change pump rate to 1.6 bpm, 4177 CP,361 WHP,4043 BHP,517 off bottom dP 10/15/2016 10/15/2016 0.30 PROD1 DRILL WPRT T Wiper up to 7965'at 50 FPM,37K 8,300.0 8,300.0 12:30 12:48 PUW. Trip back in at 50 FPM, 16K. 10/15/2016 10/15/2016 1.70 PROD1 DRILL DRLG T Continue drilling ahead to 8360' 8,300.0 8,360.0 12:48 14:30 10/15/2016 10/15/2016 0.50 PROD1 DRILL WPRT T Wiper trip up to 8060'while DD,GEO 8,360.0 8,360.0 14:30 15:00 and Directional Planner discuss WP13 targets. 10/15/2016 10/15/2016 6.30 PROD1 DRILL WPRT T Continue drilling ahead, 1.72 BPM @ 8,360.0 8,615.0 15:00 21:18 4650 CP,390 WHP,4153 BHP,556 dP off bottom, 10/15/2016 10/15/2016 2.20 PROD1 DRILL TRIP T TD Build/Turn section @ 8615,Pump 8,615.0 55.2 21:18 23:30 5 X 5 Sweeps,Trip out,Open EDC @ 7804,AVG DLS 32.9° 10/15/2016 10/16/2016 0.50 PROD1 DRILL PULD T At surface,PJSM. Lay down BHA#15 55.2 55.2 23:30 00:00 10/16/2016 10/16/2016 1.50 PROD1 DRILL PULD T Complete PUD BHA#15 55.0 0.0 00:00 01:30 10/16/2016 10/16/2016 1.50 PROD1 DRILL PULD T PJSM,PD BHA#16 lateral section 0.0 72.2 01:30 03:00 with.5°AKO motor and RB HYC bi- center bit.Make up to coil and surface test. 10/16/2016 10/16/2016 1.40 PROD1 DRILL TRIP T Trip in hole,EDC open, Pumping min 72.2 7,510.0 03:00 04:24 rate 10/16/2016 10/16/2016 0.20 PROD1 DRILL DLOG T Log K1 tie in for-15'correction,Shut 7,510.0 7,520.0 04:24 04:36 EDC,PUW=34K 10/16/2016 10/16/2016 1.80 PROD1 DRILL TRIP T Continue in well to drill,work pipe to 7,520.0 8,609.0 04:36 06:24 bottom,stack out at 8609',51K PUW 10/16/2016 10/16/2016 2.60 PROD1 DRILL WPRT T Clean hole,wiper up to billet,RBIH, 8,609.0 8,609.0 06:24 09:00 try drilling to bottom,work tight spot at 8490'to 8510',made multiple attempts to get back to bottom,sit down at 8600'and lose 5' to 10'of ground each time we pick up and turn around. Pick up weights are sticky,45K to 55K,see-2K to-4K overpull on DHWOB,heavy returns on shaker, very fine grained silty sandstone,fine shale and siltstone. 10/16/2016 10/16/2016 2.00 PROD1 DRILL DRLG T Drill to bottom from 8606'to 8615',drill 8,609.0 8,723.0 09:00 11:00 ahead at 1.62 bpm,4408 CP,294 WHP,4035 BHP,780 dP on bottom, 2.5K WOB,10K CW. BHA wiper at 8694',35K PUW, 10/16/2016 10/16/2016 4.00 PROD1 DRILL DRLG T 8723'new mud(sys 4)at bit,9.8K 8,723.0 8,790.0 11:00 15:00 CW, 1.61 bpm,4277 CP,286 WHP, 4072 BHP,695 dP, 1.4K WOB Page 18/23 Report Printed: 10/25/2016 ill Operations Summary (with Timelog Depths) 0.4 0 1H-07 CanacoPhilltps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Cade Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/16/2016 10/16/2016 2.50 PROD1 DRILL WPRT T Wiper trip,clean PU 36K,pulled thru 8,790.0 7,780.0 15:00 17:30 tight spots 8590'and 8470',45 to 53K, continued to 8000',RBIH and sat down at 8065,8170,8490',8640', worked tight spots to 8670',got back to 8700'pulled 62K with no change in WOB,wiper back to 8000',try to go back down,not able to pass 8600', wiper back to the tubing. Open EDC and 1.89 bpm,PUH to 7501 for tie in 10/16/2016 10/16/2016 0.20 PROD1 DRILL DLOG T Log K1 for+7', 7,501.0 7,514.0 17:30 17:42 10/16/2016 10/16/2016 1.50 PROD1 DRILL WPRT T RBIH to drill,cloase EDC @ 7798, 7,514.0 8,609.0 17:42 19:12 Multiple tight spots,Unable to get past 8609 with multiple speeds and tool faces.Hard bottom with stalls.Pick ups @ 50K but consistant.Confer with town,drill through tight spot @ 70 to 80°LOHS 10/16/2016 10/16/2016 1.90 PROD1 DRILL DRLG T Attempt to drill past tight spot @ 8609, 8,609.0 8,659.0 19:12 21:06 1.68 BPM @ 4225 PSi FS, BHP=4215,TF 70°LOHS. Never got in old hole,Near bit changing from other hole,Drill ahead 50' 10/16/2016 10/16/2016 0.60 PROD1 DRILL WPRT T Wiper trip from 8659,got past 8609, 8,659.0 8,090.0 21:06 21:42 PUH to 8093,Tight spots with motor work and over pulls 8600 to 8430,Pull up to 8090 10/16/2016 10/16/2016 0.80 PROD1 DRILL WPRT T RBIH to drill,Hole in better shape,still 8,090.0 8,659.0 21:42 22:30 ratty 8430 to 8500,Easy past 8607 10/16/2016 10/17/2016 1.50 PROD1 DRILL 'DRLG T 8659',Drill,1.7 BPM @ 4465PS1 FS, 8,659.0 8,726.0 22:30 00:00 BHP=4100 PSI 10/17/2016 10/17/2016 1.90 PROD1 DRILL DRLG T 8726',Drill ahead, 1.7 BPM @ 4390 8,726.0 8,826.0 00:00 01:54 PSI FS,BHP=4115,RIW=7.7K DHWOB=2.2K 10/17/2016 10/17/2016 0.50 PROD1 DRILL WPRT T BHA wiper, 100', PUW=43 8,826.0 8,826.0 01:54 02:24 10/17/2016 10/17/2016 3.80 PROD1 DRILL DRLG T 8826',Drill, 1.7 BPM @ 4375 PSI FS, 8,826.0 8,960.0 02:24 06:12 BHP=4170,RIW=7.3 @ 1K DHWOB 10/17/2016 10/17/2016 0.70 PROD1 DRILL WPRT T Wiper to 8400',PUW off bottom was 8,960.0 8,960.0 06:12 06:54 53K,worked tight areas,pulled tight at 8400'to 58K,opted to stay below 8400',worked to get past 8600' 10/17/2016 10/17/2016 2.70 PROD1 DRILL DRLG T 8960',Drill, 1.60 BPM,@ 4190 PSI 8,960.0 9,050.0 06:54 09:36 FS,4225 BHP,9.6K, 1.9K WOB.ROP avg 35 FPH. PU off bottom,change rate to try to get higher ROP, 1.75 BPM,4675 PSI FS,4280 BHP,550 dP,not much change in ROP 30 to 50 FPH 10/17/2016 10/17/2016 0.20 PROD1 DRILL WPRT T BHA wiper, 100'to 8950',PUW=62K 9,053.0 9,050.0 09:36 09:48 10/17/2016 10/17/2016 4.50 PROD1 DRILL DRLG T 9050',Drill at 1.76 bpm,4675 PSI FS, 9,050.0 9,262.0 09:48 14:18 4280 BHP,550 dP. At 9153'pumped 5x5 Lo/Hi Vis sweep,seeing some stick/slip,got back small gravel size pieces of sand/shale. At 9167' pumped a 5x5 Lo/Hi sweep, At 9252' start 5x5 Lo/Hi vis sweep Page 19/23 Report Printed: 10/25/2016 • • 0 '0. Operations Summary (with Timelog Depths) 1H-07 ConocoPhiilips r,l.rks Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/17/2016 10/17/2016 5.70 PROD1 DRILL WPRT T 9260',PUW=62K,wiper up hole at 15 9,260.0 7,500.0 14:18 20:00 FPM,33k CW, 1.8 bpm,4600 CP,371 WHP,4070 BHP,578 dP,work though tight areas,pulled 63K at 8560',wiper up to 8000',attempt to RBIH and keep sitting down at 8509', tried to vary running speed,pump rates,tool face,keep sitting down in the same spot. Pump 5 bbl Hi Vis sweep, Consult town engineer,pull up into tubing,open EDC while waiting. 10/17/2016 10/17/2016 1.50 PROD1 DRILL TRIP T Trip out for different BHA 7,500.0 72.2 20:00 21:30 10/17/2016 10/17/2016 1.30 PROD1 DRILL PULD T Hold PJSM,PUD BHA#16, 72.2 0.0 21:30 22:48 10/17/2016 10/18/2016 1.20 PROD1 DRILL PULD T MU BHA#17 with 1.2°AKO motor, 0.0 72.0 22:48 00:00 2.79"D331 mill with diamond side cut. PD BHA 10/18/2016 10/18/2016 1.30 PROD1 DRILL PULD T Continue PD BHA#17 with D331 and 72.0 72.0 00:00 01:18 1.2°motor,Inspect choke A,All good, M/U to coil and surface test tools 10/18/2016 10/18/2016 1.50 PROD1 DRILL TRIP T Trip in hole BHA#17,Test HOT on 72.0 7,510.0 01:18 02:48 way in 10/18/2016 10/18/2016 0.20 PROD1 DRILL DLOG T Log K1 for-15.5'correction,Close 7,510.0 7,520.0 02:48 03:00 EDC,PUW=34k, 10/18/2016 10/18/2016 3.50 PROD1 DRILL TRIP T Continue in well,Clean pass through 7,520.0 9,263.0 03:00 06:30 window,Initial set down @ 8492. Work pipe down to 8517, Back ream up Continue working to bottom.8530 hard to get by 10/18/2016 10/18/2016 0.90 PROD1 DRILL WPRT T Made it to TD @ 9263',Pump 5 X 5 9,263.0 7,850.0 06:30 07:24 sweeps and chase to window, PUW=38K 10/18/2016 10/18/2016 0.30 PROD1 DRILL WPRT T Pull up through window,Open EDC 7,850.0 7,510.0 07:24 07:42 and circ 2 BPM,PUH to K1 10/18/2016 10/18/2016 0.20 PROD1 DRILL DLOG T Log K1 for+4'correction 7,510.0 7,517.0 07:42 07:54 10/18/2016 10/18/2016 0.70 PROD1 DRILL WPRT T RBIH,Close EDC @ 7822,Trip in to 7,517.0 9,260.0 07:54 08:36 TD @ 9260,hole in much better shape 10/18/2016 10/18/2016 2.30 PROD1 DRILL WPRT T Tag TD,Pump 10 X 10 sweeps and 9,260.0 62.0 08:36 10:54 chase to swab 10/18/2016 10/18/2016 1.50 PROD1 DRILL WPRT T Tag up,Reset counters,RBIH 62.0 7,510.0 10:54 12:24 ' 10/18/2016 10/18/2016 0.20 PROD1 DRILL DLOG T Log K1 for-16'correction 7,510.0 7,538.0 12:24 12:36 10/18/2016 10/18/2016 2.00 PROD1 DRILL WPRT T Continue in well to confirm TD,Close 7,538.0 9,263.0 12:36 14:36 EDC @ 7801,Slight bobble @ 8600', Pretty clean to TD @ 9263 10/18/2016 10/18/2016 2.40 PROD1 DRILL TRIP T Trip out pumping beaded liner running 9,263.0 52.0 14:36 17:00 pill followed by 11.8 PPG Completion fluid,Paint EOP flag @ 6300', Continue out of well 10/18/2016 10/18/2016 0.50 PROD1 DRILL -OWFF T Tag up at surface,Perform 30 Min 52.0 52.0 17:00 17:30 flow check 10/18/2016 10/18/2016 1.50 PROD1 DRILL PULD T PJSM,LD BHA#17(D331 and 1.2° 52.0 0.0 17:30 19:00 motor). Page 20/23 Report Printed: 10/25/2016 • • 0 1111 Operations Summary (with Timelog Depths) 1H-07 ConocoPhiilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/18/2016 10/18/2016 1.00 PROD1 DRILL PULD T PU BHA#18(HCC RR and 0.5° 0.0 72.2 19:00 20:00 motor). 10/18/2016 10/18/2016 1.65 PROD1 DRILL TRIP T RIH with BHA#18,EDC open 72.2 7,510.0 20:00 21:39 10/18/2016 10/18/2016 0.20 PROD1 DRILL DLOG T Log K1 for-15.5'correction. 7,510.0 7,535.0 21:39 21:51 10/18/2016 10/19/2016 2.15 PROD1 DRILL DISP T Cont RIH to 7,810'.Displace well from 7,535.0 7,820.0 21:51 00:00 11.8 ppg K-formate brine to 8.6 ppg FloPro holding 11.4 ppg managed pressure schedule at the window. 10/19/2016 10/19/2016 0.20 PROD1 DRILL DISP T Finish displacing wellbore above 7,820.0 7,754.0 00:00 00:12 window from 11.8ppg K-formate brine to 8.6ppg FloPro.PUH to close EDC. PUW=31 k. 10/19/2016 10/19/2016 0.30 PROD1 DRILL TRIP T RIH,stacked out @ 8,051'once.PUH 7,754.0 8,531.0 00:12 00:30 and run through.Stacked out again @ 8,531'.Worked pipe varying speed from 5 to 50 FPM,tried various tool faces,no luck. 10/19/2016 10/19/2016 5.70 PROD1 DRILL WPRT T PUH,pull heavy @ 8,315'.Work pipe. 8,531.0 8,531.0 00:30 06:12 Cont POOH to above window.Discuss with town.Decision made to swap back to beaded liner pill and completion fluid(k-formate brine)and run liner.RBIH,pump 10x10 sweeps, PUH above window,wait on liner pill and completion fluid.RBIH to 8,531'. 10/19/2016 10/19/2016 2.90 PROD1 DRILL DISP T Trip out pumping beaded liner running 8,531.0 66.0 06:12 09:06 pill followed by 11.6 PPG completion fluid, Paint EOP flag 7690,and 6300' 10/19/2016 10/19/2016 0.50 PROD1 DRILL OWFF T At surface,perform 30 min no flow 66.0 66.0 09:06 09:36 10/19/2016 10/19/2016 0.90 PROD1 DRILL PULD T Good no flow,PJSM,Lay down BHA 66.0 0.0 09:36 10:30 #18 10/19/2016 10/19/2016 4.50 COMPZI CASING PUTB P PJSM,R/U floor to run liner,M/U BHA 0.0 1,428.2 10:30 15:00 #19 with non-ported bullnose, 15 Jts slotted liner,32 Jts blank and 6.42' seal bore deployment sleeve 10/19/2016 10/19/2016 1.00 COMPZ1 CASING PULD P M/U coiltracto completion and surface 1,428.2 1,472.4 15:00 16:00 test 10/19/2016 10/19/2016 2.50 COMPZ1 CASING TRIP P Trip in hole,BHA#19 1,472.4 8,057.0 16:00 18:30 10/19/2016 10/19/2016 2.00 COMPZ1 CASING TRIP T Hard tag @ 8,057'.Worked liner at 8,057.0 1,472.0 18:30 20:30 various speeds(5-100 FPM),various pump rates,to no avail.Decision made with town to POOH with liner. 10/19/2016 10/19/2016 0.50 COMPZ1 CASING OWFF T At surface with coil,perform 30 min 1,472.0 1,472.0 20:30 21:00 flow check. 10/19/2016 10/19/2016 1.75 COMPZ1 CASING PULD T PJSM,LD BHA#19(liner running 1,472.0 1,422.0 21:00 22:45 assembly). 10/19/2016 10/20/2016 1.25 COMPZI CASING PULD T LD 14 jnts solid liner averaging 11-12 1,422.0 1,002.0 22:45 00:00 jnts/hr. 10/20/2016 10/20/2016 2.50 COMPZ1 CASING PULD T Cont LD remaining 33jnts liner(47 1,002.0 0.0 00:00 02:30 total)averaging 13 jnts/hr. 10/20/2016 10/20/2016 1.50 COMPZ1 CASING PULD T PJSM,MU BHA#20(D-331 mill 2.79" 0.0 62.4 02:30 04:00 NoGo+1.2°AKO motor).Pull and replace UQC check valves.MU to coil connector and test tools. Page 21/23 Report Printed: 10/25/2016 • • Operations Summary (with Timelog Depths) 0 1 H-07 CCX10.1 Phillips a.Lnks Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(5KB) 10/20/2016 10/20/2016 1.40 COMPZ1 CASING -TRIP T Trip in EDC closed,pumping min rate 62.4 7,510.0 04:00 05:24 10/20/2016 10/20/2016 0.20 COMPZ1 CASING DLOG T Log K1 for-15.5'correction 7,510.0 7,520.0 05:24 05:36 10/20/2016 10/20/2016 0.10 COMPZ1 CASING TRIP T RIH to just above window. 7,510.0 7,822.0 05:36 05:42 10/20/2016 10/20/2016 2.00 COMPZI CASING DISP T Displace 11.6ppg K-formate brine to 7,822.0 7,822.0 05:42 07:42 9.0ppg FloPro(higher weight due to K -formate mixing from previous fluid swaps).Receive EDC error code 4, BHI consult with town.Calibrate EDC in hole.Continue swapping to Flo Pro 10/20/2016 10/20/2016 2.80 COMPZ1 CASING WPRT T Continue in hole,Clean pass through 7,822.0 9,263.0 07:42 10:30 window.Tag up @ 8090 work pipe and back ream up from 8108.Work and get through 8530 tag up and ream up from 8624 to 8460.Set down at 8530 and attempt to get by.Pump sweep and ream up to 8450.RBIH to 8530 try to work past.Try different tool faces and go through @ 130°LOHS. Trip in to bottom 10/20/2016 10/20/2016 3.50 COMPZI CASING WPRT T PUH,PUW=33K,8630 pulling heavy, 9,263.0 8,110.0 10:30 14:00 back ream area.8544 again pulling heavy and slight packing off. Back ream up 8520 and 8497.recip these areas and work pipe up to 8110. 10/20/2016 10/20/2016 0.60 COMPZ1 CASING WPRT T Trip in hole to bottom,Liner running 8,110.0 9,263.0 14:00 14:36 pill ready to go,Stack out at 8497, Pick up and continue in hole 10/20/2016 10/20/2016 0.40 COMPZI CASING WPRT T Tag up at TD 9263,Recip waiting on 9,263.0 9,263.0 14:36 15:00 pill 10/20/2016 10/20/2016 2.00 COMPZ1 CASING TRIP T Trip out of hole laying in beaded liner 9,263.0 62.4 15:00 17:00 running pill 11.5PPG followed by 11.5PPG Completion fluid.Paint YELLOW flag @ 7,700'and WHITE flag @ 6,300'. 10/20/2016 10/20/2016 0.50 COMPZ1 CASING OWFF T Perform 30 min flow check. 62.4 62.4 17:00 17:30 10/20/2016 10/20/2016 1.50 COMPZ1 CASING PULD 'T LD BHA#20(D331 mill+1.2°AKO 62.4 0.0 17:30 19:00 motor).Mill was still 2.79"NoGo. 10/20/2016 10/20/2016 2.75 COMPZ1 CASING PULD T PJSM,MU liner assembly,BHA#21, 0.0 1,423.1 19:00 21:45 with 1.5°bent sub+1.82'pup jnt+ bull nose to simulate same lift as the previous BHA.RD power tongs.RU little jerks. 10/20/2016 10/20/2016 1.50 COMPZ1 CASING PULD T PJSM,MU liner assembly to running 1,423.1 1,479.7 21:45 23:15 tools,including Torque Through Deployment Sleeve to allow for orienting.CO UQC check valves, check inj PO. 10/20/2016 10/21/2016 0.75 COMPZ1 CASING TRIP T RIH BHA#21. 1,479.7 6,077.0 23:15 00:00 10/21/2016 10/21/2016 0.95 COMPZ1 CASING TRIP T RIH BHA#21 oriented HS.Stacked 6,077.0 8,052.0 00:00 00:57 out @ 8,052'.Worked pipe in 10° increments LOHS,20-50 FPM. Passed through at 70°LOHS,22 FPM. Page 22/23 Report Printed: 10/25/2016 • 0 0 Operations Summary (with Timelog Depths) ga 1H-07 ConocoPhiflips , A;.xAa Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKB) End Depth(ftKB) 10/21/2016 10/21/2016 1.15 COMPZ1 CASING TRIP T Cont RIH oriented 130°LOHS. 8,052.0 8,538.0 00:57 02:06 Stacked out @ 8,538'.PUH,oriented to 160°ROHS and passed through. 10/21/2016 10/21/2016 2.80 COMPZ1 CASING TRIP P Cont RIH.Worked pipe extensively 8,538.0 9,022.0 02:06 04:54 from 8,900'to 9,022'.Worked pipe in 20°increments,various speeds.Tried to stay above 8,900'while working pipe due to fault. 10/21/2016 10/21/2016 1.00 COMPZ1 CASING TRIP P Closed Choke,pressured up wellbore 9,022.0 9,061.0 04:54 05:54 to BHP @ tool=4200 psi.Worked pipe from 9,022'to 9,061'.PUWs—50-65k. Bled off pressure,cont to work pipe. Pressure up wellbore to BHP @ tool=4400 psi.Cont working pipe. 10/21/2016 10/21/2016 2.50 COMPZ1 CASING TRIP P Continue working pipe,loosing ground 9,061.0 9,079.0 05:54 08:24 at every pick up,Trying multilpe tool faces and running speeds 10/21/2016 10/21/2016 0.30 COMPZ1 CASING TRIP P Unable to get past 9079,consult with 9,079.0 9,045.0 08:24 08:42 town,Release from liner, TOL=7654.4,PUH 10/21/2016 10/21/2016 2.00 COMPZ1 CASING DISP P PUH to 9045,Reset depth for liner left 9,045.0 7,607.0 08:42 10:42 in hole,roll hole to seawater 10/21/2016 10/21/2016 3.80 COMPZ1 CASING DISP P Trip out of well, Pump 25 BBIs freeze 7,607.0 41.0 10:42 14:30 protect well from 2500' 10/21/2016 10/21/2016 2.50 COMPZ1 CASING PULD P At surface,PJSM,PUD BHA#21, 41.0 0.0 14:30 17:00 FVS not holding,Power up and shut EDC.Cont PUD ops. 10/21/2016 10/21/2016 2.50 DEMOB WHDBOP MPSP P PJSM,RU and lubricate in BPV,550 0.0 0.0 17:00 19:30 psi WHP.BPV set,RD lubricator. 10/21/2016 10/22/2016 4.50 DEMOB WHDBOP RURD P Pull UQC checks,blow down stack, 0.0 0.0 19:30 00:00 reel,other rig lines.Troubleshoot Gen power issue. 10/22/2016 10/22/2016 3.00 DEMOB WHDBOP NUND P Finish blowing down lines,ND BOP, 0.0 0.0 00:00 03:00 install tree cap. **Rig Release @ 0300 after ND BOP"" Cont with rig down checklist,trucks arrived 0400. Page 23/23 Report Printed: 10/25/2016 • • ❑ v 0 2 ,- CoQ V(O N ~ ❑ V) N- @❑ Q � 0)) +c- 4 a)xs 0 m � o `m (-NJ m n�n a) CO S ❑ C O 0 0 U 0 C) C m , "O � � F- -J c-1 0 t Q rn co a. o-C ti t E °6 Ili ]-13a) o@) Co Nco a � Qaoo = ❑ crn 00 'c) 8 L .E ~ C a � F- QN mo ,n -1S a) N- i,3 _ is E m m a) a) N _ U aN NQ a a ,. En O. LQOr❑ 7 -o El OUJ W N� O� C CO p C o LN 6 � (DE ❑ l) (N a) co m m ❑ ❑ Eo? U) EIS ❑a 1 1-O@ N .fl E 2 ❑ � pN (r3 � O-� 0 N C p Ur Nr UV U) 4 N a Cl) CNO NCO CN- U) r C OJ r O CoQ ., co r CO r 0 N- C 0 N. CK) co c , ❑ CO co O 0 N- CO 0 „i W Ur IB I a3 C1 Cl) U Y C1 Cl) (p I,- a)C i ❑ a) i • �, p-,,A),71,77'4,4'.„, `THE STATE• Alaska Oil and Gas i:,,.aA�n 1 sKA Conservation Commission O =�"= 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 h'v Main: 907.279.1433 o4'.ILAS1°.' Fax: 907.276.7542 Q� www.aogcc.alaska.gov 14 J l 'q Jason Burke \f CTD Engineer ConocoPhillips Alaska, Inc. S��� L' P.O. Box 100360NEV FEB Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H-07 Permit to Drill Number: 182-084 Sundry Number: 316-024 Dear Mr. Burke: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, - ":9D-e-L-74 --- Cathy '. Foerster Chair i Si- DATED this z--4ay of January, 2016. RBDMS LL- JAN 2 5 2016 • • RECEIVED JAN 14 016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ^I 4111C, APPLICATION FOR SUNDRY APPROVALS ( C 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑r Fracture Stimulate 0 Repar Well 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 ChangeApproted Program 0 Plug for Redrill ❑., . Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other. 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory 0 Development 0 182-084 ` 3.Address: Stratigraphic 0 Service [], 6.API Number. Rib PO Box 100360 Anchorage AK 99510 50-029-20755--Mr OC) 7.If perforating: 8.Well Nane and Number. What Regulation or Conservation Order governs well spacing in this pool? - Will planned perforations require a spacing exception? Yes ❑ No 2 / KRU1H 07 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25639 ' Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): %/ Plugs(MD): Junk(MD): 8274' 6937' 8194' 6867' 3065 psi None 8162'(fish) Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 80' 80' 1640 psi 630 psi Surface 2365' 10-3/4" 2365' 2255' 3580 psi 2090 psi Intermediate Production 8274' 7" 8274' 6937' 4980 psi 4330 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7696'-8051' • 6442'-6744' 3.5" L-80 7910' Packers and SSSV Type: Packer Baker FHL retrievable Packers and SSSV MD(ft)and TVD(ft): t Packer @ 7675'MD&6424'TVD SSSV:Nipple . SSSV @ 503'MD&503'ND 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development❑ Service 0 14.Estimated Date for 15.Well Status after proposed work: �( Commencing Operations: 3/1/2016 OIL ❑ WINJ L ' WDSPL 0 Suspended [ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jason Burke,CTD Engineer Email jason.burkea.conocophillips.com Printed Name Jason Burke 907- •5-6097 Title CTD Engineer i Signature i� - one Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ErV Mechanical Integrity Test ❑ Location Clearance 0 Other: dap i-r ,t -to 35--(Jop 5,' (./1/1 P 5 P is 306, 5- p 5 5 4-7.--)nu La r- pit-e" /tv t-re 1-r5 t 1-c. 25-0 c, 7, 5 r 4/tcvnatc plvy pleaccvvar appro vcc/ p v .20 4A-C 25. 112- Cil Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No By Subsequent Form Required: /0 40 5- 4e7() APPROVED BYApproved by: COMMISSIONER THE COMMISSION Date: /,27-4,.., !/T1/21/14 i i/is/i� Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate �R(id ORIGINAL 1 .,0 RBDMS Lt- JAN 2 5 2016 • • s ConocoPh i l l ip Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 13, 2016 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a two lateral well out of the Kuparuk well 1H-07 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in March 2016. The CTD objective will be to drill three laterals (1H-07A& 1 H- 07AL1), targeting the A sand intervals. A cement plug must be placed and squeezed in the3.5" x 7" annulus of well 1 H-07 to facilitate a casing exit for these laterals, which will likewise effectively plug off the existing perforations. ConocoPhillips requests a variance from the plugging requirements of 20 AAC 25.112 (c)to facilitate the casing exit of the 1H-07 horizontal laterals. The proposed plugging procedure meets the overall objective of this section, providing an equally effective plugging of the well to prevent migration of fluids to other hydrocarbon zones or freshwater. Attached to this application are the following documents: - 10-403 Sundry application to plug A/C-sand perfs in 1H-07 - Summary of the operations - Permit to Drill Application Form 10-401 for 1 H-07A& 1 H-07AL1 - Detailed Summary of Operations - Directional Plans - Current Schematic - Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6097. Sincerely, 411011.4e. Jason Burke Coiled Tubing Drilling Engineer 907-231-4568 Ike �&C work 0 Dal ,'rt/" "e EOR flood et#ech'eeetew P e rite-of Peat (1*1 ; gIovr.� (ecop-e f . KR4- 011 • KRU 1H-07 CTD Summary for Plugging Sundry (10-403) Summary of Operations: Well KRU 1H-07 is a Kuparuk A-sand/C-sand injection(service)well equipped with 3'/2"tubing and 7"production casing. The CTD laterals drilled from the injector well will target the Kuparuk A-sands in fault blocks adjacent and corresponding to the wells current locations. KRU 1H-07 is planned for 2 laterals or 4,245' of total hole in the A-sand reservoir. Prior to drilling,the existing C-sand perforations in 1H-07 will be plugged with cement,and the A-sand will need to be permanently abandoned with sand and cement on top of a plug set in the 2'/8"tubing tail. The purpose of this is to provide a means to kick out of the 3-1/2"and 7"casing and also to isolate the C-sand and A-sand perfs from the newly drilled laterals in the A-sand. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A/C-sand perfs in this manner. Cement will be laid in from the tubing tail plug at 7910' MD and then squeezed into the Cl &C3/C4 perforations through the AVA ported nipples located at 7781' &7874' MD. The cement will be milled out using CT down to 7857' MD which will leave a 32' cement plug on top of the sand and plug in the 2'/8"tailpipe. A mechanical whip-stock will then be set at 7842' MD to perform the CT sidetrack for 1H-07A&AL1. CTD Drill and Complete 1H-07 Laterals: April 2016 Pre-CTD Work 1. RU slick-line i. Set plug in D-nipple at 7899' MD. ii. Dump 10'of sand on top of tubing tail plug 2. RU coil i. Cement squeeze C-sand perforations, and fill 3-1/2"x 7"annuli allow cement to harden. ii. Mill down to 7857' MD -7741 -.5 iii. Under ream down to 7857' MD ,It/Y2 civ iv. Pressure test cement. 3. RU E-Line i. Dummy WS drift to 7842' ii. Run and set WS at 7842' MD. 4. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16" BOPE,test. 2. 1H-07A Side Track(A4 sand south) a. Mill 2.80"window at 7,842' MD. b. Drill 2.74"x 3.00"bi-center lateral to TD of 11,100' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 8,254' MD n / 3. 1H-07AL1 Lateral(A4 sand south) N.•w p 7-1) a. Kick off of the aluminum billet at 8,254' MD b. Drill 2.74"x 3.00"bi-center lateral to TD of 9,250' MD Page 1 of 2 1/11/2016 i • c. Run 2%"slotted liner from TD up to 7830' MD, inside the 31/2"tubing. Liner includes a swell packer at 7832' MD and a liner-top packer inside the 3'/2"tubing. 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Produce well for more than 30 days 4. Re-sundry to turn back to injection Page 2 of 2 1/11/2016 • P777 b • vb-rn ` � I Kuparuk CTD Laterals NASOOS 1 H-07A & A L1 Application for Permit to Drill Document 2RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.0050 and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 MC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 MC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Quarter Mile Injection Review(for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 1 H-07A&AL1 7 Attachment 2: Current Well Schematic for 1 H-07 7 Attachment 3: Proposed Well Schematic for 1 H-07A&AL1 7 Page 1 of 7 January 11, 2016 • • PTD Application: 1H-07A & AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) The proposed laterals described in this document are 1 H-07A& L1. All laterals will be classified as"Service— Injection"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1 H-07A& L1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Using the maximum formation pressure in the area of 3721 psi in 1H-07 (i.e. 10.9 ppg EMW), the maximum potential surface pressure in 1 H-07, assuming a gas gradient of 0.1 psi/ft, would be 3065 psi. See the"Drilling Hazards Information and Reservoir Pressure"section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The formation pressure in KRU 1H-07 was measured to be 3721 psi (10.9 ppg EMW) on 11/27/2015. The maximum downhole pressure in the 1 H-07 vicinity is the 1H-07. The well will be drilled toward lower pressure. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No gas injection performed at 1H pad however, if significant gas is detected in the returns, the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected risk of hole problems is 1 large fault crossing. Managed pressure drilling (MPD)will be used to reduce the risk of shale instability associated with the fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 H-07 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 January 11,2016 • • PTD Application: 1 H-07A & AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 1H-07A 8254' 11100' 6481' 6582' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 2%", 4.7#, L-80, ST-L slotted liner; 1 H-07AL1 7830' 9250' 6650' 6659' with a swell packer in the'B' shale and a liner top packer on top Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 65.0 H-40 Welded 30' 80' 0' 80' 1640 630 Surface 10-3/4" 45.5 K-55 BTC 29' 2365' 0' 2340' 3580 2090 Production 7" 26.0 K-55 BTC 29' 8274' 0' 6937' 4980 4330 Tubing 3-1/2" 9.3 L-80 8rd EUE 25' 7662' 0' 6413' 10160 10530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (9.7 ppg) — Drilling operations: Chloride-based PowerVis mud (9.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over-balance and maintain wellbore stability while running completions Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1 H-07 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 7 January 11, 2016 • • PTD Application: 1H-07A & AL1 Pressure at the 1H-07 Window(7842' MD, 6566'TVDSS) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure(10.9ppg) 3721 psi 3721 psi Mud Hydrostatic(9.6 ppg) 3278 psi 3278 psi Annular friction (i.e. ECD, 0.060 psi/ft) 471 psi 0 psi Mud+ ECD Combined 3748 psi 3278 psi (no choke pressure) (overbalanced (underbalanced -27 psi) -444 psi) Target BHP at Window(11.8 ppg) 4029 psi 4029 psi Choke Pressure Required to Maintain 281 psi 751 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 1H-07 is a Kuparuk A-sand injection well equipped with 3'/2"tubing and 7"production casing. Two laterals will be drilled to the south of the parent well with the laterals targeting the A4 sand. A thru- tubing whip-stock will be set inside the 3'/2"liner at the planned kickoff point of 7842' MD to drill both laterals. The 1H-07A southern sidetrack will exit through the 31/2"liner and 7"production casing at 7842' MD and TD at 11,100' MD,targeting the A4 sand. It will be completed with 2%"slotted liner from TD up to 8254' MD with an aluminum billet for kicking off the 1H-07AL1 lateral. The 1H-07AL1 will drill south to a TD of 9250' MD targeting the A4 sand. It will be completed with 2%" slotted liner from TD up to 7830' MD with a swell packer in the `B' shale and a liner top production packer on top. Page 4 of 7 January 11, 2016 • PTD Application: 1 H-07A & AL1 Pre-CTD Work 1. RU slickline. a.Pull lower most AVA isolation sleeve at 7874' MD b.Dummy of GLV's 2. RU pumping a.Perform injectivity test using diesel on the Cl perfs 3. RU slick-line a.Pull AVA isolation sleeve at 7781' MD allowing the Cl & C3/C4 to equalize 4. RU coil a.Cement squeeze C-sand perforations,and fill 3-1/2"x 7"annuli allow cement to harden. b.Mill down to 7857' MD c.Under ream down to 7857' MD d.Pressure test cement. 5. RU E-Line a.Dummy WS drift to 7842' b.Run and set WS at 7842' MD. 6. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1H-07A Side Track(A4 sand south) a. Mill 2.80"window at 7,842' MD. b. Drill 2.74"x 3.00"bi-center lateral to TD of 11,100' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 8,254' MD 3. 1 H-07AL 1 Lateral(A4 sand south) a. Kick off of the aluminum billet at 8,254' MD b. Drill 2.74"x 3.00"bi-center lateral to TD of 9,250' MD c. Run 2%"slotted liner with swell packer at 7832' MD from TD up to 7830' MD,inside the 3'/2" tubing with a liner top packer Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Produce well for more than 30 days 4. Re-sundry to turn back to injection Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. Page 5 of 7 January 11, 2016 S PTD Application: 1H-07A & AL1 — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick-line. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 1H-07 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance 1H-07A 6990' 1 H-07AL1 6990' Page 6 of 7 January 11, 2016 • • PTD Application: 1H-07A & AL1 — Distance to Nearest Well within Pool -A- Name Distance Well 1H-07A 1H-14 1080' 1 H-07AL1 1H-14 730' 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 1H-14 & 1H-16 are within '/4-mile of the 1H-07A & L1 wells • See Attached AOR sheet 17. Attachments Attachment 1: Directional Plans for 1H-07A &AL1 Attachment 2: Current Well Schematic for 1H-07 Attachment 3: Proposed Well Schematic for 1H-07A &AL1 Page7of7 January 11, 2016 • 0 Area of Review Well Name Top of A-sand Top of A-Sand Oil Top of Cement Tap of Cement Top of Cement PTD API WELL NAME STATUS Oil Pool(MD) Pool(TVD55( (MD) (NDSS) Determined By Reservoir Status Zonal Isolation Cement Operations Summary Mechanical Integrity Pert,cemented and State witnessed passing MIT- 182-084 50.0129-20755 10-07 Suspended 7696' 6441' 6850' 5656' CBL abandoned Packer @]880'MD 9625x5 Class G cement IA to 2820 psi on 8/11/13 192-131 50-029-22315 10-16 Producing 7185' 6632' 6300' 5798' CET Perfs open for Packer @6804'MD 590 sxs Class G cement SI-TIFL Passed.Initial T/I/0= production si 160/1250/780 on 5/30/15 193-052 50-029-22359 1H-14 Producing 8691' 6554' 8330' 6412' CET Pert,open for Packer @0172'MO 520 sxs Clans ci cement Competent producer with production passing TIN. ei II" KUP INJ • 1H-07 CQt1QCQf (tlIlIS0 Well Attributes Max Angle&MD TD ' ; n'(Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Czyyackip u 500292075500 KUPARUK RIVER UNIT INJ 53.77 5,200.00 8,300.0 ftivps ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1H-07,11111/2013647:34 PM SSSV:NIPPLE Last WO. 11/11/2007 35.49 6/16/1982 Vertical schemalc(ecWell Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag SLM 8,079.0 11/3/2013 Rev Reason:GLV C/O,TAG,RESET BPC lehallf 11/11/2013 HANGER;24.9 VI f7 Casing Strings rl Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD).., Wt/Len(I...Grade Top Thread ,1 CONDUCTOR 16 15.060 30.0 80.0 80.0 65.00 H-40 WELDED I _ a,, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 29.0 8,274.0 6,936.9 26.00 K-55 BTC -^.^n CONDUCTOR;30.0-000- I^-+^Tubing Strings Tubing Description String Ma...ID(in) Top(MB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection NIPPLE,503.4tax TUBING 2007 W0 I 31/21 2.9921 24.91 7,662.0 6413.21 9.301 L-80 (EUE 8RD f Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 24.9 24.9 0.15 HANGER CAMERON GEN 4 TUBING HANGER 3.500 i 503.4 503.3 0.49 NIPPLE CAMCO DS NIPPLE 2.875 7,620.0 6,377.7 32.41 NIPPLE CAMCO DS NIPPLE 2.813 SURFACE;29.0-2,365.0----e111 7,658 4- 6,410.1 32.37 SEAL ASSY LOCATOR SEAL ASSEMBLY 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection GAS LIFT;7,572.0ig TUBING 1994 WO I 41/2 2.992 7,661.6 7,910.71 6,624.2 9.30 L-80 EUEBRDMCD I 3.5x2.875 l Completion Details Nominal ID Top(RKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE,7,620.0 7,661.6 6,412.8 3236 PBR BAKER 80-40 PBR w/10'STROKE 3.000 7,675.4 6,424.5 32.35 PACKER BAKER'FHL'RETRIEVABLE PACKER 2.992 7,702.9 6,447.8 32.31 BLAST JTS STEEL BLAST JOINTS 2.992 7,781.3 6,514.0 32.03 NIPPLE AVA BPL PORTED NIPPLE 2.812 SEAL ASSY;7,658.4 _ 7,788.1 6,519.8 32.01 SEAL ASSY BAKER KBG-22 ANCHOR SEAL ASSY 3.000 ` a i 7,789.0 6,520.6 32.01 PACKER BAKER 80-40'SAB-3'PERMANENT PACKER 3.250 PBR;7,661.6 ` 7,815.0 6,5427 31.89 BLAST JTS STEEL BLAST JOINTS 2992 PACKER;7,675.4 7,874.2 6,593.0 31.61 NIPPLE AVA BPL PORTED NIPPLE 2.750 7,876.9 6,595.3 31.60 XO Reducing CROSSOVER 3.5 x 2.875,ID 2.441,66.5,L-80, 2.875 EBRDMOD INJECTION;7,008.7 Ti 7,879.1 6,597.2 31.58 SEAL ASSY BAKER 80-32 GBH-22 LOCATOR SEAL ASSEMBLY 2.437 -I 7,880.1 6,598.1 31.58 PACKER BAKER 84-32 MODEL'D'PERMANENT PACKER 3.250 7,883.8 6,601.2 31.56 SBE SEAL BORE EXTENSION 3.250 IPERF;7,696.0-7,7550 I it- I 7,898.9 6,614.1 31.49 NIPPLE OTIS'XN'NIPPLE 2.250 7,9102 6,623.7 31.43 WLEG BAKER WIRELINE ENTRY GUIDE 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SLEEVE;7,781.3 Top(ND) Top Incl To NIPPLE;7,781.3 - p(ftKB) (ftKB) (°) Des Corn Run Date ID(in) P!' ' 7,781.3 6,514.0 32.03 SLEEVE SET 2.81"BPC-COMMINGLING OR OPEN 11/3/2013 2.310 7,8742 6,593.0 31.61 SLEEVE SET 2.75"BPI=ISOLATION OR CLOSED 5/6/2009 2.310 SEAL ASSY;7,788.1 8,162.0 6,839.7 29.83 FISH Vann Gun Left in Hole after original pert 6/16/1982 PACKER;7,789.0 'err. Perforations&Slots Shot Dens 3 - . ' Top(ND) Btm(TVD) (shots/f INJECTION;7,800.7 (, Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com i 7,696.0 7,755.0 6,441.9 6,491.8 C-4,C-3,1H- 6/20/1988 8.0 IPERF 2 1/8"EnerJet;30 deg 07 ph II 7,805.0 7,830.0 6,534.2 6,555.4 C-1,UNIT B, 6/20/1988 4.0 IPERF 21/8"EnerJet 1 _ IPERF;7,805.0-7,830.0 I nom. I 1H-07 8,015.0 8,023.0 6,713.4 6,720.2 A-5,1H-07 2/16/2007 6.0 RPERF 2 1/8"EnerJet,0 deg phase 8,015.0 8,023.0 6,713.4 6,720.2 A-5,1H-07 6/20/1988 12.0 IPERF 2 1/8"EnerJet SLEEVE;7,874.2 ._.. NIPPLE,7,874.21 _.i.�€;" 8,031.0 8,051.0 6,727.1 6,744.2 A-4,1H-07 2/16/2007 6.0 RPERF 21/8"EnerJet,Odeg IAB phase 8,031.0 8,051.0 6,727.1 6,744.2 A-4,1H-07 6/20/1988 12.0 IPERF 21/8"EnerJet 11 Mandrel Inserts SEAL ASSY;7,879.1 - St ati C PACKER;7,880.1 en Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) See, Type Type (in) (psi) Run Date m AIR SBE,7,883.8 CIP 1 7,572.0 6,337.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/15/2007 Iill 2 7,688.7 6,435.7 CAMCO MMM 11/2 INJ DMY RK 0.000 0.0 5/25/1994 3 7,800.7 6,530.5 CAMCO MMM 11/2 INJ CV RK 0.188 0.0 11/3/2013 miffs NIPPLE;7,898.9 NsNotes:General&Safety IEnd Date Annotation 5/24/1994 NOTE WORKOVER WLEG;7,910.1 I 2/17/2004 NOTE:WAIVERED WELL:T x IA COMMUNICATION 3/2/2011 NOTE:View Schematic w/Alaska Schematic9.0 RPERF;8,015.0-8,023.0 IPERF;8,010-8,023.01 5 3/27/2012 NOTE:The 2007 tubing detail did not include the RKB;adjusted for RKB,but need verifying IPERF,8,031.0-8,051.0 RPERF;8,031.0-8,051.0 Alit 1 ) FISH;8,16201.5 PRODUCTION;29.0-8,274.0 • 0 nfAIII rue Num WELLBORE DETAILS:IH-07A REFERENCE FFORM8TION �. Project:Kuparuk River Unit Magnem cum,.+aar Site:Kuparuk IH Pod Naannm Feld Parent Wellbore'1H-07 CoadnaI FOOl Rekrerrce:wellltill7True NMh BAKER Well:1H-07 strenptn.5]aat&nrVertical(ND)Reference'.Mean See Level aea�le.e+.ar Tie on MD:7800.00 Satoh S Reference Slot-000N,000E Wellbore:tH-07A N) ( I ConocoPhI lips PIen:1H-07A_wpO5(IH-07/1H-07A) ModeCate lBeGIAxis Measured DEO Reference 1H0I @ O50efl(13-07) HUGHES Calculation Method.Mnimunt Curvature 575011■1 is `f ■ I. -2a I■■ ■IrI1 ■ ' ----- ■■ ■■ 1 -115:14{�5 5500 1111 ,i 1. ,.�I KM P!!iiI11iiIilII11i_ -_, , 1 4,,d - --- -- 4500 ++ -* 1111111 I, 1/_ ■■■•-R. Y 1I,.45:III l 5 400D liii _ _ ■■ I II ■ ■ __ A I i^ 3750 ■ ■ (.,.i i L. .. --- ./ ■/� II I 35170 -_-'---'I �■ it ���i i k ,® ■, d _.__.__- C 3250 __r__■,� ■�.i 1■1/M IMil r .r■■I :, ■ -_ , -.3000 ■, Mil ■ Ir. ■ , ■ !� �i--_.■ ■ ■ _ in NJ1750 _ - , ILVI__!PPPIIIP!F -250a — -`I 1, 3111� � � .� s.2000 , ► I ) ��� I 14..1,+I3-03 1750 L�� ... -- 1500 iIjI, $ili!JIpuII1 0II -._� - im 0 — —0a.-- PI , ,,„ ... 500 E IliIt 3vf.5F}0 --- I -- 250 • - k.