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Home My WebLink About190-098 • STATE OF ALASKA AL _,CA OIL AND GAS CONSERVATION COM1._JSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon [I Plug Perforations U Fracture Stimulate [J Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well Q Re-enter Susp Well ❑ Other: ESP Change-out 0 12.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 190-098 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22073-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT SB J-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL RECEI V E D 11.Present Well Condition Summary: Total Depth measured 6,320 feet Plugs measured N/A feet MAY 2 6 2015 true vertical 4,571 feet Junk measured 6,002(Sand) feet A�.JGCC 5,063 Effective Depth measured 6,002 feet Packer measured 5,680 feet 3,588 true vertical 4,323 feet true vertical 4,070 feet Casing Length Size MD ND Burst Collapse Conductor 105' 13-3/8" 105' 105' 1,730psi 740psi Surface 2,913' 9-5/8" 2,913' 2,398' 3,520psi 2,020psi Intermediate Production 6,299' 7" 6,299' 4,554' 7,240psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic feet SCANNED ‘I'Ai i 1 201L True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 4,417' 3,183' HES Versatrieve 5,063' 3,588' Packers and SSSV(type,measured and true vertical depth) HES AWD Sump N/A 5,680' 4,070' 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 520 227 Subsequent to operation: 91 _ 51 492 240 250 14.Attachments(required per 20 AAC 25.070 25.071,s 25 283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development ElService ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-288 Contact Chris Kanyer Email ckanverahilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature (in Phone 777-8377 Date 5/26/2015 g •/..s' RBDMS kR"Y 2 7 2015 Form 10-404 Revised 5/2015 ��LSubmit Original Only 6-A. 5"---- Milne Point Unit • 14 Well: MPJ-04 SCHEMATIC Last Completed: 5/18/2015 Hilcorp Alaska,LLC PTD: 190-098 CASING DETAIL Orig.RKB Elev.:34'/Nabors 27E Size Type Wt/Grade/Conn ID Top Btm 3 3/8" Conductor 54.5/K-55/ButtTUBING Weld 12.715 Surface 105' L 9-5/8"1Surface 36/K-55/Btrc. 8.921 Surface 2,913' Al ei . o. 1.* r7" Production 26/L-80/Btrc 6.276 Surface 6,299' 13-3/8' ,.''';, 110 0,� DETAIL tr L_2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 4,417' • 3/8" Cap String Stainless Steel N/A Surface 4,417' is o: ! JEWELRY DETAIL %,, No Depth Item 4 li 1 176' GLM A r 2 4,207' GLM 1' I' 3 4,351' XN-Nipple i" i. 4 4,362' Discharge Head:FPDIS r4 5 4,363' Pump:119FLEX 10/PM SXD 9-5/8'' - R 6 4,386' Gas Separator:GRSFTX AR H6 7 4,391' Upper Tandem Seal:GSB3DBUT SB/SB PFSA 8 4,398' Lower Tandem Seal:GSB3DBUT SB/SB PFSA I 9 4,405' Motor:CL5/MSP1-325/60hp/1,240V/29A 10 4,413' We11Lift Sensor 11 4,415' Centralizer-Bottom @ 4,417' Haat Trace @ i 12 5,063' HES Versatrieve Packer 3,031' d 13 5,063' Top of 2-7/8"Blank Pipe-432'in length 14 5,521' 12 ga screen w/2.44"ID-145'in length-Gravel Pack N-Sands,20/40 mesh Gravel 15 5,666' 0-Ring seal Sub(2"ID) 3/8"SSCap String 3 16 5,666' 12 ga screen w/2.44"ID-11'in length 17 5,680' HES AWD Sump Packer w/4"ID 18 5,697' HES XN-Nipple(1.791"ID) 19 5,698' WLEG 2 PERFORATION DETAIL i 11 '' Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status (u1 N Sands 5,524' 5,540' 3,947' 3,960' 16 4/7/1991 Open 3 N Sands 5,562' 5,610' 3,977' 4,015' 48 4/7/1991 Open It N Sands 5,630' 5,660' 4,031' 4,054' 30 4/7/1991 _ Open t4 0 Sands 5,735' 5,777' 4,044' 4,147' 42 4/7/1991 Open N: 4 1%, 0 Sands 5,820' 5,853' 4,111' 4,181' 33 4/7/1991 Open , !x 5 OPEN HOLE/CEMENT DETAIL WELL INCLINATION DETAIL , a 13-3/8" 485sks Permafrost"C"in a 30"in a 30"hole KOP @ 400' y 9-5/8" 1,100sks Permafrost"E"in a 12.25"Hole Max Hole Angle=60 deg.@ 3,900' ' i 7.3,9 7" 405sks of Class"G"a 8.5"Hole Hole Angle Thru Perfs=39 Deg. TREE&WELLHEAD STIMULATION DETAIL 9 Tree WKM 2-9/16"5M Intervals:5,735'to 5,777'&5,820'to 5,853'- WKM 11"x11"5M tbg spool 11"x 2- Frac w/100bb1 Pre Pad,260bb1 Pad,204 bbl t Wellhead 7/8"8 EUE 8rd(Top&Bottom)WKM Prop Slurry(51,600Ibs of Carbo Lite 4 10 Hanger w/2.5"'H'porfile 11 i •- 12&13 GENERAL WELL INFO . .14 44 API:50-029-22073-00-00 N Sands RATAG RWO/Multiple Frac Packs-4/7/1991 -- ; @S307 ESP RWO w/EWS Rig#4 -10/19/1992 " 15 ,• ESP Change-out w/Nabors 35-12/27/2002 16 r ESP RWO w/Nabors 3S-2/21/2007 >-a t.::. , 17 ESP RWO&Acidize Screens w/Nabors 3S-5/8/2009 p ,18 ,,:, ESP RWO w/Nordic 3-5/18/2015 ), Top of Sand OSends{ 196,007 7.,L+, ID=6,320(MD)/TD=4,571'(TVD) PBTD=6,208'(MD)/PBTD=4,484'(TVD) Created By:TDF 5/26/2015 Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPJ-04 50-029-22073-00-00 190-098 5/15/2015 5/18/2015 Daily Operations: 5/13/15-Wednesday No operations to report. 5/14/15-Thursday No operations to report. 5/15/15-Friday Rig accepted.Spoke to Bob Noble AOGCC @ 0030 hours, Informed of progress for BOP test. MIRU, berm cellar,spot tanks,run hardline,spot spooler, PU BPV.SICP 460psi,SITP 400psi. Blow down well to 30 psi displace w 150°8.5 ppg Sea water first round/Thick Heavy crude 17 bbls to catch circ at 3 BPM second round circ end of circ gauging tanks well pressure increased to 180 psi from zero. 22 bbls lost Empty kill tank SIP down to 115 psi 5/16/15-Saturday Pressure down to 115psi.Blow to zero,builds back to 70psi. Resume pumping 8.5ppgt SW SI after full circ. Pressure to 70 psi. Find out 2 injectors feeding.Weight up to 8.9ppg to kill.Circulate well tubing light vacuum casing light blow. Disconnect lines install BPV. ND tree, NU BOPE remove BPV. Install TWC.Shell test BOPE,OK.Test BOPE 250psi low/3,000psi high.Test annular 250psi low/2,500psi hoigh. Remove 2 way check,annulus 90psi and crude,circ.well, well still out of balance. PU hanger out of wellhead slug tbg with 2 bbls 9+ppg tubing response vacuum annular response displacement.Well is static.Check on trip tank,all is OK. PU hanger to floor decomplete LD hgr.SW is 74k. ESP and heat trace are banded. POOH to GLMs, LD same w/pups,continue POOH string cable to spooler. POOH with heat trace and ESP to 1,344'. 