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180-075
STATE OF ALASKA ALTA OIL AND GAS CONSERVATION COI SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon [i Plug Perforations U Fracture Stimulate U Pull Tubing FA Operations shutdown u Performed: Suspend 0 Perforate D Other Stimulate Q Alter Casing D change Approved Program Plug for Redrill El erforate New Pool Li Repair Well 12 Re-enter Susp Well Q Other: ESP Change-out 0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑ Exploratory ® 180-075 3.Address: Stratigraphic Service ED 6.API Number: 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 50-029-20490-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047438 MPU B-01 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Unit/Tertiary Undef WTRSP 11.Present Well Condition Summary: Total Depth measured 9,638 feet Plugs measured 3,282 (' " gCEIVED true vertical 9,439 feet Junk measured N/A 7 Effective Depth measured MAR 1 0 201! P 3,282' feet Packer measured 2,565&2,865 feet true vertical 3,277' feet true vertical 2,565&2,865 feetAOGCC N Casing Length Size MD TVD Burst Collapse Conductor 105' 20" 105' 105' 1,530psi 520psi Surface 2,635' 13-3/8" 2,635' 2,635' 5,380psi 2,670psi Production 3,487' 9-5/8" 3,487' 3,473' 8,150psi 7,100psi Perforation depth Measured depth See attached schematic feet True Vertical depth See attached schematic feet 4-1/2" 12.6/L-80/Supermax 2,525' 2,525' 4-1/2" 12.75/L-80/EUE 2,689' 2,689' Tubing(size,grade,measured and true vertical depth) 4-1/2" 9*.5/L-80/EUE 3,282' 3,282' BOT Twin Seal Packer Packers and SSSV(type,measured and true vertical depth) Dowell 16-E Gravel Pkr N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A r' 1x APR 1 Treatment descriptions including volumes used and final pressure: ��� � CJ: 1 2r'{ N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 20 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.07o,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations EI Exploratory® Development Li Service 0 Stratigraphic Copies of Logs and Surveys Run El 16.Well Status after work: Oil 0 Gas ® WDSPL Q Printed and Electronic Fracture Stimulation Data El GSTOR Q WTRSPQ WAG 0 GINJ ❑ SUSP Q SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-559 Contact Stan Porhola Email sporhola(U7hiIcorp.com 534 Printed Name Bo York Title Operations Manager Signature ` & ( . 1�E / I{ Phone 777-8345 Date 3/8/2017 - Vi-- 3-71- it RBDMS Lv MAR 2 2 2017 Form 10-404 Revised 5/2015 /7 Submit Original Only 4. • Milne Point Unit - SCHEMATIC Well: MPU B-01 Last Completed: 1/13/2017 Hileorp Alaska,LLC PTD: 180-075 Orig.KDB-SL.:46/KDB-GL.:24'(PRKR 128) TREE&WELLHEAD RKB-THF:30.40'(Doyon 14 FMC 4-1/16"3,0004 w/4"LPT Treetop Connection ukiit Tree 4-1/2"Tubing Hanger Threads TC-II Top and Btm 20 4 OPEN HOLE/CEMENT DETAIL i ' 20" Cement to surface:26"Hole 13-3/8" 4,000 sx Arctic Set II:17-1/2"Hole u9-5/8" 997 sx Self Stress:12-1/2"Hole ,t7.4?" ,..tt 13-3/8 7" 230 sx Self Stress:8-1/2"Hole ...i,k1 kki CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 41 i'$ 20" Conductor 94/H-40/N/A N/A Surface 105' 0.3553 Min ID=3.810i 1 13-3/8" Surface 72/N-80/BTC 12.347" Surface 2,635' 0.1481 9-5/8" Production 47/S00-95/BTC 8.681" Surface 3,487' 0.0732 2 TUBING DETAIL p • 41 \; s' 4-1/2" Tubing 12.6/L-80/Supermax 3.833" Surface 2,525' 0.0152 3 4-1/2" Tubing 12.75/L-80 EUE 3.833" 2,555' 2,689' 0.0152 4-1/2" Blank Pipe 9.5/L-80/EUE 4.090" 2,865' 3,282' 0.0162 I 0 II .. 4 L ' 5 JEWELRY DETAIL ` „ to d 7, No Depth Item i 1 2,386' 4-1/2"XN-Nipple,Min ID=3.810" 6 It 2 2,434' Discharge Head 4A 1 3 2,435' Tandem Pumps,513 series 68 stage SG7300 (r r € "i 7 : 4 2,479' Gas Separator it 6 5 2,480' Tandem Seal -$.7. 9 6 2,498' Motor,562 series KMS 360 HP 7 2,521' Sensor,SLB XT-150 Type 0 �, w1 t 10 8 2,523' Centralizer:Bottom @ 2,525' 9 2,555' 4-1/2"Cut Tubing(Radial Torch) 11 10 2,565' BOT Twin Seal ESP Packer(Unable to Pull) P`: 11 2,580' 4-1/2"Camco GLM Punch Holes: . , i 2,611'-2,621' ' " 12 12 2,611' 4-1/2"Camco DB-5 profile(3.687"ID) 4spf0.34"EH . � , 13 2,689' Tubing Tail,8.0"OD Centralizer 14 2,865' Dowell Model 16-E Gravel Pack Packer(4.75"ID) 15 3,092' 4-1/2"9.5412 Gage Wire Wrapped Screen(4.09"ID) 16 3,271' '0'Ring Seal Sub w/6'Tell-Tale .r 17 3,282' EZSV Retainer ,,- svk'* 18 3,300' EZSV Retainer PERFORATION DETAIL *, Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status r Tertiary 2,903' 2,936' 2,903' 2936 33 N/A Open 7, tjWaterrtiaSands 3,102' 3,157' 3,101' 3155 55 N/A Open i 3,196' 3,266' 3,193' 3261 70 N/A Open '. Ref Log: DIL Log 1/20/1981-4"Hollow Carrier 12 SPF 90'Phasing 13 '¢ _ GENERAL WELL INFO ` 14 Completed By Parker 128 1/28/1986 if `* '.15 ESP Repair by Doyon 14 1/13/2017 E-Linetag@ ;:+ , § "= 3,279' ,>a tr -* ' 10/18/85 l'164;;'0:i;"?..';1. , +`s,* ,, ,�� 5 16 Via.. �l TOC@ p,�n-. 17 3,289' *18 9-5/8" TD=3,487(MD)/TD=3,473'(TVD) PBTD=3,282'(MD)/PBTD=3,106'(TVD) Revised By STP 3/01/2017 • • Hilcorp Alaska, LLC IliteorpAlaska,LLC MP B-01 Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPB-01 Doyon 14 50-029-20490-00-00 180-075 12/7/2016 1/13/2017 Wednesday �� ���i ���'� �w � VIII 0/6/22=MIT TxIA PASSED to 1500 psi(Tbg=Heater String)Rig up to heater string and pump x1.6 bbls diesel to test.T/IA lost 34/31 psi 1st 15 min&13/11 psi 2nd 15 min. Bled back to 0 psi(^'1.5 bbls) 1/6/17 iFrida ( ;III ��°" �i z 4i�iy�N ��_ --s IiF�� .r44 i(i (�H (Ii . r r �1�i ( Rig Crew and Company Man Arrived at Milne Point at 1130 hrs.Prep Rig to Move F/S-Pad to B-01,General Maintenance. 1/7/17-Saturdaya , (;IP,I'„ oli;y „;' ' ,,'q;' Skid Rig floor,Prep for Rig move,clear snow on B pad for Rig move.(AOGCC was notified of right to witness BOP test on 1-6-2017 @ 14:54 PM)Right to witness was waived @ 15:47 PM by Chuck Scheve).Move Rig from MPS-Pad to MPB-Pad.ASRC Crane Hoisted and Removed B-01 Well House,Doyon Forklift Removed Matting Boards and Replace around well head,Set New Production Tree and Tubing Spool Back side of Rig, Drive and Turned Rig around at the end of Location.Spot Carrier over well,Skid Derrick over Well.Continued Rigging up, (Accept Rig at 0400 hrs. Safety Sundry Meeting with Rig Crew on the B-01 with Rig Crew.Greased Choke Manifold Valves,Bleed off I-A psi=0,Well Head Inserted Rep Tee Bar Check Pressure Below BPV High Pressure was Observed Unable to Remove BPV with Tee Bar. @ fit/17;4.1 1 IP' �r.' ii Il,, Mip iuµ ii� ) '(� _ ts u��� ��� � �`.. (���i >ii �l ' (��4ll r1�'., �{ � _ Attempt to pull BPV with Tee bar,BPV had gas under it which prevented from utilizing the Tee bar,Rigged up Lubricator and bleed trailer,pulled BPV with lubricator and bleed off small amount of gas and crude oil to bleed trailer.Install 1502 flange on 4”tree,Rig up and bullhead 65 bbls down 4.5"tubing @ 5 bpm @ 1140 psi.Tubing went on vac.Rig up to circulate down 1.5"heater string taking returns up annulus to flow back tank,Circulate @ 3 bpm @ 2930 psi to clean 9 5/8"x 4.5"up.Blow lines down,rig down circulating lines.ND circulating head from tree,install TWC in tubing hanger.Nipple down production tree,verify threads in heater string&Tubing threads.Install TWC valve in heater string.Nipple up BOPs.Rig up Test Equipment Borrowed 2 each 3-1/2 IF X 1502 xo Subs for Test Joints F/I-RIG. Test Bop's as per well Program Test Joints used 4.5& 4'Test all choke Vales and Rams to 3,000/ 250 psi 5 min Each,Tested Annular 3000/250 psi 5 min Each,Test Pre charge Bottles. and Time on Accumulator (Tested Gas and Fire Alarms)Tested Good( Right to witness was waived On 1-7-17 @ 15:47 PM by Chuck Scheve)Rig Down Test Equipment Same. , \46da�' "aitlir4r`w. °9i6 47�dN1'V ili' , .zP i.' `� �. _ ii Iei� i1111111 Attempt to pull TWC from Heater string,debris was in TWC,pulled TWC in 4.5"string,washed out debris from heater string,pulled TWC from heater string,installed BPV in 4.5"string.Make up 2 3/8"landing joint,screw into heater string,pull heater string to rig floor with 5K,lay down landing joint. TOOH,lay down 1900'of 1.5"NU tubing string 44 joints.&14 joints of 1"CS Hydril string Lay down handling tools.Pull BPV with Tee bar from 4.5"tubing. Rig up GBR casing equipment,hang ESP sheave with elephant trunk hose.Make up landing joint to tubing hanger,back out Lock down screws.Attempt to pull tubing,hanger&_release ESP^packer,pulled 40 K over PU wt.increase pull to 77 K over PU wt to max on tubing elevators, continue to work string at 190k,150 K without top drive wt.(Doyon 14 went on High Line Power at 1630 hrs.),Continued Working tubing and Hanger& Attempt to release ESP packer,Pulling 40 K over PU wt.increase F/77k at 10k Increments to a Max Pull to 150K W/Top Drive Weight of 40k,PU wt to max on tubing elevators of 190k, continue to work string at 190k.Change out Elevator F/75k to 125k,Max Tensile Strength 4-1/2 L-80 280K Work Tubing F/190K to 260k at 10k increments with Added 40k Top Drive weight at 80%Pull on Tubing Max Pulled 265k.Engineer Ted Kramer was Called Decision was make to Cut Tubing 10 Ft above PKR Joe Dalebout Null Pollard E-Line was Called and Up Dated.Clean and Maintain Rig While Waiting on Wire Line Truck. • • Hilcorp Alaska, LLC LLC MP B-01 Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPB-01 Doyon 14 50-029-20490-00-00 180-075 12/7/2016 1/13/2017 1J10/17 Tuesday �I rI af. Maintain Rig while waiting on pollard Wire line service and Halliburton,Wire Line Truck and Halliburton Arrived on Location at 20:00 Hrs,Held JSA with Rig Crew and Null Pollard E-Line Crew/Halliburton Crew,Rig Crew,Rig up E-Line and Lubricator on Dutch System Halliburton Tools Arrived on Location at 2200 hrs.Perf Guns and Tubing Cutter Equipment,Make up Run No 1'RIH Stacked out at 2,631 ft.Pick up Attempt to work through Tight Spot Slowly Unable to Get Past 2,631 ft.Correlate Tools on Depth Shot Holes in Tubing at F/2,621-2,611 4spf POOH Lay down Guns all Shots Fired on Gun, Gas Migrated up Hole Closed Blind Rams Bull head 20 bbl 8.8 Brine Down Tubing Well went on a Vacuum,Make up Run No 2' RIH Hole Correlate Tools on Depth Shoot Holes in Tubing F/2,608-2,598 4spf POOH Gas Migrated up hole Closed Blind Rams Bull Headed 20 bbl.Down Tubing Well went on a Vacuum. -'We[ ' �„y a M��116;i��, �IIVP 1/11;17 Rig up&RIH with Radial Torch cutterLlinto place with CCL,cut tubing at 2,555'POOH with wireline. lay down tools,remove dutch riser and lubricator. Wait on pump in sub from Pollard wireline service.Maintain rig.Monitor wellbore.Pick up landing joint and make up to tubing hanger,pick up 1'at approximately 53K overpull,make up Radial Torch cutter,RIH,log into place with CCL,make cut at 2,555'POOH with tool string.(Notified AOGCC of right to witness the test of breaks and equipment used during bullheading 1-10-17 @ 15:34 hrs.),Rig Down Pollard E-Line Equipment to the side,Pulled on Tubing String 72k Pulled Free ESP Cable is Cut,Pulled Tubing Hanger to the rig Floor,Break and Lay Down,Finish Rigging down E-Line off Rig Floor,Rig up GBR Power Tongs and Power Unit„Held JSA with Rig Crew,Centrilift Rep,GBR Hands,Trip out of the Hole Laying Down 4-1/2 Tubing and ESP Cable, Recovered 80 JTS+7FT.(Total of 164 Stainless steel Bands Recovered)(1 Band missing)(4-1/2 Tubing in Good Condition),Rig down GBR Tools and Equipment,Changed over Handing Equipment to Run 4-3/4 Drill Collars,Make up Mule shoe and XO Sub, 9-4-3/4 Drill Collars,20- 4'HWDP, 10-4' DP, 9-5/8”Storm Packer,3-4'DP RIH Set Storm Packer C/O/E @ 110 ft.Test Storm Packer to 3,000 psi(Good Testi. 1/12/14 <7hut dayl i aii 01,4 'i) IEIii il�hl;!11i1 = . ., i1li(i i) . i � i � d1 n ii ( �” d (II iii �: ii i � L I 6a UV10i ...I �: i �I� I � JP ,...... �:..- ��ii I .i lh��u��1L.�___. ,wI ND BOP,Install new tubing spool,change out IA valve,NU BOP torque connections.Test BOP breaks,to 250/3000 psi,perform Accumulator test.(Matt Herrera with AOGCC visited the rig and reviewed test charts),RIH with 1 stand from derrick,screw into Halliburton Storm packer,check for pressure, release storm packer,lay down storm packer,continue to TOOH,laying down drill pipe and heavy wt.drill pipe&4 3/4"DCs,Pick up tools for ESP,string cable over sheave,set control line spool on rig floor.Make up&service ESP Pump Assembly.Trip in the hole with 4-1/2 Super Max 12.6/L-80 Tubing and ESP Pump Assembly to(1,106 ft. 30 Joints)Summit Rep Said Temperature Readings went F/49 to 396 Degrees,at 1,106 ft.Engineer Ted Kramer was Called Decision was Made to Trip out of the hole Stand Back Tubing in Derrick, Change out Temperature Sensor on Pump.Trip in the hole with ESP Completion Assembly to 1,106ft Check ESP Pump Readings Same Results 49 Degrees at Surface,396 Degrees at 1,106 ft.Changed out Meters with Same Results. Pi1iI) 1 9 airi �i,� I' ��I t � o I�i��� �I I � �� . �,Ii Continue to TIH with ESP assembly on 4.5"Super Max 12.6#tubing.ran a total of 72 joints.Make up landing joint&Tubing hanger.Make up field connector for penetrator„Land tubing hanger,run in lock down screws, bk out and lay down landing joints,Install TWC with Tee bar.Change upper pipe rams to 2 3/8",Nipple down BOPs,NU Adapter flange&tree,test hanger void to 500/5000 psi.Fill tree with diesel,test tree to 250/5000 psi,Pull TWC, install BPV,Rig up Little Red Services,bullhead 118 bbls.of diesel down 9 5/8"x 4 1/2”bullhead 33bbls.of diesel down 4 1/2"Tubing. Rig down Little Red Services, Secure Well,Clean and Rinse Pits(Rig Release at 2100 Hrs.),Prep Rig Move Derrick over Center of Carrier. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1-2-4761 11 i1 I,7 DATE: 1/12/2017 P. I. Supervisor FROM: Matt Herrera SUBJECT: Doyon 14 BOPE Test Petroleum Inspector MPU B-01 PTD 1800750 Sundry 316-559 - On 1/12/17 I travelled to Milne Point and met with Doyon 14 Operator representative Don Haberthur about the well control incident on MPU B-01, a source water well. There were perforations made below the existing packer that released a small amount of gas that migrated up hole. Well control components involved per Mr. Haberthur were: Blinds, IA Valve, HCR Kill valve, Manual Kill valve, 4" Kill valve in pits and HCR Choke. The decision was made to bullhead 8.8ppg brine to kill the well — successful. The above components mentioned were then tested to 3000 psi and charted. An accumulator drawdown test was also performed. I had just arrived as they were performing the drawdown but did not witness the valve and Blind Rams retesting. Everything appeared to be in working order and under control so they were allowed to continue with well plan. The pressure test chart for the rams and valves is attached; the results of the accumulator test were as follows: ACCUMULATOR SYSTEM: Test Time/Pressure Result System Pressure (psi) 3,000 P Pressure After Closure (psi) 1,700 P 200 psi Attained (sec) 36 sec P Full Pressure Attained (sec) 182 sec P Blind Switch Covers: All stations Yes Nitgn. Bottles# & psi (Avg.): 6 x 2,108 psi P ACC Misc 0 NA Attachments: Test Charts (2 pgs) Non-Confidential SCANNED MY ` 0 'di?, 20 17-0 1 12_B OP_Doyon 14_test-after-use_MPU_B-01_mh.docx Page 1 of 1 60 n v 0------%-:- ___. - w....... ,,,....„ ..„_________ „so__ : ____, _„,. ____.,_,_. _„:,..„.,, ---,-- ->:„- ... ..,......., 500 ,,-----;-- -,==iftr----- .4•, ..,N, \.\‘ /p„,4w0,010% -_--..- -,----_,-----,.-- ___--9-9-.= r---,00 . .Ai'-;J-1,---,.-fr ---_,-=_ww,ftwo-4...-"t-- - -N-. ..,,,S,N:\. ,-, ..1,..1r . ./.,,,-- -2 .W,, -mrs ---4-. --,, -\ .:.\\, ,,,,NN „...„ N. ,' op __ --o-. o.:----w-•...4.„„.. k, . :\:,:\,\\\\ \\ \d‘4,\, / 14* 1,4:: v ''';#, -_-:::arar:::77_-!".....W.;, _^.**S.\;ii.' •*,AN\NEA\ %\\\\\\‘‘t \‘‘, Iffr' 1 r /I, i 1:37,..*W' '' 0 '•-t411.-.1K,36 ‘It'0 ,,'NIt II% it \ 1 1 um '4444' pi te,• it.-• -70/ Graphic CPntrols 10/Vii // ifte, •' i /'Pt i 461 CHART NO. 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B-O Pm 23C C75c, Regg, James B (DOA) From: Schwartz, Guy L(DOA) \C' 1 I Sent: Wednesday,January 11, 2017 2:44 PM To: Ted Kramer; Regg, James B (DOA) Cc: Bo York Subject: RE: Closing of the BOP Blinds on Doyon#14 and Pumping down the Kill Line - Response Pursuant to Guidance Document 10-003. Ted, Thanks for the additional information. Your proposed plan to retest the blind rams after pulling the ESP and setting a storm packer is approved. Good luck with the rest of the operation. Guy Schwartz Sr. Petroleum Engineer AOGCC SCANNED MAY . i.2U i'+ 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From:Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Wednesday,January 11, 2017 2:11 PM To:Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov>; Regg,James B (DOA) <jim.regg@alaska.gov> Cc: Bo York<byork@hilcorp.com> Subject: Closing of the BOP Blinds on Doyon #14 and Pumping down the Kill Line- Response Pursuant to Guidance Document 10-003. Guy and Jim, Here is the additional information on the closing of the blinds on the BOP Stack early this morning following Guidance Bulletin No. 10-003: Date and time: 1/11/2017,Times are below in the Operations Summary: Well/ Location/ PTD Number : Milne Point-Well B-1 WSW, PTD 180-075 Operations Summary: Between 0130 and 0400 hrs this morning Hilcorp was punching holes in two joints of 4-1/2"tubing. There were two runs. The first punched holes underneath a twinseal ESP Packer from 2,621 to 2,611' (4 JSPF). The guns were removed from the well preparing to make a second run when it was noticed that a puff gas and some oil had migrated to surface. There was no increase in pressure associated with the appearance of the oil and gas bubbles, and no well control event took place, it was merely observed. There was not a pump in sub on the well so the decision was made to close the blinds and pump down the kill line with 20 bbls.of 8.8 ppg kill weight fluid. The well went on a vacuum at that point and the operation of punching the second Joint continued. 1 i ! Between 0400—0600 hrs,the second joint was punched from 2,598—2,608'. This time the rig crew was watching for signs of gas and oil migrating to surface. At the first sign of gas bubbles the blinds were again closed and 20 bbls of kill weight fluid was pumped down the well via kill line. No pressure increase was observed and the well went on a vacuum after pumping the fluid. Reason for BOPE Use: Hilcorp sees this use of the blinds not as a well control event but more as away to put the kill weight fluid down the tubing via the kill line to return the well to a vacuum. However, since hydrocarbon was present and the BOPE equipment was exercised, Hilcorp wanted to report it. Actions Taken/To be Taken: Since the blinds on the BOPE were exercised, Hilcorp will re-test the blinds as soon as possible. This will occur as soon as the tubing and ESP cable is pulled from the Water Supply Well. At that point a storm packer will be placed in the well and tested. The BOPE will be removed, the tubing hanger will be changed to a single hanger. The BOPE will then be re- installed, and the break and the blinds re-tested. The new ESP will then be ran in the well. Please let me know if you need any further information. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 2 THE ti OF TFJ g ,—,1,/�,s THE STATE Alaska Oil and Gas ofLASI�°A Conservation Commission A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS1‘ts. Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC ?r47 3 800 Centerpoint Drive, Suite 1400 SCO KO ` Anchorage, AK 99503 Re: Milne Point Field, Tertiary Undefined WTRSP Pool, MPU TER B-01 Permit to Drill Number: 180-075 Sundry Number: 316-559 Dear Mr. York: 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. "ncerely, Daniel T. Seamount, Jr. -11 Commissioner DATED this� day of November, 2016. RBDMS \" NOV 1 6 2016 • RECEIVED • STATE OF ALASKA OCT 3 12016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory ❑ Development ❑ 180-075 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service 0� 6.API Number: Anchorage Alaska 99503 50-029-20490-00-00 • 7. If perforating: 8,Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20AAC25.055• Will planned perforations require a spacing exception? Yes ❑ No El / MILNE PT UNIT TER B-01 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047438 - MILNE POINT/TERTIARY UNDEF WTRSP , 11. PRESENT WELL CONDITION SUMMARY Total�Deptthh MD(ft): Total D th TVvD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): T 63,x: "41 3,282' 3,277' 934 3,282' N/A Casing Length Size MD TVD Burst Collapse Conductor 102' 20" 102' 102' 1,530psi 520psi Surface 2,635' 13-3/8" 2,635' 2,635' 5,380psi 2,670psi Production 3,487' 9-5/8" 3,487' 3,473' 8,150psi 7,100psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 1-1/2" 2.9#CS Hydril 1,990 See Attached Schematic/ See Attached Schematic 4-1/2" 12.75#/L-80/EUE 8rd 2,689 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ' Bot Twin Seal Submersible&Dowell 16-E Gravel Packer and N/A 2,565(MD)/2,565(TVD)&2,865(MD)/2,865(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service 0, 14.Estimated Date for 15.Well Status after proposed work: 1:::-;"-"L Commencing Operations: 11/28/2016 OIL 0 WINJ ❑ WTRSP ❑✓ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ 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 Ted Kramer Email tkramer©hilcorp.cqm Printed Name Bo York Title Operations Manager Signature 0 1-1//1.., Phone 777-8345 Date 10/31/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness t �� Sundry Number. Plug Integrity ❑ BOP Test If Mechanical Integrity Test ❑ Location Clearance ❑ Other: k_ 3 op 0 r 3:- )P . I7 5 a4.2-5t- j- DD p5 v /) Post Initial Injection MIT Req'd? Yes ❑ No ❑ /�, h, 6 rt Spacing Exception Required? Yes ❑ No LXI Subsequent Form Required: 1 V 91:),L4RB�MS LL, 1 u i 1 2016 t u "(a '/ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: LT i f// 6 ..ekl. 41/ (. ,i0(4_ f &et/4 Submit Form and Form 10-403 Revised 11/2015 0VdteGprINA olid for 12 months from the date of approval. Attachments in Duplicate • Well Prognosis Well: MPU B-1 WSW Hilcora Alaska LU Date:10/25/2016 Well Name: MPU B-1 WSW API Number: 50-029-20490-00 Current Status: SI Water Supply Well Pad: B-Pad Estimated Start Date: November 28th, 2016 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 180-075 First Call Engineer: Ted Kramer (907) 777-8420(0) 985-867-0665(M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 1,196 psi @ 2,611' ND (BHP 10/30/2016/8.6 ppg EMW) Maximum Expected BHP: 1,378 psi @ 3,084' TVD (No new perfs being added) MPSP: 934 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU B-1 WSW was drilled and completed in May of 1981.The B-1 well was plugged back to the tertiary water sands in 1982 and was left SI / Suspended until January of 1986 when it was brought on line as a water source well. The last ESP Change was in 2002. In 2004 the well was placed on the long term shut in list. Objective: aReplace the failed ESP and return the well to water supply status. / (� 5 Note: CO 390A is not applicable for water supply wells. e 1 1i ` ',4 Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well.Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services and 500 bbl returns tank with choke manifold. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services. 8. Set BPV. RU crane. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house.Spot mud boat. WO Rig Procedure: 10. MIRU Hilcorp ASR#1 W ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg seawater prior to pulling BPV. Set TWC. 12. Test BOPE to250 psi Low/3,0�00 �si-High,annular to 250 psi Low/2,500 si_High (hold_each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests.. • H . • Well Prognosis Well: MPU B-1 WSW Hilcorp Alaska,Lb Date: 10/25/2016 a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Concjitions of approval. d. Test VBR rams orJ,Z test joint. <- la, ' ,.'- e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor V% the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking , ti anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Set BPV in the 4-1/2" string side. Kill well and insure well is dead. Insert TMC. 15. Rig up on the side string. Have emergency safety joint made up and on the rig floor. ' Note: Hilcorp requests a waiver of 20AAC25.285(c)(2)(A)(i)for the pulling of the side string of 1- t 177-10 rd. (1,578 ft) X 1"CS Hydril (386 ft). Hilcorp plans to have an emergency safety joint made 0�\ up on the rig floor which will consist of 4-1/2" pup joint with a floor valve screwed into the top and \11y the bottom end crossed over to the small diameter tubing being pulled. In the event any pressure y„ t. is observed,the safety joint will be screwed into the small diameter tubing and the bop rams closed ('j4 on the 4-1/2"tubing. x it/c,i- (' hQ,wi.- - 16. Insure there is not pressure on the well. POOH with the side string. Blank off side string side of the well head. ji17. Rig up on the 4-1/2" tubing side. RU spoolers for electrical cable. ,t 18. Check for any pressure on the well kill as necessary. ,,,,ii v 19. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg fel seawater as needed. 20. MU 4-1/2" landing joint and BOLDS. 21. Pull over string weight on tubing hanger to confirm free. LD tubing hanger. The well also has a Baker Twin Seal ESP packer at 2,565'. This packer is a straight pull release. Pull 40,000 pounds over string weight to release packer. a. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 22. POOH with ESP completion. Lay 4-1/2"tubing on the pipe rack-. Tubing willnot_be_re-used. Prep for inspection. Lay down ESP equipment. . H S Well Prognosis Well: MPU B-1 WSW Hilcorp Alaska.LI'' Date: 10/25/2016 23. PU casing scraper on work string and RIH to 2,676' (top of gravel pack packer). POOH with scraper. 24. PU RIH with Test packer to 2,800'and set same. Pressure up on the back side to 1,500 psi.for 30 "15i-1 mins. (Chart same). POOH W/test packer. 25. If well is losing fluid indicating thqt screens are open,go to step#27. Otherwise go to step#26. 4t a7 26. PU 430' of 2-7/8 'tubing on bottom of the workstring and RIH to 2,865'. Work into top of screens and nose down to tag for fill and verify that the screens are open. POOH with same. 2 . PU new ESP completion and RIH on 4-1/2 "tubing setting the bottom of the ESP centralizer at 2,680' (+/-) MD. Note PU (Pick Up) and SO (Slack Off)weights on tally. Netj 28. Land tubing hanger. RILDS. •1''3,/ 29. Set BPV. ND BOP, NU Wellhead and test. gip,Lr1n • 30. RD Hilcorp ASR#1 WO Rig. 0 Post-Rig Procedure: 1. RD mud boat. RD BOPE house. 2. RU crane. ND BOPE. 3. Pull BPV. RD crane. 4. Move 500 bbl returns tank and rig mats. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Proposed Tree/Wellhead 6. FWD Circ to Kill Tank Flow Diagram 7. REV Circ to Kill Tank Flow Diagram 8. Bleed to Pits Flow Diagram 9. Blank RWO Changes Form • 0II ._ WELL No. B-1 COMPLETION SKETCH MILNE POINT UNIT (WSW) Menu,Alit km..61.t: API No.: 50-029-20490 PERMIT No.: ?? COMPLETED: 11/7/85 LAST WORKOVER: 2/11/86 r-- FMC DUAL—STRING TUBING HANGER W/4" 'H' BPV PROFILE NOTES: 4 1/2", 12.75# EUE 8rd L-80 TUBING 1. ALL MEASUREMENTS ARE FROM KDB OF PARKER RIG 128 (3.958 ID, 3.833" DRIFT) KDB—SL = 46' NO. 2 REDA RED ESP POWER CABLE (1.30" OD) KDB—GL = 24' 2. MAX. ANGLE = 0.5' 1 1/2", 2.9# CS HYDRIL TUBING SIDESTRING 3. K.O.P. = NA 4. VERTICAL HOLE r. 1 1/2"xl" CROSSOVER 5. TREE TYPE: FMC 4 1/16" 3000# 1", 2.25# CS HYDRIL TUBING SIDESTRING W/ 4" LPT TREETOP CONNECTION 1990' TUBING TAIL 6. COMPLETION FLUID: 8.6 PPG KCI BRINE 7. GRAVEL PACKED 7/27/82 GRAVEL PACK LOG RUN ON 10-26-85 INDICATED GOOD PACK W/GRAVEL TOP AT 2924' 8. 7" LINER WAS JUNKED IN PLACE BY k. 2565' BOT TWIN SEAL SUBMERSIBLE PUMP J.D. POLYA ON 9/19/91. IF WELL IS i, PACKER EVER RECOMPLETED IN 7" IT WILL NEED 2580' CAMCO 4 1/2" GAS LIFT MANDREL TO BE RE—CLAIMED FROM JUNK. GRAVEL PACKED W/158 FT3 20-40 MESH GRAVEL. , 2611' CAMCO DB-5 NIPPLE (3.687" ID) ESP CENTRILIFT HPGS PUMP 195 HP KMXP1 MOTOR IL2689' TUBING TAIL (8" OD CENTRALIZER IMMEDIATELY ABOVE TAIL) 2865' DOWELL "16—E" GRAVEL PACK PKR 4 1/2", 9.5# BLANK PIPE AM 3092' TOP OF GRAVEL PACK SCREEN PERFORATIONS: 4 1/2", 9.5# 12 GAGE WIRE—WRAPPED SCREEN TERTIARY WATER SANDS 6' TELL—TALE 3271' '0' RING SEAL SUB W/6' 4" HOLLOW CARRIER 12 SPF, ` SCREEN 90' PHASING • a 3279' E—LINE TAG 10/18/85 2903'-2936' 3102'-3157' 3282' EZSV RETAINER 3196'-3266' 3289' TOP OF CEMENT (ALL DEPTHS FROM OIL LOG OF 1-20-81) . 3300' EZSV RETAINER 7188'-7214' (MIDDLE KUP INTERVAL) 927O'-9300' (SAG RIVER) 3348' TOP OF 7" LINE 3487' 9 5/8" 47# 500-95 BTRS (8.681" ID, 8.525 DRIFT) APPROVED BY: HDS DATE: 7/30/92 DRAFTED BY: SJN CAD FILE: WCOB1 . 