{1 _ �:m. I Ell - }�IfD r l - 1.1-254 WA.a ----- - \`�" - m,,,, , - , , , r,NR„--.,-leauglimurilimis , , MO H-nM1 IAA �e� 134IS e t I t nn of nl-{,u . w �,v3- i°--' EMMEN 11111111111111111 -3000-2750-2500-2250-2000-1750-1500-1250-1000-750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 West(-)/East(+)(250 usft/in) • I ConocoPhillips NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H-07 1H-07A Plan: 1 H-07A_wp05 Standard Planning Report 07 January, 2016 'flu BAKER HUGHES 4111 • ConocoPhillips nii1111 ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 1 H-07 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-07 @ 85.00usft(1 H-07) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-07 Survey Calculation Method: Minimum Curvature Wellbore: 1H-07A Design: 1 H-07A_wp05 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1H Pad Site Position: Northing: 5,979,968.84 usft Latitude: 70°21'21.831 N From: Map Easting: 549,197.16usft Longitude: 149°36'1.675 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.38 ° Well 1 H-07 Well Position +N/-S 0.00 usft Northing: 5,979,935.13 usft Latitude: 70°21'21.476 N +E/-W 0.00 usft Easting: 549,560.55 usft Longitude: 149°35'51.058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1H-07A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 4/1/2016 18.60 81.00 57,498 Design 1H-07A wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,800.00 Vertical Section: Depth From(TVD) r• +N/-5 +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 200.00 1/7/2016 11:44:43AM Page 2 COMPASS 5000.1 Build 74 0 40 rip-- ConocoPhillips Witt ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 1 H-07 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-07 @ 85.00usft(1 H-07) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-07 Survey Calculation Method: Minimum Curvature Wellbore: 1H-07A Design: 1 H-07A_wp05 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) Target 7,800.00 31.97 55.69 6,444.91 2,999.74 1,862.27 0.00 0.00 0.00 0.00 7,842.00 31.76 55.94 6,480.58 3,012.20 1,880.61 0.59 -0.50 0.60 147.96 7,867.00 39.55 49.08 6,500.89 3,021.11 1,892.10 35.00 31.18 -27.44 330.00 7,937.00 65.05 34.08 6,543.49 3,062.83 1,927.42 40.00 36.42 -21.44 330.00 8,007.00 74.79 6.05 6,567.92 3,123.92 1,949.19 40.00 13.92 -40.04 285.00 8,347.07 90.00 227.81 6,661.00 3,226.12 1,722.36 40.00 4.47 -40.65 -106.37 8,387.07 90.00 224.61 6,661.00 3,198.45 1,693.49 8.00 0.00 -8.00 270.00 8,460.00 91.00 221.87 6,660.37 3,145.32 1,643.53 4.00 1.37 -3.76 290.00 8,550.00 94.54 222.50 6,656.02 3,078.72 1,583.18 4.00 3.94 0.70 10.00 8,690.00 89.95 225.70 6,650.53 2,978.30 1,485.86 4.00 -3.28 2.29 145.00 8,890.00 89.81 233.70 6,650.94 2,849.06 1,333.45 4.00 -0.07 4.00 91.00 9,175.00 89.82 222.30 6,651.87 2,658.68 1,121.99 4.00 0.00 -4.00 270.00 9,425.00 90.69 212.34 6,650.78 2,460.12 970.61 4.00 0.35 -3.98 275.00 9,750.00 90.67 199.34 6,646.92 2,168.27 829.27 4.00 -0.01 -4.00 270.00 9,950.00 104.45 196.85 6,620.67 1,980.30 767.78 7.00 6.89 -1.24 350.00 10,150.00 94.39 186.97 6,587.91 1,787.70 727.40 7.00 -5.03 -4.94 225.00 10,425.00 91.19 205.98 6,574.41 1,525.57 649.79 7.00 -1.16 6.91 99.00 10,600.00 89.47 193.85 6,573.39 1,361.35 590.29 7.00 -0.98 -6.93 262.00 10,850.00 88.89 211.34 6,576.98 1,131.46 494.61 7.00 -0.23 7.00 92.00 11,100.00 88.65 193.84 6,582.39 901.60 398.96 7.00 -0.10 -7.00 269.00 1/7/2016 11:44:43AM Page 3 COMPASS 5000.1 Build 74 • Conoc • oPhillips Fail ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 1 H-07 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-07©85.00usft(1 H-07) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-07 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-07A Design: 1 H-07A_wp05 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (0) (usft) (usft) 7,800.00 31.97 55.69 6,444.91 2,999.74 1,862.27 -3,455.77 0.00 0.00 5,982,946.83 551,402.75 TIP 7,842.00 31.76 55.94 6,480.58 3,012.20 1,880.61 -3,473.75 0.59 147.96 5,982,959.41 551,421.01 KOP 7,867.00 39.55 49.08 6,500.89 3,021.11 1,892.10 -3,486.05 35.00 -30.00 5,982,968.40 551,432.44 End 35 dls,Start 40 dls 7,900.00 51.34 40.67 6,524.02 3,037.84 1,908.51 -3,507.39 40.00 -30.00 5,982,985.24 551,448.73 7,937.00 65.05 34.08 6,543.49 3,062.83 1,927.42 -3,537.34 40.00 -24.06 5,983,010.35 551,467.48 4 8,000.00 73.63 8.69 6,566.02 3,117.24 1,948.33 -3,595.62 40.00 -75.00 5,983,064.89 551,488.03 8,007.00 74.79 6.05 6,567.92 3,123.92 1,949.19 -3,602.19 40.00 -65.89 5,983,071.58 551,488.85 5 8,100.00 68.08 327.34 6,598.57 3,207.83 1,929.96 -3,674.46 40.00 -106.37 5,983,155.35 551,469.06 8,200.00 71.14 284.65 6,634.89 3,261.03 1,856.13 -3,699.20 40.00 -93.59 5,983,208.05 551,394.88 8,300.00 83.00 245.33 6,658.10 3,251.91 1,761.37 -3,658.22 40.00 -78.07 5,983,198.30 551,300.20 8,347.07 90.00 227.81 6,661.00 3,226.12 1,722.36 -3,620.64 40.00 -68.88 5,983,172.26 551,261.36 End 40 dls,Start RSM 8,387.07 90.00 224.61 6,661.00 3,198.45 1,693.49 -3,584.76 8.00 -90.00 5,983,144.40 551,232.68 7 8,400.00 90.18 224.12 6,660.98 3,189.20 1,684.44 -3,572.98 4.00 -70.00 5,983,135.10 551,223.70 8,460.00 91.00 221.87 6,660.37 3,145.32 1,643.53 -3,517.76 4.00 -70.00 5,983,090.95 551,183.08 8 8,500.00 92.57 222.15 6,659.12 3,115.62 1,616.78 -3,480.69 4.00 10.00 5,983,061.07 551,156.52 8,550.00 94.54 222.50 6,656.02 3,078.72 1,583.18 -3,434.53 4.00 10.01 5,983,023.96 551,123.17 9 8,600.00 92.90 223.64 6,652.77 3,042.27 1,549.11 -3,388.63 4.00 145.00 5,982,987.29 551,089.35 8,690.00 89.95 225.70 6,650.53 2,978.30 1,485.86 -3,306.88 4.00 145.07 5,982,922.91 551,026.53 10 8,700.00 89.94 226.10 6,650.54 2,971.34 1,478.68 -3,297.89 4.00 91.00 5,982,915.90 551,019.40 8,800.00 89.87 230.10 6,650.70 2,904.58 1,404.26 -3,209.70 4.00 91.00 5,982,848.65 550,945.43 8,890.00 89.81 233.70 6,650.94 2,849.06 1,333.45 -3,133.30 4.00 90.99 5,982,792.67 550,874.99 11 8,900.00 89.81 233.30 6,650.98 2,843.11 1,325.41 -3,124.97 4.00 -90.00 5,982,786.67 550,866.99 9,000.00 89.81 229.30 6,651.30 2,780.60 1,247.38 -3,039.54 4.00 -90.00 5,982,723.65 550,789.38 9,100.00 89.81 225.30 6,651.63 2,712.80 1,173.90 -2,950.70 4.00 -89.99 5,982,655.38 550,716.36 9,175.00 89.82 222.30 6,651.87 2,658.68 1,121.99 -2,882.09 4.00 -89.97 5,982,600.92 550,664.82 12 9,200.00 89.90 221.31 6,651.93 2,640.05 1,105.33 -2,858.88 4.00 -85.00 5,982,582.17 550,648.28 9,300.00 90.25 217.32 6,651.80 2,562.69 1,041.98 -2,764.52 4.00 -85.00 5,982,504.41 550,585.46 9,400.00 90.60 213.34 6,651.06 2,481.13 984.17 -2,668.10 4.00 -85.00 5,982,422.47 550,528.19 9,425.00 90.69 212.34 6,650.78 2,460.12 970.61 -2,643.73 4.00 -85.03 5,982,401.38 550,514.77 13 9,500.00 90.68 209.34 6,649.88 2,395.74 932.17 -2,570.08 4.00 -90.00 5,982,336.75 550,476.76 9,600.00 90.68 205.34 6,648.69 2,306.94 886.26 -2,470.93 4.00 -90.04 5,982,247.65 550,431.44 9,700.00 90.67 201.34 6,647.51 2,215.14 846.65 -2,371.13 4.00 -90.08 5,982,155.61 550,392.45 9,750.00 90.67 199.34 6,646.92 2,168.27 829.27 -2,321.13 4.00 -90.13 5,982,108.62 550,375.38 End RSM,Start 7 dls 9,800.00 94.11 198.73 6,644.84 2,121.05 812.98 -2,271.19 7.00 -10.00 5,982,061.30 550,359.40 9,900.00 101.01 197.49 6,631.69 2,026.89 782.18 -2,172.18 7.00 -10.03 5,981,966.95 550,329.23 9,950.00 104.45 196.85 6,620.67 1,980.30 767.78 -2,123.47 7.00 -10.19 5,981,920.28 550,315.14 15 10,000.00 101.96 194.32 6,609.25 1,933.42 754.71 -2,074.95 7.00 -135.00 5,981,873.31 550,302.38 1/7/2016 11:44:43AM Page 4 COMPASS 5000.1 Build 74 • • ConocoPhillips MN Conoco:Phillips Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 1 H-07 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-07 @ 85.00usft(1 H-07) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-07 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-07A Design: 1 H-07A_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (o) (a) (usft) (usft) (usft) (usft) 0100usft) (°) (usft) (usft) 10,100.00 96.93 189.39 6,592.83 1,836.94 734.48 -1,977.36 7.00 -135.58 5,981,776.71 550,282.79 10,150.00 94.39 186.97 6,587.91 1,787.70 727.40 -1,928.67 7.00 -136.39 5,981,727.42 550,276.03 16 10,200.00 93.83 190.44 6,584.32 1,738.41 719.85 -1,879.77 7.00 99.00 5,981,678.09 550,268.81 10,300.00 92.68 197.35 6,578.64 1,641.55 695.88 -1,780.56 7.00 99.25 5,981,581.09 550,245.49 10,400.00 91.49 204.26 6,574.99 1,548.19 660.40 -1,680.70 7.00 99.64 5,981,487.51 550,210.63 10,425.00 91.19 205.98 6,574.41 1,525.57 649.79 -1,655.81 7.00 99.89 5,981,464.81 550,200.18 17 10,500.00 90.46 200.78 6,573.33 1,456.76 620.04 -1,580.97 7.00 -98.00 5,981,395.81 550,170.88 10,600.00 89.47 193.85 6,573.39 1,361.35 590.29 -1,481.14 7.00 -98.07 5,981,300.22 550,141.77 18 10,700.00 89.23 200.85 6,574.52 1,265.97 560.49 -1,381.32 7.00 92.00 5,981,204.65 550,112.60 10,800.00 89.00 207.85 6,576.07 1,174.93 519.30 -1,281.68 7.00 91.92 5,981,113.35 550,072.01 10,850.00 88.89 211.34 6,576.98 1,131.46 494.61 -1,232.39 7.00 91.81 5,981,069.73 550,047.62 19 10,900.00 88.84 207.84 6,577.97 1,088.00 469.93 -1,183.11 7.00 -91.00 5,981,026.11 550,023.22 11,000.00 88.73 200.84 6,580.10 996.97 428.74 -1,083.48 7.00 -90.93 5,980,934.82 549,982.64 11,100.00 88.65 193.84 6,582.39 901.60 398.96 -983.68 7.00 -90.78 5,980,839.26 549,953.49 Planned TD at 11100.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (••) (••) 11,100.00 6,582.39 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EI-W (usft) (usft) (usft) (usft) Comment 7,800.00 6,444.91 2,999.74 1,862.27 TIP 7,842,00 6,480.58 3,012.20 1,880.61 KOP 7,867.00 6,500.89 3,021.11 1,892.10 End 35 dls,Start 40 dls 7,937.00 6,543.49 3,062.83 1,927.42 4 8,007.00 6,567.92 3,123.92 1,949.19 5 8,347.07 6,661.00 3,226.12 1,722.36 End 40 dls,Start RSM 8,387.07 6,661.00 3,198.45 1,693.49 7 8,460.00 6,660.37 3,145.32 1,643.53 8 8,550.00 6,656.02 3,078.72 1,583.18 9 8,690.00 6,650.53 2,978.30 1,485.86 10 8,890.00 6,650.94 2,849.06 1,333.45 11 9,175.00 6,651.87 2,658.68 1,121.99 12 9,425.00 6,650.78 2,460.12 970.61 13 9,750.00 6,646.92 2,168.27 829.27 End RSM,Start 7 dls 9,950.00 6,620.67 1,980.30 767.78 15 10,150.00 6,587.91 1,787.70 727.40 16 10,425.00 6,574.41 1,525.57 649.79 17 10,600.00 6,573.39 1,361.35 590.29 18 10,850.00 6,576.98 1,131,46 494.61 19 11,100.00 6,582.39 901.60 398.96 Planned TD at 11100.00 1/7/2016 11:44:43AM Page 5 COMPASS 5000 1 Budd 74 • • `,,- Baker Hughes INTEQ Plitt ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1 H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft(1 H-07) Reference Site: Kuparuk 1H Pad MD Reference: 1H-07 @ 85.00usft(11-1-07) Site Error. 0.00 usft North Reference: True Reference Well: 1H-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma 1. Reference Wellbore 1 H-07A Database: OAKEDMP2 Reference Design: 1 H-07A_wp05 Offset TVD Reference: Offset Datum j Reference 1 H-07A_wp05 1. Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,800.00 to 11,100.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,301.50 usft Error Surface: Elliptical Conic Survey Tool Program Date 117/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 7,800.00 1 H-07(1 H-07) BOSS-GYRO Sperry-Sun BOSS gyro multishot 7,800.00 11,100.00 1 H-07A_wp05(1H-07A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (') (") 11,100.00 6,667.39 23/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 1H Pad 1H-05-1H-05-1H-05 Out of range 1 H-05-1H-105-1H-105 Out of range 1H-07-1H-07-1H-07 7,849.99 7,850.00 0.20 2.08 -1.60 FAIL-Major Risk 1 H-07-1 H-07AL1-1 H-07AL1_wp04 8,274.73 8,275.00 2.37 0.46 2.02 Pass-Minor 1/10 1H-10-1H-10-1H-10 Out of range 1H-12-1 H-12-1H-12 Out of range 1H-13-1H-13-1H-13 Out of range 1 H-14-1 H-14-1H-14 8,370.87 7,925.00 1,088.83 264.13 843.98 Pass-Major Risk 1H-15-1H-15-1H-15 Out of range 1 H-16-1H-16-1 H-16 10,050.00 7,150.00 1,130.82 259.81 874.93 Pass-Major Risk 1 H-21-1 H-21-1H-21 Out of range Plan:1H-104(formerly 101 and 27)-Plan:1H-104 Out of range Plan:1H-104(formerly 101 and 27)-PIan:1 H-104 Out of range Plan:1H-104(formerly 101 and 27)-Plan:1 H-104 Out of range Plan:1H-104(formerly 101 and 27)-Plan:1 H-104 Out of range Plan:1H-104(formerly 101 and 27)-PIan:1 H-104 Out of range Plan:1H-112(formerly 106 and 28E)-Plan:1H-11 Out of range Offset Design Kuparuk 1H Pad- 1 H-07-1 H-07-1H-07 Offset Site Error: 0.00 usft Survey Program: 100-8OSS-GYRO Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go AllowableWarning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (use) (usft) (usft) (usft) (usft) (usft) 0 (usft) (usft) (") (usft) (usft) (usft) 7,825.00 6,551.13 7,825.00 6,551.13 0.08 0.15 85.54 3,007.17 1,873.19 2-11/16 0.00 1.08 -0.86 FAIL-Major Risk,CC 7,849.99 6,572.29 7,850.00 6,572.38 0.13 0.31 -155.07 3,014.55 1,884.10 2-11/16 0.20 2.08 -1.60 FAIL-Major Risk.ES,SF 7,874.53 6,591.58 7,875.00 6,593.66 0.13 0.46 -156.33 3,021.88 1,894.99 2-11/16 3.37 3.60 0.01 Pass-Major Risk 7,897.41 6,607.39 7,900.00 6,614.97 0.14 0.62 -159.51 3,029.15 1,905.86 2-11/16 10.53 5.15 5.63 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor.ES-min ellipse separation 1/7/2016 10:47:47AM Page 2 COMPASS 5000.1 Build 74 • • WELLBORE DETAILS:1H-07A REFERENCE INFORMATION i Project:Kuparuk River Unit Maweno o r e eo^ .Il.. Site:IH-07Kuparuk iH Pad C04.1111810elNlE)Refoeocn Well)HL I.neI Nvin Well:1H-07 neer Parent Wellbore:78-0. Vertical(TVD)Reference:Mean See lanl `' e°nem°Msi Magnetic Tie on MD:7800.00 BAKER Wellbore:101-07A �° Section(VS)Reference:Sbl-(00014 o 00E) ConocoPhillips PIan:1H-07A_wp05E1H-07/1H-07A) M°aeDete laaa8p,e Measured°�°"�er��'"°'��° """°� HUGHES Caoulefion Met.-Minmun Curvature WELL DETAILS: 1H-07 4800 411-S +E1-W Northing Easting Latitude Longitude 4500 0.00 0.00 5979935.13 549560.55 70°21'21.476 N 149°35 51.058 W 4200 Sec MD Inc Azi TVDSS 41,-S -EI-W Dleg TFace VSect Annotation 13-07/14-07.41.1 1 7800.00 31.97 55.69 6444.91 2999.74 1862.27 0.00 0.00-3455.77 TIP 3900' IH-074 T03 2 7842.00 31.76 55.94 6480.58 3012.20 1880.61 0.59 147.96-3473.75 KOP • 10-07A-T.2 3 7867.00 39.55 49.08 6500.89 3021.11 1892.10 35.00 330.00-3486.05 End 35 dls,Start 40 dls 3600 1'01-07p T01 4 7937.00 65.05 34.08 6543.49 3062.83 1927.42 40.00 330.00-3537.34 4 Fad40aa,Stert° 5 8007.00 74.79 6.05 6567.92 3123.92 1949.19 40.00 285.00-3602.19 5 ,-.3300 6 8347.07 90.00 227.81 6661.00 3226.12 1722.36 40.00 -106.37-3620.64 End 40 dls,Start RSM a lx-07A roe-- ---- �:':-S 111 07/1F-07 7 8387.07 90.00 224.61 6661.00 3198.45 1693.49 8.00 270.00-3584.76 73000 1w7A 0s---- 8 846000 91.00 221.87 6660.37 3145.32 1643.53 4.00 290.00-3517.76 8 9 8550.00 94.54 222.50 6656.02 3078.72 1583.18 4.00 10.00-3434.53 9 0 2700 m-u A_1utr----- TIF i!OF1pd 35 d1a.``cart40 dla 10 8690.00 89.95 225.70 6650.53 2978.30 1485.86 4.00 145.00-3306.88 10 11 8890.00 89.81 233.70 6650.94 2849.06 1333.45 4.00 91.00-3133.30 11 ..--1-'2400 1H-07A Faultl 12 9175.00 89.82 222.30 6651.87 2658.68 1121.99 4.00 270.00-2882.09 12 13 9425.00 90.69 212.34 6650.78 2460.12 970.61 4.00 275.00-2643.73 13 2100 IH-0'A TO'---- 14 9750.00 90.67 199.34 6646.92 2168.27 829.27 4.00 270.00-2321.13 End RSM,Start 7 dls 1-1-07A_To8- 1 E u1 RSM,Start 7 dls 15 9950.00 104.45 196.85 6620.67 1980.30 767.78 7.00 350.00-2123.47 15 ,x800 Hl-07A_T07-- 16 10150.00 94.39 186.97 6587.91 1787.70 727.40 7.00 225.00-1928.67 16 7 17 10425.00 91.19 205.98 6574.41 1525.57 649.79 7.00 99.00-1655.81 17 c,91500 1H-07A_110---- 18 10600.00 89.47 193.85 6573.39 1361.35 590.29 7.00 262.00-1481.14 18 19 10850.00 88.89 211.34 6576.98 1131.46 494.61 7.00 92.00-1232.39 19 1200 20 11100.00 88.65 193.84 6582.39 901.60 398.96 7.00 269.00 -983.68 Planned TD at 11100.00 900 IH-07A TIIPlaaaed.T11_at 1110000 -....._..-1H-07/101-07A 600 /300.-, -1500-1200 -900 -600 -300 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 6080- West(-)/East(+)(300 usft/in) 6175- 6270 E O °I m "• ~f y� H ` 0 Q Q w 6365- 9 x of S a 7 S x 5 _ _ • V1 6460 • a 5 xOE. t 6555 435d1&-Sfa-4(4.• I• F H-071 11-07.M.1 , Q 6650-" I . • ', ',, ',, If 17 18 19 Plaoaed'4D at 11100.00 .!'d Erd 40 31s,Start RSM I S 101-07/101-074 6745 / 3 9 10 11 'i2 13 Start 7 dl; a) 7 6840 N 5 IF-07/1F-07 E= 6935 7030' 1H 07ti Fauit1 7125 Mean Sea L...4 - - -3990-3895-3800-3705-3610-3515-3420-3325-3230-3135-3040-2945-2850-2755-2660-2565-2470-2375-2280-2185-2090-1995-1900-1805-1710-1615-1520-1425-1330-1235-1140-1045 -950 -855 -760 -665 -570 -475 -380 Vertical Section at 200.00°(95 usft/in) • • • o s NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H-07 1 H-07AL1 Plan: 1 H-07AL1_wp04 Standard Planning Report 07 January, 2016 rI BAKER HUGHES • • ConocoPhillips V/.al. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 1 H-07 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-07 @ 85.00usft(1 H-07) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-07 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-07AL1 Design: 1 H-07AL1_wp04 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1H Pad - a .. �, Site Position: Northing: 5,979,968.84 usft Latitude: 70°21'21.831 N From: Map Easting: 549,197.16usft Longitude: 149°36'1.675 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.38 ° Well 1H-07 Well Position +N/-S 0.00 usft Northing: 5,979,935.13 usft Latitude: 70°21'21.476 N +E/-W 0.00 usft Easting: 549,560.55 usft Longitude: 149°35'51.058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 H-07AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 4/1/2016 18.60 81.00 57,498 Design 1H-07AL1_wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,254.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 350.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) (°) Target 8,254.00 76.78 262.94 6,649.97 3,264.30 1,804.71 0.00 0.00 0.00 0.00 8,324.00 101.18 276.78 6,651.21 3,264.16 1,735.42 40.00 34.86 19.78 30.00 8,394.00 86.62 300.82 6,646.39 3,286.56 1,670.01 40.00 -20.81 34.33 120.00 8,530.00 88.03 355.26 6,653.26 3,397.53 1,600.82 40.00 1.04 40.03 90.00 8,630.00 89.85 2.02 6,655.11 3,497.42 1,598.46 7.00 1.82 6.76 75.00 8,730.00 94.35 7.40 6,651.45 3,596.95 1,606.65 7.00 4.49 5.37 50.00 8,830.00 90.83 13.46 6,646.93 3,695.14 1,624.73 7.00 -3.52 6.06 120.00 8,900.00 88.38 9.21 6,647.42 3,763.75 1,638.48 7.00 -3.50 -6.06 240.00 9,075.00 88.41 356.96 6,652.33 3,938.10 1,647.87 7.00 0.02 -7.00 270.00 9,250.00 87.39 344.74 6,658.76 4,110.43 1,620.12 7.00 -0.59 -6.98 265.00 1/7/2016 11:39:00AM Page 2 COMPASS 5000.1 Build 74 • 0 ConocoPhillips FGLl ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 1 H-07 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-07 @ 85.00usft(1 H-07) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-07 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-07AL1 Design: 1 H-07AL1_wp04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (e) (e) (usft) (usft) (usft) (usft) (e/100usft) (e) (usft) (usft) 8,254.00 76.78 262.94 6,649.97 3,264.30 1,804.71 2,901.32 0.00 0.00 5,983,210.98 551,343.45 TIP/KOP 8,300.00 92.82 272.03 6,654.13 3,262.34 1,759.14 2,907.31 40.00 30.00 5,983,208.72 551,297.90 8,324.00 101.18 276.78 6,651.21 3,264.16 1,735.42 2,913.22 40.00 29.17 5,983,210.38 551,274.17 Start 40 dls 8,394.00 86.62 300.82 6,646.39 3,286.56 1,670.01 2,946.64 40.00 120.00 5,983,232.35 551,208.62 3 8,400.00 86.62 303.22 6,646.74 3,289.74 1,664.93 2,950.65 40.00 90.00 5,983,235.49 551,203.52 8,500.00 87.50 343.27 6,652.09 3,368.13 1,606.40 3,038.01 40.00 89.86 5,983,313.48 551,144.47 8,530.00 88.03 355.26 6,653.26 3,397.53 1,600.82 3,067.93 40.00 87.72 5,983,342.84 551,138.71 End 40 dls,Start 7 dls 8,600.00 89.30 360.00 6,654.89 3,467.43 1,597.93 3,137.27 7.00 75.00 5,983,412.71 551,135.35 8,630.00 89.85 2.02 6,655.11 3,497.42 1,598.46 3,166.72 7.00 74.89 5,983,442.71 551,135.68 5 8,700.00 93.00 5.78 6,653.37 3,567.21 1,603.22 3,234.62 7.00 50.00 5,983,512.53 551,139.98 8,730.00 94.35 7.40 6,651.45 3,596.95 1,606.65 3,263.32 7.00 50.09 5,983,542.28 551,143.22 6 8,800.00 91.89 11.64 6,647.64 3,665.87 1,618.21 3,329.17 7.00 120.00 5,983,611.26 551,154.32 8,830.00 90.83 13.46 6,646.93 3,695.14 1,624.73 3,356.87 7.00 120.23 5,983,640.58 551,160.64 7 8,900.00 88.38 9.21 6,647.42 3,763.75 1,638.48 3,422.05 7.00 -120.00 5,983,709.27 551,173.94 8 9,000.00 88.39 2.21 6,650.24 3,863.15 1,648.42 3,518.22 7.00 -90.00 5,983,808.73 551,183.22 9,075.00 88.41 356.96 6,652.33 3,938.10 1,647.87 3,592.12 7.00 -89.80 5,983,883.66 551,182.17 9 9,100.00 88.26 355.21 6,653.06 3,963.03 1,646.17 3,616.97 7.00 -95.00 5,983,908.58 551,180.30 9,200.00 87.67 348.23 6,656.61 4,061.86 1,631.79 3,716.80 7.00 -94.95 5,984,007.30 551,165.27 9,250.00 87.39 344.74 6,658.76 4,110.43 1,620.12 3,766.65 7.00 -94.70 5,984,055.78 551,153.28 Planned TD at 9250.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 11,100.00 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,254.00 6,649.97 3,264.30 1,804.71 TIP/KOP 8,324.00 6,651.21 3,264.16 1,735.42 Start 40 dls 8,394.00 6,646.39 3,286.56 1,670.01 3 8,530.00 6,653.26 3,397.53 1,600.82 End 40 dls,Start 7 dls 8,630.00 6,655.11 3,497.42 1,598.46 5 8,730.00 6,651.45 3,596.95 1,606.65 6 8,830.00 6,646.93 3,695.14 1,624.73 7 8,900.00 6,647.42 3,763.75 1,638.48 8 9,075.00 6,652.33 3,938.10 1,647.87 9 9,250.00 6,658.76 4,110.43 1,620.12 Planned TD at 9250.00 1/7/2016 11:39:00AM Page 3 COMPASS 5000.1 Build 74 • • Baker Hughes INTEQ arm ConocoPhillips Travelling Cylinder Report BAKER ES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1 H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85 00usft(1 H-07) Reference Site: Kuparuk 1H Pad MD Reference: 1H-07 @ 85.00usft(11-1-07) Site Error: 0.00 usft North Reference: True Reference Well: 1 H-07 Survey Calculation Method: Minimum Curvature Well Error 0.00 usft Output errors are at 1.00 sigma Reference Weilbore 1H-07AL1 Database: OAKEDMP2 Reference Design: 1 H-07AL1_wp04 Offset TVD Reference: Offset Datum Reference 1H-Q7AL1_wp04 Filter type: GLOBAL FILTER APPLIED:All welipaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,254.00 to 9,250.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,116.50 usft Error Surface: Elliptical Conic Survey Tool Program Date 1/7/2016 From To (usft) (usft) Survey(Wellbore] Tool Name Description 100.00 7,800.00 1H-07(1H-07) BOSS-GYRO Sperry-Sun BOSS gyro multishot 7,800.00 8,254.00 1H-07A_wp05(1H-07A) MWD MWD-Standard 8,254.00 9,250.00 1 H-07AL1_wp04(1 H-07AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") ("j 11,100.00 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 1H Pad 1 H-01-1H-01-1H-01 Out of range 1 H-05-1 H-05-1H-05 Out of range 1 H-05-1H-105-1H-105 Out of range 1 H-06-1H-06-1H-06 Out of range 1H-07-1H-07-1H-07 8,330.00 7,550.00 539.74 11.69 533.64 Pass-Major Risk 1H-07-1H-07A-1 H-07A_wp05 8,274.73 8,275.00 2.37 0.66 1.82 Pass-Major Risk 1 H-08-1H-08-1H-08 Out of range 1H-09-1 H-09-1H-09 Out of range 1H-10-11-1-10-1H-10 Out of range 1H-11-11-1-11-1H-11 Out of range IH-12-1H-i2-1H-12 Out of range 1H-13-IH-13-1H-i3 Out of range 1 H-14-1 H-14-1H-14 9,212.89 8,050.00 739.52 246.65 544.07 Pass-Major Risk 1H-15-1H-15-1H-15 Out of range 1H-18-1H-18-11-1-18 Out of range 1 H-21-1 H-21-1H-21 Out of range 1H-22-1 H-22-1H-22 Out of range Plan:1H-104(formerly 101 and 27)-Plan:1H-104 Out of range Plan:1H-104(formerly 101 and 27)-PIan:1 H-104 Out of range Plan:1H-104(formerly 101 and 27)-PIan:1 H-104 Out of range Plan:1H-104(formerly 101 and 27)-Plan:1 H-104 Out of range Plan:1H-104(formerly 101 and 27)-Plan:1 H-104 Out of range Plan:1H-106(formerly 107 and 28D)-Plan:1H-10 Out of range Plan:1H-107(formerly 108 and 30E)-Plan:1H-10 Out of range Plan:1H-112(formerly 106 and 28E)-Plan:1H-11 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor.ES-min ellipse separation 1/7/2016 10:59:56AM Page 2 COMPASS 5000.1 Build 74 • • Project Kuparuk River Unit aneec Nr,.teem VVELLBORE DETAILS:1H-07AL1 REFERENCE clroo4Ainoc Site:Kuparuk 1H Pad M Fla coadroielN,>=)Relerenm.WdliH-7.1Ne Nmm .�.. Well:1H-07 �avenath Vas/sane Parent Wellbore:1H-07A Verlag(IVO)Relaence;Miran Sam loot Wellbore:1H-07AL1 Tie on MD:8254.00 sedlcnNs)Retaenw 5MI-IoaoN o.InE1 BAKER ConocoPhillips Plan:1H-07AL1 wp04(1H-07/1H-07AL1) DipDate Angle 0105 MeasaeaoenmRMae a IH-07 @&Wwa11HU HUGHES Calculation Method Minim CurvatureCurval WELL DETAILS: 1H-07 4400 +1\11-S +EI-W Northing Easting Latitude Longitude 4300- 0.00 0.00 5979935.13 549560.55 70°21'21.476 N 149°35'51.058 W 4200 F Planed at 92 .00 Sec MD Inc Azi TVDSS +N/-S .Ej-W Dleg TFace VSect Annotation 1 8254.00 76.78 262.94 6649.97 3264.30 1804.71 0.00 0.00 2901.32 TIP/KOP 4100 11-07A1 t Tns.-- 2 8324.00 101.18 276.78 6651.21 3264.16 1735.42 40.00 30.00 2913.22 Start 40 dls 3 8394.00 86.62 300.82 6646.39 3286.56 1670.01 40.00 120.00 2946.64 3 40004 8530.00 88.03 355.26 6653.26 3397.53 1600.82 40.00 90.00 3067.93 End 40 dls,Start 7 dls5 8630.00 89.85 2.02 6655.11 3497.42 1598.46 7.00 75.00 3166.72 5 03900 6 8730.00 94.35 7.40 6651.45 3596.95 1606.65 7.00 50.00 3263.32 6 7 8830.00 90.83 13.46 6646.93 3695.14 1624.73 7.00 120.00 3356.87 7 ?3800 . 8 8900.00 88.38 9.21 6647.42 3763.75 1638.48 7.00 240.00 3422.05 89 9075.00 88.41 356.96 6652.33 3938.10 1647.87 7.00 270.00 3592.12 9 03700 iH-07ALI`TO4- 10 9250.00 87.39 344.74 6658.76 4110.43 1620.12 7.00 265.00 3766.65 Planned TD at 9250.00 X3600 6 ,03500 to n-el t_^n>•__..___._.___4. 5 C 40 ds,Stan 7 dla _...._ 400 •',,j3300 -Stmt 40 ills 1H-07AL1_T02--- --- 7IP/KOP IH-07AL1_T01 3200- --1HM/1H-07 3100 3000 11-07/II-07A e/ 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 6440 West(-)/East(+)(100 usft/in) 6475 CC 6510� l F PI 4, �l 6545 = S S F. 4 6580 M_ t 6615 6 P11nud TD at 980 W a, I] 6650.1, it -- - / .}-flR.{`-07..L7 •▪ 6685- ',MOP i • 5 6 8 9 Start 40 d1s End 40 dls.Stmt 7 d.s 6720- ' a H 6755 6790- 6-07/H-07 6825 • Mean Sea L_..1 - 2625 2660 2695 2730 2765 2800 2835 2870 2905 2940-297.5 3010 3045 3080 3115 3150 3185 3220 3255 3290 3325 3360 3395 3430 3465 3500 3535 3570 3605 3640 3675 3710 374.5-3780 3815 3850 3885 3920 3955 Vertical Section at 350.00°(35 usft/in) • • 1H-07 Proposed CTD Schematic Modified by JGE 12-29-15 DS nipple at 503'MD(2.875"min ID) 3W 9.3#L-80 EUE 8rd Tubing to surface 3W Camco KBMG gas lift mandrel at 7572'MD 16"65#H-40 at 80'MD DS landing nipple at 7620'MD(2.812"min ID) ■ Baker 3W PBR at 7662'MD 10-314"45.5# — _ Baker FHL packer at 7675'MD K-55 at 2365'MD rI 3W Camco MMM production mandrel at 7689'MD t =I AVA ported nipple at 7781'(2.813"ID) ................ Baker KBG-22 anchor seal assembly at 7788'MD C3/4 perfs(sqz'd) Baker SAB-3 packer at 7789'MD 7696'-7755'MD C4 straddle cement 3W Camco MMM production mandrel at 7801'MD unless AVA ported nipple at 7874'(2.75"ID) squeezedulow x/o to 2W tubing at 7877'MD inj1' `i eel Baker D packer at 7880'MD Cl perfs (�� XN landing nipple at 7899'MD(2.25"min ID) 7805'-7830'MD Plug set to abandon A-sand perfs,capped with cement Cl straddle cement we 2%"tubing tail at 7910'MD squeezed KOP @ 7842'MD Annulus of Cl straddle _ 1 H-07f,wp04 Liner-top packer at-7832'MD& TD @ 11,100'MD assembly cement squeezed if �{ swell packer in B-shale to ensure Liner top at 8254'MD MIMI YO no behind-pipe comm to Cl A-sand perfs 8015-8051'MD !�c _ _ ;'s 7"29#K-55 at 1H-07 ,wp04 7"249' D TD @ 9250'MD Liner top at 7845'MD • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task esponsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in th Patrici or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend' boxes are also checked, cross out that erroneous entry and initial it on both ,/ copies of the Form 10-403 (AOGCC's and operator's copies). V 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patrici or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jen.ni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states"Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab tenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change 411441-. LI I- the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the laia4R4 Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. • v<C2- tet 2s,5a1 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. December 18, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED /2.I/2O1 Anchorage, Alaska 99501 M K.BENDER RE: Multi Finger Caliper and Jewelry Logs: 1H-07 Run Date: 11/19/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1H-07 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20755-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: /2L/a - • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,August 27,2013 TO: Jim Regg 2( � /f o/ 13 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 11-1-07 FROM: Jeff Jones KUPARUK RIV UNIT 1H-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ,J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H-07 API Well Number 50-029-20755-00-00 Inspector Name: JeffJones Permit Number: 182-084-0 Inspection Date: 8/11/2013 Insp Num: mitJJ130822143209 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ix-07 Type Inj w iTVD Gaza IA 625 2820 2740 2740 I -- PTD 1820840 Type Test sPT Test psi 1606 OA 180 220 - 220 1 220 • Interval 4YRTST P/F P ' Tubing 2010 . ' 2100 2125 2100 Notes: 1.2 BBLS diesel pumped. 1 well house inspected,6 exceptions noted;bolts not properly engaged on well head.. ,/ S V DEL I. Q 2Y3 Tuesday,August 27,2013 Page 1 of 1 • MEMORANDUM To: Jim Regg ~~~ 4/~~'~c~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector ~ State of Alaska Alaska Oii and Gas Conservation Commission DATE: Monday, August 17, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1H-07 KUPARLJK RIV iJNIT IH-07 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~-- Comm Well Name: KUPARUK RIV iJNIT 1H-07 Insp Num: mitRCN090815095127 Rel Insp Num: API Well Number: 50-029-20755-00-00 Permit Number: 182-084-0 ~ Inspector Name: Bob Noble Inspection Date: 8~14/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well tH-o~ TYpe Inj. N TVD 6aza IA o z~9o - zi2o - zizo , P.T.D 1g2°8 °4 iTypeTest SPT Test psi 219o pA o 0 0 0 Interval a~TST p~F P~ Tubing ~s ~oo ~oo ioo Notes: A~11~1, (r%c' ~`S~' ~Si,~ l~C~b ~s~ b ~~~ ~.: ~ 1 ~ ~„ ~ ~f 4 ~ ....,,_~, ~~:,a,w ?.~. - .... . . Monday, August 17, 2009 Page 1 of 1 ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 • _~~ ~,~ _~, ~. ~,~ ~i "!'' . ~~~ ~ j 4'"^ b \ ~~~"f ~~~ Dear Mr. Maunder: ~~~~ MAR ~ ~ 2a~~ i Enclosed please. find a spreadsheet with a list of wells from the Kuparuk field (KRiI). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and- corrosion inhibitor, engineered to prevent water"f~om entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 17, 2008 and the corrosion inhibitor/sealant was pumped on February 2, and March- 8, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~,,.-- ,-- f .~ ~~~~^ ~'' C M.J. veland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field natp 3/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 H-04 182-103 23" NA 23" NA 4.5 2/2/2008 1 H-06 182-068 28' 3.2 5" 1 /17/2008 5.5 2/2/2008 1 H-07 182-084 9' 3" 1 11" 1/17/2008 7 2/2/2008 1 H-08 182-093 SF NA SF NA 4 2/2/2008 1E-31 .197-138 4'10" NA 4'10" NA 21 3/8/2008 1 E-32 197-132 8" NA 8" NA 3.5 3/8/2008 1 E-35 198-195 12" NA 12" NA 2 3/8/2008 1 E-36 198-213 20" NA 20" NA 4.5 3/8/2008 ~ ~~s ~~~i~ED STATE OF ALASKA JAN ~ 120~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO~'~a Oil & Gas Cons. Comcnissta~~, 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q - Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 182-084 / 3. Address: Stratigraphic ^ Service Q 6. API Number: " P. O. Box 100360, Anchora e, Alaska 99510 50-029-20755-00 7. KB Elevation (ft): 9. Wetl Name and Number: _ RKB 85' ' 1 H-07 8. Property Designation: 10. Field/Pool(s): ADL 25639, ALK 464 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8300' ~ feet true vertical 6959' " feet Plugs (measured) 7899' Effective Depth measured 8087' feet Junk (measured) 8162' true vertical 6775' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SUR. CASING 2280' 10-3/4" 2365' 2341' PROD. CASING 8189' 7" 8274' 6937' JAN ~ ~' 200 Perforation depth: Measured depth: , 7696'-7755', 7805'-7830', 8015'-8023', 8031'-8051' true vertical depth: 6442'-6492', 6534'-6555', 6713'-6720', 6727'-6744' Tubing (size, grade, and measured depth) 3.5" / 2-7/8", L-80, 7877' / 7911' MD. Packers & SSSV (type & measured depth) pkr-- BAKER'FHL' ; BAKER'SAB-3' ; BAKER'SAB-3' pkr= 7675' ; 7788' ; 7880' Camco'DS' nipple @ 504' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7696'-7755' Treatment descriptions including volumes used and final pressure: 700 bblS SIICk Seawater 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation -- 300 -- Subsequent to operation -- 163 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ ^~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Guy Schwartz @ 265-6958 Printed Name Guy Schwartz Title Wells Group Engineer Signature %/`~ ~\ `' ~ Phone Date ~ - %b'° ~~ ~ I 5 ! ~ P red b haron Allsu -Orak 263-4612 "` ~J ~~ s -~i> ~' ~ {~ t ~ t~ `-1 Form 10-404 Revised 04/2006 ~ 15~~F: ~~~ ~ ~ ?~~~ ~ Submit Original Only 1 H-07 Stimulation Summary • DATE Summary 1/1/08 PUMPED C4 SAND HPBD UTILIZING 700 BBLS OF SLICK SEAWATER IN THREE STAGES. MAX TREATING PRESSURE WAS 3900#. SAW 300# BREAKDOWN DURING FIRST STAGE AND 150# BREAKDOWN DURING THIRD STAGE. WELL FREEZE PROTECTED WITH 25 BBLS OF METHANOL. ~ • ~~; _, l Concsc©Rhiil`rps Alaska! Inc. KRU 1 H-07 i ~=o~ - I aPi• ~ ~nnx»m~~m ~ wou r~~.,o• ~ ini i ~ ©.,~~A rn, Tc• ~ s~ ~o~ n ~ac~ I MEMORANDUM To: Jim Regg 3 ~ ~ ~:, ~ /:, ~~i =I P.I. Supervisor ~ I _ FRO1Vt: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, January 10, 2008 SGBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA L~iC I H-07 KUPAR[,'K RIV UNIT IH-07 Src: Inspector NON-CONFIDENTIAL Reviewed By; P.I. Suprv ~"' Comm Well Name: KUPARUK RN U"NIT tH-07 Insp Num: mitLG071229122255 Rel Insp Num: API Well Number: 50-029-20755-00-00 Permit Number: 182-084-0 Inspector Name: Lou Grimaldi Inspection Date: 12/292007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. l H 07 ----- ~ ---- well !Type Inj. ' ~I'~ ~ - -- --, - 6424 '~" IA ~ ~ ! 1785 ~ ~, ~ 1730 1710 I P.T iszos4o 'TypeTest SPT ii Test psi I 1606 ~ pA loo ', 150 1so ~ 1so - WRKOVR P ~! Interval P!F ' TUbin i 2325 2300 ~ g' 2300 '- 2340 T ,_ __ __ - --__ Notes• 1.8 bbPs pumped. Good test. - ___- _ ~~ ~ #'~~1}17~a~ ,JHI~ ~ Kt ~UU~ i i._ _ _... _,.. Thursday, January 10, 2008 Page I of I • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION lit REPORT OF SUNDRY WELL OPERATIO~~~ ~a6 ~~f ~~,~, ~~r~m~~~a~l 1. Operations Pertormed: Abandon ^ Repair Well Q ~ Plug Perforations ^ Stimulate ^ Othe~;~;;~:r~ ~? Alter Casing ^ Pull Tubing ~ Perforate New Poot ^ .Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Pem~tit to Dri11 Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 182-084 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20755-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 85' ~ 1 H-07 8. Property Designation: 10. FieldlPool(s): ADL 25639, ALK 464 Kuparuk River Field /Kuparuk Oil Pool - 11. Present Well Condition Summary: Total Depth measured 8300' ~ feet true vertical 6959' feet Plugs (measured) 7899' Effective Depth measured 8087' feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SUR. CASING 2280' 10-3l4" 2365' 2341' PROD. CASING 8189' 7" 8274' 6937' Perforation depth: Measured depth: , 7696'-7755', 7805'-7830', 8015'-8023', 8031'-8051' true vertical depth: 6442'-6492', 6534'-6555', 6713'-6720', 6727'-6744' Tubing (size, grade, and measured depth) 3.5" / 2-7/8", L-80, 7877 / 7911' MD. "" '' ` ~~ Packers 8~ SSSV (type & measured depth) pkr- BAKER 'FHL' ; BAKER 'SAB-3' ; BAKER 'SAB-3' pkr= 7675' ; 7788' ; 7880' Camco'DS' nipple (a~ 504' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation -- SI -- Subsequent to operation -- 300 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt: 307-202 contact Brett Packer @ 265-6845 Printed Name r tt Packer Title Wells Group Engineer ~ ~~ ~~~ Phone Date ~~ ~ ~ ~ ~~ ~'" Signature ~....- - P d b Sharon l! u Drek 2 3-4612 Form 10-404 Revised 04/2006 ~ ~~0 Submit Origins{ Only • ~ KRU 1 H-07 ~ C©n©cc~~h~llips Alaska, tnc ~- ------ --- 1H-07--------- - ----------------- -- ---- - -------- --~ - API: 500292075500 Well T e: INJ An le Zo TS: 3`L de a) 76915 TU61NG ~ SSSV Type: NIPPLE Orig 6/16/1982 Angle @ TD: 30 deg @ 8300 (a7ss2, OD:3.500, I Com letion: ID:z.ss2) ~~,~~ Annular Fluid: Last WlO: 11!11!2007 Rev Reason: WORKOVER I ~,.: PKR (7s75-7s7s, OD:6.156) TUBING (7662-7877, OD:3.5C0, ID:2.992) Perf (7696-7755) SLEEVE-C (7781-7782, OD:2.810) Pert (7805-7830) SLEEVE-C (7874-7875, OD:2.750) TUBING (7877-7911, OD:2.875, ID:2.441) PLUG (7899-7900, OD:2.310) TTL (7911-7912, OD:2.875) Pert (8015-8023) Pert (8015-8023) Perf (8031-8051) Perf (8031-8051) Perforations Summary I Interval TVf] ~ 7nna, ~ Stntue I Ft , fiPF ~ t]atw I Tvna I Cnmmant 7696- 7755 6442- 6492 C-4 C-3 59 8 6/20!1988 IPERF 21/8" EnerJet• 30 de h 7805- 7830 6534- 6555 C-1,UNIT B 25 4 6/20/1988 IPERF 2118" EnerJet 8015- 8023 6713- 6720 A-5 8 18 2/16/20D7 RPERF 2 1/8" EnerJe 0 de hase ~ LSV it - ~SVbI ~ 6<L ~- 6144 ~ H-4 ~ _-- ~ ZV ~ l23 ~ Z/lb/LUIJ ~ 1i F't FSt' ~ C IRS" t11BfJ2r, V O@(~ p118S2 I Gas Lift Mandrels/Valves St MD j ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO l Date Run I 1 ~ I ~ - I I I I I Cmnt ~- I 1 7572 6337 Camco KBMG SOV _ T 1.0 _ BEK 0.000 0 11/11/200 ~ Injection Ma_ndrels/Valves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 2 7689 6436 Camco MMM DMY 1.5 RK 0.000 0 5/25/1994 Closed 3 7800 6530 Camco MMM DMY 1.5 RK 0.000 0 2/24/2003 (1) 1. Closed w/DCT Pko - ~ Other (plugs, equip., etc.) -SLEEVE h TVD T e Descri ion ID 7781 6514 NIP AVA BPL PORTED NIPPLE 2.812 7781 6514 SLEEVE-C 2.81" AVA NEW STYLE BPI set 10/23/2007 2.310 .~ 7874 6593 NIP AVA BPL PORTED NIPPLE 2.750 7874 6593 SLEEVE-C SET 2.75" BPI set 3/12/2006 2.310 Fish -FISH L Depth I Description I Comment I 8162 Vann Gun Left in Hole after original pert General Notes L~ Tubing String -.TUBING I Size I Too i Bottom i TVD I WI I Grade I Thread I • • Con©coPhitlips Time Log Summary Weftvtew V/eb Reporting I ~ Well Name: 1 H-07 --------------------------------- - Job Type: RECOMPLETION j Time Lomas - _ __ ~ Date _ -From To _ - Dur ___S Depth __E._ Depth: Phase _ Code_ 5ubcode _T CO__M - _ _ __ ___ __ 11105!2007 19:00 00:00 5.00 MIRU MOVE WOW NP Released rig from 1C-170 @ 19:00 hrs on 11/5107. Waiting on weather, phase 2 ,winds 25-35 m h. 11106!2007 00:00 16:00 16.00 MIRU MOVE WOW T Continue to wait on winds to die down in order to sco a and la over derrick. 16:00 21:00 5.00 MIRU MOVE DMOB P Begin laying derrick over and move auxiliary equipment away from rig. Load out remaining auxilary e ui ment. 21:00 00:00 3.00 MIRU MOVE MOB P Move rig from 1C-170 to 1H pad 11/07/2007 00:00 06:00 6.00 MIRU MOVE RURD P Move in and spot equipment over well. Begin to RU equipment and berm rig. Raise and sco a derrick. 06:00 10:00 4.00 MIRU MOVE RURD P RU floor and tie in inter connects alon with steam. 10:00 16:00 6.00 MIRU RIGMN' OTHR T Slip and cut 16:00 17:30 1.50 COMPZ WELCT KLWL P Accept rig @ 16:00 hrs on 11-7-07. Pressure test lines and open up IA to tiger tank and begin to bleed off 450 si of ressure. 17:30 18:00 0.50 COMPZ WELCT SFTY Held safety stand down w1 both Nabors rig crews, Tool pushers, Company men, CPIA Safety Rep. Gary Gauthier) and Drlg Rep (Garret Madell) on the 3 incidents that occurred toda . 18:00 18:30 0.50 COMPZ RPCO SFTY P Held Pre spud and pre tour mtg w/ Ni ht crew. 18:30 00:00 5.50 COMPZ WELCT CIRC P Continue to Bleed off well and lubricate out BPV. RU and Circulate diesel from wellbore to maintain well control. 11!08/2007 00:00 04:30 4.50 COMPZ WELC CIRC P Pump 30 bbls down tbg and return to tiger tank with the IA till no diesel in returns. Pump 50 bbls down IA and return to tiger tank with the tbg till no diesel in returns. Monitor well -out of balance. Reverse circ well @ 3.4 bpm @ 267 psi with 270 bbls to balance out the well. 04:30 05:00 0.50 COMPZ WELCT OWFF P Monitor well. Blow down lines. ~. ~. ~~~~ 1 a~f ~~ • Time Lois _ _ _ _ ___ __ _ ___ _ i I Date _ _From_To Dur S D~th_ E_ De^~th Phase Code Subcode T COM 11/08/2007 05:00 13:00 8.00 COMPZ RPCO NUND P Set BPV and ND tree. Inspect lift threads in hanger -good. install plug off tool in BPV and NU BOP. Due to Gen 1 McEvoy head clearance issues while installing the DSA, alternative wrenches were re uired. 13:00 20:00 7.00 COMPZ WELCT BOPE P Function test BOP and fill stack. Pressure test 250/3000 on rams and 250/2500 on annular. Pull plug off tool and BPV with dry rod. Test was witnessed by Chuck Sheavey w/ AOGCC on 11-8-07 15:00 hrs. 20:00 21:00 1.00 COMPZ RPCOA PULD P Make up landing jt and back out lock downs. unland tbg @ 25k and pull to 100k max when seals started moving w/ 85k up wt. Pull hanger to floor and fa down han er w1 u 't. 21:00 00:00 3.00 COMPZ RPCOh PULD P Pooh laying down and tallying w/ 63 jts, and landing nipple w/flow cou lin . 11!09/2007 00:00 08:30 8.50 COMPZ RPCOh PULD P Continue to Pooh laying down Production string. Heavy corrosion found @ 3940' and 1st hole was found @ 4062' (size of pencil) 2nd @ 4150' ( size of golf ball ). OOH all seals accounted for. Pics of corroded pipe in "S" drive folder 08:30 09:30 1.00 COMPZ RPCOh OTHR P Clean up rig floor. Preparing new com letion strip to RIH. 09:30 09:45 0.25 COMPZ RPCO SFTY P Pre job safety meeting. Discussed pinch points, well control and RiH rocedure. 09:45 14:00 4.25 0 COMPZ RPCOtr RCST P PU and RIH with completion string as er ro ram / i e tall . 14:00 19:30 5.50 7,190 COMPZ RPCOh PULD P 2.867" drift found and retreived from joint #95 while RIH with completion string. Continue to RIH with completion string with drifting each joint in the skate to 229 jts. MU Baker Storm packer and set @ 30' and test to 500 si. 19:30 22:00 2.50 COMPZ RPCOti NUND P Blow down surface lines, remove flow riser, bop hoses, choke & kill lines. ND ROPE and remove DSA. 22:00 00:00 2.00 COMPZ RPCOh NUND P Bleed off OA & well head. ND tbg spool and csg grew 16". Pull casing s ool. __ ~~~ E~~ge 2 sit A~ · . ~V~VŒ (ID~ ~~~~[\~ / l AI/ASIiA. OIL AND GAS /~ CONStiRVATlON COMMISSION I I SARAH PALIN. GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brett Packer Wells Group Engineer ConocoPhillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 H -07 Sundry Number: 307 -202 SC~'JNED JUN ,2 0 2007 Dear Mr. Packer: 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. When providing 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 to Superior Cóurt unless rehearing has been requested. Sincerely, John K. Norman Chairman DATED this iJ day of June, 2007 Encl. I~d - otl"'( r,j'1/7 Cff /; ~/'7 -0. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED kG./~~ APPLICATION FOR SUNDRY APPROVAL JUN 1 5 2007 20 MC 25 280 Alaska Oil & Gas Cons. Commission A h nc oranp. 1. Type of Request: Abandon D Suspend 0 Operational Shutdown D Perforate D Waiver D Other D Alter casing D Repair well 0 - Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing 0. Perforate New Pool D Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 182-084 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20755-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes D No 0 1 H-07 ,- 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25639' ALK464 / Kuparuk River Field / Kuparuk Oil Pool - RKB 85' 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8300' 6959' 8099' 6785' Perf guns: 8162' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 80' 80' SUR. CASING 2280' 1 0-314" 2365' 2341' PROD. CASING 8189' 7" 8274' 6937' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7696'-8051' 6442'-6744' 3~1/2" x 2-7/8" L-80 7911' Packers and SSSV Type: Packers and SSSV MD (ft) Packers = BAKER 'FHL'; BAKER 'SAB-3'; BAKER'D' Packers = 7675'; 7788'; 7880' SSSV = Cameo 'W-1' Landing Nipple SSSV = 2027' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development D Service 0 / 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 4-Sep-2007 Oil D Gas D Plugged D Abandoned D 17. Verbal Approval: Date: WAG D GINJ D WINJ 0 / WDSPL D Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Printed Name Brett Packer Title: Wells Group Engineer Signature 7?,~ 7~ Phone 265-6845 Date 6//1/0 r- . Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry :2;/)~ ' dO:;) Plug Integrity D BOP Test ~ Mechanical Integrity Test Ø- LocationClearance D " Other: ~O ~~\ "ß~" -\fc-=> \-, \l\~f,\-~~~~'ð ~'" û.~~'~Iê.\ \ \ ~s..~~~'-Q- S; ~~\>\\\.:.:J Ð~",=""",,,",. ""'<>,c-c.o~ Þ,\G d-~. S"bso,"'" Fo= """;C,,, u..o~ ' RBDMS BFl JUN 202007 Y APPROVED BY 6-/1--~r Approved by: - -/ I / -~~(>MMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 n ~ ~ h II \t1( I """"- ./ ~ . Submit in Duplicate 'f%7' ~ '\l~..ð? . . Conoc6Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 14, 2007 Dear Commissioner: RECË/\/EJ) ; JUN 1 5 2 . /,Uaska Oil & . 007 Gas Con A s. CiJ~n".' nChorage ',i;,ssiaiJ Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1 H-07 (PTD# 182-084). \ \c _. \ r !> \L.J~\c.. \,,~ ~ve:.. '-> Injection well 1 H-07 was drilled in June 1982 originally as a 2-7/8" triple producer. In 1994, the well was converted to a 3-1/2" triple injector. The well failed an MITIA in January 2003 and a leak was discovered in one of the tubing collars. Several attempts to patch the leak were done, but with short-lived success. Subsequently, the well was waivered for water-only injection:"'This well passes a comboMIT, demonstrating integrity of the production casing and upper packer. A recent Kuparuk C-3/4 redevelopment has prompted the need for increased C-3/4 injection support. It is desired to perform a high-pressure breakdown of the C-3/4 sands in this well, but due to the T x IA communication and the waivered status, we cannot exceed 45% of the burst pressure of the 7" production casing which is 2241 psi (45% of 4980 psi). Therefore, the high- pressure breakdown cannot be performed until the T x IA communication issue has been resolved; which is what this workover intends to do. The purpose of the proposed workover will be to pull the 3-1/2" tubing above the PBR and replace it with new 3-1/2" tubing. The last static BHP on 5/20/07 measured 4003 psi at 6467' TVD with a SITP of 1600 psi. The maximum anticipated surface pressure (MASP) is expected to be 1600 psi. At all times will there be a column of fluid in this well. The current wellhead is rated to 3000 psi, thus we cannot exceed 3000 psi in the BOP test, well above the MASP. During this workover, plans are to upgrade the current tubing head to a new tubing head with a higher pressure rating of 5000 psi. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-6845. Sincerely, ~ 7zßL ~~S'< ""-J1Süs ~ ..3>~ (0 W~\ \ \--.-C-\. <-:.\ ~~~<:~) ? ~ N \--\ ~ 'Ð\ <:. <: \)')4~ ~ ,'-';¿, <;0\ \ \~cl ""',\ \ ,<,,,,, ~ \." \\\oc \ ' \ ç-. ~ \....:> ~ ~ C:C~ \0 \ C£k\.. ."" ~~ '? ",. \ ~.<o .ç \'-><~ '\'\ S ~~\ ~ ß-S!?)'tI? ~ A ~ Brett Packer Wells Engineer CPAI Drilling and Wells . . Conoc~hilUps 2007 RWO PROPOSED COMPLETION API: 500292075500 PTD: 182-084 Wellhead: McEvoy Gen I X-mas Tree: 3Ys", 5M Lift Threads: 3%" BTC BPV: CIW 3" 'H' St Ie Proposed Completion · Tubing = 3W', 9.3 ppf, L-80, EUE 8rd Mod from 0' - 7877' MD. · Tubing = 2Va", 6.5 ppf, L-80, EUE 8rd Mod from 7877' - 7911' MD. · 2.875" 'DS' nipple at 500' Lock is 2.906" .2.813" 'DS' nipple at 7630' Lock is 2.856" Perf Zones C-4, C-3: 7696' - 7755' (8 spf, 6/20/88) C-1, B-5: 7805' - 7830' (4 spf, 6/20/88) A-5: 8015' - 8023' (6 spf, 2/16/07) A-5: 8015' - 8023' (12 spf, 6/20/88) A-4: 8031' - 8051' (6 spf, 2/16/07) A-4: 8031' - 8051' (12 spf, 6/20/88) Directional: Max Incline: 53.8° @ 5200' MD Max Dogleg: 4.4°/100' @ 5700' MD Well: 1 H-07 Conductor: 16",65#, H-40 at 80' DS Surface CasinQ: 10.75",45.5#, K-55 at 2365' Production CasinQ: 7",26#, K-55 at 8274' Gas Lift Mandrels: MD TVD ~ +/- 7600' +/- 6361' 1" KBMG Injection Mandrels: MD TVD 7689' 6436' 7800' 6530' ~ 1.5" MMM 1.5" MMM Fill at: 8099' RKB TD: 8,300' RKB Last Updated: 14-Jun-07 Updated by: JBP . . IH-07 Kuparuk Injector General Workover Procedure, Pull & Replace Tubing c....\e,,><t <7.\cc(è;c~~~ ~ \~'I:.-\o..\ \ ~~\\,--~~e;;.,\ ~\'-Jc.. <.... M \ '"\ ~~-' \ ~~ .v1 1. MIRV. ~ ~f) · / 2. Pull BPV, verify well is dead, set BPV, ND tree, install plug off tool in tbg hanger, NU and test BOP. 3. Remove plug off tool and BPV. 4. Pull tubing from PBR. Lay down old 3Yz" tubing. a. If tubing does not pull free, chemical cut above PBR and pull tubing. 5. Run new 3Yz" completion with seal assembly. a. If tubing did not pull free, run a po-boy overshot w/ packer and seal assem~. \t., 6. Change tubing head and IC packoffs during trip in the hole wi completion. ""'~ ~ \ \. ~\~ ~ , \ 7. Sting seals into PBR, PT to verify seals in place, pull up and spot inhibited brine. ~ ~ ~<:J Ÿ' &c.... \.j\.J\t:<;.~'\~1"- a. If po-boy overshot was run, locate tubing stub, spot inhibited brine, overshot tubing stub, set packer, shear PBR and pull up. 8. Space out and land completion. Pressure test tbg and IA. Shear SOY. 9. Set two-way check, ND BOP, NU and test tree. 10. Pull two-way check, set BPV. 11. RDMO Cøh~ /fir1/1if ~{I~ FW: 1H-07 (182-084) workover . . Subject: FW: IH-07 (182-084) workover From: "Packer, J.Brett" <J.Brett.Packer@conocophillips.com> Date: Mon, 18 Joo 200713:27:49 -0800 To: tom_ maooder@admin.state.ak.us Torn, The C sands will be isolated by using the isolation sleeves in the BPL ported nipples and dummy valves in the injection mandrels across the C-3/4 and C-l 'intervals. A plug will be set in the 'XN' nipple at 7899' RKB to isolate the A sand and CaC03 will be dumped on top of the plug. Once the mechanical isolation is in place, the tubing and IA will be CMIT'd to ensure no reservoir communication. This well has not had problems in the past passing a CMIT w/ these mechanical isolations in place. We will be using 9.6 NaCl brine as a completion fluid, circulated through GLM#l just above the top packer. We will be installing a storm packer prior to NO and changing out the tubing head and IC packoffs. If there is anything else I can answer for you, please let me know. Gary forwarded me this message because I didn't receive the original. My email address is: j.brett.packer@conocophillips.com Thanks! J. Brett Packer ConocoPhillips Alaska ATO-1510 Ph# 265-6845 -----Original Message----- From: Eller, J Gary Sent: Monday, June 18, 2007 1:08 PM To: Packer, J.Brett Subject: FW: IH-07 (182-084) workover Brett - See below. Probably want to give Torn your e-mail address if the original didn't reach you. -Gary -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, June 18, 2007 12:58 PM To: brett.packer@conocophillips.com Cc: Eller, J Gary Subject: IH-07 (182-084) workover Gary, I am not sure of Brett's eddress. Please forward if I don't have it correct. Thanks. t;3rett, I am reviewing the sundry application to workover IH-07 and have some questions. 1. Is or will some sort of mechanical plug be set to isolate the presently completed intervals? 2. What weight fluid will be employed while working over the well? 3. Do you plan to install a storm packer prior to NO and removing/upgrading the tubing head? Thanks in advance. Call or message with any questions. Torn Maunder, PE 10f2 6/19/20078:17 AM 06/08/07 ">'-">._"""'--~""- , Schlumbel'gel' NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ]. 20m S(;ANNED JUN 14 2D07 ~v Field: Kuparuk lJ IC- l"Od - OOZ( Well Date BL Color CD Job# Log Description 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT OS/25/07 1 2V -08A 11629013 PMIT 05/15/07 1 1 J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1 H-07 11665436 SBHP SURVEY OS/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1 B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1Y -11 11632708 INJECTION PROFILE OS/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1 F-08 11665435 SBHP SURVEY OS/20107 1 1J-170 11632709 INJECTION PROFILE OS/24/07 1 1 D-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . • ,y~vv ~~TT ~~11~~ppa~crya~~7e~~7t~~ ®~i ~~+~+~z~.~~T `L®~d~iYil-~~i~®ld ~®-7-7~®!.7 • FRANK M. rNURKOVISKI, GOVER^lOR 333 W. T" AVENUE, SUITE id0 ANCHORAGE. ALASKA 99501-3539 ?HONE (907) 279.1433 FAX (907) 276.7542 ADMINISTRATIVE AP'PR®VAL, N®. AI®2B.006 Mr. Jerry Dethlefs Problem well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99~ 10-0360 RE: KRU 1 H-07 (PTD 182-484) Request for Administrative Approval Dear Mr. Dethlefs: `~~~~ JAN ~ ~ 2D~ On May 28, 2006 ConocoPhillips Alaska, Inc {"CPAI") requested an administrative approval under Rule 9 of Area Injection Order ("AIO") 2B to allow continued water injection in service well Kuparuk River Unit ("KRU"} 1 H-07. The Alaska OiI and Gas Conservation Commission ("Commission") GRA_tirTS CPAI's request for `WATER ONLY service, as detailed below. 1 H-07 was originally reported to have tubing x inner annulus ("T x La") pressure communication in February 2003. Mechanical integrity was restored by placing a patch over the leak, however pressure communication returned in December 2003. CPAI has determined that a rig workover is necessary to repair the well. CPAI has attempted to perform corrective action on 1 H-07 to restore full integrity, however the work was not ultimately successful and CPAI does not propose to continue with any planned repairs. The Commission finds that, based upon reported results of CPAI's diagnostic procedures, 1 H-07 exhibits tw-o competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity and will not result in an increased risk of movement of fluids outside the injection zone. `t'here freshwater is not affected, 20 AAC 2~.4~0 gives the Commission authority to approve less stringent well integrity and operation requirements. Per Rule 9 of AIO 2B, the Commission hereby grants CPAI's request for administrative approval to continue water injection in KRU I H-07 on the following conditions: 1. Injection is Limited to w'ATER ONLY; _aD~I[NESTR~T'I~'E APPROVAL a[O ti~ ZB 006 June 20, 2006 Page 2 of 2 '. CPAI shalt monitor and record tubing, inner. annulus and outer annulus (T~I;'O) pressures and injection rate daily; 3 CPAI shall submit to the Commission a monthly report of we11 pressures and injection rates including an} pressure bleed events; 4. CPAI shall perform an Combined Mechanical Integrity Test (CHIT} of the tubing and inner annulus (T x IA) e~rery two years; ~. CPAI shall perform an tiIIT-OA every two years; 6. CPAI shall immediately shut in the well and notify the Commission upon any measurable change in the wells mechanical condition; and 7. After well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection. 8. The i~~tIT anniversary date is January- 3, 2006. As provided in AS 31.0.080, 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 to Superior Court unless rehearing has been requested. D~OiriE at Anchorage, Alaska and dated June 21, 200f. The Alaska ®il a®d Gas Conservation Commission J ormar~i"-~~ Daniel T. Seamount, Jr. Chairman Commissioner ;i' ~ :~ _ /~.~ . A '~ _ ' r ~ ~ . ~ r ~' ~ ~ f ~-l ~ J , - ' ~' _- a w ~~ y~ ~ ~y 0 F ' Vi y .1~~;- . ~ z. TT._ ` ~.. J /~ 1 i ~ ~' r'I Cathy . Foerster Commissioner ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg }).I. Supervisor ,--7 ( I 1~i1 I 4 Ot· DA TE: Wednesday, January 04, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 1 H-07 KUPARUK RIV UNIT IH-07 \ QJJ:'Ocg+ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :W~~- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IH-07 Insp Num: miUJ060104083655 Rellnsp Num API Well Number 50-029-20755-00-00 Permit Number: 182-084-0 Inspector Name: JeffJones Inspection Date: 1/3/2006 Packer 1820840 1606 IA OA Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1600 2600 2580 2540 2540 610 610 610 610 610 1550 2510 2480 2460 2460 ."._.._.w,~,_ _ . .~_,_" 'W".'_""""W'.' ...""'----~..._-,_.._._,-'..'-'._-,,.,_.._, .'... .'.""-"~.-.-'.-_....". Well P.T. IH-07 Type Inj. N TVD 6424 In te rv a I .~EQ~AR .__.rlF.._._.._..._________~..__.__u_____ __.____.......___n_.___!.~~_~.~g Notes .5 BBLS diesel pumped. Tx IA communication; TTP set @ 7686' MD. 1 well house inspected; no exceptions noted. C AAJ>r T K11~. ~Ç^NNl~~J ...~;qN 1 1 2005 Wedncsday, January 04, 2006 Page 1 of 1 ) ~,1I~lf1). ...... ~. Å. ...... .... ::¡::: .. '::::~:::::::~l¡' ConocoÞtulhps Alaska, tnc" SSSV (2027-2028, 00:3.500) PKR (7675-7676, 00:6.156) SLEEVE-O (7781-7782, 00:2.810) Perf (7805-7830) SLEEVE-O (7874-7875, 00:2.750) NIP (7899- 7900, 00:2.875) TUBI NG (7877-7911, 00:2,875, 10:2.441 ) Perf (8015-8023) Perf (8031-8051) ¡ r , . ~ \ I~;"....J. i. '1' ~ , I ¡ . ¡ _m ¡~·..·fl 1:8:1.1u ~ -+ -+ -r .. ~¡~~~¡f:m¡¡~¡¡1 j~~: ........- : -. .~.~...~.','," :',.;.:......~ . -+ -+ -+- -.;.. ! IÌ.·...\ ¡ ~_................;¡ ~ 1:' ',/( 00:_: · . ' . · . ' , . · . ".' ~ : .". <::: .. 0_ -.;.. t -~ :b ~ --Ö- E -¢- -r I -õ ~ API: 500292075500 SSSV Type: NIPPLE Annular Fluid: Reference Log: Last Tag: 8103 Last Tag Date: 9/14/2004 qasliïg:Strlhg:.S,A~(/:$tB. N(3$.·..::··::::::··· Description Size CONDUCTOR 16.000 SUR. CASING 10.750 PROD. CASING 7.000 I Size 3.500 2.875 Top o 7877 ) KRU 1 H-07 Well Type: Orig Completion: Last W/O: Ref Log Date: TO: Max Hole Angle: INJ 6/16/1982 5/24/1994 Angle @ TS: 32 deg @2 7696 Angle @ TO: 30deg @2 8300 Rev Reason: TAG FILL Last Update: 9/18/2004 8300 ftKB 54 deg @ 5200 Top o o o Bottom 80 2365 8274 TVD 80 2341 6937 Wt 65.00 45.50 26.00 Grade H-40 K-~¡5 K-~;5 Thread Bottom 7877 7911 Wt 9.30 6.50 L-80 L-80 EUE 81RD AB-MOD EUE8RD MOD TVD 6595 6624 Status Date Type Comment 6/20/1988 IPERF 21/8" Ener.let; 30 deg ph IPERF 2 1/8" Ener~let St MD TVD Man Man Type Mfr 1 7612 6371 Cameo Injection MandrelsNalves St MD TVD Man Man Type Mfr 2 7689 6436 Ca meo 3 7800 6530 Ca meo 1. Closed wlEXT Pkg .Othßr:(PIUgs;.~qÜjp~(ëtc;):":4.EWELRY:::·:··:··: Depth TVD Type 2027 2021 SSSV 7662 6413 PBR 7675 6424 PKR 7788 6520 PKR 7880 6598 PKR 7899 6614 NIP 7911 6624 m Interval 7696 - 7755 7805 - 7830 TVD 6442 - 6492 6534 - 6555 8015 - 8023 8031 - 8051 6713 - 6720 6727 - 6744 Type NIP SLEEVE-O NIP SLEEVE-O Zone C-4,C-3 C-1,UNIT B A-5 A-4 MMM MMM MMM Ft SPF 59 8 25 4 8 12 IPERF 2 1/8" Ener Jlet 20 12 IPERF 2 1/8" Ener Jlet V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.5 RK 0.000 0 Eì/4/1994 V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.5 RK 0.000 0 5/25/1994 Closed DMY 1.5 RK 0.000 0 2/24/2003 (1 ) Description ID 2.812 3.000 2.992 3.250 3.250 2.250 2.441 Cameo W-1' Landing Nipple Baker Baker 'FHL' Baker 'SAB-3' Baker '0' Otis 'XN' Nipple NO GO Description ID 2.812 2.370 2.750 2.325 Depth TVD 7781 6514 7781 6514 7874 6593 7874 6593 Fish - FISH Depth I Description 8162 Vann Gun GëneräINôtes.· ...·i·. Date I Note 2/17/2004 WAIVERED WELL: T x IA COMMUNICATION AVA BPL PORTED NIPPLE SET 2.81" BPC SET 1/29/2004 AVA BPL PORTED NIPPLE SET 2.75" BPC set 1/29/2004 I Comment Left in Hole after original perf Schlumbepger NO. 3213 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: 8eth 1l.7 09/24/04 Company: Alaska Oil & Gas Cons Comm AUn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date 8L Color <¡ 'f -o'{ 2- 3C-06 10922465 PRODUCTION PROFILE W/DEFT 09/19104 1 't5 -05' 2A-18 10802936 PRODUCTION PROFILE W/DEFT 09/12/04 1 '8{- 038 28-12 10802934 INJECTION PROFILE 09/10/04 1 !' J/- I ~ 4 2X-11 10802933 PRODUCTION PROFILE 09/09/04 1 }~l- ~5 18-10 10922467 PRODUCTION PROFILE 09/21/04 1 () ". ~5 3G-08 10802935 PRODUCTION PROFILE 09/11/04 1 ri-oz ( 2F-08 10922466 PRODUCTION PROFILE 09/20/04 1 t ~'f - (( 7 2G-11 10884019 PRODUCTION PROFILE 09/08/04 1 f ~2. -,~ 1H-19 10802940 INJECTION PROFILE 09/14/04 1 1 2.- , 1H-07 10802939 INJECTION PROFILE 09/14/04 1 ~ß2. -C;(O 1A-14 10802938 INJECTION PROFILE 09/13/04 1 ( '1'" 010 2H-03 10802945 INJECTION PROFILE 09/18/04 1 Iß~"05' 1Y-02 10802942 INJECTION PROFILE 09/16/04 1 ''þ- O'f'f 1Q-13 10802941 INJECTION PROFILE 09/15/04 1 ... 7-H~ 3H-09 10922468 INJECTION PROFILE 09/22/04 1 I ~6-ltfl 2T-02 10802944 TEMPERATURE SURVEY 09/18/04 1 '9() - / r,(P1A-26 10802943 LEAK DETECTION LOG 09/17/04 1 Kuparuk CD ----' ~ sl€Ç;kc-l.kl'~ SCANNED NO V 082004 DATE: /0104 Please sign and returle copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. VIC File Review Date: February 10,2004 Subject: CPAI KRU WelllH-07 PTD#: Orders: 182-084 403-304-043 AI02B I 9J~ Tom Maunder, P.E. ~ Reviewers: Initiating Action: Application for Waiver to Continue Injection with T x IA Communication Review Summary 1. This well was drilled in June 1982. 2. Nothing remarkable is reported for either hole section and both casing strings were run and cemented successfully. Cement is not reported to surface on the surface casing, but no top job was performed. 3. The well was Arctic Packed. 4. It is reported that a CBL was run with the rig on the hole. Blair performed a MIT Part II in December 1993. He notes "Excellent bonding above the perfs". 5. In May 1993, a 403 was submitted proposing to convert the well to water injection service. 6. In January 1994, the Commission was notified ofT x IA communication. According to the letter, communication was noticed shortly after the well was put in service (6 months earlier). Diagnostics indicated that the leak point was at the PBR. A sundry was submitted (194-015) and approved to allow the well to remain in service. 7. The well was worked over in May 1994. The well report indicates that the rig MIT was successful. 8. The only MIT report in the file was a witnessed test by Jeff Jones in July 2001. The test was successful. 9. On 2/1/03, Problem Wells reported that the well was experiencing communication problems and they requested to keep the.well in service while performing diagnostics. Problem wells reported the well to successfully pass a CMIT TxIA in mid February. Plans were made to install a patch. 10. CPA applied for a sundry (303-056) in late February to install the patch. 11. The patch was set on April 1 and the well was reported to have passed a standard MIT on April 15. 12. Jeff Jones witnessed a successful MIT on May 31 and John Crisp also witnessed a successful MIT on September 29. This most recent test was necessary due to pulling the patch to access other WL tools below the patch. 13. In early December new communication problems were experienced. Resetting the patch did not correct the problems. As part of their diagnostics, CP AI successfully conducted a CMIT TxIA with a plug in the tailpipe on January 28, 2004. 14. CP AI has determined that further patching is not appropriate and that a workover will be necessary to return full integrity. In the latest sundry it is proposed to keep the well in water only service, submit the monthly monitoring information and perform a CMIT TxIA every 2 years. Review Conclusions: ~((;ANNEI) fEO 1 8 2004 1. No problems were reported drilling any hole section or cementing any casing. It is not clear if the surface casing was cemented to surface. 2. A bond log was run in the 7" casing and an MIT II analysis was performed in December 1993. Based on the volume pumped, more than sufficient cement was pumped. Blair determined that there was "Excellent bonding above the perfs". 3. CPAI reported T x IA communication in January 1994 and proposed to keep the well in water service while performing diagnostics. Their request was granted. 4. The well was worked over in May 1994 restoring full integrity. 5. New communication was reported in February 2003 and repairs were made using a patch, which appears to have subsequently failed. 6. According to CP AI, the well has successfully passed a CMIT TxIA on January 28, 2004 7. CP AI has proposed to keep this well in WATER ONLY service, add this well to the monthly monitoring list and perform a CMIT TxIA every 2 years. These are the standard conditions that have been applied to wells with similar leaks. Recommendation 1. I recommend approval of CPAI' s request. MECHANICAL INTEGRITY REPORT . SPUD: 6/C3/82 RIG RElEASE: 6//6/R? I . / OPER & FIELD Arc. () //.1<.. J< I ¡: I \-rELL NUMBER III - 7 '5' 2 - ORt,. TD: e30ö MD 6959 TVD; PBTD: 8/94- MD G8&7 TVD Shoe: 8274 MD TVD; DV: MD -TVD Shoe: MD TVD; TOP: MD TVD WELL DATA Casing: 1 ~6 (~ Liner: Tubing: .3 11.. Packer -¡.£' 7? MD TVD; Set at 16'12 Hole Size 81"4- ; Perfs 7676 to 8ð:Ç/ and MECHANICAL INTEGRITY - PART HI Annulus Press Test: IP 15 min 30 min Comments: ,..- . MECHANICAL INTEGRITY - PART #2 -r ~., ~'=' ts: "" { 8, b ~ 'to f t..F :, 3; q. :.- . -5 5-6. ~ Cement Volumes: Amt. Liner ; Csg 96'? S'~ ; DV 14.7' 9.3 íl.(."'l- Cmt vol to cover perf s(~ 0 ,. .( 9 ~ ~) + ('2.6 ~ .3 J(, ~) -r t§2 7" - 7{9(;). /2.8-4 :-98: 2. 7}G' B~ -:. ( ~8-e¡. Theoretical Toe 1(.. 96 - [C 96 Z. - 98.-;).. ..;. ("28 Lf ;:: 96 ~I Cement Bond Log (Yes or No) r.e'S ; In AOGCC File C [':1 L CBL Evaluation, zone above perfs ,r;;.x:(~~e//:.;~:r'I'f- l~"/lJf~'~í abn(t-~~ 17eII~,;: < J Production Log: Type ; Evaluation CONCLUSIONS: Part 11: . Part # 2: .fv? /' /~< {~7 cJ~(-'(J jp'rl .4Jk;. 12/6!9.7 rev. OS/20/87 C.028 Conoc~hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 8, 2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. welllH-07 (PTD 1820840). The request regards approval to inject water with a failed MIT. Please call Marie McConnell or me at 659-7224 if you have any questions. Sincerely, ~f~ Problem Well Supervisor Attachments RECE\VEO FEB 1 0 2004 " G Coos.. Ltlll1ln"SS\on MS$ka O~\ & ]as Anchorage ORIGiNAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 9. Well Name and Number: 1 H~07 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): 6867 MD 1. Type of Request: 0 0 0 Suspend 0 Repair well 0 Pull Tubing 0 Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 85' 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 8300' 6959' 8194 Casing Length Size CONDUCTOR SUR. CASING 80' 2280' 16" 10-3/4" PROD. CASING 8189' 7" Perforation Depth MD (ft): 7696'.7755',7805'.7830',8015' - 8023',8031' - 8051' Packers and SSSV Type: pkr= BAKER 'FHL'; BAKER 'SAB-3'; BAKER 'SAB-3' SSSV= SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Variance 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Perforate 0 Stimulate 0 4. Current Well Class: Development Stratigraphic 0 0 Exploratory 0 Service 0 A-; ?ç~ "'/I, ¿fi/ / fZ-- Annular Disp. 0 Other 0 182-084 6. API Number: 50-029-20755-00 Junk (measured): Burst Collapse TVD 80' 2365' 80 Perforation Depth TVD (ft): 6442'.6492',6534'.6555',6713' - 6720', 6727'.6744' Packers and SSSV MD (ft) pkr= 7675'; 7788'; 7880' SSSV= 2027' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 02/10/04 Date: 8274' 2341 6936 Tubing Size: 2-7/8" Signature 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Jerry Dethlef ~C Contact: Title: Phone 659-7224 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness RECe\¥EQe 0 I ~\" \'1 ~ ??r\-\,,\ O~~ ~q~ ~~~ ~\tè"><;\)~"> Of'.-- d '-p-c.ìc\r¿~~1~,,~~)(cj~0~~{ dOOG:" Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Other: "'.).~'~ Q...f)~ L '-.) C~\'\ .\~ 'Cf Approved by: Form 10-403 Revised 2/2003 . COMMISSIONER ()Q'GJNAL BY ORDER OF THE COMMISSION BfL Tubing Grade: L-80 Tubing MD (ft): 7911' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Marie McConnell 659-7224 Problem Weill Supervisor ~~T~N DUPLICATE ConocoPhillips Alaska, Inc. Kuparuk WelllH-07 (PTD 1820840) SUNDRY NOTICE 10-403 VARIANCE REQUEST 02/08/04 The purpose of this Sundry Notice variance request is for approval to continue water-only injection with a failed MIT. WelllH-07 was reported to the AOGCC in February 2003 as having T x IA communication. Diagnostics found a tubing leak at 4054' MD, which was patched with AOGCC approval (Sundry 303-056). The well again failed an MIT in December 2003, and a second tubing leak was found at 7612' MD. A workover will be required to fully repair the well. On 01/28/04 a tubing plug was set in the D nipple below the packer. A successful CMIT T x IA was performed to 2500 psi. The MIT test form is attached. CMITs are proposed as the chief method to verify the casing continues to have integrity; as long as a CMIT will pass it will demonstrate competent casing and packer. The following Action Plan is proposed to support the variance request for continued injection: ACTION PLAN 1. Well will be used for water injection only (no gas or MI allowed); 2. Perform CMIT T x IA against a tubing plug every 2-years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum); 3. Submit monthly reports of daily tubing & IA pressures and injection volumes; 4. Shut-in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. NSK Problem Well Supervisor 12/12/03 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.usandBob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 1 H-07 01/28/04 Fitzpatrick NA 0 P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 1H-07 01-28-04.xls 2/8/2004 SSSV (2027-2028, 00:3.500) Gas Lift mdrellOummy Valve 1 (7612-7613, 00:6.016) PKR (7675-7676, 00:6.156) Injection mdrel/Oummy Valve 2 (7689-7690, 00:6.016) SLEEVE-O (7781-7782, 00:2.810) Injection mdrel/Oummy Valve 3 (7800-7801, 00:6.016) Perf (7805-7830) SLEEVE-O (7874-7875, 00:2.750) NIP (7899-7900, 00:2.875) TUBING (7877-7911, 00:2.875, 10:2.441) Perf (8015-8023) Perf (8031-8051) ConocoPhillips Alaska, Inc. 1 H-07 KRU 1 H-07 API: 500292075500 SSSV Type: NIPPLE Annular Fluid: Well T e: INJ Orig 6/16/1982 Com letion: Last W/O: 5/24/1994 Ref L Size 16.000 10.750 7.000 To 0 0 0 Bottom 80 2365 8274 TVD 80 2341 6937 Wt 65.00 45.50 26.00 Grade H-40 K-55 K-55 Thread Thread EUE 8RD AS-MOD EUE 8RD MOD Zone C-4 C-3 C-1,UNIT S A-5 A-4 Status Ft SPF Date 59 8 6/20/1988 25 4 Comment 21/8" EnerJet. 30 de h 2 1/8" EnerJet ..--- --.. ID 2.812 ----....--. - ...- 2.370 -.--... --.-..---- --i75C) - --------. -- --- ---'-"-----" . _m__- 2}2~. -. -----... ..--... Comment Left in Hole after ori inal eri ------'-'-- FV~I; Kuparuk 1 H -07 Status ( ( ç(e - f'Tb -:tL I SZ-DE< Subject: FW: Kuparuk IH-07 Status From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Thu, 29 lan 2004 12:46:09 -0900 , ":;",,,,"", ' " . ,',' "", ,,'" ",' :"".' ",:" ' , ',' ,.' " .',' '. .' "'"."'. ':'", .,:" rOt::,,:, ,TQp;1:'¥aunder AQqcç::(~-111~1l),. ',,<:ton1¿U1atmde:r@a~n.state,.~k. ~s~,,:: ..J 1m, : Rë$g;'*OGçc (E-mai1rt;'-<ji~';:'T~:g:~@ädmin:.,stat~~åk~us>~"~'".\VintoilAubert'," "'.',, '" "-::y. AOGCC'{E-rnaîl)",<winton~allbért@'admin:.state~ak~us>":' ,.' , Winton, Torn, Jim, Continued update on 1H-07: A CMIT passed on 1/28/04 with a plug in the D nipple and the C sand isolated. We are preparing a variance (10-403) to injection water only with a failed MIT. The well will continue to be reported on the failed monthly MIT report and remain SI until a variance can be obtained. Please let me know if you have any questions, Marie McConnell ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Sunday, January 25, 2004 9:01 AM To: Torn Maunder AOGCC (E-mail); Jim Regg AOGCC (E-mail) Cc: NSK Problem Well Supv Subject: FW: Kuparuk 1H-07 Status Torn, Jim, Here is an update on the progress on injection well 1H-07. We reset the bottom portion of the patch (Sundry # 303-056) and the combo MIT failed (after a passing CMIT before setting the patch) . Our plan forward is to re pull the patch and run a plug to the D nipple. If we can get a passing CMIT showing sound casing/packer integrity, our plan forward is to apply for a variance (10-403) to inject water only with a failed MIT. The well will continue to be reported on the failed monthly MIT report and remain SI until a variance can be obtained. Please let me know if you have any questions. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 5CANNEDf£B 0 2 2004 1 of 3 1/29/2004 5 :20 PM F\X!: Kuparuk 1 H -07 Status . ( ( " -----Original Message----- From: NSK Problem Well Supv Sent: Friday, January 16, 2004 5:16 AM To: 'Thomas Maunder'" Cc: NSK Problem Well Supv Subject: RE: Kuparuk IH-07 Status Torn, We pulled the patch on IH-07 and did some additional leak detection work and discovered an additional leak at a dummy valve below the patch. The DV was replaced and a combo MIT now passes. Our intention is to re set the patch, MIT the IA, and return the well to service in the next couple weeks. Do we need a new 10-403? or can I just file a 10-404 after the patch is re run, reporting that it was pulled and re run? Please advise. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 -----Original Message----- From: Thomas Maunder" [mailto:tom maunder@admin.state.ak.us] Sent: Monday, December 15, 2003 :3:30 AM To: NSK Problem Well Supv/PPCO@Phillips Cc: Jim Regg Subject: Re: Kuparuk IH-07 Status Thanks Jerry. I understand that the weather has been bad. As you note, please update us when you have the new information. Torn NSK Problem Well Supv wrote: Tom: I have a note here from Nina that I am to report the status of IH-07 failed MIT diagnostics to you by December 15. Unfortunately we have had almost a week of Phase 2 & 3 weather up here and haven't been able to rig up on the well. As a review, the (injector) well failed an MIT and was reported to you on December 2. We had just set a tubing patch and it appears the patch is leaking. Our diagnostics plan is to check the patch for leaks and pull and rerun if it has failed. It may be a leak in another location. In the meantime the well is on water injection. 2of3 1/29/20045:20 PM F\\(: Kuparuk IH-07 Status . f \ We are planning on getting on the well as soon as the weather breaks. We will update you at our earliest opportunity. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 3 of 3 1/29/2004 5 :20 PM ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 1,2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7t~' Avenue, Suite 100 Anchorage, AK 99501 RECEIVED OCT 0 ,.,' 20 5 ~J'~a 0il& 6~s Oons. Co~ ~n~on~ Dear Mr. Maunder: Enclosed please 'find 10-404 Sundry Notices for ConocoPhillips Alaska, Inc., wells 1. A-13 (PTD .181.-195), IH-07 (PTD 1.82-084), and 30-04 (PTD 188-062). The Sundry Notices regard tubing patches run to fix tubing leaks in IA-I 3 and I.H-07. IH-07's Sundry is a repeat notice as the patch was recently pulled and re run to access the C sand. 30-04 Sundry Notice is for an OA casing patch repair. Please call Nina Woods, Jerry Dethlefs or me at 907-659-7224 if you have any questions. Sincerely, MJ ConocoPhillips Problem Well Supervisor Attachments REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [] Suspend E~ Operation Shutdown [] Perforate [] Variance L_{ Annular Disp. [] Alter Casing [] Repair Well [] Plug Perforations ~ Stimulate r-] Time Extension [--~ Other Change Approved Program [--] Pull Tubing r-~ Perforate New Pool ~--~ Re-enter Suspended Well ,, 2. Operator Name: 4. Current Well Status: 5. Permit to Ddll Number: ConocoPhillips Alaska, Inc. Development [] Exploratory E~ 182-084 / ' 3. Address: Stratigraphic C~ Service r'~ 6. APl Number: P. O. Box 100360 50-029-20755-00 7. KB Elevation (ft): 9. Well Name and Number:. RKB 85' 1H-07 ~. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8300' feet true vertical 6959' feet Plugs (measured) Effective Depth measured 8194 feet Junk (measured) true vertical 6867 feet · Casing Length Size MD 'I'VD Burst Collapse Structural CON DUCTOR 80' 16" 80' 80' SUP. CASING 2280' 10-3/4" 2365' 2341' 4980' 2090 PROD. CASING 8189' 7" 8274' 6936' 3580' 4320 Pedoration depth: Measured depth: 7696'- 7755', 7805'- 7830', 8015'- 8023', 8031' - 8051' RECEIVED true vertical depth: 6442' - 6492', 6534' - 6555', 6713' - 6720', 6727' - 6744' OCT 0 ? 20,05 Tubing (size, grade, and measured depth) 2-7/8", L-80, 7911' MD. ~a~a 0~t & Gas C0J15. CoJ~j~jor~ Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; BAKER 'SAB-3'; BAKER 'SAR-3' pkr= 7675'; 7788'; 7880' SSSV= SSSV SSSV= 2027' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casin,q Pressure Tubing Pressure Prior to well operation Subsequent to operation 150 1750 2400 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run __ Exploratory r-1 Development O Service ~-~ Daily Report of Well Operations __X 16. Well Status after proposed work: Oilr'--~ Gas r-"] WAG [~] GINJ[~ WINJ ~ WDSPL[-'-] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: 303-056 I Contact Printed Name MJ Loveland/l~da Woe~'s Title Problem Well Supervisor Signature .,,,..,~~"/~~"~ '//~,....._,,......~.._.~on e 659-7224 Date Prepared by Sharon AIIsup-Drak~ 263-4612 Form 10-404 ed 2/2003 · SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. Kuparuk Well 1H-07 (PTD 1820840) SUNDRY NOTICE 10-404 TUBING REPAIR 10/1/03 This Sundry is a report of completed well operations that repaired ConocoPhillips (CPA) Kupamk Well 1H-07 with a tubing patch. On February 1, 2003 the AOGCC was notified of a failed MIT. Subsequent diagnostics indicated a hole in the tubing at 4054' MD. Sundry Notice 10-403 #303-056 for a tubing patch was approved February 25, 2003. Subsequently a 20' retrievable eclipse tubing patch and a K3 packoff assembly was set from 4044-4064' on April 1, 2003, and April 10, 2003, respectively. A Passing IA MIT to 3000 psi was completed on April 15, 2003. Subsequently the 20' patch was pulled to access and open the C sand via an AVA sleeve on 8/15/03. The retrievable eclipse patch and K3 packoff assembly was then reset August 10, 2003 and August 30, 2003, respectively. An additional State witnessed MITIA to 2480 was completed August 29, 2003. NSK Problem Well Supervisor MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: Jim Regg P.I. Supervisor ' -~ ' I,.~ FROM: John Crisp Petroleum Inspector DATE: September 29, 2003 SUBJECT: Mechanical Integrity Tests Conoco/Phillips Kuparuk River Field KRU 1A-13- 1H-07 Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. We,,I ~A-~3 IType,nj.I S IT.M.D. 15953 ITubingl 1250 I~o I~o I~o Ilntervall O P.T.D.I 1811950 ITypetestl P ITestpsil 2000 I Casingl 680 I 20001 19501 19301 P/F I B Notes: Post patch MIT - 1.2 bbl. Pumped. OA 0 psi. We,,I iH-O? IType,nj.I S I T.V.D. I~ I Tubingl 1600 I 1600 I 1600 I 1600 I,nter~a,I O P.T.D.I 1820840 ITypetestl P ITestpsil 2000 I Casingl 800 I 24801 2420 I 2410 I P/F I ~ Notes: Post patch MIT - 1.7 bbl. Pumped. OA 340 psi. to 400 psi during test. Well l Type Inj. P.T.D.I Notes: Well l P.T.D. ~ Type test Notes: P.T.D.I Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Two MITIA's performed. No failures witnessed. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed' 2 Number of Failures: 0 Attachments: ~ Total Time during tests: 4 hfs, cc: MIT report form 5/12/00 L.G. 2003-0929_MIT_KRU_1H-07_jc.xIs 10/10/2003 ~: [Fw~ MIT KRU 1H-07 04-15-03.xls] Subject: Re: [Fwd: MIT KRU 1H-07 04-15-03.xls] Date: Mon, 02 Jun 2003 14:58:29 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: NSK Problem Well Supv <n1617@conocophillips.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us>, Jim Regg <jim_regg@admin.state.ak.us>, Bob Fleckenstein <bob_fleckenstein@admin.state.ak.us> Hi Nina, Jeff called me after the "standard" pressure test. I am comfortable with the "draw down" test. In the "draw down" mode, the patch was tested in the direction of a potential leak. I believe that the monitoring employed through the 5 hours demonstrated the tubing integrity. The normal operations monitoring you and your colleagues perform should allow any pressure increase to be detected. This will be especially important when and if MI is put into the well. Thanks for working with us with regard to demonstrating integrity on this well. Tom Maunder, PE AGOCC NSK Problem Well Supv wrote: Saturday, 6/28/03, we performed a 1 Hour MITIA on 1H-07 with Jeff Jones. T/IlO = 2300/1300/0 Pressure up IA with diesel to 3000 psi, start MITIA T/IlO= 2300/3000/0, 15 minute reading T/IlO= 2300/2825/0, 30 minute reading T/IlO= 2300/2745/0, 45 minute reading T/IlO= 2300/2680/0, 60 minute reading T/IlO= 2300/2645/0. Per your request, we performed a drawdown test on the well fo/lowing the MITIA. The IA was bled down to 1300 psi. Jeff returned 5 hours later to note the IA pressure was holding at 1300 psi. I Spoke with Jeff Jones 6/1/03 and he declared this a passing MITIA. We all agreed that a minor leak does exist and the current patch might not have truly repaired the leak. We plan to closely monitor the well if and when we convert to MI Injection. The near future plans are WI only for this well with MI injection a possibility in early 2004. Are you comfortable with these results and continued injection in 1H-077 P/ease call with questions, Thanks, Nina Woods Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 Tom Maunder <tom_maunder@admin. state, ak. us> 05/14/2003 01:36 PM To: NSK Problem Well Supv/PPCO@Phillips, AOGCC North Slope Office <aogcc_prudhoe_ba y@ adm in.stat e. ak. us> > cc: Jim Regg <jirn_regg@admin. state, ak. us> > Subject: Re: [Fwd: MITKRU 1H-07 04-15-03.xls] > M J, Jerry 'al'tO, ina, '"'-'"'~ -' > In mid April, you sent an MIT for 1H-07 after a patch was installed to > remedy 1 of 3 Si~.NN~D, JUN :[ 0 200"3 613/2003 8:38 AM [Fwd': MIT KRU 1H-07 04-15-03.xls] tubing x IA communication. 2, 30 minute MITs were conducted. In each test, the total pressure loss measured was 8% of the applied test pressure and the pressure loss in the 2nd 15 minute observation period was less than that experienced in the first observation period. Although the presented test information meets that absolute criteria of a successful M/T, the pressure losses reported do not seem to indicate that the patch has truly repaired the tubing leak. It would have been interesting to see how the pressures behaved if the observation period had been lengthened to maybe an hour. In the tests presented, the higher annulus pressure appears to be equalizing with the lower tubing pressure although the delta is decreasing as the annulus pressure drops. Based on the annulus pressure prior to beginning the test, the tubing appears competent since a 1400 psi differentia/ is present. We would appreciate if you would provide us with the T/IlO information for the well since the patch was installed and also make arrangements for an Inspector to witness an MIT. Please call my self or Jim Regg with any questions. Tom Maunder, PE AOGCC > > Subject: MIT KRU 1H-07 04-15-03.xls > > Date: Tue, 15 Apr 2003 18:22:05 -0800 > > From: "NSK Problem Well Supv" <n 1617@conocophillips. com> > > To: bob_fleckenstein@admin, state, ak. us, tom_maunder@admin.state, ak. us, > > jim_regg@admin.state, ak. us > > CC: "n 1617" <n 1617@conocophillips. com> > > Tom, > > Here is the post patch MIT-IA data on 1H-07 (PTD# 182-084). > > We will take this well off the failed MIT report for May, but will report > > it for April. > > The 10-404 paperwork will follow. >> > > Please let me know if you have any questions > > MJ Loveland >> > > Problem Well Supervisor > > ConocoPhillips Alaska Inc. > > (907) 659-7224, 659-7043 > > (See attached file: MIT KRU 1H-07 04-15-03.xls) 2 of 3 6/3/2003 8:38 AM ,~.s: [Fwd: MIT KRU 1H-07 04-15-03.xls] > > Name: MIT KRU 1H-07 04-15-03.xls > > MIT KRU 1H-07 04-15-03.xls Type: EXCEL File (application/msexcel) > > Encoding: base64 >> >> >> > (See attached fi/e: tom_maunder, vcO Tom Maunder <tom maunder~admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 3 of 3 6/3~2003 8:38 AM MEMORANDUM State of Alaska jAlaska (~il and Gas Conservation Commission TO: Randy Reudrich : May 31, 2003 Commissioner ~ ~ ¢/,~ --) ~ f,~,~, .