5/17/15-Sunday Continue POOH from 1,344'from jt above GLMs all the way through the pump is packed solid with fine formation sand. There is no evidence of scale pn the pipe or BHA. More clamps and straps were recovered than reported run and the flat bar count was off by 15 less than reported.Clean rig floor and pipe racks of oil,clean move off all recovered clamps t36% and parts.Organize floor PU MU casing scraper with 4" Muleshoe.TIH with 2-7/8"tbg to 5,030'. Break reverse circ.2x C. 1 BU returns clean no sand. POOH w/scraper, LD all bad pipe as per program.Total 93 jts.Offload pipe and scraper. / PUMU RTTS. RIH with packer, picking up replacement singles.Set packer @ 5,000'. Pressure test casing and chart for 30 /G minutes to 1,500psi.Bleed off annulus release packer. POOH. BOLD packer.Onload ESP gear assemble and service ESP assy.Connect capillary and motor electrical connections and capillary check. 5/18/15-Monday Resume RIH w/completion.Start heat trace from 3,031',cable and cap check OK.Cap test @ 2,500psi. RIH to t/2,500'. Continue RIH f/2,500'-4,382'. Install hanger and landing joint,splice& MU ESP, H/T and cap connections and test. Land hanger/pup,4jts tbg, 1 pup,GLM @ 126', 1pup, 127 jts tbg, 1 pup.GLM 4,207',4 jts tbg,XN @ 4,350', 1pup, pump@ 4,363',gas separator @ 4,386', motor @ 4,404', EOT centralizer 4,417'. RILDS.Set BPV. ND BOPE. 5/19/15-Tuesday No operations to report. Ty(-COT N1//7,'- THE STATE Alaska Oil and Gas F , "tli ofALAsKA Conservation Commission • ittr _ 333 West Seventh Avenuei'�" WALKER � , . GOVERNOR BILL Anchorage, Alaska 99501-3572 o . Q+ Main 907 279 1433 ALA5� Fax: 907.276.7542 SCANNED MAY 2 0 2 15 www.aogcc.alaska.gov Chris Kanyer o 1 g Operations Engineer 0 Hilcorp Alaska, LLC 1 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB J-04 Sundry Number: 315-288 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, F, Cathy P. oerster Chair DATED this 151ray of May, 2015 Encl. RCEJV ED STATE OF ALASKA (,AM 1 11 Mit ALASKA OIL AND GAS CONSERVATION COMMISSION S� S ,,,( APPLICATION FOR SUNDRY APPROVALS A �✓ , 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑✓ . Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well 2- Re-enter Susp Well ❑ Other. ESP Change-out 2, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory 9 Development 2, 190-098 • 3.Address: Stratigraphic 9 Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22073-00-00 . 7.If perforating: ?A) 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.c Will planned perforations require a spacing exception? Yes 9 No 9 3 MILNE PT UNIT SB J-04 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 ` MILNE POINT/SCHRADER BLUFF OIL' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6,320 * 4,571 - 6,002 - 4,323 - N/A 6,002(Sand) Casing Length Size MD ND Burst Collapse Structural Conductor 105' 13-3/8" 105' 105' 1,730psi 740psi Surface 2,913' 9-5/8" 2,913' 2,398' 3,520psi 2,020psi Intermediate Production 6,299' 7" 6,299' 4,554' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic i See Schematic 2-7/8" 6.5#/L-80/EUE 8rd 4,969 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES Versatrieve&HES AWD Sump and N/A ' 5,063(MD)/3,588(TVD)&5,680(MD)/4,070(TVD)and N/A• 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development 9 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/16/2015 OIL ❑✓ - WINJ 9 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS 9 WAG ❑ GSTOR ❑ SPLUG 9 Commission Representative: N/A GINJ 9 Op Shutdown ❑ Abandoned ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanver hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature Phone 777-8377Date 5/11/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:3' r 2-Cg Cg Plug Integrity 0 BOP Test [3 Mechanical Integrity Test ❑ Location Clearance 0 Other: . 3MOj _ ) � ./5 ( ,q4p = / Spacing Exception Required? Yes 9 No LvJ Subsequent Form Required: /0 •- 0(1 APPROVED BY Approved by:C11167/619:),(.441,„„ G A COMMISSIONER THE COMMISSION Date: S-I S _�S— nI �I ��t�I� SI l� Submd Fonn and Form 10-403 Revised 5/2015 IVAb r rid I i AaLfor 12 month,s from thg date of appyAttmenta in Duplicate A 3//to- RBDMS MAY 1 5 2015 Well Prognosis Well: MPJ-04 Hilcorp Alaska,LL Date:5/11/2015 Well Name: MPJ-04 API Number: 50-029-22073-00-00 Current Status: SI Producer Pad: K Pad Estimated Start Date: May 16, 2015 Rig: Nordic 3 Reg.Approval Req'd? May 15, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-098 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Ted Kramer (907)777-8420 (0) (985)867-0665 (M) AFE Number: 1521265 Current Bottom Hole Pressure: - 1,588 psi @ 4,000' TVD (Last BHP measured 12/31/2013) Maximum Expected BHP: — 1,588 psi @ 4,000' TVD (No new perfs being added) Max. Allowable Surface Pressure: 136 psi (Based on actual reservoir conditions and water cut of 40% (0.374psi/ft)with an added safety n factor of 1000' TVD of oil cap) Brief Well Summary: ✓ 67—/G -(5� The Milne Point J-04 well was drilled as a Schrader Bluff development well that TD'd at 6,320' and ran and cemented 7" casing in January 1991.The well was perforated and frac'd in the Schrader Bluff sands and initially completed with an ESP in April 1991. This and subsequent ESPs failed and were replaced in 1992, 2002, 2007, and 2009. The recent pump failed January 2013.The most recent casing pressure test performed during a RWO on 12/27/2002 to 3,500psi.A casjng pressure test will be completed during this workover. Due to observed scale issues, a downhol�a F-emical injection line will be run as part of the new completion. No subsidence issues are expected in this well/ Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issues suspected. RWO Objective: Pull ESP, run casing scraper, pressure test casing, & run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Attempt to circulate well with 8.5ppg seawater and monitor well. 3. ND tree, NU 11" BOPE and test to 250psi low/3,000 sl igh, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test 4. 