11 • . Milne Point Unit . PROPOSED Well: MPU B-01 Last Completed: 1/28/1996 Hilcorp Alaska,LLC PTD: 180-075 Orig.KDB-SL.: -GL.:24'(PRKR 128) TREE&WELLHEAD s Tree FMC 4-1/16"3,000#w/4"LPT Treetop Connection 20 ) a " OPEN HOLE/CEMENT DETAIL `' * 20" Cement to surface:26"Hole -w. ' 'ac, «; ,4 i 13-3/8" 4,000 sx Arctic Set lb 17-1/2"Hole ' f« 9-5/8" 997 sx Self Stress:12-1/2"Hole ,.,�..ti,. �•A,t 7" 230 sx Self Stress:8-1/2"Hole CASING DETAIL " Size Type Wt/Grade/Conn Drift ID Top Btm BPF i 20" Conductor 94/H-40/N/A N/A Surface 105' 0.3553 13-3/8" Surface 72/N-80/Btrs 12.347 Surface 2,635' 0.1481 9-5/8" Production 47/S00-95/Btrs 8.681 Surface 3,487' 0.0732 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/EUE 8rd 3.958 Surface ±2,600 0.0152 3/8" Capstring Stainless Steel N/A Surface ±2,600 N/A 4-1/2" Blank Pipe 9.5/N/A/N/A 4.090 2,865' 3,282' 3,282' JEWELRY DETAIL No Depth Item 1 2,600' 4-1/2"XN-Nipple 13-3/8 , 'd IR' 2 ±2,640' Discharge Head 3 w 3 ±2,646' Pump 4 ±2,666' Gas Separator 5 ±2,676' Tandem Seal 3,8"Capstnng 6 ±2,686' Motor 7 ±2,698' Sensor t. 8 ±2,700' Centralizer:Bottom @ 2,701'4,kk.ivik 9 2,865' Dowell 16-E Gravel Pack Packer - 10 3,092' 4-1/2"9.58 12 Gage Wire Wrapped Screen i"tf ' 11 3,271' '0'Ring Seal Sub w/6'Tell-Tale • +: 12 3,282' EZSV Retainer i 1 , , tit13 3,300' EZSV Retainer ""° PERFORATION DETAIL � 2 ff Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status• M ' 2,903' 2,936' 2,903' 2936 33 N/A Open fes. Tertiary (LII: 4 Water Sands 3,102' 3,157' 3,101' 3155 55 N/A Open `f 3,196' 3,266' 3,193' 3261 70 N/A Open 5 '01 Ref Log: OIL Log 1/20/1981-4"Hollow Carrier 12 SPF 90'Phasing _ � GENERAL WELL INFO It 6 Completed By Parker 128 1/28/1986 ' 7 '. 33i1 "'. 8 i tj 6 r? « z, t.° ,10 E-Linetag @ ' '' 3,279' 104,, a h I.x g4t4 ,,,,,,11 -roc @ L = .:..,.. 12 3,289' ) y 13 9-5/8"L. 1. TD=3,487(MD)/TD=3,473'(TVD) PBTD=3,282'(MD)/PBTD=3,106'(TVD) Revised By TDF 10/25/2016 i • Milne Point 2016 ASR Rig 1 Knight Oil Tools BOP Ill,nip U.1.k,.1.1.1: / \ Stripping Head MK 11F"-- milNit r CIIShaffer ' hi, 11" - 5000 flit a l al I I!0 III Ili TOULII TO LLiC 2 7/8" —5" VBR I _ �� , 0......„. -U I H 11" 4- 00011 _- Blind : ®l 2" Kill Line 2" Choke Line I lib , ... _ i _ 1 _l lf� 1 1717 iv,41. 1 ky, , =, 4 III* 1 l Ti lli 1- 113 �-— Manual Manual Manual HCR v 1 i Updated 2/29/16 . • • Current configuration B-01 dual string hanger and wellhead MI 10-27-16 Wei III 4 1/16" 5K a , p Cameron FL Actuated valve (II] 4 1/16" 5K Cameron FL second master valve I. NI 4 1/16" 3K x 4 1/16" 5K DSA r=— n 4 1/16" 3K FMC ` • Master valve o 1 IlL' f FMC Dual String Hgr„ long side-4 FMC Dual String Hgr„short 1/2 EUE top and bottom with 4''A" side-2 3/8 EUE top and EUE pup bottom with 1' 10rn 66r - x. crossover,and ESP fY penetrator lii_ �7___ -- L1( 1 ,EL`"---- il n.. �3� moi" r/n4L.., 33��000, FMC Old style Dual I' I II ' I Tbg spool i1 U 111 ;, Horizontal outlet for short PI side. 2" 3K FMC 70 Master valvef ! Wilk- l [kip WV a • 0 • Proposed configuration for MPB-01 10-27-16 71 4 1/16" 5K FC .-._ Swab valve Ca,0 Ai II vC;C�� .1 gra 41/16 5K FC =,: I Wing valve o ,f, .. .. 4 1/16" 5K FC second _- actuated master valve .9A p 4 1/16" 5K FC . '© ' Master valve La ..i Ltrr1,, 1 1111 Seaboard 4%"Tbg Hgr„4 —• — 10 1 IMPIP e-mail %"TCII top and bottom Seaboard Tbs spool -" and ESP penetrator ( - 11 3K x 11 5K. 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Q tO C 0 NN O s g0 co ` C.J ii• r C) O 0 i a= V CD ] N 0 •--• ,z V o N N ¢ o 3 Q n- d • • z • Schw art , GuyL (D OA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, November 09, 2016 9:53 AM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: B-1 WSW ESP RWO (PTD 180-075) Sundry 316-559 Guy, That is correct. I spoke with our wellhead person and was told we can put a TWC in both sides and pull the short string without pulling the hanger for the long string. Step 12 (d) should say 4-1/2" not 2-7/8". You are also correct that we will need to set a storm packer to change out the tubing spool. Step 24 on will change to what is below. 23. PU casing scraper on work string and RIH to 2,676' (top of gravel pack packer). POOH with scraper. �✓ ,p` 24. PU RIH with Test packer to 2,800' and set same. vressure up or aac::Slue to 1,500 psi. for 30 mins. (Chart same). POOH W/test packer. 25. PU Storm packer. RIH to 500' and set. Pressure test to 500 psi. sting off and POOH. 1;1— L 26. Change out tubing spool. -1-91 27. PU WS. RIH and release storm packer. POOH W/Same. ea � 28. If well is losing fluid indicating that screens are open, go to step#30. Otherwise go to step#29. 29. PU 430' of 2-7/8 'tubing on bottom of the workstring and RIH to 2,865'. Work into top of screens and nose down to tag for fill and verify that the screens are open. POOH with same. 30. PU new ESP completion and RIH on 4-1/2 "tubing setting the bottom of the ESP centralizer at 2,680' (+/-) MD. Note PU (Pick Up) and SO (Slack Off)weights on tally. 31. Land tubing hanger. RILDS. 32. Set BPV. ND BOP, NU Wellhead and test. 33. RD Hilcorp ASR#1 WO Rig. Post-Rig Procedure: 34. RD mud boat. RD BOPE house. 35. RU crane. ND BOPE. 36. Pull BPV. RD crane. 37. Move 500 bbl returns tank and rig mats. 38. Turn well over to production. RU well house and flowlines. Sorry for the confusion on this. I hope this clarifies the procedure for you. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 1 • From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.govj Sent:Tuesday, November 08,2016 2:03 PM To:Ted Kramer<tkramer@hilcorp.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: B-1 WSW ESP RWO(PTD 180-075)Sundry 316-559 Ted, Can't figure out how you will test BOP's with the dual string. Can you set a TWC in the short string also? Can you pull the 1 1/2" CS without pulling tubing hanger first? There is nothing in the procedure regarding installation of the new tubing spool ... please include those steps. Looks like it would be inserted after step 23 or so. ( hang off a storm packer??) You can send additional steps by email. No problem with pulling the short string first and using a crossover to 4.5" to close BOP rams on as requested. Also, Looks like a typo on step 12...should be testing VBR on 4.5"joint not 2 7/8" Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 2 Ima~Oroject Well History File Cover ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J~ -~) 7'-~Well History File Identifier Organizing ¢o,~ RESCA~N ~ Color items: '~,G [3 Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes. No. Other, No/Type BY: BEVERLY ROBIN VINCENT ~ARIA WINDY OVERSIZED (Scannable) Maps: Other .items scannable by large scanner OVen-Scannable) f various kinds Project Proofing ROBIN VINCENT SHERYL MARIA WINDY BY; Scanning Preparati ~ x 30 = v ~roduction Sca~ng Stage l PAGE COUNT FROM SCANNED FILE: , ~' BY: Stage 2 BY; (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES ) Isl + /(~' = TOTAL PAGES PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: lsl General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd • UNSCANNED, OVERSIZED MATERIALS AVAILABLE: /F6 0 TILE # / Tel 'd h c/a 7 U vt / ( ovie I I To request any /all of the above information, please contact: Alaska Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279 -1433 ►Tax (907) 276 -7542 RE: MPU Water Supply Wells S 4 Subject: RE: MPU Water Supply Wells From: "MPU, Well Operations Supervisor" < welloperationssupervisor @BP.com> Date: Fri, 02 Mar 2007 13:49:38 -0900 To: Thomas Maunder <tom maunder @admin.state Tom, I from what I know, they have always been ESPs. If you would like, I can dig back through the well files. Please let me know. Thanks, 2' 2.° John R. Cubbon MPU Well Operations Supervisor 1- 907 - 670 -3330 Original Message From: Thomas Maunder [mailto:tom maunder:odmin_ :ate.ak._s] Sent: Friday, March 02, 2007 1:28 PM To: MPU, Well Operations Supervisor Subject: Re: MPU Water Supply Wells Thanks John. For the ESP wells, they have always been ESPs correct? Tom MPU, Well Operations Supervisor wrote, On 3/2/2007 1:17 PM: r Hi Tom, C.k`S O �P V`- " \S(°- \ Q1 The information for these wells is as follows: F -02 ESP Completion Active Water Supply Well VAC, VAC A2A ESP Completion Active Water Supply Well tC S - ‘ C c B -01 ESP Completion Non - Active Water Supply Well (has not been utilized since at least 2004, and likely much longer) k %o _ d C F -21 ESP Completion Active Water Supply Well ‘C“0--k S F-58 ESP Completion Active Water Supply Well \ CO _ F -77 ESP Completion Active Water Supply Well \ C S - V 3 Co S -22 Jet Pump Completion in the UGNU. Has been SI since 2005 due to � _ i excessiv an production. S-9� lled as a hot Ivishak water supply well in 2006. We are evaluating completion options and trying to overcome potential a o S - v � S" corrosion challenges due to the high CO2 content of the water. Tentative plan to put into service later in 2007. I hope this helps Tom. If you have any questions, or need any further details, please don't hesisitate to let me know. Thanks John R. Cubbon MPU Well Operations Supervisor 1- 907 - 670 -3330 1 of 2 3/2/2007 1:58 PM RE: MPU Water Supply Wells 4 4 Original Message From: Thomas Maunder [ma.iit or mau nderdmin.state.ak.us] Sent: Monday, February 26, 2007 3:13 PM To: Cubbon, John R Subject: MPU Water Supply Wells John, I see that MPF -02 was just worked over. In the course of checking a few things, I noticed in our production report that this well was reported to be a flowing completion and it appears to have been since completion in August 1996. I have checked our reports on your other wells and found the following: MPA- 02A-- submersible, SI or no information to August 1995, then flowing or no information since. MPB- 01 - - -- submersible, SI or no information to January 1998, then flowing to September 2001 and SI since MPF- 21 - - -- flowing since completion June 1997 MPF- 58 - - -- flowing since completion November 1996 MPF- 77 - - -- flowing since completion April 1996 MPK- 34 - - -- flowing since completion December 1997 MPS- 22 - - -- hydraulic pump or flowing since completion in October 2003, SI mostly MPS- 90 - - - -no water production reported I think the production method for all the wells is ESP. Am I correct? I am not sure where the error might be coming from. When you confirm the production method, I will get with our stat techs here and see how we are receiving the information. Then I will get back to you and we can see what changes may be needed. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 2 of 2 3/2/2007 1:58 PM Tom Painter Divgslon Manager Conoco inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended te serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There are 19 active and 5 inactive production wells at Miine Poin:. ACTi~: ~-~,~ B-4A, B-6, B-9, B-10,~ B-il, B-!3, B-!5, B-16, C-l, C-2, C-3, C-~, C-5A, C-7, C-9, C-13, C-14, C-16 S~A%iC: - C-i8 B-2O, B-21, B-22 C-i/, =.~_ active oroduction wells w~i be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced with a diesel:oil mixture to at leas: 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and we%lhead valves will be closed. Yhe inactive production wells have been adequately freeze protected with diesel across the permafrost. %here are currently ten active and six inactive water injection wells in the Milne Point Unit. ~. -'l"[ i 'V ~'_-.; ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-Ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-l; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. if you have any questions on the shutdown proced,'re please contact Don Girdler at 564-7637. Yours very truly, ~~.~.'~a int e r ion Manager AlasKk 0:; i .... STATE OF ALASKA COMi~,~.,~SiON ALASt OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request' Abandon ~ Suspend [] Operation Shutdown Re-enter suspended well [] Alter casing [] T~me extension [] Change approved program [] Plugging [] Shmulate [] Pull tubing [] Amend order [] Perforate [] Other 2 Name of Operator Conoco Inc. 3 Address 3201 C Street, Ste. 200, Anchorage, Alaska 99503 4 Location of well at surface 214' FNL, 4235' FEL, Sec. 19, T13N, RILE, U.M. At top of productive interval 284' FNL, 4233' FEL, Sec. 19, T13N, RILE, U.M. At effective depth At total depth 1427' FNL, 4092' FEL, Sec. 19, T13N, RllE, U.M. 5. Datum elevahon (DF or KB) 46' KB 6. Unit or Property name Milne Point Unit 7 Well number B-1 8. Permit number 80-75 9. APl number 50-- 029-20490 10. Pool Kuparuk River feet 11 Present well condition summary Total depth PBTD measured 3282 feet true vertical (vertical) feet Plugs (measured) Effechve depth measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth Structural Conductor 80' 20" To Surface 105' Surface 2610' 13 3/8" 4000 Sxs 2635' Intermediate Production 3452' 9 5/8" 480 Sxs 3487' Liner Perforation depth measured 2903'-2936'; 3102'-3157'; 3196'-3266' true vertical (vertical) Tub,ng (size, grade and measured depth) 4½", L-80, 2689' Packers and SSSV (type and measured depth) Pump Packer @ 2565' True Vertical depth same same same 12.Attachments Descmphon summary of proposal J~ Detailed operations prograR[~ ~--1~I V~ 13. Estimated date for commencing operation January 1987 DEC 2 4 1986 14 If proposal was verbally approved Name of approver Alaska 0ii & Gas Cons. Commission Date approve~pch0rage 15. I hereby certify that the foregpjng ~s true and correct to the best of my knowledge Signed Commission Use Only Date Conditions of approval Approved by ORIG'NAL SIGHED BY LONNI( C. $i111 , Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Commissioner by order of the commission Date /,,.~/.~ Subm'it in triplicate John R. Kemp O~ws~on Manager Wa~en J. Hairford D~ws~on Operations Manager Gordon A. Hitchings D~wsion Projects Manager Conoco Inc. 3201 C Street Su,te 200 Anchorage, AK 99503 (907) 564-7600 May 21, 1986 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Well Recompletion Report for MPU Well B-1 Attached for your information and file is the original and one copy of the subject report. If you should have any questions please call Charles Taylor at 564-7606. Yours very truly, E. D. WilsOn Division Administrative Manager CLT/vv Enc RECEIVED MAY 2 2 1 86 Alaska 0~1 & Gas Cons. Commission Anchorage ",' .. ' -, STATE OF ALASKA C( ALASK~ ,AND GAS CONSERVATION . MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classlf,cat~on of Service Well OIL [[] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~ Water Suppl~z ,,, 2 Name of Operator 7 Permit Number Conoco Inc. 80-75 -- , 3 Address 8 APl Number 3201 C Street, Ste. 200, Anchorage, AK 99503 50_029-20490 4 Location of well at surface 9 Un~tor Lease Name 214' FNL, 4235' FEL, Sec. 19, T13N, RllE, Umiat Meridian Milne Point Unit At TopProducmglnterval 10 Well Number N/A B-1 At Total Depth 11 F~eld and Pool 1427' FNL, 4092' FEL, Sec. 19, T13N, RllE, gmiat Meridian Kuparuk River Field 5 Elevauon m feet (,ndmate KB, DF, etc ) I 6 Lease Designation and Serial No 46~ KBI ADL 47438 , ,. 12 Date Spudded1_4_81 13 Date T D Reached3_2_81 114 Date C°mp ' Susp °r Aband' ] 15 Water Depth' If °ffsh°re 116 N° °f C°mpletl°nsl--28--86 N/A feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back DeptlY('MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 9635' (9439' TVD)3282,MD/3106,T. VD YES]~ NO[-] N/A feetMD 1800'-_.. 22. Type Electra or Other Logs Run Refer to original completion report 23 CASING, LINER AND CEMENTING RECORD ,, I SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" .94 H-40 ' 30, 105i 26" Cement to surf. 0 -' 1~ ~/8" 72 N-8~ 30' 2635' 17~"2 4000 sx Arctic Set II 0 9 5/g" 47 ISOO-~5 30' 7617' · . ~-~. 997 sx Self Stress 0 7" 29 N-80 7470' 9630' 8~"2 230 sx. Self Stress 0 , 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD ~nterval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) .... 2903'-2936' MD 4~" 2689' 2565' 3102,_3157, MD 1~" 1990' N~)'A 3196'-3266' MD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED * All perforations are 12 SPF, ._. 90~ phasing, 0.40" holes 27 PRODUCTION TEST Date F~rst Production I Method of Operation (Flowmg, gas I~ft, etc ) 1-10-86I Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATi~R-BBL CHOKE SIZE IGAS'OILRATIO 1-11-86 24 TEST PERIOD I~ 0 N/A 13,585 N/AI 0 Flow Tubing Casing Pressure cALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 300 0 24-HOUR RATE ~ 0 N/A 13,585 N/A 28 CORE DATA Brmfdescr~puonofl,thology, poros~ty, fractures, apparent dlps and presence of oil, gas or water Subm~tcorechlps Refer to the original completion report. · * NOTE: This well was recompleted as a water supply well. R E C E IV E D MAY 2 2 1986 Alaska 0il & Gas Cons. Commission , Anchora,qe Form 10-407 Rev 7-1 80 CONTINUED ON REVERSE SIDE Submit in dupllcat~ 29 30. · GEOLOGIC MARKERS FORMATION TESTS , ,, NAME ..... Include interval tested, pressure data, all ¢lu,ds recovered and grav,ty, MEAS DEPTH Ii TRUEVERT DEPTH GOR, and t~rne of each phase Refer to original completion report. 31 LIST OF ATTACHMENTS Completion Sketch - Casing Sketch 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct we!l 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 measuremf.~nts 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. , MILNE POI[IT B-1 (WSW) OPERATOR: CONOCO INC. SURFACE LOCATION: 214' FNL, 4235' FEL, Section 19, T13N, RILE, U.M. BOTTOM HOLE LOCATION: 279' FNL, 4233' FEL, Section 19, T13N, RILE, U.M. SPUD DATE: 01/04/81 (Original Hole) NOTES: 1. Ail measurements from KDB of Parker 128 2. KDB - SL - 46' 3. KDB - GL = 24' 4. Max. angle = 0.5° 5. KOP at N/A REC MAY ~. Vertical Hole 13 3/8" Surface Casin~ '1. Pumped 50 Bbls of water pre-flush 2. Pumped 4000 sx of 15 ppg Arctic Set II cement. 3. Displaced with 380 Bbls mud. Or~ / C1~'.4 KJS Of~m / C#14 Oefe ..... ,, 20" 94#, H-40 at 105' TOC (Estimated) at 1500' 13 3/8" 72#, N-80 Btrs. at 2635' 3282' - EZSV Retainer 3289' - TOC 3300' - EZSV Retainer 3348' Top of 7" Liner 9 5/8" 47#, 500-95 at 3487' NOTE: Approximately 150 Bbls cement returns to surface during Job. Centralizers: 1 per 20' Surface - 80' 1 per 80' 80' - 2555' 1 per 20' 2555' - 2635' 9 5/8" Production Casing: 1. Casing originally run 0' - 7617'. Window milled at 3487' - 3529' for subsequent redrill. Effec- tive depth of 9 5/8" casing is now 3487'. 2. Pumped (from shoe at 7617') 40 Bbls spacer, 580 sx self-stress cement with 1% D-60, 2% D-13, .2% D-46 and displaced with 544 Bbls mud. 3. Pumped (from stage collar at 5033') 40 Bbls spacer, 417 sx self-stress cement with 1% D-60, .2% D-13, .2% S-l, .2% D-46 and displaced with 384 Bbls mud. ~ueezes: 1. Squeezed 67 sx Class "G" with 2% S-I, .2% defoamer out perforations at 3285'. 2. Squeezed 166 sx Class "G" cement with 2% S-I, .2% defoamer behind casing from perfs 3190' to perfs at 3090'. Squeezed 49 sx of additional cement out of perfs at 3090'. 3. Circulated 86 sx of Class "G" cement with additives behind casing from perfs at 2951' to perfs at 2888'. 4. Squeezed 122 sx of Class "G" cement with additives out perforations at 3087'. 5. Squeezed 49 sx of Class "G" cement out perforations at 2951'. 9 5/8" x 13 3/8" Annulus 1. Circulated Arctic Pack to surface followed by 150 sx of Arctic Set II and 100 sx of Class "G" with 3~ CaCI~ (circulatio~ perforations at 2000'). IVED 2 1, $6 Cons. ,C0mm]s$i0n hcrage B-1 MILNE POINT UNIT (WATER SOURCE WELL) ACTUAL COMPLETION SKETCH COMPLETED ON 8-2-82 RE-COMPLETED ON 1-28-86 FMC DUAL-STRING TUBING HANGER NOTES: 1. All meaeur®mente ere from KDB of Porker Rig 128 KDB - 8L · 46' S. KDB - GL · 24' 4. Idex. &nolo · 0 S° S. KOP · NA 6. VERTICAL HOLE 7. Min. engle-NA 8. APl No. 50-029- 20490 B, Completion fluid 8.6 ppg KCl brine Caning and eomant Information euppilod on ~eelng end ©emont oketoh. 4 I/e". 12 T54~- EUE 8rd L-80 tubing (3 958"1D, 3 833'* drift ) -- N2 2 Clntrllift '200' ESP Power Cable (I 30" OD) ~/~.~ ~ 9~P CS Hydrll tubmg eldeetrlnq I ~/~ # X t" Crossover -- I', 2 25~ CS Hydril tubing sideifring I~0' Tubing toll 2565' BOT TwlnSsal Submersible Pump Packer P580' CAMCO 4 I/l' Gel Lift Mandrel 2611 ' CAMCO DB-S nipple (S 687" ID) PERFORATIONS TERTIARY WATER SANDS 4" hollow carrier 12 SPF, 90° phoelng 2903' o 2936' 3102' - :5157' 3196' o 3266' (All depths from DIL log of I' 20-81 ) ECEIVED Ancl~orage ORIIINAI,. h~, ?___Io / I / ss ~/~ , ,, 2689'Tubing toll (8" OD centralizer Immediately above ta~J ) Dowel! "IG-E'* pocket I/2", 9 5 ~ blank ptl~ Top of ICreen I/2", 9 S.~ 12 gage wire- wrapped lc:teen NOT£. Gravel poc/~ log /*un '0' Ring Seal Sub w/6' tell-toll screen EZSV Retmner Top of Cement EZSV Relatnar TOp of 7" Liner 348?° 9~/a'' 4T-~' SO0-9S ( 8 681" ID, 8,525" drift "~ Gravel p~c~ed w/158 ft~ 20- 40 mesh ~revs/ iii iii i ii ii STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator 7 Permit No Conoco Inc. 80-75 3 Address 3201C Street, Suite 200, Anchoraqe, Alaska 99503 4 Location of Well 214' FNL, 4235' FEL, Sec. 19, T13N, RllE, U.M. 8 APl Number 50- 029-20490 9 Umt or Lease Name Milne Point Unit 10 Well Number 13-1 11 F~eld and Pool Kuparuk River 5 Elevation ~n feet (~nd~cate KB, DF, etc ) 46' KB 6 Lea~eTt~nat,on and Ser,al No 12 (Submit m Tr~phcate) Perforate [] Alter Casing [] Perforations Stem u late [] Abandon [] Stem ulatlon Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulhng Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF' (Submit ~n Duplicate) [] Altering Casing [] Abandonment [] Other 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) This well was brought on as a water producing well on 1-11-86, and its status should be changed from suspended to service and classified as a water source well. 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S~gnedt..~~ .... l~tle The space be~l~for Comm,ss,on use Cond~uons df Approval, ~f any Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "lntent,ons" in Triplicate and "Subsequent Reports" ~n E)upl,cate Conoco IRC. 2525 C Street Suite 100 Anchorage, Alaska 99503 November 6, 1984 Mr. Jim Trimble Alaska Oil & Cas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-l, A-2, B-l, B-2, B-3, B-4A, B-5, C-l, C-2, C-3, D-I, L-I, M-IA, N-lB, and Gwydyr Bay State 2A. Ail of the above are classified suspended wells. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the wells are suspended. Please contact Jim Dosch at 279-0611 if you have any questions. Your_s very tru]y,~ /anager of Alaskan Operations ~' JTD/ks ~ Attachments RECEIVED NOV 0 9 l 184 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ALAS( OIL AND GAS CONSERVATIONt_ .)MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL 2 Name of Operator 7 Perm~tNo Conoco Inc. 80-75 3 Address 8 APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50- 029-20490 4 Location of Well 214' FNL, 4235' FEL, Section 19, T13N, RllE, U.M. 5 Elevation m feet (md,cate KB, DF, etc ) 46' KB 12 Lease Des~gnat,on and Serial No ADL 47438 9 Umt or Lease Name Milne Point Unit 10 Well Number Milne Point B-1 11 F~eld and Pool Kuparuk Field Check Appropmate Box To Indicate Nature of Not~ce, Report, or Other Data OTHER [] NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit in Tmpllcate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulhng Tubing [] (Note Reportmult~plecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for each completion) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Request one year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the well is suspended. This well will be utilized in the Phase I development of the Milne Point Unit. Work to re-activate this well will begin prior to production in early 1986. RECEIVED NOV 0 9 Alaska Oil & Gas Cons. Commission Anchorage Date 14 I here~e fore_~~e and~ to the best of my knowledge Manager of Alaskan Operations Cond~lfs of Approval, ~ a-~y .... "' .. b, ,~,L~.~I~ ByOrderof Approved by COMMISSIONER the Comm~smon Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate '"" ,' MEMO i IDUM Sta e of Alaska TO C. V.I q~t~rton OATE August 22, Chai~ FILE NO D.31.52 THRU: Lonnie C. Smith Commi s s loner ~ TELEPHONE NO ~ROM Bobby Foster~. Petroleum Inspector 1984 SUBJECT Inspect Suspended Wells and Locations at Conoco Sites. Thursday, August 16, 1984: I traveled this date to Prudhoe Bay~,and met with Jerry Fritch and Jim Dosch, Conoco representatives, to inspect the suspended drill sites and wells listed below. Gwyder Bay 2A Milne Point N-lB Milne Point M-iA Milne Point L-1 Milne Point Pad A (4 wells) Milne Point Pad C (4 wells) Milne Point Pad B-~ Milne Point Pad D I recommend to the Commission that these wells and drill sites be accepted as suspended. Pictures attached. 02 00lA(Rev 10179) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFOP~4ATION:/~ . ~~-~--' [.~>~_~O .... Date Suspended Address ~~ d ~' ~_/~/~ ~ ~~o~~. ~. .. Lo' - ' ~er~it No. ~O cation of Well Surfaqe ~/~ Ft. F ~ L, ~Ft. F~L API No. 50 ~~-~~y~ Se~[/~" T~ ~ , R~ ~ , ~ M. Unzt or Lease Name~]'/~ Well No., '~-~_ Field & Pool ~/~ ~~ Condition of Pad. Condition of Pits Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard Attached to Information correct No Ye s No No Cellar - Opened Yes Fil led Yes Covered ~ WaterWell - Plugged off No Rat Hole Open Yes No No Fz 1 led Y.~ No No Covered ~3 No Capped Open Expla nation ~J//~ Photographs taken to verify above conditlons~ No Explanaton Work to be done to be acceptable This well and location i~ (unacceptable) to be classzfzed as suspended for the period of ~_-/~_- .. ~~~~ .... 19~-. Date: F-/~- . Revised 8/24/82 H. D. Haley Manager of Alaskan Opera. ons Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 October 17, 1983 Mr. Jim Trimble Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-i, A-2, B-I, B-2, B-3, B-4A, C-i, C-2, C-3, C-4, D-I, and Gwydyr Bay State #2A. Ail of the above are classified as suspended wells, and Conoco will be contacting one of your representatives to conduct an inspection of these wells each year as long as the wells remain under this status. Also attached is a completed 10-407 form requesting a change in status for Milne Point B-5 from plugged and abandoned to suspended. You will also find photographs enclosed covering the cleanup operations that took place subsequent to this year's inspection of Gwydyr Bay State #1 and #2A. Photographs are also included that show the new signs mounted on Milne Point C-4 and D-2A. Please contact J. T. Dosch if additiona] information is necessary or if you should have any questions. It. D. I-Ialey Manager of Alaskan Operations cc: A. E. Hastings, Anchorage ~' STATE OF ALASKA (~' ALASKA OIL AND GAS CONSERVATION C ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL )(-I OTHER [] 2 Name of Operator 7 Permit No Conoco Inc. 80-75 3 Address 8 APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50-029-20490 4 Location of Well 214' FNL, and 4235' FEL of Sec. 19, T13N, R11E, U.M. 5 Elevation ,n feet (md~cate KB, DF, etc ) 46' KB 12 I 6 Lease Designation and Serial No ADL 47438 9 Umt or Lease Name Milne Point Unit 10 Well Number Milne Point B-1 11 F~eld and Pool Kuparuk Field Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submtt m Triplicate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~X Pulhng Tubing [] (Note Report mult,ple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Request one year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year until the well has a plugged and abandoned status. 141 hereby/~.~y)th~he foregomg~ ,s true and correct to the best of my knowledge ~ V l-- S,gned A- /~~~~ T,t,eManager of Alaskan Operations lhespace~e,~forComm,ss,onuse ~'6. Haley Date 10-19-83 Cond,t~ons of Approval, ~f any Approved by 6RIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev 7-1-80 Submit "Intentions" ir~ Triplicate and "Subsequent Reports" ~r~ Duplicate ' MEMORA iDUM Stat of Alaska TO Ccsamissione~ FILE NO TELEPHONE NO September 2, 1983 108A~J5 FROM Harold R. Hawkins Petroleu~ Inspector SUBJECT Cleanup Inspection for Extension of Suspended Status Conoco, Milne Point B-l, Sec 19, T13E,RllE, Permit No. 80-75. Wedn..e.