~,u ~UBJECT: Mechanical Integrity Tests THRU: Jim Regg '~,~--~/"i' ' ConocoPhillips Alaska Inc. P.I. Supervisor "~ ~ 1H Pad 1 H-07 FROM: Jeff Jones KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. 45 min. 60 Min. w,,,I~,-o~ I Type,ni.I s I T.V.D.I~ J Tubin~J 2300 J 2300 J 2300 J 2300 J 2300 J 2300 I,nter,,a,J 4 P.T.D.J 1820840 JTypetest~ P J TestpsiJ 1500 JCasin~lJ 1300J 3000 I 2825J 2745l 2680l 2645l P/F I P Notes: Test fluid 1.5 BBLS diesel. Post tubing patch MIT. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) May 31, 2003: I traveled t° ConocoPhillips Alaska's Iuc.'s (CPA/) WAG injection well 1H-07 to witness a 4 year IV[IT. Nina Woods was the CPAI representative for the test today. The pretest pressures were monitored and found to be stable and a one hour annulus pressm'e test was then performed with well 1H-07 meeting the criteria for a successful MIT. To fut'ther demonstrate mechanical integrity, the IA pressure was then reduced to 1300 psi and remained at this value during a five hour observationpe]'Jod. The one hour MIT was performed at the request of AOGCC Senior Petroleum Engineer, Tom Maunder. One well house inspection was conducted with no exceptions noted. Summary:I witnessed a successful IV[IT on CPArs WAG injection well 1H-07 in the Kuparuk River Field. One well house inspection, no exceptions noted. M.I.T.'s performed: 1_ Number of Failures: 0 Total Time during tests: 6._..~5 Attachments: wellbore schematic (1) cc: annular communication history (1) MIT report form 5/12/00 L.G. 2003-053 I_MIT_KRU_I H-07_jj.xls 6/19/2003 8CANNED LIUL r0 9 2_003 SSSV ~ (2O27-2O28. 0D:3,500) PKR (7675-7676, 0D:6.156) SLEEVE-C ('/781-7782, OD:2.810) SLEEVE-C (7874-7875, 0D:2,750) NIP (7899-7~, OD:Z875) TUBING (7877-7911, OD2.875, ID:2.441) (8015~023) (8031.8051) ConocoPhillips Alaska, Inc, KRU 1H-07 -- 1H-07 · APl: i00292075500 SSSV Type: NIPPLE Annular Fluid: Reference LO~l: Last Tag: 8127 Last Tag Date: 4/21/2001 Casing Strin9 - ALL STRINGS Description Size CONDUCTOR 16.000 SUR. CASING 10.750 PROD. CASING 7.000 Tubing 'String '.TUBING Size I Top 3,500 0 2.875 7877 Perforations Summary, Well Type:I INJ Odgl6/16/1982 Completion:l Last W/O: 1512411994 I Ref Log Date:~ , ' TD:18300 flKB Max Hole Ancjle:~ 54 de~] ~ 5200 Top 0 o 0 Bottom 7877 7911 Angle @ TS: Angle @ TD: Rev Reason: Last Update: TVD 6595 6624 ,32 dog @ ,.7696 30 dog @ 8300 Set DMY, pull plug, reset sleeve 2/'27/2003 Bottom WD I Wt I Grade I Thread 80 B0 I65-°° I H'40 I 2365 2341 I45.5° I K-~5 I 8274 6937 I 26.00 1'~-55 I I wt '1''GradeI Thread I 9.30 IL-S0 I EUEBRDAB-MOD I 6.50 I L-80 I EUEBRDMOD 7696-7755 6442-6492 Ic-4.c-3I 1 59 I s 16/20/19881 IPERF 12 1/8" EnerJet; Perfat30 I . I I I I I Idecj angle 7805 - 7830 6534 6555 C-1, NIT 25 4 IPERF 2 1/8" EnerJet 8015-8023 6713-6720 I A-5 I ', I 8 1121 I IPERF 121/8" EnerJet 8031 - 8051 ,6,727 - 6744 I A-4 I I 20 I 12 I I IPERF 121/S" EnerJet GasLiftMand~l:SNalveS ; ~;: ~;..: ':::; ':;:: :: ::;: ::::, st } MD ITVD'I'Man I Man I V I~fr I V Type I V OD I La{ch I Port I TRO'j' Date I Vlv IMr Type Run I 176121 63711Camco1' M v ! VI I I DMY11.5 IRK 10.000 Io 16/411994'1cmnt Inj6~i,0~'ilM~ndrel~N~l~eS: i i::i::il ::::ii;:.'::;:;;;:: ::: ::;: :;:: :;. ;:,:': :::i;;:!;::::; st I MD I TvD I Man I Man I V Mr, I V Type I V OD I LatCh I Port I Tm) I Dat. I V,. I I IMfr !Typo I I I I I I I Run J Cmnt 2 17689],~,4361CamcoI ~V~ I , I Dm I,'1'5 IRK 10.00,01 0 IS125/199flC~osed 3178001 65301Camcol rvtWM I , I DMY I 1.S I .RK 10.0001 0 ,12/24/2003l (1) 1. Closed w/EXT Pkg Other, (plugs~; equip:;~ilatc;l Oepth lWOl Ty~ / 2027, 12o211 sssv ] 7662 164,131 PBR. 7675 16424 I PER 7788 16520 I PKR ' 78s0 16598 I PKR 7899 16614 I NIP 7911 I 6624 I TTL Description ID Camco 'W-l' Landing .Nipple 2.812 Baker 3.000 Baker 'FHL' 2.992 Baker 'SAB-3' 3.250 Baker 'D' 3.250 Otis 'XN' N!pple NO GO 2.250 2.441 Other (plugs, ecluip.~ etc.) - SLEEVE Depth I TVD I Type / Description ID 7781 16514 1 N~P IAVABPLPORTEDNIPPLE 2.812 7781 I 6514 I SLEEVE-C/SET BPI 2/24/2003 2.370 7874 I 6593 I NIP /AVA BPL PORTED NIPPLE 2,750 7874 16593 I sLEEvE-C IsET BIll 2/13/2003 2.325 Fish:"iFISH:~ :::' ;,;:::: :: ;;:;;;:i;;:: ':;:::;;:: ;;.;. : :::!~:;:::: :::::i ;: ;:;;;,: ::: ::: :::'::' : Depth'! Description I Comment 8162 IVann Gun J Left in Hole after original perf Annular Communication History Well 1 H-07 Problem: T x IA communication Tubing leaks @ 7784' between top & middle packer (C sand) and 4054' Status: Currently SI > 07/06/01: witnessed) > 01/31/03: > 02/01/03: On Monthly > 02/13/03: 4-year MITIA Passed (State PE reports T x IA communication MITIA failed, reported to AOGCC. Reports. MI'I-I' failed - CMIT passed > 02/15/03: LDL found leaks @ 7784' (C sand) and 4054' (collar) > 02/19/03: AOGCC approval to inject during diagnostics > 02/21/03: Submitted 10-403 to AOGCC for tubing repair > 02/28/03: Received 10-403 Sundry Approval from AOGCC > 04/01/03: EL Set lower packer for patch > 04/11/03: PAtch complete ready to BOL > 04/15/03: MIT-IA to 3000 psi Planned Action: Received 10-403 Aprroval to patch. 1. PWS: Submit 10-4-4 post patch. 2. Report on Monthly Report until May patched to AOGCC. Date Comment 5/15/2003 4/15/2003 4/12/20O3 4/10/2003 4/1/2003 2/28/2003 2/24/2003 2/19/2003 2/15/2003 In mid April, you sent an MIT for 1H-07 after a patch was installed to remedy tubing x IA communication. 2, 30 min MITs were conducted. In each test, the total pressure loss measured was 8% of the applied test pressure and the pressure loss in the 2nd 15 minute observation period was less than that experienced in the first observation period. Although the presented test information meets that absolute criteria of a successful MIT, the pressure losses reported do not seem to indicate that the patch has truly repaired the tubing leak. It would have been interesting to see how the pressures behaved if the observation period had been lengthened to maybe an hour. In the tests presented, the higher annulus pressure appears to be equalizing with the lower tubing pressure although the delta is decreasing as the annulus pressure drops. Based on the annulus pressure prior to beginning the test, the tubing appears competent since a 1400 psi differential is present. We would appreciate if you would provide us with the T/I/O information for the well since the patch was installed and also make arrangements for an Inspector to witness an MIT. Tom Maunder, PE MIT-IA to 3000 psi, passed (post patch set). T/I/O = 2360/960/100. Initial IA FL NS. Pumped 1.5 bbls down IA to pressure up to 3000 psi. IA lost 150 psi in the first 15 minutes, and 90 psi in second 15 minutes. Tested again to check for stabilization. IA lost 130 psi in first 15 minutes, and 90 psi in second 15 minutes. For a total loss of 220 psi during 30 minute test. Final pressures; 2360/1000/100. TROUBLESHOOT COMMUNICATION LEAK AT K-3 PACK-OFF ASSEMBLY @ 4054'ELM, ABLE TO GET GOOD TEST ON TUBING & CASING, SET SLIP STOP ABOVE PACK-OFF @ 4018'WLM TAGGED ECLIPSE PACKER @ 4064'ELM, SET K-3 PACK-OFF ASSEMBLY @ SAME DEPTH, SET TUBING STOP @ 4018'WLM, TUBING /CASING TEST FAILED, JOB IN PROGRESS. SET ECLIPSE LOWER PACKER FOR PATCH WITH MID ELEMENT AT 4064' RKB (2.75" X 3') . Received 10-403 Sundry Aprroval from AOGCC to set a tubing patch. Approval #303-056 PULLED 2.31" XXN PLUG @ 7899' RKB. REPLACED 1.5" DV @ 7800' SLM W/EXTENDED pKG DV. DRIFTED TBG TO 4200' SLM W/20' X 2.76" DUMMY PATCH. You have approval to keep the well in water only service while awaiting the repairs. As noted, please put the well on the monthly report. Although you state the timing is "several weeks", we would hope that the repairs can be effected by early to mid April. Please keep us informed of the well work. Tom Maunder, PE AOGCC LEAK DETECTION LOG RAN W/PUMPING DN TBG, RET. UP IA TO FL ON 1H-13. WITH PLUG IN XXN @ 7785' ELMD. LOGGED BL TEMP TO PLUG @ 7885' ELMD. PUMP 0.75 BPM @ 2900 PSI, LOG LDL UP PASSES AND STOP CTSABOVE & BELOW ANOMALIES. FOUND 0.75 GALLON PER MIN. LEAK IN INJ. MAN @ 7784' MD AND MAIN LEAK OF 0.75 BPM IN COLLAR @ 4054' ELMD CORRELATED TO 5/30/2003 Page 1 of 2 03/19/03 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth N0.2705 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 2T-27 / C~ ~_ ~)~,~ TEMPERATURE LOG 01/01/03 1 1B-12 I~j~- ~)~ ~ NJECTION PROFILE 03/04/03 1 lC-135 ~-~,~l - ~ I<::~O INJECTION PROFILE 02/26/03 1 1D-12'-'/"-C~, ('/' t[~)'~q PRODUCTION PROFILE 03/05/03 1 1F-19 ! c~ (fl- ~ ) ?~.~. LEAK DETECTION LOG 02/08/03 1 1H-07 / ~ o ~7~'~ LEAK DETECTION LOG 02/15/03 1 SIGN L DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Conoco hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 21, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 Sundry Notice for ConocoPhillips Alaska, Inc., Well 1H-07 (PTD 1820840). The Sundry Notices regards a tubing patch to repair the well. Please call MJ Loveland or me at 907-659-7224 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachments: Well Log Schematic 10-403 SCANNED MAR tt 7 2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ / Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _X Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 767' FNL, 786' FEL, Sec. 33, T12N, R10E, UM At top of productive interval At effective depth At total depth 2906' FNL, 3981' FEL, Sec. 27, T12N, R10E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X (asp's 549561, 5979935) (asp's 551618, 5983087) 6. Datum elevation (DF or KB feet) RKB 85 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 H-07 9. Permitnumber~provalnumber 182-084 ~ 10. APInumber 50-029-20755 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 80' SUR. CASING 2280' PROD. CASING 8189' 8300 feet Plugs (measured) 6959 feet 8194 feet Junk (measured) 6867 feet Size Cemented Measured Depth True vertical Depth 16" 3t5 SxAS, 80' 80' 10-3/4" 250 sx AS ,, 1000 sx AS m 2365' 2341' 7" 962 sx Class G 8274' 6936' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 7696' - 7755', 7805' - 7830', 8015' - 8023', 8031' - 8051' 6442' - 6492', 6534' - 6555', 6713'- 6720', 6727'- 6744' ;,';" 3-1/2", 9.3#, L-80 Tbg @ 7877' MD; 2-7/8",6.5#, L-80 Tbg @ 7911' MD. '-- ,. ~; · , ~_.~' ?~; .. ,-'/ ~ ,..~[-~-~ ~' ~ BAKER 'FHL' @ 7675' MD; BAKER 'SAB-3' @ 7788' MD; BAKER 'D' @ 788q .IV,~,;:..~ ~[[ ~ ~' ..... ~., CAMCO 'W-I' LANDING @ 2027' MD. 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch _ 14. Estimated date for commencing operat/ion As soon as approved 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Service Water Injector Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~( ~ ~ Title: Problem Well Supervisor Jerr~Dethlefs FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrify _ B~P Test_ Location clearance _ ~' 4 Mechanical Integrity Test ~ Subsequent form required 10- (~ Approval no. Approved by order of the Commission Original Signed By _ ~llldy ~. ~ _m~l_ .~3~ ' Commissioner 2 5 2003 ,SCANNED ~AR 0 7 2003 Form 10-403 Rev 06/15/88 · Date SUBMIT IN TRIPLICATE ConocoPhillips Alaska, Inc. Kuparuk Well 1H-07 (PTD 1820840) SUNDRY NOTICE 10-403 TUBING REPAIR 02/21/2003 / This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk ~Well 1H-07 with a tubing patch. On February 1, 2003 the,~-)EC was notified of a failed MIT. Subsequent diagnostics show a hole in the tubing a/re/405~ MD. Pending the results of a tubing caliper, the plan is to patch the tubing with a 20' p~v~tanent patch. Following a successful MIT, the well /' will be returned to normal water injection. Should the caliper indicate inadequate tubing for patching, the AOGCC will be notified and an alternative plan discussed. REPAIR PLAN 1. Caliper the Tubing 2. Set 20' 3.5" permanent patch from 4044' - 4064' MD. 3. MIT as per AOGCC requirements (0.25 x TVD to packer) // 4. Submit 10-404 post repair /' NSK Problem Well Supervisor SCANNED MAR 0 7 2003 06/23/0! Cable S_~eed(C__S)_ (F/MN) Computed CCL (CCLC) 2oI PUMPING TEMPERATURE(WTEP) (DEGF) (2027-2028, 0D:3.500) PKR (7675-7676, 0D'6.156) SLEEVE-C (7781-7782, OD.2 810) (7805-7830) SLEEVE-C (7874-7875, OD:2.750) PLUG OD 2 310) TUBING (7877-7911, OD'2875, ID:2.441) (80158023) Perf ConocoPhillips Alaska, Inc. KRU 1H-07 -- IH-07 APl:J500292075500 SSSV Type: NIPPLE Annular Fluid:J Reference Log:J Last Tag: 8127 Last Tag Date: 4/21/2001 Well Type:J INJ Ong J6/16/1982 Completion:J Last W/O: J 5/24/1994 Ref Log Date:J TD: 8300 ftKB Max Hole Angle: 54 deg (~ 5200 Casing String - ALL STRINGS Description CONDUCTOR SUR, CASING PROD. CASING Tubing String · TUBING Size t Top 3.500 0 2.875 7877 Perforations Summary Interval TVD 7696 - 7755 6442 - 6492 7805 - 7830 6534 - 6555 8015-8023 6713-6720 8031 - 8051 6727 - 6744 Gas Lift Mandrels/Valves Angle @ TS: Angle @ TD: Rev Reason: Last Update 32 deg @ 7696 30 deg @ 8300 Set plug & Sleeves 2/14/2003 Size Top Boffom TVD Wt Grade 16.000 0 80 80 65.00 H-40 10.750 0 2365 2341 45.50 K-55 7.000 0 8274 6937 26.00 K-55 Thread Bottom J TVD Wt Grade Thread 7877J 6595 9.30 L-80 EUE 8RD AB-MOD 7911 6624 6,50 L-80 EUE 8RD MOD Zone Status Ft SPF Date Type Comment C-4,C-3 59 8 6/20/1988 IPERF 2 1/8" EnerJet; Perfat30 deg angle C-I,~NIT 25 4 IPERF 2 1/8" EnerJet D A-5 8 12 IPERF 2 1/8" EnerJet A-4 20 12 PERF 21/8 EnerJet StI MO I TVD I Man I Man I V Mfr I VTypeI v OD I Latch I Po. I TRO I Date I Vlv Mfr Type Run 637110amcol~w I o.ooo0 6/4/1994lcmnt Injection Mandrels/Valves St MD TVD Man Man VMfr VType VOD Latch Port TRO Date Vlv Mfr Type J Run J Cmnt 2 76891 6436 Camco MA/~ DMY 1.5 IRK 10.0001 o 15/25/19941Closed 3 7800 6530 Camco k/It, WI DMY 1.5 RK 0.000 0 ~11/20/199q C osed ID 2.812 3.000 Other (PiugS~ equip., etc.) - JEWELRY Depth/TVDI Type / 2027 2021 SSSV Camco'W-l' Landing N~pple 7662 I 6413 PBR Baker 7675 I 6424 I PKR Baker'FHL' 7788 16520 I PER IBaker'SAS-3' 7880 16598 I PER ISaker'D' 7899 6614 PLUG XXN PLUG SET2/13/2003 7899 6614 I NIP IOtis'XN' Nipple NO GO 7911 6624 TTL IOther (Plugs, equip,, etc.) - SLEEVE 7781 I 6514 NIP /AVA aPL PORTED NIPPLE 7781 16514 I SLEEVE-C/SET BPI 2/13/2003 7874 I 6593 I NIP /AVA BPL PORTED NIPPLE 7874 I 6593 I SLEEVE-C |SET BPI 2/13/2003 Fish - FISH Description 2.992 3 250 3.250 0.000 2.250 2.441 ID 2.812 2.370 Description 2.750 2.325 Depth Description 8162 Vann Gun Comment Left in Hole after original perf SCANNED ~AR 0 ? 2003 Re: Ku,paruk 1H-07 (182-084) Subject: Re: Kuparuk 1H-07;(182,084) Date: Wed, 19 Feb 2003 07:39:31 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: NSK Problem Well Supv <n1617@conocophillips.com> CC: Jim Regg <jim_regg@admin.state.ak.us> MJ and Jerry, You have approval to keep the well in water only service while awaiting the repairs. As noted, please put the well on the monthly report. Although, you state the timing is "several weeks", we would hope that the repairs can be effected by early to mid April. Please keep us informed of the well work. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: > Tom/Bob, > Attached is a copy of the passing Combo MIT ConocoPhillips completed on KRU > injection well 1H-07 (PTD (182-084). Subsequent to the MIT we ran a leak > detect log and discovered 2 leaks, one above the packer at 4054' and below > the top packer in a C sand injection mandrel > Current plans include dummying off the C sand leak and patching the tubing > leak @ 4054'. Most of the neededpatch equipment is on site, however, it > may take several weeks to get the work scheduled and completed. We would > like approval to continue injection until the well work is started. We > will carry the well on the Monthly failed MIT report and submit the > appropirate 10-403/404 forms as needed with the patching operation. > > MJ Loveland > ConocoPhillips > Problem Well Supervisor > 659-7224 > (See attached file: MIT KRU 1H-07 02-13-03.xls) Tom Maunder <tom maunder@admin.state.ak, us> 02/03/2003 12:57 PM To: NSK Problem Well Supv/PPCO@Phillips cc: Jim Regg <jirn_regg@admin.state. ak. us> Subject: Re: Kuparuk 1H-07 (182-084) > Thanks Jerry. I agree with your comment on the process time. I expected > you were on top of things. We will look forward > to hearing of the diagnostics mid month or so. Please look to reach > closure on this matter by the end of February. > Tom Maunder, PE > AOGCC > NSK Problem Well Supv wrote: > > > Tom: I am writing procedures right now for slickline, so I would think we > > should have results from setting plugs and pressure testing within a > couple > > weeks. Then depending on the leak rate and whether it appears to be ,SCANNED FEB 1 2083 1 of 3 2/19/2003 7:41 AM Re: Ku. paruk 1H-07 (182-084) packer > or tubing hole it will guide us on the next step. The process is never as > quick as we all would like, but I will keep you informed as we go. Thanks > for the feedback. > Jerry Dethlefs Tom Maunder <torn_maunder@admin.state. ak. us> 02/03/2003 11:49 AM ',, · > To: NSK Problem Well Supv/PPCO@Phillips > cc: Jim Regg <jim_regg@admin.state. ak. us>, Bob Fleckenstein <bob_fleckenstein@admin.state.ak. us> > Subject: Re: Kuparuk 1H-07 (182-084) > Jerry, > Thanks for the notification. You have approval to keep the well in service > while conducting the diagnostics. What sort of timing do you have in > mind?? Do you plan to have some information developed by mid February or so ?? Bob, please make an entry of the data base of this MIT failure. Tom Maunder NSK Problem Well Supv wrote: > Tom: Today (2/1/03) ConocoPhillips' Kuparuk injection well 1H-07 failed an > > MITIA. The well had been reported to have the IA tracking the tubing and > > would not stay bled down. A diagnostic MIT @ 3000 psi failed. Test > > pressures were (T/IlO): injecting 2350/2440/200 psi, initial MIT > > 2350/3000/200 psi, 15 minutes 2350/2440/200. Repressure to 3000 psi, > bleeds > > off 400 psi in 10 minutes. Our plan is to determine the leak path, > setting . ~, > > plugs or running Leak Detect Logs as needed. We would like to keep the > well > > on water injection service as needed during the evaluation process. > Please > > let me know if you concur with ourplans. Until the problem is resolved >we > > will report on the Monthly Failed MIT report (starting this month). >> > > Jerry Dethlefs > > Problem Well Supervisor > > ConocoPhillips Alaska > (See affached file: torn_maunder, vcf) (See attached file: tom_maunder, vcf) Name: MIT KRU 1H-07 02-13-03.xls MIT KRU 1H-07 02-13-03.xls Type: EXCEL File (application/msex~N~,;;D FEB ~ 1_ 20[]3 Encoding: base64 2. of 3 2/19/2003 7:41 AM MEMORANDUM TO: Julie Heusser'~/~--^~[b~ Commissioner r~L' State of Alaska Naska Oil and Gas Conservation Commission DATE: July 6, 2001 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder .~~_.,~37 Phillips Alaska Inc. P.I. Supervisor/,~,-~-~' ~_.-..-.. 1H Pad ~o\..~\~-~1, 1H-03, 1H-04, 1H-07, 1H-08, 1H-09 FROM: Jeff Jones KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. 'Wad. '~o3 I Type'~nj.J s .I T.V.D..I s20~ I Tuangl 25oo_ i 2so~ I~ ~oo' I 2soo I~=-a~l 4' p.T.D.I 1821150 ITypetestl P IT'll ~SS~ I ca~n~l sro I~e~o I, ~sr, o.I ~ol P/F I P. I Welll 11:-1~)4 I Type Inj'.l s' I 'f.V.O. ,! 6!85 I T~bing ! 2500' I, ~50~, "i 2500 I.~ 2500 l i,d~nmll 4 P.T.D.I...'~.82'm3Q ITypete,tl P IT~p~I ~.5,,6 I Casin01 900 I. 1770 I ~o I ~no I PA= i _P I No, es: I '"W,,,'I ~H.O? I T~nj.I 'S' I T;V~D. I 6424 I T~bikgi 2~-0' I '23.20' i' .2,320',1 2320' l i,,t~,l' 4'1 PiT.D:I1820840 ITypeteetl P . ITest. psil '~606 IC~,,! ~ I ~T,m I ~?,m I .~?,.o ! PA= I P_ I Nolm~: '1 wdq '~H-08 IT~.e~.j.I S I T.v.D;I 62O3 I'¥ubing'/' .~860' I' ~8~0 I 'ii~,0 1'~8~0 Iini~va~l 4 P.T.D?I '~820930 ITy~, ,test. I P IT~,t,P~I ~55~ I cas~nsl 860, 1,2350 123oo I 23OO' '1 PA: I P_ 'W,,,q '~H-o~ I~'),,e~.jll s.I T.V.O. t 6468 I Tubin~'l 2.~50 I' '2550 I' ~r, so" 1'~25s0 .l~nien~ll 4' .'P,T.D.I 1930290 ITypetestl P ITestpsil ~6~? I C~.01 670 I ~?~01 ~750'1~ '~740 I .PA= I P Type INJ. Flu~l Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other(describe in notes) Tsst's Oetails Friday, J~ul_v 6_s 2001: I traveled to Phillips Alaska Inc.'s 1H Pad and witnessed the 4-year MIT's on wells 1H-03, IH-04, 1H-07, 1H-0$ and 1H-09. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with all five wells passing the MIT's. Summary,: I witnessed successful 4;y~ar MIT's on PAI's wells 1H-03, 1H-04, 1H-07, 1H-0S, and 1H-09 in the Kuparuk River Field / KRU. M.I.T.'s performed: Attachments: Number of Failures: Total Time during tests: 3.5 hrs, c,c.'. MIT report form 5112100 L.G. MIT 1H Pad pg.2 KRU 7-6-01 JJ.xls 7/16/01 STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing X Alter casing Stimulate M Plugging Perforate _ ~.~ ~- Repair well O t h e r __ ..-- ~,-..~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 768' FNL, 788' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 2117' FSL, 988' FWL, Sec. 27, T12N, R10E, UM At effective depth 2283' FSL, 1151' FWL, Sec. 27, T12N, R10E, UM At total depth 2370' FSL, 1291' FWL, Sec. 27, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8300' 6959' feet feet Plugs (measured) 6. Datum elevation (DF or KB)"..-!7.,~ 85' RKB 55' PAD GL \ feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-7 9. Permit number/approval number 82-84 10. APl number 50-029-20755 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 81 94' true vertical 6867' feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 16" 315 Sx AS II 2365' 10-3/4" 250 sx AS II 1000 sx AS III 8274' 7" 962 sx Class G measured 7696'-7775', 7805'-7830', 8015'-8051' MD true vertical 6442'-6509', 6533'-6555', 6799', 6713'-6744' Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80 @ 7911' Packers and SSSV (type and measured depth) Measured depth True vertical depth 80' MD 80' TVD 2365' MD 2341' TVD 8274' MD 6936' TVD RECEIVED TVD JUN 1 4 1994 Alaska Oil & Gas Cons. Commission Anchorage Baker FHL Retrv Pkr @ 7675', Baker SAB-3' Perm Pkr @ 7789', Baker Model 'D' Perm Pkr @ 7880', Camco W-1 SLN @ 2028' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations X 16. Status of well classification as: Water Injector m Oil m Gas Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 05/17/89 Title Area Drilling Engineer Date ~. ~/~/~¢ SUBMIT IN DUPLICATE ARCO ALASKA INC. WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1H-07 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER DAILY OPERATIO~ PAGE: 1 ACCEPT: 05/19/94 10:00 SPUD: RELEASE: 05/25/94 12:00 OPERATION: DRLG RIG: WO/C RIG: NORDIC 1 05/20/94 (1) NORDIC 1 TD: 8300 PB: 8194 05/21/94 (2) NORDIC 1 TD: 8300 PB: 8194 05/22/94 (3) NORDIC 1 TD: 8300 PB: 8194 MONITOR WELL MW: 0.0 MOVE RIG F/3H PAD TO KCS PAD. WAIT ON ARCO DSO CREW CHANGE. MOVE RIG F/KCS PAD TO iH PAD. SPOT RIG OVER 1H-07. ACCEPT RIG @ 2200 HRS 05/19/94. PULL BPV, RU HARD LINES, TAKE ON SEAWATER. PRESS TEST RIG LINES TO 2000 PSI, HARD LINES TO 1000 PSI(OK). PMP SW DOWN TBG, TOOK RETURNS THROUGH ANN AND RIG CHOKE TO 1H FACILTIES, BULLHEAD 5 BBLS TO TBG TAIL, PICKLE FLOW TO iH FACILITIES, MONITOR SITP PRESS. EMW=9.0 PPG. POOH, LD TBG MW: 0.0 CIRC WELL W/SW @ 2 BPM & 200 PSI, SHUT DN, NO PRESS ON TBG OR ANN. OPEN WELL & MONITOR, WELL STATIC ON BOTH SIDE. SET BPV, ND TREE, REMOVE OLD STUDS F/TBG SPOOL, BTC IN HGR IN ROUGH COND, REDRESS SAME, NU DSA, MUD CROSS, 11" 5M DOUBLE BOP, 11" 5M ANN. FIN NU, PICKLED PROD FLOW W/60 BBLS DIESEL. PULL PBV & INSTALL TEST VALVE. PRETEST BOP'S, HAMMER UP LEAKING FLANGES. TEST BOPE TO 250/3000 PSI-2 FAILURES ON MANUAL CHOKE & OUTSIDE KILL LINE VALVE, REPAIR & RETEST-OK, ACCUM TEST-OK. BOLDS, PULL HGR TO FLOOR, HST WT 55K, CIRC BU @ 2000 STKS, GAS SURF. CLOSE HYDRIL, CIRC THROUGH CHOKE. OPEN HYDRIL, CIRC BU. OBSERVE WELL 15 MIN-OK. LD TBG HGR, POOH, LD TBG. CBU W/PKR MW: 0.0 LD 3-1/2" TBG, 244 JTS, 4 GLM, 1 SSSV, 1 PBR, 34 SS BANDS. RIG FLOOR TO PU FISHING TOOLS & BHA, FIN UNLOADING TBG F/PS. MU 5 3/4" GUIDE, OVERSHOT, W/4-1/4" GRAPPLE, TOP EX, TOP SUB, BUMPER JARS, SUPER JARS, 12 4-3/4" DC, PMP OUT SUB, ONE JT 3-1/2 DP. LOAD PIPE SHED W/3-1/2" DP, SLM. RIH W/FISHING BHA #1, PU DP. PU KELLY, TEST UPPER & LOWER KELLY VALVES TO 250/3000 PSI-OK. TAG FISH @ 7608' MD RKB, LATCH FISH, FREE FISH, ATTEMPT TO CIRC, LET PKR RELAX 30 MIN, WORK PIPE, SET KELLY BACK. WORK PIPE TO FREE RUBBER. CBU. RECEIVED JUN 1 4 1994 Alaska Oil & Gas Cons. Commission Anchorage WELL: API: PERMIT: 1H-07 PAGE: 2 05/23/94 ( 4) NORDIC 1 TD: 8300 PB: 8194 05/24/94 ( 5) NORDIC 1 TD: 8300 PB: 8194 POOH, LD DP MW: 0.0 CBU, VENT THROUGH GAS BUSTER LAST 2500 STKS. CIRC THROUGH FLOW LINE ADDITIONAL 1000 STKS. CLEAN SW BACK, WELL STATIC. POH W/FISH @ SLOW SPEED TO MINIMIZE SWABBING. LD FISH, BREAK DOWN & LOAD OUT FISHING TOOLS. RECOVERED COMPLETE TAIL ASSY, RE-ENTRY GUIDE, 2 JTS 3-1/2" TBG, CAMCO D NIPPLE, BROWN HH-1 PKR. MU RERUN 6-1/8" ROCK BIT & RIH FOR CLEAN OUT. PU 3-1/2" DP, TAG FILL @ 8050' MD RKB. WASH & REAM F/8050'-8173' MD, TOP OF FISH. CIRC, PMP HI VIS SWEEP W/40 BBLS, FOLLOWED BY ANOTHER 25 BBLS 15 MIN LATER, CIRC HOLE CLEAN. WORK & ROTATE PIPE W/CIRC. BLOW DN & STAND BACK KELLY, POOH, LD DP FOR TBG. TESTING TBG & PKR MW: 0.0 PERFORM RIG SERV. FIN LD 3-1/2" DP & 12 4-3/4" DC. RU SWS, TEST LUB TO 1500 PSI. MU & RUN JB, 5.875" GAUGE RING TO 7890'-0K. POH. PU BAKER MODEL "D" 7" X 2-7/8" PERM PKR W/3.25" ID SEALBORE & 4.35' EXT. RIH & TIE IN, SET PKR @ 7866' POH, RD. FIN LOADING PIPE SHED W/3-1/2" 9.3# L-80 EUE MOD TBG & COMPLETION TOOLS. SLIP & CUT DRILL LINE 50'. STRAP & GIH, PU COMPLETION ASSY, PER TBG DETAIL, RAN 240 JTS. TAG BTM PKR, SPACE OUT W/1 JT. MU HGR, LAND TBG, DROP BALL, SET PKRS. 05/25/94 ( 6) NORDIC 1 TD: 8300 PB: 8194 FINAL RPT-RIG RELEASED MW: 0.0 TBG WILL NOT TEST-LOST 300 PSI IN 10 MIN. WAIT ON SL UNIT. RU SL. RIH, PULL CIRC VALVE FROM GLM @ 7612'. RIH W/i-i/2" DUMMY VALVE. ATTEMPT TO SET DUMMY. LOST DUMMY DOWN HOLE. RIH, FISH OUT 1-1/2" DUMMMY VALVE. RE-RUN DUMMY VALVE & SET DUMMY @ 7612'. TEST TBG TO 1000 PSI-OK. SHEAR OFF OF DUMMY. POOH W/WL. TEST ANN TO 2500 PSI F/30 MIN-OK. RIH, PULL DUMMY VALVE. RIH, SET CIRC VALVE IN GLM #1 @ 7615'. POOH. RD SL UNIT. TEST TBG TO 2500 PSI F/15 MIN. SHEAR PBR @ 14K OVER STRING WT. STRING PU 58K. STRING SO WT 46K. SET BPV. ND 11" BOP STACK. NU MCEVOY 11" 3000# X 3-1/8" 5000# ADAPTER SPOOL & MCEVOY 5000 PSI TREE-TEST PACK-OFF TO 3000 PSI F/15 MIN-OK. TEST TREE TO 250/3000 PSI-OK. FREEZE PROTECT ANN W/12 BBL OF DIESEL. BULLHEAD 4 BBLS DIESEL DN TBG @ 1/2 BPM 2000 PSI FOR FREEZE PROTECTION. SITP=O SICP=0. DRAIN LINES. SECURE WELL. RIG RELEASED @ 0000 HRS 05/25/94. SIGNATURE: DATE: RECEIVED JUN 1 4 1994 Amska OJJ & G~s Oons. OommJssJo. Anchorage Alaska Oil Gas Conservation Cammission 300i Porcupine Drive Anchorage, Alasl(a 995111-31 907-279-1433 To: ~e.' Permit # Thc following data is hereby acknowledged as being reEcived: ~' Received by: Dated: Copy sent to sender: L .l ~I YeS f~.o ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 28, 1994 Mr. David W. Johnston, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' On January 25, 1994 you approved ARCO's request for a varianc'e on well 1H-07 (copy attached), but noted that "a plan for corrective action must also be approved by the Commission". ARCO plans to repair this well with a rig workover and upon completion the well will be in nearly new condition. P. S. White Senior Engineer Kuparuk Petroleum Engineering 0 5 ~994 Gas Cons. c0mm'iss'~o~ AR3B-6003-93 242-2603 WALTER J. HICKEL, GOI/ERNOFI ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3392 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 25, 1994 Mr. P. S. White ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River 1H-07 - 10-403 request for variance Dear Mr. White: Per Rule 7 of Area Injection Order (AIO) No. 2 as amended by Administrative Approval AIO 2.2, injection may continue but a plan for corrective action must also be approved by the Commission. Timely notice will be expected in the future S' Chairman RECEIVED MAR 0 5 1994 Alaska 0il & (~as Cons. Commission Anchorage ARCO Alaska, Inc.(~? Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 28, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~2~ 1H-07 Other c/o¢151 3G-04 Stimulate ~y~--O ~ 3Q-02 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering AR3B-6003"93 242-2603 STATE OF ALASKA (' ,N,ASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing ~ Alter casing 2. Name of Operator Stimulate Plugging Repair well R10E, UM R10E~ UM 00 feet 59 feet ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 768' FNL, 788' FEL, Sec 33, T12N, R10E, UM At top of productive interval 2117' FSL, 988' FWL, Sec 27, T12N, R10E, UM At effective depth 2343' FSL, 1246' FWL, Sec 27, T12N, At total depth 2370' FSL~ 1291' FWL~ Sec 27~ T12N~ 12. Present well condition summary Total Depth: measured 8 3 true vertical 6 9 Type of Well: Development _ Exploratory _ Stratigraphic Service X Perforate ~,~. Other X ~)1~1/~--,'~ 6. Datum elevation (DF or KB) RKB 85 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 H-07 9. Permit number/approval number 82-84/94-01 5 10. APl number 5 0-029-20755 11. Field/Pool Kuparuk River Field/ Oil p.ool Plugs (measured) None Effective depth: measured 81 9 4 feet true vertical 6867 feet Junk (measured) Vann Gun @ 8162' Casing Length Size Structural Conductor 80' 1 6" Surface 2333' 1 0-3/4" Intermediate Production 8 24 0' 7" Liner Perforation depth: measured 7696'-7755', true vertical 6442'-6492', Cemented Measured depth 315 SX AS II 80' 1000 SX AS III & 2367' 250 SX AS II 962 SX Class G & 82 7 4' 250 SX AS II 7805'-7830', 8015'-8023', 8031 '-8051' 6533'-6555', 6713'-6720', 6727'-6744' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7642' Packers and SSSV (type and measured depth) PKR: Brown HH-1 @ 7577'; SSSV: Camco TRDP-1AE w/WRDP @ 1936' True vertical depth 80' 2342' 6936' ECEIVEr -3 1994 Gas Cons. Commas, 13. Stimulation or cement squeeze summary Ran injection tests, determined packer has moved, freeze protected well on 2/16/94. Intervals treated (measured) N/A Treatment description including volumes used and final pressure Ran tests for 11 days, varying injection pressure, final iniection pressure was 2300 psi. 14. Representative Daily Averaae Production or Injection I;)ata Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X ~OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 2600 ,~ ...... 2600 0 0 2600 ~' 2600 16. Status of wellclassification as: Tubing Pressure 2300 2300 Oil _ Gas Suspended Service H20 Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. :Signed ~~J, ~ Title Senior Enflineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE · ...................................................... KDOS" MORNING~" WELz. L "REPORT's'F-OR' 02/06/94 I'FT~"STATUg"~IOOR %==~12000"~T'S I DA] W Z S ................. ; ................................................... ~"~ OAS ........ OAS: E-0 -T--CHOKE ............................................. 7" ...... 10" ........ INd' .......... OPT ..... OPT - ......... H-M-- L N' 'A'?,.~..tOR "~-. ...................... MC ~:H2S .... CSO~T~-'cSO ..... METER VO~ ....... RATE ..... O~ ............ R I~ - b-.--E--~T,~~;..xA~.TP &~.READ l N~ ..... MSt ¢'~-+ MSC FD--.:R OOT~-~:S--N'~ --:..1 ..... '2 5, .... 1'2 5'--8 5.~'': "'.~;"'~" O' 6 B-TS .... 176 .--334- -126 ...... 2- 25-1300 520 10 B PR'-~':' 1'76 314' "89:~' ':'0.~' ...... O' 600 320 11..-( P ......... 1-.18 .... .-32 16.-B-P 108 82--.-,-,.',~-..4..~-~.',~ ..... 5--,i300.~ .............. 640'.'.-~ ............................. 0 17 B P'R ' 176' '300 29 0 5 625 640 " 0 2.1 C PR ...... '. 1'76 ...... 327 ........9"7"':'":' ..... :'1 ............... 0 ' ',5R5 ..... 140 ................ 0 0--'t"356'"~--1' 534'''~''' ..... 6:-i"-'"' 0000 0 ............. '0 ................. 0 'r'"' ...... 0:'0 ............. 0000 0 ........... 663 ........i 570 ........ 4.: '6 .......... 0000 0 4.01 ' , 0 '0. 0'' 0000 0 ............. 0 '"'/'? 1686 .......... 2. 0'.-":":':" 0000.7;~ 0:.-~-0000.~ 0.: ..0-?:.-.,,?...-:~ 400 -;, 1 ~35 . ~,, ... ..:. ,L ....... 0':'~:?'"0.' 0 '"'¥-'"' 0000 5~3 ...... 505~ ...... ~. 8 · - 0 -' 0":<" O. 0":'","":0000' iC ii DATA ..... : ...... ~.__. ..... -' .~..~ ....... . ...... -- ;'~.~..~ ...... . ..... W Z S ................. , ....................... WATER .- RECt'"tD ..... '-:~--'-GAS ,-:-- .......................... C ....... E 0 · T" CHOKE -7" t. 0 ..... Ibld INd' IN,.) H M ',- L-'-,N-~?-A. ~OR ....... I.i',t.d ...................... C;' S C-,- .... GS~'-'---ivlE:'IF ER .............. VOL: .......... IR'A'I'~E ........ ':" VOL: .... .... L~''"'E''?~T:~'~%':r'' ........ P S I". ....... 1 !S I?r~"'' P'S I~::'~R E'AD I'NQ .......... :":'B BLS ..... B'WP D""~"~:r~MMSC F~":'?~';'"?':"" S &.~ .. --- .-/.~,'.,,. .: :, - . . ! - .. ~.p W.~,:~,,, · .... 3"C .:,..,.-! 0".";'~'-1937.'.~ ........ "'19B7~ .......OrOOO,.:~T~".'~-,O000- -x'O .......... ~(~'B PI,,,I.-.~-.-~~,~.~2B --'14.4. ........... -9.50--.'I ....... 75, ..................... ; ............. 0 ........ ,51-77 50,6'9~.z..~-.0.. O00.;-,.-z-.:,-O000 ...... 0 ........ PN -,50 'i-gzL o '1-.4-s'- 1' 20. 'T5 "-6 0 :-..",041 0.- o. 000 - 8 B----.PW .............. i-7.&-..;~209 ..... 14.4. ............. ~.00 .......... ~.~ .......... 0 ,.68',B,'t. - ....56'95~ O, 000 ......... 0000 ..... 0 ............ '~ I ,1'4,4, ........... 760 ...... P-.3~O ~64.~ 0:' 000' '-"?"'-0000 ..... 0 18' i ':'0000; ...... 0 ........... ~ 20 C PW '100'~2227 1'4.4 ....... :'"';: 0'""' 160 0 ....... 304,9 :~868~ ..... 0/000 .... ?~:'0000 '"0 2~ ~-PW ....... ~.,-176.--~20 ....... 14.3 ............ ~80 ..... 0 ........ 0 '-33~7 ......... 3096~ ...... O; 000 ............ 0000 .......0 ................... T'OTA~S:- ................... ~,: ...... ~ ..... ~ ....... SWI .................. O.----+..-,PW-I:: ..... 28~78-~= ............ ~8578 25555 0;000 ~ELL'~'SHOU~D"." B E~;:' W'I'DE-''~'' OPEN ~'.R EQAR DEESS' 'OP~:THE f' L~I STED R EC OMMENDED ? R ATE':_ . ........... ,-.:; ..... .... ................................... . ...... ................ ..: ........................ . .... ................................... ..] . . ' ............. . ...; ~';~.,.,, ALASKA OIL AND GAS CONSERVATION COM~IISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 25, 1994 Mr. P. S. White ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River 1H-07 - 10-403 request for variance Dear Mr. White: Per Rule 7 of Area Injection Order (AIO) No. 2 as amended by Administrative Approval AIO 2.2, injection may continue but a plan for corrective action must also be approved by the Commission. Timely notice will be expected in the future S' Chairman ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 13, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive 'Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action 1 H-07 Variance Anticipated Start Date 2/94- 9/94 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments R£C£1V£D JAN 1 8 1994 Oil & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE Of ALASKA ~ A OILAND GAS CONSERVATION COMMI ,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well _ Plugging_ Time extension _ Stimulate__ Change approved program __ Pull tubing __ Variance ~ Perforate __ Other __ - 2. Name of Operator 15, Type of Well: 6. Datum elevation (DF or KB) I Development _ ARCO Alaska. Inc. ~ Exploratory _ RKB 85 feet 3. Address ~ Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 ~ Service X Kuparuk River Unit .. 4. Location of well at surface 768' FNL, 788' FEL, SEC 33, T12N, R10E, UM At top of productive interval 2117' FSL, 988' FWL, SEC 27, T12N, R10E, UM At effective depth 2343' FSL, 1246' FWL, SEC 27, T12N, R10E, UM At total depth 2370' FSL~ 1291' FWL~ SEC 27~ T12N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8 3 0 0 feet true vertical 6 9 5 9 Plugs (measured) feet 8. Well number 1H-07 9. Permit number 82-84 10. APl number __50-029-20755 11. Field/Pool Kuparuk River Oil Field/Pool None Effective depth: measured 8 1 9 4 true vertical 6 8 6 7 feet Junk (measured) feet CaSing Length Size Structural Conductor 8 0' 1 6" Surface 2 3 3 3' 1 0- 3 / 4" Intermediate Production 8 2 4 0' 7" Liner Perforation depth: measured 7696'-7755', true vertical 6442'-6492', Cemented 315 Sx AS II 1000 Sx AS III & 250 Sx AS II 962 Sx Class G & 250 Sx AS II 7805'-7830', 8015'-8023' 6533'-6555', 6713'-6720', Vann Gun @ 8162' Measured depth 80' 2367' 8274' 8031'-8051' 6727'-6744' True vertical depth 80' 2342' 6936' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 @ 7642' Packers and SSSV (type and measured depth) Pkr: Brown HH-1 @ 7577'; SSSV: Camco TRDP-1AE w/WRDP @ 1936' 13. Attachments Description summary of proposal .X Detailed operation program Continue water injection into well. RECEIVED JAN 1 8 1994 A~ska Oil & Gas Cons. Commis: 14. Estimated date for commencing operation Februarv 1994 - September 1994 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil m Gas , , Suspended, Service Water Injector 17. I hereby,~"~ify that tt~ foregoing is true and correct to the best of my knowledge. Si~ned' '"~'"~/~~, ~fl~-/~ ,Title Sr. Engineer FOR COMMISSION USE ONLY Date/'" Conditions of approval: Plug integrity Mechanical Integrity Test Notify Commission so representative may witness BOP Test Location clearance _ Subsequent form require 10- '"'- Approved by order of the Commission Form 10-403 Rev 06/15/88 Original David W. J0hnsm JApproval No. Approved Copy Returned Commissioner Date SUBMIT IN TRIPLICATE ion Attachment 1 Request for Variance Kuparuk Well 1H-07 As per Area Injection Order No. 2, Rule 7, ARCO Alaska, Inc. is hereby notifying the Commission of pressure communication between the tubing and casing in Water Injection Well 1H-07. As set forth in the Rule 7, ARCO Alaska, Inc. is requesting Commission approval to inject water into this well. As found in Area Injection Order No. 2, the aquifers described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit are exempted for Class II injection activities by 40 CFR 147.102(b) (3) and 20 AAC 25.440(c). As such, injection will not endanger any Underground Source of Drinking Water (USDW). A brief summary of how the communication was detected is presented below. Permission (approval number 93-125) was granted by the AOGCC on May 26, 1993 to convert well 1H-07 to water injection service. On ~~ ~ during a wireline job to pull the GLV's, tubing/casing communication was noted. Seals on the tree were tested June 12 and held, suggesting the location of the communication to be somewhere downhole. On June 13, a pump rate test was conducted on the tubing to establish the extent of the communication and intermittent injection began on July 1 in an effort to determine its location. Finally, a spinner survey was performed on July 12, which pinpointed the location to the top of the PBR. The well was shut- in at that point and freeze protected on August 3. ARCO Alaska, Inc. would like to be able to test and inject into the well as circumstances arise. The 7" and 10" casing pressures on the well indicate that there are no external casing leaks and injection fluids are confined to the Kuparuk River Sands. Casing and tubing pressures will continue to be monitored and reported as per Area Injection Order No. 2, Rule 4 to ensure that the casing pressure does not exceed 70% of the casing's minimum yield strength. RECEIVED JAN ! 