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. b. With stack out of the test path,test choke manifold per standard procedure Well Prognosis Well: MPJ-04 Ililcora Alaska.Ll; Date:5/11/2015 c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 5. Unseat hanger and pull 2-7/8" ESP completion from 4,969' to surface and lay down same. Contingency: (Pending condition of pulled completion—sand/scale in pump) 6. RIH with cleanout BHA to +/-5,000'. POOH with same. 7. RIH and set test packer at+/-5,000' (Note: Due to the proximity to the existing upper gravel pack packer, / test will be performed within 600ft of open perforations). AA �l 8. Perform a charted casing pressure test to 1,500psi for 30min. Bleed off pressure and POOH with same. �"" 9. MU and RIH with ESP with 2,500' heat trace and 3/8" chemical injection line on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-4,769'. Land tubing hanger. 10. ND BOP, NU and tree. 11. RDMO workover rig and equipment. 12. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPJ-04 . 11 SCHEMATIC Last Completed: 5/8/2009 HilcorpAlaska,u.,: PTD: 190-098 CASING DETAIL Orig.RKB Elev.:34'/Nabors 27E Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 54.5/K-55/Butt Weld 12.715 Surface 105' : i 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,913' 41 :.. . 7" Production 26/L-80/Btrc 6.276 Surface 6,299' 13-3/8" 1 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 4,969' JEWELRY DETAIL No Depth Item 1 174' GLM:Camco 2-7/8"x 1",KBMM w/DPSOV 2 4,760' GLM:Camco 2-7/8"x 1",KBMM w/DGLV 3 4,903' XN-Nipple (2.25"No-gi 4 4,918' WeIILift Discharge Gauge Unit: 5 4,922.7' Discharge Head:FPHVDIS 6 4,923' Pump:127-P8 SXD 45/8'.A 7 4,938' Gas Separator 8 4,943' Upper Tandem Seal 9 4,950' Lower Tandem Seal 10 4,957' Motor:KMH 76hp/1,360V/34 A 11 4,965' WeIILift MGU Sensor w/Centralizer-Bottom @ 4,969' 12 5,063' HES Versatrieve Packer 13 5,063' Top of 2-7/8"Blank Pipe-432'in length Heat Trace @3,418' 14 5,521' 12 ga screen w/2.44"ID-145'in length-Gravel Pack N-Sands,20/40 mesh Gravel 15 5,666' 0-Ring seal Sub(2"ID) 16 5,666' 12 ga screen w/2.44"ID-11'in length 17 5,680' HES AWD Sump Packer w/4"ID 18 5,697' HES XN-Nipple(1.791"ID) 19 5,698' WLEG PERFORATION DETAIL illSchrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status N Sands 5,524' 5,540' 3,947' 3,960' 16 4/7/1991 Open N Sands 5,562' 5,610' 3,977' 4,015' 48 4/7/1991 Open N Sands 5,630' 5,660' 4,031' 4,054' 30 4/7/1991 Open 0 Sands 5,735' 5,777' 4,044' 4,147' 42 4/7/1991 Open 0 Sands 5,820' 5,853' 4,111' 4,181' 33 4/7/1991 Open 4.4&5 ;; OPEN HOLE/CEMENT DETAIL WELL INCLINATION DETAIL 6 13-3/8" 485sks Permafrost"C"in a 30"in a 30"hole KOP @ 400' 7 9-5/8" 1,100sks Permafrost"E"in a 12.25"Hole Max Hole Angle=60 deg.@ 3,900' ;: 7" 405sks of Class"G"a 8.5"Hole Hole Angle Thru Perfs=39 Deg. $&s TREE&WELLHEAD STIMULATION DETAIL Tree WKM 2-9/16"5M Intervals:5,735'to 5,777'&5,820'to 5,853'- 10 WKM 11"x11"5M tbg spool 11"x 2- Frac w/100bb1 Pre Pad,260bb1 Pad,204 bbl Wellhead 7/8"8 EUE 8rd(Top&Bottom)WKM Prop Slurry(51,600Ibs of Carbo Lite :.'l Hanger w/2.5"'H'porfile GENERAL WELL INFO ,$-1.-- r.aj .12 a 13 API:50-029-22073-00-00 ._ - 14 RWO/Multiple Frac Packs-4/7/1991 RA TAG ESP RWO w/EWS Rig#4 -10/19/1992 N Sands a -@5,3ar ESP Change-out w/Nabors 3S-12/27/2002 � 15 ESP RWO w/Nabors 3S-2/21/2007 .' 16 ESP RWO&Acidize Screens w/Nabors 35-5/8/2009_ ..4.. 17 18 19 O Sends-I 7" a II. TD=6,320(MD)/TD=4,571'(TVD) PBTD=6,208'(MD)/PBTD=4,484'(TVD) Created By:TDF 5/11/2015 Milne Point Unit 14 Well: MP J-04 - PROPOSED Last Completed: 5/8/2009 Hilcorp Alaska,LLC PTD: 190-098 CASING DETAIL Orig.RKB Elev.:34'/Nabors 27E Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 54.5/K-55/Butt Weld 12.715 Surface 105' 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,913' 41 . 7" Production 26/L-80/Btrc 6.276 Surface 6,299' 13-3/8" TUBING DETAIL 1 2-7/8" Tubing 6.5 80/EUE 8rd 2.441 Surf ±,. JEWELRY DETAIL No Depth Item 1 ±174' GLM:Camco 2-7/8"x 1",KBMM w/DPSOV 2 ±4,560' GLM:Camco 2-7/8"x 1",KBMM w/DGLV 3 ±4,703' XN-Nipple (2.25"No-go ID) 4 ±4,718' WeIILift Discharge Gauge Unit: 5 ±4,722' Discharge Head:FPHVDIS 6 ±4,723' Pump:127-P8 SXD 45/8, 7 ±4,738' Gas Separator 8 ±4,743' Upper Tandem Seal 9 ±4,750' Lower Tandem Seal 10 ±4,757' Motor:KMH 76hp/1,360V/34 A 11 ±4,765' WeIILift MGU Sensor w/Centralizer-Bottom @ 4,769' 12 5,063' HES Versatrieve Packer 13 5,063' Top of 2-7/8"Blank Pipe-432'in length 14 5,521' 12 ga screen w/2.44"ID-145'in length-Gravel Pack N-Sands,20/40 mesh Gravel 15 5,666' 0-Ring seal Sub(2"ID) 16 5,666' 12 ga screen w/2.44"ID-11'in length 17 5,680' HESAWDSump Packerw/4"ID 18 5,697' HES XN-Nipple(1.791"ID) 19 5,698' WLEG PERFORATION DETAIL Ill 2 Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status N Sands 5,524' 5,540' 3,947' 3,960' 16 4/7/1991 Open N Sands 5,562' 5,610' 3,977' 4,015' 48 4/7/1991 Open 3 N Sands 5,630' 5,660' 4,031' 4,054' 30 4/7/1991 Open 0 Sands 5,735' 5,777' 4,044' 4,147 42 4/7/1991 Open 01...] Sands 5,820' 5,853' 4,111' 4,181' 33 4/7/1991 Open EJ 4&5 OPEN HOLE/CEMENT DETAIL WELL INCLINATION DETAIL 6 13-3/8" 485sks Permafrost"C"in a 30"in a 30"hole KOP @ 400' 9-5/8" 1,100sks Permafrost"E"in a 12.25"Hole Max Hole Angle=60 deg.