~ay,~ Auq~t 17, 19835 ~hile I ~as inspecting other we/Is at-M~lne POint, I inspeCted Conocoas Milne Point No. B-1 Well. Pad, sign, and well ~eet A.O.G.C.C. regulations. I took a picture to verify conditions. .I filled out an A.O.G.C.C. report which is attached. In summary, I inspected Conoco's Milne Point, Well No. B-1 for extension of suspension and found a/1 requirements of A.O.G.C.C. ~re met. I feelthis well should be approved for extension of suspension. Attachments 02-001A(Re~ 10/79) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator L-D z~ ~ Addre s s Surface Location of Well /~ Ft. F_~~L, ~~fFt. F Da te Suspended /~_ Permit No. ~--7~~- ~- L API No. 50 Unit or Lease Name~~_~/~_~-_ Well No. _ Field & Pool Condition of Pad /Qzd Well head - Ail outlets plugged Yes No Well sign - Attached to well head Ye~ No Attached to well guard ~e~s~J No Attached to Information correct ~e~ No Cellar - Opened Yes No Rat Hole Fi 1 led Ye s No Cove red Ye s No WaterWell - Plugged off Capped Open Explanation Open Yes Fi 1 led___ Ye s ~6~e~ ~'> Ye s No Photographs taken to verify above conditions ~ No Explanaton Work to be done to be acceptable _ 7-2/~/~___~__~ ~_ .?~o_~__,~?_ ~Z = ~his well and location is~(unacceptable) to suspended for the period o~/- 19.. thru by ~'~ Inspected : / Da te :_ be classified as 19 . {evised 8/24/82 TABLE 2 WATER ANALYSIS REPORT Well Name: Milne Point Unit, B-1 Water Well Formation: Prince Creek Sample Point: Bleeder Hose Date Collected: 11-1-82 ANALYSIS RESULTS Specific Gravity: 1.003 Resistivity at 73°F 1.650 OHMMeters PH: 7.20 MG/L Total Salts 3320 Hydrogen Sulfide 0 Chloride (CL) 53.5 1900 Sulfate (SO4) 0.0 3 Carbonate (CO3) 0.0 0 Bicarbonate (HC03) 2.6 163 Hydroxyl (OH) MEq/L,, ~ MG/~L Sodium 46.4 1068 Magnesium (MG) 0.9 16 Calcium (CA) 6.1 122 Barium (BA) 0.0 0 Iron (MG/L) Total 0 Diss 0.5 Suspended So]ids 8.8 MG/L Silver (AG) <.030 Aluminum (AL) <.15 Boron (B) .11 Beryllium (BE) <.005 Cadmium (CD) <.015 Chromium (6/{) <.03 Copper (CU) <.015 Iron (FE) .06 Manganese (MN) .19 Molybdenum (MO) <.05 Nitrate <1 Arsenic <.002 OTHER ANALYSIS K 88 Trace Analysis Nickel (NI) Lead (PB) Antimony (SB) Tin (SN) Strontium (SR) Titanium (TI) Thallium (TL) Vanadium (V) Zine (ZN) Mercury Selenium MG/L <.075 <.25 <.25 .11 2.3 <.025 <.50 <.025 <.025 <.002 <002 B'J . TERTIARY ~ATER SANDS RECEIVED AUG 0 619ll4 rdas"a,,,,'" & Gas Cons. Commission ? m;h ~rt~e 9,POId T&J~IEOUg -POTENT I AL. -I-~ *- 6AMM& RAT r//i//../i////~/i//.- FiG'URE-G S9ecif[c GraVitY: I .017z~ Total salts u,,aro~e~ Sulfide chlor~ - Sulfate rbonate (CO~J Ca _.. (~c03) potassium 5 t r out ~um 321~ .3 0.3 0.0 5B .~ gestst~Vit~ at 11500 13 0 3560 0.2B ORM Meters 120 3.9 ?tt: 7.~0 SodiUm lB 1.5 B6 MagnesiUm (MG) ~. 3 39 CalciUm (C~) 0.6 rtUm (Bk) .3 Dias Ba ,.,o~.~ Total 5.B Suspended RECEIVED AUG 0 619~ Alaska 0il & 8as Cons. Commission Anchorage TABLE 4 Reservoir Properties Porosity: Middle Kuparuk Lower Kuparuk Permeability: Absolute Air Permeability Oil Permeability Range Middle Kuparuk Average Lower Kuparuk Average Average Water Saturation: Middle Kuparuk Lower Kuparuk Oil Viscosity (at IO0°F) Oil Gravity (average) Bw at 3540 psi Bo at 3540 psi (reservoir pressure) Bo at 2125 psi BPP GOR Gas Gravity (Air = 1.00) .183 .215 50-4890 md 34-330 md 158 md 60 md .271 .210 40 cp 22° API 1.024 BBL/STB 1.153 BBL/STB 1.164 BBL/STB 290 SCF/BBL 0.65 ,. March 3, 1983 Conoco Inc. 2525 C Street Suite 100 Anchorage. Alaska 99503 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Driv~ Anchorage, Alaska 99501 Gentlemen: Enclosed are "Subsequent Reports" for the following wells: Well Milne Point A-2 Milme Point B-1 Milne Point B-1 Milne Point B-3 Brief Description · Other - Abandon Other - Casing Changes Perforate Perforate, Test & Suspend If you have any questions, please contact Steve Berg at 279-0611. Very truly yours, W. M. Haskell Administrative Coordinator kr Enclosure RECEIVED MAR ? 983 Alaska OIJ & Gas Cons Co/nr~/ssiorl Anchorage 2 Name of Operator Conoco Inc. 3 Address " f STATE OF ALASKA ALASK~ oIL AND GAS CONSERV,t~I~ G~,.~MMISSION SLII IDRY I IOTIC=S AHD WE LS DRILLING WELL ~ CO~ff~ED WELl 2525 C Street, Suite 100, Anchorage, Alaska 99503 4 Locatmon of Well 214' FNL, 4235' FEL, Section 19, T13N, RllE, UM OTHER [] SUSPENDED 7 Permit No 80-75 8 APl Number 50-029-20490 . 9 Umt or Lease Name Milne Point Unit 10. Well Number Milne Point B-1 5 Elevation m feet (,nd~cate KB, DF, etc ) I 6. Lease Designation and Set,al No 46' KB I ADL 47438 12 Check Appropriate Box To Indicate Nature of Notme, Report, or Other Data 11. F,eld and Pool Kuparuk River Field NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit m Triplicate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations [] Altenng Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repa,r Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] [] [] [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) Change Plans 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On January 14, 1981, a Sundry Notice was submitted indicating a change in the original plans submitted to the Oil and Gas Conservation Commission in the Permit to Drill Application for Milne Point B-1. The changes to the plans were completed as follows: 1) A 12-1/4" hole was drilled to 7600' measured depth. The hole was logged and conditioned for casing. While conditioning for casing an additional 25' of hole was drilled. 2) 9-5/8" 47#, S00-95, BTRS, casing was run from surface to 7617'. (A 5000#, 9-5/8" wellhead was used as indicated in initial Sundry Notice). 3) The 9-5/8" shoe was drilled out and an 8-1/2" hole was drilled to 9635'. 4) A 7", 29#, N-80, LT&C, liner was run and cemented from 7470' to 9630'. Cross-reference: For more detailed information, please refer to the Well Completion Report submitted in May, 1981. 14 I hereby ce~fy that the foregoing is true and correct to the best of my knowledge S,gned T,deSupervisin..g Production Engineer Date The sp~bel r Commission use Cond,~tlons of ,~pproval, ,f any 2-24-83 '~ By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Tr~phcate and "Subsequent Reports" in Duphcate March 3, 1983 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Driv~ Anchorage, Alaska 99501 Gentlemen: Enclosed are "Subsequent Reports" for the following wells: Well Milne Point A-2 Milne Point B-1 Milne Point B-1 Milne Point B-3 Brief Description · Other - Abandon Other - Casing Changes Perforate ' Perforate, Test & Suspend If you have any questions, please contact Steve Berg at 279-0611. Very truly yours, W. M. Haskell Administrative Coordinator kr Enclosure RECEIVED MAR-- ? ,983 Alaska 0,t & Gas Cons CoJnrn¢ssion Anchorage " ' A(~ STATE OF ALASKA ALASK IL AND GAS CONSERVATIONC MMISSlON SUNDRY NOTICES AND REI ...I:ITS ON WELLS 2 Name of Operator '-4q~(.],,/~.~ ~, . 7 Perm,t No Conoco ]:nc. -~3.~ _ I 80-75 3 Address 4,, j.;7.~?¢ ~,' 2525 C Street, Suite 100, Anchorage, Alaska 995~3'4'~ ~"~2';;<':.1;~¢)_029_20490~8 APl Number 4 Location of Well 9 Umt or Lease Name Milne Point Unit 214' FNL, 4235' FEL, Section 19, T13N, RllE, UM 10. We~Number Milne Point B-1 11 F~eld and Pool 5 Elevation m feet (,nd~cate KB, DF, etc ) I 6 Lease Deslgnat,on and Serial No Kuparuk River Field 46' KB I ADL 47438 12 Check Appropriate Box To Indicate Nature of Not,ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repa,r Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multlplecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for eachcomplet~on) OTHER [] SUSPENDED [] [] [] Change Plans 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On January 14, 1981, a Sundry Notice was submitted indicating a change in the original plans submitted to the Oil and Gas Conservation Commission in the Permit to Drill Application for Milne Point B-1. The changes to the plans were completed as follows: 1) A 12-1/4" hole was drilled to 7600' measured depth. The hole was logged and conditioned for casing. While conditioning for casing an additional 25' of hole was drilled. 2) 9-5/8" 47#, S00-95, BTRS, casing was run from surface to 7617'. (A 5000#, 9-5/8" wellhead was used as indicated in initial Sundry Notice). 3) The 9-5/8" shoe was drilled out and an 8-1/2" hole was drilled to 9635'. 4) A 7", 29#, N-80, LT&C, liner was run and cemented from 7470' to 9630'. Cross-reference: For more detailed information, please refer to the Well Completion Report submitted in May, 1981. 14 I hereby ce_,r~fy that the foregoing is true and correct to the best of my knowledge Signed T,tleSupervising Production Engineer Date The sp e belovy or Commission use Conditions of ;~pproval, if any 2-24-83 Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~r~ Duphcate - ' A(' STATE OF ALASKA ALASK _ .L AND GAS CONSERVATION C .~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED ~ELL [] 2 Name of Operator Oonooo no. 3 Address 2525 C Street, Suite 100, Anchorage, 4 Location of Well 5 Elevat,on ~n feet (~nd~cate KB, DF, etc ) 46' KB 12. OTHER [] 7 Permit No 80-75 8 APl Number 50-- 029-20490 9. Unit or Lease Name Milne Point Unit }0. Well Number Milne Point B-1 I6 Lease Designation and Serial No ADL 47438 Check Appropriate 8ox To Indicate Nature of Not,ce, Report, or Other Data NOTICE OF INTENTION TO- SUBSEQUENT REPORT OF' (Subm,t in Tr,pl~cate) Perforate [] Alter Cas,ng [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tub,ng (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 11 F~eld and Pool Kuparuk River Field (Submit tn Duplicate) [] Altering Casing r-] [] Abandonment [] [] Other r-I 13 Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, tncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On March 13 and 21, 1981, a Sundry Notice was submitted noting the intent to perforate. The following work was perforated under the approval of the Oil & Gas Conservation Commission: 1) Well was perforated from 9270' to 9300' (30') @ 12 jet shots per foot at 90° phasing (perforated on March 15, 1981). 2) After testing these perforations were abandoned with 150 sx. of cement. 3) Well was perforated from 7188' to 7214' (26') @ 12 jet shots per foot at 90° phas- ing (perforated on March 23, 1981). Note: Well was not hydraulically fractured as initially proposed. 4) A plug was run in an X-nipple below the packer (at 7165'). The hole above the packer was then changed over to 10.2 CaCl2 water. 5) The well was to be perforated in two other intervals (4420' to 4495' and 3890' to 3950'). However, while squeezing the intervals for isolation purposes, a RTTS packer was cemented in the hole and the hole was abandoned from 3529'. 6) As noted in the Well Completion Report (Form 10-407), the well was sidetracked away from the junk in the original hole, and a zone from 3895' to 3959' was open hole gravel packed, then tested. Cross-reference: For more detailed information, please refer to the Well Completion Report (Well History) on Milne Point B-l, submitted in May, 1981. 14 I hereby/certify that the forego,ng ,s true and correct to the best of my knowledge S,gned ' _ rm~upervising Production Engineer Date The s~pce belov~or Comml~ss~on use Conditions of Approval, ~f any By Order of Approved by COMMISSIONER the Corem,ss,on Date 2/24/83 Form 10-403 Rev 7-1-80 Subm,t "Intentions" ~n Tr~phcate and "Subsequent Reports" in Duplicate Fe~ruaz~ 16 · 19 83 COIIOCO TrlC · 2525 C Street, Buite 100 ~nchorage, Alaska 99503 Res Subsequent Reports, Sundry Notices and Repo~s on Wells (For~ 10-403) For the following lists of 'Notice of Intention To:' Sundry ~otices and Report on Wells (for~ I0-403) this office does not have on record the "Subsequent Repor~ of~ ' defining the action taken on the approved inten~ion. Please advise this office by Subsequent Report of the disposition of the tntent£on. Milne Pt. 1/14/e! 3/21/1~1 5/17/82 Casing head, casing changes Perforate and testing Perforate, flow test, sust~,nd LCS/J~T/g lh H. D. Haley Conoco Inc. Manager of Alaskan Operatmons October 1, 1982 2525 C Street Suite 100 Anchorage, AK 99503 Mr. Jim Trimble Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for: Milne Point A-I~B-1, B-2, B-3, B-4A, C-1, C-3, D-l, Kavearak Point 32-25; and Gwydyr Bay State #2A. All of the above are classified as suspended wells and Conoco will be contacting one of your representatives to conduct an inspection each year until the wells have a plugged and abandoned status. Also attached is a completed 10-407 form requesting a change in status for Gwydyr Bay State #1 from suspended to plugged and abandoned. You will also find the photographs you requested concerning the recent inspections of Gwydyr Bay State #1, #2A, and Milne Point A-1. Please contact J. T. Dosch if additional information is necessary or if you should have any questions. Yours very truly, H. D. Ha ley Manager of Alaskan Operations JTD/tt cc' G. A. Merriman - w/o attachments A. E. Hastings - w/o attachments C STATE OF ALASKA ~ ALASKA ,~.AND GAS CONSERVATION C ,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL)~ OTHER [] 2 Name of Operator 7 Permit No Conoco Inc. 80-75 3 Address 8 APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 5o- 029-20490 4 Location of Well 214' FNL and 4235' F£L of Sec. 5 Elevation ~n feet (~nd~cate KB, DF, etc ) 46' KB 19, T13N, R11E, UM 12 Lease Designation and Serial No ADL 47438 9 Unit or Lease Name Milne Point Unit 10 Well Number Milne Point B-1 11 Field and Pool Kuparuk Fi eld Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Triplicate) (Submit ~n Duplicate) Perforate [] Alter Casmg [] Perforations [] Altermg Casmg [] Stimulate [] Abandon [] St~mulanon [] Abandonment [] Repmr Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~ Pulling Tubing [] (Note Reportmult~plecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for eachcomplet~on) 13 Desc.be Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, mclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Request one year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year until the well has a plugged and abandoned status. 14 I hereby ~~ certify that f~oregomg~l's true and correct to the best of my knowledge Signed ~_~~~ T.tle Manager of Alaskan Operations Date The space below for Commission use 10-6-82 Conditions of Approval, ~f any An inspection will be necessary by August 1983. ORIG'flAL SIGNED Approved by, BY H'RRY W. KDGLER COMMISSIONER ~,Fprcved Copy [~eturned By Order of the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" ~n Duplicate September 10, 1982 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Enclosed are the following subsequent Sundry Notices: - Wireline re-entry, Kavearak Point 32-25 - Perforations, Milne Point B-4A - Cement squeeze, Milne Point B-3 - Gravel pack completion,,Milne Point B~ If you have any questions, please call either Don Girdler or me at 279-0611. Very truly yours, Gary A. Merriman Supervising Production Engineer tt cc: R. J. Francis, w/attachments A. E. Hastings, w/attachments D. R. Girdler, w/attachments Wel! Files - 32-25: B-4A:B-3:B-1, w/attachments RE['E!VED SEP 1 3 i982 A~aska Oil & Gas Cons. 6ommissior~ ,Al~chorage L STATE OF ALASKA ~ NOO.~T~tD ALASKA ,LANDGAS CONSERVATION C ,~MISSIO SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator 7 Permit No. Conoco Inc. 80-75 3 Address 8 APl Number 2525 C Street, Suite lO0, Anchorage, Alaska 99503 5o_029-20490 4 Location of Well 214' FNL and 4235' FEL, Sec. 19, T13N, RILE, U.M. 6 Lease Designation and Serial No ADL 47438 9. Un,t or Lease Name Milne Point Unit 10 Well Number Milne Point B-1 11 F~eld and Pool Kuparuk River Field Kuparuk River Pool 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stlmuh~t~on [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On July 8, 1982, Conoco submitted a Sundry Notice for the clean-out and gravel packing of the Milne Point Unit B-1 well. On July 13, 1982, the Roll'n #4 completion rig began to RIH and clean-out the well. The following is a detailed explanation of the operatior with a final completion sketch: I ECEIVED SEP 1.3 1982 AJaska 0ii & Gas Cons. Commission Anchorage 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge The sp~e below~or Comm,ss,on use Conditions of Approval, if any Approved by / Form 10-403 By Order of COMMISSIONER the Commission Date Rev 7-1~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ( CONF DENTL Date 7-13-82 7-14-82 7-15-82 7-16-82 7-17-82 7-18-82 7-19-82 7-20-82 7-21-82 7-22-82 Operations RIH w/3½" drill pipe and tagged the top EZSV retainer at 2265'. Circulated out the diesel w/9.2 ppg KCL then began drilling on the retainer. Drilled out the retainer at 2265' and pushed down to 2905' while circulating out sand. Losing fluid at 2 BPM so fluid weight was cut from 9.2 ppg to 9.0 ppg. Drilled up second retainer at 2905'. Still losing fluid at 2 BPM with 9.0 ppg brine. Having trouble w/retainer parts hanging-up in the hole. Tripped for new bit then swept hole with a gel pill. Drilled for 1½ hours on the third retainer at 3065'. TOOH and changed out to a concave mill then finished drilling up the retainer at 3065'. Tagged the fourth retainer at 3187'. Drilled on the retainer and while sweeping the hole, lost returns with 8.8 ppg brine. Tripped for a new mill then finished drilling up the fourth retainer at 3187'. Chased the retainer to the top of the retainer at 3338'. The State witnessed the tagging of the retainer at 3338', then a 50' cement plug was spotted on top of the retainer. Tagged the TOC for the State at 3289' with a mill and scraper on the drillpipe. RIH with a Dowell wash too]. and tagged fill 60' high. Could not reverse circulate so the wash tool was pulled. Drillpipe was RIH open ended, and fill was cleaned out to 3289'. The hole was swept, then a pill was spotted across the perforations. The wash tool was run back in, and the perforations were washed from 3272' to 3102' (DPM). There was intermittent pressure seen during the test with a maximum pressure of 1000 psi before it broke back to 300 psi. However, the majority of the perforations were washed with no pressure indications. After POOH with wash tool, TIH with open ended drillpipe. Tagged at 3236'. Cleaned out the well to PBTD then scoured out the 3½" IF workstring by pumping a 5 bbl pill of 15% HCL and 1% P-200 inhibitor and 0.3% L-41 iron sequestriant. Spotted a gelled pill w/breaker (J-218) across perforations. RIH w/a 9 5/8" retainer and set at 3282'. POOH. TIH w/gravel pack assembly on a cross-over typo running tool. Set the model 16 packer at'2867'. Attempted to gravel pack the well as follows: CONFIDEi F 7-23-82 7-24-82 7-25-82 7-26-82 a) Pumped 24 bbls of 13 ppg slurry (5500 lbs of sand) with no pressure increase. b) Pumped an additional 16 bbls of 15 ppg slurry (6000 lbs of sand) with only 100 psi pressure increase. c) Pumped a third batch of 16 bbl of slurry (w/4250 lbs of sand) and saw a sand out with 7 bbl of sand left in tubing (based on displacement volume). Ran pressure up to 500 psi then slacked off into the squeeze position and pumped to a sand-out at 1700 psi. Released from packer and reverse circulated without returns. PU workstring and weight increased 8000# before pipe came loose. POOH with workstring. Ran in hole w/shifting tool w/o the 2 3/8" wash pipe to check the pack. While stinging into the packer the tool was catching on the packer. Attempted to release from packer and POOH with workstring. Brought packer and screen out of the hole. RIH w/OEDP and circulated out the gravel pack sand. POOH. WO Dowell parts. (Discovered that the packer had not set because the slips were not hard enough to hold in S00-95 casing). Tagged for fill. No fill. Special slips were installed on the packer, and the gravel pack assembly was run in the hole. Assembly sat down 50' high (3230'). POOH. RIH w/OEDP and clean out to PBTD and then spotted a gel pill. POOH. RIH w/gravel pack packer and assembly. Set packer at 285~' (2' of fill). Gravel packed the well as follows: a) Pumped 16 bbl slurry w/6000 lbs of sand w/o a pressure increase. b) Pumped 16 bbl slurry w/3900 lbs of sand w/o a pressure increase. Pumped only 12 bbl of slurry when problems with surface lines developed. c) Pumped a third slurry of 12 bbl w/4500 lbs of sand to a screen out. Shifted to the squeeze position at 500 psi then pumped until a sand-out of 1500 psi. Released from packer and attempted to reverse out but could not. POOH and layed down the tail pipe then TIH w/cross-over tool and latched back into the packer. Tested backside to 1000 psi. 7-27-82 7-28-82 7-29-82 7-30-82 7-31-82 8-1-82 8-2-82 8-30-82 Mixed up and pumped a 10 bbl slurry w/3250 lbs of sand. Sandout occured after displacing 3/4 of the tubing volume. Pressured up on the pack five times to 1500 psig with decreasing bleed-off each time, resulting in a final bleed-off pressure of 700 psig. Released from packer and attempted to reverse circulate but could not. Waited for 2½ hours to allow the gel to break then stung back into the packer and was able to pump away with 200 psi. Mixed and pumped a 4 bbl slurry w/1250 lbs of sand. Sanded out at 3/4 displacement then pressured up on the pack to 1200 psi 10 times, while allowing the pressure to fall off to 300± psi each time. The final bleed-off was very slow below a 1000 psig and leveled at 600 psig. Released from packer and reverse circulated after gravel packing. Waited on the pack for 25 hours then stung back into packer and tested the pack. Pressure increased to 800 psi almost immediately with a slow bleed-off to 300 psig. POOH and layed down the workstring. TIH w/2 3/8" x 2 7/8" tapered workstring and tagged fill at 3174'. Cleaned out sand to 3269'. Sand was mostly gravel pack sand w/trace of formation sand. With the tapered workstring in the hole (tapered workstring was run to allow adequate clearance inside of blank and screen) the well was changed over to fresh water. Well began to flow w/2-15 psig surface pressure at 6 BPH. The fluid weight gradually increased w/a resulting decrease in rate. (chlorides were 9-10 M) The well was swabbed from 700-1000' @ 22+ BPH w/returns weighing 8.5-8.6 ppg. TIH and tagged sand at 3034' then reversed out to 3280' (DPM). Returns were predominantly gravel pack sand with a trace of formation sand. It was believed that the sand had to be coming from the cross-over ports, so the Dowel] shifting tool was re-run after killing the well. The indications were that the sliding sleeve was not closed. Sleeve was closed with the shifting tool. POOH. RU and swabbed the well from 1000'. Swabbed 250 bbl then TIH and tagged at 3276' (DPM) - 4' of fill. PU and swabbed an additional 267 bbls. TIH and tagged fill @ 3275' (DPM) reverse circulate out sand to 3280'. Killed the well w/8.8 ppg KCL brine. POOH laying down. Bull-headed 150 bbls of diesel into casing (2059'). Began RD. Finished rigging down and released rig. Rig up crane and run Gould turbine pump and 585' of 4%" tubing. Rig down and prepare surface equipment for injectivity test. CONFIDENTIAL .! MEMORANDUM State of Alaska ALASK~OIL AND GAS CONSERVATION COMMISSION C. V/~,~rton ToC. V Thru: Lonnie C. Smith 7~0 Commissioner FROM. Michael T. Mindef//~ Petroleum Engineer DATE August 4, 1982 FILE NO' 108/L TELEPHONE NO SUBJECT Plug and Abandonment of Lo~r Well Bore on Conoco's Milne Point Well No. B-1 Sec. 19, T13N, RllE, UM Sunday, July 18,_ 19_82 - I witnessed the tagging of the previ0uSly set cement retainer at a depth of 3,339' with 10,000 pounds and the subsequent placing of a 20 sack cement plug on top of said retainer. The cement ~as in place at 4:00 p.m.; at 4215 a.m. the next morning the top of the plug was tagged at 3,289', but would only support 4,000 pounds. I left B-Pad at 9:00 a.m. on July 19, 1982 to accompany Ed Sipple on an inspection of reclaimed well sites in the West Sak a rea. On a fo1 low-up phone e~n~rsation with Mr. Terry Lucht of Conoco July 26, 1982: the plug was tagged again at 6~00 p.m.~on July 19, 1982 (the cement having set up) and the top confirmed at 3,289'. On July 21 an EZSV retainer was set at 3,280' and the gravel pack assembly is now in p lace. I filled out the A.O.G.C.C. Plug and Abandonment Reort along with a well bore sketch which is attached. In summaz~, I witnessed the abandonment plug for zone below 3,289' in Conoco's Milne Point B-1 well located in Sec. 19, T13N, R11E, UM. 02-001,A(Rev.10/79) Or.G ~6 4/8o Operator STATE ~l,' ALASKA ALASKA OIL & GAS C' IISERVATION COMMISSION ( Plug & Abandonment Repo( Date Well No. - I Company Repr Lease No. Total Depth ~_~ Elevation ~ /~,~ Drilling Permit # ~0- 7~ Sec. T-~ /? -/,,~N --//z~- Mud Wt., Casing: Drive Pipe "O.D. Set at · Conductor ~0 "O.D. @ .... ~O Intermediate Ft. w/ Pete. Ft. Surface ]~3/~ "O.D. @,, ~$~_~. Ft. Ft. ~,, . 7 "O.D. @ $3q~ Ft. Plugging Data: 1. Open hole plugs: 2. Open hole isolation plug: 3. Perforation plugs (if any) 4. Annulus plugs (if any): 5. Casing stub plugs: /~ 6. Surface plug: /VA Casing removal:, "casing cut at ' "casing cut at ' "casing cut at ' wi~ /~.~o¢ ~' ~ a~ .¢~. ~,-~~ ~o7~ i,,'W~-J . o~ ~~ . ~o~ ~ ~ - ~,-~-~: ~" d" ' / . I II - ' I '~ . /- .} , /. j Inspector/s: ~.~~' ,1' · Conoco Inc. 2525 C Street State 100 Anchorage, AK 99503 July 8, 1982 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Enclosed are the original and two copies of a Sundry Notice for Milne Point B-1. This Sundry Notice shows our general procedure for abondon- ing the lower completion and gravel packing two water sands in Well B-1. These water sands will be used as a water source during an injectivity test we have planned for the beginning of August. If you have any questions concerning our plans for Well B-l, please contact either Don Girdler or Gary Merriman at 279-0611. Yours very truly, G. A. Merriman Supervising Production Engineer kp Enclosure L - $ I96'2, Gas Cons. oommismon A~Chor~ge SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER C[]X 2. Name of Operator 7. Permit No. Conoco Inc. 80-75 3. Address 8. APl Number 2525 C Street Suite 100, Anchorage, Alaska 99503 5o-029-20490 4. Location of Well 214' FNL and 4235' FEL of Sec. 19, T13N, R11E, UM 5. Elevation in feet (ind,cate KB, DF, etc.) 46' KB 6. Lease Deslgnat,on and Serial No. ADL 47438 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point B-1 11. Field and Pool Kuparuk Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [-i Alter Casing [] - Perforatmons [] Altering Casing ~] Stimulate [] Abandon [] Stimulation [] Abandonment I-1 Repa,r Well [] Change Plans I'-I Repamrs Made [] Other [] Pull Tubing [] Other )~ Pulling Tubing [] (Note Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Descrmbe Proposed or Completed Operatmons (Clearly state all pertmnent detads and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170). Plans are to re-enter and clean-out the "B-i" well then gravel pack the shallow water sands. "B-I" well is currently inactive. Estimated startup date July 14, 1982. Procedure: 1) Miru workover rig and install BOP's 2) Drill out 9 5/8" casing to top of 7" liner (3348'). Permanently abandon the lower portion of the hole by setting a 100' cement plug on top of the 7" bridge plug at 3800 Set a 9 5/8" bridge plug above the 7" liner at 3280'+. 3) Wash perforations (3102' - 3157', 3196' - 3266') with wash tool. 4) RIH with a gravel pack assembly. Set gravel pack packer at 2850'+_. 5) Gravel pack the water sands with 20-40 gravel pack sand. 6) Flow the well to clean it up. Kill the well with NACL Brine. Secure the well. 7) Once downhole pump is ready, rig down tree and using a crane, lower the downhole pump on 4 1/2" tubing to 600'. Nipple-up tree and flowline. 8) Use the downhole pump to provide water for the Milne Po~r~C~l~rE~jection Project. ...... t ¥\7c~--'k Repoz'tecl (;m yo~sn ~o. J U L - 8 1982 Alaska 0il & Gas Cons. Comrrij$$Jorj Anchorage 14. I hereby c~t~fy that the foregoing ~s true and correct to the best of my knowledge. Th~ ~ I r Commission u~e Conditions of Approval, ~f any ~.~ proved Cop~ Approved by BY tO)~HiE G. SMIT~I . COMMISSIONER Rcturned 8¥ Order of the Commission Date Form 10-403 Rev. 7-1 Submit "Intentions" mn Trlpl,cate and "Subsequent Reports" ~n Duplicate · ....~cr' zoo' 7" q~o soo- 34::¢/0! / -\ $Z85'____ ~ ~oo0 ~ J~F Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 May 10, 1982 Mr. Lonnie Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: SUBJECT: MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Attached are the subject reports for the month of April. Very truly yours, W. M. Haskell Administrative Coordinator SHB/kr Attachments cc: Working Interest Owners, w/Attachments STATE OF ALASKA CL ALASK/~ ,L AND GAS CONSERVATION ¢IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drdhng well [] Workover operatlon~[~ 2 Name of operator Conoco Inc. Anchorage, AK 99503 3 Address 2525 C Street, Suite 100 4 LocatIon of Well atsurface 214' FNL, 4235' FEL, Sec. 19, T13N, RilE, UM 6 Lease Demgnat~on and Semal No A~T, A74~R 5 ElevatIon ~n feet (~nd~cate KB, DF, etc ) 46' KB 7 Permit No. 80-75 8 APl Number 5o-029-20490 9. Un,t or Lease Name Milne Point Unit 10 Well No Milne Point B-1 11 F,eld and Pool Kuparuk River Field Kuparuk Pool For the Month of April ,19 82 12 Depth at end of month, footage drdled, hsh~ng jobs, d~recttonal drdhng problems, spud date, remarks Ail work on this well has been temporarily suspended since March 7, 1982. 