8 1994 A~aska Oi~ & Gas Cons. Commission Anchorage ARCO Alaska, Inc(~ Post Office'~,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION E- 15 Perforate ,1 E-15 Stimulate '1H-07 Other -, 1H-08 Other --1 H- 15 Stimulate q.~~ H-22· Stimulate H-22 Other ~ut--'~c~ 1Q-08 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Sr. Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C LO~ STATE OF ALASKA ( AND GAS CONSERVATE)N ~~~ ~ REPORT OF SUNDRY WELL OPERATIONS ©/' 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development _ iARCO Alaska. In~, Exploratory _ RKB ~5 feet !3. Address Stratigraphic _ 7. Unit or Property name i P. O. Box 100360, Anchorage, AK 99510 Se~ce ;K Kuparuk River Unit 4. Location of well at surface 8. Well number 768' FNL, 788' FEL, Sec 33, T12N, R10E, UM 1H-07 At top of productive interval 9. Permit number/approval number 2117' FSL, 988' FWL, Sec 27, T12N, R10E, UM 82-84/93-125 At effective depth 10. APl number 2343' FSL, 1246' FWL, Sec 27, T12N, R10E, UM 50-029-20755 At total depth 11. Field/Pool 2370' FSL~ 1291' FWLr Sec 27~ T12Nr R10E~ UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8 3 0 0 feet Plugs (measured) None true vertical 6959 feet Effective depth: measured 81 94 feet Junk (measured) Vann Gun @ 8162' true vertical 6 8 6 7 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' I 6" 315 SX AS II 80' 80' Surface 2333' I 0-3/4" 1000 SX AS III & 2367' 2342' Intermediate 250 SX AS II Production 8 24 0' 7" 962 SX Class G & 82 7 4' 6 93 6' Liner 250 SX AS II Perforation depth: measured 7696'-7755', 7805'-7830', 8015'-8023', 8031 '-8051' true vertical 6442'-6492', 6533'-6555', 6713'-6720', 6727'-6744' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7642' Packers and SSSV (type and measured depth) PKR: Brown HH-1 ~ 7577'; SSSV' Camco TRDP-1AE wANRDP @ 1936' 13. Stimulation or cement squeeze summary Converted well from oil producer to water injector on 7/1/93, c~,:.i-' 2 Intervals treated (measured) N/A Alaska Oil & (:-;as Co~s. Treatment description including volumes used and final pressure N/A 14, Reoresentative Daily Averaae Production or In_iection Dat.~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 475 950 0 1600 160 Subse(:luent to operation 0 0 2000 1500 _~_~50 15, Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Water Injector ~ Daily Report of Well Operations X Oil ~ Gas Suspended Service 17, I hereby ce/~ that the foregoing is true and correct to the best of my knowledge, Signed i' Title Senior Engineer Date '""~f'" · Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE KDGS MORNING WELL REPORT FOR 07/01/93 DRILLSITE 1H PAQE 1 PRODUCTION WELL STATUS W Z S E 0 T CHOKE L N A OR L E T % FTP FTT 1 A PR 176 173 35 2 B PR 176 114 38 6 B PR 176 125 118 "OTALS: 7" 10" WC H2S CSG CSG % PPM PSI PSI 0 0 700 200 0 0 850 180 0 25 1150 960 GAS LIFT STATUS IGOR = 9000 Si DAT~ GAS GAS INJ OPT OPT METER VOL RATE GL READINQ MSCF MSCFD ROOTS H M [ R I I S N E 0 467 0 0.0 0 396 0 0.0 0 142 1208 2.0 1005 1208 0000 0000 0000 INdECTION WELL STATUS INdECTION VOLUMES SI DATA W Z S E 0 T CHOKE 7" 10" L N A OR IN,] CSG CSG L E T % PSI FTT PSI PSI 3 B SI 0 OM OM 830 E~pO 4 B PW 100 2347 144 1510 750 7 B SI 0 OM OM 780 320 8 B PW 100 2268 144 1300 850 WATER RECMD GAS INJ INd INd METER VOL RATE VOL READING BBLS BWPD MMSCF 0 0 O* 0.000 0 6076 7858* 0.000 0 164 O* 0.000 0 10129 18083* 0.000 OTALS: SWI: 0 + PWI: 16369 = 16369 25941 0.000 C H M 0 R I D S N E 2400 62 0000 0 2400 62 0000 0 ,N ~ AFTER THE RECOMMENDED WATER INdECTION RATE 'INDICATES THAT THE iLL SHOULD BE WIDE OPEN REQARDLESS OF THE LISTED RECOMMENDED RATE, APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ OperatiOn Shutdown _ Re-enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate Change approved program ~ Pull tubing _ Variance _ Perforate _ Other 5. Type of Well: Development 2. Name of Operator ARCO Alaska. Inc. Exploratory RKB 85 leet 3. Address P. O. Box 100360, Anchorage, AK 99510 Stratigraphic Service 4. Location of well at surface 768' FNL, 788' FEL, SEC 33, T12N, R10E, UM At top of productive interval 2117' FSL, 988' FWL, SEC 27, T12N, R10E, UM At effective depth 2343' FSL, 1246' FWL, SEC 27, T12N, R10E, UM At total depth 2370' FSL, 1291' FWL, SEC 27, T12N, R10E, UM ¸12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 8 0' Surface 2 3 3 3' Intermediate Production Liner Perforation depth: 8240' 83OO 6959 8194 6867 Size 1 6" 1 0-3/4" 7" feet feet 13. Convert well from oil producer to water injector. 14. Estimated date for commencing operation June. 1993 16. If proposal was verbally approved Name of approver Date approVed Plugs (measured) feet Junk (measured) feet Cemented 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-07 9. Permit number 82-84 10. APl number 50-029-20755 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool None Vann Gun @ 8162' MeaSured depth True vertical depth 315 Sx AS II 80' 80' 1000 Sx AS III & 2367' 2342' 250 Sx AS II 962 Sx Class G & 8 2 7 4' 6 93 6' 250 Sx AS II measured 7696'-7755', 7805'-7830', 8015'-8023', true Vertical 6442'-6492', 6533'-6555', 6713'-6720' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 @ 7642' Packers and SSSV (type and measured depth) Pkr: Brown HH-1 @ 7577'; SSSV: Camco TRDP-1AE w/WRDP @ 1936' Attachments Description summary of proposal X.~ Detailed operation program 8031 '-8051' , 6727'-6744' RECEIVED 15. Status of well classification as: Oil Gas Service M AY 1 199T Alaska 0il & Gas Cons. Anchorage BOP sketch Suspended Water Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C'~u~' ~ Title Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BO/P Test_ Location clearance__ Mechanical Integrity Testy_ Subsequent form require 10, ~' ~ ~ Original Signed By David W. Johnston Approved by order of the Commission Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE -~pproved Copy Returned Attachment 1 Injecti°n(~ '~;onversion to Water ' Kuparuk Well 1H-07 ARCO Alaska requests approval to convert Well 1H-07 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6442' and 6744'. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECEIVED MAY 2 1 199;5 Alaska 0ii & Gas Cons. C, ommissio~ Anchorage STATE OF ALASKA (~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Operation Shutdown m Pull tubing Alter casing Stimulate __ Plugging , Perforate .~X Repair well Pull tubing Other~ 2. Name of Operator ARI~Q Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 768' FNL, 788' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 2117' FSL, 988' FWL, Sec. 27, T12N, R10E, UM At effective depth 2283' FSL, 1151' FWL, Sec. 27, T12N, R10E, UM At total depth 2370' FSL~ 1291' FWL, Sec. 27, T12N, R10E, UM 12. Present well condition summary Total Depth: measured 81 9 4' feet true vertical 6867' feet Plugs (measured) n/a 6. Datum elevation (DF or KB) 85' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1 H-07 -Producer 9. Permit number/approval number 8-474 10, APl number 50-029-20755 11, Field/Pool Kuparuk River Field/Pool feet Effective depth: measured 7 9 75' feet true vertical 6679' feet Junk (measured) n/a Casing Length Size Structural Conductor 8 0' 1 6" Surface 2172' 10 Intermediate Production 8697' 7" Liner Perforation depth: measured 7696'-7755', true vertical 6442'-6492', 3/4" Cemented Measured depth True vertical depth +-200 CF 1 1 0' 1 1 0' 1200 Sx 2200' 2200' 1000 Sx Class G 8 723' 71 6 6' 7805'-7830', 8015'-8023', 8031'-8051' MD 6533'-6555', 6713'-6720', 6727'-6744' TVD Tubing (size, grade, and measured depth) 3 1/2" 9.2#, J-55 @ 7642' Packers and SSSV (type and measured depth) Brown HH-1 @ 7577' MD, Camco WRDP @ 1936' MD 13. Stimulation or cement squeeze summary n/a Intervals treated (measured) n/a Treatment description including volumes used and final pressure n/a 14. Reoresentative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 490 2447 3 200 632 2817 0 200 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil ~ Gas ....... Suspended m Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 06/15/88 Title Sr. Operations Engineer Date ~-/~-//~ ~ SUBMIT IN DOPLICATE Subsidiary of Atlantic Richfield Compare CONYRACTORC REMARKS ]~,~o. o,s~,cm- ~m^~ OPERATION AT Rg;POI~T I-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp. Chill Factor I Visibility !Wind Vel. Report ] 'F . *FI' miles AlaSKa, InC ,~v· , Subsidiary of Atlantic Richfield Compar, 'WELL /H'? ( IPBDT I CONTRACTBR . REMARKS ,/..j .~ /~ ,.. ~ ~r '" IFIELD - DISTRICT - ST,~T.E~ CP -/ //¥Y l) OPEFIA-T[ON AT REI~OI~r tl~l'lE - WELL SERVICE REPOR' IDAYS iOATE . _, ~0° ' Z.. I'"1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp. Chill Factor I Visibility Wind Vel. Report I OF °FI miles I Signe~ kn°tsl Sub$1dl&ry of Atlantic Richfield Compa WELL CONT%CTOR REMARKS ~'~t.~ ~ ~~ ' FIELD - DISTRICT. STATI~ C_OF-I / iOpER~TION AT hEiS~R*l'-Tl~E II I.,I,.I. VI.,, ! II IVI"" Ilar Vrl IDAYS I DATE KUPARUK OPERATIONS ENGINEP..HIN~': - . -~. + ~ IO1~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~IIVV r,i i &4 ~,;t i~tA ~ Subsidiary of Atlantic Richfield Compa Y CONTRACTOR IOPERATION A'T F(EPOI~T I I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK REMARKS CONTINUED: DESCRIPTION DAILY ACCU M. TOTAL CAMCO OTIS , DRESSER-ATLAS , DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts I Diesel Methanol Supervision ' . Pre. Job Safety Meeting ., AFE TOTAL FIELD ESTIMATE ~r ~..~ ~ c~ o ..... _ $ t~,..~., k-~. ALAS OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ~C0 ~!aska~ !n_c_ 3. Address P. 0. Box 100360: ^nchoraoe. Alaska 4. Location of well at surface 99510 768' FNL, 788' FEL, Sec. 33, T12N, RIOE, UM At top of productive interval 2117' FSL, 988' FWL, Sec. 27, T12N, RIOE, UM At effective depth 2283' FSL, 1151' FWL, Sec. 27, T12N, RIOE, UM At total depth 2370' FSL. 1291' FWL. Sec. 27. T12N, RIOE. UM 11. Present well condition summary Total depth: measured 8194' feet Plugs (measured) true vertical 6867' feet 8121' Effective depth: measured 6804' feet true vertical feet Junk (measured) 5. Datum elevation (DF or KB) p.~_R 8 5 Feet 6. Unit or Property name KuDaruk River Unit 7. Well number 111 """/ r~,_A ,J ...... 8. appro*~'l-r~ur~l~eUr7::~.?~V Pe~ i:.-..? t 2-2-2--~ - 9. APl number 50- 0_~9-__.0755 10. Pool KuDaruk Riwr Oil Pool Casing Length Size Cemented Structural 80' 16" 200 CF Conductor 2172' 10.75" 1200 SX Surface Intermediate 8697' 7" 1000 SX Production Liner Perforation depth: Measured depth True Vertical depth 110' 110' 2200' 2200' 8723' 7166' measu red 7805'- 7830' 8015'- 8023' 8031' - 8051' - 6306' 6799' - 6806' 6813' - 6830' true vertical 6533' -6555' ' 6799' Tubing (size, grade and measured depth) 4 SPF 8 SPF 3-1/2", 9.2#/J-55 @ 7642' MD Packers and SSSV (type and measured depth) Brown HH1 Ca 7577'; C. amcn WRBP 0 lg36' 12. Stimulation or cement squeeze summary Perforated: 7696' - 7720' @ Intervals treated (measured) 7720' - 7735' @ 735 , _ ' 7755 Treatment description including volumes used and final pr'es~dre 13. Prior to well operation Subsequent to operation Representative Daily Average Production o.r Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 490 2500 0 500 170 630 2300 0 500 170 Tubing Pressure 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge //~~ ~xz~Ld~/j~ ~¢ Sr. Operations Engineer Signed " Title Form 10-404 Rev. '12-1-85 Date q/~' f'/~l~r Submit in Duplicate WELL ARCO Alaska, In9 ~ Subsidiary of Atlantic Richfield Comp~ CONT%CTOR IFIELD - DISTRICT- STATE OPERATION ~,m hEJS(~RT-TI~E WELL SERVICE REPOR S $t J'-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W"'h'r i'r°m"' Is""' ~""'°r I v'""""' Iw'n"v'"..,.or, ',=',=m,,. ARCO Alaska, Incr ~ ' Subsidiary of Atlantic Richfield CompanK WELL I H'7 IiPBDT CONTRACTORC , . ,EMARKS IFIELD . DISTRICT . ~TATE OPERATION AT R~POF~T TI~ WELL SERVICE REPORT IDAYS ID. ATE .g, -/I ' ~_ £ 2, 30 D5/oH/,., ~s ~- C~s+ r'-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport I Temp. Chill Factor I Visibility IWind Vel. "F "F miles ARCO Alaska, lng- <} Subsidla~/of Atlantic Richfield Compa& WELL SERVICE REPOR' WELL IPBDT /./-/-7 CONTRACTOR ° . rlEMARKS //"/ S ~--4~ FIELD - DISTRICT- ST4~TE OPERA-TIOI~ AT REI~:)R~ tI'M'E - / · 1'-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp. Chill Factor I Visibility iWlnd Vel. Report °F 0FI miles ARCO Alaska, In,c. Subsidiary of Atlantic Richfield Comp~ WELL CONTRACTOR .~IEMAR'~ - ,PBDT FIELD - DIST...RICT - STATE OPERATION A'T FfEPOFJT TI-Mi WELL SERVICE REPOR' I r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL ..... CAMC© OTiS ...... DRESSER-AT~S ....... DOWELL HALLIBURTON ............................. ARCTIc COIL TUBING '" FRAC~AsT'E~ ........ a. J. Hu~HEs ........... RoUsta~uts Diesel "~ethanol ..... , , ,,,, , ,t~ Supe~ision .... ~ ,, ..... ~rmJob"Safety Meeting AFE ........... ~" :' ;";~'~' ...... ~':~ ~'~'"~ '"~ ~';~ :'~ '" "- ,,, , ..................... .... .... ..... TOTAL FIELD... ESTIMATE ..... MISSION S(~ STATE OF ALASKA ALA A OIL AND GAS CONSERVATION COM " APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend 'i Operation Shutdown ii Re-enter suspended well [] Alter casing [] Time extension ' Change approved program 2! Plugging ~ Stimulate 2] Pull tubing ~ ' Amend order Iq Perforate ~ Other 2. Name of Operator ARCO A-lamina, Inc RK~ I~um elevation (DF or KB) 3. Address PO Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 768' FNL, 788' FEL, Sec.33, T12N, RIOE, UM At top of productive interval 2117' FSL, 988' FWL, Sec. 27, T12N, RIOE, UM "-- -- - "2~f'e~i~[?e~l' FWL, Sec.27, T12N, R10E, UM At total depth 2370' FSL, 1291' FWL, Sec. 27, T12N, RIOE, UM 6. Unit or Property name Kuparuk River Unit 7. Well number 1H-7 /~,~ · q u ~-r- , er 9. APl number 029-20755 50-- 10. Pool Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured 8194' MD feet true vertical6867' TVD feet Plugs (measured) None Effective depth: measured 7975' MD feet true vertical6679, TVD feet Casing Length Size Structural 80' 16" Conductor Surface 217 2' 10- 3 / 4" Production XxxxL~R~rxxxx Perforation depth: measured 8697' 7" 7805'-7830 MD true vertical6533,,6555, TVD Tubing (size, grade and measured depth) '-" 9 2#/d-55 @ 7642' MD B Packer~,,,?.Dd..S~_.Lt,~pe nd me d rown ..1 to ,~'//-; ~amco ~De~ ~ep!t~6' Junk (measured) None Cemented +200 CF 1200 SX Measured depth 110' MD 2200' MD 1000 SX 8723' MD True Vertical depth 110' TVD 2200' TVD 7166' TVD RECEIVED Alaska Oil & ~as Co~s. Cornmis$1or~ Anchorage 12.Attachments Description summary of proposal ~ Detailed operations program [21 BOP sketch Perforate C234 Sand 7696'-7755' MD 8 SPF 13. Estimated date for commencing operation June 20, 1988 14. If proposal was verbally approved Name of approver /, ,~/[4 [/~ 8'ubs;'~zent~. , Work Bepor'te,,t on t~orm No./O- ~_O_ff__ Datecl__~.~s~,/.~ 'Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~,~ /'~~~Title Sr. Operations Engineer Commission Use Only Date6/13/88 Conditions of approval. Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved C.opy Returneo ~- ORIGINAL SIGNED BY & .~ ;Z ~_~_~ LONNIE C. SMITH Commissioner Approval No. /~- ~? 9 the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate WELL 1H-7 General Description Well 1H-7 is a single completion. The well is currently flowing from the A Sands and the C1 Sand. The proposed perforations would also allow production from the C234 Sand. No workover fluids would be required. The C234 sand bottom-hole pressure is expected to be ±3000 psi based on offset wells. LCF'pg:O081 KUPARUK WELL 1H-7 C234 SAND PERFORATING PROCEDURE le 2. 3. 4. 5. e Pull WRDP at 1936' RKB. MIRU E-line. PT lubricator to 3000 psi. RIH w/gun and CCL. Tie-in w/CCL log dated 6/14/82. Perforate 7710- 7720' RKB at 4 SPF. Test well for 2 hours. If an obvious oil rate increase ~s observed, calculate the GOR of the C234 Sand. If the GOR is greater than 5000 SCF/B, halt perforating operations. Also, if the well begins producing water without an obvious oil rate increase, halt perforating operations. Perforate using multiple trips so that 7696 - 7755' RKB has a final shot density of 8 SPF. 7. RD E-line. 8. Install WRDP. 9. Test well. Notes: o Load guns. so there is a big hole charge after every three deep penetrat- ing charges. ° Perforate using 2-5/8" or 2-1/2" hollow carrier guns (2-1/8" guns are a 1 so acceptable }. ° Perforate at 0° phasing using magnets to decentralize the guns 30° off the low Side. Each zone should be shot twice at 4 SPF. The second run should be shot 60° from the first run. ° Perforate at maximum underbalance. This is obtained by flowing the well just under .the rate at which the tools begin to float. ° After perforating, flow well for 2 minutes at maximum underbalance before choking well back to retrieve guns. 1. 5000 P'SI ?" WELLHE.,AJ:) CONNECTOR FLANGE 2. 5000 PSI WIRE:LINE RAMS (VARIABLE ,SIZE) · 3.5000 PSI 4 1/6" LUBRICATOR 4. :5000 PSI 4 I/E," IrLOW TUBE PACK-OFF bi ] REL ] NE BOP EOU ] PI, lENT Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 22, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are intent notices on Kuparuk Wells 1H-7 1Q-6 as listed below' Well Action Anticipated Start Date 1H-7 Perforating June 26, 1987 1Q-6 Acidizing June 15, 1987 If you have any questions, please call me at 265-6840. Sincerely, and 'G. B. Sma llwood Senior Operations Engineer GBS'pg-O091 Attachments cc' File KOE1.4~9 Alaska 0ii 8, (~as Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA I~.~',.,ISSION AL,,A OIL AND GAS CONSERVATION CO APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska, ]:nc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 768' FNL, 788' FEL, Sec 33, T12N R10E UN At top of productive interval ' ' ' 5. Datum elevation (DF or KB) RKB 85 6. Unit or Property name Kuparuk River Unit 7. Well number 1H-7 8. Permit number Permit #82-84 9. APl number 50-- 029-20755 2117' FSL, 998' At effective depth 2283' FSL, 1151' At total depth 2370' FSL, 1291' 11. Present well condition summary Total depth: measured true vertical FWL, Sec.27, T12N, RIOE, UM FWL, Sec. 27, T12N, RIOE, UM FWL, Sec.27. T12N, RIOE, UM 10. Pool Kuoaruk River Oil Pnol 8194' MD feet 6867' MD feet Plugs (measured) None feet Effective depth: measured 7975' MD feet Junk (measured) None true vertical 6679' MD feet Casing Length Size Cemented Measured depth 80' 16" +200 CF 110' MD Conductor Surface 2172' 10-3/4" 950 SX Fondu 2200' MD xxl~~(t~ & 250 SX AS Production 8697' 7" 1000 SX Class G 8723' MD xx~(~<xxxxx Cmt Perforation depth: measured 7805'-7830' MD w/4 SPF, 0° Phasing true vertical 6533'-6555' TVD True Vertical depth 1_10' TVD 2200' TVD 7166' TVD Tubing (size, grade and measured depth) 3½" 9 2#/d-55 @ 7642' MD Packers and SSSV (type and measured depth) Brown HH1. @ 7577'; £arncn TI~I3P-'IA_ fa lC1~' 12.Attachments Description summary of proposal [] ,] N 2 i987 Alaska 0ii & ~as Cons, Commission Anch0r~gs Detailed operations program [] BOP sketch [] CTU clean out, Perforate A4 Sand 8015'-8023'; 8031'-R051' RSpF: 40° Phasing 13. Estimated date for commencing operation June 26, 1987 14. If proposal was verbally approved Name of approver L. Smith Date approved 6/12/87 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~ J~,~./.c,,~C)Title Sr. Operations Engineer Commission Use Only Date 6/14/87 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI --~.... ~.z//'~, Approved by Form 10-403 Rev 12-1-85 . ~¢ ~ byorderof ~ .... .~ s o the Submit in triplicato Drill Site lA Wel 1 No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A ATTACHMENT I I KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Log Date 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 //F7 Drill Site Well No. Log Date 1B-1 12/26/81 1B-2 6/25/81 1B-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 lB Drill Site 1C Well No. 1C-1 1C-2 1C-3 1C-4 1C-5 1C-6 lC-7 1C-8" Log Date 519181. 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 10 10-1 · 1/80 5/23/83 10-3 8/5/80 10-4 7/30/80 8/13/80 10-5 6/11/81 10-6 6/9/81 10-7 6/8/81 D-8 (WS-8) 5/~0178 A/aska Oil & ~ Co:,s ,.. ....... Attachment Page 2 Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 7/20/82 1H-8 7/22/82 Drill Site Well No. .Lo9 Date lq t!q~~1~11~/85 Drill Site 1E Wel 1 No. 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Lo.q Date 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Lo9 Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Dri 11 Si te Wel 1 No. 9/7/82 1F 1F-1 9/25/82 1F-2 9/28/82 1F-3 12/8/84 1F-4 10/13/82 1F-5 11/12/82 1F-6 3/!2/83 1F-7 Alaska Oil & Gas Cons. Log Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 !0/28/82 11/19/82 5/7/83 Attachment Page 3' Drill Site Well No. Lo9 Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~6 / 18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 11~;1~ 5110183 ~._ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Dril 1 Site Wel 1 No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 ~2~l~tZtlt~8~ Drill Site Well No. Lo9 Date 2Z' l~-l~m=~.' 7/10/83 2Z-2 ': 6/24/83 7/19/83 2Z-3 ' '8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF-pg-O052 Anchora~oe "- ..... -- Drill Site Well No. 1H-3 ~1H-4 ~1H-7 ~1H-8 Lo~) Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E Drill Site 1G Wel 1 No. "'"IG-1 '",I. 8-2 ",~1G_3 '"~1G-4 ",,4G-5 %1G-8 Log Date 9/7/82 -9/25/82',,,, 9/28/82 / 12/8/84/ - 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. Log Date 1F IF-1 2/19/83 1F-'2 2/3/83 ""'IF-3 1/31/83 "1F-4 5/29/83 %1F-5 10/25/82 '~1F-6 10/28/82 ~ 1F-7 11/19/82x,~ ,,, 5/7/83..,." "I Y- % ~ I~/,,,' RECEIV · FEB 2 1 1986 Alaska 011 & Gas Cons. Commission Anchorage .'7 ARCO Alaska, Inc.~*',, Post Office ^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-11- 85 TRANSMITTAL NO: 5346 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHOICAGE, AK 99510 TRANSMITTED HEREWITH ARE ThE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETUkN ONE SIGNED COPY OF THIb TRANS~IITTAL. lQ-12 2Z-2 3B-14 WSW-5 iR-ii 1R-12 1H-07 SEQUENCE OF EVENTS SBHP 9/3-4/85 SEQUENCE OF EVENTS FRACTURE STIMULATION 9/2/85 SEQUENCE OF EVENTS PBU 'A' SAND 9/2/85 SEQUENCE OF EVENTS TEMPERATURE LOG 8/15/85 STATIC BOTTOMHOLE PRESSURE REPORT 8/19/85 STATIC BOTTOMHOLE PRESSURE REPORT 8/19/85 STATIC BOTTOMHOLE PRESSURE REPORT 8/20/85 RECEIPT ACKNOWLEDGED: BPAE* B. CURRIER CHEVRON* D & M* DRILLING L. JOHNSTON MOBIL* NSK CLERK DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL* J. RATe, ELL* D .~Co, F~rnission UNION* K.TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc[ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Harch 7, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As'Built Location Plat - 1H-Pad Wells 1-8 Dear Elaine- Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG6/L20'tw Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany LEGEND B NOTES S. PROTRACTED SECTION CORNtR, FUTURE V/ELL LOCATIONS. PERM),NENT SURVEY LDCATION MONUMENTS. EXISTING W~LLH[~ F~NO THI~ SU~EY, AS-BUILT S~T ELEVATI~, PAD DiMENSiONS S~WH AN[ MEA~S TAKEN FR~ &S-~SLT SURVEY ~TES ATIONS TAK[~ F~OM A~-IUILY ~URVEY NOTES, ELEVATIONS ARE ~S~O ~ S~-BP VERTICAL OAKUM. A~ C~DINATES ~N ARE ~ASKA ~T~TE ~IN~ CO~GINATE SYSTEM, ZONE 4. S[CTI~ C~NERS S~WN ARE ~SED ~ ALASKA PROTRACTION SYSTEM, THE ENTIRE AHEA LIES WITflI~ Tt~N, RIOE, UMIAT MERIOIAM, ~ASKA. iLL AZIMUTH WN ARE ALASKA STATE ~ANE GRID AZIMUTH ALL DISTANCE ~N ARE Tfl~ ~STA~E~ AS -BUILT D R I L L S I T E "I-H" ARCO Alaska, Inc. ARCTIC SURVEYING, IN~, " ANCflMAG[ , ALAIKA aO/~ ' 5,S?S,I4O ,~,. I ~'~'" . +-. ,J ..... :J ' ._ _~ ..... t I.__2 I_2:[2. ISO' -- ~. ', ~ AZ ITSI4T'SS"--ITSO.O' TRUE _ ~ CONDUCTOR HOLE LOCATIONS WITHII~ SECTION COURDI~AIES I' 1 I "'' [ -.~ ,o-~,'~.~l "'~'~'"" ~'"~'~'~" ~'~eg'" l~'_i ,o-,,' ,o.~t:I ,.- ~' I~ ,o.,,.,i.,~l '~"-' 0i.,,- ,.,,,.,,.,o ~,.~o,.o. Iii I I I DA,, ......... I ........... I '"'"' I' 1 °' ....... '; J '"""0 '" ..... .. I.':~'' I"1~, "' NSK;3.2.1';II '~," ' ,. FNL . FEI. I i,, I '"' I - SW COH / ALASKA OIL AND GAS CONSERVATION COMMISSION Permit No. Bill Sheffield Governor 30{31 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501.:-3192 TELEPHONE (907) 279--1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject Well which our records indicated was completed Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, Chairman WELL COMPLETION OR RECOMPLETION REPORT AND LOG -1. Status of Well Classification of Service Well O~L [~ GAS [] SUSPENDED [] ABANDONED [] SERVtCE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-84 3. Address P.0.Box 360, Anchorage, AK 99510 4. Location of well at surface 768' FNL, 788' FEL, Sec 53, ¥i2N, R'i0E, UH At Top Producing lnterval 2177' FSL, 998' FWL, Sec 27, T12N, R10E, UN At Total Depth 2370' FSL, 1291' FWL, Sec 27, T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 85' RKB I ADL 25639 ALK 464 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Sum. or Aband. 6/3/82 6/13/82 6/16/82 17. Total Depth (MD+TVD) 8300' 6959' 8. APl Number 50- 029-20755 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1H-7 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 18. Plug Back Depth (MD+TVD)' 8194' 6867' 16. Water Depth, if offshore 116. No. of Completions N/A feet MSLI I 19. Directional SUrvey 20. Depth where SSSV set I 21. Thickness of Permafrost YES [~ NO [] 1924' feet MD I 1900' (approx), 22. Type Electric or Other Logs Run DIL/SP/GR, DIL/FDC/Cal, RFT, Dipmeter, Gyro/CCL, CBL/VDL 23. CASING SIZE WT. PER FT. 16" 62.5# · .10.3/4" 45.5# 7" 26# GRADE H-40 K-55 K-55 CASING, LINER AND CEMENTING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and .interval, size and number) 7805-7830' w/4 SPF, 0° Phasing HOLE SIZE CEMENTING RECORD 24" 315 sx AS II 13 1/2" 1000 sx AS III & 250 sx AS II B 3/4" 962 sx Class G Cml 25. TUBING RECORD , SIZE DEPTH SET (MD) PACKER SET (MD) 3 1/2" 7642' 7573' 26. ' ~ ACID, FRACTURE, CEMENT SQUEEZE, ETC. SETTING DEPTH MD TOP (BOTTOM Surf I 78' Surf I 2367" Surf / 82,74' AMOUNT PULLED 27. DEPTH INTERVAL (MD) N/A , PRODU(;TION TEST IMethod o~. Operation (FIowing,.gas lift, etc,) IAMOUNT & KIND OF MATERIAL USED Date First Production 7/20/82 Date of Test 7/19/82. Flow Tubing Press. 135 Flowinq TEST PERIOD ~ ~ , ~ 280 I .... 114 , 1~.6 : CALCULATED ~}'O"L-BBL I'GAS-MC~ Casing Pressure __ ~4-HOUR RATE ~ I ' 318 I 127 28. CORE DATA WATER-BBL WATER-BBL ICHOKESIZE IGAS'OILRATIO 96/ 4 I 398 OIL GRAVITY-APl (corr) 21,4 Brief description of lithotogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,'ECEI'VEg DECO Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME InClude interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk N/A River Form. 7622' 6379' Base Kuparuk River Form. 8116' 6799' · .. · . /Y 31. LIST OF ATTACHMENTS N/A , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Si,ned ~. 'Title Date I' .'1~ fl-' -' - / - INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disPosal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. . Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng 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 · ARCO Alaska, Inc. Post Office El/ 360 Anchorage,~/~,...,ka 99510 Telephone 907 277 5637 November 22, 1982 C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001-Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Please find attached the well completion reports for the following producing/injecting wells:' 1B-9GI 1H-3 1B-10GI 1H-4 1B-11GI 1H-6 1E-11 1H-7 1E-14 1H-8 1E-15 Very truly yours, Area Operations Engineer slz Attachment cc: L, M. Sellers "E. A. Simonsen R. L. Stramp H. C. Vickers AN0-332 w/attachments AFA-311 w/attachments AST-308 w/attachments AFA-326 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany TO: William VanAlen FROM: D. W. Bose/Lorie L. Johnson Transmitted herewith are the foll~ing: PT.WASE NCY/~: BL-.BLUELY, S- SEPIA, F- FTT~I, T- TAPE, '/ ,.,~ ARCO AIASKA, INC. ATTN: LORIE L. JOHNSON - AF~311 P. O.-BOX'360 ANCHORAGE, AK. 99510 KUPARUK ENGINEERING TO: DATE: · qfl d~ ~~'~~ FROM: D.W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: ~ ~ F - FILM, T'- TAPE ~/PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX '360 ANCHORAGE., AK 99510 KUPARUK ENGINEERING TO: TRANSMITTAL D. W. Bose/Lorie L. Johnson DATE: ~/~//~% WELL 'NAME: //~- 7 Transmitted herewith are the following: PLEASE NOTE: ~, ~ F - FILM~ T - TAPE RECEIVED 0':/ ~,,,~,~, ~,c. PLEASE RETURN RECEIPT T -- AIaska0il &~n.h.GaS CONS. ~rr~: ~,o~z~, ~,. ~o~so~ - P. O. BOX 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc.[ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 15, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1H-7 Well Completion Report Dear Mr. Chatterton' Enclosed are the well completion report and gyroscopic survey for Kuparuk Well 1H-7. If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG'llm Enclosures GRU1/L49 JUL 1 91982 Alaska Oil & Gas Coas. AOChorago c°mtniSsioa ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ 1. Status of Well Classification of Service Well OIL)~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 82-84 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20755 4. Location of well at surface -r---.--__ 9. Unit or Lease Name 768' FNL, 788' FEL, Sec. 33, T12N, R10E, UMILOCA~? Kuparuk River Unit At Top Producing Interval / 10. Well Number 2201' ESL, 1030' F,t, Sec. 27, T12N, R10E, O. j Sur~. P___~__t 1.-7 At Total Depth J ~. tJ.._~__~J 11. Field and Pool 2370' FSL, 1291' FWL, Sec. 27, T12N, R10E, UM~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River' 0i 1 Pool 85' RKBI ADL 25639 ALK 464 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 06/03/82 06/13/82 06/16/82 N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD)i 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8300'MD,6959'TVD 8194'MD, 6867'TVD YES ~[] NO [] 1924' feetMD 1900' (approx) 22. Type Electric or Other Logs Run DI L/SP/GR, D I L/FDC/Cal, R/F-'d'~, Dipmeter,"Gyro/CCL, CBL/VDL 23. ~ ........ CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT.. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED lb" 62.5# 'l-t0 Surf 78' 24" 315sx AS II 10-3/4" 45.5# (-55 Surf 2365' 13-1/2" 1000sx AS III & 250 sx AS II 7" 26.0# ~(-55 Surf 8274' 8-3/4" 962sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A 3-1/2" 7642' 7573' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A , 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing;'gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I1~ '. Flow Tubing Casing Pressure . CALCULATED' .~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None J U L 1 9 i982 AJaska 0il & Gas Cons. C0m,~[ssJ011 Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. '~ ~ 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7696' 6441' N/A Base Upper Sand 7831' 6556' Top Lower Sand 8007' 6706' Base Lower Sand 8116' 6799' 31. LIST OF ATTACHMENTS ..... Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~,~ ,~, ~ Title Sr. Drilling Engr. Date /-?, ! z-" ~- I'1 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 1H-7 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 0600 hrs, 06/03/82. Drld 13-1/2" hole to 2381'. Ran 55 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2365'. Cmtd 10-3/4" csg w/lO00 sx AS III & 250 sx AS II. ND Hydril & diverter. Instd 10-3/4" packoff & tstd to 3000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld cmt, FS & 10' new form. Tstd form. to 12.5 ppg EMW - ok. Chg over to XC polymer mud. Drld 8-3/4" hole to 8194'. Ran DIL/SP/GR & DIL/FDC/Cal. Ran RFTs. RFT #1 sets @ 7703', 7706', 7820', 7823', 8019', 8037' & 8050'. Samples @ 8037'. RFT #2 sets and samples f/7819'-7825'. Ran dipmeter f/2367'-8170'. Collected samples @ 7875' & 8037'. Cont drlg 8-3/4" hole to 8300' TD (06/13/82). Ran 193 jts 7", 26#/ft, K-55, BTC csg w/shoe @ 8274'. Cmtd 7" csg w/962 sx Class G cmt. Instld packoff & tstd to 3000 psi - ok. Drld cmt to 8194' PBTD. Arctic packed 7"x 10-3/4" annulus w/300 bbls H20, 250 sx AS II, & 114 bbls Arctic pack. Ran Gyro/CCL. Ran CBL/VDL. Ran 3-1/2 completion assembly w/tail @ 7642' & pkr @ 7573'. SSSV @ 1924'. Tstd tbg hanger & packoff to 3000 psi - ok. Disp well w/diesel. Dropped ball & set pkr. Closed SSSV. ND BOPE. NU tree & tstd to 3000 psi - ok. Secured well & released rig @ 1000 hrs, 06/16/82. JG:llm 07/15/82 GRU1/DH27 JUL 1 9 J982 Alaska Oil & Gas Cons~ Cornrnissioa Anchorage l'-J - / ' '% ',.. l.-., '.,.' '...l ',..I ' 'J '.l- ,I;.J~J J ~ J. J..*l-,. 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O0 ...... 3000. O0 4000. O0 5000. O0 6000. O0 7000. O0 , ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. Boss-16056 Well No. H-7 (Sec 33 T12N R10E) Kuparuk Field North Slope, Alaska Survey Date: June 14, 1982 Operator: John S~ Scale; 1"= 1000' 3764.48' @ N33O 31'E I I I -I'-' '-' 1000. O0 2000. O0 9000. O0 4000. O0 VF___RTICRL PROJeCT_TO I -500.00 T~UE NOF~TH .ARCO Al_ aska, :L-,,,~,c. ". our Boss Gyroscopic Survey Job NO. Boss-16056 Well: H-7 (Sec 33 T12N R10E) Kuparuk Field North Slope, Alaska Survey Date: June 14, 1982 Operator: John Samec Scale: 1"= 500' -~000.00 8300 -2500.00 -2000.00 1500.00 -1000.00 // 3.30 I 500.00 t000.00 ].500. 00 2000.00 Surface Location (768FNL 788FEL) --500.00 HOR J; Z ONTCqL PROJECTION Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator,-~11 Name ~nd Number Reports and Materials to be received by: .. Date Required Date Received Remarks - , ...Ccmpleti°n Report Yes _..W. el 1 .His. t.ory . . . Yes _~~s ~,_.?/ .~ .~. ~ .~. Mud Log ~ p Core Chips Core Description ... ':iii~,~~'~' 'k ~,~ ..................... ~ .... ~Regzstered Survey Plat ..... ~ '. ~ Inclination Su~ey ~ Drill St~ Test Re~s ~:,,..~:~ Pr~u~ion T~t Re~s STRATIGRAPHIC HIGH RESOLUTION DIP METER LOCATED IN THE APPENDIX . KUPARUK ENGINEERING TO: TRANSMITTAL DATE: ~~~ WELL NA3.[E: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, ~- TAPE~~ IPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: Alaska Oil & Gas Cons. Commission 'Anchorage DATE: ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 KUPARUK ENGINEERING TO: TRANSMITTAL ~F-~~ FROM: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: ~ S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDGED: ~~LEASE RETURN RECEIPT TO: 81982 DATE: Alaska Oil & Gas Cons. Commission ARCO ALASKA, INC. Anchorage ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 MEMORaNDuM of AlaSka TO: C. V on DATE: June 7, 1982 Chai~ - /~./ ~ FILE NO: 108/A T}]RU: Lonnie C. Smith~ Commissione r/ ' TELEPHONE NO: ~"OU~ Harold R..awkins ~/~j Petroleum. Inspector- , . SUBJECT: TO Witness BOPE Test ARCO, Kuparuk 1 H-7 Sec. 27, T12N, R10E, UM. Permit No. 82-84 Saturday,_ June_ 5., 1982: I left Anchorage at 2:30 p.m. by Alaska Airlines to Prudhoe arriving at 4:00 p.m., and at Kuparuk 1 H-7 at 5:15 p.m~.-., via ARCO's Otter. ~en I arrived at the location nippling up BOPE was finished, and BOPE test was started immediately, there were no failures. I filled out an AOGCC report which is attached. In summary, I witnessed the BOPE test on I H-7 for ARCO, at the Kuparuk field. Tests were performed satisfactorily. O&G ~4 4/80 STATE OF ALASKA ( ALASF~% OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Date Well Location: Sec 27 TIA.~ · Drilling Contractor:' · Location, General _ ~/~._ Well Sign General Hous eke eping_ Reserve pit d,/~ ~ig BOPE Stack Annular Preventer Pipe Ra~ms Blind R~s Choke Line Valves H.C.R. Valve Kill Line Valves Test Pres sure Check Valve Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pressure_ ,~ ~ _(9___ psig Pressure After Closure ~y,~, ,~,.,~, psig 200 psig Above Precharge Attained:,-~-' min__~'~ec Full Charge Pressure Attained:._ . ~ min/~_ sec ~:~ .~2~ .. ~mot~ d/V' '~as ~tch co~r ~/f , 3 ~ ' ~~ ~ ~' ' ' ' ' ~ ' "' - ' ~ Kelly and Floor Safety Valves Upper Kelly Lower KellyI Ball Type Ins ide BOP Choke Manifold No. Valves... No. 'flanges / Adjustable Chokes Test Pressure Test Pressure Test Pressure · . · Test P-ressure Hydrauically operated choke__-T.~ . _. -~_._~? . -.'~ ~ . Repair or Replacement of failed equipment to be made w~thLn . _ ays and Inspector/Commission office notified. Dis tribution orig: - AO.&C~C cc - Ope rator cc - Supervisor Inspector June ~, 19~ ~tr. Jeffrey B. Ke~in Senior Dril ling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk River Field No. l-H7 ARCO Alaska, Inc. Permi.t No. 82-84 Sur. Loc. 7$8'FNL, ?8?'FEL, Sec. 33, T12N, R10E, Btmhole Loc. 2525'FNL, 1450'F~L, See 2?, T12N, RIOE, Dear ~. Kew'in: Enclosed is the approved application for permit to drill the above referenced well. Well samples and a ~d log are not required. A continuous directional survey is required as per 20 AAC 25,050(b)(5). If available, a tape containing the digitized log infol~natton shall be submitted on all lo~s for copying except experimental logs, velocity surveys and dipmeter surveys. ~any rivers in Alaska and their drainage systems have been classified as im~rtant for the spawning or ~igration of anadro~ous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunde~ (Title 5, Alaska Administrative Code). Prior to com~aencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and G~. PollUtion of any waters of the State is prohibited by AS 46, Chapter 3, Article ? ~d the repletions promulgated thereunder (Title I$, Alaska Administrative Code, Chapter 79) and by the Federal Water Pollution Control Act, as a~ended. Prior to eom~aencin~ operations you may be contacted by a representative of the Department of ~nvironmental Conservation. To aid us in scheduling field ~ork, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representative of the C~issio~ may be present to witness Mr. Jeffrey B, ~ ,~in Kuparuk River Field No. lB-? -2- ( June 2, 1982 testing of blowout preventer equipment before surface casing shoe is drilled. 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 Chairman of BY ORDER OF TH~ CO~:,~,~,~=,~ON Alaska Oil and Gas Conservation C~ission EnO 10 sure ce= Department of Fish & (],me, Habitat Section w/o enel. Department of l~nvtronmental Conservation w/o encl. CVC ~ be ARCO Alaska, Inc.~ Post Office B"k 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 1, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Subject- Drill Site 1H-7 Application for Permit to Drill Enclosed is our application for Permit to Drill well DS 1H-7 and the required $100.00 filing fee. Attachments include a drawing of the proposed wellbore, and a drawing and description of both the surface hole diverter system and the BOP equipment, including anticipated reservoir pressures. Since we estimate spudding this well June 2, 1982, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, //J./ B./Kewin Senior Drilling Engineer JBK'GA:ltc Enclosures RECEIVED JUN - t 1982 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, ~nc. is a s~bsidiary o1 AtlanticRichfieldCompany C'i STATE OF ALASKA ALASKA LAND GAS CONSERVATION C ~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~'l DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, AK 99510 4. Location of well at surface 768'FNL, 787'FEL, Sec' 33,' T12N, RIOE, UM At top of proposed producing interval 2000' FSL, 1100 D i: f' E i %i r' r~ a% L- ~,, i,. i ! JUN - 1 i982 Alaska 0il & Gas Cons. Con '.FWL, Sec. 27, T12N, R10E, UM Anchorage 9. Unit or lease name Kuparuk'.River Unit I number At total depth 2525'FNL, lqE0'FWL, Sec. 27, T12N, R10E, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. 