@ 3,900' 1111: 7 7" 405sks of Class"G"a 8.5"Hole Hole Angle Thru Perfs=39 Deg. 8&9 TREE&WELLHEAD STIMULATION DETAIL Tree WKM 2-9/16"5M Intervals:5,735'to 5,777'&5,820'to 5,853'- 10 WKM 11"x11"5M tbg spool 11"x 2- Frac w/100bbl Pre Pad,260bb1 Pad,204 bbl Wellhead 7/8"8 EUE 8rd(Top&Bottom)WKM Prop Slurry(51,600Ibs of Carbo Lite Hanger w/2.5"'H'porfile on,11 GENERAL WELL INFO _� ,12&13 API:50-029-22073-00-00 RWO/Multiple Frac Packs-4/7/1991 14 NSarxls ESP RWO w/EWS Rig#4 -10/19/1992 { -RA TAG s @53oa ESP Change-out w/Nabors 3S-12/27/2002 15 ESP RWO w/Nabors 3S-2/21/2007 ESP RWO&Acidize Screens w/Nabors 35-5/8/2009 16 ., ►� Ii. 17 i 18 0 Sands{ 19 7" A r. TD=6,320(MD)/TD=4,571'(TVD) PBTD=6,208'(MD)/PBTD=4,484'(TVD) Created By:TDF 5/11/2015 11" BOP Stack ! 1 O O fit eassa Hydril 11" SM \ CIO-1 Shaffer 0 1 )121) 2 3/8" Rams CCIO .---[\ 11" SM 2 7/8-5.5 variables \ 0 i Hydril �C 11" SM � Blinds N__,___AVAII ,---) 71: O tional valve port cripe- „) - c ,- '.--..... WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital infomlation available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. ~ a q <a-' Well History File # Digital Data Added to LaserFiche File [I CD's - # 0 Yes 0 No - [I DVD's - # 0 Yes 0 No - 0 Diskettes - # 0 '+{ es 0 No - Oversized Material Added to LaserFiche File 0 Maps # D ""-es 0 No - 0 Mud Logs # - IJ Yes 0 No 0 Other # 0 '+{ es 0 No - General Notes or Comments about this file. Ifany of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. - - - - STATE OF ALASKA ALA OIL AND GAS CONSERVATION CO~SION REPORT OF SUNDRY WELL OPERATIONS R~~EI V E~ ~~'~~~ ~ 7 2009 1. Operations Performed: .i~+astia ~:+ ~~ ° ~~~ v~~JCtS. Ci0f11(TIISSI ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Er~,~~~~~~s~~~ded Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP & Acidize Screens " ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 190-098 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22073-00-00 7. KB Elevation (ft): 70 20 9. Well Name and Number: MPJ-04 8. Property Designation: 10. Field /Pool(s): ADL 025906 ~ Milne Point Unit / Schrader Bluff . 11. Present well condition summary Total depth: measured 6320 'feet true vertical 4571 feet Plugs (measured) NONE Effective depth: measured 6008 feet Junk (measured) NONE true vertical 4328 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 13-3/8" 105' ° i~a5' ~ ~ ~ ~' 1740 750 Surface 2878' 9-5/8" 2913' 2397' 3520 2020 Intermediate Production 6264' 7" 6299' 4554' 7240 5410 Liner ~ °J U 6'~~ FS ~ L~ ~ ~7 ~ :~c ~ Perforation Depth MD (ft): 5524' - 5853' Perforation Depth TVD (ft): 3947' - 4207' 2-7/8", 6.5# L-80 4969' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Screen Assembly - 7" Otis Versatrieve Packer and a 7" 5063', 5680' AWD Perma Series Packer with a leg to 5698' 12. Stimulation or cement squeeze summary: Intervals treated (measured): W~.~,~ S ,~, ~ C ~ --~~' Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 300 0 Subsequent to operation: 52 ~ 68 291 340 280 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ' ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA 'rf C.O. Exempt: Contact Hank Baca, 564-5444 N1A Printed N m ondra Stewm Title Drilling Technologist ' Prepared BY Name/Number: ,~ ~~ ' '~ Si tur l~ ..,f ~ Phone 564-4750 Dat Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 JiJ~ 4 5 2009 ORIGINAL Submit Original Only ~~~~ C~<~~~~ 3~ Tree: WKM 2 9/16" 5M ~ Wellhead 11" x 11" 5M tbg. spool, 11" x 2 7/8" 8 rd EUE (top & bottom) WKM tbg. hng. w/ 2.5" 'H' BPV profile. M P J -04 KB elev. = 70.2' DF elev. = 68.7' GL elev. = 35.0' 7/8"x 1" KBMM GLM 174" 13 3/8", 54.5 ppf, K-55 Butt Weld 105' KOP @ 400' Max Hole Angle: 60° @ 3900' MD Hole angle through perfs = 39 deg. 9 5/8", 36 ppf, K-55, Btrc. 2413' MD 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. production casing (drift ID = 6.151", cap. = 0.0383 bpf ) New #1 Ceber SS cable installed 12/27/02 PERFORATION SUMMARY REF LOG: SWS DIL/SFL 3/91 Size SPF MD D "N" Sands 4.5" 12 5524'-5540' 3946'-3959' 4.5" 12 5562'-5610' 3976'-4014' 4.5" 12 5630'-5660' 4030'-4053' "O" Sands 4.5" 5 5735'-5777' 4113'-4146' 4.5" 5 5820'-5853' 4180'-4206' Centrilift 3433` heat trace I 2-7/8"x 1" KBMM GLM 4760` 2-7/8" HES XN nipple(2.205") 4902` WeIILift DGU 4918` Centrilift SXD 127-P8 4923` Gas Separator 4938` Tandem SS 4943' GS63DBLT/UT AB/AB PFSA KMH 76 hp motor, 4957' 1360 v. / 34 amps. Centrilift WeIILift MGU 4965' HES Versatrieve packer @ 5063' MD (3.25"id) 2-7/8"Blank pipe 432' 145' -12 ga screen 2.44" id @ 5521' Gravel pack N-Sands 20/40 mesh gravel O-Ring seal sub (2" id) @ 5666' 11'-12 ga screen 2.44" id HES AWD Sump packer @ 5680' MD (4.0" id) HES XN-Nipple (1.791"ID) @ 5697' WLEG @ 5698' sand to 6002' 7" float collar (PBTD) szos' and 7" casing shoe s2ss' and DATE REV. BY COMMENTS MILNE POINT UNIT 4/07/91 RWO/ MULTIPLE FRAC PACKS WELL J-04 10/19/92 ESP RWO EWS Rig - 4 API NO: 50-029-22073 12/27/02 M.Linder ESP changeout, Ran new Centilift heat trace. 