13 Camng or hner run and quantities of cement, results of pressur9 tests 14 Comng resume and brief descmpt~on 15 Logs run and depth where run 16 DST data, perforating data, shows of H2S, miscellaneous data RECEIVED MAY 1 Al.~sl<a 0il & Gas Cons~ C0mmmsion Anchorage 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge SIGNED~ TITLE Drlg. Superintendent DATE May 10, 1982 NOTE--Report on th~s form m required for each calendar month, regardless of the status of operations, and must be fded m duphcate w~th the Alaska Od and Gas Conservation Commission by the 15th of the succeeding month, unless otherwme d~rected Form 10-404 Submit ~n duphcate Rev 7-1-80 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 April 27, 1982 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are two copies of the subsequent Sundry Notice on perforating and testing Milne Point B-1. This work was approved by the OGCC on January 14, 1982. If you have any questions, please call either Jim Fox or me at 279-0611. Sincerely, , /G. A. Merriman Supervising Engineer kr Enclosures REC IYED APR 2 81982 A!aska 0il & Gas Cons. Commission Apchorag9 STATE OF ALASKA ALASKA (_ AND GAS CONSERVATION C~ ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] COMPLETED WELL r-I OTHER 2 Name of Operator 7. Perm,t No. Conoco Inc. 80-75 3. Address 8. APl Number 2525 "C" Street, Suite 100, Anchorage, Alaska 99503 5o-029-20490 4. Locat,on of Well 214' FNL and 4235' FEL of Sec. 19, T13N, RllE, UM 5. Elevat,on ,n feet (,nd,cate KB. DF, etc.) 46' K.B. 12. Lease Deslgnat,on and Serial No. ADL 47438 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point B-1 11. F,eld and Pool Kuparuk Fi eld Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit ,n Duphcate) Perforate I--I Alter Casing [] - Perforat,ons [] Altering Casing Stimulate [] Abandon [] Stimulat,on [] Abandonment Repair Well [] Change Plans [] Repa,rs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13 Descr,be Proposed or Completed Operat,ons (Clearly state all pertinent details and give pertinent dates. ,nclud,ng estimated date of start,ng any proposed work, for Abandonment see 20 AAC 25 105-170) Milne Point No. B-1 was re-entered on February 32, 1982, to test shallow water sands. The following procedure was used' a) Displace diesel from 2000' to surface with 9.2 ppg. KC1 brine. Make a scraper trip to the liner top at 3348'. b) Run a Gamma Ray /CCL log from 3400' to 2000'. Set an EZSV retainer at 3340'. c) Perforate and squeeze the following intervals' Perforation Depth 4 holes @ 3285' 4 holes @ 3190' and 4 holes @ 3090' 4 holes @ 2951' and 4 holes @ 2888' Estimated Cement Into Formation Set EZSV retainer @ 3190' and squeeze holes with 67 sks. of Class "G" (w/additives). Set EZSV retainer @ 3100' and circulate squeeze 166 sks. of Class "G" (w/additives) from 3190' to 3090'. Bradenhead squeeze 49 sks. of Class "G" cement into perforations at 3090 Set EZSV retainer @ 2937' and circulate squeeze 86 sks. of Class "G" (w/additives). Attempt to Bradenhead squeeze per- forations at 2888'. Drill out cement/retainers and pressure test squeeze perforations. 14 I hereby/~,fy that the foregoing ,s true and correct to the best of my knowledge S,gned Title ~'~//-[J/~¢ The Io r Commission use Con~t~ons of Approval. ~f any Date APN 2 8 Approved by COMMISSION~I~~ the Co~"~J9 Date Form 10-403 Rev. 7-1 ~0 Subm,t "Intentions" ,n Tr,pl,cate and "Subsequent Reports" ,n Duphcate Fage 2'. ( ( CONFIDEI rL L Set [ZSV retainer @ 3043' and resqueeze perforations @ 3087' with ]8 sks. of cement. Bradenhead squeeze 49 sks. cement through perforations at 2979'. Drill out cement/retainers to 3340' and pressure test squeeze perforations. d) Perforate casin9 from 3266' to 3]96' with a shot density of ]2 jspf. e) Run D.S.T. too] in hole and set packer at 3082~. Swab in we]] and test production. Puli D.S.T. too] out of hole. f) Run in, set, and test EZSV retainer at 3187'. Perforate casing from 3157' to 3102' with a shot density of 12 jspf. g) Run D.S.T. tool in hole and attempt to swab test. Downhole shut-in valve failed and D.S.T. tool was pulled out of the hole. Run D.S.T. tool in hole and set packer at 3020'. Swab in well and test production. Pull D.S.T. tool out of hole. h) Run in, set, and test EZSV retainer at 3065'. Perforate casing from 2936' to 2903' with a shot density of 12 jspf. i) Run D.S.T. tool in the hole and set packer at 2800'. Swab in well and test production. Pull D.S.T. tool out of hole. j) Run in and set EZSV retainer at 2905'. Spot 1000 lbs. of 20/40 mesh sand on top of plug and pressure test plug. k) Displace top 2000' of hole with diesel fuel. Well flowing. 1) Displace hole with 8.9 ppg KC1 brine. Well dead. m) Run in and set EZSV retainer at 2000' and test. n) Displace hole with diesel. O) The rig was released on March 7, 1982. Conoco requests that the well be considered temporarily suspended as of March 7, 1982. STATE (JF ALASKA ALASKA('. AND GAS CONSERVATION C(~ ,MISSION ~ MONTHLY REPORT OF DRILLING AND WORkOVER OPERATIONS Dr,ll,ng well [] Name of operator Conoco Inc. Workover operation [~ 7 Permtt No 80-75 4 Locat,on of Well atsurface 214' FNL, 4235' FEL, Sec. 19, T13N, RllE, UM 3 Address 8 APl Number 2525 C Street, Suite 100 Anchorage, AK 99503 50- 029-20490 9 umt or Lease Name Milne Point Unit 16 LeaseADL D~n~on and Sertal No March 82 For the Month of , 19~ 5 Elevation ~n feet (~nd,cate KB, DF, etc ) 46' KB 10. Well No Mil ne Point B-1 11 Fmeld and Pool Kuparuk River Field Kuparuk Pool 12 Depth at end of month, footage drilled, hshlng jobs, dmrectmonal drlllmng problems, spud date, remarks Tested well - results to follow on final report. Rig released on 3/7 and moved to Hilne Point B No. 2. 13 Casing or I~ner run and quantities of cement, results of pressure tests Set EZSV plug at 2905' and dumped 1000 pounds of 20/40 sand on top of plug. 14 Conng resume and brief description None 15 Logs run and depth where run None ,16 DST data, perforating data, shows of H2S, miscellaneous data Perfs' SPF From To 2 9,32 1 2 2903' 2936' Ataska Oi~ & Gas Cons~ C0mrnis~iot A~ch0rag~ 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge .~4¢,/~. ~~~,_~p g Prod. Eng. ~/_~/~' SIGNED TITLE Su_ervisin_ DATE R~rt on t~ls /' .... NOTE-- form ~s required for each calendar month, regardless of the status of operations, and must be fded m duphcate w~th the Alaska Od and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise d~rected Form10-404 AFE ]745 A0 & GCC (2) ~I0 Submltlnduphcate Rev 7-1-80 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drdl~ng well [] Workover operatlon~ ~ ~// 2 Name of operator Conoco [nc. 3 Address 2525 C Street Suite 100, Anchorage, Alaska 99503 4 Location of Well at surface 214' FNL, 4235' FEL, Sec, 19, T13N, RILE, UM 5 Elevation m feet (~ndlcate KB, DF, etc ) 6 Lease Designation and Serial No 46' KB ADL 47438 7 Permit No 80-75 8 AP) Number 5o-029-20490 9 Unit or Lease Name Milne Point Unit _ 10. Well No Milne Point B-1 11 F~eld and Pool Kuparuk River Field Kuparuk Pool February For the Month of. 82 '12 Depth at end of month, footage drdled, fishing jobs, d~rect~onal drdhng problems, spud date, remarks DST results will follow on final report 13 Casing or hner run and quant.t.es of cement, resq~l~f, pr~j~i~d Cement sqz. on perfs' (1) (2) (3) (4) (5) 67 (6) Production perfs 166 (7) Production perfs 49 86 po[ 125 sks. cmt. f/2937'-2564' attempt Bradenhead sqz - 0 ~ooa. ' ' 14 Coring resume and brief description 15 Logs run and depth where run Logs- From To GR-CCL 3400' 2000' 16 DST data, perforating data, shows of H2S, miscellaneous data Perfs' SPF (1) 4 @ 3285' (6) (2) 4 @ 3190' (7) (3) 4 @ 3087' /45/ 4 @ 2951' 4 @ 2888' 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge SPF From To 12 3196' 3266' 12 3102' 3157' Tested sqz. perfs. - OK Tests DST DST Drilling Supervisor DATE NOTE--Report on th~s form ~s required for each calendar month, regardless of the status of operations, and must be filed ~n duplicate with the Alaska Od and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise d~rected Form 10-404 Submit m duplicate Rev 7-~-8o AFE 1745 A0&GCC (2) Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 January 11, 1982 Mr. L. C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 995013192 Dear Mr. Smith: Enclosed are three copies of a Sundry Notice indicating our plans to test some water sands in Milne Point B-1 to evaluate their potential use for a water source. If you have any questions, please call Gary Merriman at 279-0611. Very~rul? yours, H. D. Haleyv Manager of Alaskan Operations GAM/kr RECEIVED Alaska Oil & Gas Cons. Anchorage ' STATE OF ALASKA O~ ALASKA ,_ AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL [] OTHER 2 Name of Operator CONOCO I NC. 3 Address 2525 "C" Street, Suite 100, Anchorage, Alaska 99503 4 Locat,on of Well 214' FNL and 4235' F£L of Sec 19, T13N, Rll£, UM 5 Elevation ~n feet (~nd~cate KB, DF, etc ) 46' KB Lease Des,gnat,on and Ser,al No ADL 47438 7. Perm,t No 8fl-75 8. APl Number 50- 029-20490 9. Un,t or Lease Name Milne Point Unit 10. Well Number Milne Point B-1 1 1. F~eld and Pool Kuparuk Field 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO ,SUBSEQUENT REPORT OF: (Submit m Tr~plmate) (Submit ,n Duplmate) Perforate [] Alter Cas,ng [] . Perforat,ons [] Altenng Casing D Stimulate [] Abandon [] Stimulation [] Abandonment I'-1 Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tub,ng [] Other [~ Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each complet,on ) 13 Descr,be Proposed or Completed Operat,ons (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud,ng estimated date of starting any proposed work. for Abandonment see 20 AAC 25 105-170) Plans are to re-enter Milne Point B-1 and test shallow water zones. Milne Point B-1 is suspended at this time. Procedure: 1) MIRU workover rig and install BOPE. 2) Displace the hole with 9.2 ppg KCl water. 3) Run a retrievable bridge plug and set at 3340'+. 4) Block squeeze above and below test intervals using 100 sacks of Class 'G' w/l% D-60, 2% S-l, and 0.2% D-46. Intervals to be tested are as follows: I - 3196' to 3266' MD II - 3102' to 3157' MD III - 2903' to 2936' MD 5) Perforate the test intervals with 4" casing guns and 12 jet shots per foot. Each zone will be perforated and tested separately. 6) After each zone has been tested abondon the zones with 100_+ sacks of Class 'G' with 1% D-60, 2% S-l, and 0.2% D-46. (AOGCC representative may want to witness plug hardnes 7) After the final test zone has been abandoned displace the upper 2000' of 9-5/8" casing with diesel and RDMO the workover unit. I E££1VED Approximate starting date: January 20, 1982 J AN 1 ~ 1982 14 I hereby cert,fy that the ~orego,ng ,s true and correct to the best of my knowledge S,gned I ...- .... _ T,tle Manager of Alaskan Operation6ate The space be ow ' Co ss o Conditions of Approval. ~f any Approved by ORIGINAL SIGNED BY LOflNIE C. SMITH 1-11-82 Approval Copy Subsequent Work Beported ,,,mod on Form No./.~Dated /_ BV O~dui of COMMISSIONER the Comm,ss,on Date Form 10-403 Rev 7-1-80 Su bruIt "I ntent,ons" in Tr,phcate and "Subsequent Reports" ~n Duphcate AC STATE OF ALASKA (~ ALASK ,L AND GAS CONSERVATION CO~, .vllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL [] OTHER r~ Suspended 2 Name of Operator 7 Permit No Conoco, Inc. 80-75 3 Address 8 APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 5o-029-20490 4 Location of Well 214' FNL, 4235' FEL, Section 19, T13N, RIOE, UM 5 Elevation ~n feet (~nd,cate KB, DF, etc ) 46' K.B. 12 Lease Designation and Serial No ADL-47438 9. Umt or Lease Name Milne Point Unit 10 Well Number ~---/ Milne Point 1 1 F~eld and Pool Wildcat Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF. (Submit ~n Tr~phcate) (Submit ~n Duplicate) Perforate [] Alter Casing [] . Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tub,ng [] Other ~ f~ Pulhng Tub,ng [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent details and g~ve pertinent dates, ~ncludlng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Conoco proposes to change the well number for Milne Point Number 2 (API Number 50-029-20490) to Milne Point Number B-1. RECEIVED Cons. Corn,,,,.._, · ~,~'norage ..... 14 I hereby~fy~ego~ng,~ ,s true and correct to the best of my knowledge S,gned -~ZJ/~/~_~.~ T,tle Manager of Alaskan Operations The space below for Comm,ss~on use./ Date 11-13-81 Conditions of Approval, ~f any Approved by. Approved -opy Returned COMMISSIONER the Commission Form 10-403 Rev 7-1-80 Submit "Intentions" in Trlphcate and "Subsequent Reports" in Duphcate ALASKA OIL AND GAS CONSERVATION COMMISSION J,4Y S. HAMMOND, GOVE/INOR 3001 PORCUPINE DRIVE ANCHORAGE.ALASKA 99501 TELEPHONE (907) 279- 1433 September 25, 1981 Senior Production Engineer Conoco, Inc. 3201 C Street, Suite 403 Anchorage, Alaska 99503 I am sorry to report that the core chips you suhnitted frcm the subject well are of insufficient size to provide adequate record of the sed/ments penetrated. Although, with serene exceptions such as noted below, you did submit a chip frcm each foot of recovered oore, the problem is in the size of the chips suhnitted. You provided 0nly "d/me"-size chips. What the C~ssion requires, and what most operators provide are "silver- dollar"-size chips. That's pretty m~h standard geologic practice. ~cordingly, at your earliest convenience, it is respectf~ly requested-- % that you suhnit adequately sized core chips frcm each foot of recovered ] that you report 60' recoveries frcm both cores 5 and 6 cut frc~ 7235 '-7295' and 7295 '-7355', respectively. H~er, the chips frcm cores 5 and 6 that we received May 15th cover only the interval 7277' to 7344'. Please be sure that all such gaps are covered in the newly submitted core material. Also, please clearly label the boxes, envelopes and/or bags containing the core material. The boxes and envelopes in the previously sutanitted shi[m~ent were inadequately labeled. It was only with considerable detective work that we were able to interpret from what well the material actually originated. Thank you for remedying the problem of providing adequately sized core chips. Sincerely, William VanAlen Petroleum Geologist Conoco lng. 3201 C Street Suite 403 Anchorage, AK 99503 May 7, 1981 William VanAlen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Completion Data and Reports Milne Point No. 2 - Permit No. 80-75 API# 50-029-20490 Status - Suspended Dear Mr. VanAlen: This report includes data required by the Alaska Oil and Gas Conservation Commission as stated in OGCC regulations. Accompanying this/report are the following materials: tf'&~l) 1 blueline and 1 sepia of all electric and electric and radioactive logs. 1 lis tape containing raw data from logging operations. 1 blueline and 1 sepia of the mud log. Core chips from all cores taken (one chip per foot) We wish to hold confidential as much information as possible, as per regulation 20AAC 25.537. If you have any questions, or if additional data is needed please call me at 279-0611. Sincerely ar~y A.~ e~ Senior ~roduction Engineer P, ECEIVED Alaska Oil & Gas Cons. Commission Anchorage WELL COMPLETIOi I i CONSERW ION ,ISSION ) RECOMPLETION IIEPORT AND LOG 1 Status of Well Classification of Serwce Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number Conoco Inc. 80-75 3 Address 8 APl Number 3201 "C" St. Suite 403 Anchorage, Ak 99503 50-029-20490 4 Location of well at surface ii 9 Unit or Lease Name 214' FNL and 4235' FEL of Sec. 19, T13N, R~E,UM Milne Point Unit _ At TOp Producing Interval 10 Well Number //~ (,4/ ~1~./ N/A At Total Depth ~ 11 Field and Pool 1427' FNL and 4092' FEL of Sec. 19, T13N,R~E, OM 5 Elevation in feet (red,cate KB, DF, etc ) 6 Lease Designation and Serial No 46' KB ADL 47438 Wildcat 12 Date Spudded 13 DateT.D Reached 14 DateComp,Susp orAband 15 Water Depth, ~f offshore 116 No of Complet~ons 1/4/81 3/2/81 Ma~ 5,-198~ N/A feetMSLI N/A , 17 Total Depth (MD+TVD) 18 Plug 8ack Depth (MD+TVD) 19 D~rect.onal Survey I 20 Depth where SSSV set 21 lh~ckness of Permafrost 9635' ,. 9439TV]) 3800' , TVD~ YES~ NO[],I N/A feetMD 1800-+' 22 Type Electric or Other Logs Run DIL/SFL/GR; BHC/GR; LSS; FDC/CNL; HDT. 23 CASING, LINER AND CEMENTING RECORD sETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94 F.-40 0 105' 26" Cement to surface O' L3-3/8" ?2 N-80 0 2635' 17½" 4000s× Arctic Set TT O' 9-5/8" 4? 500-95 0 7617' 12½" 99? s× Self Stress 0 7" 29 N-80 74 9630' 8½" 230 sx Self Stress ' 0' , Continuation )f casir, g and liner dat.a on page 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD N/A interval, size and number) SIZE DEPTH SET (MD) PACKER sET (MD) N/A See pg 2 - Test Perforations 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ,,, See page ... -I 27 PRODUCTION TEST - See pg. 3 - 'Test D. ata Date F~rst Production I Method of Operation (Flowing, gas I~ft,, etc ) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GA$-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ I Flow .Tubing Casing Pressure cALCULATED OIL-BBL GAS-MCF WATER'-BBL OIL GRAVITY-APl (corr) Press 24-HOUR RATE I~ 28 CORE DATA Brief description of Iithology, porosity, fractures, apparent dips and presence of od, gas or ware r Subm,t core ch,p~ E C ~ i %, ~. D See page Nos. for Core data (Note - No recovery on Core .#9)MAY Al?.ska 0il & Ga~ C,~,~. C0~m~ssf0.~ Anchorag9 ..... Form 10-407 Submit ~n duphcate Rev 7-1-80 CONTINUED ON REVERSE SIDE Page 1 of 3 29 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and grav,ty, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase Prince Creek 3840' 3800' See pg. ~ Middle Kup 7168' 6974' Lower Kup 7389' 7195' Sag River 9318' 9067' Sadlerochit 9472 ' 9272 ' 31 LIST OF ATTACHMENTS 32'. I hereby certify that the f°regolng is true and correct to the best of my knowledge S~gned . T~tle Senior Productb~ / Enqin~r 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 ~s used as'refer, ence (where not otherwise shown) for depth measurements given in other spaces on this form and in a~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. Milne Point No. 2 ~ Well Completion or Recompletion Report and Log continued 27. TEST DATA Test Number 1 B 2 3 3 A Date of Test 3/20/81 3/27/81 Method of Operation DST F lowing 4/23/81 4/1/81 Diesel & Diesel & Nitrogen Nitrogen lift lift Hours Tested 12½ 39 29½ 21 Flowing Tubing Pressure, psig 0-2 195 Casing Pressure, psig Produced Oil,bbl 5 0-100psig 0-100psig 0 0 0 0 1110 40+ 33 Produced Gas,MCF --- 389 Produced Water,bbl 7 0 327 0 Choke Size --- 1-3/8" GOR --- 350 Flowing BHP, psig 647-961 2200-3020 976-1411 600-1033 Final Buildup Pressure 2289 3222 1573 1157 Maximum Rates: BOPD 10 1900 30± 55 BWPD 14 0 266 0 Gas, MCFD --- 665 Oil gravzty, °API 35° 22° ~ EI~ :n-~,~ MAy 1 5 ISSI Alaska Od a Gas Cop3. Anchorage Page 3 of 3 Milne Point No.2 ( Well Completion Report and Log continued 23. Casing, Liner and Cementing Record (cont.) Casing Wt. Per Setting Depth, Md Hole Size Ft. Grade Top Bottom Size Cementing Amount ' Record 'Pulled 7" 29# N-80 3348' 3895' 8½" 125 Sx "G" w/l% D-60 , 2% CaC12, 0.2% D-46 4½" 9.5# J-55 3760' 3959' 12" Wire Wrapped 47' screen - gravel packed w/20-40 sand 24. Test Perforations Test Perforations: Test #1 - 9270' to 9300' (30') 12 jspf at 90° phasing. Test #2 - 7188' to 7214' (26') 12 jspf at 90° phasing. 26. Cement Squeeze Squeeze #1 - Squeeze 7" liner lap with 300 sx of Class G w/ 0.75% D-65, 0.15% D-13, and 0.3% D-46. Test to 3500 psig. Squeeze #2 - Abandon perforations from 9270' to 9300' - Pump 100 sx of Class G neat into perforations and 50 sx of Class G neat on top of cement retainer set at 9240' . Squeeze #3 - 4 holes at 4530'. Squeeze w/200 sx of Class G with 1% D-60, 2% S-2, and 0.2% D-46. Squeeze #4 - 4 holes at 4395'. Squeeze w/200 sx of Class G with 1% D-60, 2% S-2, and 0.2% D-46. Squeeze #5 - 4 holes at 3965'. Squeeze w/200 sx of Class G with 1% D-60, 2% S-2, and 0.2% D-46. Cement RTTS packer and 4 joints of drillpipe in the hole. Squeeze #6 - Shoot 4 holes at 2000'. Squeeze with 150 sx of Dowell Arctic Set II cement followed by 100 sx of Class G w/3% CaC12. (Arctic Pack job). Squeeze #7 - 4 holes per foot from 3867' to 3869'. Squeeze R~C~IV~.D with0.2% D-46200 sx. of Class G with 1% D-60, 2% S-l, and MAY Al.~ska Oil & Gas Cons. Commission Anchor~cj~ Page 2 of 3 WELL HISTORY MILNE POINT NO. 2 - CONOCO, et al API# 50-029-20490 DATE OPERATIONS 12/16/80 to 1/3/81 1/4/81 1/4 to 1/8 1/9 to 1/12 1/13 to 1/18 1/18 1/19 1/20 1/21 1/22 1/23 to 1/28 1/29 1/30 Move in and rig up drilling rig and support facilities. Set conductor pipe (20", 94~, H-40) at 105' KB. Spud well at 0900. Drill 17½" hole from conductor shoe to 2635'. Run the following logs from surface to 2637' (WLM) : SP/GR/ Dual Induction/SFL/BHC. Attempt to run LSS/ GR - Misrun. Shot 16 sidewall cores recovering only one at 2147' (WLM). Run 13-3/8", 72#, N-80, BTRS, surface pipe to 2635' and cement with 4000 sx of Dowell Arctic Set II (15.0 ppg). About 150 barrels of cement was return- ed to the surface with good circulation throughout the j ob. Drill and Dyna-drill 12¼" hole from 2635' to 3925' building hole angle to 22.5°, S17.5OE. Core #1 - Core from 3925' to 3938' (jammed barrel). Recovered 11' of 4" core. Core #2 - Core from 3938' to 3966'; recovered 28' of 4" core. Dril,1 from 396,6 to 4197'.~C°re #3 - Core from 4197 to 4226 ; recovered 15' of 4" core. Drill from 4226' to 4480' and log as follows: SP/ IND - 4458' to 2626', GR/FDC/CAL - 4430' to 2626, shot 40 sidewall cores - recovered 23. Drill from 4480' to 4550'. ~pre #4 - core from 4550' to 4571'; recovered 18' 4" core. Drill from 4571' to 7000' dropping angle from 23°, S14°E to 4.25° S 24°W. Run Dual Induction/SFL/GR from 6989' to 2630'. Drill from 7000' to 7235'. MAY 1 5 1 81 ,:.,.,!:'s:~a 0,I & Gas Cons. Commission AnChorage Page 1 of 6 WELL HI STORY MILNE POINT NO. 2 1/31 to 2/4 Core #5 - Core from 7235' to 7295'; recovered 60' of 5¼" core. Core #6 - Core from 7295' to 7355'; recovered 60' of 5¼" core. Core #7 - Core from 7355' to 7415'; recovered 60' of 5¼" core. Core #8 - Core from 7415' to 7475'; recovered 40.5' of 5¼" core. Core #9 - Core from 7475' to 7535; No recovery. 2/4 to 2/9 2/10 to 2/11 2/11 to 2/15 2/15 to 2/20 2/21 to 2/26 2/27 to 3/1 3/2 to 3/4 Drill 12¼" hole from 7535' to 7600'. Ran the foll- owing logs: FDC/CNL/GR - 7600' to 3900'; DIL/SFL - 7600' to 6400'; BHC/CR - 7600' to 2635'; LSS - 7600' to 2635'; Dipmeter - 7600' to 2635'. Ran RFT at selected intervals. Shot 81 sidewall cores and recovered 65. Drillto 7625' and run 9-5/8", 47#/ft, 500-95, BTRS casing with shoe at 7617'. Cement around shoe with 580 sx of Dowell ~elf-Stress cement w/l% D-60, 0-2% D-13, and 0.2% D-46. Open stage collar at 5033' and cement with 417 sx of Dowell Self-Stress cement w/ 1% D-60, 0.2% D-13, 0.2% S-l, and 0.2% D-46. Clean and drill out cement to the float and test the casing to 4000 psig. Attempt to circulate in arctic pack and permafrost cement in the 13-3/8" x 9-5/8" annulus through FO tool at 2500'. Drill out shoe and drilled an 8½" hole to 7655'. Drill from 7655' to 8358'. Once again, attempt un- successfully to pump in arctic pack through FO tool. Core #11 - Core from 9321' to 9291'; of 4" core. Core #12 - Core from 9291' to 9351'; of 4" core. Drill from 8368' to 9203' . Log as follows: Dual Induction/SFL/GR from 9180' to 7600' . Core #10 - Core from 9203' to 9231'; recovered 2~, of 4" core recovered 60 recovered 60 Drill from 9351' to 9635 Log as follows: DIL/ · SFL, BHC/GR, LSS/GR, FDC/CNL, Dipmeter from 9635' to 7600'. Shot 30 sidewall cores and recovered 26. Page 2 of 6 WELL HI STORY MILNE POINT NO. 2 3/5 to 3/7 3/8 to 3/9 3/10 3/11 to 3/14 3/15 3/16 to 3/20 Run 7", 29#, N-80, LT&C liner from 7470' to 9630'. Cement liner with 230 sx of Dowell Self-Stress cement w/l% D-60, 0.2% D-13, and 0.2% D-46. Lap broke down with pressure test at 1700 psig. Squeeze line lap with 100 sx of Class G w/0.75% D-65, and 0.15% D-13. Lap broke down again at 1700 psig. Set cement re- tainer at 7375' and squeeze liner lap with 100 sx of Class G w/ 0.75% D-65 and 0.15% D-13. Lap broke down at 2900 psig. Squeeze liner lap with 300 sx of Class GW/0.75% D-65, 0.15% D-13, and 0.3% D-46. Test lap to 3500 psig. Run gauge ring and junk basket on wireline: in 7" 29# liner.- Lost in hole. Push gaugering and junk basket to 9524'. Run CBL/VDL/CCL/GR in 7" liner and in 9-5/8" casing. Run gyro survey from 9500' to 7700'. Set bridge plug at 9350'. Perforate w/Schlumberger 4" casing gun w/12 SPF, 90° phasing from 9270' to 9300' . Run DST #lA - Sag River Formation. Tool plugged 1 minute after opening. Recovered 13 bbls of water cushion and 2 to 4 bbls of gas cut mud. 3/20 to 3/21 3/22 Run DST# lB - Sag River Formation. Open at 0613 on 3/20. Closed tool at 1857 on 3/20. Recover 13 bbls of water cushion, 13 bbls of enulsion ( 5 bbls of oil, 7 bbls of water, and 1 bbl of rathole mud). Flowing BHP - 647 psig to 961 psig. Final buildup pressure 2289 psig. Oil gravity approximately 35" API. Set cement retainer at 9240'. Pump 100 sx of Class G into perforations and 50 sx of Class G on top of retainer. Test cement plug for AOGCC representative with 1500 psig for 30 minutes. Set bridge plug at 7479'. Equalize 50 sx of Class g cement on top of plug. Tag top of cement at 7346'. Cleanout to 7364'. Page 3 of 6 WELL HI STORY MILNE POINT NO. 2 3/23 to 3/25 3/27 to 3/31 4/1 4/2 4/3 4/4 to 4/7 4/7 to 4/13 4/14/ to 4/16 Perforate with Schlumberger 4" casing guns at 12 SPF, 90° phasing from 7188 to 7214. Set Dowell Model 18 packer at 7040'. (Packer extension includes 3 Otis x-nipples). Run 3½", 9.3#, N-80, AB modified coup- ling tubing displace the hole with 10.2 ppg CaC12, water, and stab into the packer. Displace CaC12 with nitrogen to 4000'. Flow test #2 - Middle Kuparuk River Formation. Open well at 0300 on 3/27. Shut in well at 2400 on 3/28. Obtain three bottom hole fluid samples. Open well for flow at 1930 on 3/29. Final shut in at 0100 on 3/31/ Maximum rates - 1900 BOPD, 0 BWPD; GOR 350 MCF/BBL. Oil gravity produced 1110 bbls of oil in 39 hours; BHFP - 2200 to 3020 psig, FBV - 3222 psig. Run x-n lock an PX plug (OTIS) and set in packer extension nipple at 7265'. Pull seals out gf the packer and displace oil in tubing with 10.2 ppg CaC12 water. Set 9-5/8" bridge plug at 4596'; pump 5 sx of sand on top of bridge plug. Shoot 4 holes at 4530' and squeeze with 200 sx of Class G w/l% D-60, 2% S-2, 0.2% D-46. Shoot 4 holes at 4395' and squeeze with 200 sx of Class G w/l% D-60, 2% S-2, 0.2% D-46. Shoot 4 holes at 3965' and squeeze with 200 sx of Class G with 1% D-60, 2% S-2, and 0.2% D-46. Cement RTTS packer and 4 joints of drillpipe in hole. Attempt to fish and washover drillpipe and packer stuck in the hole. Fish left in hole: Top at - 3755' , Bottom a~.~t 3885' .... Mill section in 9-5/8" casing from 3487' to 3529' - Equalize 150 sx of Class G w/2% S-l, 0.75~ D-65 and 0.2% D-46. Kick off cement plug with dyna drill and drill an 8½" hole to 3897'. Run 7", 29#/ft. N-80, ~~T&~ liner. Top of li~e'~"~ @ 3348' - bottom of liner @ 3895'. Cement liner with 125 sx of Class G cement with 1% D-60, 2% CaC12 and 0.2% D-46. Shoot 4 holes at 2000' and circulate acrtic pack and 100 sx of Dowell Arctic Set I cement in 13-3/8" x 9-5/8" annulus. Cement would not hold pressure. Circulate actic pack with 100 s~ of Class G w/ 2% CaCi'2. Squeeze test would not holed pressure. ,!!'