85'RKB 54.5' Pad I ADL 25639 ALK 464 I 12. Bond information (see 20 AAC 25.025) Type Statewide Su'retyand/ornumberFed. Ins. Co. 8088-26-27Amount $500,000 11. Field and pool Kuparuk River Field Kuparuk River 0il P0ol 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW Peadhorse miles 768'FNL @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8723'MD, 7166'TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2400 feet. MAXIMUM HOLE ANGLE 45 °l(see2OAAC25.035(c) (2) 15. Distance to nearest/cl?ill]:r~g-~ completed we,, 1H-6 (. 90~//¢-~'r feet 18. Approximate spud~-att~ 06/02/82 2983 psig@__ ~)0° ~Surface 3560 psig@ 7166 .ft. TD (TVD) 21 SIZE Hole I Casing 24" 116" 13-½ /10-3/4" 8_3/4i 7, Weight 65# 45.5# 26# Proposed Casing, Liner and Cementing Program 22. Describe proposed program: :ASING AND LINER Grade I Coupling Length U-40 I REB I 80' K-55 / BTC 1217:2' K-55 I BTC 86.97" SE 1 t lNG DEPTH MD TOP TVD 30' I 30' i 28' 28' i I 26' ~ 26' I I MD BOTTOM TVD 110' 110' 2200' 2200' I 8723' 17166, I · QUANTITY OF CEMENT (include stage data) -~200CF 950sx Fondu & 250sx /~ lO00sx Class "G" cmt ARCO Alaska, Inc. proposes to drill a Kuparuk River Field development well to approximately 7166'TVD, 8723"MD. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surfaCe hole. A 13-'5/8", 5000·psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will 'be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure will be 2983 psig based on cooling of a gas bubble rising at constant volume. Selected intervals will be logged. The well will be completed with 3 '- 9.'2# J-55 buttress tbq --2, , Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on sub- sequent reports. A downhole safety valve will be installed and tested upon completion of the job. · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED (/~j,~?_,/~./~/~-~4,.f.,4~' T'TLE Sr. Dril 1 in.q Engineer The space b~/f~$~'~sio~use CONDITIONS OF APPROVAL Samples required I-lYES ~'NO Permit number APPROVED BY Mud log required []]YES [~-N O Approval date Directional Survey required I APl number ~]YES [-]NO[ 50- O2.~c~ -7..O 73~.~~' SEE COVER LETTER FOR OTHER REQUIREMENTs ,COMMISSIONER DATE by order of the Commission Form 10401 Rev. 7-1-80 Submit in triplicate FtRCO FILI:J~i~,,,I NC ............ ............. ~ .... : ........ ~ / --- , ~ . ~ .._ EAS~' ~NIPSTDC~ INC. :: .... ..............J ~ ~ . ~ . . . I ' '~j ................. .~ .......... . t,. .......... J ........... . ~ . . ~ ........ ~ .......... , .......... ~ ...... :.:::.:::;_:::::._ .-=.:_:.':_~ :.::::=:.::.:-:-.,. :-= :.:..:.: ::::::::::::::::::::::::::: ::::::::::::::::::::: ~ ...... l .................... J : :: :.: ...... 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'~ ~ , ~ : i ~ : ': ~ ~ ~ 4 ~ t ; ~ ' ~ ~ i i '. : ~ '. ~ ~ ~ ~ ; ~ i L L ~ i . ~ ~_.~_~__.~ ~'-::~~--?---':::~ ...... ~-'~"~~-'-~--r~-~-~-~', ~t~~::'~-'t-t~F::::;~::y;~:~: i, -:,, r"~'t-~, ~ ~ .',-.-.~.--~ ...... ~.. .. ~--;....~.4--. ~..-..~. .--'.--.-: ..... :. .~_.. .:_. .;._~ ...... ~._...~ ...~.__~._~._.~_:4__..:_._L_.~.._: ..... ~.__~._.~_.~...~_.~.~--~ ....... ~.~.A.-.`~-~....~...~.-~.~-~...~..w..~-.~-~-.~-~.-~.`~... ~`~..~...~..~....r~.-~..~ ~ ....... ~.---~.--.~--~.-P-~-- ' ~ : ' : , ~.~ : ] : L ~ ~ ~ ' ~. '..~ !-~ ....... i._.S ........ ~.._~..._~_.,_ ~ ,_.~_~ ~ i- ~ .........~_ '~_~.._.~-~--~-.~-4...~ ........... ~.-~-~ ...... ---~ ........ ~ ........ - .... -~-": ............. ~ ....... ~'"~--~ ...................... ..... ~--~'-':~ ....... :'--'-'-~' ..... :-'f--7-"~ ~: ' ~ ~'., ~ ~ ~: : ~ ........ , ........ , ................. .... , ......... .............. ..................... ................. .......................................... ...... ?_ ...... ....... ............ . . ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3575 psia from RFT and pressure build-up data. This pressure @ 7081' SS = 7166'TVD will be balanced by 9.6 ppg mud weight. Normal drilling practice calls for 10.4 ppg weight prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 290 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2998 psi during drilling operations. Derivation assumes a gas kick at reser- voir temperature and pressure (160°F, 3575 psia), gas migration to the surface without expansion, and cooling to 60°F cellar temperature. This is well below the 5000 psig BOPE.working pressure and less than the 3000 Psi weekly test pressure. Pi = pressure initial (reservoir) T. = temperature initial (reservoir) V. : volume initial (reservoir) 1 Pf = pressure final (surface) Tf = temperature final (surface) Vf = volume' final (surface) PiVi = PfVf Ti Tf Since Vi = Vf, i.e.,~no expansion Pi = Pf PiTf Ti -~ Then Pf - Ti - (3575 psia)(60°F + 460) ' ' (160°F · 460) Pf = 2998 psia = 2983 psig JUN - I Alaska Oil 8, Gas Cons. Commission Anchorage -® .qurfac=~ ~i v=rter~ S..v s tern. I. 16" Bradenhead. 2. 16" x 20" 2000 psi double studded adapter. 3. 20'.' 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lC" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell l~ippie. o 16" Conductor Maintenance & O~eration 1. Upon initial installation close annular preventer and verify tha% ball val yes have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under ~ circ~nstances. JUN - 1 ~882 A~ska'Oii & Gas Cons, Commissio~ Anchora§~ RNNUL.q.q PREVENTOR 9 ) ( P I PE R,qNS ' f ) ) 1 PIPE RRMS TBG HD CSG HD 2 £.EIVED JUN - 1 1982 Alaska Oil & Gas Cons. CommisqPe.n Anchorage 5000 PSi ?,SR,q.A BOP STACK 1. 16" Bradenhead 2. 15" 2000,~q_T. x 1O" ~uu~'~^ PSI casing head 3 lO .... n PS ' ' heax 4. 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PS! pipe rams 6. 13-5/8" 5000 PSI drilling spool w/choke and kill lines . 7. 13-5/8" 5000 PSI pipe rams 8. 13-5/8" 5000 PSI. blind rams 9. 13-5/8" 5000 PSI annular 14. 15. 'i .- ACCIEIULATOR CAPACITY TEST 1. C~ECK $';D FILL ACC~,IJLATOR RESERVOI~ ~0 PROPER L~'EE Nt~H NYD~UL~C FLUID: 2. ~SURE THAT ACC~i~TOR PP~SSURE I5 ~OO PSI WI~.lhO0 PSI D~~q OF ~E RE~TOR. 3. OBSERVE TIHE THEN CLOSE A~L UNITS SI~LTANE- OUSLY SND REC02D THE TI~ AND PRESSU~ RE~IN- lNG ~R ALL UNITS ARE CLOSED WIT~ ~G!NG P~-'~ OFF. 4. RECORD 0~( IADC REPORT. ~E ACCEPT$$~ L~.;ER LtNIT IS 45 SECON~ CL~I)~ TI)IF AND 1200 PSI R~AIN I,,~ PRESSURE. - 13-5/8' BOP STA~ TEST I. FILL BOP STACK AND K~NIFOLD NI~ AR~C DIESEL. 2. ~ECK r~JT ALL HO~ D~,~( SCR~'S ARE ~LLY RE- TRACTED. P~EDETE~-IINE DEPTH THAT TEST PLUG WILL S~T A)~D S~T IN WEL~.D. RU~ IN LOCK DEaN SC~,~S IN H~D, 3. CLOSE ~(:~ULAR PREVENTER ~(D CqOKES ~D BYP~S Y~VES ON I.W(IFOLD. 4. TEST ALL C~qPONENTS TO 2~ PSI AND N~D FOR lO HINUTES. 5. INCR~E PRESSURE TO 1800 PSI AND N~ FOP, lO MINUTES. BLEED TO ZERO PSI. 6. OP~( ~;NU~ PP, E'/~ER ~'(D CLOSE TOP S~ OF 7. INCREASE .PRESSURE TO 3~0 ~I AND h'~ FOR lO H I f~TES. 8. CLUE V~VES DtRE~T UPSTRE~4 OF BLEED D~XNSTR~'4 PAESSUP. E TO ZERO PSI ~0 TEST V~VES. TEST P.~-!A!N!NG U~(T~TED H.~NIFOLD Y$~VES, IF ~qY, WI~q ~0 PSI UPST~'4 OF YALVE ~'~D Z~O PSI D~NSTP,~M. BLEED SYST~I TO ZERO PSi. 9. OPEN TOP S~ 0F P~PE ~'~S ~'~O CLOSE BO~C:'l S~ 0F PIPE 10. INC~SE P~ESSUP, E T0 3g$0 PSt ~'~g H~D FOR l0 V, INUTES. BLEED TO ZE~O PSI. lt. OPEN 80~OH S~ 0F PIPE P~q'.IS. 5AC;( OFF RUN- ~(I);S JO[~ A~;D PULL O~ 0F HOLE. ~OSE BLIND ~I.IS AND TEST TO 3~0 ~I FOR t0 HIMUTES. BLEED T0 ZERO PSI, 12. OPEN BLI:~D P~'~S AND P, EC~'ER TEST PL~. HAKE SURE b~NIFOLD ~'~g LINES A~ FULL CF ARCTIC . DIESEL ~';D ~L VALY~ ARE SET II( C~ILLING P~ITtmt. T~T STANDPIPE V~YES TO 3000 PSt. T~T KELLY CO~S ~'~D INSIDE 80P TO 30~ PSI RECORD TEST [NF0?J~ATION TEST FOP~q SIGN A:;D SEND TO C, EILLI;;G SUPER- YISOR. . PERFOPJ.I C~!PL[TE BOPE TEST ONCE A ~WEE~ ~'JO FU;;CTIO~LLY OPZP~TE 50PE ~iLY. CHECK LIST EOR NEW WELL PER,MITS Company IT~ APPROVE DATE (2) Loc · ~' thru 8) i · · 3. 4. 5. 6. ,7. 8. (3) Admin ~~ ~/~'~ 9, (9//thru il) 10. 11. (4) CasA ~/~.~.,~'. ~-~-~-- (12 thru 20) 12. 13. 14.' 15. 16. 17. 18. 19. 20. (21 thru 24) 22. 23. 24. Is the permit fee attached ........................................ Is well to be located in a defined pool ............................ Is well located proper distance from property line .............. · . Is well located proper distance from other wells .~ .............. Is sufficient undedicated acreage available in this pool ........ Is well to be deviated and is well bore plat included ............ Is operator the only affected party ............................ Can permit be approved before ten-day wait .................... Does operator have a bond in force ...................... Is a conservation order needed ......... Is administrative approval needed ................. , .................. Is conductor string provided .................... Is enough cement used to circUl2tg g~'ggn~gg[g~';n~ sElf'ce ....... [. 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 ,~Om~ psig .. ~f ..... Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements Additional Remarks: REMARKS Geology: Engin~_r i~ng: HWK LCS ~'~.-~' BEW ~ rev: 01/13/82 INITI'AL GEO. UNiT ' 'ON'70~F 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 APPENDIX. .. No special'effort has been made to chronologically organize this category of information. ,o D I Pt~E ~E R 4 F:T. COR:~,. - 2 :FT, 30 X2 &ERICH ANGLE ATLANTIC R/~CH~IELU ~CO, ~IH-7 PAGE 1-FILE # FORMATION , BQ~:S~.O~E ~ OU~L, '--'--'---'-'------,----------------------------------, INDEX DEPTH . DIP D.~ ~ DEV. DEV, DIA~ DIAH ~ ~EE~T * AZ1, . AZI. 1-3 2-4 * =A ************************************************************************* 2376.0 18.8 36 2378.0 5..1 234 18.9 36 2380.0 19.0 36 2382.0 19.2 36 2384.0 19,3 36 2386.0 19.5 36 2388.0 3.~1 202 19.6 36 2390.0 4. I 1.51 19,6 36 2392.0 4.9 138 19.6 36 2394.0 2.9 -131 19,7 36 2396.0 '~.;7 200 19,7 35 2398.0 4.:5 140 t9,? 3.6 2400.0 ,1'9,8 36 2402.0 19,9 35 2404.0 8.;5 186 19,9 36 2406.0 5,9 26'/ 20,0 35 2408.0 8.;5 267 .20,! 35 2410.0 5,0 .353 20,.! 36 2412.0 9.~8 290 20,2 36 2414.0 4,6 268 20.2 36 2416,0 2.;5 262 20,3 37 2418.0 &,O 2.54 20,4 36 2420.0 ~li~, 6 20'/ 20.4 36 2422.0 b,~O 163 20,4 36 2424.0 ~.;7 i28 20,4 36 2426.0 $. 3 119 20,5 36 2428.0 4.9 100 20,5 36 2430.0 6..4 1'16 20,5 36 2432,0 5.6 49 20,5 35 243'4.0 3.:5 36 20.5 36 2436.0 3.9 124 20,5 36 2438.0 5.6 132 20,5 '36 2440.0 5,9 i-46 20,5 36 2442.0 6 ;6 146 20,5 36 2444.0 6.~:8 14'/ 20.5 36 2446.0 4.!8 I55 20.6 35 2448,0 3.-:~8 1r53 20,6 35 2450.0 20.7 35 2452.0 ~,;? 141 .20,7 .35 2454.0 4.4 I32 20.8 36 10.8 10.5 I0.3 10.1 10.2 ,10.7 10.9 t0,6 10.5 !0.6 11,2 i 1-3 11.2 10.8 10.4 10,6 10,7 10.6 10,4 ,10.3 10..2 10,2 ~10,2 10,2 10,2 10,2 t0,3 10,4 10,5 10,7 ~10,7 10.7 10.7 .10,8 10.7 10,5 I0.4 ..1).4 ~12.1 ~I0.3 9.5 9.6 9.9 ~10,0 9.7 9.4 9.5 9.8 10,4 ~I0.6 9.9 9.5 9,5 9,0 9,0 8,8 8,8 8,8 8,8 9,0 ,9.2 9.5 D B B F A E A A E E E E E E E E E a # FOR~AT]C~N · BQ~EH.QLE ~mmm~mmmmmm~mmmmmmm*mmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmm DEPTH # DIP DIP , DEV. DE¥, DIRM DIA~ · iZI. , AZI. 1-3 2-4 # # 2456.0 2458,0 2460.0 2462.0 2464.0 2466.0 2468.0 2470.0 2472.0 2474.0 2476,0 2478.0 2480.0 2482.0 2484,0 2486.0 2488.0 2490.0 2492.0 2494.0 2496.0 2498,0 2500,0 2502,0 2504.0 2506.0 2508,0 2510,0 2512,0 2514,0 2516,0 25i8,0 2520,0 25:22,0 2524.0 2526,0 2528.0 2530-0 2532.0 2534.0 t~,:2 9.~t 6,3 5°'4 :6 5 10.~! ~I0,~2 ~, g 147 20,8 36 10.3 9,0 142 20,8 36 I0,1 8,9 116 20.8 36 10.0 8.9 122 20,9 36 10,0 8.9 1-19 20.9 36 10.1 140 21.0 36 10,1 185 21,0 36 i0.1 171 21.0 36 10.0 8.9 152 21.0 36 10.0 100 21.0 36 10.0 115 21,0 36 IO,O 8,9 47 21-1 36 10.1 8,9 43 21.1 36 10.1 9.0 47 21-I 36 9.9 9.0 73 21,1 35 10.0 9,0 122 21.2 36 10.2 9,0 i31 21'.2 36 10,4 9,2 85 21,1 35 10.5 9,5 2i,1 35 10.4 21,1 36 I0.0 144 2~.1 36 9.8 9.0 95 21.2 35 9.9 9,2 21,3 35 908 9.2 137 21-3 35 9.r6 8.9 '123 21'3 35 9.5 ~,'8 87 21,3 35 9,5 158 21.:3 35 9,-5 8.7 159 21,3 35 9,4 21.3 35 9.4 8.7 184 2i,4 35 9.4 8.7 21,4 35 9.4 181 21',5 35 9,4 8,6 194 21.5 35 9.4 143 21,5 35 9.5 143 21,5 35 9.6 8,8 146 21,6 35 9.6 8,8 2.1,6 35 9.6 209 21.7 35 9,6 295 2t.7 35 9,6 8.7 190 2i,I 35 9.6 QUAb. INDEX BEST =A g A C B B D D C A C A A C C B B ATbANTIC RICHFIELD CO, I,H-? PAGE ************************************************************************* * , FORmAtION # .BORE~ObE , DEPZH , DIP D~f , DE¥. DEV. 'DIA~ , · AZI. · AZI. 1-3 ***************************************************** * 2536,0 ~10.~1 189 21.8 * 2538.0 8.~0 83 21.8 * 2540,0 9.;7 73 21,8 , 2542.0 21.8 * 2544,0 21.9 * 2546,0 4.~1 336 22,0 * 2548,0 2,9 :320 22,0 * 2550.0 4,'4 295 22.0 # 2552.0 3,~1 1.5 22.1 . 25.54.0 :22.1 , 2556,0 22,1 , 2558,0 22,2 * 2560.0 22.2 * 2562.0 ,22.2 * 25'64,0 22,2 # 2566,0 22-3 * 2568,0 22'3 * 2570,0 '3,.1 I9 22~4 , 2572.0 9~i 54 ~22-4 * 25,74.0 ~9.?0 ,64 22.5 * 2576,0 4~3 ~74 22,5 * 2578.0 &~2 ~191 22*6 * 2580.0 ~,..9 208 22,7 * 2582.0 5.:3 :~51 ,22.7 * 2594,0 0,:5 ~180 22.7 * 2586.0 2,5 '147 22,8 * 25~8,0 ~,9 ~32 :22.8 * 2590,0 22,8 , 2592,0 ~,.;5 ~330 22-9 # 2594.0 8.:3 ~'I33 22.9 * 2596,0 ~15,~6 25.9 23,0 * 2598.0 9,~4 '301 .23,0 * 2600,0 8,~4 ~302 23.0 * 2602,0 :~10~2 296 23'0 * 2604,0 .~,'3 31.9 23'0 * 2606.0 ~13;3 ~171 :23.0 * 2608.0 ~13,~5 ,,165 23.0 * 2610,0 ~13,;7 ~147 23-1 * 2612.0 ~13.9 'i49 23,1 # 2614.0 ~14.~2 7154 ~23.2 . OUAb. -----------* INDEX DIAH ,IEEST 2'4 * =A 35 9.6 8.7 35 9.6 8.8 35 9.6 8.8 35 9.6 8.8 35 9.6 8.8 35 9.7 8.8 35 9.7 8.8 .35 9.6 8.7 35 9.6 8.7 35 9.5 8.7 34 9.5 8.7 34 9,5 0.6 35, 9,6 8.7 35 9.7 8.8 34 9.8 34 9,9 9,0 35 ~10-I 9,1 35 ~10.2 9,2 35, 10,2 9.:2 35 I0'2 9.2 35, .10'2 9,2 35 .t0.2 ~*';1 35 10-2 8.8 35 10.I 35 ~10-0 8.8 35 9.9 8,~7 35 9.7 8'8 35 9.6 35 9.6 8'8 35 9.6 8-7 :35 9-6 8.7 35 9.7 8,8 35 9,8 35, 9.7 8,9 35 9.7 8.9 35: 9.8 9.0 35 9.8 '35 9,7 8.8 35 9,7 8,9 35 9.7 8.8 A~bAN~fC ~F~ICHF~E~f ,CO. IH-7 lfAGE 4~f iLE 2 # a FO~RA~LN # BQ}EHOLE ~ DEPTH # DIP DIP # DE¥, DEV. DIAM 2616.0 14,~1 2618,0 10..I 2620.0 6,6 2622,0 8,8 2624,0 5,9 2626.0 4,i8 2628.0 6.3 2630,0 2632.0 9.~2 2634,0 6,5 2636,0 5,6 2638,0 2640,0 ,14,'6 2642,0 2644.0 8,;7 2646,0 '10,4 2648,0 5,~8 2650,0 2652,0 9,~4 2654.0 8.~2 2656,0 4~8 2658,0 5,0 2660.0 1~.4 2662.0 2664.0 t3,~2 2666.0 ~10,3 2668.0 16,~4 2670,0 ~10.4 2672.0 ~7 2674.0 b,3 2676,0 5;6 2678.0 4.:5 2680.0 2682.0 10.6 2684,0 ~2 2686,0 ~,3 2688.0 ~13.~4 2690.0 24.4 2692.0 25,;0 2694.0 3~2 161 174 166 148 1.73 122 130 119 112 90 125 1'46 79 141 140 ~'143 140 109 121 92 16~ 158 143 125 1.50 150 1.54 129 128 122 146 148 180 180 324 23,2 35 9,7 23.3 35 9,7 23,3 35 9,7 23.3 35 9.4 23,4 35 9,4 23.4 35 9.5 23.4 35 9.6 23,4 35 9.7 23,4 35 9,7 23.4 35 9.5 23.5 35 9.4 23,5 35 9.4 23.5 35 9.4 23,5 35 9.5 23.6 35 9.5 23.6 35 9.4 23.6 35 9.5 23.6 35 9,4 23,7 35 9.4 23.7 35 9.3 .23,8 35 9.3 23,8 35 9.3 23.8 35 9.4 23.8 35 9.4 23,9 35 9.4 23.9 35 9,4 24,0 35 9,5 24.0 35 9.5 24.0 35 9,6 24,1 35 9,6 24 -1 35 9.6 24.1 35 9.5 24,2 35 9,5 24.2 35 9.5 24.2 35 9.5 24.3 34 9.6 24°3 34 9,6 24.4 35 9.7 24,.4 35 9.8 24,4 35 9,.7 -----------, INDEX DIAM 2'4 ,##** 8,8 l 8,8 8.8 E 8.7 A 8,7 C 8.8 C 8,8 k 8.8 E 8.7 A 8.7 C 8.7 A 8.7 C 8. '7 C 8,7 A 8,6 A 8.7 A 8.7 A 8.6 A 8.6 A 8,6 8.6 A 8,6 E 8.6 C 8,6 C 8.7 A 8,7 E 8.7 E 8.8 E 8.7 E 0.:7 8,7 A 8..7 E 6.8 E 8.8 k 8.8 A 8.8 F 8-9 F 8,8 E ~/~ANTI~C R~H) IEbD ,CO, ~I:H-7 P~E 5-FII~E 2 , 2696.0 , 2698.0 # 2700.0 , 2702.0 , 2704.0 * 2706.0 # 2708.0 , 2710.0 * 2712.0 # 2714.0 * 2716.0 # 2718.0 * 2720.0 * 2722.0 * 2724.0 * 2726.0 * 2728°0 * 2730.0 * 2732,0 . 2734.0 , 2736.0 * 2738.0 * 2740.0 * 2742.0 * 2744.0 * 2746.0 # 2748.0 , 2750.0 * 2752.0 * 2754.0 * 2756,0 * 2758.0 # 2760.0 * 2762.0 * 2764.0 * 2766.0 # 2768.0 , 27,70.0 # 2772.0 13..2 ~15.,2 ~19;3 .-14,;5 & ,~8 6 ,;7 8 .:5 0 6 8,9 2.0 4 4 7,' .~0 6"6 ~.~0 5 t4 3,~4 I-5.A 15.~2 4 ;3 '; .0 ~.~2 6.9 ~ .;5 0,'6 24,5 35 9.7 122 24.5 35 9.6 8,6 138 24.5 35 9.6 8,7 139 ,24.5 35 9.7 8.8 24.6 35 9.8 9.0 133 24.6 35 9.9 9.0 129 24.6 35 9.8 8.9 143 24,6 35 9. $ 8.9 144 24.6 35 9.9 9.1 134 24,7 35 9,8 9.0 130 24,7 35 9.8 8.9 127 24.7 35 9.9 9.1 118 24.8 35 10.0 9.3 :i3-7 24.8 35 10.2 9.4 360 24,9 35 .10.3 9.2 :I 24,9 35 10.2 8.9 136 24.9 35 10.2 8.9 70 25,0 35 10.3 9.0 7.7 25,0 35 10,2 9,0 ~ 10'9 25.1 35 ~10,0 8.9 107 25,1 35 10.0 8.9 1"05 25.2 35 10.2 9, ol 114 25.2 35 10,2 9.0 84 25.3 35 10.2 8.8 100 25,3 35 10.2 '1r53 25'3 35 10'2 8.8 159 25,4 35 10.1 155 25,4 35 10.0 8.9 151 25,4 35 9.9 8.8 148 25.4 .]5 9.8 8,.8 25.5 35 9.7 8.8 160 25.6 35 9.8 8.8 149 25.6 35 .I0.0 8.8 1,52 25.6 35 10.0 8.8 151 25.7 35 10.0 8.8 165 -25.7 35 10. 0 t). 8 180 25.7 35 10.0 8.8 222 25-7 35 10.0 8.8 221 25.8 35 10.2 8.8 , 2774.0 4.5 62 25.8 35 10.2 8.8 , GOAL. ---, INDEX M 4 * ~*********** A?bANTIC Ii:ICHF}E I.;[; CO, IH-7 ~[-AGE 6;F.~LE # FO. RI*A'I]C.N # BI:}[ EHOLE * OUAb, ,---,~------,-----.--- #----------------------------------, INDEX DEPTH ~ DIP DIP ~ DEV, DEV, DIAH DIAH ~ BEST # AZI, ~ AZI, 1-3 2-4 # =A 2776.0 4,0 60 25.8 35 2778.0 3,6 t11 25,8 35 2780.0 3.;7 22 25.9 35 2782.0 8..0 77 25.9 35 2784.0 ~12.0 60 25.9 35 2786.0 26.0 35 2788.0 ~.3 108 26.! 35 2790.0 ~.3 107 26.1 35 2792,0 ~14,~4 32 26.2 35 2794.0 5..0 142 26.2 35 2796.0 3.;7 166 26.2 35 2798.0 5;6 11.5 26.2 35 2800,0 8,~2 I46 26,2 35 2802.0 26.2 35 28.04.0 t.~O 243 .26.3 35 2806,0 14,.1 163 2.6,3 35 2808.0 8,;8 145 26.4 35 28~0.0 6,~8 :149 26.4 35 2812.0 ~,~1 I80 26.4 35 28~4,0 ~12,6 209 26.5 35 2816.0 ,I0,~8 221 26.5 35 2818,0 26,5 35 2820.0 3,0 43 26.5 35 2822,0 3~1 ~19 26,6 36 2824,0 3,0 92 26.6 35 2826,0 ~,9 ~I03 26.7 35 2828,0 2,~2 I51 26.7 35 2830,0 2.0 248 26.7 35 2832.0 6.~1 222 26,8 35 2834,0 8,~8 246 26.8 :35 2836,0 ~,9 241 26,9 35 2838.0 4,9 69 26,9 35 2840,0 S.~O 89 27.0 35 2842.0 ~.9 109 27.0 35 2844,0 3.8 12.7 27,1 35 2846.0 27,! 35 2848.0 6,~ 88 27,2 35 2850,0 9.~2 124 27,2 35 2852.0 ~.3 137 27.3 35 2854.0 t.4 I02 27,3 35 0.2 8.8 0.2 8.8 0.3 8.8 A 0.3 9.0 0.3 9.3 C 0.2 9.6 0,1 9,4 A 0.1 9,2 A 0,0 9.0 C 9,9 8.8 C 9.9 8.8 g 9.9 8.8 C 9.9 8.8 A 9.9 9,9 1~.9 D 9.9 8.9 F 9.9 8.9 9.9 8.9 F 9.9 8.9 9.8 8.8 D 9.8 8.7 O 9.8 8,7 9.8 8.8 9.8 8.8 g 9.6 8.8 A 9,7 8.9 A 9.7 9.0 C 9.7 9.0 A 9.6 8.9 E 9.6 8.8 9.5 8.8 9.5 8.9 C 9.5 8.9 C 9.5 9.0 9,5 9.0 C 9.4 8.9 9.2 8.8 C 9.0 8.7 C 9,0 8.7 A 9,0 8.8 A ATLANTXC R~HFIELD CO. IIH-7 PAGg 7-FILE 2 # FORMATION ~ BOFEf,ObE DEPTH # DIP D~F · D}V, DEV, DIA~ DXA~ # AZI, # AZX, 1'3 2'4 2856,0 3.2 2858,0 2.3 2860,0 8.;7 2862,0 4.:5 2864.0 2866.0 ~,i8 2868,0 ~,3 2870,0 2872.0 6.8 2874.0 8.6 2876.0 2878.0 2880.0 2882.0 2884.0 3'3 2886.0 2888-0 2890.0 2892,0 2894.0 2896.0 289~.0 $~2 2900.0 2902.0 $~;2 2904,0 9,3 2906-0 2908,0 '3~7 29iO, 0 10,0 29i2,0 2914-0 7~9 2916.0 2918-0 5~3 29'20.0 4,9 2922.0 2924.0 10~1 2926,0 I~0 2928,0 15-;7 2930.0 it.2 2932.0 2934,0 12.1 I47 27.3 22'4 27.4 285 .27.4 274 27.4 27.4 245 27,5 236 27.5 ~172 27,5 261 27,5 296 27.6 287 27,.6 27.6 27.6 !338 ~27,6 281 27.6 2'7,7 '27,6 '27,6 27,6 27,6 ~27,6 ,,78 27..5 ~78 2.7,5 80 ~27.5 ~72 27,5 80 27,5 92 :27.5 :59 ~27.5 .27,6 84 '27.7 84 !27,7 ~15' :.27,7 8'9 27,7 i08 ~27o7 ~i06 27.7 ~::14~ 27,8 '11,'7 ~27,8 i07 ,27,8 .47 27.8 55 INDEX # 35 9.0 8.8 C 35 9.1 8.8 B 35 9.1 8.8 B 35 9.2 8.8 D 35 9.2 8,9 35 9.2 9.0 D '35 9.2 9.0 B 34 9.3 9.0 D 34 9,3 9,0 D 34 9.2 8'8 D 35 9.2 8,7 D 34 9.5 8.6 :34 9,b $,6 34 9,7 8,6 D 34 9,7 8.6 B ~34 9.7 8,6 '34 9.7 8.6 :35 9.6 8.6 '34 9.5 8,6 34 9,3 8.6 ~35: 9,2 35 9-i 8.6 :35~ 9,1 8.6 C 35 9.2 8.6 A 35 9.2 8-7 A 35 9.3 8,7 A 35 9,3 8,7 C 35 9,2 8,7 A 35 9,i 8-6 35 9.2 8'6 A '35 9,2 8,6 A 35 9.1 8.5" A ~35 9,1 8,5 A 35 9.2 8.6 E 35 9-3 8,6 C 35 9.4 8,6 C 34 9.2 8,6 C 34 9.i 8,5 34 9-I 8.5 A 34 9,1 8.5 A ATLANTIC RICHFIELD CO, I~-7 PAGE 8-FILE . FORmAtION # BORE~OLE # ~AL, DEPTH ~ DIP DIP · DEV, DEV, 'DIAH DIAN # BEST # AZI, ~ AZ~. 1-3 2-4 ~ =A 2936,0 9,3 2938,0 2940,0 ,I3,5 2942,0 2944,0 ~12,'0 2946,0 '15,3 2948,0 4.2 2950,0 2952,0 9,.1 2954,0 9,'3 2956,0 4,!4 2958,0 2960.0 ~.~7 2962,0 ~10,9 2964,0 ~I0.~2 2966,0 ~.~4 2968,0 ~.:0 29?0,0 2972,0 29~4,0 :4oi0 2976.0 2978.0 2980,0 2982,0 29'84,0 2986.0 2988,0 2990,0 ~,6 2992,0 2994,0 6.~7 29.96,0 4,i8 2998,0 ~,~2 ~3000,0 3002.0 3004.0 ~.;7 3006,0 3008.0 4,~0 3010,0 30:12,0 30i4.0 83 27.9 35 9.2 8.5 A 86 27.9 35 9.3 8.7 D 76 28,0 35 9.4 8.7 B 86 28,0 35 9.4 8.7 F 96 28.1 35 9.4 8.8 F 1.10 28.1 35 9.5 8.9 D 99 28.1 35 9.5 8.8 D 28,1 34 9.4 8,7 .~, 107 28.1 33 9,4 8.7 D t04 28,2 33 9,4 8.7 I0.3 28.2 34 9,3 8.7 D 349 28.3 34 9.3 8,7 D .355 28.3 33 9,3 8.7 D 22 28.4 33 9,3 8,6 B '3 28,4 34 9,3 8.6 D :33 28,5 34 9.2 8,6 O 1.~t9 28,5 33 9.2 8,6 D 28,5 34 9,2 8,5 ~10 28,5 34 9.2 8,5 D 203 28.6 34 9.3 8.5 F :1,86 28.6 3~t 9.4 8.6 B 185 28.7 34 9,4 8.7 A 125 28.7 34 9..4 8.6 E :100 28.8 34 9.4 8.6 C 99 28,8 34 9.5 8.6 C 93 28,8 34 9,4 8.6 E '105 28.9 34 9.4 8,6 C i09 28.9 34 9.5 8,6 C :154 28.9 34 9,6 8.6 E -146 29.0 35 9.7 8.6 i73 29.0 35 9,7 8.7 E 1.70 29,0 34 9.7 8,7 E 1,54 29.0 34 9.7 8.6 A i~'l. 7 29.0 34 9.5 8,6 A 1'10 29.1 34 9.6 8.6 C 88 29,'1 34 9.7 8.6 C 79 29,1 34 9.6 8.6 C ~51 29,1 34 9.5 8.6 F 50 29,2 34 9.6 8.5 F 29,2 34 9.7 $.6 ATI..ANTIC RI~CHI~*'IIgLD CO. ill'{- 7 PAGE 9-FIL, E , , FORMATION * BOI. tEI. I. OI..E , aUJt L. . ,------------------,----------------------------------, INDEX . DEPTH * DIP D.~f , DEV. DE¥. QIA~ DIAM , if'EST , * AZI, , 12;1. 1-3 2-4 * =A ************************************************************************* * 3016.0 29.3 34 9.6 8.5 * 30t8.0 }.~8 '325 29.3 34 9.6 8.5 * 3020,0 5.9 321 29,3 34 9.6 8.5 , 3022,0 9.2 85 29.3 35 9.6 8.5 * 3024.0 9.6 131 29.4 34 9.6 8.~5 * 3026.0 29.4 34 9,7 .8,6 * 3028.0 29.5 34 9,8 8,7 * 3030.0 29.5 34 9.8 * 3032.0 $.'6 2.42 29.6 34 9.8 8,? * 3034°0 29.6 34 9,8 8.8 * 3036,0 b.3 310 29.7 34 9.8 . 3038.0 29.7 34 9,8 * 3040.0 29,7 34 9.8 8.5 * 3042.0 29,7 34 9.8 8.5 * 3044.0 ~16.:5 199 29.8 34 9,8 8.6 , 3046.0 ~16.;5 212 29.9 34 9.8 8.8 * 3048.0 ~15.'6 211 30.0 34 9,8 * 3050.0 '1).~5 1t4 30.1 34 9,8 * 3052.0 30.2 34 9,7 8.8 * 3054.0 ~10.6 107 30.3 34 9,7 8.8 * 3056.0 30.3 34 9.7 8,7 * 3058.0 30.4 34 9,7 8'6 * 3060,0 30.¢ 34 9.7 8,5 , 3062.0 30.4 33 9.7 8,5 * 3064.0 5.5 I54 30.5 33 9.7 8.5 * 3066.0 6.20 160 30.6 33 9.7 8.5 * 3068.0 30.6 33 9.7 8.8 * 3070.0 4..1 136 30.7 33 9.8 8.9 * 3072,0 9.A -127 30.8 34 9,7 * 3074.0 ~.3 213 30.9 ;33 9,8 9.2 * 3076.0 31.0 :34 9.8 9,6 * 30,78.0 3,;7 I42 31.1 34 9,7 9.2 * 3080.0 4.4 9-6 31.1 34 9.7 8.7 . 3082.0 3.2 ~15 3t.2 34 9.7 8.6 * 3084.0 3.~1 119 31.2 34 9,6 8.6 * 3086.0 5.9 84 31,3 33 9.6 , 3088.0 3.;7 119 31,3 33 9,6 8,6 # 3090.0 31~3 34 9.6 8,6 , 3092.0 3.6 151 31.4 34 9.6 8,7 . 3094.0 ~.;7 239 31'.4 34 9,6 B B D D D D D D D C C E C C ATbABIlC RICHFIELD ,CO. IH-7 PAGE 10-FILE # FOR~A~.ICN # BGfEHOLE # GUAb, · ------------------#----------------------------------, INDEX DEPTH · DIP DIP # DE¥o DEV. DIAM DIAM # BEST 3096,0 0.6 42 31,4 34 3098.0 5.0 '120 31,5 34 3100,0 13.0 87 31,5 34 3102,0 4,2 ~77 31.6 34 3104.0 },'6 158 31,6 33 3106,0 9,9 ~1'56 31.7 34 3108.0 ~,~8 14! 31.7 34 '3110,0 5,.4 148 31.8 34 3112,0 4,.2 '141 31.8 34 3'114,0 31.8 34 3116,0 3.,4 291 31,9 34 3118.0 31.9 34 3120.0 ,2~,;7 ,70 31.9 34 3122,0 5,~4 86 31.9 34 3124,0 9.;5 I00 31.9 34 3126,0 3,~2 '148 31.9 34 3128,0 9,3 59 31,9 34 3130,0 ~i~,:3 54 32,0 34 3132,0 3,~0 55 32,0 34 3~34,0 4,.1 165 32,0 34 313&,0 b,;3 201 32.1 34 3138,0 ~,~0 ~19~ 32.1 3~ '3140,0 ~,9 208 32.2 34 3142,0 ~ie,'3 ~i92 32.2 34. 3144,0 ~2,.4 229 32.2 34 3146,0 8,;7 ~t2 32.3 34 .3148,0 ~,;? ~158 32.3 34 3150,0 ~,;5 149 32.3 34 3152,0 .~,.9 148 32.3 34 3154,0 9,~ 98 32.3 34 3156,0 5'0 '107 32,4 34 3158,0 4.;? :341. 32,4 34 3160,0 4.9 '358 32.5 34 3162,0 .~;6 't:58 32.5 34 · 3164,0 4;6 ~I81 32.6 33 3~66,0 2.9 203 32,7 33 3168,0 3~.? 33 :3~70,0 3~.8 34 '3172.0 ~12,.~ 27 32,9 33 3174,0 ~14.~ 85 33.0 33 9,6 8,8 C 9.6 8.8 C 9.6 8,8 C 9.5 8.6 C 9,5 8,6 9.3 D.6 A 9.3 $,6 C 9.3 8.6 C 9,4 8.~ 9.4 8.? C 9.4 8.8 9.3 ~.8 B 9.3 8.8 9.3 8.8 C 9,3 8.8 C 9.3 8.8 C 9.3 8,7 C 9.3 8.6 C 9,3 8.6 C 9.2 e.6 A 9.2 8.6 C 9.2 8,6 A 9.2 8.6 E 9.3 a.6 E 9.3 8.6 E 9.3 8.6 E 9.3 ~.6 C 9,3 8.6 C 9,3 B.6 9.3 8.6 A 9.3 8.6 A 9,3 8.6 C 9.2 B.? C 9.2 ~.~7 C 9.2 8.8 C 9.2 8,8 9.2 8.7 9.2 8.6 C 9.2 8.6 E # # AZI. , AZI. 1-3 2m4 , =A , 3176.0 5..1 100 33.0 33 9.1 8.6 3178.0 2..2 I03 '33.! 33 9.1 8.6 C 3100.0 4,1 90 33.2 34 9.1 8.6 C 3182,0 10.3 ~07 3302 34 9.1 8.5 C 318400 10.~I 12i 33.3 34 9.1 8.5 318600 ~15,0 121 33.3 34 9,0 8.5 E 3188,0 :10.3 125 33.4 34 9.0 8.5 3190,0 b.i 151 33.4 34 9.0 8,5 C 3192.0 6.:5 t81 33.4 34 9.0 0.5 3194,0 8,:0 2i9 33.5 34 9.0 8.5 C 319600 33,5 34 9.0 8.5 3i98,0 5.~8 188 33.5 34 9.0 8.5 3200,0 6,,I 129 33.6 34 9.0 8.5 A 3202.0 6,,4 123 33.6 34 9.0 8,5 A 3204,0 2..1 57 33.7 34 9.0 8.5 C 3206,0 ~,~7 112 33.8 34 9.0 8.5 A 3208,0 9.~4 ti4 33.8 34 9.0 a.5 A 3210.0 33.9 34 8.9 8,5 3212.0 ,4.~8 252 33.9 34 8..9 $,5 A 32~4,0 .4.~0 251 33.9 34 8.9 8.4 C 3216,0 3t9 I04 33.9 34 8.8 8.4 A 32i8.0 ~7 '1~67 34.0 34 8.8 b.4 C 322000 9.J ~08 34.0 34 8.9 8.4 D '3222,0 4.~2 172 34.0 34 8.9 8.4 D 3224.0 3.~8 101 34.0 34 8.9 8.5 B '3226.0 4.~4 'lOl 34.0 34 9.1 8.7 B 3228,0 ~.9 149 34.0 34 9.1 8.7 D 3230,0 ,~,~1 153 34.1 34 9.1 8.7 D .323200 ~:18.~4 258 34.1 34 9.1 8.6 F 323400 34.1 34 8.9 8.4 3236,0 8.;7 184 34.2 33 8.9 8.4 F 3238.0 9.;5 180 34.2 33 9.0 8.4 3240.0 ~.;7 ~78 34.3 33 9.0 8.4 D 324200 6,9 ~55 34.3 33 8.9 8;3 3244,0 4,~2 257 34.4 33 8.9 8.3 324600 34.4 33 8.9 8.4 3248*0 2~1 ~I, 5 34.5 33. 8.8 8.4 D 3250.0 8j7 1.57 34.5 33 8.6 8.4 D 325200 ~1'3.'6 .58 34.5 33 8.9 8.4 O '3254-0 9.;2 137 340:5 34 9.0 8.6 D Ali, ANtIC RICHFIELD ,CO. IH,,7 PAGE 12-FIIE 2 DEPTH 3256.0 8.9 152 34.5 3258.0 5.0 29 34.5 3260°0 ~18.;5 '166 34.6 3262,0 ;18.;5 166 34,6 3264,0 4,8 200 34,6 3266°0 4.9 255 34°6 3268.0 3,.2 107 34.6 3270,0 4,1 107 34°7 3272.0 5,;5 112 34°? 3274.0 ~..4 302 34.7 3276.0 5,5 85 34,7 3278.0 3.3 48 34.8 3280°0 3.;7 85 34,8 3282.0 9.~2 174 34,7 3284,0 9.;0 180 34.8 3286,0 8,3 :135 34.8 3288.0 6.~4 131 34.8 3290,0 5.;7 238 34,9 3292,0 5°4 209 35.0 3294.0 )10.9 .I38 35,0 3296,0 ~t~,~l -140 35.1 3298.0 ~,~3 i07 35,1 3300°0 6.9 ~iT 35.1 3302.0 e.~l 148 35,2 3304,0 1.~.! 140 35,2 3306°0 ~. 9 ~66 35.3 3308,0 10,0 159 35,3 3310.0 23,0 172 35,4 33~2,0 23.0 171 35.4 3314,0 ~15.0 168 35,5 3316.0 ~15.6 i72 35.5 3318.0 ~iS.~8 169 35.4 3320.0 -13.0 165 35,5 '3322,0 ,1}.'4 167 .35.5 3324,0 9,;5 150 35,6 3326,0 ~,Ii,4 152 35,6 3328,0 ~1~,8 168 35,? 3330.0 ~13.;7 169 35.7 3332.0 ,14.;7 174 35.? 3334.0 ~15.,4 174 35.8 34 9,2 33 9,2 34 9.2 34 9.0 34 8,9 34 8,9 34 34 34 8,8 34 33 8,8 34 9,0 34 34 9,2 34 9.2 33 9,2 '33 9'3 33 9.3 33 9,3 34 33 33 9.6 33 33 9.4 133 9.2 '33 :33 9.2 33 9.2 33 9.2 33 9,2 33 33 33 9,5 33 33 9°? 33 33 9,? 33 9,8 33 33 8.9 8.7 8.5 8.4 8.4 8°4 8.4 8.4 8.4 8.4 8.5 8.6 8.6 8.6 8.7 8,8 8.8 8.7 8.~6 8.6 a OUAb. --# INDEX * BEST * =A 3336.0 3338.0 3340.0 3342,0 3344.0 3346.0 3348,0 3350°0 3352.0 3354,0 ~3356.0 3358.0 3360,0 3362,0 3364.0 3366,0 3368,0 :3370.0 '3372.0 ~3374,0 3376'0 3378,0 3380°0 ~3382o0 3384,0 3386,0 3388,0 3390.0 3392.0 :3394.0 3396.0 ~3400.0 3402.0 3404,0 3¢06,0 3408.0 3410,0 3412'0 3414,0 4i..6 4{.~=8 0,9 ~2~.~.8 )10 9 35,,8 35,,8 '147 35,8 '155 35,8 35,8 35,8 35,8 35,8 35 ':178 35,8 ! 80 35.6 35,9 :332 35.9 3.'5 .' .8 35,8 '35,8 35,8 35.9 3'5.9 35.8 35,8 35,9 36,0 36.0 181 36,i 36'2 36,2 36.3 !32 36-3 86 36,3 36,,2 36,,,2 36,2 3:6.2 36. :3 36.3 36,3 13i 36.4 ~I05 36.4 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 34 34 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 33 ,10,2 9.1 10,2 9.4 10.2 9.2 10.3 9.0 i0,3 10.3 10,2 8,9 .I0.2 8.7 10.! 8.8 10.0 I0,0 8.8 10.0 10,0 8.9 ,10.0 8,7 ~10,0 8.8 .10.0 ~tO,O 8'8 9.9 8.9 9,9 9,9 9.9 9.9 9.2 9.8 9.i 9,8 9,2 9-9 9,2 9.9 9.0 9.9 8.8 9'9 9,8 9.7 8,5 9.5 9.3 9,2 9.2 8.9 ~9.2 8.9 9.2 8.8 9.2 9.2 9.2 8.7 9.2 8.7 e OUAb. --# ]'NDE:X # ~E EST # --A D F D .F D g A~bANIIC RICRFIEbD CO. IH-? PAGE 14-FIlE 2 ************************************************************************* , , FOR~ATIEN . BO~E~OLE ~ DEPTH , DIP DIP . DEV. DEV. DIAH , * AZI.. * AZI. 1-3 ***************************************************** . -----------, INDEX DIAM , BEST 2-4 * =A , 3416,0 9,.4 111 36,4 33 9,1 8.6 D * 3418,0 ;18,0 85 36,5 33 9,0 a,4 F , 3420,0 5..7 154 36.5 33 8.9 8.4 D , 3422.0 36.5 33 8.8 8.5 , 3424,0 36,6 33 8.8 8.5 # 342e.0 36.6 33 8,8 0.5 * 3428.0 36.6 33 8.8 8,5 * 3430.0 36.6 33 8.8 8.5 , 3432.0 36.7 33 8.8 8.6 * 3434.0 36.7 33 8,9 8.6 # 3436.0 36.8 33 9.0 0,7 * 3438.0 36.8 33 9,0 8,7 * 3440.0 36,9 33 9,1 8,:7 # 3442,0 5,~1 165 36,9 33 9.2 8,7 * 3444.0 4,9 126 37,0 33 9.2 8.8 F * 3446.0 4.~4 77 37.0 33 9,3 ~.8 D , 3448,0 37.i 33 9.3 8,8 * 3450.0 5.1 182 3~.1 33 9,5 8,9 D * 3452,0 9.8 150 37.2 33 9,5 a,8 D * 3454,0 4,~2 ~5,9 3'7,2 33 9.6 8,8 E # 3456,0 ~,15 159 37.3 34 9,6 8,8 * 3458.0 ,13..9 I02 37,3 34 9.8 8.9 * 3460,0 ~,0 I01 3'7.3 33 9.9 9.0 , 3462.0 ~.~1 ~16 37.4 33 9,9 9.1 * 3464.0 4.i8 178 37.4 33 9.9 9,2 C * 3466.0 4.9 198 37,4 34 9,9 9,1 C * 3468,0 5.;5 21.1 37,5 33 ~I0,0 9,1 C * 3470.0 4.;~ 47 37.6 34 .10-0 8.9 E -'~ * 3472,0 6.9 6.3 37.6 33 10,0 8,9 R * 3474,0 ~.~8 1.54 37.7 33 .10,0 8,8 E * 3476.0 0.9 210 37.8 33 .10.1 8,6 * 3478,0 3,;7 236 37,8 33 .I0,0 8,6 * 3480.0 3,.2 199 37.9 33 .I0.0 8.~5 E * 3482.0 ~.;7 173 37.9 33 9,9 8,5 E * 3484.0 3.5 220 37.9 33 9.9 8,6 * 3486,0 3.~0 277 37.8 33 t0,0 8,6 , 3488.0 37.7 33 9.9 8.8 * 3490,0 ,13.'6 .191 37.7 34 9,8 9,0 .D * 3492,0 37,7 34 9,8 9,0 * 3494.0 37.7 34 9,8 9,0 3496,0 3498.0 3500.0 3502.0 3504,0 3506.0 3508.0 3510.0 3512.0 351,4,0 3516.0 3518.0 3520.0 3522.0 3524,0 3526.0 3528.0 35'30,0 3532,0 :3534,0 3536,0 13538.0 3540,0 3542,0 3544,0 3546.0 3548.0 3550.0 3552,0 35!54.0 3556,0 3558,0 3560,0 3562,O 3564.0 3566.0 3568,0 3570.0 3572°O 3574,0 4 5,3 ~.;7 8 9.9 9.3 ~ 10,4 '13,4 8 ,~0 8 .: 3 P,~GE 15-FILE 2 BOFSfOLE , DEV, DIA~ AZI. 1-3 oo..o.omo.., INDEX DIA~ 2'4 * =A 37.7 34 9.8 9.0 173 37.7 34 9.8 9.0 176 37.7 35 9.8 9.0 37.7 34 9,8 9,0 160 37.7 34 9.8 9.0 146 37.8 34 9.8 8.9 f35 37,8 34 9.8 8,8 120 37*9 34 9.8 8.8 92 37.9 34 9,8 8.8 ~t3 38,0 34 9,8 8.8 161 38,0 34 9,8 8,7 '~72 38.0 33 9,8 8.6 ~186 38.0 33 :192 38,~ 33 9,8 8,6 i83 38,2 33 9,8 8.6 165 38,2 :33 9.7 8,7 38.1 33 9.7 8,7 I47 37,9 33 37.8 I50 37.8 33 9.7 8,7 121 37,8 33 9.7 8,7 37,8 33 9,7 8.7 37°8 34 9,6 8.6 37'8 34 9.,6 8,6 37,8 '33 9,7 ~171 37,8 33 9,6 8,6 ~158 37.8 33 9.6 8"7 t55 37,8 '33 9'6 8..7 171 3!7.8 33 g.5 37,8 33 9,5 37*8 33 9.5 37,8 :34 9,4 8.5 3:7,8 34 9,4 8.6 37.8 :34 9,4 8,7 207 37,8 34 9,5 8*8 37.8 34 9.6 8,8 37,8 34 9,7 8.8 154 37.8 33 9,8 8,8 167 37,8 34 9.8 8.7 233 37,8 :34 9.9 8,7 A~bAN]IC ,RICHFIELD COo IH-? PAGE 16-FILE 2 # FOI~I~A~ ~C.N # BO~'EHOLE DEPTH e D'~P DIP a DE~. DEg. DXAM DIA~ ~ AZI. ~ AZI, 1-3 2-4 3576,0 3578.0 3580.0 5.0 3582,0 3584,0 6.3 3586.0 3588,0 5.0 3590,0 3592.0 3594.0 3596.0 3,3 3598.0 3 ,~7 3600.0 4 .~2 3602.0 5 .~6 3604.0 6.44 3606,0 ~.6 3608.0 3610,0 5.6 3612.0 4.9 3614.0 3616.0 3618,0 3620,0 4.~2 3622.0 3624.0 3626.0 3,9 3628.0 3630°0 3632.0 3634,0 3636.0 3638~0 3640~0 ~.3 3642.0 5.3 3644.0 3646,0 3648.0 3650.0 3652.0 3654.0 OUAbo iNDEX BEST 74 37.8 33 9.9 8.6 B 37.8 33 9.9 8.7 177 37.8 34 9.B 8.7 D 187 37,8 34 9.8 8.8 F 61 37.8 34 9.8 8~9 D 79 37.9 34 9.8 8.9 D 109 38.0 34 9.8 8.8 F ~58 38.0 '34 9,7 8.8 F 173 38.0 33 9.7 8,8 B 77 38.0 34 9,7 8.7 E 80 38.0 34 9,8 8.6 E 83 38.0 34 9.8 8.6 ~ 122 38,0 34 9,8 8,6 E 160 38.0 34 9,8 8,7 E ~28 38,0 34 9,7 8.8 E 124 38.0 34 9,7 8,8 E 166 37.9 34 9,7 8.8 E 192 37,9 34 9,5 8.8 C 166 37.9 34 9.4 8.8 E 136 37.9 ~34 9,3 8'9 E 178 38.0 34 9,3 9,0 .C t77 38°0 34 9,2 9.0 C ~65 38,1 34 9°2 9,0 C 38,! 34 9,2 9,0 187 38.1 34 9,1 9,0 C ~3,5 38,1 34 9,1 9,0 C 78 38.1 '34 9,1 9,.1 C 79 38,2 34 9,0 9.! E 175 38.3 34 9.0 9.2 C 169 38,3 34 9.0 9,2 C 201 38.3 ~34 9,0 9.2 D 38.3 35 9.0 9,0 248 38,3 35 900 9,0 D 217 38,4 35 8.9 9.1 D 38-4 35 8,9 9,2 226 38.4 35 8,9 9,2 O 38.5 r36 8,8 9,3 224 38,5 36 8,8 9,3 B 38,4 35 8.8 9'3 38.4 35 8,8 9,3 ATbANTIC R~(iH~ IEbD ,CO,, i. IH-? P~GE 17-FIbE * * FORmAtION * BO~EHO~E * ''''''''''''''''''''--''--''--''----------------------, INDEX , DEPTH , DIP P~ , DEV. DEV. ~IA~ DIR~ , ~ e AZI. , AZI. 1-3 2-4 e =A * 3656.0 * 3658.0 ,~I 4.,2 141 * 3660.0 # 3662.0 * 3664.0 8,,,2 181 * 3666.0 8.:8 154 * 3668.,0 5,:5 1.4-1 * 3670.0 1,,!8 194 . 3672.0 * 3674.0 8.,0 1 90 * 3676°0 ~10,3 168 * 3698,,0 4.;? 154 * 3680.0 5 .:5 151 # 3682.0 4,-3 140 , 3684.0 e,4 129 . 3606.0 8.,2 125 ~ 3688.0 ?,;5 ~45 * 3690.0 &.9 189 ~ 3692.0 b.~7 184 e 3694.0 4.:5 176 ~ 3696.0 4.:5 172 , 3698.0 ~ 3700.0 5.;7 181 * 3702.0 2,;8 36 * 3704,0 ~,6 309 , 3706.0 6,;5 332 ~ 3708.0 b..l ~07 * 3710,0 ~.~7 106 , 3712.0 ~.~.8 147 * 3714.0 4,4 93 * 3716,0 ~.~6 'i33 * 3718.0 S.9 128 * 3720.0 8,~8 122 , 3722.0 ~.8 1.~35 * 3724.0 5.4 151 * 3726.0 28.2 96 * 3728.0 8.9 1'08 * 3730.0 ~.;7 ~14 * 3732.0 9.~1 158 * 3734.0 S.~1 146 36.4 38,4 38.4 38.5 38,5 38,5 '38,5 38.6 38,6 38.,,7 38.7 38.7 38,7 38,8 38.9 39.0 39.1 39.2 39. ,2 39.2 39.2 39,1 39.1 39,1 39.1 39,1 39.1 39.i 39,1 '39.0 39.1 39.1 39,1 39,1 39,0 39.0 39.0 3:9,0 39.0 39,,0 35 35 36 36 36 35 '35 35 36 36 36 36 37 37 37 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 8.9 9.3 8,9 9.4 D 8.9 9.5 8.8 9,4 8,8 9,4 D 8.9 9.4 B 9.0 9.4 B 8.9 9,6 B 8.9 9.9 8.9 9,.9 D 8,9 9.9 A 8.8 9,9 C 8,7 9, '9 C 8,7 I0,0 C 8,6 ~'10.~1 8.6 ~10,!1 C 8,6 "I0. I C 8,5 ~'10.'1 C 8,5 ~10.0 C 8.5 9,9 C 8.4 9.8 8.4 9.8 8.5 9,8 C 8.5 ?10,0 C 8,5 ~I0, 1 C 8.5 ~I0.2 8'6 '~10, 3 l 8,6 10.4 C 8,6 !:I0,4 A 8.6 ~10.5 8.5 I0,7 C 8,5 ~I0.8 C 8,5 "' 10. 8 C 8'5 ~10.7 C 8,5 ~10.:7 C 8.5 ~10,8 8,5 ~1{~.0 C 8.5 :~11,. 0 C 8 * 5 ~ 10,9 C 8.5 tt,.1 C A~LAN~IC RICHFIgbD ,CO. IH-7 PAGE 18-FILE # FOR~A~]EN # BQ~EHOLE # GUAno #---------------o--#----------------------------------, INDEX DEPTH · DIP DIP # DE¥. DE¥, D # RZI, # 1-3 2-4 # =A 3736°0 5..5 138 3g.o 36 8.5 37~8.0 6.~2 148 38,9 36 8.5 3740.0 5.8 151 38,9 36 8,5 3742,0 ~,0 156 38,8 ]6 8,5 3744.0 ~.9 161 38.8 36 B.5 3746.0 38.8 36 8.6 3748.0 38.? 36 8,6 3750,0 &.9 154 38,7 36 3752,0 8.1 155 38,7 36 8,6 3754.0 8.i8 163 38.7 36 8.6 3756,0 8.3 157 38.8 36 8,6 3758,0 5.~4 166 38.8 36 8,6 3760.0 ~.:5 1.72 38.8 ~36 8,6 3762°0 5.6 161 38.9 36 8,6 3764,0 8.3 176 38.9 36 8,6 3766.0 1..2 19~ 38.9 36 8,6 3768,0 ~,:8 187 39.9 36 B,6 3770,0 9.3 181 38.9 36 8,5 3772.0 ~..2 134 38.9 36 8,5 3774,0 9..2 158 39,0 3776.0 ~.3 i44 39.0 36 8,6 3778,0 3,3 1-58 39.0 36 B,6 3780.0 3.9 204 39,0 36 8,6 37~2.0 3..I 149 38,9 36 8,6 3784.0 2,;5 147 38.9 36 8,6 37'86.0 5.~2 19.9 39.0 36 3788.0 39.0 '36 8,6 3790,0 ~.8 171 39.0 36 8.6 3792.0 6,~1 162 38.9 36 8,6 3794.0 4,9 188 38.9 36 8.6 3796.0 5.;7 188 38,9 36 8,6 3798,0 b.9 190 38.9 '36 8,6 3800.0 ~.~5 217 38.9 '36 8,6 3802,0 38.8 36 8.6 3804,0 3.~5 87 3809 36 8,6 3806.0 4.9 164 38,9 36 8,5 3808,0 9,,2 192 39,0 36 8,5 3810.0 8.~0 174 39.0 36 8,6 3812,0 ~1~.9 188 39,0 36 8,6 3814,0 ~1.~.9 203 38.9 36 8,6 3816.0 3,9 3818,,0 3.9 3820,0 3822,0 3824,0 3,~5 3826,0 3828,0 4,~5 3830.0 3832.0 3834.0 5.~4 3836,0 3838,0 5.3 3840,0 S,;? 3842.0 3844,0 3846,0 3848°0 3850.0 3852.0 3854.0 3856.0 3858,o 3860.0 3862,0 4.~0 3864,0 3866.0 3868,0 3870.0 3872.0 3874,0 29,4 3876,0 29,5 3878.0 3880,0 3882,0 3884.0 9..1 3886.0 8.:8 3888.0 3890,0 3892,0 3894.0 9.9 188 38.9 36 8.6 :10.8 197 38.9 36 8.6 -10.8 188 38.8 36 8.6 10.8 180 38.8 36 8.6 10.8 189 38.8 36 8.6 10.8 119 38.8 36 8.6 10,8 149 38.9 36 8.6 10.8 175 39.0 36 8.6 10,8 170 39.0 36 8.6 10.7 180 39.0 36 8.6 'i0.7 179 39.1 36 8.6 ~10.7 191 39.1 36 8.6 10.6 194 39.2 36 8,6 -10,7 184 39.2 36 8.5 ~10..~ 167 39.1 36 8.5 ~10.5 39.1 36 8,6 ~I0-3 39.! 36 8,7 '10;3 39.1 37 8.7 10.1 39,t 37 8.7 I0.0 39.1 36 8.7 9.9 39.0 36 8.9 9.8 38,9 36 8.9 9.7 38.9 36 8,9 9.7 159 38.8 36 8.8 9.8 38,8 36 8.8 9.7 38,8 36 8.8 38.7 36 8.8 38.7 36 8,8 9.8 38,6 36 8,8 9.9 166 38.6 36 8.7 10.2 175 38.6 37 8,7 10.4 38.6 36 8.7 10.4 38,6 36 8.7 ~10.4 38.6 36 8.6 10,3 125 38.6 36 8.6 10,2 121 38,6 36 8.6 ~10,3 12-5 38.6 36 8.6 10.4 I57 38.6 36 8,7 10.6 ~I32 38,6 36 8.7 I0.7 60 38.6 '36 8.7 '10.7 AI'IaANIlC RICItFIEbD CO. Iii-? 'PAGE 20-FIIE , ,.---..-------------,----------------------------------, INDEX · DEPT~ ~ DIP DIP ~ DE~, DEV, DIAH DIAH ~ BEST 3896.0 4..8 85 38.6 3898.0 4.3 95 38.6 3900.0 3.9 .137 38.6 3902,0 4.'4 161 38,5 3904,0 38,6 3906.0 38,6 3908,0 5.S 177 38,6 3910.0 2.9 I~12 38.7 39t2,'0 ~. 8 160 38,7 3914,0 2.;7 76 38.'7 3916.0 }.ii 205 38,? 3918.0 ~.6 212 38,8 3920.0 ~ ..'.8 234 38.8 3922.0 3.3 85 38,9 3924.0 :[..;'7 177 38.9 3926,0 4.0 i40 38,9 3928,0 4.6 147 38,9 3930.0 39.0 3932.0 8..2 73 39,1 3934.0 6.;5 80 39,1 3936.0 S.~.O 42 39,1 3938.0 ~14.0 129 39-1 39'40.0 ~10.:5 151 39'1 3942.0 28,~1 235 39,1 3944.0 39.0 3946°0 ~10.;5 14'7 39.0 3948.0 6,8 134 38,9 3950.0 1~.~4 41 38,8 39.52.0 ii,, 9 54 38,.7 3954.0 5.4 68 38,7 3956.0 ~.0 125 38,6 3958.0 1.6 ~132 38,6 3960.0 5.1 1~10 38,.6 3962,0 3.;7 1'08 38,6 3964.0 3.6 82 38,6 3966.0 ~. 3 3011 38,6 3968.0 ii.O 174 38.6 3970,0 ?;6 136 38,6 39'72.0 6,3 127 38,6 3974.0 3.9 1'09 38,6 37 36 36 36 36 35 35 36 36 36 36 36 36 36 36 36 36 36 36 36 '36 36 36 36 36 36 36 36 36 36 36 36 36 36 37 36 36 36 : 36 8.8 8,8 8.9 8.8 8.8 8.8 8.8 8.7 8.6 8.6 8,6 8.7 8.7 8,7 8.7 8.7 8.7 8.7 8.7 8.6 8.7 8.8 8.9 8.9 8.9 8.9 8.9 9°O 8,9 8.8 8.9 8,8 8.8 8.8 8.8 8.8 ~10,6 10.6 10.6 10.6 10,6 10,6 IO,5 10,5 10,.5 10.5 10,5 10.:5 IO,5 10,5 10,5 I0,4 10,4 i 0,4 10,4 ~10.3 10,1 ~ 10. i 10'2 ~10.2 ~10.2 t0.:3 :I0.:4 i0.4 10.4 10.4 10.3 t0,4 I0,5 AI'I.~AItTIC R$CIt[IEIbD .CO. lilt-7 PAGE 21-FIL. E .i # . FORMATION * ,EOREHObE · DEP~ , DIP D~F , DiV. DE¥. DIA~ DIAM , * AZI. , AZI. 1-3 2-4 ************************************************************** * 3976.0 ~.5 107 38.5 36 807 * 3978.0 38.5 36 8.7 * 3980.0 38.5 36 8.7 * 3982.0 4.0 130 3805 36 8o~ * 3984.0 4.8 203 38.5 36 8.7 * 398600 }.0 ~14 38°5 36 8.6 * 398800 4.~0 i75 38.5 36 8.6 , 3990°0 3.;? 184 38.6 36 8~6 * 3992°0 3.6 160 38.6 36 807 * 3994.0 ~.6 137 38.? 36 8.7 * 399600 4,2 189 38.8 36 8°7 * 3998.0 6.9 182 38.9 36 8.6 * 4000.0 38.9 36 806 * 4002.0 23,;? 108 38.9 36 8,? * 4004.0 26.~6 92 39°0 36 8.7 * 4006.0 ~.9 185 38.9 36 8.6 * 4008.0 I~8 I93 38.9 36 8.6 * 4010.0 ~.4 182 38.8 36 8.6 * 4012.0 3~5 106 38.7 36 8.6 * 40t4.0 8,~8 199 3807 36 , 4016.0 5,3 2~4 3806 36 , 4018.0 ~,9 155 38.6 36 8,? * 402000 2.i8 154 38.5 36 8.7 * 4022°0 4.~2 149 38.5 36 8,6 * 4024.0 20:3 191 38.5 36 8.6 * 4026.0 4.3 154 38.5 36 8.7 * 4028,0 3,,0 196 38.5 36 8,7 * 4030.0 4.5 171 38.6 36 8.7 , 4032.0 4.4 ~52 38.7 36 # 4034.0 5;6 1;55 38,8 35 8.7 * 4036.0 5,4 142 38.8 36 8°6 * 4038.0 9.4 125 38.8 36 8.6 , 4040.0 5.9 ~I0 38.8 36 , 4042°0 ~..9 ~02 38.8 36 8.6 * 4044.0 4.:5 I30 38.8 36 8.7 , 4046.0 4.3 134 38.8 36 * 4048.0 4.~7 122 38.8 36 8.7 * 4050.0 7.6 85 38.8 36 8,6 # 4052°0 ~I~.4 108 38.7 36 8.6 * 4054.0 4~4 -110 38.7 36 8.6 10.8 10'9 10.9 10.8 10.9 10,9 10.9 ,10,9 I0,9 :10,9 10.9 ~10.9 10-.9 10,8 ~10,8 ~I0,8 10'8 '10.7 10.8 t 1.2 1 {.3 11'o. 3 II',3 I1.,3 I1,,3 11,.4 11-3 1:1,'.4 ,':11,,4 ~11.,3 '11,,4 ~1~,4 11,4 11,,4 11'4 * OUAb, --* INDEX , * rE, EST # # --A C il C C C C C C C C C F C C C C A A C C C ¢ C C C C C C C C C C C C C D C ATLANTIC RACHEIELD ,CO. ilH-7 PAGE . 'FORMATION # ,------------------#----------------------------------, D~P~H , DiP D~F # DEV. DEV. ~IAM DIAM , AZ1. # AZI. 1-3 2-4 4056°0 5.3 t07 38.6 36 8.6 1~.3 4058.0 4.8 87 38.6 36 8.6 ~1~.2 4060°0 4.6 124 38.6 36 8.7 11'1 4062.0 4,:5 155 38.6 36 8.7 1~.1 4064.0 4,4 I35 38.6 36 8.6 1t,1 4066.0 6.9 93 38.7 36 8.7 4068.0 38°? 36 8.7 Ii.'1 4070,0 ~iJ.O 95 38.7 36 8.7 1~..1 40?2,0 8.;7 210 38.8 36 8,7 ~1~.1 4074.0 6,~8 .I33 38,8 36 8.7 ~1~.I 4076,0 ~,~0 ~130 38,8 37 8.7 4078,0 38,8 36 8-7 4080,0 '}.:3 ,=165 38,8 36 8.7 ~1~.0 4082,0 },13 13'4 38,8 36 8,7 ,I,~.0 4084.0 3.4 I37 38.8 36 8.7 1~.0 4086,0 2,6 I34 38.8 36 8.7 4088,0 5°~ 244 38,8 36 8,7 li-O 4090.0 ~.;5 264 38,7 37 8°? 10-9 4092,0 7j6 ~165 38,6 36 8,7 11.0 4094.0 5.;5 *155 38,5 ~17 8,7 ~1~,0 4096,0 .~.;3 60 38,4 36 8,7 4098°0 38.3 36 8.? 10-9 4i00,0 38,3 36 8.7 10.8 4102,0 :{,4 '.182 38'3 37 8.7 10,8 4t04,0 {,~7 184 38.3 :37 8.7 ~t0.8 4106.0 6,8 "278 '38.'3 '36 8,7 I0-9 4108,0 4.9 202 38,.3 36 8,? ~I0-9 4110,0 ~'3 318 38,3 36 8.7 10.9 4t12,0 38'3 36 8.7 10.9 4114.0 4,~5 347 :i'38-4 36 8,7 10.9 41i6.0 38,4 ~36 8,7 ~10-9 4i18,0 15,9 ~71 :38.4 :36 8.7 10,9 4120.0 ~16,~0 ~l 38,4 36 8.? ~t0.9 4122.0 ~7-0 44 38,,4 36 8,? 