5/8/09 I REH I ESP RWO & acidize screens -Nabors 3S ~ gp EXPLORATION • • BP EXPLORATION Operations Summary Report (Legal Well Name: MPJ-04 'Common Well Name: MPJ-04 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S Date ~' From - To ~I Hours ' Task I Code NPT' Start: 5/2/2009 Rig Release: 5/8/2009 Rig Number: Phase 5/2/2009 06:00 - 11:00 5.00 RIGD P PRE 11:00 - 11:30 0.50 MOB P PRE 11:30 - 20:00 8.50 RIGU P PRE 20:00 - 22:00 2.00 RIGU P PRE 22:00 - 23:00 1.00 RIGU P PRE 23:00 - 00:00 1.00 KILL P DECOMP 5/3/2009 00:00 - 01:30 1.50 KILL P DECOMP 01:30 - 02:30 1.00 KILL P DECOMP 02:30 - 04:00 1.50 WHSUR P DECOMP 04:00 - 04:30 0.50 KILL P DECOMP 04:30 - 08:30 4.00 KILL P DECOMP 08:30 - 09:00 0.50 KILL P DECOMP 09:00 - 14:00 5.00 KILL C DECOMP 14:00 - 15:00 1.00 KILL C DECOMP 15:00 - 21:30 6.50 KILL C DECOMP 21:30 - 00:00 2.50 KILL C DECOMP Page 1 of 4 Spud Date: 12/29/1990 End: 5/8/2009 Description of Operations Rig down all components in preparation for rig move. Disconnect all power and steam. Scope and lower the Derrick at 0700 hrs. Peak trucks arrive on location at 0900 hrs. Hold pre-job meeting with Peak drivers and crew. Pull the Carrier off of well slot MPI-03 at 1000 hrs with the Pad Operator, Toolpusher and WSL present. Arrange all rig modules on the Pad and prepare to move to MPJ-Pad. Move the Rig and all modules from MPI-Pad to MPJ-Pad. Arrive on MPJ-Pad. Spot the Camp, Shop, Generator and Parts House. Spot the BOPE behind well slot MPJ-04. Move the Carrier on well slot MPJ-04 at 1500 hrs with Pad Operator present. Lay plywood and mats around the well cellar due to thawing out conditions. Jack the Carrier in place. Spot the Pipe Shed and Pits. Raise and scope-up Derrick. RU line and power to all modules. Rig accepted at 2300 hours 5/2/2009. RU hard line to Tiger tank. Continue to RU kill manifold and hard line to Tiger tank. Held weekly safety meeting. OA valve will not function call out well support techs. PU/MU . lubricator and pressure test to 500 psi with diesel, pull BPV. Test surface lines to 3,500 psi and down stream to Tiger tank to 500 psi. Open well to closed Choke. WHP's: Tubing = 250 psi, IA = psi• ee an to ing to psi on t e u ing and 110 psi on the IA. Pump 35 bbls of 8.5 ppg, 140 degF seawater at 3 bpm / 280 psi down the tubing up the IA through the choke to the Tiger tank and recovered 18 bbls freeze protection fluid. Close the Choke and bullhead down the tubing 35 bbls at 1-1/2 bpm / 535 psi (1 bpm / 500 psi). Open the Choke and finish circulating seawater around the long way until clean returns observed on surface. Weight of returns was 8.5 ppg and returns were hot. Pumped a total of 475 bbls at 3 bpm / 280 psi down the tubing up the IA through the choke to the Tiger Tank during final circulation. Total returns on surface were 480 bbls of fluid - -5% losses for the whole well kill operation. Shut down and monitor the well for 30 minutes. The well is not dead. SITP and SICP of 80 psi. Bleed off and builds back up to 80 psi quickly. Calculate kill weight with 100 psi overbalance at 4200' TVD to be 9.3 00o brine. Discuss with Anchorage Engineering and Workover Ops Superintendent of change in scope to weight up and re-kill the well, Order out two loads of 140 degF, 9.3 ppg brine and wait on them to arrive on location. RU Elephant Trunk and spot the Spooling Unit. Service the Rig. RU 2-7/8" Handling Equipment. Hold weekly safety meeting with the day crew. Continue waiting on the two loads of 9.3 ppg brine to arrive on location. Shut in pressures have fallen slightly: Tubing = 50 psi IA = 50 psi. Open well to closed Choke. WHP's: Tubing = 40 psi, IA = 50 psi. Bleed IA and tubing to 20 psi on the Tubing and 30 psi on Printed: 5/18/2009 9:55:54 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 'From - To 15/3/2009 121:30 - 00:00 15/4/2009 100:00-00:30 00:30 - 01:30 01:30 - 02:30 02:30 - 03:30 03:30 - 05:00 05:00 - 10:30 10:30 - 14:30 14:30 - 15:30 15:30 - 17:00 17:00 - 17:30 17:30 - 19:00 19:00 - 19:30 19:30 - 20:00 20:00 - 00:00 MPJ-04 MPJ-04 WORKOVER NABOBS ALASKA DRILLING I NABOBS 3S Hours Task ~ Code~PT 2.501 KILL I C 0.50 KILL C 1.00 KILL C 1.00 KILL C 1.00 WHSUR P 1.501 WHSUR I P 5.50 BOPSU P 4.00 BOPSU P 1.00 BOPSU P 1.50 WHSUR P 0.50 PULL P 1.50 PULL P 0.50 PULL P 0.50 PULL P 4.00 PULL P 5/5/2009 100:00 - 10:00 I 10.001 PULL 1 P Start: 5/2/2009 Rig Release: 5/8/2009 Rig Number: Page 2 of 4 Spud Date: 12/29/1990 End: 5/8/2009 Phase Description of Operations DECOMP the IA. Pump 35 bbls of 9.3 ppg brine 140 degF at 3 bpm / 240 psi down the tubing up the IA through the choke to the Tiger tank and recovered a total of 31 bbls (- 3 bbls crude mixed with seawater) fluid. Close the Choke and bullhead down the tubing 35 bbls at 2 bpm (500 psi (1 bpm ! 100 psi). Open the Choke and finish circulating 241 bbls 9.3 ppg brine around the long way until clean returns observed on surface, lost 22 bbls to formation. -10% losses Burin entire well kill. DECOMP Shut down and monitor the well for 30 minutes. Well slightly out of balance. DECOMP U-Tube tubing to IA. Tubing and IA on slight vac~~m. DECOMP Blow down lines and kill manifold. DECOMP Cameron wellhead tech dry rod 2-1/2" Type "H" TWC. ressure test rom above to 3,500 si for 10 charted minutes. Test the TWC from below with LRS by pumping down the IA at 6 bbls, pumped a total of 43 bbls into the formation during the test. DECOMP RD kill manifold and lines. ND production tree and adaptor flange with Cameron rep. Screw in 2-7/8" EUE 8rd Landing Joint with 8-3/4 turns and flag Landing Joint depth at the Rotary Table RKB. DECOMP Slide ROPE cradle into ce{lar and NU BOPE. Function test and find leaking lockdown, re-tighten OK. The well is taking -8 bbls per hour of 9.3 ppg brine while gravity feeding it. DECOMP Pressure test BOPE to 250 psi low and 3,500 psi high per BP / AOGCC Regulations. Each test held for 5 minutes. The VBRs and Annular were tested with a 2-7/8" Test Joint. The test was witnessed by the Toolpusher and Well Site Leader. The State's right to witness the test was waived by John Crisp at 1000 hrs on 5/3/2009. DECOMP Drain the Stack and RD test equipment. DECOMP PUMU Opso Lopso, Pump In Sub and Lubricator with Polished Rod. Pressure test with diesel to 500 psi. Pull 2-1/2" Type "H" TWC. The Tubing is on a vac. LD Lubricator and Opso Lopso. DECOMP Screw into Hanger with 2-7/8" Landing