~' ~%,% ~t GS% ~gPS, ~0l~mt$$t0?iPage 4 of 6 WELL HISTORY MILNE POINT NO. 2 4/17 4/18 4/19 4/20 to 4/22 4/22 to 4/23 4/24 to 4/26 4/27 4/28 to 4/29 4/30 4/31 5/1 to 5/3 Set bridge plug at 2072' and pump 5 sx of sand on bridge plug. Pump arctic pack and 150 sx of Dowell Arctic Set II cement followed by 100 sx of Class G w/3% CaClz. Retrieve bridge plug, drill to the top of the 7" liner and pressure test liner lap and casing to 1500 psig for 30 minutes. Drill out and test liner to 1500 psig for 30 minutes. Change over mud system to 9.2 ppg KC1 water. Drill a 6" hole to 3959' and open hole from 6" to 12". Run 4½" blank liner and wirewrap screen. Top of liner at 3760' - bottom of liner at 3956'. Gravel pack using HEC polymer and 20-40 mesh gravel. Total volume of gravel pumped equaled 248% of the theore- tical pack volume. Stuck wash pipe in the hole, losing 8 joints of 2-3/8", 4.6#, 10RD wash pipe. Recovered all washpipe and clean out wirewrap screen. Run 3½" tubing and prepare to test. Test well using nitrogen and diesel to lighten the fluid column. Produced 327 bbls of water and about 40 bbls of oil in~9½ hours. Flowing BHP - from 976 - 1411; FBU - 1573 psig. Run Gamma Ray/Collar log from 3922 to 3200'. RIH and pull out 2 joints of 4½" blank liner so that the 7" shoe may be squeeze cemented. Top of 4½" liner now at 3817'. Shoot 4 shots per foot from 3867' to 3869' for cement squeeze. Squeeze holes with 200 sx of Class G with 1% D-60, 2% S-l, and 0.2% D-46. Cleanout cement and sand back inside wirewrap screen to 3933'. RIH with 3½" tubing and bundle gauge carrier. Test well using nitrogen and diesel to lighten the fluid column. Produced 33 bbls of oil; 8,~5°~ API gravity; BHFP - 600 to 1033 psig; FBU-1157 psig. Page 5 of 6 WELL HISTORY MILNE POINT NO. 2 5/4 Reverse test string and POH. RIH with a 7" retriev- able bridge plug. Set the bridge plug at 3800'. Displace upper 2000' of hole with diesel. Nipple down BOPE and flange up well cap. Status of well - suspended. Page 6 of 6 CORE NO. WELL Milne Point Unit CON D CONOCO , CORE DESCRIPTION REPORT B~%SINNorth Slope, Alaska DEPTH 3925- 3935 L'ITHOLOGY SYMBOL LITHOLOGY DESCRIPTION Generally this interval is a it to md gy very fine gr, occ md gr ss with abundant clay and probably Silt Grains are subang - sub rounded, qt zose, clr to white, possibly w/some feldspar tr mica some organic matter, including rootlets. Poorly sorted. Clay per- centage increases and decreases, sometimes suggesting bedding, othe times in a lenticular fashion. Porosity and permeability are gen- erally poor, and decrease as clay percentage increases. The clay is it. gray to it gray brown firm stick~ There are occasional rounded chert (?) pebbles. No calcite was detected in this in- terval. Cementing is due to clay in matrix and since the clay is soft the formation is easly cut or crumbled by hand. BEDDING ANGLE Bedding cuts core at an angl that is not quite perpend- icular to its long axis. Sinc wellbore is deviated, it is likely that bedding is near flat. DESCRIPTION BYt Phil Sa!avadqr AREA 19-13N-lIE SEDIMENTARY STRUCTURES This interval does not have any prominent sedimentary structures These more subtle ones were observed -Cross bedding, on a scale of 1" or 2" thick intervals,notice~ in some more silty bed -Bedding, occasionally core parts along beds, displaying organic carbanaceous material (leaves or wood?) lyin flat on bedding. Beds, where visible, appears to be on the order of 1/4" to 1/2" thick. Not especially notice- able. -Crude graded bedding in beds less than 1" high. Slight scouring possible at bases of these beds. SHOWS Entire inter- val appears to be more or less oil saturated with thicker concentra- tions in · coarse, size sand pockets. Some free dark brown oil to be seen. Fair to good oil coor Dark brown to black stain. Faint to very faint orange brown streaming . visible cut, very fast streaming bright yello% white fluor- escent cut. .) CORE NO. CO ENTU C O N'O C O CORE DESCRIPTION REPORT DESCRIPTION BY~ Phil Salvador WELL Milne Point Unit #2 BASIN North Slope, Alaska AREA 19-13N-liE 3935-3936 DEPTH LITHOLOGY SYMBOL LITHOLOGY DESCRIPTION ,, Siltstone - it. gray, very har~, very calcareous, poorly sorted, sandy in places, ab dt organic debris. BEDDING ANGLE Bedding not observed. SEDIMENTARY STRUCTURES Contact between this interval and above is severely eroded & reg- ular. Fine to md gr sand oil saturated lies in pockets on top of eroded siltstone. SHOWS Core was bleeding oil from pin poini por~.sity. No No visible cu No odor, splo chy fair yell( while fluor, bright yellow white fluor when trichlor, applied to ch .p. CORE NO. C 0 N 0 C 0 CORE DESCRIPTION REPORT DESCRIPTION BY: Phil Salavador 3938-66 WELL Milne Point Unit ~ASIN AREA North Sloper Alaska DEPTH LITHOLOGY SYMBOL LITHOLOGY DESCRIPTION Dk gray fine to v fine gr ss with silty, clayey matrix varying in middle third to clayey silt stone with abundant very fine grained sand. Poorley to very poorly sorte clr to whitish qt zone grains, trac to moderate mica, trace to mod organic debris, occassionally lying flat along bedding plane. Occ root lets. Pervasive oil coating & stain ing obscures determination of many grain lithologies.Subang to sub- rounded. Clay matrix is it gy brn, sticky. Where clay is abdt, core mo coherent,elsewhere it tends to crumble. Generally core easily cut: with knife, is harder in a few plac, Non calcareous in all places tested' BEDDING SEDIMENTARY ANGLE STRUCTURES Bedding cuts at high angle to core but not_[. Probably bedding ~, nearly horiz,i since well bore deviated. ~e -Occassional low angle cross bedding in siltie sections. -Laminations, approx 1-2mm thick, occ up to lcm. These caused by variations in coarsenes of sedimints in zone. More coarse grained zon. are cleaner, more oil saturated. In places zones of varying clean- liness appear more lent cular or splotchy. -Parting along bedding planes is very crude. -One piece with slicken side found. Location in core unknown. Slicken- side surface smooth, striated, undulating, hard. SHOWS -Pervasive oilsaturation through-out, lepending on ~leanliness. -Pops of dk ~brown oil & g bubbles seen ks sides of co while being -Fair to good - odor -Abundant sta: ing & free o: -Dim to very dull orange flour. Pervasive to patchy, depen¢ ing on distr.i- bution of coarser sand Coarser sand is ~ine gr.) .Dark amber, f streaming vis cut. -Very fast str lng bright yellow white fluor. n- st ble ~am- PAGE 1 OF.1 ....... CORE NO. CONnD CONOCO DESCRIPTION BY~ Phil Salavador , ~ELL Milne Point Unit #2A~ch0ra~o DEPTH 4197 - 4209 L'iTHOLOGY SYMBOL CORE DESCRIPTION REPORT ~ASIN LITHOLOGY DESCRIPTION Silty sandstone, md. gray very fine grained, 10-15% lithic frag,~ 5% silt. Non calcareous, medium to poorly sorted, subang to rounded. Massive, very homogeneous (minor variations in silt, extremely u~consolidated. BEDDING ANGLE No bedding obse- rved. Some part- ings in core suggested that they might be along bedding. If so, bedding is essentially flat. AREA North Slope, AK SEDIMENTARY STRUCTURES None. However, when att empting to start out with core barrel, core barrel became stuck, an it took a few minutes to pull loose. While pulling, jars went off 3 times. It is possi- bl~ that this shock may have damaged sedi- mentary structures, possibly even fluidizin the sand in the core, destroying all struct- ures. Due to extreme softness most of the core fell apart. While removing the core from the barrel, the core would often be slow to come out, so the barrel was repeatedly stuck with a sledge hammer. This may have damaged interal struct- ure. SHOWS Faint odor. No stain. Oil seen run- ning from core barrel while attemp- ting to pump core out of barrel. Very faint dull orange fluo- recence very slow faint amber visible cut very fast bright yello% white fluor cut. CORE NO. CONOCO CORE DESCRIPTION REPORT BASIN DEPTH 4550-53.9 4553.9-56 4556-59 4559-62 4562-64.5 Very Hard, gy brn Hand a~a, but with vugluar porosity begin- ning to develop. A great deal of vugular porosit5 maybe 15%. Core becoming crum- bly in places. Vugular porosit decreasing. Cor becoming harder Continuing decreasing vugs Core very hd, cannot drive .nail into it. LITHOLOGY DESCRIPTION General microscopic lithologic description. Minor variations from place to place: Dk gy brn silty, slicl~yed v f gr ss, well sorted, subang to rounded non cal~, very loose to very hard. Grains 90% gtz, trcht & mica, occ well rounded pebbles, very rare ,shell frag near base. Pervasive oil saturation has altered shell frag, makes some lith determina- tions difficult. Fair to excellent ~, mod perm? BEDDING ANGLE Bedding breaks at approx 20° angle to core. c Suggests beddin is low angle on zero dip since its deviated 23° approx. DESCRIPTION BY: Phil. Salvafor AREA, .North...~.lope, Alaska SEDIMENTARY STRUCTURES Traces of laminae, about 1-2mm thick, expressed hiefly by parting along laminae. Contact with zone below apparantly gradamonal, but takes place over only 5-10cm. SHOWS ) Abundant oil bleeding from core, partic- ularly in more vuggy zones. Gas "pops" observed. Oil is ~k brn, fairly liquid. Show intensity varies slightl with varying grain size dis tribution, but in general: Good to strong! odor, abundantl free oil, Dk blk to brown pervasive stai Fair golden yellow uniform fluor, fast dark tea color ed visible cut, very fast bright bluish yellow milky fluor cut. PAGE J OF _~ CORE NO. 4 CONOCO DESCRIPTION BY: Phil Salavador CORE DESCRIPTION REPORT 4564.5-67 WELL Mfln, Point ~Init 02 BASIN DEPTH LITHOLOGY SYMBOL LITHOLOGY DESCRIPTION Very hard silty very fine gr ss (or sdy siltstone), very calcare- ouS, contains 3-4cm long shell halves (mussel?) with original shell material. Md gry to dk brn where oil saturated. Probably leached from shell fragments BEDDING ANGLE No bedding ob- served. Core breaks ~ to core axis, sug- gesting no bedding plane weakness (No bedding do to bioturbation?) AREA North Slope, Alaska SEDIMENTARY STRUCTURES None observed. Sediment may have been bioturba- ted, but no burrowing observed. Possibly reworked by bivalves like mussels SHOWS ~o bleeding oi or gas except near upper & lower boundari, GQod to no odo good to no stain, patchy to uniform fl- uor no vis cut to slow weak tea colored & milky blue, to oright bluish yellow milky fluor cut. lt. CORE NO. CONOCO J_oF DESCRIPTION B¥~ Phil Salavado~ CORE DESCRIPTION REPORT WELL M(lnP P~(nt Tln~t ~2 BASIN DEPTH 4567- 67.9 L'ITHOLOGY SYMBOL LITHOLOGY DESCRIPTION , , Essentially a return to the litho- logy of 4550- 64.5.Very fine gr sandstone, silty, clayey, dark gy bn, firm, sli-oa~o BEDDING ANGLE None observed AREA North Slope. AK SEDIMENTARY STRUCTURES None observed. Return of vugular poros~{y Contact with zone above apparently gradational but occurs over 5-10cm. SHOWS Bleeding oil in core, good odor, perva- sive dk brn stain, free oil in sample moderate yellow fluor,. fast tea col- ored visible cut, very fast bright bluish yellow milky fluor cut. PASE / CORE NO. 5 7235 - 7295 = 60' ; Rec = 60 CONnDENTU CONOCO REPORT DESCRIPTION BY: M Bradshaw WELL Milne Point Uni~ No, 2 BASIN ~orth Slone -- AREA DEPTH 7235 7295 LITHOLOGY SYMBOL GENERAL REMARKS Upper 15' of core was bleed- ing sl. amts of oil mainly be- tween laminae and along nat- ural partings. Core was in general "oily" although only mildly so. Live oil was seen on the core and running out of the core barrel onto the rig floor during core retrieval. All the live oil seen amoun- ted to little more than 2 cup full or so. LITHOLOGY DESCRIPTION Interlaminated silty shale/siltston and v.f. gn sandstone. Shale is dk gy-blk, v. micaceous, w/abun carbonaceous material; v. silty; pyritic; w. evidence of bur- rowing (i.e. filled worm tubes) and bioturbation; tr amts small shell casts and molds; burrows are in shale and sand filled, v. low ~ & K v. large (1") oyster type shell @ 7250'. Sand is v.f. gn, sub ang-sub rnd; ¢lr-sl frosted qz gns; good brn oil stn; fairly abun mica and carbon- aceous material; sl glauc in parts; sand often fills burrows and boring in finer gn matrl. ~ & K fair w/in sand laminae. Occ lenses of f-med gn sand. *Sorting is fair to good individual laminae, but poor if rock is considered as a whole. Over all rock is v firm mdr. but will part fairly easily along laminae. BEDDING ANGLE Essentially None - near horizontal SEDIMENTARY STRUCTURES Almost entire 60' column of rock is made up of alternating lam- inae of silt and sand on a mm scale. Sand occ seen in small lenses. Laminae are very wavy and some times exhibit v.f. scale x-blg. ~arbonaceous partings Detween sand layers are common. Laminae are sometimes as thick as several cm. SHOWS Shale exhibit no fluoresc- ence or cut. fair petroleu odor v. dull orang~ flu w/yell cloudy ins - anea cut foll owed by slow streaming. V. lt. amber cut in while li . CORE NO. 6 7295-7355 = 60' R~c = 60' (59' + 1' rubb~ left on drill floor)' CONOCO .~ commi$$iOli ~ CORE DESCRIPTION REPORT PAGE 1 OF 1 DESCRIPTION BY: M. Bradshaw , WELL Milne Point Unit No, 2 BASIN North Slope DEPTH 7295 - 7355 LITHOLOGY SYMBOL eneral Comments Rock is v. firm and well indur- ated but parts fairly easily along bedding planes and laminae. LITHOLOGY DESCRIPTION Entire core consists of interlamin- ated sand and silt or silty shale. Sandstone is oil-stained dusky yell brn; v.f.-f, gn w/occ med size gns; clr- sl frosted; sub-ang-sub=nd; mostly qz, but some glauc in dk grn rndd gns; mod sorting; micaceous; carbonaceous and pyritic; occ sm shell frags; firm & sl. friable; oc¢ sl calc i/p; w/fair ~ & K. Shale is dk gy-blk; often v. silty but can vary to more blocky, massiv~ "amorphous" looking sh w/conchoidal fracture (however, this is rare); v. micaceous, often w/med gn-size flakes; abun carb material; Occ some crm color poss tuffaceous? blebs; Sh typically occurs in paper thin to a few mm wavy laminae than alt w/ss; Bioturbation is common. BEDDING ANGLE Essentially Horizontal. Laminae alter- nate in wavy and sl. contort ed bdg. w/occ small scale xbdg AREA Sec. 19, T13N, RllE SEDIMENTARY STRUCTURES Interbedded sand and silt on a mm to cm scal~ Laminae are gen. wavy & irregular w/occ small scale xbdg. Contacts between sand & shale layers are usually grad- ational but occ are ver~ sharp & distinct' Other structures include sand filled burrows & boring trails; poss excretions and evidence of Biotur- bation in gen. SHOWS Sandy laminae .exhibit brn oil stn and faint petrol- eum odor; v. dull orng flu w/yell-grn cloudy cut followed by slow streamin ;Vis wh-lite cut is v. it amber. Some live oil seen between laminae wher~ rock parts along bdg planes. Occ pops seer here and thex throughout core. g · CORE NO. 7 7355 - 7415 = 60' ;Rec = 60 ' · ,~ :'~\ C~ ,n~f,t. 6'~ ~,~0%~t°' '' CORE DESCRIPTION REPORT PAGE 1 OF 2 DESCRIPTION BY:M. Bradshaw ~ELL Milne Point Unit No. 2 BASIN North Slope, Ak AREA Sec 19t T13Nt RllE DEPTH 7390- 7402 7402- 7415 LITHOLOGY SYMBOL LITHOLOGY DESCRIPTION fairly friable-single gns can be easily dislodged w/a probe; fair- good visual ~ & K; largely frame- work w/v. little in filling mtx mat'l; less micaceous; @ 7396 - gy: brn clay layer acm or so thick; v. well indurated w/ litt fissility-blocky & massive; w/abun off-wh to crm colored clayey or poss tuffaceous "blebs showing lineations and imbrications II to bdg plane; sh does not appear as micaceous as that seen earlier in this core; still abun carb mat'l & glauc. Sandy laminae are increasing in mtx type mat'l and are becoming "dirtier" again. Essentially a return to the lithology described for 7355-7390. .e BEDDING ANGLE A/A SEDIMENTARY STRUCTURES Sand laminae incr. in thickness at expense of shale, wh/is deer. in freguency & thicknes but thin laminae of shale are still present SHOWS A/a CORE NO. 7 7355 - 7415 = 60' i Rec = 60 CONOCO PAGE 2 OF 2 DESCRIPTION BY.' M. Bradshaw CORE DESCRIPTION REPORT WELL Milne Point Unit No. 2 BASIN North Slope, Alaska AREA Sec ~9, T13N, RllE DEPTH 7355 - 7390 7390 - 7402 LITHOLOGY SYMBOL Overall rock is firm & well indurated, but will break fair ly easily along bdg or lamine. Probable Lower Kup LITHOLOGY DESCRIPTION Interlaminated sand & shale on a mm to cm scale ........ Sand laminae are v.f. -f. gn; clr- sl frosted; subrnd-subang; mod srtd qz gns; silty, glauc; pyritic; carb & v. micaceous; firm - sl. friable; gen H brn color due to oil stn on gn surface; fair ~ & K. Shale laminae are dk gy-blk; often silty & sandy; fissile; v. micac- eous & carb, often in paper thin laminae; occ sl blocky; tr amts calc material occ wh-crm; poss clay material or clay clasts in linear or imbricate arrangement.; pyritic; usually in wavy laminae a few mm to a few cm thick; bioturba- tion is common (ie sand-filled tubes & burrows etc.) Ss: dusky yell-drn (prob from oil snt) v.f. - f. gn; subrnd -subang; clr-sl frosted; fairly well-sorted; qz gns w/minor gns of rndd grn glauc & blk carb material. BEDDING 'ANGLE Essentially horiz but lamin- ae are wavy & contorted. SEDIMENTARY STRUCTURES Laminations on a small mm to cm scale; some minor x-bdg. Contacts between laminae are usually somewhat grad. but can be quite dis- tinct. Bioturbation is common; poss some small scale load castings. Sandy laminae becoming more massive (ie: a few inches to sev. feet thick) w/fewer sh lam- inae. SHOWS Sandy laminae exhibit it brn oil stn; dull ornge flu w/lt yell-grn cloudy cut followed by slow stream- ing Vis wh light cut is ~. lt. amber. faint petrol- eum odor. No vis bleed- ing or oil pops. A/A CORE NO. 8 7415-7475 = 60' Reci = 40.5' CONOCO CORE DESCRIPTION REPORT DESCRIPTION BY~ M Brad. shaw WELL Milne Point UDi~ NO, 2 BASIN North Sloper Alaska AREA sec. 19f T13N~ RllE LITHOLOGY BEDDING SEDIMENTARY DEPTH SYMBOL LITHOLOGY DESCRIPTION ANGLE STRUCTURES SHOWS 7415 - Overall core Interlaminated sand & shale on a Horizontal Interlam. layers of sand Sand layers 7455 is well indur- mm-cm scale ........ & sh on a small mm-cm show it. brn ated and break~ scale; Laminae are wavy oil stn w/v. along laminar Sand is yell-bm (from oil stn); v.f. & sl contorted w/some dull orng flu ,, planes fairly f. gn; subang-subrnd; mod. w. sorted sm scale x-bdg;Contacts and It yell- easily. Core ~clr-sl frosted; firm-sl friable- between lam. are commonlygrn cloudy cut face r'ippled loose gns easily dislodged w/probe; grad., but can be v. followed by texture caused largely qz; tr amt lt-dk grn glauc sharp. Sandy layers are slow streamin] by interlamina-gns carb; sl mic; occ w/silty mtx usually thicker & more Vis wh lite tions, mat'l;fair-good ~ & K freq. Sh layers often cut is v. it Shale is dk gy-blk; silty & sandy paper-thin, amber. i/p; firm & fissile w/abun mica; Faint petroleu often w/wh-crm clay clasts or poss Sh shows some evidence odor. tuff mat'l wh/is usually oriented of sm scale load casts, in lineations along bdg planes & &occ sm boudin-like occ imbricated; bioburbation is lenses of sand w/in the common (ie sand-filled burrows, shale. tracks & trails, etc) Occ layers of a cm or so that are more ~dense w/ mcr clay content-v, firm & blocky, Poss sl slickensided Occ sm mm size lenses of clean wh surf. representing (non-strd) sand w/in sh layers, fault @ 7430 . CORE NO. 10 9203-9231 = 28' Recovered - 28' Could not get back to bottom on conn @9231'..POH CONOCO CORE DESCRIPTION REPORT PAGE 1 OF 1 DESCRIPTION BY: M. Bradshaw 9203 9210 9220 9230 WELL Milne Pt. Unit No. 2 BASIN North Slope, AK AREA Sec. 19, T13N, RllE DEPTH LITHOLOGY SYMBOL LITHOLOGY DESCRIPTION Shale dark grey - greenish grey (dr greenish black (wet); fairly firm ~ brittle; fissile; breaks easily along horizontal parting planes or bdg; after fractured - both linear and conchoidal; sl. mic., tz amts of coaly plant mar'l; some evidence of biotrubation (fecal pellets?, worm tubes, various depressions); Remains of small gastropod opercula (~-2mm); tr amt$ pyrite; pyritezed~worm tubes; s~ {q~k~; some minor v.f. gn qz sand lenses ( ; mm x 2cm) . Overall core breaks into disks ie "poker chip" shale. BEDDING ANGLE y) Horizontal High angle fault or frac. @ 9210 ~ 20° to long axis of core. SEDIMENTARY STRUCTURES Bioturbated SHOWS None PAGE 1 OF4 CORE NO. 11 9231-9291 = 60' Recoveriy = 60 ' WELL Milne Pt. Unit ? CONOCO ,~:~,~%C.~,~.C:~]~,.,~.~ DESCRIPTION REPORT ,, BASIN North Slope. ak DESCRIPTION BY: M. Rfa~h~w AREA Sec 19; T].~_ ~ ~E DEPTH 9231 9245 9250 9255 9260 9263 9265 LITHOLOGY SYMBOL This section o core was gener ally broken into thin disk along parting planes resemb- ling large "poker chips" Core becomes more coherent 9245-63; dense solid chunks LITHOLOGY DESCRIPTION Shale: dk gy-blk (dry); blk (wet) fairly firm brittle; fissile; sl silty in part; overall fairly non- descript and "aphanitic" looking; tr amts carb plant mat'l; tr pyrite; almost a slate grade; micr¢ mic. As above Shale: basically as above but w/iht sand content in lenses and lobes sand is v.f.-f, gn, poorly srtd, sbrnd-sbang qz&glauc; abun mtx in sandly areas; often occurrs in filled burrows & worn tubes, shell casts & molds; these are also often pyritized; several pieces of large (-~-2cm) petrified wood or plant remains; also carb plant mat'l.) Sandy shale: shale as above but increasing in sand content and gn size; V. silty; interlaminated mm scale sand-silt layers; it grn sbang-sbrnd glauc common; sand is v.f.-f.gn w/abun in-filling cly mt; mat'l. Several large (~v l"x3" burrcw casts); m.+caeous BEDDING ANGLE Horizontal r Ilorizontal Horizontal SEDIMENTARY STRUCTURES SHOWS None apparent None Bioturbated potty, streak 1 yell grn flu mainly in sand filled ts & molds, ; slo faint lky-wh cloudy ; colorless lite cut; 1 odor. Small scale mm size dull gold flu sand silt laminae; in a few frac wavy bdg. Sedament ures and hazy drape over large burr patches; slo type cast. v. faint cloud milky wh cut f~u; colorless vis cut; CORE NO. 11 g231~929] =60' CONOCO PAGE _2 OF..A_ DESCRIPTION BY~ M. Bradshaw CORE DESCRIPTION REPORT 9267 9268 9270 WELL Milne Pt. Unit No. 2 BASIN North Slope, Ak AREA S~n_ lq: ml~N. nllR DEPTH LITHOLOGY SYMBOL Scattered bleed ing oil pops 9267-9285 LITHOLOGY DESCRIPTION Shale: grnish blk/dusky yellsh brn (dry); grnsh-blk (wet); v. silty & sandy; sand is v.f. grn & occurs in patches and stringers usually filling small burrows & worm tubes; glauc; v. hard and coherant,micac- eous; est por & perm is almost nil- appears v. lite; bioturbated to som, extent Clay/Shale: lt-med gy, firm, fissil w/abun dy v.f. gn, rndd-subang, "floating" glauc gns; pyritic, some sand-filled and pyritized worm tube br burrows; laminated-alt w/mm size laminae of sand; sand is v.f.-f, gn . . anF almost inter locking grn-v.-lit abu~ glauc & pyrite Sandstone: lt-med grnsh gy; firm; v.f. gn, sbang-sbrnd, clr-frstd; qz gns and abun (~ 30%) f.gn, sbrnd it-pyrite; occ streaky patchy brn oil stn; fair sorting; abun mtx mat'l sl calc poor ~ & K; lite BEDDING ANGLE , , Horizontal e;Horizontal Hozizontal SEDIMENTARY STRUCTURES None apparent mm to cm scale sand/clay laminae Bioturbated SHOWS Med gold uni- form flu, en- hanced in sandier worm tubes & fill- ed burrows e tc; s lo mi 1~ ~h cloudy cut followed by slo streaming :loudy wh cut flu;v.pale str ~w ~is cut; sl. petroleum odo . ~ull orng-brn ~airly uniform flu; no cut flu, no vis cut; no odor. Hod yell/gold scattered flu (60%) enhan- ced where bio- turbated; v. slo dull ~lui- sh-ye~l stream. ing cut flu, :olorless wh- lite cut, v. sl. odor. CORE NO. 11 9231-9291 =60' ' Recovere~ 60' CONOCO PAGE 3 OF 4 DESCRIPTION BY ~. Br~a~haw CORE DESCRIPTION REPORT WELL Milne p%, Unit No. 2 BASIN North Slope, AK AREA Sec. 19, T13N, RllE ,, L'ITHOLOGY BEDDING SEDIMENTARY DEPTH SYMBOL LITHOLOGY DESCRIPTION ANGLE STRUCTURES SHOWS iiii i Ill IIll I I I I I Il I II I! I II I Il I Ill I I I II 927 2 Sandstone; As above (9270) Horizontal 3ioturbated Mod yell/gold patchy flu (60%); v. $1o dull yell streaming followed by $1o blooming cloud cut flu clorless wh lite cut; no discernable odor. 9275 As above; tr fossil "ghosts" A/A with v pale straw vis cut.; faint ordor 9278 Sandstone: dk grnsh gy (dry); v.f- Horizontal 91 bioturbated fair odor; f. gn, sbrand-sbang, clr-sl frsted, mod-bri uni- qz gns; much less glauc than above . 9280 high angle form gold flu ,~-10% lt-dk grn, f gn, sbrnd gns; fracture (-~, 20° slo mod strm~- 9280 abun silty & clayey mtx mar'l, some from vert axis ing bluish/ it brn oil stn; v. sl. calc, small of core) w/slick-~ ~ h cut follow- tr pyrite; poor vis ~&K. ensided surface ed by bloom- and well develop, d ing milky wh subhedral qz xls cloud, v. on frac plane pale straw surface; vis cut. 9282 As above w/decreasing glauc A/A A/A A/A, brn oil str~. 9284 CORE NO. 11 9231 - 9291 = 60' Rec i = 60' COH D WnAL CONOCO PAGE 4 OF 4 DESCRIPTION BY: . . . =_=~.. CORE DESCRIPTION REPORT WELLMilne Pt. Unit ~o,...2 DEPTH 9285 9290 9291 LITHOLOGY SYMBOL This section of core was all rubble. foot or so was 1 coherent piece BASIN North Slope, AK . LITHOLOGY DESCRIPTION As above; sl-mod more calcareous As above BEDDING ANGLE AREA Sec 19t T13N, Rile SEDIMENTARY STRUCTURES SHOWS AS above @ 9278 CORE NO. 12 9291 - 9351 = 60' Recovery = 60' CONOCO DESCRIPTION REPORT PAGE 1 OF 6 DESCRIPTION BY: M. Brad~haw WELL Milne Pt. Unit No. 2 BASIN North Sloper Ak AREA Sec 19~ T13N~ RllE 9291 9293 9296 9300 9302 LITHOLOGY DEPTH SYMBOL 9291'-9318' ble ding oil in scattered small mm size "pops" LITHOLOGY DESCRIPTION Sandstone: med grnsh gy (dry); v.f. gn, sbrnd-sbang, clr-sl frstd qz gns; tr amts glauc, lt-dk grn; v. · gn, sbrnd gns; ss is v. sl. fria- ble; sl. calc; abun silt & clay mtx! at't wh/gives overall v. lite app- arance; v. poor vis ~ & Kit brn oi tn; tr carb mat'l. s above; patchy brn oil stn; more arb mar'l, fossil "ghosts" s above; sl-non calcaueous s above .andy Shale: paper-thin laminae of ]k grnsh gy, mica., carb., firm, ilty sandy SHALE interspersed w/v.f 'n sbrand-sbang, clr-sl frstd sand .s above; sand lenses & stringers ~re thin (1 mm or less) and show irregular wavy bdg on a v. small ~cale; Sh and sand are sl. calc. BEDDING SEDIMENTARY ANGLE STRUCTURES SHOWS Horizontal None apparent bioturbated (filled worm tubes), fossil As above ghosts Horizontal Essentially Horizontal V. small scale paper- thin laminae of sand & shale; wavy bdg. fair petro- Leum odor; un form dull-mod gold flu; v. slo faint blu ish-white ~treaming cut ~/slo blu/wh blooming. V. Straw vis cut aniform bri fell flu cut ~s above; vis ;ut as above aniform dull ]old flu )therwise as ~bove; ~s above to 9300 ~o discern- ~ble odor patchy string- ~-rs of dull gold flu zn sandy lam; 31o v. faint ~lu-wh cloudy :ut, color- less vis cut. CORE NO. %~ 92~1-93~1 =60' Rec i = 60 ' CONF D CONOCO PAGE 2 OF 6 DESCRIPTION BY~ M Brad~haw CORE DESCRIPTION REPORT NELL MX]ne Pt. Unit No. 2 BASIN North Slope, .Ak AREA Sec. 19~ ~13N~ RllE 9304 9306 9308 9310 DEPTH LITHOLOGY SYMBOL LITHOLOGY DESCRIPTION Sandstone: med grnsh gy; v.f. gn, sbrad-sband, clr-sl frstd, qz gns, glauc-lt to clk grn, sbrnd gns; w/abun silt & clay infilling mtx mat's sl calc; tr pyrite, tr mica, tr carb mar'l; tr amt brn oil stn; bioturbated poor vis ~ and K As above; frequent carb. plant remains, patchy brn oil stn As above in wavy laminae w/paper thin shale similar to 9302' As above without the shaly laminae but ss still has abun silt & clay mtx filling mat'l, freq carb plant mat'l BEDDING ANGLE Horizontal SEDIMENTARY STRUCTURES Bioturbated - (filled burrows & worms tubes) As above Well developed bioturba tion As above As above SHOWS No descern- able odor; patchy string- ers of dull gold flu in sandier lamin- ae; slo v. faint blu-wh cloudy cut; v. pale straw vis cut Fair petroleum Ddon , spotty dull yell flu, enhanced in carb remains; slo. v. faint 0Iu-wh cloudy cut w/some v. slo blu-wh streaming; colorless vis cut. faint odor; un iform-to occ patchy dull gold flu; , v. faint blu/wh cloudy cut followed by v. slo lt. blu/wh streaming;v.lt CORE NO. 12 9291 - 9351 =60' Recovered ~60 ' CONOCO PAGE 3 OF 6 DESCRIPTION BY= CORE DESCRIPTION REPORT DEPTH 9312 9314 9316 NELL Milne Pt. Unit No. 2 , LITHOLOGY SYMBOL , , , LIGHOLOGY DESCRIPTION , , As above; incr. calc; v. lite almost interxln txt As above; large sand filled burrow or tube (~-8 mm x 6cm); incre in calc As above but sl less calc. BEDDING ANGLE As above AREA Sec. li, T13N~ Rile ,, SEDIMENTARY STRUCTURES ,, As above , SHOWS Patchy mod yell/ gold flu; other- wise as above. CORE NO. No. 12 9291 - 9351 =60' ~ec =6 0 CON DEWnAL CONOCO CORE DESCRIPTION REPORT , , , , , , DEPTH 9318 est. top of Shublik 9320 9322 9324 9326 ~ELL Milne Pt unit NQ. 2 , LITHOLOGY SYMBOL 9318-22 was gen fairly broken and rubbly. Several large imbricate frac's developed here @~ 20°~ from long axis of core. Well developed sub- hedral to euhedral calcite xls along fracture plane. Some fracture fillings as much as 17 wide DUNHAM LS CLASSiFiCATiON BASIN North .q]oD~. AW -- LIGHOLOGY DESCRIPTION Calcareous shale, dk grnsh gy; firm; sl fissile i/p; w/several lg lenses or nodules of v.f. gn sandy calc mat'l; calc mat'l is it brn-tn; bioturbated; sand-filled bu'frow w/calcite cntr; Over- all ~ock is very "dirty" looking Shale: dk gy-blk; firm; fissile; sl glau v. calc; carb; w. abun small laminae & lenses of cal mat'l wh/is It gy-tan; poss sl brn oil stn, Limestone: dkgy-blk; v. argillaceous; very "dirty" looking; almost xln; mud- stoner wackestone; w/large calcity fille fractures. Calcity is wh-tan; transpar- ent-translucent; subhedral-euhedral; often w/argill impurties; Limestone: mudstone-wackestone; med bluish gy; v. argill; v.f. xln; gy-lt tn xln txt; w/remnants of partial pele- cypod valvQ (~ 1 em) casts; appuars rexl? sl glauc Mudstone-Wackestone; med-dk grnsh gy; argill; v.f. g xln txt; gen A/A w/lg calcite filled frae or vein BEDDING ANGLE Horizontal c;Assentially Horizontal Horizontal PAGE 4 _OF 6 DESCRIPTION BY~,M Bradshaw AREA s~ lq, m~. ~]~E SEDIMENTARY STRUCTURES SHOWS , , , Bioturbation - filled burrows, disturbed bd~ Wavy bdg- interlaminat sh and Is; pred sh. Wavy fine gr small scale laminae to odor; patchy dull' ~ell flu in sandy lenses; no cut. No discernable d odor; v. sl. tr. dull yell flu in sandy/calc lenses; no cut. bri yell min flu only As above @ 9322 As above CORE NO. 12 9291 - 9351=60' ........ Rec ' =60' ! CONOCO PAGE 5 OF 6 DESCRIPTION BY~ M Bra~shaw CORE DESCRIPTION REPORT WELL Milne Pt. Unit No. 2 DEPTH 9328 gq30 9333 9335 9337 9340 9342 0344 9346 LITHOLOGY SYMBOL BASIN North Slope, Ak ,, ,, LIGHOLOGY DESCRIPTION , Mudstone - Wackestone; med bluish gy; firm-hd; argill; f gn xln txt; xls gen gy - it brn; w/wh translucent sub- hedral-eudral calcite vien and fracture filling xls-on acm size scale; some fossi.1 ghosts and evidence of bioturb. tr pyrite As above but more fossiliferous- abun pelecypod (Monotis?) single valves ( ~ 1-Scm); largely rexl; abun other biogenic debris. Shale: dk grnsh gy; v. firm; sub riss; calc; silty; fossiliferous as above As above @ 9335 Siltstone; olive gy; v. f. gn silt size mat'l, calc; a few scattered pelecypod valves as above; argillaceous; sl fissil tr pyrite & carb mat'l, occ w/small bleb of calcite BEDDING ANGLE r,/ Horizontal Horizontal s AREA Sec 19, T13N, RllE ,,, SEDIMENTARY STRUCTURES Micro-scale wavy bdg; bioturbated. 9332 - high angle frac as described earlier @ ~' 20° to long axis of core. None apparent , SHOWS ~No odor; v.f. faint dull orange scatte flu w/extremely faint blu/wh v slo cloudy cut; no vis white Lite cut. As above .! CORE NO. Nh_ l) 92,9] -9351 = 60' Recovered = 60' CON D CONOCO PAGE 6 OF 6 DESCRIPTION BY~ M. B~adshaw CORE DESCRIPTION REPORT ~ELL Milne Pt. Unit No. 2 BASIN North Slope, Ak AREA Sec 19, T13N, RllE DEPTH ,, , 9348 9351 LITHOLOGY SYMBOL , , , LIGHOLOGY DESCRIPTION Shale; dk grnsh gy-dusky yell brn; v. calc; pyritic; firm; sub-fissile; abun single pelecypod (Monotis?) valves (~ 1-4cm) ; almost a packstone. Some valves are pyritized. As above * Overall core is v. hard and coherant w/few rubbly zones. Most of core had to be broken off with a hammer. BEDDING ANGLE Horizontal SEDIMENTARY STRUCTURES Bioturbated , , SHOWS No odor; v. faint v dull orange scatt ered flu; extremely faint blu-wh v. sl¢ cloudy cut, no vis cut · ORIGIN ° March 17, 1981 Mr. Terry Lucht Conoco 3201 C. Street Anchorage, Alaska 99503 Re: Our Boss Gyroscopic Survey Job No. Boss-16754, 16764 Milne Point No. 2 ~/~ v - ~ ~ ~- ' J'~ Wildcat Field /~ ~ ~ Operator: John Samec, Blaine Baertsch Survey Date: February 15, March 15, 1981 Dear Mr. Lucht: Please find enclosed the "Original" and two(2) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thane you for giving us this opportunity to be of service. Yours very truly, SPERRY-SUN, INC. Ken Broussard District Manager KB/kc Enclosures / ,iLNE Pl'. NO WILCCaT , ,',OR TH SLOPE BOSS SURWEL TRUE SUB MEASURED VERTICAL SEA DE F'TH DFPTH T'gO COURSE PAGE' DATE OF SURVEY MARCH 16, 1980 VERTICAL SECTION DIRECTION INCL SPERRY'SUN INC. RECORD OF §U~-~Y COURSE DOG-LEG INATION DIRECTION SEV RECTANGUL/~ G {q)6j' [JEG MIN ri~"~tjO-O ...... NO'A"TH)$OU'T TOTAL R COORDINATES VERTICAL 0.00 O.OO -~+6.00 i'O0 , 00 i 00', O0 5 2 O0,00 199,99 153,g9 5 OD, OC 299.99 253,99 q OO,O0 399.99 ORIGIN AT SURFACE o 25 s 65 ~6 w .21 D 2] S 77 42 W .10 0,00 N 0.00 E 0.00 .15 .~6 .G7 .73 S .51 W .OG S 1.Sq W .20 S 1.97 U ~'~9 S 2.6q W .23 500. 6010, 700. 800. 900. O0 q99.99 453.99 0 17 O0 ....... 5'99*99 ......... 5§3.99 0 lq O0 699,98 655.98 0 1'0 OD 799,98 753.98 0 2 O0 899,9'8'''= ............. 8'5'~'2'~8 .......... 0 22 S 88 0 W .15 .73 N 80~0 W ,07 ,70 S 65 18 W .l~ ,75 N 79 q8 W .~3 .78 S 3.26 W .11 S 3.70 W .01 S q,05 W S ~.lg W -,01 S 88 30 W .32 .78 S q.5q W -.07 1000.00 999.98 953.98 0 1~+ " i' 1100','00 .... ii0'99",98 ....... 1055 '~9~' ij----g , , 3.200.00 ~' 1199.38 1Z55'98 0 7 lqOO.O0 3399.98 1 '~' ~'~";'g~ 0--- g ..... S 21 G E .qg .g8 s b'-3---~g .~:~ Z,2~-S S 22 5q E ,1E~ 1,~1 S 8 24 W ,15 1.70 ~,~-'5~' '-O-"g · T~ 1 , 9'7 q,78 W .08 4.81 W .33 ~,88 W .qB q.87 W .77 5-'Ol-'W-- 1,01 1500.00 1499.98 1453.98 ' "'~700.00 " 1~99.9S lS53.gS 1900.00 1899.97 ~853.97 0 14 S 51 42 W ,08 2,17 S 0 15 S 15 54 E ,35 '2.74 S 0 28 S 88 50 W .56 2.94 S Ti- 1'~ ~ '-i~Tg- ~-g-"g · ~'5 3', O 2 "S 5,27 W 1.16 5,66 W 5,85 W 1.62 6,18 W 1.7q 6 · ~7"/'-~ 1.71 00 2399.96 235.5.96 00 2499.96 2455'.96 O0 .......25'99','96 ...... 2553.96 0 13 o' 0 26 0 25 2700.00 2699.95 2653.95 ~80O.O0 2799.92 2753.92 O0 .......... 2'~"~'9",77 ...... "2'853.7'7 0 28 0 '4/-+ 0 28 2 1 N 79 42 W .12 5.05 S g-'T0-Tll-'~ ...... ', 13 3 '1'0'S N 85 12 W .23 5.1~+ S S 82 18 W .11 3.17 S 7.lq W 1.68 7,55 W 8.15 W 1.59 8,93 W 1.~6 N 82 30 W .16 3.18 S 9.69 W 1.34 S 8q 18 W ,13 ;~,18 .......... ~3"~-[r .3i ,5, I. 2 S q~ 6 W .60 5.52 S 3 0 W 1,70 5,36 ..... 9--" ,-3--~9--E ....... I'2 8,9 1'o -, 5'0 10,~1 W 1.2 I1',~5-W 12.37 U .9 12.7q W 2.9 'i'~;'6i'~ 0:o' I NC ' UPTH SLOPE BOSS SURWEL TRUE SU MEASU{ED ......... V.ERTI..C.A.L .......... SE DEPTH DEPTH TV B COURSE SPE RECORD CO VERTICAL RRY-SUN INC. OF SURVEY URSE DOG-LEG P46E 2 DATE OF SURVEY MARCH 16, 19R0 SECTZON DZRECTION A...__.~ ~.CL !.N ~A T D DEG MI N DEG M I TOTAL QN .......S_[V ......... REClANGULAR · .COOR.D I..N_AT£S__ _ V(.R~_T N DEG/IO0 NORTH/SOUTH E^ST/WEST SECTIOn] 3000.00 2999. 953 31'00,'00''' 3098,57 3052 3200,00 31~7,07 3151 1,3300 O0 3294 ~8 32~8 3qO0,O0 3~90,~8 3544 .39 5 56 · 57 8 37 · 07 11 8 · ~8 14 53 ,4R 17 3b S 15 0 E 2.25 18,87 S 11.05 S 15 48 E 2.69 31.07 S 7,67 S 15 12 E 2,52 47.60 S 3.10 S 16 54 E 3.77 64.23 S 3.17 '--'~ 3S 36'~' 2.73 96.09 S lO.9n W 16,50 W 29.12 E 6 62 E 96.45 3500.00 3/.+R5.28 ..... 3600,0'0 .... 57'8" 3 3700,00 3671,64 3800.00 3764.00 3/439 362~ 3718 · 2 e 1%_2_7 ,93 21 31 · 64 22 31 ,00 22 34 22 15 3900,00 3856,z, 5 3810.45 S S S S ]5 6 E 1.90 126.75 S 19.33 E__ 15 24 E 2.02 160.53 S 28.54 E 15 12 E 1.01 196.69 S 3R.43 E 15 6 E .06 233.69 $ 48.45 [ ~3 54 E .55 270.5g S 58,00 E 128.1~ 163.nq 200.qO 238.62 276.64 4000.00 3948,95 3902.95 22 25 S 12 54 E .41 307.55 S 66.80 E 314.59 ...... ~'!00"013" 4041,/.t~ 3995.44 ' 4RO0.O0 4133,88 4087.88 ............ ~300.00 ......... ~' 22.6.,.!..4 ...... 4180.14 4400.00 ~338.25 ~272.23 22 22 22 23 18 32 52 1 4500.00 4410,36 I........... 46.00'00 ~502.51 .~ 4700,00 459q,64 ..... ~. 4800,00 ~F. 86.84 4900,00 4779.00 436~.56 22 46 4456.51 22 56 AbqS.6q 22 49 4640.84 22 4q 473J.00 22 58 ...... 5000.00 4871.13 4825.13 . ~..5100,00 4963.133 4917.33 ' ,5200,00 5055.64 5009,64 ............. 5300,00 5147,79 5400,00 5239,~8 22 49 --2T'4¥ .... 22 30 2~ 12 22 ~2 5500,00 5332,ql 52~6,91 5600.00 5427.3~ 5381,34 5700°00 5522.80 5~76.80 5800,00 561g.11 5573,11 2,'] 15 iR 8 16 30 14 40 5900,00 5716.23 5670.23 S 11 12 E .66 344.74 S 7~.74 E S 12 36 E .58 382.05 S 82,61 E S 12 18 E ,35 419.72 S g0,92 E 352.61 390.73 q29,29 S 12 18 E .15 457.80 S 99.22 E 468.25 S 11 42 E .33 495.84 S 107.31 E E F S 11 42 E .37 533.87 S 115.19 S 11 6 E .27 571,98 S 122,87 S 10 30 E ,24 ~10,00 S 150,13 S 10 54 E ,27 6~8.16 S 137.3q S 10 6 E .35 686.40 S 144.42 E --~ 9 48 E .14 72q.52 S 151,11 E S 9 ~2 E ,23 762,41 S 157,62 E ~ 4 5a E .70 800,68 S 164,23 E S 9 24 E .SA 83g,12 S 170,7/ E 7 623.5A 662.38 701.24 739.96 ~17.2~ S 10 12 E 2.47 875.19 S 176,99 S 10 24 E 2,12 907,52 S 182,86 E S 8 18 E 1,75 936,88 S 187,72 E S 6 30 E 1,90 963.50 S 191,20 E 'S--~ 30 E 1.79 987,14 S 193.90 E q25,69 982e24 1-565.97 /~ONOCO$ INC, . MILNE PT, NO P UTLDCaT '..",'lq SLDPE BOSS SURWEL F . .. TRUE MEASURED VERTICAL DE P T H D E'P 'T H -D~GE 3 DATE OF SURVEY MARCH ]6, lgA-O VERTICAL SECTION DIRECTION S-]P-$q-CO.~F .- . SPERRY-SUN INC. R ¢: C6KD-'6-~ ",-qURV ~ ~ .... SUB COURSE COURSE DOG-LEG T SEA INCLINATION DIRECTION SEV RECTANGULAR 'TV~- ....... 0~ MI~] ........ ~E~- ~'I ~-' -F~I~fI"D-O .... NOR'TH'~S'OUTH OTAL COORDINATES VERTICAL E-I'~T7-D~-~T ....... ~ E C T TO.~-- 6000.00 5814,03 5768,03 6100.00 '' 59'12-;25 ....... 6200,00 6010,68 5~64,68 G~OO,DO 6109,q3 6400.00 620~.q7 6162.q7 ll 7 S G 6 E 1.75 i0 ~ S 4 ~+~ E .g-~ 9 47 S 5 30 E .77 8 i7 S ~ A2 E 1.51 -7" ~ b- ........-~ 7 0 E .7~' 1007.80 S 1 026'51 S 1044,09 S 1059,7q S 196.18 E i~2~.69 i97,97 £ 199.55 E 1 200.96 E 107 62 202,35 F ...... i000.~--- 6500,D0 6307.75 6261.75 6600.00 6407~,26 6361.26 6700.00 6506,,86 6q60.86 6800,00 6606,51 6.560.51 6900.00 6706,22 6660.22 6 4 S 1 6 W 1.79 5 15 S 12 ~8 W 1,41 4 57 S 23 12 W .97 A 39 S 28 lP W .51 4 1 S 28 6 W 1C85.30 S 1095.05 S 203,0A r llOq.14 201,9q E 1113,51 199.23 E 3121.29 195.61 F 1128.03 lq2. O5--E - il ~-~q;~-- 1103,q8 1~11.02 1117.68 7000.00 6806°02 6760.02 7100,00 6905,86 6~59,86 7200,00 7005,73 6959.73 7~oo,oo 71'OS.~i 7o59.61 7q'oD'-oo ........7'2"015', '6' 0 ........... 71~9'~'5 o 3 21 S 52 6 W .72 2 53 S 37 ~2 W .24 2 4A S 27 36 W .52 ~' ~¢'- ' S 29 6 W .25 1323.25 1I~.% 92 S 11~o10 S 1156.20 S llZ+O.21 S 188.8~ E llSR.~O 185,79 E--1142.82 182,75 E 1146,37 180,1~ E 11~9.91 17'?,95 E 1153.~5 7500.00 7305.A1 7259,ql 76'00.00 7405,35 7'~9.35 7625.00 7~30,35 738~,.33 7700,00 7505.30 7459.3,0 ............... 7"8-0'0 "0 0 ............... i'6 0'5';'2'~ ......... ~ ~'5 ~ . 2 6 2 19 S 29 12 W 1 52 S ~3 12 W 1 31 S 58 42 W · 17 1143.87 S ,65 1146.85' S · lA 11~7.q5 S .77 11q8,85 S · f'i~ i i' Sd', i'7' S 175.90 F 13~~ I73'82' 173,27 E 1159.71 171,59 E 1160,78 ] 6 9,2~ "E .... 7900.00 7705.2q 7659.2q :~,8000,00 ...... 78'05.~3"' 7759,23 8100.00 7905.22 7859.22 ..... 82.00,0..0 8005.20 7959,20 RSO0,OO 8105.16 8059.16 0 55 S 73 24 W O 47 S 52 OW 1 17 S 40 12 W l'-ii~-- s 28 6 w ,7o 1151,o5 S ,09 1151.5~ S · 25 1152.26 S · 53 1153.5q S .55 1155.71 S 167.27 E 1162.11 165,80 E 'YI'~-~-.-'5"~--- 16q,5~ E 1162.R2 163.28 E 116'3.8q 161.8~ F 8AOO,O0 8205,12 8159,12 ,:~,':,,::t86 00, O 0 ,,. 840A,~8 8358.98 ' "8700,00.. 850A.gO 8458.')0 8800.00 860,~.82 8558.82 1 50 2 q 2 23 2 1~ S 16 12 W S 11 36 W S 12 0 W S lq 30 W S 13"2q'"W .39 1158,56 S · 27 ' ' 1161,87 S · 35 1165.67 S · 12 H169,66 S .'0'5 ............ 1"1'73','58 S 160,70 E 116A,31 " '159.89 E ' l171.qO 159,10 E 117A.99 158,16 E 1178,75 ................ 1'5'7,'19"E ...... 1'I82;42 ' CONOCO~ INC, MILNE mT.. NO WILDCAT r,:r' R T H SLOPE BOSS SURWEL _MEASURED. VERTICAL SEA DEPTH DEPTH TVD PACE DATE OF SURVEY MARCH 1~, 19~0 VERTICAL SECTION DIRECTION SPERRY-SUN INC. SOSS-I~7G~ RECORD OF SURVEY COURSE COURSE DOG-LEG TOTAL IN_C_.L._I.N~T_ I~ON _ _D.I_ R~E_C~_T._I_ON S~)L ......... RE.CT.ANGULAR C.OORDiNA~E__S.__ DEG MIN DEG MIN DEG/IO0 NORTH/SOUTH EAST/WEST VER_T__I_CAL SFCTION QqOO,f)O R7nq.73 9000.00 880q,63 875R 9100.00 890q,5q 8858 ............. 9200,00 900~,q2 8q58 ~300.00 qlOq,26 9058 · 63 2 qO S ~ 30 W ,26 ]182,01 S · Sq 2 23 S 16 AR W ,53 1186,32 S · q2 3 1 S 15 q2 W ,63 1190.85 $ ,26 $ 25 S P3 6 W ,57 1196,12 S ..................................... CALCUL · I0 3 6 $ 22 36 W ,31 ]201,35 S lq9,60 ,95 3 11 S 30 36 W ,~5 lP06,2~+ $ 1/+7,15 ATIONS ARE BASED ON THE MINIMUM RADIUS OF CURVATURE ME:THOO ** E 1212-~'=' HORIZONTAL DISPLACEMENT = 1215,18 FEET AT SOUTH 6 DEG, 57 MIN, EAST (TRUE) ................ START OF' SURV~'~'-'~§ ........ '~'~,'~)0 FEET ABOVE SEA LEVEL ;, ,. 5 _1_1 IZl?..f. 5 _ . C0N0C35 INC, MILNE PT, NO 2 k~ILD~T .... ~(;P. lq SLOPE BOSS SURWEL DAT[ OF ~URVFY PAGE' MARCH ]~:, lqPO MEASU:~ED DEPTH INTERPOLATED RECORD OF SURVEY TRUE DEPTH TVD ELEVA T ION TOTAL P,~U'E'~'ff- ~- i~ 00 ~, D I N ~ TF-S -' NORTH/SOUTH EAST/WEST 146, 100, 246. 200. -0, -100, '200· 0, S 1..-~ 1, S 2 W '300· '400· 1 · S 2, 1, S 546, 746, , 5A6, 500, 646, 600', 746. 7no~ 846. ............. §d6; .... 946, 900. B46. 946, -500, '600'· '700, 1. S 1. S -800. -900. 3, W 4. W 4. .5. W 146, 11~6'. llO0. 12~6, 1200. 134~. 1300; 1446. 1400. 446, 'lOOO, '1100, '1200, ---13DO. -1400, 846, gq6. ~5~6'. '- 15db; 16~6, 160~, 1746, 1700. -]700, 18~6. ..... i~0o. -i'sbb". 19~6, 1900, -1900, · 1. 2, 2, 5. 5. 14 5· k 7, W 2· S · 2'046. ~t)OO~. -2000. 2146. 2100· -2100. 2246. 2200; -2200', 2346., .... ,~ $~. -2,500. 2,~. 24oo. -24oo. 3, S 3. S 3. S 7. 8. 25~6, 2,~4G. ........ 2~'DD. -25oo. 2546, 2646, 2600 · -2¢, 00, 2746. 2746. 2 700, -2 700', 2946, 2~46, .... ~ 8Od'; -2800~' 2946. 2~46. 2400. -2900, · 14· ]'T;12.15. w~t'* ' "1 IT;- k~ 12. W cONOCD, INC. MILN.r mT. NO t.lIL DC~T NORTH SLCPE BOSS SU~WEL TRUE SPERRY-SUN INC, INTERPOLATED RECORD OF SURVEY DATE OF SURVEY PAGE' 6 MARCH 16. lg~O ROSS-] 67-G4 MEASU:~ED VERTICAL .~UB SEA TRUE DEPTH DEPTH TVD ELEVAT ION TOTAL PECTANGULAR NORTH/SOUTH COORDINATES EAST/WEST 3047. 3046. ......... ~000. -3000'. 24. S 3148. 3146. 3100. '3100. )B. S 3250, 32A6, ..................... ~20~? ....... -3200, 58. $ 3353, 334G, 3300. -3300, 83, $ 345B, 3446, 3400, -3400, 114, S 10. W W 7. E 16. E 3672, 3646. 3600, 3.~ ~ 9, 3846, 3~,oo, 3~7, 3946, 3900 · '3500. 148. '3600, 187. '3700, 226. -3800. 266. -3nO0. 306. S 25, E S 36. E S 47. £ S 57. r S 67. E 4105.' 4046. 4~13. '" 4146. 43.22.. ................................. ~ 4246. 4~30. 4539, 4446, i ",..' .'.,.' 46~7 · 4546 · A75G. /+GAG. 4973. 4846. 50~1. 4946. 4000. -qO.O0. 347, 4100, 'filO0, 387, 4200, -4200, 428. 4300. 'q30D. 469. 4400. -4400'. 511. 4500. -qSO0. 552. 4600. -4600. 593. 4700 . -qTO0~, 634 · 4800 , '4800. 676 · qgO0, '4900. 717. S 75. E S 84. E S 93. E S 102. E S 110. E S 11'~E S 127. E S 135. F S 143. E S 150. E ..................... 5.4.07, 5514, 5~0. 5B~B, 5.9~1,. 6033. 6134. 5046. 51q6. 5,246. 5346. 5000. '5000, 75~. 5100. '5100, 800. 5.2_o..0_~, -5200. 842 · 5300. -5300, 880 , 5400 . -5400. .913, 55q6. 550O° 5GqG. 5600. 57~6, 5700. 5846. 5800, 59~6. 5qcn. '5500. -5600, -5700. 994, -5~00. 1014. -5900. 1033. S 157. E S 164. E .S ........ 171. E S 178. E S 184. E 189, [ 192. E lg5. E 197, E 199, E CONOCO~ INC, MILNE PT,. NO 2 I..uK T M SLOPE BOSS SURWEL MEASU~, DEFT TRUE EU V£RTI'CA[ ....... H DEPTH INTE '"~ U RPOLATED RECORD TVD DATE OF SURVEY . , PAGE 7 M/tRCH 16, 1980 · . INC, OF SURVEY T'~q]E ELEVATION TOTAL R ECT A N G U L-IIT--- C 601~ D I NORTH/SOUTH EAST /WEST 6236, 60'q'G , 6337, 61q6'; 6638. 6246, 6100. 6200. -6000, -6100, -6200. 050 '- s 2 065, S 2 078, S 2 oil. E 0 E 6538. 63z+6. 6639. Gl+ z+6. 67'39' .............. 65 ~6, "' 6840, 66q6, 69q0, 67~+6. 70qO. 68~6. 7] qO · 69~6. 6300. 6qO0. 6500, 6600, 6700. 6800. 6qO0. -6300. -6~00. 10R9, S 1098, S -6500, -6600, -6700, 1107, S 1 llq, S 1 120. S -6800, -6900, 1125. S 1130. S 203. 201. 198. 191. i~. 185. 724'0. 7d'46. 7340. ' 71~6. 7q~+1. 7246. 75ql ' ........ ' ............................. ?~ZCtq' 76ql. 7~q6. 7dbd, 7100. 7200, 7300. 7~30, 77~1, 7546, 78~1, 76q6. 79~1, 7746, 80~1. 7'~6. 81~1, 79a6. 600. 700, ~OO · 900, -?000, '7100. -7200, -730'0'. -7~00o -7500" -7600', -7700. -7900, 134, S ' -- 138. S 1 1~42. S 1 ~5'[- S lqS. S I i~+9; S 1151, S 1151, S 1152."'S 1153. S 179. E 177. E 1-75; '-C-- 17~. E i7~=%-E 168. E !67. E I'~-5'. 'E 16q. E 82ql. ' 8'Oq6. 83~1, 81q6. 8qql. 82q6. 85~1. 83q6. 85q1. 8qq6. 8100. 8200, 8300. 8400. =SOOO, '8100, 'R200o -8300, -8400, 1154;'S 1157. S 1160. S 1163. S 1167. S G3."E 61. E 60. E 60. E 59. E 87q1. 8Bql. 8941. 90ql. 91~2. 8646, 8746, 8946, 8600. 8700. 8800. -8500. -8600. '8700, ' - ~8~-0'0 · -8900. 1171, 1 175. 1179. TI84 ' ~ 1P. 8, i~R. E 157. E 156. E 15q. E DATE OF SURVEY MARCH PAGE 8 16) 19qO Pq%L-lfi7fiq MEASURED DEPTH .......................... ~ ~-J~F~9 ;-SUN iNC. INTERPOLATED RECORD OF SURVEY TRmU~ ....................... VERT1'CAL ~J'g REA TRUE DEPTH TV[') ELEVA T ION TQ.T AL~ RECTANGULAR COORDIrJATES NORTH/SOUTH E'A ST/WEST J..... 9R~2, 90q6. 9000. '9000. 93~2, 9146. 9100. '9100. x 9~q2, 9246, 9200, 9500, g3O~. 925R. -g258. 1193. S 153. 1198, S 15J,,,,, ]20A, S 1~7. INTFRPOLATED COORDINATES._FQR_ ~V_~.Y___.IOO.OO FEET OF SUE-SEA DEPTH FROM 0,00 FEET TO 9P57.gb FEET TRUE NORTH CONOCO Boss-16754,16764 Milne Point No. 2 Wildcat Field Survey Date: 2/15, 3/15/81 HORIZONTAL PROJECTION Scale: 1"=200' . Check Form for timely compliance with our regulations. ~_~,,~.~..~ ~ , -'I ~,,~ ~" Operator, Wel 1 ~ame and Number Reports and Materials to be received by:'.~ - ~ Date Required , Date Received ! Remarks Completion Report _~ Well History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data Yes - STATE OF ALASKA ALASKA i~_ AND GAS CONSERVATION C((' MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling well Workover operation [] Name of operator Conoco Inc. 3 Address 3201 "C" St. suite 403 Anchorage, Ak 99503 ;3 Location of Well at surface 214' FNL, 4235' FEL, Sec. 19, T13N, R10E, UM 5 Elevation ~n feet (,nd~cate KB, DF, etc ) I 6 Lease Designation and Serial No 46' KRI ADL 47438 7. Permit No 80-75 8. APl Number 5°-029-20490 9. umt or Lease Name Milne Point Unit 10. Well No Milne Point No. 2 11 F,eld and Pool Exploratory For the Month of April ,19 81 2 Depth at end of month, footage drdled, hsh~ng jobs, d~rect~onal drdl~ng problems, spud date, remarks Cemented RTTS in the hole, top of fish at 3755' btm at 3885'. Milled window in 9-5/8" casing from 3487' to 3529'. Side track junk and drill an 8½" hole to 3895' and run 7", 29# N-80, LT&C liner. Liner top at 3348' btm at 3895'. Drill 6" hole to 3949' and open hole to 12". Run 4½" blank and wire wrap screen from 3760' to 3956'. Gravel pack with 20-40 sand; pumped 248% theretical pack volume. After gravel packing (o 13 Casing or hner run and quant~tms of cement, results of pressur9 tests Cemented the 7" 29# liner with 125 sx of Class G with 1% D-60, 2% CaC12 and 0.2% D-46. Test all casing and liner to 1500 psi9 for 30 minutes. Shot holes at 3867' to 3869' and squeeze holes with 200 sx of Class G with 1% D-60, 2% S-l, and 0.2% D-46. 14 Coring resume and brief description None 15 Logs run and depth where run ,16 DST data, perforating data, shows of H2S, mIscellaneous data RECEIVED MAY 1 5 1981 AlasKa 0ii & Gas Cons. Commission Anchorage Test #3 - Test gravel packed interval - Test well using nitrogen and diesel to lighten the Produced 327 bbls of water and about 40 bbls of oil in FBHP from 976-1411 psig; FBV-1573 psig. fluid column. 29½ hours. 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge SIGNED TiTLE Senior Production Eng~ATE May 8, 1981 NoTE--F~eeport on ttl~s form ,s required for each calendar month, regardless of the status of operat,ons, and must be flied ,n duphcate with the Alaska Od and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise d~rected Form 10-404 '~..~.~ ~ Rev 7-1-80 Submit ~n cluphcate ~er) 12.lost 8 joints of 2-3/8", 4.6#10 rd wash pipe in the hole. Fished and recovered all wash pipe. Tested well. Pulled top two join-ts of 4½" blank liner out of the hole to squeeze cement near the 7" 1-iner shoe. ~ STATE OF ALASKA ALASK/~I[" _ AND GAS CONSERVATION Ct~ MISSION R..OR OF 1 Drdlmg well C~ Wu o e ope atlon [] 2 Name of operator - '~ ~ Conoco Inc 80-75 3 Address 3201 "C" St. Suite 403, Anchoraqe, AK 99503 4235' FEL, Sec. 19, T13N, R10E, UM 4 Location of Well at surface 214 ' FNL , 5 Elevation ~n feet (~nd~cate KB, DF, etc ) I 6 Lease Designation and Serial No 46' KBI ADL 47438 8 APl Number 50-029-20490 9 Un,t or Lease Name Milne Point Unit 10 Well No Milne Point No. 11 F~eld and Pool Wildcat For the Month of May ,19 81 '12 Depth at end of month, footage drdled, f~shmg jobs, d~rect~onal drdhng problems, spud date, remarks (Sidetrack hole TD - 3959' MD) Test well using nitrogen and diesel to lighten the fluid column. After testing, set a retrievable bridge plug at 3800' and displaced mud with diesel at 2000'. Cap well and stack rig on location. 13 Casing or hner run and quant~tms of cement, results of pressure tests None 14 Cor~ng resume and brief description None 15 Logs run and depth where run None MAY 1 5 1981 Alaska 0il & Gas Cons. c~-mmjcsi~ ,16 DST data, perforating data, shows of H2S, m~scellaneous data Test No. 3A (Retest after squeezing 7" liner shoe). Produced 33 bbbls of oil; 8.5°± API gravity; BHFP - 600 to 1033 psig; FBU - 1157 psig Anchorage 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge SIGNED ~ ~ TITLE Senior Production 'R, nc[~ATE May 13, 1981 NOTE--F~eeport o~h~s form ~s required for each calendar month, regardless of the status of operations, and must be fded m duphcate w~th the Alaska Od and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise d~rected Form 10-404 Rev 7-1-80 Submit ~n duphcate ( ALASKA OIL AND GAS CONSERVATION COMMISSION Hoy le H. Hamilton/f]~ Chairman Thru: Lonnie C. Smith~~ Commissioner Harold R. Hawkins Petroleum Inspector April 28, 1981 To Witness Setting of Plugs; MILNE POINT WELL #2 Conoco Oil Co. March 21, 198.1: I left Anchorage at 8200 am, by Wien Airlines, to Prudh~e Bay, arriving at 9:35 am and arrived at Milne Point No. 2 at 11:30 am. The purpose of the trip was to witness plug setting and squeez- ing of the perfs, inside the 7" liner and a plug set above the 7" liner inside the 9 5/8" casing. There are to be more tests in the 9 5/8" casing above the plug tagged (20,000 lbs. bit wt.) at 7,339'. There was a pressure test of the plug set at 8,964' feet for 30 min. at 1,500 psi with no leak off. I also made a schematic of the work done on the well® ~~copy ]~attached ). In summary, I witnessed the setting and cement capping of the EZ drills and squeezing of the perfs on Conoco, MILNE POINT WELL ~2. The work performed to this point is satisfactory. I ~ STATE OF ALASKA ~ ~<' ALASK/~ IL AND GAS CONSERVATION C[r 4MISSION ~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1 Drilling well [~ Workover operation [] 2 Name of operator Conoco Inc. 3 Address 3201 "C" St. Suite 403 Anchorage, AK 99503 4 Location of Well at surface 214 FNL and 4235' FEL of Section T13N, R10E, UM 5 Elevation ~n feet (~nd~cate KB, DF, etc ) 46' KB 6 Lease Designation and Serml No ADL 47438 19 7. Perm,t No 80-75 8 APl Number 50-- 029-20490 9 umt or Lease Name Milne Point Unit 10 Well No No.2 11 F,eld and Pool · Wildcat For the Month of. March ,19 81 12 Depth at end of month, footage drdled, fishing jobs, d~rect~onal drdl~ng problems, spud date, remarks 9635' , Core and drill 9291' to 9635' . 13 Casing or hner run and quantities of cement, results of pressure tests Ran 40 joints of 7" 29#/ft, 8 round, N-80 liner. Shoe @ 9630' w/top liner @7470'. Cemented with 230 sks of self stress cmt w/l% D-60 F.L.A., 2% D-46 and .2% D-13. Squeeze liner lap 3 times. Test lap to 3500 psi - OK. Set EZSV @ 9240' and squeeze 100 sks cmt below and put 50 sks on top. Set EZSV @ 7479' and spot 50 sks on top. 14 Coring resume and brief description Core #12 9291' - 9351' Recovered 60' 25' of sand w/oil shows followed by 35' of shale and limestone RECEIVI:D 15 Logs run and depth where run Run 3/4/81 DIL/SFL/GR/BHC 9635' - FDC/CNL/GR 9635' - LSS 9635' - HDT 9635' - Shot 30 SWC's - Recovered 26 7600' 7600' 7600' 7600' APR 1 3 1981 Rlask~ 0il & Gas Cons. ColmliJssjon /mch0rage .16 DST data, perforating data, shows of H2S, m~scellaneous data DST lB Perf. 9270' to 9300' w/12 shots/ft, recovered 13bbls oil and water emulsion. Perf. 7188' to 7214' w/12 SPF, set permanent packer @ 7040' and flow test well thru 3½" tubing. Flowed approximately 1900 bbls of oil per day. 22° API gravity. 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge SIGNED ~'~~~'"~TITLE Drilling Supervisor DATE Apr il 9, 1981 NOTE--Report on th~s form ~s required for each calendar month, regardless of the status of operations, and must be fded ~n duphcate w~th the Alaska Od and Gas Conservation Comm,ss~on by the 15th of the succeeding month, unless otherwise d~rected Form 10-404 Submit ~n duplicate Rev 7-1-80 7Zr~'ec~ ~0 Z>v, April 8, 1981 William VanAlen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak 99501 Re: Dry Samples - Milne Point No.2 API #50-029-20490 Permit #: 80-75 Dear Mr. VanAlen: Conoco Inc. 3201 C Street Suite 403 Anchorage, AK 99503 This letter of transmittal accompanies dry Samples taken from Milne Point No. 2. The sampled interval was from 2390, to 9635, (TD) . The remaining data and core samples required by the Alaska Oil and Gas Conservation Commission will be delivered to Your office Within the ~-~_~ew weeks. tions please feel free to ca'~l---r~-e_a.~_2 If you have any ques- Sincerely, 79-0611. Gary A. Merriman Senior Production Engineer STATE OF ALASKA ALASKA(' IL AND GAS CONSERVATION (~ MMISSION SUNDRY NOTICES AND RE ,.u ll= cl N WELLS OTHER ID DRILLING WELL [] COMPLETEO~EI"&"J2]AI~fiI'f ~ ~cc, S 2. Name of Operator Alaska 0ii & Gas Cons. Conocot Inc. ---u~nch9~"~ 3. Address 3201 "C" Street Suite 403 Anchorage, AK 99503 4. Location of Well 214' FNL and 4235' FEL of Sec. 19, T13N, R10E,UM. 5. Elevation in feet (indicate KB, DF. etc.) 4.6 ' KB 12. I 6. Lease Des,gnat,on and Ser,al No. ADL 47438 7. Permit No. amtssi0n 8 0 - 7 5 8. APl Number 50-- 029-20490 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point No. 2 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: {Subm,t ~n Tnpl,cate) {Submit ~n Duplicate) Perforate ~] Alter Casing [] - Perforations [] Altering Casing I-! Stimulate [] Abandon [] Stlmulat,on [] Abandonment I-'1 Repa,r Well [-] Change Plans I-] Repairs Made [] Other I-I Pull Tubing [] Other [] Pull,ng Tubing [] (No~e- Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion ) 13. De~ribe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, ~ncludlng estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Proposed work: Perforate from 7188' to 7214' and test; perforate from 442 ' to 4495' and test; perforate from 3890' to 3950' and test. · Estimated starting date: March 24, 1981 proposed Procedure 1) Perforate with 4" casing guns, 12_ jet shots per foot, from 7188 to (DIL measurements) 2) RIH with a Dowell Model 18 packer and packer extension and set at Packer extension contains one 2.75" and two 2.313" OTIS x-nipples. 3) With a plug in the packer extension change the hole over to 10.2. calciu]~ chloride water. RIH with 3½" tubing (9.3#, N-80) and pull the plug out of the hole and test. 4) Depending on the test the well may be hydraulically fractured followed by another test. 5) After testing this zone a packer with a 2600+' 2-7/8" tubing extension will be run in the hole and hydraulically set. The 2-7/8" tubing will be stabbed into the Model 18 packer set at 7135+'. (note: a plug will be placed in the Model 18 packer extension to isolate this zone. ) 713 . , Subsequent W. orl~ lteporterl 14. I hereby Get,fy that the foregoing ~s true and correct to the best of my knowledge. ------'---- Signed T,tleSenior Production Engr. Date March 21, 19~ The sp~e below f/Comm,sslon use ..... Conditions of Approval, if any Approved by Form 10-403 Rev. 7-1-80 Approved -o~y Returned By Or~ COMMISSIONER the Comm,ss~on Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate / State of Alaska Sundry Notices & Report on Wells Form 10-403 cont ' d 6) Change the hole over to KC1 water (9.3# / gal) and perforate from 4420' to 4495' with 4" casing guns, 12 jet shots per foot. TEst the well using DST tools. If sand becomes a problem the zone will be gravel packed using a 4½" wire wrapped screen. 7) After this zone has been tested, perforate from 3890' to 3950' with 4" casing guns, 12 jet shots per foot. If the previous zone required gravel packing, this zone will be gravel packed then tested. 8) After testing~tubing will be run to the top of the upper packer and the wellhead will be installed. Note: Zones will be isolated at all times through the use of tubing plugs. This completion is- not intended for dual production of zones. Only one zone will be produced or tested at a time. RECEIVED · aska Oil & Gas Cons. Comm~s~n H. D Haley Manager of Producteon Ventura Dews,on March 13, lC)81 Conoco Inc 290 Maple Court Ventura CA 93003 (805) 642-8154 State of Alaska Alaska 0il & Gas Conservation Comm&ttee 3001 Porcup&ne Dr±ye Anchorage, Alaska 99501 Gentlemen: Last February you recezved a letter from Mr. Vzc Lyon wzthCon~gD_O_~in Houston ask&n~ that the Mzlne Po&hr un&t be &ncluded ±n the area for whzch Arco has asked ann proposed a set of Kupurak R&ver format&on f&eld rules. Th&s Ks to adv&se that Conoco now w±shes to exclude the Milne Point unit from these rules and we w±ll contSnue to operate under the state w&de rules. As you are aware, we have three producin~ formations at Milne Point and we are now dr&llin~ confirmat&on wells. For th&s reason &t zs bel&eved that we should have a separate set of re~ulat&ons applzcable to the dzfferent formations prevalent in the M&lne Po&hr unzt, and a set of f&eld rules w&ll be proposed by Conoco after we have determined the un&t boundar&es and have accumulated add&t±onal reservozr data. Very truly yours, H I)zv&s&on Manager of Product&on mc ' ECEIVEo MAR 1 ? 