10.8 ~4124.0 8'3 75 38,5 '36 8,7 '10.8 ~4126,0 38,6 36 8,? I0,8 .4i28,0 b.~l :1:21 ~38,6 36 8,7 ~10.8 4~30.0 ~.:5 :5~ 38.6 ~3~ 8.7 ,10.8 4132.0 ~1~,0 66 38,? ~3:6 8,6 ~10,:9 4134.0 ~,6 51 38.8 ~37~ 8,6 10'9 ************************************************************************* RTbANT~C Ri~CH~IEbD CO. iI~H-? PAGE 23-FIbE 2 ,#,,#,,,,~,##,.~#,,,#.,,,,#**#### #,**,,,#,#,,#,##,#,**##,#,,#** ~ ,#,##****** , ,--..-------.------,----------------------------------, I~DEX a ~ DgBTH ~ DI:~ D~ · D~ V. D~V. ~IA~ , ~ AZI. * AZI. 1-3 ***************************************************** , 4136.0 4.~2 101 .38.8 37 8.6 * 4138.0 4.3 146 38.8 36 8°6 , 4140.0 S.;5 131 38.8 36 8.6 * 4142.0 5,0 122 38.7 37 8.6 , 4144.0 4.9 92 38.7 36 8.6 * 4146.0 6._3 124 38,7 37 8,6 * 4148.0 ~.~4 131 38.? 37 8.6 * 4t50,0 ~.'6 ~17 38.7 36 * 4152.0 6.74 ~t. 13 38.6 36 8.6 , 4154.0 6.2 87 38.5 36 8.5 . 4156,0 6.;7 96 38.5 36 8,6 * 4158.0 4.9 97 38.4 36 8.7 * 41.60,o 6.5 151 38,4 37 * 4162.0 38.4 37 8.6 * 4164.0 3.3 208 38.4 36 8,6 * 4166.0 6.3 126 38.4 36 8.6 , 4168.0 6;5 1:22 38.4 36 8°6 * 4170.0 4.~8 123 38.5 36 8.6 * 4172.0 5.~4 141 38.5 36 8.6 * 4174o0 1.'3 10.9 38.5 36 8.6 * 4176,0 8..1 88 36.5 36 8,6 , 4178.0 ~.6 ~37 38.6 36 8.6 * 4180.0 3.:8 145 38.7 '36 * 4182.0 4.0 :153 38.6 36 8.5 * 4184.0 4.:5 182 38.6 36 8.? * 4186,0 ~5 188 38,5 36 8.8 * 4188.0 15.0 164 38.5 36 8.7 * 4190.0 38.4 36 8.6 * 4192,0 6,2 I39 38.4 36 8,6 * 4194.0 10.;5 15'7 38.3 36 8,6 * 4196,0 38.3 36 8.6 # 419it,.0 4t~7 '65 38.3 36 8.6 * 4200.0 5o~6 197 38.3 37 8.5 * 4202.0 8,.1 184 38.4 36 8.5 * 4204.0 38.4 36 8.5 * 4206.0 14,~4 I30 38.4 36 8.5 # 4208.0 9,0 112 38,5~ 36 8,6 * 4210.0 4,.1 45 38.5 36 8.? * 4212.0 0.9 235 38.5 36 8.7 , 4214,0 38°5 36 8.6 DIAH #tEEST , 2-4 , =A , 10,9 .I0,8 10,8 10,8 ~10,9 10,7 t0,6 10,5 1 I0,5 ~t0.9 ~'1~..0 1:~'0 ~1~,0 ~i~,i '11'.1 ~1~.0 11,0 I t' i il,i 1 t, 1 iI,0 it'O ii.O ATbANTI¢ RICHFIEbD .CO, IH-? PAGE * # FORNATION # * DEPTH · DIP DIP #- DEV, DEV, DIAN DIAN ~ # AZI. # AZI. 1-3 # 4216.0 3.,.1 g9 38.4 37 * 42),8,0 6,~4 69 38.4 36 * 4220.0 4,0 57 38.5 36 8.6 * 4222.0 b.O 117 38.5 37 8,6 * 4224,0 2,;'/ 101 38,5 36 8,6 # 4226,0 3..0 105 38.4 36 8.6 * 4228.0 8,4 99 38.4 36 8.6 e 4230.0 9.6 96 38.4 36 8,? # 4232.0 9,.2 I~,11 38,3 36 8.? * 4234.0 ~14.'6 96 38.3 37 8.6 # 4236,0 4.6 93 38.3 3'/ 8.5 * 4238.0 3,~5 78 38,3 36 8.5 # 4240,0 ]~.;7 86 38,3 36 8,5 * 4242,0 S,O 1.74 38.4 37 8,5 * 4244.0 5.~2 1'31 38,4 37 8.5 * 4246.0 b.9 125 38.3 36 8,6 * 4248,0 6,;5 1'34 38,3 36 8,6 * 4250,0 &,;5 165 38.3 36 8,6 * 4252.0 6.~1 17.3 38,3 36 8,7 a. 4254,0 :*I ~.~;.8 125 38,3 36 8,? #' 4256.0 8,~1 1.03 38.3 36 8,7 * 4258,0 'I,~2 /~1.5 38,3 36 8,7 # 4260,0 'A,~! 151 38.3 36 8.8 # 4262.0 4.~8 129 38.3 37 8,8 * 4264.0 4.3 1~16 38.3 36 8.8 * 4266,0 4,9 89 38,3 36 8,8 * 4268.0 5.0 94 38.3 37 8,8 * 4270.0 4.6 156 38.3 37 8,8 # 4272,0 .~.3 209 38,2 37 8,8 * 4274.0 3.i8 ]:12 38.2 37 8,9 # 4'276,0 5.?.0 1'38 38,! 37 * 4278.0 ').;7 145 38,! 36 8,7 * 4.280,0 'A,~4 ~53 38-I 37 8,7 # 4282,0 5...3 12;5 38-0 .37 8,8 # 4284,0 b. 3 9.7 38,0 37 8,8 * 4286,0 ~10.1 70 38,0 37 * 4288.0 38,0 3'7 8.8 # 4290,0 9;6 94 38,O 37 8,6 * 4292,0 tl ,'~0 I'I9 37.9 37 8.5 * 4294.0 9,0 'I09 37-9 37 8,5 ATbANTIC R$CH~IE~D ~CO, ilH-7 PAGE 25-FI~£ 2 * * FORHA~ION * '''''''''''''''''''''''''''''''''''''''''''''''-''''-', i~D~X ~ DEPTH · DIP D~ * " AZI. ************************************************************************* * 4296,0 9.~5 122 37.9 37 8,4 1~.1 * 429B.0 ~,6 117 37.9 37 8,4 1~.0 * 4300.0 3.-3 121 37.9 36 8.3 1~.0 * 4302.0 9,8 le6 37.9 36 8,3 1~,0 * 4304.0 37.9 36 8.4 1~.0 # 4306.0 37.9 36 8.4 1~.0 # 4308.0 37°9 36 8.4 1~.0 # 4310.0 ~1D,.4 172 37.9 36 8,4 1~,0 * 4312.0 ~I~,~B 158 37.9 37 8.5 I~.0 # 4314,0 37.9 36 8,6 1~.0 , 4316,0 ,ID,3 192 37,9 36 8,6 1~.0 * 4318.0 5..4 186 37.9 37 8.5 1~.0 * 4320.0 ~10,~4 56 37,9 37 B,6 -1~.0 * 4322.0 ~.:5 36 37.9 37 8.6 ID.O * 4324,0 5o~4 97 37.9 37 8,6 1~,0 # 4326.0 4.~7 126 37.8 37 8.7 1.0.9 # 4328.0 4.:5 195 37.8 37 8.7 lO.g , 4330.0 ~1~.:7 99 37.8 37 8°6 1~.0 * 4332°0 8.i8 12~ 37.8 36 8.6 .ID.O * 4334.0 5,9 107 37.7 36 8,6 1~,0 * 4336.0 ~,~1 108 37,7 37 8.6 i~.0 * 4338.0 37.7 37 B,6 1D.O * 4340.0 ~.~4 I30 3?.7 36 8.6 1~.0 , 4342.0 ~.3 142 37.? 36 8°6 1~.0 * 4344.0 ~32.4 257 37.8 36 8.6 1D.O . 4346.0 )10,~8 188 37.8 36 8°6 t~.O * 4348.0 ~.9 148 37.8 ~6 8.6 .1~o0 * 4350.0 '10.3 i18 37.8 37 8.6 1~.0 , 4352.0 ~16.2 132 37.9 37 8.6 i~.O * 4354.0 28.~8 243 37.8 37 8.6 1~.0 * 4356.0 25;6 ~15 37.8 37 8.6 1~.0 ~ 4358.0 9.~6 103 37.8 37 8.7 1~.0 * 4360.0 9.~0 t17 37.8 3? 8.7 I0.9 * 4362.0 9r2 115 37.8 37 8.7 10.8 # 4364.0 9.0 84 37.7 36 8.? 10.8 * 4366,0 ,ID.~2 115 37.7 36 8,6 10.8 * 4368.0 8,3 88 37,6 36 8,6 10.8 * 4370.0 ~1{,6 76 37.6 37 8.5 10.8 # 4372.0 e.3 125 37.6 37 8,5 t0.8 * 4374.0 2,;? 246 37.6 36 8.6 10,7 A2bAN~IC ,RiCHfieLD CO, IH-7 PAGE 26-FIiE , # FORNAT. IC:N , BQ[EHaLE * · .---.----.---------#----------------------------------. INDEX · DEPTH * DIP DIP . DEV. DE~. DIAM DIRM # ~EST # * AZI. , AZI. 1-3 2~4 ************************************************************************* * 4376.0 , 4378.0 * 4380.0 * 4382.0 ~.:3 * 4384.0 5.:3 , 4386.0 ~.;7 * 4388.0 3,6 * 4390.0 9.6 . 4392,0 * 4394,0 . 4396,0 * 4398,0 * 4400,0 0,9 , 4402.0 3.~0 , 4404,0 * 4406,0 * 4408.0 3.1 * 44i0,0 4.i8 * 4412,0 . 4414,0 , 4416.0 * 4418,0 '* 4420,0 3.~t * 4422,0 2.i8 * 4424,0 * ~4426,0 * 4428.0 ,* 4430,0 * .4432.0 # 4434,0 , 4436,0 , 4438,0 , 4440.0 * 4442.0 4.6 , ~4444~0 , 4446,0 ~.9 , 4448.0 , .4450,0 * 4452,0 * 4454,0 5;3 256 37.6 229 37.6 214 37,6 200 37.6 162 37.6 84 37,6 86 37.6 76 37,6 I09 37,6 ~12 37,6 138 37.6 37,6 88 37.5 104 37.5 ~ 144 37,5 I01 37.4 . i38 37,4 '194 37,4 ~'199 37,4 ~19t 37,4 182 37,5 193 37,5 127 37,4 i32 37,4 t05 37'3 ::352 37.4 90 37.4 7.7 37*5 .74 37,5 95 37,6 ~135 37,6 ~120 37.5 !108 37,5 .128 37.5 '187 37,6 208 37,6 ~180 37.5 ~I63 37,5 149 37.6 '~i8 37,6 36 37 37 37 36 36 36 36 37 37 37 37 ~37 37 36 36 37 36 36 37 36 36 37 37 '37' 36 37 37 36 36 36 36 36 36 36 36 36 8,6 8,6 8,6 8,7 8.7 8.6 8,6 8,6 8,7 8.7 8.8 8,8 8.7 8,7 8,7 8.7 8,6 8.6 8,6 8.7 8,7 8.6 8 ,, 6 8,6 8.6 8°6 8.6 8,'/ 10.7 10.7 10,7 10.6 10.6 10,6 10.5 10.3 .~10,4 '10.5 10.7 t0.9 10-9 I0,9 I0,9 10.8 10.9 ll~.O 1~.0 I~.0 1~,1 ,1~'1 ~1~.0 11~.0 1~.0 i~.0 i~.0 i~.0 IO'V 10.9 i10.9 ~10,9 10.8 i0.8 .10.9 ~I0.8 10,8 :'10-8 t0,8 10'8 D C A C C C C C C C C A C C C ¢ C C C C C C C C C C ATL, ANI~IC RI. el. Ii~IEbD CO, :114-7 PAGE 27-FIbE =.~ # FORHATIO~ ~ .fORE~.OLE # QUAL. · ------------------,----------------------------------, INDE~ DEPTH # DIP D~F # DEV. DEV, 'UIA~ DIAH #tEEST # AZt. e AZI. 1-3 2-4 # =A 4456,0 4458.0 4460.0 4462,0 4464,0 4466.0 4468,0 4470,0 4492.0 4474,0 4476.0 4478,0 4480,0 4482,0 4484.0 4486,0 4488,0 4490,0 4492.0 4494,0 4496.0 4498,0 4500,0 4502,0 450400 450600 4508.0 4510,0 4512,0 4514.0 45i6,0 4518.0 4520,0 4522,.0 4524.0 4526,0 4528,0 4530,0 4532,0 4534,0 5,:0 8.,2 4 4.1 ."/., 8 5,3 5 .'~2 2*5 .6.9 5,9 ~ .~4 4.9 5 .~ 2 6 4 .;7 131 122 11t 78 66 214 222 i49 171 108 69 92 202 ~145 99 14'I 14t 130 ~20 126 137 1~! 7 151 37.6 37 8.7 37.6 37 8.5 37.6 37 8.5 37.6 37 8.5 37.6 37 8.5 37.6 37 8,6 37,6 37 8,6 37,5 37 8.5 37.4 37 8.6 37,3 37 39.3 37 8,7 37.2 37 8.7 37,2 37 8.8 37,2 '37 8,8 37.2 37 37.3 36 37°3 36 8,6 37.3 36 8.5 37.3 36 8.6 3703 37 8,6 37,3 36 8-6 37,4 136 8,7 37,4 ~36 8.7 37.4 36 8.7 37,4 36 8.7 37,5 36 8.7 37,5 ~36 8.7 37,5 36 8.6 37,5 36 8,7 37,5 136 8,7 37,5 36 37,5 36 8.7 37,5 36 8.6 37.5 36 8.6 37,6 36 8.6 37.6 36 8.6 37,6 36 807 37.7 36 37.7 '36 8,6 37.8 36 8,6 10.8 C 10.8 C 10.7 C 10.7 C 10.6 C ~10.5 A .10.5 C t0.4 E 10.4 i0,4 10.4 10.4 C '10,4 C 10.3 C '~I0.3 C ~10.3 C 10.4 k 10..4 A ~10,3 C '10'3 C 10,3 C ~10.3 C ~i0,2 C 10'2 A ~10.2 C I0.2 C 10.2 C 10.2 C iOo 2 ~C ~10.2 C 10. 2 C 10.2 C ~ 10.2 C 10.2 C I0.2 10..2 C ~10' 2 C · ~10.2 C :10.2 C AILANIIC RICHFIEbD CO. IH-? PAGE 28-FIRE # # 'FO~ATi~£N # BQ[EHOLE # GUAm. # ,----o-------------#----------------------------------, INDEX 4536°0 6,.1 109 37,8 4538,0 4.8 107 37,8 4540,0 4.~4 145 37.9 4542.0 3.;7 140 37.9 4544.0 ~13.'4 t05 38.0 4546,0 38,0 4548.0 38,0 4550.0 6..I 91 38.1 4552.0 8.0 ~135 38.2 4554.0 3.~1 I34 38.2 4556.0 3.~4 '140 38.2 4558.0 3.~4 .139 38.2 4560.0 4.6 164 38,2 4562.0 6.6 158 38-3 4564.0 6,9 82 38,3 4566.0 5.~0 93 38-3 4568.0 4.i8 i73 :38.4 4570,0 38~4 4572.0 38.4 4574.0 6.;? 43 38,5 4576,0 1,~:2 ~i01 38,5 4578.0 5.~8 '148 38.6 4580,0 &.2 ~'146 38,7 '4582.0 9.~I 79 38,7 4584.0 3.~8 ~til 38'8 ~4586,0 4':5 ~138 38,9 4588.0 4;3 ~1:36 38,9 4590.0 5.'6 :1:69 36.9 4592,0 ~'.~0 ~169 39,0 4594.0 3,~6 ~i38 39.0 .4596,0 39,t 4598,0 .28,i2 ~38 39,2 ,4600.0 .1.~4 I40 39'2 4602.0 {.0 141 39'3 .4604,0 5.2 ~15:3 39.3 4606,0 4,~'0 ~14t 39'3 4608'0 5.~:8 ~i05 39'4 4610,0 6'3 ~I09 39,5 ~46t2.0 ~.9 ~106 39,5 4614.0 '~..~! 70 39,5 lAM DIA~ * BEST 1-3 2-4 * =A 36 8.6 36 8.5 36 8.5 36 8.6 36 8.6 36 8.6 36 8.7 36 8.8 36 36 8.9 36 8.8 36 '36 36 8.8 36 8.8 36 8,8 36 8,7 36 8.7 36 8-7 36 8,7 36 8.7 36 8,7 36 8-7 36 8,6 36 8.7 36 8.8 36 36 8.8 37 8-7 37 8.7 37 8,7 36 8,7 36 8.7 36 8.8 36 8.8 36 8.8 37 8°8 37 8.8 36 8.8 37 8.8 I0.2 I0.2 10.2 10.2 10.2 10.2 10.2 i0.2 i0.2 10.2 10.2 10.2 10.2 10.2 10'2 10'2 10.2 10.2 10.2 10.2 10.2 i0.2 10.2 '10.2 ~10'1 iO.i '10.1 :'lO.:i 710.1 10.2 10.2 10,2 ~10,2 .10.2 ~i0,2 ~'~:{L0, 2 ~.10.2 ATbANTIC RICHf'IELD CO, IH-7 PAGE 2C~-FILE ~ ,------------------.----------------------------------, INDEX ~ DEPTH · DIP DI.P ~ DE'V. DE~, DIAM DIA~ ~ BE~T # 4616.0 6.8 58 39.6 37 8,7 , 4618.0 5.8 i35 39,7 36 8.6 # 4620.0 5..7 i31 39,7 36 8,6 # 4622,0 39,? 36 8,7 , 4624.0 39.8 37 8.7 * 4626,0 6..7 87 39,9 37 8.7 * 4628,0 39.9 36 # 4630.0 40.0 36 8,8 # 4632.0 3.8 21 40.0 36 8,8 * 4634.0 15..4 318 40.1 36 8,8 * 4636.0 4~1 149 40.i 36 8.8 * 463.8.0 4.9 136 40,2 36 8.8 * 4640,0 40,2 36 8,8 * 4642.0 40,3 36 # 4644.0 3..1 115 40.3 36 8.8 * 4646.0 6.4 181 40.4 36 8,8 # 4648.0 3.2 196 40.4 36 8.8 # 4650.0 5,3 143 '40.5 36 8,7 # 4652,0 ~1~.9 344 40.5 36 806 * 4654.0 5,9 161 40.6 36 8,7 # 4656,0 ~.~8 158 40.6 36 8.7 * 4658.0 4.~2 162 40,7 36 8,8 # 4660.0 5.4 165 40,7 36 8.7 # 4662,0 40.8 36 8.7 # 4664.0 ~.~1 128 40.8 36 8.7 * 4666.0 5.9 ~12 40.8 37 8,7 # 4668.0 5.9 ~19 40.9 37 8.7 * 4670.0 5.~5 129 40,9 37 8.7 * 4672,0 ~..1. 84 40.9 37 * 4674.0 8.1 128 41.0 36 8,7 # 4.676.0 6.3 148 41.0 37 8,7 * 4678,0 4.1 139 41.1 37 8.7 * 4680.0 3.~2 123 4i-1 36 8.8 # 4682.0 4.~7 I30 41.t 37 8.$ * 4684.0 ~.8 t71 41.2 37 * 4686,0 41.3 37 8.8 ~ 4688.0 41.3 36 8,9 , 4690.0 5~0 148 41.3 36 8.9 , 4692.0 5..1 142 41.4 36 8,8 ~ 4694,0 5~2 :163 41.4 36 8,8 10.2 ~10.2 ~10.2 I0.2 ~10.2 ~10.2 ~10.2 10.2 ~I0.2 10.2 10.2 I0,2 10.2 i0,2 10'2 10,2 10,2 10,2 10'2 ~10.2 ~10,2 10,2 10.2 I0'2 ~10.~ ~10'2 ~10'2 10.2 10.2 lO,1 10.2 I0,2 i0.2 ~I0.2 ~10,2 .I0.2 10.1 I0.:1 10,'1 iO,l C C ¢ C F C C C C C C C D D D C C C ¢ C C A'II~ANTIC RI~CH~'IEI~D .CO. ilH-7 PAGE 30-FISE 2 , ~.--------- ..... ---,.---------------------------------, I~DEX , , Ali. , AZI. 1-3 2-4 * =A , 4i~96.0 469 ii. 0 4:?00.0 4702.0 47o4.0 13.,1 4~706.0 '~. 0 ~710,0 47i4.0 47i6.o 47:~6,0 5.6 4720.0 4724.0 4726.0 4728.0 4730.0 4732.0 4734.0 4736.0 4738.0 4740.0 8.~5 4742.0 4744.0 4'746.0 6.4 4748.0 4750.0 4752.0 ~.~2 475400 4758.0 4762.0 4764,0 ~13.6 4766,0 I0,~2 4768.0 4 4770.0 4;4 4772.0 4774.0 4.9 C 14,4 D 158 4t.4 55 41.4 41.5 41.5 70 41.5 93 41.6 62 41.6 I07 41.6 161 4t.7 157 41.7 41.8 123 41.8 14t) 41,9 41.9 61 42.0 42.1 87 :42ol 159 '42.! 147 42,1 128 4202 149 42.2 119 -42,3 118 42,3 ~42,4 63 42.4 127 42-5 135 42.5 108 4205 96 .42.6 110 42.7 92 42.7 42,8 123 42.8 42,9 51 42.9 109 ~43,0 1'31 43,0 126 43,t 110 43,1 36 36 36 37 37 37 36 36 36 36 36 36 36 36 36 36 36 :}6 36 36 37 37 37 37 36 36 36 36 36 36 36 ~36 36 8.8 8.8 8.8 8.7 8.7 8,7 8.6 8.6 8.7 8.8 8.8 8.7 8.7 8.8 8.8 8.8 8.8 8- 8 8.8 8,7 8.6 8.6 8.6 8.6 8.6 8,5 8.6 8.5 8.5 8.6 8.6 8.6 ~10.1 I0.1 I0.I I0.1 10.2 10.2 10.2 10.1 ~10'I 10.1 10.1 10,1 ~lO,i :10.0 I0.0 I0.0 10.0 : 10,0 :10.0 10.0 I0.0 10.0 i0.0 t0.0 I0.0 t0,0 ~i0.0 10.0 10.0 ~I0.0 ~10.0 I0,0 I0.0 .I0.0 10,0 10.0 9-9 9,9 9,9 D C C C C C C C D D F ATI,,ANTIC RICHFIEbD CO. 1H-7 PAGE 31-FILE ,i # FORMAT ION , BORE~OLE DEPTH · DIP ~£,IP # DE¥. DEV. DIA~ 4776.0 4778,0 4780,0 4,;7 4782.0 ~-0 4784.0 4786*0 4768,0 4790.0 6.6 ~4792,0 '4794,0 4796,0 4798.0 4800,0 8,3 4802,0 4*3 4804,0 4806,0 4808.0 4812,0 4814.0 ~4'816,0 4'820.0 4822:.0 5*0 4824,0 4826.0 4828,0 4830,0 4~32,0 5;4 4834.0 4836,0 4'8 38.0 4840,0 4842.0 4844'0 '4846,0 4848.0 ~4850,0 48!52.0 6,,:2 4854-0 4.~8 1.38 162 164 84 85 t72 172 ,165 174 ~139 t, 22 103 158 ,~179 ~187 97 '104 :140 ~ 129 180 1.72 43.1 36 8.6 43.2 36 8.5 43.3 36 8.6 4303 36 8.5 43.3 36 8.5 43.4 36 8.5 43.4 36 8.5 43.5 36 8.6 43.5 36 8.6 43.6 36 8.6 43.6 3~ 8.6 43.7 36 8.6 43.7 36 8.6 43.8 36 8.6 43.8 36 8.6 43.8 36 8.6 43.8 36 8.6 43.9 36 8.6 43.9 36 8.6 44.1 37 8.6 44.1 37 8.6 44.1 36 8.6 44.2 '36 8.6 44.2 36 8.6 44.3 36 8.6 44.4 36 44.4 36 8.5 44,4 36 8.6 44.4 36 8.7 44.4 36 8,7 '44.5 36 44,6 36 8.7 '44,6 36 8,6 44,6 36 8.7 44.7 36 8.7 44,7 36 8.7 44.8 36 8.7 44.8 36 44.8 36 8.7 44.9 36 8.7 , OOAb. -----------* INDEX 1AM 2-4 9,9 E 9.9 C 10.0 C 10.0 C 10.0 F 9.9 D 9.9 D 9,9 C 9.9 C 9..9 C 9-9 C 9.8 C 9.8 C 9.8 El 9,8 E 9.8 E 9.8 A 9.8 9.8 C 9,8 C 9.8 C 9'8 C 9.8 C 9.8 C 9.8 9,8 E 9.8 E 9.8 E 9.8 F 9.8 9.8 9,8 9.8 9.8 D 9.8 9.8 D 9.8 9.8 C 9.8 C AILAN~IC RICHFIELD .CO. IH-? PAGE 32-FILE , # FOR~A~EN # BQfEHOLE # QUAb. . #------------------,-----------------------------o----, INDEX # DEPTH * DIP DIP # DE¥, DE¥. DIAM DIAM # BEST · * AZI,, * AZI. 1-3 2'4 * ************************************************************************* * 4856.0 1~.,2 51 45.0 ~ 4858.0 6.8 69 45.0 . 4860.0 9.6 149 45.1 # 4862,0 8.6 169 45,1 * 4864.0 9.,2 167 45.2 # 4866.0 6..1 158 45.2 * 4868.0 49.2 # 4870.0 3.9 35 45.3 # 4872.0 ~.~7 125 45.3 * 4874.0 5.0 124 45.3 # 4876.0 4.~7 -iii 45.3 * 4878.0 45.0 18-7 45.4 # 4880.0 4~.0 I84 45.4 # 4882.0 4~.4 182 45.4 * 4884.0 45.4 # 4886.0 5.~1 140 45.5 * 4888.0 5+~ 125 45.6 . ,4890.0 5~1 1.52 45.6 # 4,892.0 5.~4 116 * 4894.0 ~,~0 89 45,7 * 4896.0 ,45.8 * 4898.0 45°8 * 4900.0 45,8 * 4902.0 8.~4 89 45,9 * 4904,0 45.9 , 4906.0 46,0 . 4908.0 ~,9 ~8 46.0 * 4910,0 46.1 * 4912.0 46.! # 4914,0 {,~ 161 46.1 * 4916,0 2.~5 188 46.2 . 4m18.0 46.2 * 4920.0 46.2 * 4922.0 ~12.~3 50 46.2 * 4924.0 ~19,~7 55 46.3 . 4926.0 ~.~5, ~ 46.3 * 4928.0 ,10.9 20 46.4 * 4930.0 8.~8 ~3 46.4 * 4932.0 ~12.3 ,43 46.4 * 4934.0 ~10~0 51 46.5 36 ~6 :36 8,7 9,8 B 8.7 8.7 9.7 C 8,7 8.7 9,8 C 8.7 9,8 C 8,7 9.8 8.7 ,9.8 A 8.6 9.8 8,6 9.8 F 8.6 9.8 D 8.6 9.8 F 8.5 9.8 D 8,5 9-7 D 8,6 9-7 8,6 9,6 D 8,6 9'6 D 8,6 9.6 ,F 8.~ 9.6 :F 8.6 9.6 D 8.6 8,6 9,6 8.6 9,6 8.6 9,6 D 8.6 9*6 8.6 :9-6 8.6 9-6 B 8,6 9,6 8.6 8.6 9.4 F 8,6 9',4 D 8-6 8.6 ~9.4 8.6 8.6 9'4 F 8.6 9,4 D 8.6 9~4 F 8.6 9.4 D 8.6 9.4 C 8.6 A~bA.N]IC RICHF!~bO ¢0, I~-7 PAGE 33-F~!E 2 #---.--------------#----o-----------------------------# INDEX DEPTH # DIP DIP # DE¥o DE¥, OIA~ DIA~ , BEST # 'AZI, # AZI, 1-3 2"4 a =A 4936,0 9,9 53 46,5 36 8,6 9.3 A 493800 8,5 't46 46°6 36 8,6 9°3 4940,0 ,10,5 68 46.6 36 8.6 9,3 C 4942,0 .~,3 47 46,7 36 8,6 9°3 4944,0 ~.;7 45 46,7 36 8,6 9-3 C 4946,0 6,6 51 46,8 36 8.6 9.2 4948,0 ~10.i8 53 -46,8 36 8,6 9.2 4950,0 6,;7 81 46,9 36 8,5 9.1 A 4952.0 ~9,~4 99 46.9 36 8.5 9.1 4954,0 .~0~ 94 46,9 36 8,5 9,0 F 4956,0 5.3 ~! 47,0 36 8,5 9,0 F 4958,0 6.3 69 47,0 36 8.5 8.9 g 4960,0 ~,.1 162 47,0 36 8,4 8.9 4962,0 ~,~2 122 47,0 36 8,4 8,8 4964.0 8,6 97 47.0 36 8.4 8,8 D 4966.0 9.3 14'9 47.1 36 8.4 8,8 496800 47-1 36 8,4 4970,0 5.;5 127 47,! 36 8,3 &.7 4972,0 6.9 86 47.2 36 8.3 8,7 C 4974,0 6,~2 78 47,2 36 8.3 8,~ A 4976.0 4.'6 98 47,2 36 8,3 8~7 497800 3,-2 264 47.3 36 8.3 8.6 498000 5,;7 89 47,3 36 8,3 8.6 A 4982,0 8,;7 78 4704 36 8,3 8,6 4984,0 ~10;3 16 47,4 36 8,3 8.6 4986,0 ~,0 63 4705 36 8,3 8.5 4988,0 4.'3 176 47,5 36 8,3 a,5 499000 4705 36 8.3 4992.0 5.2 130 47.6 36 8,3 8.5 D 4994,0 ~19,~2 45 4.7,6 36 8,3 8.5 D 4996,0 ~13..:5 56 .47,7 36 8,3 8.5 D 4998,0 6,0 146 47,7 36 8,3 8,5 5000,0 6.:0 114 47.7 36 8.3 8.5 5002.0 5.~4 85 47.7 36 8,3 8.5 D 5004,0 8.0 6! 47,7 36 8,3 8.5 D 5006,0 ~.3 169 47.8 36 8,3 8.5 O 5008.0 9.4 91 47.9 36 8,3 8.5 D 5010.0 1,2 100 47.9 36 8.3 8,5 D 50~2.0 9,4 115 48,0 36 8,3 8,4 5014.0 ~.i8 93 48,1 36 S.3 a.4 ATI,,ANTIC I,t]SCHii IF.I,D ,CO. ~1H-7 PAGE; 34-FILE 2 5016o0 ~,9 78 48.1 36 8.2 8.4 50~8,0 ~Ie,~8 89 48.1 37 8.2 8.4 5020,0 ~,2 132 48.2 37 8.3 8°4 5022,0 5.3 108 48.3 37 8,3 8.4 5024,0 5,6 124 48,3 36 8°3 8,4 5026.0 &.,4 147 48.4 36 8.3 8.4 5028,0 9,.8 89 48.5 36 8.2 8.4 5030.0 ~18.~4 93 48,6 36 8,2 8.4 5032,0 '10,0 84 48.6 36 8.2 8.4 5034,0 ,10.~4 104 48.6 37 8.2 8.4 5036,0 -I0.;7 iO0 48,6 37 8,2 5038,0 ~14.3 i~16 48,7 37 8,i 8.4 5040.0 ,t).9 55 48.7 37 8.1 8.4 5042.0 48,~ 36 8,i 50'44,0 48,8 36 8,1 8.4 5046,0 ..2~,~8 53 48.9 36 8-2 5048,0 ~l~,O 57 49,0 36 8.2 5050,0 '19,~1 43 49,! 37 9.2 5052.0 9,9 ~3:5 49.1 3? 8.1 5054,0 ~14.3 ~12 49,1 ]7 8,0 8,3 5056,0 ,13.~4 128 49.1 37 8.1 8,2 5058,0 ~10.!8 12~ 49-1 37 8,1 8.2 5060,0 49,1 37 8.1 8.2 5062,0 9,~? ~.i8 49,! 36 8.1 8.2 5064,0 {..8 ~i3 49,2 37 8,1 8,2 5066,0 ~1).1 ~I3 49,2 36 8,1 8.2 5068,0 49,2 36 8,0 8.2 5070,0 ~1~.~5 I01 49.3 36 8.0 8.3 5072.0 ,1,5.~4 107 49.3 36 8.0 5074,0 ,1{,~2 i22 49,4 36 8,0 8.2 ,5076.0 ~12.~6 123 49.4 36 8.0 8.2 50,78,0 '~.~l 12G 49.4 36 8,0 8.2 5080,0 ,1},9 ii5 49,5 36 8.0 8.2 5082,0 ,15..0 1'03 49,6 .{6 8,0 8°2 5084.0 49,6 36 8.1 8.2 5086,0 9,~8 ~I03 49,6 36 8,0 8,2 5088,0 ~14,,,1 156 49.,7 36 8.0 5090,0 ~I{,,4 I33 49.8 36 8.0 5092,0 ~1~,;5 ~.163 49,8 36 8.0 8.2 5094.0 ,14,~4 150 49,9 36 ?.9 8,2 AIbAN~IC I~ICHFIEbD ~CO. Z~-7 PAGE 35-FILE ************************************************************************* # FORNA~ ICN # BQF~E~E * GUA~. ,------------------,----------------------------------, INDEX DEPTH ~ DIP DIP ~ DEV. D[~. DIAN DIA~ ~ ~ZZ. · AZ[. 1-3 2-4 5096,0 ,13.~8 156 49,9 36 7,9 8,2 D 5098,0 13.! 142 .49.9 36 7.9 8,2 D 5100.0 ,14.;7 141 49,9 '36 7.9 8.2 D 5102.0 2~,9 110 49.9 36 7.9 8.2 D 5104.0 2~.~4 110 50.0 36 7.9 8.2 D 5106.0 23o~2 125 50.0 36 7.9 8.1 F 5108.0 24;6 I16 50.1 36 7.8 8,! D 5112,0 20o~4 138 50,5 35 8,7 10.2 D 5~14.0 20.;7 146 50.5 36 8.7 ~10.2 D 5116.0 50,6 36 8.7 10.2 5118.0 50,6 35 8.7 10.2 5120.0 50.6 35 8.? -10.2 5122.0 50.7 35 8.7 I0.2 5124o0 ~16.;7 123 50.8 35 8.7 10,2 E 5126°0 ~18.~3 124 50.9 35 8.7 10.2 E 5128.0 ~1&,~8 130 50.9 35 8.7 I0.2 E 5130.0 ~1b,.2 126 50.9 35 8,7 10,2 C 5132,0 18.~1 -1~1 5~.0 35 8.7 10,2 D 5134o0 18~'0 122 :'5~,0 35 8°7 1'0.2 F 5136.0 ~1~,;5 120 51.1 35 8.7 10.2 D 5138.0 2~,3 110 5~.2 35 8°7 10.2 D 5~0o0 ~9~7 ~5 51.3 35 8.7 10,2 D 5142.0 18~2 t12 51.4 35 8,7 tO.2 F 5t44,0 '19~! iii 51,4 35 8,7 10,2 B 5146,0 51,5 ~5. 8.7 10.2 5148,0 5i,5 35 8.7 10,2 5i50,0 19.3 104 51,5 36 8,7 10.2 D 5i52,0 19,~2 10i 5i,5 36 8,7 10.2 D 5i54.0 ~1~.i8 ~19 5i°5 36 8,5 ~i0.2 E 5156.0 ~18,"6 ilo 5i,5 35 8,5 10.2 C 5i58,0 ~18.~0 123 51,6 36 8.6 I0.2 E 5160,0 ~18.3 126 51,7 36 8.6 10,2 · 5162,0 ~1{,~8 149 5i.7 35 8°6 10.2 D 5t64.0 20,.1 115 5i,8 36 8.7 10.2 F 5166,0 51,9 35 8,7 10.2 5168,0 52,0 35 8.6 10.2 5i70,0 :52-1 35 8.7 i0.3 5172.0 ~16,;5 123 52,i 35 8,6 10o3 B 5174,0 19,~4 112 52,2 35 8,6 10,3 D 5176,0 .18,~I !i5 52,2 35 8,7 10-3 D ATLANTIC R~CH~IEi,,D CO. !.IH-7 PAGE 36-FII.,E 2 # FORMAT. LON #------------------,-,----------------------- .... ------# i ~IDEX DEPTH e DIP 5178,0 ,15,~5 =119 52,2 35 8.6 10.4 5180,0 24,0 114 52,2 36 8.7 10.4 5182.0 lb.3 142 52.3 36 8.7 10.4 5184,0 52°3 36 8,6 10,4 5186,0 {13,9 120 52.4 36 8.6 ~10,4 5188,0 18.6 105 52.5 36 8.6 10,4 5190.0 3~.~1 2~5 52.5 35, 8.7 10.4 5192.0 lb,l 118 ~52-4 36 8.? I0,4 5i94,0 23.5 125 52,5 36 8.6 10.4 5196.0 ,52,5 36 8,6 10.4 5198,0 20,~2 90 52.6 35 8.6 10,4 5200,0 '13,4 92 52,6 35 8.6 'I0.4 5202.0 ~18,;5 lOO 52.? '36 8.? ~I0.4 5204°0 18.'4 110 :52.6 36 8.? I0,4 5206.0 23.9 I08 52.7 36 8.6 ~10,4 5208.0 ~15.6 ~12 5r2'7 36 8.6 10.4 5210,0 1~,0 103 52,7 36 8,6 10o4 52i2.0 52.? 36 8,6 10,4 5214.0 22,9 102 52,? ~36 8.6 ~10,4 5216.0 20,4 106 52,6 36 8.6 10'4 5218.0 52,6 '36 8.6 10,4 5220.0 25.2 1i5 :52.5 35 8.6 t0.4 5222.0 ~14.~? 94 52.5 36 8,6 .10.4 5224,0 ,14,8 ~I0 52,4 36 8,6 ~10.4 5226,0 52.4 36 8,6 10.4 5228.0 ~13,6 69 :52.4 36 8,6 10.4 5230,0 I3'3 113 52.4 36 8.6 10.4 5232,0 ,52,4 36 8.6 10.4 5234,0 ,16.9 147 52,4 36 8,6 ~10,5 ,5236.0 i{.1 ~116 52.3 36 8.6 I0.5 5238.0 44..1 2~7 52,3 36 8.5 I0,5 5240.0 ~44.i8 377 52,3 36 8.6 ~I0,5 5242.0 ,13,~4 102 52.2 36 8,5 10,5 5244.0 i4*~rO 159 ~52'1 36 8.5 I0.5 5246.0 6,9 I08 52.0 35 8.5 ~10,5 5248,0 ~10,9 i06 52.0 35 8.4 ~10.5 5250.0 10,i 112 52.0 35 8,5 10.5 5252,0 13.2 l'19 .51..9 35 8,5 ~I0..5 5254,0 3,~2 I33 51,8 35. 8.5 t0,5 5256,0 ~,9 124 5i,8 36 8,5 ~10,6 # F F A C ¢ D D ,.~ O ~ F D D C A C DEPTH A~bANIIC ~ICHFI~D CO, 1H-7 PAGE 37-FILE 2 ************************************************************************* * FGR~A~I£N . BQf:EKOLE * DIP DIP # D'E¥, DE¥. DIAN * AZI, # AZI, 1-3 ****#~****#***~.#**#****#*********##~#~**#** # 5258,0 '1),.1 129 51.7 35 8.5 * 5260.0 11~2 132 51.6 35 8,5 . 5262.0 .13..8 128 51.6 35 8.5 * 5264,0 '13,5 112 51.5 35 8.5 # 5266,0 ~1).:8 72 51.5 36 8,6 * 5268,0 10,;7 68 51.5 36 8.6 , 5270,0 51.4 36 8,5 * 5272.0 51.4 36 8,5 * 5274.0 6.;5 122 51,3 36 8,4 , 5276.0 I0.1 34 51-3 36 8.4 , 5278,0 ~1~.9 70 51,2 36 8,4 # 5280.0 1~.3 60 51.1 35 * 5282,0 ~15~1 52 51,1 35 * 5283,0 ~13.9 65 51~.0 '36 8,4 , 5286.0 51.0 36 8,4 , 5288,0 9.'6 '110 50.9 36 8,4 , 5290,0 6.8 ~I4 50,9 36 8,4 * 5292,0 ~.0 108 50.8 36 8,4 * 5294,0 ~,~2 95 50.8 36 8.4 . 5296.0 50,7 36 8.4 * 5298,0 50,6 36 8,4 # 5300.0 -I~,1 290 50,6 36 8,4 * 5302,0 50.6 36 8,5 * 5304,0 50.5 36 8,6 * 5306.0 ~.2 116 50.5 36 8,5 * 5308.0 6,.1 141 50,4 36 8,4 * 5310,0 ~.i8 145 50.4 36 8,5 * 5312,0 3.18 ~1.53 50,3 36 8,5 * 5314.0 ~.;? 190 '50.3 36 8,5 * 5316,0 50,2 36 8,5 * 5318,0 :50,2 36 8,5 * 5320.0 4.;7 -168 50.1 36 8,4 * 5322.0 6,0 1:56 50.1 36 * 5324.0 5.5 167 49,9 36 8,5 , 5326.0 4.'6 246 49.g 36 8.5 # 5328.0 ~.~5 70 49.8 36 8,5 , 5330,0 ~.~4 ~19 49,7 36 8,5 * 5332.0 ~13..8 '18.5 49,7 36 8,5 . 5334,0 49,6 36 8,5 * 5336.0 49.5 36 8,4 * GUAL, -----------* INDEX DIAN , BEST 2-4 * =A #******************# 10.6 10.6 10,6 10.6 .10,5 10.6 10,6 10-6 10.6 10,6 ~10,6 10-6 10,6 ~10.6 I0,6 10.6 I0.6 10,6 10,6 10'6 10,6 10,6 10'5 10,6 10,6 10,5 ~I0..5 ~I0,5 ~I0,5 10,5 10,5 10.5 t0,5 10.5 10,5 ~10,5 ~10,5 ~10,5 ~i0,5 ~10.:5 * , FORMATION , BO~EHObE , DEPTH , DIP ****#****#,#**~***#,#**#,#~*******#,#,#******#**~#,#****** * 5338.0 9..1 98 49.5 # 5340.0 .13.~1 '189 49.5 * 5342.0 49.4 * 5344,0 49,3 * 5346.0 49.3 * 5348.0 ,1&..2 343 49.2 # 5350.0 ~15.~8 ~47 49.2 * 5352.0 '49,2 , 5354.0 4.6 }11 49,1 * 5356.0 49,1 * 5355,0 ~..0 1'07 49.0 * 5160.0 ~.~1 }14 49.0 * 5362.0 '18.0 ~335 49,0 # 5364.0 49.0 * 5366.0 ~.9 I0~ 49.1 * 5{68.0 8.~1 128 49.0 , 5370.0 }..1 109 49,0 * .5~72.0 8.5 ~I04 49.0 * 5374.0 &.6 135 ~49,0 * 5376.0 :48,9 * 5378.0 48.9 * 5~80,0 8.~4 94 48,8 # 5382.0 ,1~.6 35 48,8 * 5384.0 48.7 . 5386.0 -48.6 * 5388.0 9.8 54 48.6 * 5390,0 ~10.:5 47 48.5 # 5392,0 &.5 42 ~48,5 * 5394.0 5.~0 84 '48,'4 * 539600 9.6 97 48.4 * 5398.0 ~1~.~1 97 '48.3 * 5400.0 )1{.4 98 48,3 , 5402.0 6.0 75 48.2 * 5404.0 {.~4 '}14 48.1 * 5406.0 ~.9 186 48,-i * 5408.0 4.0 163 48.0 * 5410.0 59.2 28:~ 47,9 * 5412.0 47,9 * 5414.0 &.'6 50 47'9 . 5416.0 4.6 .62 36 8.5 ~10.4 36 8.5 -10.4 36 8.5 ~10.4 36 8.6 ~10.4 36 8.6 ~10.4 36 8.6 i10.4 36 8..6 ~10.4 36 8.6 .10.4 36 8,6 ~10.4 36 8.6 ~10.4 36 8.5 ~;t0.4 36 8.6 ~10.4 36 8.7 ~10.3 36 8,6 ~10.3 36 8.6 ~10.4 36 8.6 710.4 36 8,6 ~10.4 36 8,6 ~10.4 36 8,6 ~10,4 36 8,6 ~10-4 '36 8,6 !10,4 .36 8.5 ~i0..4 '36 8.5 ~10.4 36 8,5 .10'4 36 8.5 ~10'3 36 8,5 ~10,'3 36 8,4 ~10.3 36 8.4 ~10'3 ~.36 8.6 ~36 8,6 ~10~3 36 8-6 ~'I0-3 ~36 8,5 ~10'3 36 8.5 ~10.::3 36 8,5 36 8.6 ~i0-3 36 e-6 ~10-3 36 8.6 ,10-3 36 8.6 ~10'3 36 8,6 ~10,3 36 8.7 ~10,3 A~HAN5 lC ..RICHFIELD :CO. IH-7 PAGE 3g-FIlE 2 , # 'FORNAT ]C.N · BQF;EIdIILE # DEPTH ~ DI~ DIF # DEV. DEV. DIA~ DIA~ # # AZI. * AZI, 1-3 2'4 5418.0 5420,0 5422.0 5424.0 5426,0 5428,0 5430.0 .5432,0 5434,0 :5436,0 5438,0 3440,0 5442,0 5444,0 ~5446.0 :544~.0 5450,0 5452.0 5454.0 5456.0 5458.0 5462.0 :5464,0 5466,0 5468,0 5470.0 5472,0 5474.0 5476,0 5476,0 5480,0 5482.0 5484.0 5486.0 5485.0 5490.0 5492,0 5494,0 5496.0 28.~0 5.9 & 5.9 9.,2 5,.,1 6 2&,~4 23 .;7 24,6 144 70 89 '12'7 '128 7136 148 167 1~19 1~13 122 I~14 135 123 *~120 121 t32 124 142 124 136 47,9 47.8 47.8 47.8 47.8 47-8 47.7 47.7 47,6 47.6 4 7.6 47..5 47:,5 47,4 47*3 :47.2 47.2 :47.2 47--1 47',I 47.0 47'0 46.9 46.9 46,8 46.7 :46,7 46. ? 46 .. 7 · 46.6 ~ 46.6 46.6 46,6 46,5 46,5 46 '5 ~46.5 46.4 46,3 46.3 36 8.7 36 8.6 36 8.7 36 8.7 36 8.6 36 8.7 36 8.7 36 36 8,6 36 36 8.6 36 36 8.6 35 8.5 35 8.5 35 8.6 35 8,6 35 8.7 35 8.7 35 8,7 35 35 8.6 35 35 8,8 35 ~35 8.7 35 8.6 36 8.6 35~ 8.8 35 35 8.8 '35 8.8 36 8.8 136 8.8 36 8.7 35 35 8.7 35 8,9 36 8,9 '36 8-8 10.3 10.3 10,3 10,3 10,3 10,3 10,3 10,3 .10,3 ~10,3 ~ 10.3 10.3 10-3 10,3 I0,3 10,3 10;3 10.3 10,3 10.3 10.13 I0.3 10,3 i O, 3 10'3 10,3 10,3 10-3 10.3 10,3 IO.3 10.3 10,3 ~I0.3 'i0,3 10.3 ' 10.3 10,4 '10'3 10'3 ATLANT[C R~£H~'IEbD .CO. ilH-? PACE 40-FIbE 2 * * FORHATION # BO~EROi. E # GUAL. · # e-------------..---#-...---...........................# I~DEX * # DEPTH # DIP D~f # DEV. DEV, DIAN DIAN . IEEST # * * AZI. * AZI, 1-3 2-4 * =A ************************************************************************* # 5498.0 * 5500.0 # 5502.0 26.6 * 5504.0 , 5506.0 , 5508.0 * 5510.0 25.~2 * 5512.0 ~1~.~? * 5514.0 , 5516.0 2~.~2 # 55.18.0 25.9 , 5520.0 2~.~4 , 5522.0 , 5524~0 * 5526.0 , .5528.0 , 5530.0 , 5532.0 * 5534,0 * :5536.0 . 5538.0 * 5540.0 * 5542.0 , 55:44.0 , .5546.0 * 5548.0 * 5550,0 * 5552,0 * 5554.0 * 5556.0 * 5558.0 , 5560,0 * 5562,0 * 5564.0 23,9 # ~5566.0 * 5570.0 1t6,~8 # 5572.0 ~19~0 * 5574,0 ~19.~8 * :5576,0 46.3 35 8.8 46.2 35 8.9 151 46.2 35 8.7 46.1 35 8.6 46.i 35 8.7 92 46.0 35 8.7 94 46.0 35 8.9 '72 46.0 35 8.9 45.9 35 8.8 93 '45o9 35 8,9 87 45.8 35 75 45~7 45.6 35' 8.7 45.6 35 8.7 45,6 35 8.7 45.5 ~6 8.6 45.4 36 8.5 45,3 36 8.5 45,2 36 8.6 45-! 36 8.6 45. i 36 8 '45.0 36 8.7 :45.0 36 8.7 :'45,0 36 8,7 44.9 36 8.7 44,8 36 8.8 ~44.7 36 8,8 44.7 36 8,7 44.? 36 8,7 36 8.7 44.6 :37 8-7 ~44-6 '37 8.7 '44,5 36 8,8 124 44.5 36 8.8 4'4.5 36 8.7 ~i36 :44,5 37 8.8 ~129 44,4 37 ~:130 44.4 ~38 8.8 ~132 ,'44'3 "38 8.8 ~38 44'3 37 8.8 10.4 10.4 10.4 10.4 10.4 10.4 10.4 10.4 10.4 10.4 ~i0.4 10.4 iO.4 10.4 10.4 10.4 10..4 10.4 IO.4 10,4 10'4 i0.4 10-3 .t0-3 10'3 i0.2 iO.2 IO.2 I0'1 10.i i0,2 10.2 10.~3 10.3 '10,3 I0.~ ~10.:2 10.2 ~IO.2 ~i0.2 D B D ! ~ B AILANiIC RICHFIELD CO, IH-? PAGE 41-FILE # #--,-.--------------#---,------------------------------, INDEX · DEPTH # DIP D~P # DE¥, DE¥. DIAM DIAM ~ ~EST # ~ AZI, # AZIo 1-3 2-4 * =A 5578.0 44.2 37 8.8 10.2 5580.0 44.0 38 8.8 10.2 5582.0 20.5 153 44,0 38 8,8 10,3 5584.0 44,1 38 8.7 10,3 5586.0 ~30.~8 180 44.1 38 8.7 10.3 5588.0 2~.6 184 44.1 38 8.7 I0.3 5590.0 23.3 181 44.0 38 8.7 10.3 5592.0 40.8 208 44,0 38 8.7 .10,4 5594,0 43.~4 206 44,0 38 8,? 10,4 5596,0 4~.6 200 44,0 38 8,? '10.4 5598.0 .46.;7 195 43.9 38 8.7 ~10.4 5600.0 43.9 38 8.7 ~10.3 5602.0 43.8 38 8.? 10,3 5604.0 43.7 38 8.8 10,3 5606.0 43.6 38 8.8 10,3 5608.0 43.6 38 8.8 10.3 5610,0 43,6 38 8.8 .I0~3 5612.0 43.6 38 8.8 10.3 5614.0 43.5 39 8.8 10-3 5616.0 ~13.6 62 43,5 39 8.8 ~10,~3 5618.0 13.~4 60 43.5 39 8.8 10,3 5620.0 .15.'6 75 43.4 39 8.8 ~10.2 5622,0 43,3 39 8,8 10,1 5624.0 43.3 39 8.9 10,1 5626,0 43,3 39 9,0 10,3 5628,0 )13,18 76 43,2 39 9.0 ~I0.3 5630.0 10,~! 83 43.2 39 9,1 10,2 5632.0 ~1~0 78 43.2 40 9.1 10,3 5634.0 14.0 ~75 43.1 40 9.1 10.3 5636,0 14~0 81 43.1 39 9,2 10,3 5638.0 43-1 39 9.2 10,2 5640.0 15.0 45 43~1 39 9.1 10.2 5642.0 ,15.9 71 43.1 40 9,1 ~10.2 5644.0 t3.~0 78 43.1 40 9.1 10'2 5646.0 43.2 40 9,2 I0.1 5648.0 43.2 39 9.2 10.0 5650.0 43.2 39 9.2 10.0 5652.0 43.3 39 9.3 10,0 5654,0 16,1 44 43.3 40 9.3 9.9 5656.0 1~.:5 62 43.3 40 9.3 9,9 A C C A A A ATLANTIC R~CH~IELD CO. ~IH-7 ?AGE 42-FILE , # FORMATION , BQREHDLE . .------------------,--..----------------------- .... ---# I~DEX # , DEPTH * DIP D~F · DEV. DEV. DIA~ DIAM *~EEST , , AZ1. * AZI. 1-3 2-4 ************************************************************************** , 5658,0 1~..I 65 43.3 40 9.3 * 5660.0 2).'6 57 43.3 40 9.3 * 5662,0 43,4 40 9,2 * 5664,0 ,19.;7 74 43,5 40 9,2 , 5666,0 43.6 40 9.1 * 5668,0 43.6 40 9.1 * 5670.0 43,7 41 9.0 , 5672.0 43.7 41 8.9 . 5674.0 43.8 41 * 5.676,0 43.7 40 8.8 * 5678,0 43.7 40 8.7 * 5680,0 43,7 40 8,6 * 5682.0 43.8 40 8.6 . 5684,0 43,8 40 8.5 * 5686,0 43.8 40 8.5 . ,5688.0 4308 40 8.5 * ~5690.0 43.8 40 8.5 * 5.692,0 20,~4 60 43.9 40 8.5 * 5694.0 ~19.3 57 43.9 40 8.5 . 5696.0 43.9 40 8.4 * 5698.0 ~I9.8 72 '44.0 40 8.4 , 5700,0 44.0 40 8.4 * 5702,0 44.0 40 8.4 , 5704.0 44.0 40 8.4 * 5706.0 ~13.0 349 43.9 40 8.4 , 5708.0 319.9 355 43.9 40 8.4 * 5710,0 43.9 40 8.4 * 5712,0 43.9 40 8,3 * 5714.0 43.9 40 * 5716.0 43.9 40 8.3 . 5718,0 43,9 40 B.2 , 5720,0 2~.'6 356 43.9 40 * 5722.0 2~.~6 6 43.9 40 8,2 * 5724,0 43.9 40 8,1 * 5726,0 43,9 40 8,1 * 5728,0 ~1fi.;3 '~I3 43,9 40 8.1 , 5730.0 ~16,.t ~.14 43.9 40 8.1 * 5732,0 44,0 40 8.1 * 5734.0 43.9 40 8.1 * 5736,0 3.~1 73 43,9 40 8.1 9,9 9,9 9,9 9,9 9,9 10,0 10-1 10.r3 10,3 10.4 10,4 i0,4 10'4 10,5 10,5 'I0.5 10.5 10.6 10.,6 10.6 10,~7 I0~7 ~10.7 ~10,7 10,8 10,8 10'8 10,8 10'8 I0'8 i0,8 '10,8 '10'8 '10.8 'I0,8 ~10.8 'i0'8 D .F .F A~LAN~ lC RICRFIEIaD ,CO. X,H-.7 PAGE 43-FILE 2 a FORNATICN a~ BOF~EHOLE DEPTH e DIP DiP e DE~, DE~, D lAM D * AZI. * AZI, 1-3 5738.0 43.9 40 8-1 10.8 5740.0 ~43.9 40 8.1 10.8 5742.0 ~..8 310 43.9 40 8.1 10.8 5744.0 5.9 360 43.9 40 8.1 '.10.8 5746.0 ,10,2 33 43.9 40 8.0 10.8 574e.0 43.9 40 8.0 10.8 5750.0 43.9 40 8.0 10.8 5752.0 43.9 40 8.0 10.8 5754.0 43.9 40 8.0 10.8 5756,0 43.9 40 8.0 10.8 575~.0 43.9 40 8.0 10.8 57b0.0 43.9 40 7.9 10.8 5762.0 43.9 40 8.0 10.8 5764.0 43.9 40 8.0 10.8 5766,0 ~10.~1 172 43.9 40 8.0 10.8 5768.0 ,12,8 183 43.9 39 8.0 ,10.8 5770.0 44.0 39 8.0 10.8 5772.0 44.0 40 8.0 10.8 5774.0 44.0 40 8.0 10.8 5776.0 44.0 40 8.0 10.8 5778.0 44.0 40 8.0 10.7 5780.0 44-0 39 7.9 10.7 5782.0 44.0 40 7.9 10.7 5784.0 35.~5 238 44.0 40 7.9 10.7 5786,'0 4~.5 2.17 44.0 40 7.9 10.7 5788,0 49.~6 208 44.0 40 8.0 10.7 5790,0 35.~2 233 44,1 40 8.0 10.6 5792,0 44.6 211 44.1 40 8.0 10.6 5794,0 ~46.9 208 44.1 40 8.1 '10.6 5796,0 3~.~1 236 44.1 40 8,1 10.6 5798,0 45.6 21.7 44.2 40 8.1 10.6 5800.0 '44.2 40 8.1 10.6 5802,0 50,2 208 44,2 40 8.1 10.6 5804,0 44.2 40 8.I I0.5 5806,0 44.2 40 8.1 10.5 5808,0 44.2 39 8.1 10.5 5810,0 44.2 40 8.2 10..5 58t2,0 44.2 40 8.2 10.5 5814,0 44,2 39 8.1 10.5 5816,0 44.2 39 8.1 10.5 --# INDEX # BEST D D D ATbANTiC R~CHflEbD CO, ~IH-7 PAGE 44-FILE ~ FORMATION # BGREHOLE # OUCh, #o-----------------#----------------------------------# INDEX DEPTH # DIP D.~F ~ DEV, DEV, DIA~ DIAM #~EEST # AZI. * AZI. 1'3 2-4 ~ =A 5818,0 ,1~,~4 .350 44,2 39 8,2 5820,0 'lb..8 344 44,2 40 8,3 5822,0 44,2 40 8,4 5824,0 22.~6 45 44,2 39 8,4 5826,0 :18,-2 71 44.2 39 8.4 5828,0 ~.19,;5 81 44,2 39 8,4 5830,0 44,2 40 8.4 5832,0 44,2 40 8,4 5834,0 44,1 40 8,5 5836,0 ~13,:5 79 44,1 39 8,5 5838,0 9,~8 89 44.1 -39 8.5 5840,0. ~I~,;5 86 44.1 39 8.5 5842,0 44,0 40 8,5 5844,0 44.0 40 8.5 5846,0 5,~1 98 44.0 40 8.6 5848,0 9,.S -111 44,0 40 8,6 5850,0 44,0 40 8.5 · 5852,0 5,6 116 43,9 39 8.5 585400 5,3 54 43,9 39 8,4 5,856,0 &,,2 63 43.9 39 8,4 5858,0 6,:5 23 43,8 39 8,3 5860,0 ~14.~6 23 '43.8 40 8.3 5862,0 )I~,~8 :35 43,8 40 8,2 5864,0 28,'~2 246 43,8 40 8,2 5866,0 -29,6 245 43,8 40 .8,2 5868,0 28,9 247 43.8 40 8,1 5870,0 29,~2 247 43.7 40 8.1 587200 3.::8 335 43,7 40 8.1 5874,0 3.9 273 43.8 40 8,1 5876,0 43,8 40 8.1 5878,0 .~,~8 219 43,8 40 5880,0 ~,i.8 223 43,9 ,39 8',1 .5882,0 43,9 40 8,t 5884,0 {,;7 104 43.9 40 8,2 5886,0 5,.:5 352 43,9 39 8.2 5888,0 5,9 321 43,9 39 8,1 5890,0 4309 39 8,2 5892,0 43.9 40 8.2 5694,0 4,9 233 43-9 40 8.2 5896,0 43.9 40 8,2 10,4 .10,4 i0.3 10.3 10.3 10,3 10.3 10,2 10.2 '10.2 10.2 10.2. 10,2 10.2 10.2 10.2 I0.3 10.3 10,3 I0,4 :10,4 10.4 10.4 10,4 -10,4 10.4 10,4 10,4 10.3 10,3 10.3 1-0.3 10-3 t0.3 10.3 10,2 10.2 10.2 I0,2 D F F C E A C ¢ C D D D D D F F F B ~IbAN'I IC RICHFIEbD .CO. I'H-? PAGE 45-FILE , # FOR.NAT.~(.:N # BQI: EH. DLE # GUAL. # ,------------------,------------------'---------------, INDEX · DEP~fl # DIP DIP # DE¥, DEV. DIAM DIAM # BE$~ * 5898.0 # 5900.0 # 5902.0 # 5904,0 12.'4 , 5906,0 4, * 5908.0 0*6 # 5910.0 2..8 , 5912.0 * 5914.0 4.6 * 5916.0 4.~7 * 5918.0 ~ 5920,0 3.:5 # 5922,0 * 5924.0 3,9 , 5926,0 4 ,~2 * 5928.0 3 .~ 5930.0 4,72 # 5932.0 5.0 * 5934,0 4,~0 # 5936.0 4 * 5938.0 5 * 5940.0 5 ~ 5942.0 3,::8 , 5944.0 2.~5 ~ 5946.0 # 5948,0 * 5950.0 6.~4 ~ 5952.0 # 5954,0 , t,. 9 * 5956.0 ~,4 , 5958.0 * 5960,0 * 5962,0 0.3 * 5964.0 9,~0 ~ 5966.0 '10.3 ~' 5968.0 # 5970.0 * 5972,0 13,4 # 5974,0 ~e 597'6.0 343 43.9 40 8.2 .10.2 D 43.9 40 8.2 t0.2 43.9 40 8.2 10.2 174 ;43.9 39 8.2 10.1 D 198 43.9 39 8.2 10.1 D 1'I'3 43.9 40 8.2 10.0 F 135 43.9 39 8.3 9.9 F 43.9 39 8.4 9.8 I31 43.8 39 8.4 9.8 F ti7 43.8 39 8.4 9.8 F 101 43.8 39 8.4 9,.7 D 96 :43.8 39 8.5 9.7 D '43.8 39 8.6 9.7 ~75 43.8 39 8.6 9.7 E 120 43,7 39 8.6 9.7 E 116 43.6 39 8.6 9.-7 E 106 43,6 40 8,5 9.7 E 72 43.6 39 8.5 9,7 ~ 6! 43.6 39 8.6 9..7 E 135 43.6 :39 8.6 9.7 E 1.54 43.6 39 8.5 9.7 C 163 43.5 39 8.5 9.7 C 142 43,5 39 8,5 9.7 E 93 43.4 40 8.5 9,7 E 43..4 40 8.5 9,7 8 43,4 40 8.6 9.6 A 24 43.3 39 8.6 9,6 E 260 43.3 40 8.6 9.6 E 295 43.3 40 8.6 9,6 E 232 43.3 39 8.7 9.6 E 99 43.3 40 8,6 9.6 E 84 43,3 40 8.6 9.6 g 320 43.3 40 8.7 9.6 E 329 43.3 40 8,6 9.6 F 338 43.3 39 8.6 9.6 D 324 43,2 40 8,6 9.6 F 271 43,2 40 8.6 9.6 F 334 43.1 40 8.6 9.6 F 320 43,1 40 8.6 9.6 D 43-1 40 8.6 9.6 2 ATLANTIC R~I:H[IEI=D ;CO, ~IH=7 PAGE 46-FILE 2 ,----.---.---------,---.------------------------------, I IDEX * DE~H , DI~ D.~ ~ D~V, DEV. ~IA~ DIA~ ~ ~EE~T ~ · AZI. * AZI. 1-3 2'4 * =A , ********************************************************************** . 5978.0 . 5980.0 , 5982.0 , 5984,0 . 5986.0 , 5988.0 * 5990.0 * 5992,0 * 5994.0 , 5996.0 , 5998,0 . 6000.0 * 6002.0 , 6004.0 * 6006o0 , 6008.0 * 60t0.0 * 6012.0 , 6014.0 * .6016.0 * 6018.0 * 6020.0 * 6022.0 * 6024.0 * 60'26.0 * 6028.0 , .6030.0 , 6032.0 , 6034,0 * 6036.0 * 60 tt!l. 0 * 6040.0 * 6042.0 # 6044,0 , 6046.0 * 6048.0 * 6050,0 * 6052.0 * .6054.0 # 6056,0 3,3 4.3 6.9 6,6 8-4 5 5.9 180 43.1 40 8.6 9.6 43.0 39 8.6 9.6 42.9 40 8.6 9,6 183 42°9 40 8.6 9.6 42.9 39 8.5 9.6 351 42.9 39 8,5 9,6 167 ~42.9 40 8.6 9,7 I18 42.8 40 8.6 9.7 42,8 40 8.6 9.7 180 42.7 40 8.6 9~7 180 42,7 40 8-5 9,7 156 42'8 39 8.6 9~7 42.7 '39 8.6 9.7 '42.7 40 8,6 9,7 148 42*7 40 8,6 9.7 161 42.6 39 8'9 9,7 ~174 42.6 39 8,9 9,7 42.6 39 8.7 9.7 88 .42.6 39 8-7 9~7 ~162 ~42,6 139 8,6 9.7 ~172 42.6 40 8.6 9,7 ~141 '42.6 ~40 8.6 9~7 !188 42,5 40 8.6 9,;7 ~,t!7,7 42.6 39 8,5 9,8 4 42.6 39 8.6 :9.8 42.6 39 8.6 9.8 ~!66 '42,5 39 8.6 9'8 ~170 42-5 39 8.6 9'8 ~,171 42-4 40 8.5 9'8 ,16,6 42'4 40 ~1,55 ~42.4 39 8.6 9*9 ~166 42.3 39 8.6 ~i67 ,42 '3 39 8.6 9 :~129 42-3 39 8.6 9.8 ~'I38 '42,3 39 8,6 ~9,8 ~163 :42,3 39 8.6 9.9 159 42,3 ~39 8.6 9*9 151 ,42-3 '39 8,8 9-9 162 42-3 39 8,9 9.9 157 42.2 40 ~.7 9.9 C C C C C .C C C C C ,C C C ,C C C C C 'C DEPTH # DiP DiP # DE¥. DE¥, DIAM DIAM # AZI. ~ A%,I, 1-3 2-4 6058,0 ~..0 159 42,2 39 8,7 9,9 C 6060,0 }.!8 180 42,2 39 8,7 9,9 C 6062,0 6.g 181 42,2 39 8,7 9,9 C 6064,0 6.6 139 42,1 39 8,7 9,9 C 6066,0 ~.0 133 42,1 39 8,7 9,9 C 6068,0 ~.;5 140 42.1 39 8,7 9,9 C 6070,0 ~.~2 164 42-1 39 8,8 9.9 C 6072.0 6,4 157 42.1 39 8.9 9,9 C 6074,0 5,~5 133 42,0 39 8,8 9,9 C 6076°0 5.~2 152 42.0 39 8,7 9.9 C 6078.0 4~1 76 42.0 39 8,8 9,9 C 6080.0 8.3 ~29 42.0 39 8,8 9,9 C 6082,0 ~.~8 149 42,0 39 8,8 ~10,0 C 608.4,0 ~,~8 147 41,9 39 8,8 .10,0 C 6086,0 41.9 39 8.7 10.0 6088.0 41.8 39 8,7 10.0 6090,0 5.4 154 41.,8 39 8,7 10,0 C 6092.0 6,3 166 41o8 39 8,7 10,0 6094,0 5,;5 144 41,8 39 8,6 ~10,0 C '6096,0 5,~4 145 41,9 39 8,6 10,0 C 6098,0 8.0 180 41,9 39 8,6 10,0 C 6100,0 ~.3 ~70 41,9 39 8,6 10,0 C 6102,0 5,;7 148 41,8 39 8,6 10,0 A 6104,0 ~,;7 141 41,8 39 8,7 '10,0 C 6106,0 9,~6 139 4~,8 39 8,8 I0,0 C 6108,0 3.!8 149 41.8 39 8,7 ~10,0 C 6110.0 5,8 184 41,7 39 8,6 ,10,0 C 6112.0 41.7 39 8.5 10,0 61i4,0 6,~4 51 4i.7 39 8,6 9,9 C 6116,0 3,:5 -187 41.7 39 6118,0 9.;7 182 41.? ~9 8.7 10.0 C 6220.0 5.~2 58 41.7 39 8,7 iO,O E 6122.0 6.~8 80 41.7 39 8.7 9,9 C 6124,0 3.~5 168 -41o7 39 8.7 9,9 D 6126.0 41.7 39 8,7 9.9 6128.0 ~,;7 205 41,6 39 8.7 9,8 ,D 6130.0 2.~7 ,i40 41.6 39 8,7 9,8 F 6132,0 3,~2 146 41.6 39 8,8 9,9 F 6134.0 41.5 39 8-7 9.9 6136,0 41.5 39 8.7 9,9 BEST AIbANIIC ilCHFltbO ¢0, IH-? PAGE 4B-FILE ~ ,------------------,----------------------------------, INDEX a DEP~fl e DIP DIP e DEV. DE~. DIAN DIA~ e BEST 6138,0 9,9 6140,0 6142.0 10.0 6144,0 5.9 6146,0 5.6 6148.0 6150.0 b152.0 6154.0 4,;7 6156,,0 4,;5 6158.0 6160.0 6162.0 6164o0 6.3 6166.0 6168,0 6170.0 5.0 6172.0 4,~2 6174.0 69.;5 6176.0 70.~8 6178,0 6180,0 6182.0 5.~4 6184.0 .6186.0 5.9 6188.0 5.6 .6190.0 5.3 6192.0 6194.0 6196,0 5.3 6198,0 6200.0 6202.0 6204.0 6206.0 4.9 6208.0 6210.0 4,15 6212.0 4.~4 6214,0 5 6216.0 4 ..i8 172 101 160 149 143 166 186 141 ,143 -171 181 1.75 165 169 278 2,77 143 169 153 128 I43 155 196 182 177 214 24.2 98 1_57 181 140 140 160 160 41.5 39 8.7 9.9 41,6 39 8,6 9.9 41.6 39 8.8 9,9 41,6 39 8.7 9.9 41,6 39 8,6 9,9 ,41,6 39 8,7 9,9 41,6 39 8.8 9.9 41.5 39 8.8 9-9 41.5 39 8.7 9.9 41,5 39 8,6 9.9 41.5 39 8.6 9.9 41.4 39 8.6 9.9 41.4 39 8.7 9.9 41,4 39 8.8 9,9 41,4 39 8.8 9.9 41,4 39 8.7 9,9 ~4i,4 39 8,7 9.9 41.4 39 8.7 9.8 41.3 39 8.8 9.9 4i.3 39 8.8 9,9 41.3 39 8.8 9.9 41.3 39 8.8 9.9 41-3 39 8.8 9,9 41.3 39 8.8 9.9 4i.2 39 8.7 9,8 4io2 39 8.7 9,9 41.2 39 8.7 9,9 4.1,3 39 8.7 9.9 41-3 39 8.6 9,9 41.2 39 8.6 9.9 41.2 39 8.6 9.9 41.1 40 8.6 10o0 4t.1 39 8.6 9.9 ~41,.I 39 8.6 4t.0 39 8.6 9.8 41.0 39 8-6 9.8 41.0 39 8.6 9.8 '41.0 39 8.6 9.8 4i,0 ~39 8.6 9.8 4t,0 39 8.6 9.8 C C E C C ,¢ C ,C C C C C C C C C C A D C C C C C C ATbANTIC R~CHI;IEL, D ,CO. ~IH,-7 PA'GE 49-FIl,,E 2 # a FO.RNRTION * ,------------------,----------------------------------, I~DEX ~ DEPTH ~ DIP ************************************************************************* . 6218.0 ~41.0 39 8.6 9.8 # 6220.0 5,~4 161 41.0 39 8.6 9.8 C . 6222.0 5.;? 160 41.0 39 8.6 9.8 C # 6224.0 5.;7 177 40.9 39 8.7 9.8 C , 6226.0 4.4 164 40.9 39 8.7 9.8 C * 6228.0 4.3 180 40.9 39 8.7 9.8 C * 6230.0 4.~6 178 40~9 39 8.7 9.8 C # 6232.0 5.8 t75 40.9 39 8.8 9.9 C * 6234.0 3.~8 136 40.9 39 8.8 9.8 C * 6236.0 3.;7 138 40.8 39 8.9 9.8 C . 6238.0 ~,4 179 40.8 39 8.9 9.8 C * 6240.0 b.8 180 40.~ 39 8.9 9.8 C * 6242.0 9.~4 ,:185 40.7 39 $.8 9.8 C , 6244.0 8,8 187 40.6 39 8.? 9.8 C * 6246.0 6.:5 -177 40.7 39 8.8 9.8 C * 6248.0 9.0 162 40.7 39 8.8 9.8 E * 6250.0 3.6 132 40.7 39 8.8 9.8 C # 6252,0 3,0 130 40.7 39 8.8 9,8 C ~ 6254,0 6.9 I91 40.7 39 8.9 9,? C * 6256.0 ~,9 151 40.7 40 8.9 9.7 E * 6258,0 6,:0 105 40,7 39 8,8 9,7 C , 6260,0 9.9 167 40,6 39 8,7 9.8 C * 6262.0 6.~2 159 40.6 39 8.7 9.? C , ~264.0 5.~1 177 40.6 39 8.8 9.7 C . 6266,0 5,0 176 40,-5 39 8,7 9,? C , 6268.0 4,~I 177 40.6 39 8.8 9.~ C * 6270,0 40.7 39 8.9 9.8 # 6272°0 40.7 39 8.9 9.8 ~ 6274,0 ~,,0 180 40.7 39 8.9 9,7 C * 6276,0 4..;7 200 40,6 39 8,9 9,7 C * 6278,0 8,~3 182 40,6 39 8.9 9,~ C * 6280,0 6,~2 159 40.6 39 8.9 9.6 C . 6282.0 4.~4 I32 40.6 39 8.8 9.-5 C * 6284.0 3,~2 199 40.5 39 8.9 9.4 C , 6286.0 5.~4 176 40.5 40 8.9 * 6288,0 3.8 154 40.5 39 8.8 9,2 C ~ 6290.0 3.9 1.72 40.5 39 8.8 9.2 C . 6292.0 3,5 158 40.5 40 8.7 9.2 * 6294.0 40.5 40 8.7 9.2 * 6296,0 40.5 40 8.7 9.1 A]~AN11C RICHFIEbD CO. IH-7 PAGE §O-FI~E 2 · DEPTH , DIP DIP , DE~. DEV. DIAH · # AZ1, · AZI. 1-3 6298.0 6300,0 6302,0 6304.0 6306,0 6308,0 13.3 6310.0 6312.0 29.5 6314.0 6316.0 24.~4 63i8,0 6320,0 6322°0 6324,0 6326.0 6328.0 2~.;5 6330.0 8*3 6332,0 6334,0 6336.0 6338,0 8.6 6340,0 6342.0 7,5 6344,0 6346,0 6348.0 6.~8 6350,0 6.i8 6352.0 6354,0 9,0 6356.0 6.9 6358,0 6360.0 4..9 6362.0 ~.~i 6364.0 6366.0 ~,~2 6368.0 6370,0 6;6 6372.0 5.9 6374,0 6;6 6376.0 13 28 15 1'{ 9 36 3:55 343 334 127 1.74 174 159 153 1,71 I.'