Joint. BOLDS with Cameron reps. Check the IA through 2" valve - IA on a vac. Pull the Hanger off seat with PUW = 43K and ull the Han er to the Floor with PUW = 42K. DECOMP Circulate surface to surface with 9.3 ppg brine at a rate of 3 bpm 1360 psi. Pump a total of 258 bbls with 36 bbls losses during circulation. DECOMP BO/LD landing joint and tubing hanger. DECOMP RU floor to pull ESP/HT. DECOMP POH with ESP/HT on 2-7/8" tubing, LD first 12 joints and snake ESP/HT over sheave in Derrick into spooling unit. Pump across top of well with continuous hole fill. 15 joints out at 0000 hours. DECOMP Continue to POH from joint #15 with ESP/HT completion standing back 2-7/8" in Derrick. Maintain continuous hole fill wit -9 p oss rate. loin s ou a ours. u e 532 x 6' flat guards, 11 x 4' flat guards, 41 x 3' flat guards, 29 LaSalle clamps, 4 protectalizers, and 2 armster guards. Printed: 5/18/2009 9:55:54 AM • BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: MPJ-04 Common Well Name: MPJ-04 Spud Date: 12/29/1990 Event Name: WORKOVER Start: 5/2/2009 End: 5/8/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/8/2009 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task .Code' NPT Phase ~ Description of Operations 5/5/2009 10:00 - 13:00 3.00 PULL P DECOMP On surface with the ESP Assembly. Break out and lay down with Centrilift rep. Maintain continuous hole fill with 9.3 ppg brine while on surface. 13:00 - 15:00 2.00 PULL P DECOMP Clear and clean Rig Floor. RD Elephant Trunk. 15:00 - 15:30 0.50 CLEAN P DECOMP RU 1-114" Handling Equipment. PU all tools to the Rig Floor. 15:30 - 17:00 1.50 CLEAN P DECOMP RIH with 1-1/4" CS Hydril joints, torque all connections to 600 ft-Ibs. Fluid loss rate = 7 bbl/hr. 17:00 - 18:00 1.00 CLEAN P DECOMP RD 1-1/4" handling equipment. RU to run 2-7/8" tubing. 18:00 - 21:00 3.00 CLEAN P DECOMP RIH with 2-7/8" tubing out of Derrick. Fluid loss rate = 7 bbl/hr. 21:00 - 00:00 3.00 CLEAN P DECOMP PUW = 26K, SOW = 21 K. Tag at 5074' (appears to be top of packer ent based off correc a na a to wor i e thru obstruction with max WOB at 4K. MU circulating pin and wash down with 2 BPM / 600 psi from 5074' to 5080'. Washing off slow. Reciprocate pipe several times thru tight spot with pump on and then off with out any further restriction noticed. Build 15 bbl hi-vis sweep and RU to reverse circulate. Circulated 100 bbls with 10 bbls lost to formation. 5/6/2009 00:00 - 02:30 2.50 CLEAN P DECOMP Reverse circulate with 15 bbl hi-vis sweep surface to surface at 2 BPM / 300 psi. Sweep recovered crude and minimal scale shavings. Circulated 230 bbls and lost 52 bbls to formation (78% returns). Allow well to stabilize and monitor for 30 min. eciproca a pipe back thru previous tight spot at 5,074' without restriction. 02:30 - 05:00 2.50 CLEAN P DECOMP Single in hole with 2-7/8" tubing making up circulating pin to ever connection. RIH from 5,080' to 5 680' without obstruction. Flush pipe with i0 bbls to ensure mule shoe is clear. 05:00 - 07:00 2.00 CLEAN P DECOMP LD 6 'oints of 2-7/8" 1 xi in shed to s t workstrin at 5 500'. Prep floor for acid job. Blow thru cement line. Wait on Sclumberger to make change out to start Acid job. 07:00 - 08:00 1.00 CLEAN P DECOMP Hold PJSM with Schlumberger, LRS, and rig crew. Pressure test lines to 2000 psi. LRS pumped 3 BBLS of methanol. 11 BBLS of DAD Acid, and 3 BBLS of methanol 1 BPM with 700 sP i• 08:00 - 09:00 1.00 CLEAN P DECOMP Rig pumped 15 BBLS of 9.3 PPG brine 1.5 BPM with 640 psi. Shut down pump and close bag. Bullhead 12 BBLS of 9.3 PPG brine with .5 BPM C~3 500 psi. 09:00 - 10:00 1.00 CLEAN P DECOMP Allow Acid to soak for 1 hour. 10:00 - 10:30 0.50 CLEAN P DECOMP Bullhead 50 BBLS of 9.3 PPG brine 1.5 BPM with 730 psi to flush screens and perfs. 10:30 - 11:00 0.50 CLEAN P DECOMP Blow down and rig down circulating lines. 11:00 - 11:30 0.50 CLEAN P DECOMP Monitor well for 30 minutes. Well on a vac. 11:30 - 12:30 1.00 CLEAN P DECOMP Lay down 7) jts. of 2-7/8" tubing to pipe shed. 12:30 - 14:30 2.00 CLEAN N DECOMP Shut down rig due to Tour pusher going to Field meeting in Prudhoe and Tool pusher changing out. (Crews worked on PM's and procedures). 14:30 - 18:00 3.50 CLEAN P DECOMP POOH with 2-7/8" tubing used for work string, standin back in , derrick. 18:00 - 19:30 1.50 CLEAN P DECOMP RU 1-1/4" handling equipment. LD 20 Its of 1-1/4" CS Hydril , workstring 1x1 in pipe shed. Clean and clear rig floor. Loss rate = 4-6 bbl/hr 19:30 - 23:00 3.50 BUNCO P RUNCMP RU floor to MU ESP assembly. PUMU ESP assembly as per tally. Check and service .Maintain continuous hole fill Printed: 5/18/2009 9:55:54 AM BP EXPLORATION Operations Summary Report Page4of4~ Legal Well Name: MPJ-04 Common Well Name: MPJ-04 Spud Date: 12/29/1990 Event Name: WORKOVER Start: 5/2/2009 End: 5/8/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/8/2009 Rig Name: NABOBS 3S Rig Number: Date From- To 'Hours Task Code, NPT ! Phase 5/6/2009 19:30 - 23:0~0 3.50 RUN 23:00 - 00:00 1 1.00 RUN 5/7/2009 00:00 - 01:30 1.50 RUN 01:30 - 22:30 21.00 RUN 22:30 - 23:30 ~ 1.00 ~ RU 23:30 - 00:00 0.50 5(8(2009 00:00 - 03:00 3.00 03:00 - 03:30 0.50 BUNCO P 03:30 - 05:30 2.00 BOPSU P Description of Operations RUNCMP with loss rate of 4-6 bbl/hr. RUNCMP MU gauge unit to ESP. Perform I-Wire splice and terminate to ESP. RUNCMP Finalize I-Wire splice. Make conductivity checks. RUNCMP RIH with 2-7/8" 6.5# 8-rd tubin out of Derrick. MU torque on connections = 2,300 ft-Ibs. Use Best-O-Life pipe dope on all connections. Install LaSalle Clamps for first 10 joints then every other joint until heat trace on joint #47. Install bands and flat guards around heat trace and ESP cable. Check conductivity every 1,200' as per Centrilift. Flush pump at 