1981 Oil & Gas 0o/15 9' , STATE OF ALASKA ALASK/~ IL AND GAS CONSERVATION (~ '~vlMISSlOU SUNDRY NOTICES AND REPORT ON WELLS DRILLING WE LI_,,[~ COMPLETED WELL [] OTHER I-I 2. Name of Operator Conoco Inc. 3. Address 320! "C" 4. Location of Well Street Suite 403 Anchorage, AK 99503 214' FNL and 4235' FEL of Sec. 19, T13N, R10E, UM 7. Permit No. 80-75 8. APl Number 50-- 029-20490 9. Unit or Lease Name Milne Point Unit 10. Well Number ~7-I 11. Field and Pool 5. Elevation in feet (,ndlcate KB. DF, etc.) I 6. Lease Des,gnatlon and Serial No 46 ' KBI ADL 47438 12. Check Appropriate Box Io Indicate Nature of Notice, Report, or Other Data Wildcat NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~] Alter Casing [] - Perforat,ons [] Altering Casing Stimulate [] Abandon I-'] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note: Report multtple completions on Form 10-407 with a submitted Form 10-407 for each completion.) D D [] 13. Describe Proposed or Completed Operations (Clearly state all pemnent details and g~ve pemnent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25105-170) Estimated date of starting work - March 15, 1981 Proposed Operations: 1) Set a bridge plug on wireline at 9340'± 2) Perforate with 4" casing guns from 9270' to 9300' with 12 per foot. 3) Test the well using DST tools. 4) Set a retainer 30' above the perfs and squeeze perfs with 5) jet shots cement, and a 100 foot cement plug will be placed above A cement plug will be placed across the 7" liner top at in length. (Top of 7" liner at 7484') 100 CF of the retainer. least 100' A proposed completion plan of subsequent zones to be tested will be sub- mitted to the Commission after completion of this test. RECEIVED (Verbal approval given by Russ Douglass on March 13, 1981) MAR 1 6 1981 Alaska 0il & Gas Cons. C0mmissi0 Anchorage 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Signed T~tle Senior Production Engr. The spa~below f mmiss,on use OateMarch 13, 198 Condittons of Approval, if any Form 10-403 Rev. 7-1-80 COMMISSIONER By Order of the Commission Cop), iletumed Submit "Intentions" in Triplicate and ;'Subsequent Reports" in Duphcate STATE OF ALASKA ALASK_/~~ L AND GAS CONSERVATION C(' IMISSION / MO___NT_H_LY REPORT OF DRILLING AND WOR_'KOVER OPERATIONS / Drdhng well ~] Workover operatton [] 2 Name of operator 7 Permit No. Conoco Inc. 80-75 3 Address 8 APl Number 3201 "C" St. Suite 403 Anchorage, AK 99503 50-029-20490 9 Un,t or Lease Name Milne Point Unit 4 Location of Well at surface 214 FNL and 4235' FEL of Section 19 T13N, R10E, UM 5 Elevation ~n feet (~nd~cate KB, DF, etc ) 6 Lease Designation and Serial No 46' KB ADL 47438 10 Well No No.2 11 Field and Pool Wildcat For the Month of February ,1981 '12 Depth at end of month, footage drdled, hsh~ng jobs, d,rect~onal drdhng problems, spud date, remarks 9291' ,core and drill 7297' to 7625'. Log and run 9-5/8" hole size to 8½" and drill and core to 9291'. csg. Reduce 13 Cas~ngor hner run and quantmes of cement, results of pressure tests Run 190 joints S00-95, 9-5/8" butt. casing with shoe @ 7617' . Cement with 580 sks self-stress cmt. w/l% D-60 and .2% D-13 and 2% D-46. DV collar at 5033' - second stage cement job thru DV collar of 417 sacks self-stress cement w/l% D-60, .2% D-13 .2% S-l, .2% D-46. Attempted to place Arctic-Pac~ behind 9-5/8" csg. through F.O. collar at 2500' but could not circulate annulus. Appears to be stringers of cmt. above F.O. tool. 14 Coring resume and brief description Core #6 7295'- 7355' Recovered 60' Core #7 7355'- 7415' Recovered 60' Core #8 7415'- 7475' Recovered 40.5' Core #9 7475'- 7535' Recovered 0' Core #10 9203'- 9231' Recovered 28' Laminated sand Laminated sand Laminated sand Shale w/no oil ---Continued on back & shale w/some oil & shale w/some oil & shale w/some oil shows 15 Logs run and depth where run Run 2/5/81 DIL/SFL/GR/BHC 7600' FDC/CNL/GR 7600' LSS 7600' HDT 7600' RFT tool was also run 4 times above 7600'. Run 2/26/81 DIL/SFL/GR Correlation Log 9180' DST data, perforating data, shows of H2S, m~scellaneous data - 6400' - 3900' - 2637' - 2637' - 7600' RECEIVED MAR 1 1 1981 Oil & Gas Cons. Commission /mclmrage 17 I hereby certIfy that the foregoing ~s true and correct to the best of my knowledge SIGNED ~ .%J'~ TITLE Drilling Supervisor DATE March 9, 1981 how~ how~ how~ NOTE--Report on th~s form ~s required for each calendar month, regardless of the status of operations, and must be fded ~n duphcate w~th the Alaska Od and Gas Conservation CommissIon by the 15th of the succeeding month, unless otherwise d~rected Form 10-404 Submit ~n duphcate Rev 7-1-80 14. Core #11 9231'-9291' Recovered 60' 40' of shale, then 20' sand with some visible oil cut. Core #12 9291'-9351' Recovered 60' 25' of sand w/oil shows,then 35' of shale and limestone. Sidewall cores - Shot 81, Recovered 65 STATE Or: ALASKA ALASK/ :L AND GAS CONSERVATION C( IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1 Drdl~ng well [] Workover operation [] 2 Name of operator 7 Perm,t No Conoco Inc. 80-75 3 Address 8. APl Number 3201 "C" S. Suite 403 Anchorage, Alaska 99503 50- 029-20490 4 Location of Well at surface 214 FNL and 4235' FEL of Section 19 T13N, R10E, UM 9 Umt or Lease Name Milne Point Unit 10 Well No No. 2 11 F,eld and Pool Wildcat 5 Elevation ~n feet (,nd~cate KB, DF, etc ) I 6 Lease Designation and Serial No 46' KBI ADL 47438 For the Month of January ,19 81 Set 13-3/8" 12 Depth at end of month, footage drdled, hsh~ng jobs, d~rect~onal drdhng problems, spud date, remarks 7297' progress 7297' spud 1/4/81, drilled 17½" hole to 2635'. csg. and drill 12¼" hole directionally with S-type hole. 13 Casing or hner run and quantmes of cement, results of pressur9 tests 20" conductor preset at 105' RKB and cemented to surface. Ran 68 joints 13-3/8" csg. 72 #/ft. N-80 buttress, and set csg. @ 2635'. Cemented with 4000 sacks permafrost cement and 50bbls od ement returns to surface. . NU BOPE and test casing to 2000 psi for 30 min. 14 Coring resume and brief description Core #1 3925' - 3938' Recovered 11' Silty SS w/some free oil & good show Core #2 3938' - 3966' Recovered 28' Fine Gr. SS bleeding oil & gas. Core #3 4197' - 4226' Recovered 12' Silty SS with faint odor but no stai: Core #4 4550' - 4571' Recovered 18' Fine Gr SS bleeding oil & gas Core #5 7235' - 7295' Recovered 60' Laminae of silt & sand, upper 15' Recovered 17 sidewall cores, bleedinq oil & gas. Correlation log 15 Logs run and depth where run Run 1/8/81 DIL/SFL/GR/BHC 2635' - 105' LSS/GR 2635' - 105' Run 1/21/81 DIL/SFL/GR/SP 4458' - 2635' FDC/CNL/GR 4430' - 2635' Run 1/29/81 DIL/SFL/GR 6989' - 2635' 16 DST data, perforating data, shows of H2S, m~scellaneous data 17 I hereby cert,fy that the foregoing ~s true and correct to the best of my knowledge DATE February 5, !981 SIGNE~) ~~J ~"~~I-ITLE Drillinq Supervisor NOTE--Report on th~s form ~s required for each calendar month, regardless of the status of operations, and must be fded ~n duphcate w~th the Alaska O~1 and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise d~rected Form 10~t04 Submit ~n duphcate Rev 7-1-80 January 16, 1981 ,Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 Re: Conoco Milne Point Unit No. 2 Permit No. 80-75 Dear Mr. Wondzell: Enclosed with this letter is a sundry notice, outlining our proposal for Milne Point Unit No. 2 to set 9 5/8" casing 200' below the lower Kup River sand at 7400' TVD. As you requested in our phone conversation on January 13, the following list contains pertinent reservoir information on the Kuparuk River formation obtained from DST work performed on Milne Point Unit No. 1 last year: Reservoir Depth Reservoir Pressure Reservoir Pressure Gradient Reservoir Temperature Gas Gravity - 7068' - 3539 psig - 0.5 psi/ft - 178OF - 0.729 The base of the Kup River sands is estimated to be at 7210' TVD. In reviewing logs from the North Slope area, there are no sand formations 200' below the Kup River sands, so the deepest possible point of gas entry into the wellbore at Milne Point would be about 7210'. With a formation pressure gradient of 0.5 psi/ft, as found in Milne Point Unit No. 1, a reservoir pressure of 3605 psig was used in calculating maximum surface pressure. A maximum surface pressure of 3015 psig was calculated using the following equation: Ps - Pr (e-0. 347GD) Ps = Surface pressure, psia Pr = Reservoir Pressure, psia G = Gas Gravity D = Depth, ft x 10-4 The surface pressure of 3015 psi g ass~/~,~_ntire column of gas (0.82 psi/ft) in the wellbore. ? · 8~ka Oil & Gas Cons. COrem,--. Conoco Milne Point Unit No. 2 Permit No. 80-75 cont'd We are therefore requesting approval for setting 9 5/8", 47# casing 200'± below the bottom of the lower Kup River sand at 7400' TVD. If you have any questions please call me at 279-0611. Sincerely, · Gary A. Merriman Senior Production Engineer CONFIDENTIAL ' STATE OF ALASKA CON~DEN~A~ SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL [] 2 Name of Operator 7 Permit No Conoco Inc 80-75 3 Address 8, APl Number 3201 "C" St. Suite 403 Anchorage , Alaska 99503 50- 029-20490 4 Location of Well OTHER~ Wildcat 214' FNL and 4235' FEL of section 19, T13N, R10E, UM,. 5 Elevatmon mn feet (mndlcate KB, DF, etc ) 46 ' KB 12 Lease Desmgnatmon and Sermal No ADL 47438 9. Unmt or Lease Name Milne Point Unit 10 Well Number Milne Point Unit No. 2 11 Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF' (Submit m Tr~plmate) (Submit mn Duplmate) Perforate [] Alter Casing [] , Perforations [] Altermng Casing [] Stimulate [] Abandon [~] Stimulation [] Abandonment [] Repair Well [] Change Plans ~ Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multmple completions on Form 10-407 w~th a submmtted Form 10-407 for each completmon ) 13 Describe Proposed or Completed Operatmons (Clearly state all pertinent detads and grove pertinent dates, mncludmng estimated date of startmng any proposed work, for Abandonment see 20 AAC 25 105-170) In Conoco's original application to drill, Oil & Gas Conservation Commission in July submitted t 1980, it was a 5000#, 13 3/8" casing head would be used on Milne Po However, a 5000#, 13 3/8" casing head was not availabl 13 3/8" casing head has been installed on the surface In order to safely drill to our objective, we propose 47# casing approximately 200' below the bottom of the sand at 7400' TVD (about 7600' MD) with a 9 5/8", 5000 If formations below the 9 5/8" casing shoe warrant tes 29# liner will be run to TD and cemented. o the Alaska stated that int Unit No. 2. e and a 3000#, casing string. to set 9 5/8", Lower Kup River # casing head. ting, a 7" RECEIVED JAN 1 6 1981 Alaska 0il & Gas Cons. Commission Anchorage 14 I hereby ce/~y that the foregoing ~s true and correct to the best of my knowledge S,gned . T~tld~enior Production The space~elow for,~'omm,ss,on use Conditions of Approval, ~f any /~'~ ~)~ '~,~ COMMISSIONER Approved by Form 10-403 Rev 7-1-80 Engr .... Date .Jan uar~f 14;19 Approved . opy Returned By Order of the Corem,ss,on r~ate Submit "Intentions" in Trmphcate and "Subsequent Reports"in Duphcate 81 ( ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton~ Chairman I"" ,~/ Thru.. Lonnie C. Smith ~~ Commissioner / "' Bobby Foster~~' Petroleum Inspector January 15, 19 81 Witness BOPE Test on CONOCOtS MILNE POINT #2 Sec. 19, T13N, RllE, UM Permit % 80-75. While standing by for a BOPE test on Sohio's M.P. 43-31-11-13 I went to CONOCO tS MILNE POINT J2 and witnessed the BOPE test there. The test began at 8:~0, pm and was concluded at 1530 am 01--13--81'j Due to a 30~00 psi by 5000 psi 20w x 13 3/8w cross over spool this test was a~3000 psig,, ~ When setting the 9 5/8u casing at 7400.- this spool wi1! be changed out and a 5000 psi test will be per- forme~ o ~ ~ As the test report ~hows there were two failures. The upper kelly valve lea~e~ and the BOPE control panel on the rig floor would not operatOT~ bUt the Koomey repair man was on site and was waiting on repair par%s. In summary, I witnessed the BOPE test on CONOCO~S MILNE POINT #2. January 15, 1981 ..... h.' Mr. Jim Kothe~ Parkgr tool pusher notified me this date at the BOPE control~ ~. ~aneii6~' ~e~,rig~fl0o~iha~ibeen repa~re9 an~ operated correctly and"the'~pPe~r kglly~va!¥e~ha4 been rep.a~,re~ an', tested to 300o psi. r' ~ ~'~ ~ ' O&G #4 4/80 STATE OF ALASKA ( A[2tSKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspectxon Report Operator Well Date /~ /~- ~/ ;;ell/~//~ ~/k~/ Permit # ~O-75 / - Location: SecT/_3 iRIiFt, uF,~ ld~caslng Set @ ~dC~ ft. Drilling Contractor ~/~~F~? Rig #/~ Representative .l,'~ ~C?~_. 'Location, General Well Sign ~~ General Housekeeping Reserve pit ~~ Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure ACCUMULATOR SYSTEM Full Charge Pressur .~/~ psig Pressure After Closure./~P ~ psig 200 psig Above Precharge Attained: -- min~_~sec Full Charge Pressure Attained:_ ~' min ~sec Controls~.: Master. ~~ -~'Remote~4~ Blinds switch cover4z~ ~ / / Kelly and Floor Safety Valves Test Results: Failures ~pper Kell~ Lower Kelly Ball Type Inside BOP / Test Pressure Jo0~p / Test Pressure 3bo~ / Test Pressure 3 ~ ~ ..... / Test Pressure qZ~'-- Choke Manifold ~ Test Pressure~o~P~ 1 No. Valves / ~ No. flanges _~D Adjustable Chokes i - [ ~3~, H~"drauically operated choke. / Test Time ~- hrs.. R~paiY or Replacement of failed equipment to be made within days and Inspector/Commission office notified. cc - Operator cc - Supervisor H. D. Hal®y Manager of Production Ventura Division October 12, 1980 Mr. L. C. Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' Conoco Inc. 290 Maple Court Ventura, CA 9300; (805) 642-8154 Re- API #50-029-20490, Conoco Milne Pt. Well No. 2 In our above mentioned permit request the surface location was given as 630 ft. from the west line and 134 ft. from the north line of Section 19, T13N, RllE. c,/G o This is to advise you that the surface location for this well is now pro- posed at 1045 ft. from the west line and 214 ft. from the north line at the same section, township, and range. This change is due to a U.S. Fish and Wildlife Services request. If any further information is needed, please contact Mr. Gary Merriman of our Anchorage office. Very truly yours, ~~ DiviSion Manager of Production DLD- 1 em cc' G. A. Merriman, Anchorage ,,, WELL X = 6,022,910.307 ! Y = 572,058 417 I I LAT = 70°28'22. 353" I ' LONG = 149°24'41.192" I , , , 13 I I~B · ~ I~ 17' __ ,, --- ~4 19 , , TI~N, RIO[, U, M i ~CAL[ I HEREBY CERTIFY THAT ! AM . PROPERLY REGISTERED AND ' ' , LICENSED TO PRACTICE LAND ..~.',.~ SURVEYING IN THE STATE OF REPRESENTS A SURVEY gADE BY ME, AND THAT ALL DIHEN- S IONS AND OTHER DETA ! LS , ~c ~..,~ ARE CORRECT AS OF- DATE: I ~ " .. ' ', II I I II I ~T~: D~WI~G ~o: ~0~0~0 I~~. /~.,-~ III I I I II Nr. H. D, Haley Division Manager of Production Cono~o 2~0 Naple Court, Suite 128 Venture, California 93003 Ret Co~oco e~. al. #ilne Point So. 2 Cono~o SUr. LOC.~ 4650°FEL, 134°~Lt Sec. 19~ T13N, Rl~g, UPH. ~t~Ole ~C.8 3960*FBL, 1320e~L, Sec. 19, T13N, RILE, UPM. Enclosed lo the approved application £or permit to drill the abov~ reforeneed well. Well samples, core chips and a mud log are required. A direettwnal survey is required. If available, a tape contain- ing the digit,zed log information on all log's shall be sub- mitred for cc~yin9 except exl~erimental logs, velocity surveys and dipueter surveys. #any rivers in Alaska and their drainage systems have been anadromou8 £ish, Operations ~n these areas are sub~Ject to AS 16.50.870 and the regulations promulgated thereunder (T~le 5, Alaska Administrative Code). PE~o~ to commencing operations you m~y be contacted by the Habitat Coordinator's o££ice, Departnent of F leh and Game. Pollution o£ any waters of the State ~s prohL~ted by AS 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the federal Water Pollution Control Act, as anended. Prior to )ir. II. D. Iialey -2- Conoco et al. I~tlne Point No. 2 July 25, 1980 commencing operations you may be contacted by a representative of the Department of Environmental Consemtton. Pursuant to AS 38.40, Local Iitre Under State Leases, the Alaska Department of Labor ts beAng notAf~ed of the Aesuance of thAs permit to To aid us ~n scheduling fAeld ~ork, we would apprecAate your notLfyLn9 thLs o£ftce wLth~n 40 hours after the well is spudded. We ~uld also l~e to ~ ~ttfted so ~at a repre- of bl~out preventer ~ul~nt before surface casing sh~ is la the event of suspension or abandonment, please gave this off,ce adequate advance notl£~catton so that we may have a Co~n~ss~oner of - _o~ ~ ~HE COMMI$~IO~ Alaska Otl & Gas Co~va~on Znclosure DepaEtmen~ of Flab & Game, Habitat SectAon ~/o encl. Depa~nt of Bnv~nmental Conservation w/o/encl. Department of Labor~ Supervisor, Labor Law Compliance D~vie~on w/o e~cl. LCSsbe SUPPLEMENTAL DATA SHEET FOR APPLICATION FOR PEP~IT TO DRILL CONOCO et al. MILNE POINT NO. 2 CONOCO INC. 290 ~aple Court Ventura, Calif. 93003 I. CE~IENTING PROGRAM A. The 20" OD Conductor Casing will be Cemented to the surface with perma- frost Cement in 26" Bucket Drilled Hole. B. The 13 3/8" OD Casing will be cemented to the surface with permafrost Cement followed with 100 Sx neat Cement,,thru Drillpipe Stinger stabbed into Float Collar and thru Float Shoe. C. The 9 5/8" OD Casin~ will be cemented thru Plug Container Head, Float Shoe, and Float Collar with 2000 Sx neat Cement. Isolation of the 13 3/8"-9 5/8" Casing Annulus @ the 13 3/8" Casing Shoe will be accomplished thru Multi-stage Cementing Collar run at the 13 3/8" Casing Shoe with 125 Sx_of permafrost Cement. Non-freezing Fluid will be placed in the 13 3/8"-9 5/8" Casing Annulus thru the permafrost utilizing Multi-stage Cementing Collar placed at the base of the .Permafrost. II. ANTICIPATED GEOLOGY O' -4,500' 4,500'-7,100' 7,100'-7,900' 7,900'-8,900' 8,900'-9,000' 9,000'-9,200' 9,200'-9,900' 9,900'-T.D. III. FORMATION EVALUATION Surface Conglomerates, Silt and Sand sequences. Estimated base of Permafrost @ 2,000'. Siltstone, Shales Kuparuk River Formation Kingak Formation Sag River Formation Shublik Formation Sadl erochit Formation Kavi k Formation A. Standard ~,lud Logging Equipment will be installed while drilling interval 60' . to Total Depth. B. Full Size Cores may be taken as determined by on-site geologists. C. Wireline Logs including: Dual Induction Laterolog; Borehole Compensated Sonic-Gamma Ray; Formation Compensated Density with CNL & GR-Caliper; High Resolution Dipmeter Survey; and Velocity Survey. Page 4 IV. DRILLING FLUIDS Depth Type Density 0'-2,600' 2,600'-7,000' 7,000'- 10,000' Gel - Fresh Water Low Solids - Lignosulfonate Low Solids - Lignosulfonate 9.5 - 10.0 ppg. 9.5 - 10.0 ppg. 10.0 - 10.8 ppg. V. 'm, ANTICIPATED PRESSURES / -/~o.ro /m~l~,~ The anticipated maximum downhole pressure is 4,900~ig at Total Depth (IO,O00'MD), and the anticipated maximum surface pressure is~psig. These values were determined from offset well data, including DST and production tests. These tests reflect a formation pressure gradient of 0.49 to 0.50 psi/ft, and a produced fluid gradient of approximately 0.30 psi/ft. Offset wells used in determination of pressures include: Hamilton Bros. Milne Point No. 18-1 Chevron USA Kavearak Point No. 32-25 Conoco Milne Point No. Sec. 11, T13N, RIOE, UM Sec. 25, T13N, RIOE, UM Sec. 23, T13N. RIOE, UM Page 5 III ii i ii i ii WELL Y = 6,022,982.07 X = 571,643o96 LAT = 70°28~23o098'' LONG = 149°24~53o358" I I t hereby certify that I am properly reqlstered and licensed to oract~ce Land Surveying in the State of Alaska and that this plat represents a survey made by mc, and that al1 dimensions and other details are correct, 4-6.%0' 18 MILNE POINT UNIT 2 CONOCO INC. WE L L LOCATION · : t ~ ~E--: .... ~ R ~W , NG N 0 : ] IIii III I iiii ...... __ -- -- ~7 ( PLAN VIEW ) T I.~N - RIOE 24 18 -.,-630'-.-~SURFAC£tLOCATION- 1.,',','74' FNL & 630'FWL of Section 19 1320' : ~BOTTOM HOLE LOCATION- 1320'FNL ~ 1320'FWL of Section 19 T I~N - RI~ E .i CONOCO ~ ,, MILNE POINT Ne 2 V.D. S S. --~000 '---- IVONTHWFSy~Ry SOUTN£~5~Et~LV V.O.S S I '1- 0°, 2630' M.D. (K.O P.) I PRINCE CREEK ~ 357o' 14.D. SEABEE Jo'---- KUP RIVER . I0,000'~ L oo, 7oG5' ~.o. ! I I I I ! J 79 I0' M O. I I I I I I ! J 8880' M.D. ! KINGAK 9150' M D. SAG RIVER SA DI EROCHI T ~.. $1~?£~C£ LOCATION IO,OOo' M.D. KAVIK CONOCO INC. MILNE POINT N~- 2 lC&L[ I". I000' APP~OYKD Drill Site and Rig Layout [, ~ocd · ! 400' ! Fuel Sloroge Area I I ! I 150' 200' ~ln~rnu~rJ RIG ,! AREA 44' Section £~" For -~,4'-'-- - -=- - ...... ~,....?r c ma g; Toward- Slope : I' ~er 50' Deep Page 7 20"O.D. CASING B.O.P. STACK G" l) Relief lines from the drilling spool will be routed to accomplish downwind diversion. ~ tt/draul~c control system for this stack to include 180 gal. capac~t/ accumulator and reservoir and control manifold on rig floor with 3000 psl working pressure. BOP STAC:< FOR 20' OD CASi~tG , I CO~OCO I~IC. ~ / as the diverter is closed the remot~ control valve will be activated auto- matically to the open position. BLOW PREVENTER FOR CASING FILL U;~ I NOTES: 2) 3) 4) BOP Stack Size Rating meets API RP53 & Spec. 6A for Class 5ti with Clamp & Hub Connectors all Hydraulic Operated. BOPE to be operated on each trip & Pressure /Tested weekly. Hydraulic Control System for BOPE to include (5) Station Control Manifold located remote with 160 gal. Accumulator and Reservoir Unit and Auxiliary Energy Source for system activation. RAH TYPE BOP to include a minimum of one set of blind Ramsond two sets of appropriate Pipe Rams. CHOKE & KILL MANIFOLDS shown separately, to meet API RP53 Class 5H requirements. SPOOL CC, NCg,,S,~I,;.- MILNF' POINT Pace 9 FROM REMOTE HIGH PRESSURE PUMP CHOKE & KILL h/~ NIFOLDS FOR 137o t~ 9~'OD CASING BOP STACK ROM MUD PUMP KILL MANIFOLD ~ ~IVUD/G~,.S SE P,~RATOR NOTE: 1. DRILLING SPOOL HYDRAULIC CONTROLLED REMOTE OPERATED REMOTE PRESSURE GUAGE SENSOR L J BLEEDLINE 3'0 PIT Hydraulic Control System for BOP Stack g Choke Manifold to include (5) Station Control Manifold located remotely with 3000 psi Accu~ulator ~ 160 gaL'. Reservoir ~ Auxiliary Energy source. Station Control Hanifold plus variable Choke Control to be located on Rig floor. 2. Kill 6 Choke Manifolds to meet APl RP53 Class 5H Standards. 3. Kill }Lnifold Size-Ratan£ 2"-5000 4. Choke Hanifold Size-Rating 3"-5000 CHOKE MANIFOU TO SHALE J SHAKER BOP MANIFOLD LAYOUT CONOCO, INC. H. D. Hal®y Manager of Production Ventura Division July 22, H980 Hr. Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 300H Porcupine Drive Anchorage, Alaska 9950H Conoco Inc. 290 Maple Court Ventura. CA 93003 (805) 642-8154 Fl!l:. Dear Hr. Smith: Enclosed are permit requests for the authority to drill Milne Point No. 2, and Gwydyr Bay No. 2 on the Alaskan North Slope. These requests have been altered by your request, and they include the followin~.- (1) maximum anticipated downhole and surface pressures, (2) a revised diverter system with an automatic remote control valve, (3) a revised BOP system with three ram preventers rather than two, and (4) a location map showin~ the unit boundries. In the Gwydyr Bay No. 2 permit a TVD map showin~ previous wells drilled on the proposed location was also in- c l uded. Thank you for your assistance toward completion of these permits· If there seems to be a permittin~ problem, please contact either Dave Dooley or Bary Herriman immediately. They can be reached by cai lin= collect to ( 805 ) 642- 8 ~54 · Very truly yours, H. D. Haley ,~ Division Nana~er of ~bduction GAN-mc encl cc: File RECE!Vr:D H. D. Haley Manager of Production Ventura Diws~on July 3, 1980 Conoco Inc 290 Maple Court Ventura. CA 93003 (805) 642-8154 Hr. H, W. Kugler, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Kugler: Permit Request Hilne Point Enclosed is a permit request for the authority to drill an oilwell on the Hilne Point Unit of the Alaskan North Slope. Haterials attached to the request include (I) a plan view, (2) cross section, (3) supplemental drilling data sheet, (4) site survey, (5) schematic of rig layout, (6) 20-inch BOP schematic, (7) 13 3/8-inch and g 5/8-inch BOP, (8) choke and kill manifolds, and (g) location map. Conoco desires to drill this well according to the attached plan in an effort to further fulfill the applicable unit agreements and more assuredly evaluate the commercial hydrocarbon possibilities within the lease. It is anticipated that construction will beg±n during- the first week in November, 1980 or when there is 12 inches of frost in the ground (whichever comes sooner). Your contact relative to the permitting of this well is David Dooley. He can be reached by calling collect to (805) 642-8154. In the event of a permitting problem, please contact him. Very truly yours, H. D. Haley Division Nanager of Production DLD/Icc encs. cc: File H. D. Hal®y Manager of Production Ventura D~ws,on Conoco Inc. 290 Maple Court Ventura. CA 93003 (805) 642-8154 July 9, 1980 Mr. Lonnie C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Under separate cover Conoco has submitted applications to drill two wells. Enclosed are two $100 checks for the filing fees for these wells. Very ~rj~ly ypurs, /1'~. D. Haley Division Manager of Production CRC/lcc encs. H. D. Haley Manager of Production Ventura Division Conoco Inc. 290 Maple Court Ventura CA 93003 (805) 642-8154 July 3, 1980 Hr. H. W. Kugler, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine ])rive Anchorage, Alaska ggsoI Dear Hr. Kugler= Permit Request Hilne Point Enclosed is a permit request for the authority to drill an oilwell on the Hilne Point Unit of the Alaskan North Slope. Haterials attached to the request include (I) a plan view, (2) cross section, (3) supplemental drilling data sheet, (4) site survey, (5) schematic of rig layout, (6) 20-inch BOP schematic, (7) 13 3/8-inch and g 5/8-inch BOP, (8) choke and kill manifolds, and (g) location map. Conoco desires to drill this well according to the attached plan in an effort to further fulfill the applicable unit agreements and more assuredly evaluate the commercial hydrocarbon possibilitzes within the lease. It is anticipated that construction will be~in durinE the first week in November, 1980 or when there is 12 inches of frost in the Eround (whichever comes sooner). Your contact relative to the permittin~ of this well is David Dooley. He can be reached by callinE collect to (805) 642-8154. In the event of a permittin~ problem, please contact him. Very truly yours, H. D. Haley Division Hana~er of Production DLJ)/Icc enos, cc: File Form 10-401 REV. 9-1-78 STATE OF ALASKA ( SUBMIT IN TRIPlet ~TE (Other instructions on reverse side) ALASKA al L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL OR DEEPEN la TYPE OF WORK DRILL [~ DEEPEN [--! b TYPE OF WELL OIL GAS WELL ~-] WELL O OTHER Expl oratory SINGLEzoNE [---i MULTIPLEzoNE 2 NAME OF OPERATOR Conoco I nc. 3 ADDRESS OF OPERATOR 290 Maple Court, Suite 128, Ventura, CA 93003 4 LOCATION OF WELL At surface Sec~ion.19.zoT. e13N RllE 4650' FEL 134' FNL proposeo proa ' Section 19, T13N, Rl lE 3960' FEL 1320' FNL 13 DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 31 miles to Deadhorse, Alaska ~4. BONDINFORMATIO~3ubmitted on Form P 2, Dated June !963 TYPE surety and/or No. Federal ~ns. Co. 8015016154 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest dng, umt, ff any) 1[16 No OF ACRES IN LEASE 2560 19 PROPOSED DEPTH Southwes 10,000' API #50-029-20490 6 LEASE DESIGNATION AND SERIAL NO ADL 47438 7 IF INDIAN, ALLO'ITEE OR TRIBE NAME N/A 8 UN1T ~ NAME Conoco et. al. Milne Point 9 WELL NO 2 10 FIELD AND POOL, OR WILDCAT Exploratory 11SEC, T , R., M , (BOTTOM HOLE OBJECTIVE) 19-13N-11E UPM 12 North Slope Borough ~mount $100,000 18 DISTANCE FROM PROPOSED LOCATION 630' FW1 TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT Conoco Mi lne Point No. 1 8487' 21 ELEVATIONS (Show whether DF, RT, CR, etc.) NO ACRES ASSIGNED TO THIS WELL 640' 20 ROTARY OR CABLE TOOLS Rotary 22 APPROX DATE WORKWILL START 40' GR- Estimated from U.S.G.S. Topo November 1, 1980 23 PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE ~ SETTING DEPTH ~ant~ty of cement 26I' 20" O_B. 94.0 H-40 100' £ament to surface. 