/5 1.75 170 168 180 184 176 1~74 162 154 174 172 40,5 40,5 40,4 40,4 40.3 40,3 40-3 40.3 40,3 40.4 40,3 ~40o3 40,3 40.3 40,4 40,4 40,4 40,3 40,3 40,3 40,3 40-3 40,3 40,3 4:0,2 40,3 40,3 40.3 40,3 40,3 40-3 ~40,3 40,2 40.2 :40.2 40 40,1 40'2 40,2 # GUAb. -----------, INDEX DIA~ # BEST 2-4 # =A 39 8,9 9.2 39 8.9 9.2 39 8,8 9.1 40 8,7 9,1 40 8.8 9.3 40 8.9 9.4 39 8.9 9.4 39 8.9 9,5 4O 8.9 9.5 40 8,9 9.5 39 9.0 9.5 40 8,9 40 8,9 9'5 40 8,9 9,5 39 8.9 9.5 39 9,0 9.5 39 8,9 9,5 39 8,9 9-5 .40 8.7 9,5 40 8,7 9.5 :40 8,8 9,5 .40 8,8 9.5 '39 8.7 9,5 !39 8,7 9,5 39 8,9 9,5 39 8,9 9,5 40 8~7 40 8,7 9,5 39 8,8 9,5 39 8',8 9.5 39 8.:7 9,5 40 8.7 ~9'4 40 8,8 9,.5 39 8.8 9,6 39 8,7 39 8-8 39 8.8 9.6 39 8.8 9,.6 39 8,8 9,5 ~39 8°8 9.6 # FORHAT[O~ # BQ~EH.ULE ,------------------,----------------------------------, I~DEX DEPTH , DiP D~F ~ DEV. DEV. ~lk.~ DIA~ , * kZI. , AZI. 1-3 2'4 6378,0 6380,0 6382.0 6384.0 6386.0 6388'0 6390.0 6392.0 6394.0 6396.0 6398.0 6400.0 6402,0 6404.0 6406.0 6408.0 64~0.0 6412.0 .64 t 4.0 6418'0 6420,0 6422.0 .6424.0 6426.0 6428.0 6430,0 6432,0 6434.0 6436.0 643 a, 0 6440.0 6442.0 6444.0 6446,0 6448.0 -6450,0 6452.0 6454,0 6~56,0 168 144 156 165 i64 166 1.53 : 169 17,1 1,58 167 1,74 ~180 ~ 1.74 ~i79 ~179 173 ~65 ~7.7 175 171 ,i8t 40.2 39 8.8 9.6 C .~ 40.1 39 8.7 9.5 C a 40.1 40 8.7 9.5 C '~ 40.1 39 8.6 9.5 C · 40.0 39 8.7 9.5 C · 40.0 39 8,7 9.5 C * 40.0 39 8.8 9,4 C ~ 39.9 39 8.8 9,4 C t 39.9 40 8.8 9.4 C ~* 40.0 39 8.8 9.4 C ~ 40.0 39 8,8 9.4 C ~* ~ 40,0 39 8.8 9,3 C '. ~ 39.9 39 8,7 9.3 C ~* 39,9 39 8,8 9.3 C ~ 39.9 39 8,8 9.2 C !,* 39'9 39 8.8 9.2 C ~:'~ 39.9 39 8.8 9.3 E :r ~ 39,,9 39 8,8 9.3 C ~* 39,8 39 8,.,8 9'3 C '~'~ 39,.7 39 8.8 9,3 C ~ 39,7 .39 8,8 9.3 C ~: ~ 39.7 39 8,9 ~.3 C ~ 39,? 40 8.8 9,3 C ~ 39,6 40 8.8 9*3 C ~ 39,6 39 8,8 9.3 C ~' ~ 39,6 '39 8'. 9 9,2 C ~* 39,6 40 8,8 9.2 :C ~ * 39.6 :40 8,8 9,2 'C ~ 39.6 40 8.9 9. i C ~ 39,5 40 8.8 9.1 C ~ 39,5 40 8.8 9,1 C ~ 39 '5 40 8.8 9,1 C ~'* 39,,4 ~40 8.9 9.1 C ~ 39,4 .40 9,0 9,1 C ~,t 39,4 40 8.,9 9,1 C ~ 39'3 40 8,8 9.,~I C ~ 39,3 40 8,8 9.1 C ~ 39-3 40 8'8 9.1 C ~ 39,2 40 8,9 9'1 C ~ 39.2 40 8.9 9,t C ~ ASbAN]IC RICHfIEbD CO. ii:H-? PAGE 52-FILE ************************************************************************** * , FOR~A~{C~N , BO}EHOLE * OUAb. * *------------------,----------------------------------# INDEX P DIP , DE¥, DE¥. DIAN DIA~ # BE&T AgI, # AZI, t-3 2-4 * =A 6458.0 6460.0 5~4 6462.0 6464.0 6466.0 6468.0 9.:5 6470.0 6472.0 5.3 6474.0 7.3 6476,0 5,9 6478.0 6480.0 6.482.0 6484.0 6486.0 6488.0 6490.0 6.3 6492.0 4~5 6494.0 5,3 6496,0 6498.0 6500.0 6502.0 6.3 6504.0 ~.'0 6506.0 6508.0 9.~2 6510,0 6,~0 6512.0 ~.~4 6514.0 6516.0 6518.0 6,9 6520.0 6522.0 ~,~1 6524.0 5.~4 6526,0 6528,0 653'0.0 6.~7 -6532,0 5.i8 6534,0 6536.0 161 199 -191 157 192 1-77 183 164 142 132 I80 160 180 1'66 161 1,72 16.7 160 I81 176 ,179 184 185 179 177 175 180 162 t64 39.1 39 8.9 9.0 C 39.1 39 9.0 9.0 C 39,1 40 9.0 9,1 C 39,1 40 9.0 9.0 C 39.1 40 9.0 9.0 g 39.1 40 9.0 9.1 39,1 40 8.9 9.0 39.1 40 8,9 9.0 C 39.1 40 8.9 9.1 39,-i 39 8.9 9,1 C 39,1 39 8.9 9,1 A 39.1 39 8.9 9.2 C 39.0 40 8.8 9.1 C 39.0 40 8.9 9.2 C 38.9 40 8.9 g.2 E 38.9 40 8.9 9.2 C 36.9 40 8.:8 9,1 38.9 40 8.8 9,1 C 38-9 40 8.8 ,9-1 C 38.8 40 8.8 9,2 C 38.8 40 8,8 9,2 C 38.8 40 6.8 9,3 E 3B,8 40 8.9 9,2 C 38.7 40 8,9 9.0 A 38,7 40 8,8 8.9 E 38.7 40 8.8 9.0 38.7 4.0 8.7 9.1 A 38,7 40 8.8 9.2 C 38.6 40 8.8 9,2 E 38.5 40 8.7 9,1 C 38.5 40 8.7 9,1 C 38.5 40 6,7 9-I E 38.5 40 8.8 9,-1 C 38,5 40 8.8 9.0 C 38,4 40 8,7 9.0 C 38.4 *40 8.7 8,'9 C 38.3 40 8.7 8,9 C 38.4 40 8.7 8.9 ,C 38.4 40 8,6 8.8 C 38.4 41 8.5 8,8 C ATLANTIC R~CH~'IELD CO, iIH-7 PAGE 53-FII.E 2 6538.0 6.5 162 38.3 41 8,2 8.9 6540,0 4.6 }17 38,3 4t 8,0 8.9 6542,0 9.3 172 38.4 40 8,0 8.9 6544.0 9.6 161 38.3 40 8.5 6546.0 ~I~.:5 160 38.2 40 8.9 9.0 6548.0 ~1~.9 154 38.2 40 9,1 9.0 6550.0 4.3 127 38.2 41 9,0 6552°0 5.3 150 38.1 41 8,8 6554.0 ~..1 165 38.0 41 8,8 6556,0 g.;? 163 38,0 4i 8.8 6558.0 $,9 163 38.0 41 8,8 8,8 6560,0 6,9 167 38,0 ii 8,8 6562,0 6.;7 163 38.0 41 8,8 8,8 6564.0 6.;? -149 38.0 41 8.8 6566.0 6.~2 144 37.9 40 8,? 6568.0 9,6 166 37,8 40 8,6 6570,0 },.1 i76 37,8 40 8.6 9,0 6572,0 }.~! -173 37.7 40 8,6 6574.0 .}.3 169 37,7 40 8,7 6576.0 &.~7 156 37.6 40 8,7 6578.0 &.:6 ~166 37.6 40 8,8 9,2 6580,0 ~.3 170 37.6 40 8.8 6582,0 S.~O 147 37,5 40 8,7 9,2 6584°0 5.~2 129 37,5 40 8,7 9,2 6586,0 ~..1 83 37.5 40 8,7 9,1 6588,0 4,.1 '95 37.5 40 8.6 6590.0 3.18 '.t67 37.4 40 8.6 6592.0 $.O 131 37.4 40 8'6 6594.0 5.;7 $19 37.5 40 8,6 9,4 6596.0 5.6 16.5 37.4 40 8,7 9,4 6598.0 ~,;7 183 37.3 40 8.7 6600.0 8.;5 180 37.3 40 8.7 9.5 6602.0 ,10,~1 192 37.3 40 8.7 9.5 6604.0 9.0 186 37-3 40 8,7 ~,5 6606.0 ~.3 152 37.2 40 8,6 9,-5 6608°0 ~.3 157 37,2 40 8.5 9.5 6610.0 ~.5 1~8 37.1 4! 8,5 9,5 6612o0 ~.~3 175 37-1 41 8,5 6614.0 5.5 169 37.2 41 8°4 6616o0 6.~0 'i68 3'7.2 40 8,5 9,5 #:EEST # =A # C C C C C C C C C C C ¢ C C C C C ¢ C C C C C C C * * FOR~A~ICN , BQ~E~OLE * *------------------,----------------------------------, INDEX ~ DEPTH * DIP DI~ , DE¥. DE¥. DIAM DIAM , BEST ~ # AZI. # AZI, 1-3 ~'4 ************************************************************************* * 6618.0 5.3 152 37.2 40 8.5 9.6 E * 6620,0 37.2 40 8.4 9.6 * 6622.0 6.15 167 37,2 40 8.5 9.6 E * 6624,0 ~}.,4 171 37.2 40 8.6 9.8 C , 6626,0 ~,5 .178 37.2 40 8.6 9.9 C , 6628.0 5.~8 162 37.2 40 8.6 .9.9 A , 6630.0 b,3 153 37,2 40 8.5 9.9 C * 6632,0 6.;7 ,153 37.2 41 8.5 9,9 * 6634,0 ~,~I 146 37ol 41 8.5 9-9 C * 6636°0 8.,1 127 37.1 41 8,5 9,9 C * 663~,0 ~..t :t88 3~,t 41 8.5 9.9 C * 6640.0 ~1~,'6 255 37,1 41 8,5 9.9 , 6642,0 b.~8 172 37,0 41 8,4 9.9 C * 6644,0 ~.9 '181 37,0 4i 8,4 9.9 C * 6646.0 ~.;2 '12'4 36.9 42 8.3 9.9 A * 6648,0 ~,,2 ~100 36*8 42 8,3 9,9 A * 6650,,0 3.~4 248 36.8 41 8,3 9,9 C * 6652.0 4,9 ~167 36.8 ~41 8'3 9,9 A * 6654,0 36,7 41 8,3 9,9 * 6656,0 9,~4 ~184 36.7 ~4! 8,2 9-9 C * 6658.0 9.~8 189 36.7 41 8.3 ~10.0 C * 6660.0 8.6 ~195 36.7 ;41 8.3 '10.0 * 6662,0 ~10,i8 ~197 36,7 41 8.3 ~10.0 C * 6664,0 .1~,"6 ~192 36,? .41 8,3 ~'10,'1 * 6666,0 8.~1 ~188 36,7 41 8,2 ~:10~:I D * 6668,0 36,7 .41 8,2 ~iO,1 * 6670,0 8,.2 ~t94 36,6 41 8,2 '10'2 D * 6672,0 36,5 41 8,2 10'2 * .6674-0 ~.~4 ~181 r36'5 41 8'2 10'2 D * 6676'0 },~4 '181 36'5 41 8'2 10'2 D * 6678,0 36'5 '41 8'1 'I0'I * 6680.0 36.5 :41 8.1 10,2 * 6682.0 4*9 294 36.5 4i 8,1 ~10;3 * 6684,0 5..i 225 36-5 ~41 8.2 ~10.3 D * 6686°0 b.~6 1328 36.4 .41 8.2 ~10.3 F * 6688.0 .),I ~332 36,4 .40 8.2 10'3 D * 6690,0 '36'4 ;40 8.2 10'3 , 6692,0 36-3 4i 8.2 1'0.4 * 6694.0 36,3 4t 8'1 10.4 * 6696,0 36.3 41 8.1 10-3 FORMAT[ON ~mmm~mmmmmmmmmmmmmm~mmmmmm DIP ~ # DEV AZI. BO~EH.OLE # OUib, -----------o----------------# iNDEX . DEV. ~IA~ DIAM ,~EEST AZi. 1-3 2'4 * =A # 6698.0 10-0 188 36.3 41 8.0 # 6700.0 9.0 179 36.3 41 8.1 * 6702.0 9..1 193 36.2 41 8.2 # 6704.0 9.4 189 36.2 41 8.2 * 6706.0 36.2 41 8.t * 6708.0 36.1 41 8.1 * 6710.0 36.2 41 8,1 * 6712.0 36.2 41 * 6714.0 36.t 41 8.1 * 6716.0 36.1 41 * 6718.0 ~.6 186 36.1 41 8.2 * 6720.0 8.~2 185 36.0 4t 8,2 # 6722.0 36.0 41 8.! # 672~.0 36.0 41 8.1 * 6726.0 36.0 4I 8.1 * 6728,0 35,9 * b730.0 10,6 I90 35.9 42 8.1 * 6732,0 ~10.;2 188 35.9 42 * 6734.0 35.9 42 8,1 # 6736,0 35,9 42 8.2 # 6738.0 35.9 42 8,2 # 6740.0 ~.17 183 35.9 ~41 8,2 , 6742.0 ~.6 181 35.9 41 8.2 * 6744,0 35.9 42 8.2 # 6746.0 35.9 42 8,2 * 6748.0 35.8 42 8.2 ~ 6750.0 35,7 42 * 6752,0 ~I0.i8 293 35.7 42 8,3 # 6754.0 8,2 290 35,7 42 8,4 * 6756.0 ~.~2 285 35.7 42 8,4 * 6758,0 5,1 219 35,7 42' 8,4 , 6760.0 5,4 192 35~7 42 8.4 * 6762,0 0..1 t82 35,7 42 8,4 , 6764.0 ~.;7 202 35.7 42 8.4 , 6766.0 6.3 194 35.7 42 8.4 , 6768.0 4.9 179 35,6 4'2 8.4 * 6770,0 6,.I t81 35,6 42 8.,5 * 6772.0 6.9 185 35.5 42 8.5 * 6774,0 b,~4 '169 35.5 42 8,5 * 6776.0 e.8 '176 35.5 :42 8.6 10.3 10.3 C 10.3 C 10.3 C 10.3 10.2 10.2 10.3 I0.4 i0'4 i0.3 D 10-3 D 10-3 10.3 10,3 t0,3 10,2 D 10,0 D 9-9 10,0 .10,2 ~I0,4 F :10,3 F ~i0,2 !:I0.2 10,2 '~I0,3 ~10-3 iF 10-3 F 10,2 F 10,1 ~10'0 9,9 ~I0,0 I0,1 ~10-i 'g 10-1 E ~10,1 E '10.0 '10-I AILANTI¢ RI¢Ii~IEbD CO. ii.H-? PAGE 56-FILE ,--....---..-.-----,-..-------------------------------, INDEX DEPTH ~ DIP OIP a DEr, DE~, DIAM DIAM , BE6T · AZI. * AZI. 1-3 l'4 * =i 6778,0 },0 183 35.5 42 6780.0 6,~ 179 35.4 41 6782.0 5,8 166 35,3 42 6784,0 4.8 169 35,3 42 6786,0 }.8 181 35.2 42 6788,0 5,:5 146 35,2 41 6790,0 9,6 155 35,3 41 6792.0 ~...8 i80 35,3 42 6794,0 ~.;7 153 35,3 42 6796,0 11.1 160 35.3 41 6798,0 9.1 175 35.4 42 6800,0 35.4 42 6802,0 35,3 42 6804,0 ~.9 199 35,3 42 6806.0 8,;V 187 35-3 42 6808.0 8~2 176 35,3 42 6810,0 8.0 172 35.2 42 6812,0 8,0 175 35,2 42 6ai4.0 8,~2 173 35.2 ~42 6816,0 7,i8 169 35,2 42 6816.0 ~.;5 172 35.2 42 6820,0 7.9 i78 35.2 42 6822,0 ~,~5 179 35.2 42 6824,0 8~0 180 35,2 42 6826.0 9r2 180 35.1 41 6828,0 ~,.9 173 35,1 41 6830,0 ~,6 172 35.1 42 6832,0 7.9 169 35,0 42 65{4,0 8,1 172 35.0 42 6836,0 9,~0 183 35.0 42 6838,0 9.0 184 34.9 42 6840,0 ~.~8 1.72 34-9 42 6842,0 ~.~4 171 34,9 42 6844,0 8.~6 190 35.0 42 6846,0 9.9 193 35.0 42 6848,0 9~2 ~180 34.9 42 6850,0 8,0 i75 34.9 42 6852,0 ?,;5 171 34,9 .42 6854,0 9.0 186 34,9 42 6856,0 8/6 -186 34.9 8.7 10,3 8.6 10,3 8,6 ~10,3 8,5 10.3 8.5 ~10,2 8.5 10,2 8,5 10,2 8,5 ~I0,I 8,5 *~10,1 8,6 10.1 8,6 10.0 8,6 i0.0 8,5 9,9 8,5 9.9 8,6 9,9 8.5 9,8 8,6 9'9 8.6 8,6 :9,9 8.6 9,8 8.6 9,8 8,7 9,8 8,7 8.7 9,8 8,7 8.8 9,9 8,8 9,7 6,8 9,8 8,8 9,8 8,9 8,9 9.8 8,9 9,8 8,8 9.7 8,8 9.8 8.9 9,? 8.9 8,9 9.,6 8,9 9.6 8,9 9,6 8,8 ATLANTI~C R~CHEIELD .CO. iIH-7 PAGE 5?-FILE 2 , # FORMATION # BOIaEHOLE # OU~L. e . ,.--..-----.-------,----------------------------------, I~DEX e ~ DEPTH e DIP D~ , DE V, DEV, ~IAP DIAH * ~EE~T a , e AZI. * AZI. 1-3 2-4 * =A , , 6858.0 8.~4 , 6860.0 9.:5 , 6862.0 9.;9 , 6864.0 9.~1 * 6866.0 9.~0 * 6868,0 * 6870.0 8.'6 # 6872,0 9,0 # 6874,0 9,5 * 6876.0 * 6878.0 9.!8 * 6880,0 8.;7 , 6882.0 * 6884,0 * 6886.0 9.~2 * 6888,0 9.;7 , 6890.0 10.0 * 6892,0 ~.10,~2 * 6894,0 10~2 , 6898,0 1~.0 , 6900.0 10.6 * 6902.0 * 6904.0 -1~.;5 * 6906,0 ~10,'6 , 6908.0 11o. 1 * 6910,0 , 6912.0 * 6914-0 ,10,6 . 6916,0 10;5 * 6918,0 * 6920,0 ~1~. 6 * ~922.0 ~11,9 * 6924.0 ~1~.~6 * 6926.0 1).0 , 6928.0 10,'6 . 6930.0 ~10.9 e 6932.0 1~.~2 * 6934,0 * 6936.0 e 6938.0 184 183 .183 179 180 17.9 185 191 181 180 178 171 1.67 1'/0 1'75 180 180 177 1'/4 lg7 17~ 17~ 180 170 1~1 177 1,.72 175 170 195 183 34.8 42 8.8 9.6 E 34.8 42 8.8 9,5 E 34.8 42 8.8 9.4 34.8 42 8.8 9.4 g 34,8 42- 8.8 9,4 E 34,8 42 8.8 9.5 34.7 42 8,8 9.'5 E 34.6 42 8,8 9,4 34,6 42 8.8 9'3 E 34,6 42 8.8 9,3 34,6 42 8,7 9,3 34,6 42 8.7 9.3 34.5 42 8.7 9,4 A 34,5 42 8,7 9,4 A 34,6 42 8,8 9,4 34,6 42 8.7 9,4 E 34,5 42 8.6 9.3 E 34,5 42 8,7 9,3 g 34.5 42 8.6 9.3 34,2 40 9,3 8,8 34.3 40 9.3 8,8 E 34,2 40 9.3 8.7 E 34,2 40 9,3 8,7 g 34,2 40 9,3 8.7 E 34.2 40 9.4 8.8 E 34.2 40 9.4 8.8 34,2 40 9.3 8,8 E 34.1 40 9.2 8.,7 g 34,1 40 9,3 8,7 E 34,0 40 9.3 8.7 E 34,0 40 9.3 8.7 E 34.0 40 9,3 8,8 E 34.0 40 9.3 8,8 E 34,0 40 9.3 ~,8 E 34.0 40 9.2 8.8 34.1 40 9.2 8,8 E 34,0 40 9.3 8,9 E 34.0 40 9.3 8,8 34.0 40 9.3 ~,8 F 34,0 40 9.4 8°8 E * 6940,0 ~12,.4 -188 33.9 40 9.4 8.8 * 6942.0 11,3 175 33,9 40 9,3 8,8 * b944.0 ~10.:5 173 33.9 40 9.3 8.8 * 6946.0 10.9 178 33.9 40 9.3 8,8 # 6948.0 ,1~.;7 180 33.9 40 9.3 8.8 * 6950.0 12,0 178 33.8 40 9.3 8.8 * 6952.0 ,1~.{8 t78 33.8 40 9..3 8,8 # 6954.0 ~14,0 179 33.8 40 9.3 8,8 * 6956.0 ~14,3 182 33,7 40 9.3 8.8 * 6958,0 ~14.'6 183 33.7 40 9,3 8,8 * 6960.0 ~14,;7 180 33.6 40 9.3 8,8 * 6962.0 t12.9 171 33.6 40 9.3 8.7 . 6964.0 ,Ie,18 165 33.6 40 9,4 8.7 * 6966.0 .14.:5 183 33.5 40 9,4 8.8 * 6968.0 'I4~0 190 33.5 40 9,4 8,8 * 6970,0 -13,3 -187 33.5 40 9,4 8.8 * 6972.0 ,14,;7 177 33.5 40 9,4 8,8 * 6974.0 ~14'.~4 179 33.5 40 9.4 8.8 * 6976.0 ~I3,~5 186 33,5 40 9,4 * 697}.0 ~13,~4 179 33,6 40 9,3 8,8 * 6980.0 t5~2 169 33.6 40 9,4 8.8 # 6982.0 ~t3.9 192 33.6 40 9-3 8,8 # 6984,0 31~.~8 187 33,6 40 9.3 * 6986,0 ~13~1 177 33.5 40 9.4 ~ 6988,0 1~2 180 33.5 40 9,5 8'7 # 6990.0 ~1~.~8 182 33.4 40 9,5 8.7 * 6992.0 13'3 213 33.4 39 9,4 * 6994°0 ~i:{,6 210 33.4 39 9,5 8,5 * ,6996.0 ~13,3 188 33.3 40 9,6 * 6998.0 ~I~.:7 186 33'3 40 9.6 8,6 * 7000.0 9,,! 210 33,2 40 9.6 8,5 # 7002.0 10~0 212 33,2 40 9.6 8,4 * 7004,0 ~9.~8 229 33.2 40 9.7 * 7006-.0 10;7 239 33.2 40 9.7 8.5 # 7o08.o 9~4 241 33°2 40 9.7 8.5 * 7010,0 9,~6 228 33.2 40 9.7 8°,5 * 70'12,0 8,~8 225 33.2 40 9,8 8.4 . 7014o0 4.~6 232 33,3 40 9,8 # 7016,0 9,:5 2~6 33.3 40 9,7 # 7018,0 ~18,:5 i79 33.3 39 9.7 8,3 ATbANTLC R~CHflEbD ~CD, ~1~-? PAGE 59-FILE * 'FORMATION # BO~EHOLE # #------------------#----------------o-----------------# INDEX DEPTH # D~P D.~f # DfV. DEV, aI~ DIA~ #tEEST ~ AZI, , AZI, 1-3 2-4 7020,0 ~1&,6 182 33,3 40 9,7 0.3 7022,0 33,3 40 9,7 8,2 7024.0 ..lC.2 300 33,3 40 9,7 a,l F 7026.0 2~.~0 316 33.3 40 9,7 8.1 F 7028.0 33.3 40 9.7 7030,0 33,3 40 9.8 7032.0 ~2~2 279 33.3 40 9.9 8.2 7034,0 9,3 279 33,3 40 ,~0,0 8,3 D 7036,0 33.3 40 ,~0o0 8,3 7038,0 ?23,9 !:70 33,3 40 .tO,O 8.3 D 7040,0 ~14,9 200 33,3 40 ,10.0 8.3 .7042,0 ~12.9 201 33.3 40 9.9 8.4 F. 7044.0 ~1~*~2 212 33,3 40 9,7 8.3 F 7046,0 ~I0.9 157 33.2 40 9,6 8,I D 7048,0 33,2 39 9,6 7050,0 33.2 39 9.6 7052,0 33°3 40 9.6 7054,0 33-3 40 9,5 8.2 ~7056,0 2~.,.1 323 33,2 40 9,4 8-3 F 7058,0 2)-0 322 33.2 39 9.3 8.~ 7060.0 28,4 325, 33,1 40 9,3 8,0 E .70'62.0 2B¢2 324 33,2 40 9.2 &.O E 7064,0 29~ 326 33,2 40 9,3 8,t E 7066,0 28,9 327 33,3 40 9.4 8.2 ~7068.0 ~3,~4 't78 33-3 39 9,5 8-! D 7070,0 ~t5.4 [80 33,2 40 9,4 8.! 7072.0 ~15.0 I81 33.! 39 9,4 8.0 ~F 7074,0 $.~8 323 33,1 39 9.4 8,0 7076,0 '~I3.0 330 3.3,0 3~ ~,4 $.2 .7078.0 ~.13~3 332 33,0 39 9-3 8.3 7080e0 r12~2 ~330 33.0 39 9*3 8.2 ~ 7082,0 5~2 'I8 33.0 39 9.3 8.2 E 7084,0 ~,~7 21 33,0 '38 9,4 8-3 7086,0 8~1 ~4 33,0 38 9,6 8,4 7088,0 4.0 25 33,0 39 9,7 8.4 7090.0 6¢0 20 33.0 39 9.6 8.4 C 7092,0 6,3 356 33.0 39 9,4 8.2 C 7094.0 5.9 ~358 33~,0 39 9.3 8.! ;7096,0 ~5,~4 ~35~ 33.0 '39 9-3 8, t '7098,0 5,:2 ~1 32,9 39 9,4 8,1 E ************************************************************************* DEPTH 7100,0 7102.0 7104,0 7106,0 7108.0 7110,0 7112.0 7114,0 ~7116,0 7118.0 ~7120.0 7122o0 7124.0 7126.0 7128.0 7130.0 7132.0 7t34,0 ~7136,0 7138,0 ~7140,0 7142.0 7144,0 7i46,0 7148,0 7150,0 7152,0 7154,0 7156.0 715e.o 7160,0 7t62,0 7164,0 ~7t66,0 7168,0 7172.0 '7174,0 ~7178.0 5,9 4,0 49 .:8 48 ELD ,CO. IH-7 PAGE 60-FILE ********************************************************* OR~A~CN # BQ~EH~LE #OUAL. -------------,----------------------------------, INDEX 25 343 '301 240 243 2.43 246 .3 i41 107 '16 45 341 57 29 ~3 57 56 354 44 3 31 308 330 33.0 33.0 33.0 32.9 32.9 32.8 32.8 32.8 32,8 32.8 32.8 32.8 32.8 32.8 32.8 32,8 32.8 32.8 32,8 33.8 32.8 32.8 32,8 32.8 :32.8 32'9 32,e 32,8 32.8 32,8 '32.8 32,8 32.8 :32'8 321,8 32,8 32.8 32.7 32,7 32-7 DIAH # BEST 2~4 # =A 38 9.4 39 9.6 8.2 39 9.7 8.2 39 9.7 8.2 39 9.7 8.2 '39 9.6 8.1 39 9.6 8. I 39 9.6 39 9,6 8.1 39 9.5 8.2 '39 9.6 8,2 39 9.6 '39 9,6 39 9.6 8.3 39 9.6 39 9,6 8,2 39 9,5 8.2 39 9.5 39 9,5 39 9.5 8.2 39 9.4 8.2 39 9.4 39 9,4 39 9,5 39 9-6 8.2 39 9.4 0.2 39 9.4 39 9.4 8.3 39 9,4 8*3 '39 9-3 8.2 39 9,3 8,2 39 9.2 8,2 39 9,2 8'i 39 9.2 8,2 39 9.3 8.2 39 9,;3 8.2 39 9,3 39 9-3 8.3 39 9.3 8.3 39 9,3 DEPTH 7180,0 3.~1 12 32-6 7182.0 6.15 20 32.6 7184.0 32°6 7186,0 32,7 7188.0 2~.0 169 32.7 7~90.0 4,~4 213 32.7 7~92.0 5.~8 228 32.9 7~94.0 0;.5 345 32.7 7196.0 4.0 r 30 32'7 7200,0 2'8 29 32,9 7202,0 32.7 7204.0 8.:5 'I8 ~2,7 7206,0 32,7 7208.0 25.;5 :154 32.7 .,72~0,0 3,~1 35 32.7 92t2.0 3,~1 70 '32.7 9214,0 ~ ,.2 ~ 346 32,7 .72~6.0 t,l 244 32,7 ;7218.0 r}'~t 331 32.7 7220.0 't';3 1~ 32.7 ~7222.0 5.~4 33 32'7 ~'~224'0 ~.'3 350 32'7 '7226.0 t.:5 248 32'7 7228.0 t.9 244 32'7 ~7230.0 ~.~8 202 32'7 7232'0 ~.;~ 229 32'7 7234.0 ~''~l 248 32'7 7236'0 0'~4 ~i84 32'7 7238.0 3':0 29 32'7 7240.0 0.~5 ~346 ~32.6 7242'0 1.9 211 32.6 ~7244'0 6.9 347 32.5 "7246"0 5.9 '~79 32.5 7248.0 0.8 148 32.5 7250.0 3.6 226 32.5 7252.0 2.~4 253 32.5 7254.0 ~j5 263 32.5 7256.0 3.4 ~353 32.5 ~7258.0 3'3 32 32.5 39 40 39 39 39 39 39 '39 40 40 40 40 40 40 40 40 40 :40 40 40 40 41 4t 4t 41 41 41 41 4~ 41 41 41 40 40 40 40 40 40 9.3 8.2 9.2 8.2 9.1. 8.2 9.2 8.2 9.2 8.2 9.3 8.2 9.3 8.2 9.2 8.3 9.2 8.2 9.2 8.2 9. I 9.2 9.2 8.2 9.2 8.2 9.3 t~.2 9.3 8.2 9.4 8'3 9,5 8.4 9.4 8-3 9.3 8,3 9-3 8.2 9.4 8'3 9.5 8'3 9.6 9.5 8.4 9,3 8..4 9.3 8.3 9.4 8.3 9.3 8-3 9.3 ~.3 9.3 8-3 9.3 8.3 9.2 8.3 9-1 8.4 9.1 8.4 9.3 9.4 8..5 9.3 9.1 8.5 9.1 8.5 # F F D D D D C A C C C E E C C C E A E A]LANTIC RICHFIELD CO. IH-7 PAGE 62-FILE ************************************************************************* . ,------------------,----------------------------------, INDEX · DEPTH ~ DIP PI~ ~ DEr. DEV. DIAH DIA~ ~ BEST # * AZI, # AZI, 7260.0 4,3 37 32.5 40 9.! 8.6 7262.0 2~7 60 32.4 40 9.0 8,6 .7264.0 2,8 66 32,4 40 9.1 8,6 7266.0 2.4 70 32.4 40 9,3 8.7 7268,0 ~.2 85 32.3 40 9.3 8.7 7270,0 1,3 64 32,3 40. 9,3 8.6 7272.0 2*0 48 32.4 41 9.3 8,6 7274,0 2'6 :52 32.4 40 9.3 8,7 7276.0 3.,4 64 32,3 40 9,5 7278.0 1.6 73 32.3 40 9,6 8,8 7280,0 3.S 28 32.2 40 9,5 7282.0 2,1 ~54 32.2 40 9,4 8,8 7284.0 ~,~2 53 32,2 40 9,5 8,8 7286,0 4,9 57 32.2 40 9.6 8,9 7288.0 ~.~8 65 32.2 41 9,5 8.8 7290,0 5.~! 72 32.2 40 9.3 8,8 7292.0 5.;0 256 32-i 4t 9-1 8,8 7294°0 0.9 12 32-i 41 9,0 8,6 7296.0 0.4 1,7'9 32,0 4i 9,1 8,5 7298.0 1,9 151 32.0 42 9,3 8,5 7300.0 4.0 74 31.9 42 9,4 7302,0 4,;7 iOi 31,g 42 9,5 7304,0 31.8 42 9,5 7306.0 3.~? 53 31.8 42 9,4 8,5 7308.0 3..1 45 31,8 42 9,4 8,5 7370,0 2,9 57 3t.7 4i 9,4 8..6 7312,0 6,.:3 60 3i.7 41 9.4 8,6 7314.0 ~,9 70 3~,8 .4i 9,4 7316.0 ,~,3 151 31.8 41 9,3 73i8.0 }.9 3.57 3t.9 41 9,2 8,5 7320.0 6,;5 30 31.9 41 9.2 7322°0 31,9 41 9,3 7324.0 4,~8 :336 3i.9 41 9.4 7326.0 4,.2 '328 3~,9 4i 9.3 7328,0 {,..! 342 31.9 41 9,4 7330.0 31,9 40 90r5 805 7332,0 }.:$ 354 31,9 40 9,~ 8.5 7334.0 5.;.5 336 31.9 40 9,6 8.5 7336.0 4.~6 '156 3i.8 41 9,7 8,5 7338.0 ~.~3 173 31.8 41 9,8 8.6 7340,0 7342.0 7344,0 7346,0 7 348,0 7350.0 7352.0 7354,0 .7356,0 7358,0 7360.0 7362 · 0 7366,0 736~.0 7370,0 73~2,0 7374.0 7376'0 7378,0 7380,0 ~7382.0 738 ~. 0 7386,0 7388,0 7390,0 ~ 7392,0 7394,0 7 }96,0 7398.0 .7400,0 :~ 7402,0 7404,0 ~7408,0 ~41:0,0 74i 2.0 74t4~0 ~7418,0 260 333 ii 56 47 5O :ii4 193 31,8 41 9,8 't85 31.9 41 9,8 8,6 314 3t,9 41 9,7 8.6 ~14 31.9 4i 9.7 8.5 249 31,9 42 9.8 244 3~.9 42 9.6 8,5 31'.8 42 9,5 8.4 '146 31,8 42 9,4 8.3 C 274 31,8 42 9,4 8,3 C i49 3i,8 42 9.5 8,4 C ~144 31.8 42 9,7 8,4 C 141 31,8 42 9-7 8,5 C 'i87 3i,8 42 9.7 8,.5 234 3i.8 42 9.6 8.4 g 202 31,7 42 9.6 8,4 E 231 31,? 42 9,5 8,3 245 3i.7 :42 9,4 8,3 E 328 31,6 42 9.3 8,2 E 360 3t.6 42 9,2 8.2 72 31.7 42 9.2 8.2 61 3!-7 42 9.2 8'3 ~30 3t,7 42 9.3 $.3 .7!3 31.6 42 9.2 8.3 40 3i.6 42 9,1 8°2 C 53 3i,6 r41 9'1 8'2 C 4t 31,6 42 9.3 8-3 C 31.5 42 9.5 8.4 3i',5 4t 9,5 8.5 3~o5 42 9,4 8,4 3i'.5 42 9.1 3i',4 42 8.9 8.2 31,5 42 8,8 8.2 31,5 42 8.8 31,4 41 8,8 31,4 41 8,7 8.3 31,4 42 8,7 8,3 31,4 42 8.8 8-3 31.4 43 8.8 8'3 2i5 3i,4 43 8,9 8'3 D ~150 3i'3 43 9,0 8,3 E ~ A ~ .# A C A F F F F D ~IbANTIC RICH~IEbD .CO. .1H-? PAG~ 64-FIbE ************************************************************************* # FOR~AII£<N ~ BQ}EH.DLE # GUAb. ,------------------#----------------------------------, INDEX DEPTH # DIP DIP # DE¥. DE¥. DIAM # AZI, # AZI, 1-3 DIAM a BEST 2'4: a 7420.0 2.1 89 31.3 43 9.2 8.4 D 7422.0 1395 51 31.3 43 9.2 8.4 D 7424.0 5.~1 51 31.3 43 9.2 8.4 E 7426,0 e.*4 46 3t.3 42 9.2 8.3 g 7428.0 t.0 32 31o2 42 9.1 8-3 g 7430.0 4.6 58 31.3 42 9.2 8.3 7432.0 4.;7 68 31-3 43 9.3 9.4 7434.0 ~,~i 73 31.3 43 9.4 8.4 E 7436,0 3.;7 52 3~,2 43 9.3 a,3 E 7438.0 2,3 44 3~.2 43 9-I 8,3 E 7440.0 ~..1 236 31.3 43 9.1 8.3 E 7442,0 ~,;7 86 3~,3 44 9.1 $~3 E , 7444,0 ~.;5 8! 3~,3 44 9.3 8,4 g 7446,0 I~5 ~I~5.4 3~,3 43 9.4 8.5 7448.0 5,4 255 31'3 44 9,3 9,4 E 7450.0 5.;? 216 31.2 44 9,2 8.4 C ~7452,0 3;6 286 3~,2 44 9,2 8.4 ,7454,0 5.~8 279 31,2 44 9,3 9,4 E .7456.0 4.;7 28 3:~,2 44 9,! 8.3 E 7458,0 i;:7 58 '31,2 44 8,9 8~3 E ~7460.0 4,~2 :60 31,2 44 8.9 '8,4 ~7464,0 4,;7 43 3t,2 44 8,9 8-3 7468.0 5..~1 68 31-1 44 8,9 8*4 .7470.0 6.~8 .57 3i,:i :44 9.0 8'3 E 7472,0 ~,~8 :52 31,~ 44 9,0 8-3 E ;7474,0 6;<0 218 31,0 44 9,0 8,4 .7476.0 3.~8 ~34 3~,0 44 8,9 8.4 ~7478.0 3,9 ~6! 31,0 44 8.8 8.3 ~7480,0 3~0 ;72 31.0 ~44: 8,7 8'3 E ~74.82.0 6.>4 89 '31.0 .44 8.6 8-3 C 7484.0 8,!4 77 '3t.0 44 8,6 8*3 C .7486.0 12,;5 .69 '31.0 43 8,8 8,5 A ~74.88,0 5,9 .~f09 3~.0 44 9~2 8.6 C ~:74'90,0 ~,~1 ~123 31,0 ~44 9,6 8,8 A ~7492,0 :4~i '31 31,0 45 9.4 8,7 A ~7494.0 5.~8 :.41 31.0 44 9.0 8.6 g 7496,0 e,:6 48 31,0 44 8.9 8.5 7495,0 4~:0 ~152 31,0 ~44 9,0 8-4 C ATbANTXC R~CHFIEbD .CO. # #mmmmmmmmmmmmmmmmmm.mmmmmmmmmmmmmmmmmmmmmmm . DEPTH . DIP D~F , DEV. DEV. # · AZI. # AZI. 1-3 ****************************************************** # 7500.0 7502.0 7504.0 7506,0 7508,0 75t0.0 75t2,0 7514,0 7516,0 7518.0 7520,0 7522.0 7524.0 7526,0 7528.0 7530.0 7532,0 7534,0 7536,0 7538.0 7540.0 7542.0 7544.0 7546.0 7548.0 75'50.:0 7552.0 7554.0 7556.0 .7558.0 .7560,0 7562,0 7564,0 7566,0 7568,0 7570,0 .7572,0 7574,0 7576,0 7578.0 4,0 5.9 2.,4 6.0 13.,2 2 3.8 5 ,;5 4 .:5 0 .;7 3 3.9 3.9 3 3.0 3,1 4,4 g,8 PAGE 65-FIbE 2 * OU~b, # --=-o------, I~DEX , DIAN ,tEEST , 2'4 * =A :148 31.0 45 8.9 8.3 62 31.0 45 8.9 8.4 119 31.0 44 9.0 8.4 178 31.0 44 8.9 8.4 1349 31.0 44 8.8 8.4 45 31.0 44 8,7 8.5 1347 31.0 44 8.7 8.4 56 30.9 45 8.6 8.4 .56 30'9 45 8.6 8.4 6 30.9 45 8.6 8.4 ~72 31.0 44 8.7 8.4 200 31.0 45 8.9 8.5 203 30.9 46 8.9 8.5 66 30.9 46 8.9 8-4 334 30.8 46 9.0 8.5 66 30,8 46 9,0 8.5 85 30,8 45 8.9 8.4 '52 30.8 45 8.9 8.4 ~35 30,.7 45 8,9 44 30.7 45 9,0 30.7 45 9.I 30,7 45 9,2 8.6 ~1'4 30,8 45 9.2 ~59 30.8 45 9.3 8.6 28 30.8 45 9'3 8.6 58 30.8 45 9.3 8,7 30 30.8 45 9.2 8.6 30.8 45 9,0 8.5 30.7 45 9.1 30,7 45 9,2 8.6 140 30-7 45 9.4 8,7 49 30.7 45 9.4 0.7 '330 30.7 45 9'3 8.8 48 30.8 45 9,4 8,7 32 30'8 46 9.2 8.5 87 30.8 46 809 8.4 ~79 30,8 46 8.9 8.4 128 30,7 46 8.8 8.5 13:9 30.7 .45 8.8 8.5 73 30.6 45 8,7 C # E E E £ C E A A A B A E E ~ C ~ C D Ill] {.,ANTIC RICHFIEi.,D CO. IH-7 PAGE 66-FILE , # FOR~A~ :~CiN , BQI.'EH.QLE * QUAb, · ,------------------,-------------------.---------------, INDEX · DEPTH # DIP DiP , DEr. DE¥. DIAM DIAM , BEST , * AZI. · AZI. 1-3 2.-4' , =A · #,,******* ,,, a, ****************************** ,******,,,, #**** #,, ,,***** * , 7580,0 4..8 76 30,8 45 8.7 8.4 · B · 7582,0 3,~4 71 30,8 45 8,8 8,4 F # 7584,0 30,7 45 8.9 8,4 # 7586.0 ~.,2 84 30.7 45 9.0 8.4 D · 7588,0 30.7 45 9.0 8.5 · 7590.0 4.;7 ~178 30.7 45- 8.9 8.5 D , · 7592.0 5.3 183 30.7 46 9.0 8.6 B · 7594.0 5.!8 288 30.7 45 8.9 · 8,5 D , · 7596.0 5.~8 315 30.7 46 8,9 8,5 D # 7598.0 3.5 353 30.7 46 9.1 8,6 C , · 7600,0 ~..~1 75 30.7 46 9,2 8,6 · 7602.0 9.9 1.54 30.7 46 9.4 8.:5 F · 7604°0 2,9 69 30,7 46 9.4 8,5 # 7606.0 6.;7 5 30.7 46 9.2 8.5 'E , · 7608.0 3-.0 324 30.6 46 9,3 8,6 'E · 7610.0 5.;7 87 30.6 46 9.4 8.,6 C · 7612.O 6.0 73 30.6 47 9,3 8,6 C # 7614.0 4,9 60 30,5 47 9,3 $,.5 C · 7616.0 3.5 22-3 30.5 47 9,3 8.5 C · 7620.0 ~..2 ~107 30.O 50 8-7 9,5 E , , 7622.0 0.~7 .65 30.O 50 8.6 9.5 · ~7624.O 1'~8 25 29.9 50 8,6 9,5 C * , 7626.0 0.;7 24 30.0 49 8,7 9.4 C · 76-28.0 4,,~4 I-9 30.0 48 8,6 9,3 C · 7630.0 5,~4 354 30.0 ~49 8,5 9.2 C · 7632.0 8 .:.:5 40 30.0 49 8,5 9,2 A · 7634.0 4.,2 41 29.9 48 8,5 9.1 .C · 7636,,0 ,t.~2 ~38 29.9 49 8.4 9,1 · 7638.0 It .~:4 70 30.0 49 8.4 9.0 · 7640.0 J~o;7 :3 30..0 49 8,,5 9,0 E · 7642,0 :~.:5 345 30,0 48 8,6 9,0 C · 7644.0 :~.1 ~261 30,0 49 8.6 9.0 C · 7646,0 & j6 28 2'9.9 49 8,6 9.0 C · 7648.0 4.;7 39 30,0 48 8,6 9,1 .C · 7650.0 4.9 59 30.0 48 8,7 9.2 C. , 7652.0 4;6 :56 30.1 49 8.6 9-1 · 7654.0 4.~8 73 30.1 49 8,7 9.2 · 7656.0 4,9 ~3.7 30,1 48 8-,7 9.2 .C · 7658,0 i,,~6 241 30.2 48 8,6 9.2 A * · 7660.0 3.9 206 30.2 48 8,7 9.2 ATLANTIC RICHFIELD CO. IH=7 PAGE 67oFILE )~ FORNATION # BOREHOLE # #------------------.----------------------------------# INDEX DEPTH # ~IP D.~ · DEV. DEV, ~IA~ DIAH # BEST 2'4 # =A ~ 76~2,0 b,..1 49 30,1 48 8,7 9,3 C 7664,0 6,.4 45 30.1 49 8,b 9.2 C 7666,0 4.:8 49 29,9 49 8,6 9.1 C 7668,0 ~.4 36 29.9 49 8,6 9,'1 C 7670.0 29.9 50 8,6 9.1 7~72.0 29.9 50 8,6 9.2 7674.0 9.:5 ~11 29.9 50 8.5 9.2 A 7676.0 ].3 43 29.9 49 8,5 9.2 7678.0 ~19..~ 63 29,9 50 8.6 9..I C 7680.0 8~7 24 29.9 50 ~.6 ~.1 C 7682.0 29.9 49 8,6 9.0 7684.0 4.0 312 30,0 49 8,6 9.0 7686,0 30,0 49 8,7 9,0 7688.0 30.~ 49 8,7 9,1 7690.0 30.1 49 8,8 9,2 7692,0 3.~1 ~16 30,1 49 8,8 9-3 D 7694.0 10,.I 202 30,1 49 8,7 9,2 F 7696,0 9.~7 2~6 30,1 49 8,5 9,1 F 7698.0 30.1 48 8,7 9,3 7700,0 ~.:5 ~4 30,~ 49 8,8 9,3 F 7702,0 8.0 137 30,1 49 8,8 9,3 F 7704.0 3.~2 309 30.1 49 8.8 9.3 7706.0 ~.3 248 30.~ 49 8,6 9,2 7708.0 1~,'0 70 3000 49 8,4 9.2 C 77~0.0 30.0 49 8..4 9.2 7712,0 29.9 49 8.6 9.! 7714.0 2.~5 204 3000 49 8.8 8.9 A 77~6,0 6,0 45 30.0 49 8.8 8.9 C 7.718.0 7.g 242 30.0 49 8.7 8.9 E 7720.0 9..1 23b 30.0 49 8,7 8&9 E 7722.0 ~.8 2 29.9 49 8,6 8.8 A 7724.0 12.'6 64 29.9 48 8.6 8.8 7726.0 ~14.~4 76 29.9 .48 8,7 8,8 D 7728.0 8.;8 83 29-.9 48 8,8 8.9 D 7730.0 9.0 IO! 29.9 49 8,7 8,8 D 7732.0 29.9 49 8,7 8,8 7734.0 29,9 49 8.7 8,8 7736.0 29.9 49 8.7 8.8 7738.0 29,9 49 8.8 8.8 7740.0 29,9 49 8.8 8.8 7742.0 29,9 7744.0 29,9 7746,0 2~4 330 :29,9 7748,0 3,9 286 29,9 7750,0 6,2 251 .29,9 7752.0 29.8 7754.0 29.8 7756.0 6.9 54 29.8 7758,0 29.7 7760.0 5.6 }1-5 29.7 7762.0 2~4 303 29,7 7764.0 29.7 7766.0 29.3 94 29,8 7768.0 24.;~ 93 29,8 7770.0 5..! 5 29.8 7772.0 6,~8 357 29,8 7774.0 3.i8 29 29,7 7776.0 5,3 326 29,7 7778.0 3;6 319 29,7 7780.0 4.8 ~17 29,7 7782.0 29.7 7784.0 4.~8 72 -29,? 7786.0 3.~5 40 29'7 7788.0 ~10.~5 46 29..7 7790,0 29.7 7792.0 9~7 92 29.7 7794-0 3.~7 i48 29,7 7796.0 &.-O 8 29.7 7798.0 -29,7 7800.0 6.~8 88 29,7 7802.0 ~.~3 23'7 29,7 7804,0 ~10.0 2 .29o7 7806.0 5.4 357 29,7 7808.0 9.~X 73 29,7 78i0.0 iO.l 98 29,7 -7812,0 ~14,~0 54 ~29.8 7814.0 3.:3 347 29,8 7816.0 2.6 74 29,7 .7818,0 ~14.;7 96 29.6 7820.0 29.6 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 50 ~50 49 50 49 50 50 49 50 5O 50 $0 50 50 49 49 49 49 49 48 49 8.8 8.8 8.8 8.9 8°8 8°9 D 8.8 8.9 D 8.7 9.0 D 8.7 9.0 8.7 8.9 8.6 8.8 O 8.6 8.6 8,6 8.5 D 8.5 8.2 8,0 '~..7 7-9 .'~,9 F 8.5 8.~7 F 8,8 9.0 C 8.7 8.8 8-7 8,6 A 8,6 6.4 C 8,6 8.3 C 8' 7 8.5 C 8.7 8.7 8.7 8.7 O 8,7 8,8 F 8,7 8.7 8.7 8.7 8,6 t). 7 D 8.6 8...7 8,6 8.8 8.6 8.7 8,7 8.6 D 8.8 8.6 D 8.9 8.6 B 8.9 8.4 D 8,8 8,3 D 8'6 8,2 B 8.5 8.2 8,5 8.2 O 8,4 8.2 O 8,4 8. i 8,4 >e # A~IbANTIC RICHFIELD ,CO. I'H-7 PAGE 69-FILE: 2 ~ FORWAT~CN ~ BG}EHOLE #OUAL. ''''''''''''''''''''''''---'---''-'-'-----------------, INDEX DEPTH # DIP DIP # DEV. DEV. DIAM DIAH , BEST # AZI. * AZI, 1-3 2~4 * =A 7822,0 7824,0 2.1 ;7826.0 2.8 7828.0 7830.0 7832.0 7834.0 7836.0 4-0 7838.0 7840,0 '7842,0 .7844,0 0;7 7846,0 ~,~1 7848,0 ~,~5 .7850,0 0,~5 7852.0 ~,~7 ~7854.0 2,~0 7856,0 7858,0 7860.0 ~-0 7862.0 0,9 7864.0 .7866,0 0,i4 ~'7868.0 3,:5 ~7870,0 7872.0 7874,0 ~.~.8 7876.0 0~8 7878.0 7880,0 '~7882.0 7884.0 2.9 ,7886,0 2~4 7888.0 7890.0 2'3 7892.0 0~5 7894.0 7896.0 ~,;7 7898,0 7900,0 i~4 107 5 345 263 256 313 269 276 307 316 23O '121 338 :{50 96 1359 351 281 '35t 73 18 125 257 204 ~ 348 :J2i ~317 ~64 80 47 29.6 49 8.5 8.1 F .29.5 49 8.6 8.2 ~ 29,5 49 8.6 8.3 E 29.5 50 8.6 8'3 E 29.5 50 8.7 8.3 C 29,5 49 8,7 8.'3 C 29.5 49 8.6 8,2 C 29.5 49 8,6 8.2 E 29,4 49 8.6 8.2 E 29.4 49 8.7 8,3 ~ .29,4 49 8,7 8.3 E .29,4 50 8.6 8.3 g 29,4 50 8,6 8.3 E · 29,4 50 8.'7 8,13 E 29'3 51 8.8 8.4 g 29,3 50 8'8 8.4 E 29.3 50 8-8 8,4 'E ~29,3 :51 8.8 8.4 E 29.3 51 8.8 8.4 C 29,3 51 8,8 8.2 E 29'03 5! 8,8 8,2 ~ 29-3 50 8,8 8,2 E 29,3 5! 8,8 8.2 A ~29,2 ~51 8,7 8,1 E 29,3 50 8,8 8.2 ~ '29,3 51 8.8 8,!3 A 29,3 51 8,8 8.!3 E .29.2 50 8.7 8.:3 g 29.2 5.1 8,7 8.4 'E ~29,:I 5i 8,7 8,4 g 29,2 50 8,6 8.3 E 29,2 51 8.6 8,3 E 29.2 50 8,8 8,3 A 29,2 50 8,8 8.3 C 29,2 ~50 8,8 8,3 C ~29.2 .50 8.8 8-3 A 29,2 50 8,8 8.3 C 29.2 ~50 8,7 8,3 E 29.!i 50 8,6 8,2 ~ ~29,i SO 8,6 8:,2 ~ ATbANT[~C RI,~CH~I. EbD ~CO. tI~-7 PA~GE .70-FIbE 2 er 7902,,0 * 7904.0 3.0 * 7906.0 * 7908.0 4. # 791,0.0 # 7912.0 0.9 ,* 79i4.0 # 791.6.0 0.~7 * 7918.0 ~.;7 ~ 7920.0 er 7922.0 * 7924.0 4,,,2 ,a, 7926.0 , 7928.0 # 7930.0 3.0 er 7932.0 1.1 , 7934.0 0.~8 e 7936.0 ~, ,~5 ,~ 7938.0 1..,1 # 7940.0 2 er 7942.0 e, 7944.0 .~ 7946.0 # 7948.0 er 7950.0 5.~4 er 7952.0 1 .:5 # 7954.0 # 7956.0 5.9 # 7958.0 2.6 er 7960.0 2,3 er 7962.0 1. .;7 er 7964.0 er 7966.0 # 7968.0 er 7970.0 '~.6 # 7972.0 1.,2 4, 7974.0 2.;7 er 7976.0 2.0 er 7978.0 1.0 er 7980.0 227 25.5 2~72 28-7 199 265 189 208 173 223 278 9 ~175 124 211 82 199 189 156 257 234 236 253 2~8 235 29 21-7 245 :139 183 152 34O 335 331 ~29.1 49 8.6 8,3 29,2 48 8.7 8,3 ~29.2 47 8.7 8.4 29.3 46 8.6 29.3 46 6,6 8-5 29.4 46 8,8 8,7 ~29.5 47 8.9 8-9 29.r5 47 8,9 '9o0 29.5 47 8.9 9.0 29.5 47 8.9 9.0 29.5 46 8.7 29*6 46 8.6 29,6 46 8,6 8,4 29.6 47 8.5 ,~,9 C 29.5 48 8,4 ~,4 C 29.5 48 8,3 ~,1 A 29,5 49 6.2 29.5 49 8.2 ~,1 D 29,5 49 8.2 7.0 F 29.5 49 8,1 ~.0 F 29.5 49 8.1 7.0 F 29.5 48 8.1 ~,0 D 29.5 48 8,1 .7,0 g 29.4 49 8,1 ~,0 F ~29.4 49 8,0 7,0 D 29,4 49 8.0 ~,0 F 29.4 49 8.1 7.0 29.4 50 8.2 ~,0 D 29.3 49 8.2 7.t E 29.4 49 8.2 ~,1 E 29.4 48 8.2 7,1. E 29.4 48 8,2 ~,'1 E 29.3 48 8.2 7.2 E 29.3 48 8.2 ~.4 C 29.2 48 7.9 ~.7 29.1. 49 7,5 8,0 A ,29.1 50 7.1. 8.2 C 29.0 50 7.0 8,2 -28.9 51. 7,0 8.2 A 28.8 51 7.0 8.1. A # # A]LANTl¢ RICHFIEbD CO. 'IH-? PAGE ?I-¥ILE ************************************************************************* , , fOR~A~IC.N # BQ}EHDLE * OUAL, , #------------------,----------------------------------# INDEX · DEPTH , DIP DIP , DE¥. DE¥. DIAM DIAM , BEST # * .AZI, * AZI, 1-3 ************************************************************************* , 7982,0 2,'8 259 28,8 52 7,0 8.1 g # 7984.0 ~..8 247 28,8 51 6,9 · 7986,0 4.~2 360 28,8 51 7,0 8.1 C · 7988,0 4,8 :19 28,7 52 7,0 , 7990.0 0.~8 265 28°7 52 7°0 8.1 C # 7992,0 )..1 286 28.6 52 7.3 8.0 C · 7994.0 ~..1 ~1-5 .28.6 52 7.8 · 7996.0 6.9 58 28.6 52 8.1 ~.2 C · 7998.0 3.0 247 28,6 52 8.2 9.2 C · 8000.0 ~.~:2 280 28,6 52 8.2 · 8002,0 3.~8 2.6 28,6 53 8.1 ].1 C · 800&.O 4.2 ~3 28.6 53 8,2 9,2 C · 8006.0 I,~7 92 28.6 53 8'3 7,1 C · 8008.0 0..I 30 28,6 52 8.3 ~.1 C , 8010.0 2.8 282 28,6 52 8,2 .7,2 E , 8012.0 4.3 259 28,6 51 8.3 ~,2 C · 8014.0 ~.6 169 28.6 5:1 8.2 # 8016,0 1.0 149 28,6 50 8,1 · 8018,0 1~7 45 :28,7 49 8,4 7,5 F · 8020,0 3.3 343 ~28,.7 47 8,6 , 8022.0 4.;5 223 20,8 46 8.7 8,2 B · 8024.0 3.~2 232 29,0 46 8,6 , 8026,0 6-,~8 ~49 29,1 46 8,2 · 8028.0 .29,2 46 7,9 · 8030.0 29,2 46 7,9 · 8032,0 ~8 314 29,1 47 7,9 , 8034.0 29,0 49 8,0 ~.3 , 8036.0 29,0 50 8,0 , 8038.0 5.9 '31 .29'0 50 8.0 · 8040.0 0,9 226 29,0 49 8,0 · 80,42.0 ~.1 344 28.8 48 8,0 · 8044.O 28,6 4~ 7,9 # 8046.0 10.0 -1,73 28,5 .50 8,0 7,8 F · 8048.0 0,.2 ~30t 28.,~ $0 8,1 ~,6 C · 8050.0 4.;'5 5~ :.28,3 5O e.2 , 8052,0 4.~4 25 28,3 $0 8,4 # 8054.0 3.9 ~13 28'3 .51 8,5 , 8056.0 9.0 229 28,3 51 8,5 ~.4 C · 8058,0 3.~.1 29.6 28-3 51 8,4 · 8060.0 3.0 310 28,3 51 8,4 ~,3 *************************************************************************** AILANTIC :RICHFIELD CO, IH=7 PAGE 72-FILE 2 # , FOBi~A~]CN , BUt E~OLE ~ QUAL. ~ ~ ~-=**-----**---=---~------------*--*------------*-----~ INDEX ~ · DEP~ ~ DIP DIP ~ DE~, DEV, D]A~ DIAM ~ BE~ ){ 8062,0 5,~2 62 28,2 51 8.4 ?.3 C 8064,0 4.3 39 .28,2 51 8,4 ?,4 C 8066,0 ~.~2 80 28.2 5! 8.4 ?.4 C 8068,0 0.8 ~ll5 28,2 52 8.4 7,4 C 8070,0 3.3 30 28,2 52 8.4 ?.4 C 8072.0 2.4 59 28.2 52 8,5 7.5 C 8074,0 3.~2 213 28.2 52 8.6 ?.5 C 8076.0 0.9 217 28.2 52 8.6 7.5 8078.0 3.5 108 28.3 52 8.6 ?.5 C 8080.0 I.'6 255 28.3 51 8.6 ?.5 C 8082,0 0.'9 247 28.5 50 8.6 ?.6 E 8084.0 022 10 28.5 48 8.7 7,9 A 8086.0 ~.~ 2 .28.6 47 8.7 8.3 A 8088.0 2,6 247 28.? 47 8.6 8.7 A 8090.0 ).:5 14! 28-7 47 8,4 8.8 A 8092.0 3.:3 1.3.9 28.8 46 8.4 8094.0 6~8 79 28.8 4'7 8.6 8.8 C 8096.0 4.~2 343 28.9 47 8,7 8.7 C 8098.0 4.:5 ~135 28.8 48 8.8 8.3 C 8100,0 4.~2 157 28,8 49 8.8 8.0 A 8102.0 5~8 61 28.7 48 8.7 ?.8 A 8104.0 2-~2 2~7 28.6 48 8.7 7-9 E 8106.0 $.:5 90 28.5 49 B,3 8.3 C 8108.0 &.~4 40 28.4 51 7.9 8.5 C 8110,0 3.'6 87 28.3 51 7,6 8.5 A 81~2.0 3~0 124 '~28,2 5! 7,5 8,5 A 81i4.0 ~,,1 60 28.2 52 7.4 8.5 A 8~16.0 1~5 2?4 28.2 52 7.3 8,4 E 8~t8,0 ~3.~ 277 28.1 51 7.4 8,3 F 8120,0 S.6 262 28.! 51 7.6 8.4 O 8122.O 4,~0 94 28.0 5~ 7.9 8.2 D 8124,0 ~2 '~52 27,9 51 8.3 8.0 D 8126.0 ~.~! ~7 27.9 53 8.6 ?.8 A 8!28,0 0~8 353 27.9 53 8.7 7.8 C 8130,0 ~,2 40 27,9 52 8.7 ~.7 C 8132.0 1.~2 23 27,9 51 8.7 7,6 C 8134.0 ?.~3 2 27.9 51 8.5 ?,6 F 8136.0 9.~0 45 28.0 51 8.3 ?,7 B 8138,0 28.1 49 8,5 8140.0 ~t~,.,0 ~13 28.2 48 8.5 ?,9 'F ATLANTIC RItCHI~IEI.,D CO. iLH-,7 PKGE 73-FILE . $~ 'FORIiA'I!-IO N * E, Ola- EHOI.,E # QU~6, . #.........-........,..-.-.--.-------------------------, I~DEX , DEPTH * DIP D~ , DEV. DEV. IIlA~ DIAN , BEST · . AZI. # AZI. 1-3 2-4 * · *********# ~** a #******* #**** #** ********************************** *****#** * 8142,0 &.;7 9 28.2 47 8.4 8.1 , 8144.0 4,!8 ~127 28.3 48 8,3 8.3 , 8146.0 3.2 79 28.4 48 8,2 8.5 # 8148.0 2.9 ~'124 28.4 48 8.0 8.6 * 8150,0 1..g 290 28,4 48 7.9 8.6 * 8152,0 28.5 48 7,9 8.6 * 8154.0 ~,~2 '1:5 28.6 .47 7.9 8,5 * 8156,0 28.5 47 B,O 8.2 ~# 8158.0 28.5 :48 8.3 ~.7 * B160.0 2a,4 48 8,5 * 8162,0 a.:5 273 28,2 47 8.3 ~.0 . 8164.0 1,~8 ~320 ,28.1 ~48 7.7 ~.0 * 8166.0 28.0 5t 6.5 * 8168,0 27-9 51 5,8 ~ 8170,0 27.9 .52 5.3 6.2 # 8172.0 27'9 52 5-1 5.8 , 81'74,0 27,8 51 4,8 * 8176.0 27.? 50 ~.7 5.0 * 8175.0 27.6 ~51 4.6 * 8180.0 ,I,,~2 290 ~27'5 751 4.5 * 8182.0 27.5 52 4.4 4,3 # 8184.0 i3~7 299 ~27~5 ~52 4.4 4*3 * 8186.0 27,5 ::52 ~,3 4.2 * 8188,0 27.6 51 4.3 4.2 , ~190.0 27°6 51 4°3 4.2 , 8192.0 27.6 51 4.3 4.2 , 8194.0 27.6 51 4-3 4.2 , 819&.0 27.6 51 4.3 4.2 , 8198.0 ;48~8 217 27,5 51 4.3 4,2 , 8200°0 ;49..;1 217 27,6 51 4,3 4.2 , 8202,0 27~6 52 4,3 4.2 # 8204,0 ~13,~7. 296 ~27..6 52 4,3 4.2 * 8206,0 ~I3.;7 295 27,6 52 4,3 4.2 * 8208,0 27,6 ~52 4,3 * 8210,0 27,6 52 4,i 4.2 * 8212.0 50°9 2~7 :27.7 52 4.3 4.2 :* 8214.0 ~4D.~2 223 27.? 52 4.3 4.3 ~ 8216.0 I3,6 ~304 ~27,9 52 4,3 4'3 D ~ D ~ D ~ D ~ D ~ D ~ 144 356 1,11 143 2388°0 5.6 2390.0 2392.0 7.6 2394,0 ?. 2396,,0 11,:5 2398°0 2400.0 2402,0 5-0 2404,0 2406,0 2408.0 2410. 0 g 2412,0 9 24 i 6.0 0 * 9 2418,0 2420.0 2422.0 4.~4 2424.0 5. 2426,0 2428,0 2430,0 5~:6 24'32,0 3,1 2434,0 2436,0 2438.0 6.~0 2444,0 2446.0 4 2448.0 4,3 2450.0 2454,0 2456,0 2458.0 2460.0 ~ ,~0 2464,0 360 273 :300 323 307 294 233 200 165 125 103 102 55 60 I31 ~05 1.43 t32 ~146 -109 .~123 136 * QUALo o-----# INDEX DIA~ , BES,I 2-4 * =A 19.5 30 10,1 1~.1 19.6 30 9.7 10o7 19,6 34 9.5 t0.6 19.7 32 9.5 10.8 .19,7 30 9.9 19.8 32 10.6 -1~.5 i9'.8 33 10.6 1~.6 19.8 33 I0.0 1~,5 19.9 33 9.5 19.9 33 9.4 19,9 32 9.5 19.9 33 9,1 I~.9 20,0 33 8.9 1~.4 20.1 33 9.0 ~lt.i 20.1 33 9.0 ~I0.8 20,i 33 9.0 10,5 20,1 33 8,9 10.3 20,2 33 8,9 10.4 20,2 33 8.9 ~10,4 20,2 33 8,9 ~10.4 20.2 33 8.9 I0.3 20,2 33 8.9 :10~2 20.2 32 8,9 10,3 20.2 32 9,0 10,4 20,2 32 9-1 ~10..5 20'.2 33 9.2 I0.8 20,3 33 9.3 I~.0 20,4 33 9.3 20,5 32 9.6 i0.9 20.5 32 9,6 10.9 20.5 33 9.7 1~.1 · 20,5 33 9.9 ~1~.0 20.6 33 9,5 10.9 20.7 33 9,1 1~,0 20.? 33 9.0 10.7 20,8 33 9.0 10.3 20,8 33 9.0 10.1 20.8 33 9.0 -'10.1 20.9 33 9.0 10,2 21,0 33 9.0 10'3 DEPTH # DIP DIP ~ DEV. DE¥. DIAH # AZI, # AZI, # 2468.0 * 2470.0 6-0 ~ 2472.0 , 2474.0 ~ 2476.0 5,0 # 2478.0 8.:7 # 2480.0 9.~4 ~ 2482.0 ~.3 * 2484.0 8.~4 # 2486.0 b.~7 , 2488.0 5'8 , 24 o.o , 2492.0 , 2494.0 # 2496.0 8.6 # 2498.0 8,9 # 2500.0 * 2502.0 * 2504,0 5,0 , 2506.0 9.0 # 2508.0 * 25i0,0 6.3 * 2512o0 5~8 # 2514.0 , 2516.0 , 2518.0 * 2520.0 * 2522.0 * 2524.0 ~ 2526.0 * 2528.0 , 2530.0 ~.3 # 2532°0 , 2534.0 9.6 * 2536.0 9,4 , 2538.0 5,9 # 2540.0 4,9 # 2542.0 , 2544.0 4.~1 ~ 2546.0 ~.'6 , OUAb. -----------, INDEX DIAH , BEST 193 21.0 33 9.0 ~10.2 i69 .21.,0 32 9.0 10.1 158 21,0 33 9,0 iO.l 99 21.0 32 9.0 I0.0 124 21.0 32 9.0 10.1 77 21.0 33 9.0 I0.2 58 21,1 33 9.1 10.2 45 21.! 32 9.2 10.1 31 21.2 33 9.1 lO.i ~12 21.2 33 9.1 ~t0.3 {Ii 2i.2 33 9.4 10.6 87 21.2 33 9,7 21.2 32 9.8 10.6 21.2 33 9,4 10,1 ~12 21.2 33 9.1 ~10 2~,3 33 9.4 9.9 21.3 33 9,4 9.7 21.3 34 9.1 102 21,3 34 9.0 9.2 171 21.3 34 9.0 172 21.3 32 9.0 9.0 151 21.4 .31 9.1 8.9 202 21.4 31 9-1 146 21.5 31 9.1 93 21.4 31 9.1 IlO 21o5 31 9.0 8.9 21.5 31 9.1 8.9 21.5 31 9.1 21.5 31 9.1 168 21.5 31 9.0 243 21.6 31 9.0 ~.8 248 21.6 31 9.0 8.8 189 21,6 31 9.0 a.8 190 21.6 31 9.0 127 2{,7 31 9.0 I06 2~.7 31 9.0 2'78 2~.8 31 8.9 243 2t.8 31 8.9 8.9 247 21.9 31 8.9 ATLANTIC RICHFIELD CO. IH-.? PAGE 3-FILE ~ FORi4ATION # ,fORE~O~E ~ GUAm, · ------------------,----------------------------------, INDE~ DE~TH , DI"P D}f e DEV, DEV, ~l~f DIAH * BEST ~ AZ!, ~ AZI, I-3 2-4 * =i 2548,0 ,1).3 247 21,9 31 8,9 8..? D 2550,0 bo.2 245 22,0 31 8,8 8,5 F 2552.0 4,9 310 22.0 31 8.7 8.4 F 2554.0 5.;5 72 22.0 31 8.7 8.4 2556.0 e.~6 242 22.t 31 8.6 8.3 O 2558.0 22,1 31 8.7 8.3 2560,0 8,3 84 22,! 3! 8,7 8,3 D 2562.0 22.1 31 8.8 8-3 2564.0 22.1 31 8.9 8.3 2566°0 6~0 229 22,2 3! 8.9 a,3 O 2568,0 22,2 31 9,0 8,3 2570.0 22.2 31 9.0 8.3 2572,0 1~..! 54 22,3 31 9°0 8,3 2574,0 {I0,9 55 22,3 31 9,0 8,2 F 2576,0 5.:5 ~? 22,3 31 8,9 8,2 F 2578.0 ~.;7 137 22.4 31. 8,9 8.2 F 2580.0 3.~4 76 22,4 31 8.6 9,2 B 2582.0 10~4 ~76 22.5 31 8.6 8.2 2584.0 22.5 '31 8.7 8.2 2586,0 4~8 287 22.6 3t 8,7 8,2 2588.0 2~1 322 22.6 31 8,6 8.2 E 2590.0 22.6 '31 8.7 8,2 2592.0 ~10,9 -!64 22.6 '31 8.6 8.2 r 2594,0 9.9 128 22,7 31 8.6 8,2 F 2596.0 ~.'6 71 22.7 3t 8,6 8,2 C 2598°0 8.~2 289 22.7 3~ 8,6 8,2 A 2600,0 ~..3 292 ~22,7 31 8,7 8,~ A 2602.0 ~19.~1 333 22,7 31 8.7 8,1 ~C 2604.0 ~12'8 326 22.7 31 8,7 8. t 2606,0 ~14,9 ~68 22,7 3i 8.7 8.1 E 2608.0 ~t5.~4 162 22.8 3! 8.7 8,1 E 26i0.0 '~i).3 141 22.8 31 8.6 8.0 2612,0 ,i8,~4 169 22.9 31 8,6 8,0 E 26i4.0 ~15.~! ~t61 22.9 31 8.6 8.0 E 26i6,0 ~i3.9 i56 22.9 31 8.6 8.0 2618.0 ~1~:8 165 22.9 31 8.6 8.0 E 2620.0 .19.:5 'lrSO 22.9 31 8.6 8.1 E 2622.0 ~14.;5 126 23.0 3i 8.5 8.0 A 2624.0 ?~8 201 23.0 31 8.5 8.0 E 2626,0 9,~4 136 23.0 31 8,5 8,0 $ A'rbAN'E~C RJ~Cl'lf IE:bD ~CO. ~Ifl-? PA~GE 4-FILE DE~TH # D~P O~ # DEV 2628.0 3.;7 2630.0 2632.0 ~.'4 2634.0 ~,0 2636.0 2638.0 2640.0 ~14.~2 2642.0 ~13~8 2644.0 2646.0 2648°0 2650.0 2652,0 8.~4 2654,0 9.~! 2656.0 7,0 2658,0 ~.~0 2660.0 2662.0 ~t8.9 2:664,0 34~7 2666.0 29'b 2668.0 9.~4 267,0,0 2672.0 9,~2 2674.0 2676,0 2678.0 2680.0 6~8 2682.0 ~10,6 INDEX DIRH # BEST 1-3 2-4 * =A *********************** 142 23.0 31 8.6 8.0 D 23.1 31 8,6 8,0 95 23.1 31 8,5 8.0 F i24 23,2 31 8.5 8.0 F 23.2 31 8.4 8.0 23.2 31 8.4 8,0 119 23.3 31 8.4 8.0 D 85 23.3 31 8.4 8.0 D ~23.3 31 8.4 8,0 23,3 31 8.4 8,0 159 23,4 31 8.4 8.0 E 162 23,4 31 8.4 8.0 'E 82 .23,4 31 8,4 8,0 A 88 23.5 31 8,.4 8,0 A ~92 23,5 31 8,4 8,0 91 23-5 31 8.4 ~.9 E !3't 23,5 31 8,4 ~,g E ~.~ 6 .23,5 31 8,4 :~..9 D 251 ~23'5 31 8,4 ~7,9 249 ,23,6 31 8,4 ~,'9 C 91 23,6 31 8,4 ~,g A 140 23,6 31 8,4 .~.:9 95 23.6 31 8.4 ~,8 '102 ,23.6 31 8,3 7,8 ~I'00 23,6 31 8.3 ~.8 23,5 31 8,3 ~,8 ~33 23.3 3'1 8.3 9.8 F ~18 23.0 3I 8,3 ~,8 D D~P~H # D~P D~E # DEV DE¥ U]A~ D~AM TOP 23?6,0 t5.0 265° 18,8 36° 10.8 I3,4 BOTTOM 8216.0 ~3,6 304° 27,9 52, 4.3 4.3 D TOP 2388.0 ~5,6 '1,44. i9.5 30, 10.1 11.,1 D BOT'~OM # 2682,0 ~(',6 ~I'8, 23,0 3~, 8, S 7.8 D '0.00 0o00 0o00 0o00 0o00 0,00 0o00 ~'IHE;,5 ~N SF. CC~DS CPU 100.8 1:1,6.7 555 DISECT I/0 1164 .BUF~F ERED ,!/0 44 LSF - YES,ION 006.E04 bISTROS 2.00 0.00 0.00 0.'00 0,00 0,00 0,00 0,00 0o00 0,00 0.00 0,00 0.00 0.00 CU~ 432~'00 ~(:.00 'OJCO 0.00 '¢~J(O 0.!00 '£.00 LVP Ol0.Hol VERIFIC~TI[~,~ LISTING PAC, E 1 :~E~VICE NAME" ~SERVIC DATE :82/06/25 · 0 · QRIGIN ,107 ~ON~IN~ATIQN # PR'EVIOU~$ TAp~ ,= _~CM~UMBERGER : ALASKA COMPUTING C~NTER : ~OkPANY ~ ATLANTIC RICHFIELD COkPANY WFLt, = = KUPARUK = NO~TH SLOPE JOB ~'~U~B~P AT ACC: 10'707,6521~4 BOTTU}· DEPT}I = 8176 FT. ~O'P D~],PTfi = 236.6'....:FT.... C'~'S"I',~'~ = 10,7'5 I N. B~:I'~%' '8'.. i>~; 'E = 8':.'7.5':.:?'1N~..,,. · ;. ~ ... . .~ . ~ ~ .. · TYPE ,,. L~I~ = X'C" 'PO'LY~'ER V'ISCOS I TY = 5"0; O'" '~' :,:..,:~i: ':;....:'"".':.'.':~ ':. '. "." .". <. "'~..."': :'..~:~?. :..: :. :;.. '. :: {;,.{~'..~:., ::":.~:.~:~. :' ..~ <'' ':: ". ::':':". ~":. :.:':.'~.. ::". ?..:.~:.'~ ::.::' :"" ~:::.':... 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