0300 hrs with 10 bbls at .5 BPM / 990 psi. Loss rate = -5 bbl/hr. Ran a total of 154 joints, 29 LaSalle clamps, 4 protectalizers, 2 armster guards, 6 Cannon clamps, 2half-Cannon clamps, 547 x 6' heat trace, 20 x 4' heat trace, 36 x 2' heat trace guards and 1,749 steel bands. MU circulating pin and flush pump with final 10 bbls at .5 BPM / 980 psi. RUNCMP PU landing joint with TIW valve and MU to tubing hanger. MU hanger to string. Install penetrators and shipping caps with Cameron rep. RUNCMP Perform heat trace and ESP cable hanger splice with Centrilift rep. RUNCMP Finish heat trace and ESP cable penetrator splice. Conduct checks: BHP = 1681 psi, BHT = 60.2 degF, Phase to Phase = 2.0 ohms, Phase to Ground = 2 gig ohms. RUNCMP Final weights: PUW = 38K, SOW = 30K. Land tubing hanger and RILDS with Cameron rep. LD landing joint and TIW valve. RUNCMP PU T-bar and d rod TWC with Cameron. Test from above to 3,500 psi for 10 min -charted. Conduct rolling test from below to 500 osi for 10 min -charted. Pumped a total of 33 bbls and 05:30 - 07:30 2.00 BOPSU P RUNCMP PJSM. ND BOPE and lay in cradle. 07:30 - 09:00 1.50 WHSUR P RUNCMP Orient adapter and tree, N/U and torque bolts. 09:00 - 10:30 1.50 WHSUR P RUNCMP Test adapter void to 5K for 30 minutes with Cameron. Test tree to 5K for 5 charted. Take final conductivity checks: BHP = 1658 psi, BHT = 72 degF, Phase to Phase = 2.2 ohms, Phase to Ground = 600 meg ohms. 10:30 - 12:00 1.50 WHSUR P RUNCMP PU lubricator and MU to tree. Test to 500 psi with diesel. Pull TWC and set BPV. RU Little Red to test from below. 12:00 - 14:00 2.00 WHSUR P RUNCMP Test BPV from below. Pump 30 bbls at 3 BPM / 600 psi max for 5 min -charted. Bled down and blow down lines. RD LRS. 14:00 - 15:00 1.00 WHSUR P RUNCMP Remove second annulus and secure tree and cellar. Rig released at 1500 hrs. Printed: 5/18/2009 9:55:54 AM STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 5/412009 Rig Rep.: G. Sweatt / J. Fritts Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: W. Hoffman / D. Rhodes Field/Unit & Well No.: MPU J - 04 PTD # '!900980 Operation: Drlg: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250!3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 0 NA Housekeeping: P Drl. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Batt Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 5m P Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 3 1/8" 5m P HCR Valves 1 2 1/16" 5m P Kill Line Valves 1 2 1/16" 5m P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 2950 P Pressure After Closure 1700 P 200 psi Attained 34 sec P Full Pressure Attained 3 min P BFnd Switch Covers: All stations P Nitgn. Bottles (avg): 4@1960 Number of Failures: 0 Test Time: 5 Hours Components tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Remarks: 24 HOUR NOTICE GIVEN YES x NO Waived By John Cris Date 05/02/09 Time 49:15:00 hrs. Witness G.Sweatt NV.Hoffman Test start 9:00 Finish 14:00 hrs. BOP Test (for rigs) Nabors 3S BOP Test MPU J - 04 5-04-2009 .xls Kt:l.,t:IV t:u . STATE OF ALASKA . . ._ ALA Oil AND GAS CONSERVATION c~tb~007 RE PORT OF SU N DRY WEYt.~Iði=M1dQ~IJJÏJ,§jy!\;orrection of Summary Data & Pool .~ .3-/5-(/7 . . 1. Operations Performed: o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 190-098 ". 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22073-00-00/ 7. KB Elevation (ft): 70.20 9. Well Name and Number: MPJ-04 - . 8. Property Designation: 10. Field / Pool(s): ADL 025906 I . Milne Point Unit / Schrader Bluff ' 11. Present well condition summary Total depth: measured 6320 ' feet true vertical 4571 . . feet Plugs (measured) NONE Effective depth: measured 6008 feet Junk (measured) NONE true vertical 4328 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 13-3/8" 105' 105' 1740 750 Surface 2878' 9-518" 2913' 2397' 3520 2020 Intermediate Production 6264' 7" 6299' 4554' 7240 5410 Liner iCANNEÐ MAR 2 () 2007 Perforation Depth MD (ft): 5524' - 5853' Perforation Depth TVD (ft): 3947' - 4207' 2-7/8",6.5# L-80 4977' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Screen Assembly - 7" Otis Versatrieve Packer and a 7" 5063', 5680' AWD Perma Series Packer with a leg to 5698' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: 0 0 0 Subsequent to operation: 0 0 0 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Bryan McLellan, 564-5516 Pri~ ~Stewman_ Title Technical Assistant , 1 ~~ . Prepared By Name/Number: ignature :/"''t'" rvÃ '.Å~ r- Phone 564-4750 Date CJ3- ( j 'O'1ondra Stewman, 564-4750 Form 10-404 Revised 04/2006 S Sft MAR 'î 9 , Submit Original Only ORIGINAL ZOUI 10 ,.Áb"3·'/'" -"7 ll(, ~ JifÍ¿;b? Tree: WKM 2 9/16" 5M Wellhead 11" x 11" 5M tbg. spool, 11" x 2 7/8" 8 rd EUE (top & bottom) WKM tbg. hng. wI 2.5" 'H' BPV profile. 133/8",54.5 ppf, K-55 Butt Weld 105' I KOP @ 400' Max Hole Angle: 600 @ 3900' MD Hole angle through perfs = 39 deg. ~i\) 95/8",36 ppf, K-55, Btrc. ~ 2718" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf) 7" 26 ppf, L-BO, Btrc. production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) New #1 Ceber SS cable installed 12/27/02 PERFORATION SUMMARY REF LOG: SWS DIUSFL 3/91 Size SPF MD TVD "N" Sands 4.5" 12 5524'-5540' 3946'-3959' 4.5" 12 5562'-5610' 3976'-4014' 4.5" 12 5630'-5660' 4030'-4053' "0" Sands 4.5" 5 5735'-5777' 4113'-4146' 4.5" 5 5820'-5853' 4180'-4206' MP J-04 sand to 6002' KB elev. = 70.2' OF elev. = 68.7' GL elev. = 35.0' 2-7/8"x 1" KBMM GLM I 175" Centrilift 3418' heat trace 2-7/8"x 1" KBMG-M-2 GLM I 4767' 2-7/8" HES XN nipple(2.205") 4910' Centrilift 146 stage 4927' 400-P6 MSSD 1-5 Gas Separator 4946' Tandem SS 4951' G3B3DBFERHLSSCVH6SBI SBPFSA KMHG 76 hp motor, 4965' 1360 v./34 amps. Centrilift Pumpmate 4973' HES Versatrieve packer @ 5063' MD ( 3.25"id) 2-7/8" Blank pipe 432' 145' - 12 ga screen 2.44" id @ 5521' Gravel pack N-Sands 20/40 mesh gravel O-Ring seal sub (2" id) @ 5666' 11'- 12 ga screen 2.44" id HES AWD Sump packer @ 5680' MD (4.0" id) HES XN-Nipple (1.791"10) @ 5697' WLEG @ 5698' 7" float collar (PBTD) 7" casing shoe 6208' md 6299' md DATE REV. BY COMMENTS MILNE POINT UNIT 4/07/91 RWOI MULTIPLE FRAC PACKS WELL J'()4 1 0/19/92 ESP RWO EWS Ri - 4 API NO: 50'()29-22073 " 12/27/02 M.Linder ESP changeout, Ran new Centilift heat trace. 