17½" 13 3/8tI 72.0 MN-80 2600' £~mant to surface 3000 sx. ]9~'' 9 5/8I' k7_0 S00-95 lnnnn, ?n0o sx. Proposed surface and bottom hole location plat enclosed. As-built survey plat to be submitted after setting conductor casing. See attached Supplemontal Data Sheet. See attached well head and blowout preventor drawings. *Measured depth. Al~k~ 0~'. c'~° G,_s. _~: ........... IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM If proposal ,s to deepen give data on present productive zone and p~ra[~0 new productive zone. If proposal Is to drill or deepen d~rect~onally, give pertinent data on subsurface locations and measured and true vemcal depths. Give blowout preventer program 24 I hereby certify that~the?o~r~egoln~g lS True and Correct SIGNED ~'~L ~ .~~ ~_~ (Ttus space for State office use) SAMPLES AND CORE CHIPS REQUIRED I MUD LOG ~[YES [] NO [ ~ YES DIRECTIONAL SURVEY REQUIRED [~YES [] NO DATE 7-3/80 Division Manager TITLE of Production CONDITIONS OF APPROVAL, IF ANY OTHER REQUIREMENTS [] NO A P I NUMERICAL CODE PERMIT NO. ~ ~' TM ~ APPROVAL DATE July 25, 1980 APPROVED BY ~ ...... ~ '',~._7~ TITLE Co~mission~ DATE ~¥ ~ - ~ ~ - - *See Instruction On Reverse Side 07/25/80 CHECK LIST FOR NEW WELL PERMITS Item Approve Date (1) Fee '//~ ~/~/~o O (2) Loc./~/'~ (3) Aimin.~~ Company 1. Is the permit fee attached ......................................... .~~_ 2. Is ,~11 to 1~ located in a defined pool ............................. ~.~,~_ 3. Is a registered survey plat attached ................................ / 4. Is well located proper distance frcm property line .................. Remarks 5. Is well located proper distance frcm other wells .................... 6. Is sufficient undedicated acreage available in this pool ............ /_ 7 Is well to be deviated .................................... 8. Is operator the only affected party ................................. / 9. Can permit be approved before ten-day wait ........................ ' ' 10. Does operator haves bond in force ............... · ..... - ..... 11 Is conservation order needed · a ......:......... .........-......-;.... 12. Is administrative approval needed ................................... _ 13. Is conductor string provided ........................................ ~ (4) Casg. ~ 14. Is enough cement used to circulate on conductor and surface ......... ~ 15. Will cement tie in surface and intermediate or production strings ...~ ( 16. Will cement cover all known productive horizons ..................... ~ 17. Will surface casing protect fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and burst.. (5)BOPE ~ ~L~~&. 19. Does BOPE have sufficient pressure rating - Test to ~--~oO psig .~.. Approval Reconmended: dditional Requirements: ff. ~- ju ~, /-~...J' ~. ~',',A ];~'-,//~'- Geology: Engin .eering: - '- / ,/ z -~ ' ~ ~/~t~/~ . rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 11 11 1111 11 11 11 11 11 11 11 11 111111 111111 666666 666666 66 66 66 66 66666666 66666666 66 66 66 666666 666666 66 66 66 66 000000 7777777777 000000 000000 7777777777 000000 00 00 77 00 00 00 O0 77 00 O0 00 0000 77 O0 0000 00 0000 77 00 0000 00 O0 O0 77 00 00 OO 00 O0 O0 77 OO O0 O0 0000 00 77 0000 O0 0000 00 77 0000 00 O0 77 00 O0 00 00 77 O0 O0 000000 77 000000 000000 77 000000 11 44 44 5555555555 11 44 44 5555555555 1111 44 44 55 1111 44 44 55 1! 44 44 555555 11 44 44 555555 1! 4444444444 55 11 4444444444 55 11 44 55 11 44 55 1~ 44 55 55 Jl 44 55 55 111111 44 555555 111111 44 555555 7777777777 7777777777 77 77 77 77 77 77 ;7 77 77 77 77 77 5555555555 5555555555 55 55 555555 555555 55 55 55 55 55 55 55 55 555555 555555 GGGG G G G G GG(; G G GGG H H BI~BB H H B B H H B B HHHHH BBBB H H BBBB PPPP RRR[~ U U DD~D H H UOO P P R R U U D D H H O O P P R R U U D D H H (] O PPPP RRRR U U D D HHHHH O O P R R U U D D H H 0 0 P R R U U D D H H O O P ~ R UUU[IU DDDD H H OOO EEEEE E E EEEE E E EEEEE *STARTS MONITOF' MONIT(IR USER PCAL SWS KL10E40 USER PCAL SWS ~LIOE40 [10707,61455] jOB SHIP SEO. 7153 DATE 22-MAR-81 NOV'80. *START* [10107,614553 dOB SHiP SEO.~3 DATE 22-MAR-81 NOV 80. *START* 11:2]:52 11:2~:52 N11MBI~ {3I- BEC(JRDS: 137~ LENGTH (]F RECORDS: 1014 gYTES LENG~rh {IF LAST ELCtJRD: 78 BYTES FILE IRAILER LENGfb.' 62 BI/TE$ FILE NAME: EDIT ~001 MAXIMUM PHYSICAL R~,~URD LENGTH: NEXT ~ [L~ NAME: TAPE T~AIhER LENGTM: 112 B¥'FLS TAPE NAME: 61455 SERV1Ck NA~E: EDIT TAPE CONTINUATION NUMBER: 01 NEXT rAPE NAME: COMMENTS: 1024 B~TES DATE: 81/ 3/22 I)LPTH ?00. 000 6O0.0O0 500.000 400.000 ~00.000 200.000 100.000 ~5.000 ~Nk~tJN1C V A L UI::;, ~[' -121.500 GR 45.922 NPH1 -99q25.000 FCNL -999.250 DT -999.250 SP -135.000 GE 34.313 NPHI -99q25.000 FCNL -999.250 DT -999.250 Sk -132.500 GR 43.094 NFHI -99925.000 ~CNL -999.250 D? -999.250 SP -130.50i) GR 48.08b NPHI -99925.000 ~CNL -999.250 DT -999.250 SP -117.500 GR 36.109 NPHI '99925.000 FCNL '999.250 DT '999.250 SP -150.000 GR 51.281 NPHI -99925.000 FCNL -999.250 DT -999.250 SP -8.21q GR 28.414 NPHI -99925.000 FCNL -999.250 DT -999.250 SP -999.250 GR -999.250 NPHI -99925.000 FCNL -999.250 DT -999.250 MNEt, IUN IC GR RHO~ GR GR RHOB GR ILD GR ~HOB GR ILD GR RHOB GR ILD GR RHOB GR ILD GR RHOB GE ILD GR RHOB GR ILD GR RHOB GR VALUE ~7.719 -999.250 -999.250 45.922 112.063 .-999.250 999.250 ,~4.313 21 141 -999:250 -999.250 43.094 7.117 9,250 48°086 62.750 -.999.250 999.250 36.I09 70.625 .-999.250 99q .250 51.28! 4.336 -999.250 -999.250 28.414 -999.250 -999.250 -999.250 -99q.250 MNEMONIC CALl NEAT DT ILM CALl DT 1LM CALl NRAI DT ILM CALl DT ILM CALl NRAT DT ibm CALl NEAT DT CALl NEAT DT CALl NEAT DT VALUE 11.938 -999.250 -999.25O 152.031 37.813 -999.250 -999.250 117.438 12.672 -999.250 -999.250 156.000 5.355 .-999.250 999,250 207.219 26.422 -999.250 -999.250 138.594 33.156 -999,~50 -999. 50 lb1.063 4.551 -999.250 -999.250 148.563 -999.250 -999.250 -999.250 -999.250 MNEMONIC SFLU DRHU NCNL GR DRHO NCNb GR SFLO DRHO NCNb GR SFLU DRHO NCNL GR SFLU DRHO NCNL GR SFbU DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR VALUE 16.953 -999.250 -999.250 -999.250 67.000 -999.250 -999.250 -999.250 16.813 -999.250 -999.250 -999.250 6.156 -999.250 -999.250 -999.250 74.000 -999.250 -999.250 -999.250 208.b25 -999.250 -999.250 -999.250 14.922 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 DEP?H 1600.000 1500.000 1400.000 1300.000 1200.000 1100.000 1000.000 90O. 000 800.000 VALUE 8P -105.000 GR 90.047 NPHI -99925.000 FCNL -999.250 Dr -999.750 SP -123.750 GR 64.203 NPHI -q9925.000 FCNL -999.250 DT -999.250 SP -185.250 GH 39.695 NPHI -q9925.000 ~CNL -999.250 DT -999.250 SP -28.750 GF 74.250 NPHI -99925.000 ~CNL -999.250 DT -999.?5O MNkMONIC ILD GR RH{)B ILD GR RH[)B GR ILL GR RHOB GR ILD GR RHI3B GR SP -35.219 ILD GR 56.422 GR NPHI -99925.000 ~HOB f'CNL -999.250 GR DT -999.250 SP -109.500 GR 36.352 NPHI -99925.000 fCNL -999.250 DT -999.250 SP -105.563 GR 43.695 NPH1 -99925.000 FCNL -999.250 DT -999.250 6P -122.500 GR 33.314 NPHI -99925.000 ~CNL -999.250 DT -999.250 SP -125.000 GR 38.531 NPHI -99q25.000 FCNL -999.250 DT -999.250 1LD GR GH ILL GR IaHUO GR ILD GR RHOB GR GR RHOB GR VALIIE 13,016 -999.250 -999.250 80.047 19.266 -999.250 -999.250 64.203 86.R75 -999.250 -999.250 t9.695 25.016 -999.250 -999.~50 74.250 35.031 2999.~50 999.250 56.422 26.516 -999. 0 36,352 26.266 -999.250 -999.250 43.695 140.125 -999,~50 -999. 50 33.344 44.906 999 50 38.531 MNEMONIC CALl NRAI DT IBM CALl NRAT UT 1LM CALl NRAT DT 1BM CALl NRA~ DT iL~ CALl NRAT DT IbM CALl NRA1 DT CALl DT 1BM CALl NRAT ILM CALl NRAT DT VALUE 11.656 -999.~50 -999.250 178.250 16.109 -999.250 -999.250 184.969 29.313 -999.250 -999.250 241.969 17.409 -999.250 -999.250 210.281 24.~44 :9999.250 99 .250 146.125 19.938 -999.250 -999.250 141.750 14.938 -999.250 -999.250 12b.750 52.625 -999.250 -999.250 125.48i 19.141 -999.250 -999.250 143.281 MNEMONIC SFLU DRHO NCN~ GR SFbU DRFIO NCNb GR SFLU DRHO NCNb GR SFbU DRHO NCNb GR SFLU DRHU NCNb GR DRHO NCNb GR 8FLU DRHU NCNL GR SFBU DRHO NCNB GR SFLU DRHU NCNB GR 12.961 -999.250 -999.250 -999.250 19.891 -999.250 999.250 :999.250 91.563 -999.250 -999.250 -999.250 20.706 -999.250 -999.250 -999.250 29.813 -999.250 -999.250 -999.250 131.125 -999.250 -999.250 -999.250 21.719 -999.250 -999.250 -999.250 95.688 -999.250 -999.250 -999.250 38.469 -999.250 -999.250 -999.250 DEPTH 2500. 000 2400.000 ?]00,000 2200.OO0 2100.o00 2000.000 lqO0.O00 lWO0,O00 1700.000 MNLMtJNIC VALUE -101.000 40.203 NPHI -99925,000 FCNL -999.250 DT -999.250 SP -144.500 GR 47.125 NPH1 -99925,000 FCNL -999,250 DT -q99.250 SP -136.500 GP 47.938 NPHI -99q25.000 FCNL -099.250 DT -q9q.250 SP -110.500 GR 54.8]6 NPHI -99925.000 PCNL -999.250 DT -999.250 MNLMONIC ILD GR ILD GR GR ILD GR RHOB GR ILD G~ RHOB GR SP -95.4]0 ILD GP 50.102 GR NPH1 -99925.000 RHOB FCNh -999.250 GP DT -999.250 SP -136.500 GR 50.563 NPHI -99925.000 FCNL -999.250 DT -999.250 SP -119.500 GP 79.031 NPHI -99925.000 FCNL -999.250 DT -999.250 6P -151.500 GE 81.141 NPHi -99925.000 FCNL -999.250 DT -999.250 SP -105.500 GR 72.438 NPHI -99925.000 FCNL -999.250 DT -999.250 iLD GR RHOB GR ILD GR GR 1LD GR RHOB GR iLD GR RHOB GR VALUE 9.~67 28.S94 2.045 48.203 8.984 -999.~50 -999. 50 47.125 8.922 .-909.250 999.250 47.938 8.703 -999.250 -999.250 54.836 7.484 -.999.250 999.250 50.102 7.883 .-990.250 999,250 50.563 1.529 -.999.~50 999.250 79.031 16.984 -999.250 -999.250 81.t41 1.995 -999.~50 -999.250 72.438 MNLM(]NiC iLM CALl NEAt DT ILM CALl NEAT DT ILM CALI NEAT DT iLM CALl NRA1 DT ILM CALl NEAT DT IbM CALl NRAI DT IbM CALl NEAT DT ILM CALl NEAT DT ILM CALl NEAT DT VALUE 9.625 14.781 -999.250 133.500 9.188 -999.250 -999.250 141.438 8.891 -999.250 -999.250 143.813 8.797 -999.250 -999.250 139.969 7.410 -999.250 -999.250 150.313 7.906 -999.250 -999.250 156,563 1.684 999. 50 152.375 16.406 -999.250 -999.250 -162.750 1.697 -999.250 -999.250 168.719 MNEMONIC SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFLU ORHU NCNb GR SFbO DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNL GR VALUE 11.77] -0.7~0 -999.250 -999.250 9.484 -999.250 -999.250 -999.250 9.727 -999.250 -999.250 -999.250 10.547 -999.250 -999.250 -999.250 8.344 -999.250 -999.250 -999.250 8.b33 -999.250 -999.250 -999.250 2.857 -999.250 -999.250 -999.250 14.922 =999.250 -999.250 -999.250 2.898 =999.250 -999.250 -999.250 DEPTH ~300.000 ]200.000 ~100.000 )000.000 2900.000 2800.000 2700.000 2600.000 MNLt~I)NJC YALUE 6P -64,250 GR 7i,18~ NPMI -qqq25.O00 FCNL -g99,250 D']' 120.250 6p -56.281 GR 86.5b{ NPH1 -99925.000 fCNL -999.250 DT i]2.250 SP -84.56] GP 57.250 NPH1 -99925.000 FCNL -999.250 DT 128.000 SP -60.719 GR 74.125 NPHI -99925.000 fCNL -999.250 DT 129.750 Sp -6b.750 GR 67.000 NPH1 -99925.000 FCNL -999.250 DT 127.500 Sp -60.219 GH 64.500 NPMI -9q925.000 FCNL -999.250 bT 162.750 SP -80.313 GR 48.460 NPHI -99925.000 ~CNL -999.250 DT 1]0.750 SP -76.563 GE 71.813 NPHI -99925.000 fCNL -999.250 DT 132.250 SP -110.438 GR 5b.688 NPMi -99025.000 FCNL -999.250 DT 259.O00 ~INLMUNIC lhD GR GR lED GR RHOB GR ILD GR RHOB GR Ri{OB GR ILD RHOB GR GR RHOB GR 1LO GR RHOB GR ILD GR RHOB GR VALUE 7,297 64.250 2.207 87.000 6.5~9 87.438 2.168 105.938 .500 4 .344 2.078 63.688 6.309 70.688 2.176 79.875 7.207 61,938 2.217 89.875 5.844 75.625 2.242 83.O63 8.641 46.594 2.166 90.000 ;0,148 103,063 8.766 18,191 2,010 58,000 MNkMONIC CALl NRAT UT iLM CALl NRAT DT 1LM CALl NRAT DT CALl NRAT DT CALl DT CALl NRAT DT ILM CALl NRAT DT CALl NRA'I DT CALl NRAT DT VALUE 7.184 14.797 -999.25o 12~.375 6.191 16.016 -999.250 144.000 8.406 13.945 -999.250 134.750 5.871 14.789 -999.250 137.750 6.801 15.070 -999.250 133.125 5.246 15.156 -999.250 154.125 8.547 14.06~ -999.250 13~.000 9.781 14.938 -999.250 136.125 8.852 14.766 -999.250 54.781 MNEMONIC SFbU DRHO NCNL GR SFLU DRHO NCNL GR SFLU DRHO NCNL GR SFLU DRHO NCNL GR SFLU DRHO NCN5 GR SFLU DRHO NCNL GR SFLU DRHO NCNL GR SFLU DRHO NCNL GR SFLU DRHO NCNL GR VALUL 7.258 0.015 -.999.250 70.250 0.129 0.055 -999.250 86.31J 8.094 -0.004 -999.250 b2.594 5.b13 0.011 -999.250 73.625 6.586 0.050 -999.250 66.125 5.805 0.084 -999.250 77.313 8.828 0.045 -999.250 46.750 9.273 0.021 -999.250 72.438 9.383 -0.813 -999.250 33.719 DEPTD ~]00,000 4200.000 4t00.000 4000,000 3900. 000 3RO0.O00 3700.000 3600.000 3500.000 ~P GR NPHi FCNL Dq SP NPHI FCNL OT SP NPHI FCNL DT SP GR NPHI FCNL DT SP GR NPHI FCNL DT SP GR NPHI FCNL DT SP GR NPMI FCNL SP GR NPHI FCNL DT GR NPHI FCNL DT VALU -127. 45. 42. 598. 124. -120. ]1. 41. 593. 113. -91. 60. 41. 526. 103. -121. 28. 36, 636. 112. -71. 57. 42. 541. 80. -54. 71. -99925. -999. 105. -53. 73. -99925. -999. 139. -82. 54. -90925. -999. 121. -78. 54. -99925. -099. 121. 000 250 O4] 50O 250 000 641 846 000 000 O00 219 748 000 50n 563 188 865 500 750 875 156 188 000 000 781 688 000 250 000 219 250 000 25O 500 50O 281 000 25O 250 250 344 000 250 500 MNkMONIC 1LD GR HHOB GR ]LD GR RHuB GR ILD GR RHOB GR ILD GR GR ILD GR RHOB GR ILD GR RHUB GR ILD GR RHOB GR 1LD GR RH(]B GR ILD GR RHOB GR VALUE 1.147 44.719 2.076 96.938 1.204 28.500 2.072 92.250 2.488 46.969 2.080 78.750 1.538 25.797 2.105 84.625 8.781 52.781 2.145 84.813 4.707 73.688 2.270 76.938 b.453 78.813 2.i23 100.438 7.594 54.188 2.162 73.750 6.336 56.844 2.078 72.625 MNEMONIC IbM CALl NRAT DT CALl NRA][ DT 1bM CALl NRAT DT ILM CALl NRAT DT CALl NRAT DT IbM CALl NRAT DT CALl NRAT DT iLM CALl NRAT DT CALl NRAT DT VALUE 1.313 12.250 3.639 130.O00 1.369 12.117 3.627 116.375 2.580 12.953 3.621 111.000 i.704 13.867 3.350 115.750 8.500 14.039 3.660 91.750 4.395 15,266 -999.250 120,563 5.961 14.625 -999.250 145.375 7.938 13.938 -999.250 129.000 b.418 1~.383 -99 .250 126.375 MNEMONIC SFLU DRHO NCNb GR SFLU DRHU NCNb GR SFLU DRHO NCNb GR SFLU DRHU NCNb OR SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR VALUE 3.467 -0.002 2230.000 48.125 4.313 0.023 2326.000 27.750 3.730 -0.001 2134.000 55.063 4.617 0.003 2394.000 26.969 11.438 -0.004 2204.000 53.219 4.332 0.021 -999.250 99.625 6.301 0.041 -999.250 87.938 8.461 0.013 -999.250 81.063 6.707 -0.010 -999.250 60.406 DEPTH 520U. 000 5100.000 5000,000 4900.000 4900,000 4700,000 ~600,000 4500.000 4400. 000 HNLMON lC NPHI fCNL DT SF GR NPHJ ~ CNI_, DT SP GR NPHI FC Nb DT SP GR NPHI FCNL DT 8P GR NPHI FCNL DT SP GR NPHI FCNb DT SP GR NPHI FCNL DT SP GR NPHi FCNL DT SP GR NPHI FCNL DT VALUE -43.719 84.313 30.623 558.500 104.750 -45.710 78.125 40.723 520.000 10~.250 -75.750 84.56] 30.377 587.0OO 107.000 -48.500 81.375 ]8.574 525.000 106.000 -58.500 73.313 35.400 599.500 95.5o0 -65.06] 92.438 41.260 478.250 112.750 -65.000 85.250 12.432 476.000 94.000 -72.063 12.125 39.893 493.000 105.750 -77.000 62.56] 36.572 597.000 107.750 MNEMONIC ILO GR RHOB GR ILD GR RHOB GR lbo GR RHOB GR ILD GR RHOB GR lbo RHUB GR ILD GR RHOB GR lED GR RHOB GR ILD GR RHOB GR lED GR RHOB GR VALIIE 2.787 77.250 2.318 78.063 2.316 68.688 2.305 91.813 2.738 70.750 2.176 08.688 2.320 77.250 2.305 78.813 2.844 73.563 2.357 101.750 2.756 84.t25 2.313 127.000 2.824 7~ .625 .252 99.313 {.566 67.175 2. 30 89.063 5.203 58.750 2.125 J04.625 MNEMONIC ibm CALl NRAT DT iLM CALl NRAT DT ILM CALl NRAT DT IbM CALl NRA~ DT iLM CALl NRAT DT CALl NRAI OT CALI NRA~ DT CALl NRAT DT CALl NRAT DT VALUE 2.814 13.367 3.480 107.000 2.379 13.586 3.602 113.563 2.875 12.273 3.326 110.000 2.332 13 992 3:494 109.000 2.879 14.234 3.324 99.375 2.748 14.453 3.654 118.000 2.764 1].070 .684 115.750 3.500 13.438 3.553 107.750 4.848 12.409 3.344 114.750 MNEMONIC SFbO DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFbO DRHO NCNb GR SFbU DRHO NCnb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFbO DRHO NCNb GR SFLO DRHO NCNb GR VAL, UL 2.771 0.028 2120.00o 80.875 2.293 0.052 1996.000 83.688 3.199 0.006 2170.000 78.875 2.363 0.054 2122.000 89.438 3.686 0.082 2226.000 83.375 2.732 0.062 1866.000 116.750 2.607 0.065 1779.000 83.875 3.703 0.089 1808.000 80.313 3.311 0.038 2222.00O 68.563 DEPTH filO0.O00 6000,000 5900.000 5800.000 5700.000 5600,000 5500,000 5400,000 5300,000 MNEr4~)NiC 5P GP NPHI FC NL DT SP GR NPHI FCNL DT SP GR NPHi FCNL DT SP GR NPHI FCNL DT SP GR NPHI FCNL DT GR NPHI FCNL DT SP GR NFHI FCNL DT SP NPHI FCNL DT SP GR NPHI FCNL DT VAL -25 92 564 9~ 99 732 93 -24 94 726 q~ -31 88 38 575 gq -3l 74 35 610 97 -32 74 36 673 100 -40 87 ]5 b36 102 -40 84 37 b32 98 -36 84 41 567 UE .739 .~25 .7gl .500 .375 .219 .375 .592 .500 .750 .71g .813 .105 .500 .125 .219 .313 ,135 .500 .375 .219 .188 .938 .500 .500 .7]g .563 .670 .500 .750 .719 .625 .449 .500 .750 .21g .563 .207 .000 .500 .781 .625 .064 .000 .500 MNEMONIC JLD GR RHOB GR ILD GR RHOB GR ILl) GR RHOB GR ILD GR RHOB GR ILD GR RHOB GB ILD GR RHOB ILO GB RHf)B GR iLD GR RHOB GR 1LD GR HHOB GR VALI1E 2.230 88.188 2.375 g8.~13 2.922 99.563 2.875 88.688 2.]54 100.875 2.461 83.750 2.t67 92.I25 2.469 68.~38 2. 32 78.750 2.551 70.750 2.2Y7 69.125 2.287 83.688 2.389 125.188 2.627 78.438 2.350 85.000 2.658 77.313 2.346 75.938 MNEMONIC ibm CALl NRAT DT C~Li NRAT DT CALl N~AI DT IbM CALl NRAT DT iLM CALl NRAT DT IbM CALl NRAT DT CALl NRAT DT IbM CALI NRAT DT CALl NRAI OT VALUE 2.336 12.922 3.311 99.375 3.072 12.859 3.082 96.188 2.965 12.969 ].i88 97.188 2.543 13.438 3.453 102.375 2.564 13.047 3.324 100.375 2.803 13.492 3.377 104.188 2.357 14.422 3.330 106.188 2.682 14.070 3.420 102.000 2.699 13.805 3.627 107.563 MNEMONIC SFbU DRHO NCNL GR SFbO ORHO NCNb GR SFbU DRHO NCNb GR SFLU DRHO NCNb GR SFbU DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR 8~bO ORHO NCNb GR SFLU DRHO NCNL GR VADUL 2.258 0.051 2072.000 70.375 3.090 0.023 2378.000 95.063 2.951 0.018 25b0.000 82.563 2.627 O.03b 2196.000 92.250 2.578 0,035 2268.000 b8,375 3.127 0.017 2436.000 69.375 2.410 0.062 2252.000 85.813 2.686 0,046 2254.000 79.563 2.717 0.036 2228.000 74.750 DI:.PTH 7000,000 6000.000 6R00,000 6700.000 6600.000 hSO0,O00 6400.000 h300.O00 6200,000 SF NPH I F'CNL DT SP GR NPttI FC N I, DT SP GR NPHI FCNL D'r GR NPMI FCNL DT SP GR NPHI FCNL DT SP GR NPHI FCNL DT GP NPHI FCNL DT SP GR NPHI FCNL DT SP GR NPHI FCNL DT VAL 113 47 403 111 t{E .51 .50 -38.12 117.93 48.63 387.50 100.25 -4t. 162. 40. {49. 110, -41, 143. 42, 441, 114, -32. 170. 39. 444. 108. -]8. lbO. 39. 593. 101. -37. 98. 30. 799. 84. -42. 120. 35. 623. 98. -25. 101. 34. 586. 97. 219 250 381 750 750 875 25O 480 5O0 250 688 875 893 25O 375 0O0 000 844 000 000 688 5OO 811 000 750 625 125 400 5OO 875 750 000 750 MNEMON1C GR GR ILD GR RHOB GR ill) GR RHOB GR ILD GR RHOB GR iLD GR RHOB GR ILD GR RHOB GR ILD GR RHOB GR ILD GR RHOB GR ILD GR RHOB GR VAI, UE 1.604 103.250 2.402 113.875 1.445 100.188 2. 65 117.938 2.451 148.875 2.377 162.250 2.084 138.000 2.350 143.250 1.566 188.375 2.J89 170.875 1.652 154.875 2.]77 160.000 1.826 q5.150 2. 42 98.500 2.490 2. 24 1,20.125 2.424 89.500 2.400 97.500 MNEMONIC IL~ CALl NRAT DT CALI NRAT DT IbM CALl NRAT DT CALl NRAT DT ILM CALI NRAT DT CALl NRAT DT ibm CALk NRAT DT 1bM CALl NRAT DT CALl NRA2 DT VALUE 1.675 13.953 3.990 118.563 1.54] 14.445 4.063 105.375 2.545 14.391 3.605 111.000 2.066 13,609 3,701 122.188 1.491 12.805 3.535 108.375 1.741 13.336 3.547 106.375 2.148 12.891 3.033 86.188 2.572 13.914 3.316 102.750 2.537 13.406 3.273 101.188 MNEMONIC SFbO DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFbU DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFbU DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR VAbUk 1,951 0.078 1702.000 126.063 2.326 0.065 1674.000 115.250 3.025 0.042 1850.000 177.500 2.021 0.058 1'195.000 156.625 1.958 0.044 1785.000 211.000 1.913 0.033 2304.000 158.250 3.977 0.022 2726.000 115.313 2.590 0.041 2222.000 127.063 2.580 0.063 1977.000 98.125 DEPTH 7900.000 7~00.000 7700.000 7600,000 7500.000 7400.000 7t00.000 7200.000 7100.000 MN~ P~I:IN IC SP GR NPHI P CNI., DT SP GR NPH1 FCNL DT SP GR NPHI FCNL DT SP GP NPH1 [CNL DT SP GR NPHI FCNL DT SP GR NPHI FCNL DT SP GR NPHI PCNL bi SP GR NPHI FCNL D% SP GR NPHI FCNL DT VALUE -58,688 91.688 43,164 465,000 -62,750 93.500 36.572 527,500 102,500 -06,500 93,313 36,572 533,500 100.375 -~5.250 93,000 34,033 631.500 97,500 -29,250 91,500 40.918 537,500 95,875 -75.438 54,281 28.407 887,000 88.750 -51,031 83,500 33.057 68i,000 86.250 -56,219 53,688 28.271 819.000 87.625 -37.000 104,375 ~9,404 490,000 105.250 MNEMONIC ILL GR RHOB GR 1LD GR RHOB GR ILD GR RHOB GR II, D GR RHOB GR ILD GR RHOB GR ILD GR RHC]B GR 1LD GR RHOB GR ILD GR RHOB GR 1LD GR RHOO GR VALUE 1,44b g2.~25 91,688 1.809 91.500 2 400 2,023 90,438 2.363 93.313 2,344 149,~75 1. 65 93,000 I .960 88.250 2.451 91.500 !.777 40,875 2.277 54,281 ~.561 70.063 2,461 83,500 17,953 42,156 2, ~.60 53,688 1,749 102.~75 2. 71 104,375 MN~MQNIC CALl NRAT DT iLM CALl NRAT DT ILM CALI NRAT DT ibm CALl NRAT DT ILM CALI NRAI DT ILM CALl NRA2 DT IbM CALl NRAT DT IbM CALl NRAT DT CALl NRAT DT VALUE 1.554 Ii.891 3.693 104.563 1.805 14.063 3.385 105.000 2.098 13.352 ].365 100.563 2,578 9,781 3,080 96,000 2,000 12.422 3,584 98.188 2.068 12.156 2.855 91.563 3,924 12.180 3,164 88,750 16.422 12.141 2.842 90.563 1.826 12.88~ 3.512 109.750 MNEMONIC SFLU DRHO NCNL GR SFLU DRHO NCNb GR SFLU DRHO NCNL GR SFLU DRHO NCNL GR SFLU DRHO NCNL GR SFLU DRHO NCNb GR SFLU DRHU NCNb GR SFLU DRHO NCNb GR 8FLU DRHO NCNL GR VALUE 1.754 0.054 lb92.000 90.438 2.016 0,054 ,875 2,359 0,065 2006.000 85.438 2.738 0.005 2104.000 41.531 2,061 0,064 2082,000 74,750 3.768 0.040 2636.000 38.469 4,535 0,020 2324,000 bi.688 34.438 O.039 2332.000 50.094 2.016 0.075 1827.000 122.188 8~00.000 8700.000 8600.000 8500.000 8400,000 8300,000 R200.000 8100,000 8000,000 ~NEMONIC SP NPH! FCNL I)T SP GR NPHI FCNL DT SP GR NPH! FCNb DT SP GR NPHI FCNL DT 6P GR NPHi ~CNL DT SP GR NPHI FCNb SP GR NPHi FCNL DT SP GR NPHI ~CNL DT SP GR NPHI ECNL DT AL 53 88 24 73 99 51 90 21 32 87 .2 .7 .7 .0 .4 .7 .2 .6 .0 .8 50 5O 5b 00 38 5O 5o 31 00 75 47.25 84.81 ]2.27 7t.00 96.12 -43. 100. 45. 394. 110. -47. 81. 28. 807. 250. -45. 73. 29. 677. 93. -49. 90. 32. 641. 99. 43 5O 36 00 62 50 12 85 00 12 71 75 78 O0 12 25 93 81 5O O0 75 87 31 00 25 00 56 72 00 50 -60. 60. 22. 1208. 80. -50. 85. i2. 421. 105. MNEMi)NiC VALUE ILD 2,689 GR 90.]1] RhOB 2,518 G~ 88.750 iLD 2 45] (iR 83:563 RHO8 2.557 GR 90.250 ILD 2.127 GR 80.813 RHO0 2.410 GR 84.813 ILD 1,419 GR 109.438 RHOB 2.299 GR 100.500 ILD 2.385 GR 75.500 RHOB 2.480 GR 81.125 ILD 2.141 RHOB 2. 5 GR 7].750 ILD 1.802 GR 91.125 RHOB 2, 92 GR q0.938 ILD 3.q71 GR 58,~13 RHOB 2. 86 GR 60.875 ILD 1.167 GR 92.063 RHOB 2.289 GR 85,563 MNLMONIC CALl NRAI DT CALl NRAT DT ibm CALl NRAT DT ibm CALl NRAT DT iLM CALl NRAT DT ILM CALl NRAT DT IbM CALl NRAT DT CALl NRAT DT IbM CALl NRAT DT VALUE 2.863 9.391 2.465 87.750 2.752 9.195 2.240 88.000 2.3t6 10.406 3.047 95.563 1.540 11.430 3.805 103.750 2.502 10.086 2.793 91.000 2.234 10.195 2.865 92.375 1.921 12.117 3.145 100.000 4.156 9.719 2.328 81.375 1.239 12.492 3.684 104.750 MNEMONIC SFbO DRHO NCNb GR SFLU DRHO NCNb UR SFLU DRHO NCNb GR SFbO DRHO NCNL GR SFbU DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFLU DRHO NCNb GR SFbU DRHO NCNb GR VAbUL 3.336 0.053 2678.000 82.813 3.645 0.029 2764.000 82.250 2.594 0.091 70.000 2291.938 2.010 0.105 1639.000 11{.250 2.703 0.073 2430.000 75.125 2.527 0.086 21~0.000 77.813 2.219 0.039 2088.000 86.500 4.676 0.012 3148.000 58.219 1,557 0.008 1766.000 83.688 g650.000 q600,O00 gSO0.O00 9400.000 9300.000 q?O0.OO0 9100.000 g000,000 8900.000 flNLMON lC 5P NPHi FCNL DT SF NPMI FCNL DT SP GR NPH! FCNL DT SP NPHI FCNL DT SP G~ NPH1 FCNL DT SP GR NPHI FCNL DT SP GR NPHI ?CNL DT SP NPMI FCNL DT SP GR NPHI ? CgL DT 15 2 1 15 11 AL O~., 40.7 95.5 2.1 04.5 72.2 57.0 95.5 18.8 18.0 05.1 94.1 21.3 21.7 32.0 76.8 1%.6 97.7 22.6 96.0 78 .b 36.1 89.0 18.1 34.0 78.0 37.3 84.8 44.5 79.5 07,0 45.5 93.3 41.7 36.5 00.6 50 O0 97 O0 00 O0 9b O0 25 88 75 77 O0 75 88 5O 07 O0 25 25 O0 64 O0 00 13 75 31 O0 O0 03 75 97 O0 25 45.81J q4.375 45.117 13.750 04.250 52. 97. 40. 71. 99. 000 875 b74 500 125 ~INkMON IC ILD GR RHOB GR iLD RHOB I L,D GR RHOB GR iLD GR RHOB GR 1LD GR RHUB GR ILD GR RHOB GR ILD GR - RHOB GR ILD GR RHOB GR ILl) GR RHOB GR VAb!IE 4.531 10.q53 2.303 05.500 6.020 107.063 2.602 95.500 5.895 117.125 2.432 121.375 5.313 87.~38 2. 37 g7.750 4.996 85.063 2.531 89.000 1.110 80.~13 2. 09 84.875 1.425 93.375 1.470 88.188 2.342 g4.375 1.438 96.625 2.424 g7.875 MNEMONIC ILM CALl NRAT DT ILM CALl NRAT DT CALl NRA'.[ DT ILM CALl NRA] DT ILM CALI NRAT DT IbM CALl NRAT DT ILM CALl DT IbM CALX NRAT DT CALl NRAT DT VALUE 3,891 8.500 0.435 77.563 6.031 8.~34 1. 79 78.188 6.473 8.117 2.160 80.000 5.121 8.852 2.277 79.188 5.090 8.609 1.960 76.188 1.203 15.641 3.869 108.375 1.506 12.102 J.623 99.000 1.604 14.836 3.881 107.000 1.540 11.844 3.555 99.563 MNEMONIC SFLU DRHO NCNL GR SFLU DRHO NCNb GR SFbU DRHO NCNb GR SFbO DRHO NCNb GR SFbU DRHO NCNb GR SFbU DRHO NCNb GR SFbU DRHU NCNb GR SFLU DRHO NCNb GR SFbU DRHO NCNb GR VALUE 5.141 -0.411 97.188 31.484 6.516 0.006 3302.000 25.625 11.047 -0.005 3454.000 114.688 9.164 0.016 2834.000 90.375 5.270 0.030 3512.000 78.875 1.721 0.039 1562.000 84.750 2.033 O.Obb 1746.000 88.500 2.213 0.089 1700.000 85.813 1.953 0.095 1850.000 91.063 DA~I~M SPECIFICATION BLOCKS: UNIT AP1 AP1 AP1 AP1 FIbL SIZE SAM HEP PROCESS INDICATORS 1DEPT 2 SP DIL ~ ILD DI I, % ILM D] L 5 SFL{~ DIL 6 GR 7 GR CNL 8 CALI CNL 9 DRHO CNL ~0 NPH! CNL 11 RHI]B CNL 12 NRAT CNI~ 1] NCNL CNL 14 FCNL CNL 15 GR BHC 16 DT BHC 17 GR LSS 18 DT LSS FT 0 0 0 0 0 4 MV 7 1 0 0 0 4 OHM~ 7 12 46 0 0 4 OHMM 7 12 44 0 0 4 OHMM 7 22 1 0 0 4 GAPI 7 ]1 ]2 0 0 4 GAPi 42 ]1 32 0 0 4 IN 4~ 28 1 0 0 4 G/C3 42 44 0 0 0 4 PU 42 68 ] 0 0 4 G/C] 42 ]5 1 0 0 4 C/C 42 42 1 0 0 4 CPS 42 ]4 92 0 0 4 CPS 42 34 93 0 0 4 GAPI bO 31 32 0 0 4 US/F 60 52 32 0 0 4 GAPI 60 31 32 0 0 4 US/F 60 52 73 0 0 4 1 68 l 68 1 68 l 68 I 68 1 68 1 68 1 68 1 68 1 68 1 1:)8 I 68 1 b8 I 68 i 68 1 68 DEFINED OUTPUT ARRAY OUTPUT SP AT 2 OUTPUT ILD AT 3 OUTPUT IL~ A~ 4 OUTPUT S~LU AT 5 OUTP{]T GR AT 6 OUTPUT GR AT 7 OUTPUT CALl AT 8 OUTPUT DRH[! AT 9 OUTPUT NPH1 A7 lO OUTPUT RHOB A~ 11 OUTPUT NRAT AI 12 OUTPUT NCNL AT 13 OUTPUT FCNL A~ 14 OUTPUT GR AT 15 OUTPUT OT AT 16 OUTP{{T GR AT 17 OUTPUT BT AT 18 DATA ?OP, MAI SP~CI~ICATI[]N L~,NG~H: 7 ]0 0 S1Z~ REP CODE ENTRY I 66 0 FLUID LOSS = 5.6 ML RM @ SEA6 TEMP. = 4.20 @ 70 F ~MF " " = 1.68 .~ 70 f RM~ " " = 1.59 @ 70 ~ DIL RUN # 6, bOGGED 3-NAR-81 CASING DRILLER = 9.625 IN. ~ 7617 FT. BIT SIZE : 8.5 IN. FLUID IN IH~ HOL~ = LIGNOSUL~ DENS = 10.8 VISC = 44.00 PM -- 9.5 FLU ID LOSS -- 6.5 ML ~N a ~EAS TEMP. = 1.77 ~ 65 F RMF " " = ~.]! @ 62 F RMC " " = 1.9~ ~ 62 F fILF: HEADER I,ENGTH: 62 BYTES NAME: ED1T .001 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FiLE NAME: COMPANY : CONUCO INC W~bI, : M[LNE PLI1NT #2 FIELD : WILDCAT ~ANGE : 11~ TOWNSHIP : 13N SECTION : 19 COUNTY : NORTH SLOPE STATE : ALASKA DENSITY : 800. 1024 BYTES SCHLUMBERGER COMPUTING CENTE~ 10707,61455 REEL HEADER I,ENGTH: 132 BYTES REEL NAME: P.C.A.L. SkR¥ICE NAME: EDIT PEEL CONTINUATION NUMBER: 01 PREVIOUS REEL NAME: COMMENTS: LIS FORMAT CUSTOMER TAPE DATE: 811 ]122 TAPE HEADER I,ENGTH: 132 B~TES TAPE NAME: 01455 SERVICE NAME: EDIT TAPE C(]NTINUATiON NUMBER: O1 PREUlOUS TAPE NAME: COMMENTS: TAPE COMMENTS ON RUN 6 TH~ REPEAT WAS MERGED IN ON THE DIL AND BHC BECAUSE ON THE MAIN SECTION THE TOOL STUCK. FLUID iN HOI,E = SPUD MUD DENS = 10.1 VISC = 70.0 PH = 9.0 ?LUID LOSS = 14.8 RM ~ MEAS TEMP. = 5.62 @ 66 F RM~ " " = 4.30 R~C " " = 4.28 a 63 F f)IL RUN # ] L[JGGED CAS1NG DRILLER BIT SIZE FLU!D IN THE HOLE DENS VISC PH ~LU1D LOSS RM ~ MEAS TEMP. RMF " " RMC " " 29-JAN-81 = 13.31 IN. ~ 2635 FT. = 12,25 IN. LIGNOSLILFONAT~ = 10.2 = 42.0 = 9.7 = 6.0 ML = 3.21 @ 68 F = 3.04 0 68 F = 3.80 ~ 68 F DII, PUN # 4 Li;GGED 5-FEB-81 CASING DRILLER = 13.36 IN. M 2635 FT. BlT SiZE = 12.25 IN. FLUID 1N THE H(II, E = LIGNOSULFONATE DENS = 10.3 rISC = 43.0 PH ; 10.3 DATE: 81/ 3/22 VV ' VV EEEEEEEEEk RRRRRRRR VV ~V EE~EEEEEEE RRRRRRRR ~V VV EE RR RR YV V¥ EE RR RR VV VV EE R~ RR VV VV EE RR RR YV VV EEEEEkkk RRRRRRR~ VV VV EEEEEEEE RRRRRRRH VV VV E~ RR RR V¥ VV [E RR RR VV VV EE RR ~R VV VV EE RR RR VV EkEEEEEEEE ~P RR YV EEEEEEEEEE RR RR IIIIII IIIIII II II II II II II II II ii II Illiii IIIIII FFFP F~`P ~ FP FFP'~FFFFFFF FF FF F~ FF FF[FFF~F FF FF PF FF YY YY YY YY YY YY YY YY YY YY YY YY YY YY YY YY YY 000000 000000 333333 000000 000000 333333 O0 O0 O0 O0 33 33 O0 O0 O0 O0 33 3~ O0 0000 O0 0000 33 O0 0000 O0 0000 33 O0 O0 O0 O0 O0 O0 33 O0 O0 O0 O0 O0 O0 33 0000 O0 0000 O0 33 0000 O0 0000 O0 33 O0 O0 O0 O0 33 33 O0 O0 O0 00 33 33 000000 000000 33{333 000000 000000 333333 ,START* USER PCAL [10!07,61455J JOB SHIP sg~. MONITOR $w$ KL10E40 NOV 80 ,START* ~Ih&: DSKH:VERIFY.00~<051>~10707,61455J CREATED: PRINTED: 22 MAR OUEU~ SWITCHES: /FII,E:FURT /COPIES:! /SPACING:I /LIMIT:94 /FORMS:NORMAL 7153 DATE 22-MAR-81 22-MAR-81 11:22:03 11:2.3:52