02/21/07 R. Handy ESP RWO Rig 3S BP EXPLORATION AK . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-04 MPJ-04 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/14/2007 Rig Release: 2/20/2007 Rig Number: N3S Spud Date: 12/29/1990 End: 2/20/2007 2/13/2007 16:00 - 19:30 3.50 RIGD P PRE Rig down rig components and prepare to move from MPJ-08A 100' south to MPJ-04. 19:30 - 00:00 4.50 MOB P PRE Move Pipe Shed to location at MPJ-04. Back Pits away from . Carrier and drive Carrier to MPJ-04. Center Carrier over the hole (not the Tree). Spot Pits next to Carrier. Clear snow and spot BOP Cradle behind Cellar. 2/14/2007 00:00 - 03:00 3.00 RIGU P PRE M/U Berming around Carrier and Pits. Level Carrier, Pits, and Pipe Shed. Raise and scope Derrick. 03:00 - 07:30 4.50 RIGU P PRE Move in and spot Tiger Tank. M/U Hardline and Berming for Tiger Tank. M/U Steam Lines and Electrical Lines. Accept rig at 0600-hrs. 07:30 - 10:30 3.00 KILL P DECOMP Take on fluid to Pits. Connect Hardline to circulating lines. Steam and test Hardline, then blow it down before starting Well Kill circulation. 10:30 - 11 :00 0.50 KILL P DECOMP P/U Lubricator and pul BPV. 11 :00 - 11 :30 0.50 KILL P DECOMP PJSM on Rig Floor with crew, Veco truck driver, Tool Pusher, and WSL to discuss well kill operations. Hooked Veco truck to driller side of the Rig Carrier, directly into the charge pump suction. 11 :30 - 12:30 1.00 KILL P DECOMP Air line from Driller's console to Mud Pump clutch frozen. Drain airline and build air pressure for blowing down hardline. Steam out blow down hardline to Tiger Tank. 12:30 - 13:00 0.50 KILL P DECOMP Open choke to take returns to Tiger Tank and IA pressure immediately bleeds from 380-psi to O-psi. Start Mud Pump to pump 120-F seawater and build rate from 1-BPM to 4-BPM; pressure climbs from 80-psi to 400-psi on the Tubing and from O-psi to 150-psi. Returns to the Tiger Tank after 10-Bbls pumped. Pump 1500-stks = 35-Bbls, and S/IIA to Bullhead. 13:00 - 13:30 0.50 KILL P DECOMP Bullhead 120-F seawater at 1.5-BPM, 360-psi for 1500-strokes = 35-Bbls into formation. 13:30 - 16:00 2.50 KILL P DECOMP Open IA and take returns to Tiger Tank. Circulate at 4-BPM and pressure in tubing builds from 320-psi to 395-psi; pressure in IA builds to 250-psi, then gradually falls off to 20-psi after 8,500-strokes = 207-Bbls. Continue pumping to empty Veco Vac truck and tubing pressure is 370-psi, IA pressure remains at 20-psi. Returns are seawater. Hook up empty Vac truck to Tiger Tank and pull off 240-Bbls of returns estimated at 80% seawater, 20% oil, and trace of Diesel. 35-Bbls Bullheaded into formation and 15-Bbls lost to the formation. 16:00 - 17:00 1.00 KILL P DECOMP Blowdown all lines and monitor well. Well on vacuum on both sides. Break out circulating lines, clear cellar and wait for Well support to install TWC. 17:00 - 18:00 1.00 WHSUR P DECOMP Well support personnel P/U TWC on Dry rod and RIH to set in Hanger profile. 18:00 - 20:30 2.50 WHSUR P DECOMP Thaw out Test Pump Tank. Place steam on Tree in order to prevent freezing while testing TWC. Line up to pump down the IA. Test TWC from above to 3500 psi. Lose 300 psi in 2 minutes. prr again from above to 3500 psi. Gain 250 psi in 5 minutes. Suck dry Tree to ensure it is not frozen. Test Pump Manifold and Hose are frozen. Thaw Manifold and Hose. 20:30 - 21 :30 1.00 WHSUR P DECOMP Move BOP Cradle in order to close Cellar Doors. Place plywood over piping train and cable trays behind rig to prevent elephant trunk from contacting the trays. Printed: 3/13/2007 8:43:04 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-04 MPJ-04 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/14/2007 Rig Release: 2/20/2007 Rig Number: N3S Spud Date: 12/29/1990 End: 2/20/2007 2/1412007 21 :30 - 00:00 2.50 WHSUR P DECOMP Test TWC from above to 3500 psi for 10 minutes and chart; test flat-lined. Test TWC from below to 1000 psi. Pumped 3 BPM at 350 psi for 10 Bbls away to the formation. Test not possible. It took 15 Bbls to fill the IA. The well is taking -2 Bbls/hr. 2/1512007 00:00 - 02: 15 2.25 WHSUR P DECOMP PJSM. Suck Tree dry. N/D Tree and Adapter Flange. Function all LDS with success. Screw XO into the top of Hanger with 7.5 . turns. Threads in good condition. 02:15 - 03:00 0.75 KILL P DECOMP FiIIlA w/5 Bbls of seawater. Losses at 2 Bbls/hr. Release Vac Truck. 03:00 - 07:00 4.00 BOPSU P DECOMP PJSM. N/U BOPE. 07:00 - 15:00 8.00 BOPSU P DECOMP Thaw frozen test pump lines and replace Whitey valves in test pump manifold. Continue to thaw and drain Roughneck Heaters in the Cellar. Repair burst lines in steam distribution system. Hook-up additional trunk for Tioga Heater to reach Cellar. Remove heater cores from both Roughneck heaters; only have one replacement core. Haul both to 3S shop for repairs. 15:00 - 19:00 4.00 BOPSU P DECOMP Start BOPE tests, 250-psi low, 3,500-psi high. Test Annular Preventer, TIW valve. Dart valve froze up. Resume testing and Pipe Rams won't function. Drain stack to check actuation of rams. Drain line frozen. Test Pump Manifold frozen. Thaw Hoses and Manifold. 19:00 - 20:30 1.50 BOPSU P DECOMP Thaw frozen test pump lines and replace Whitey valves in test pump manifold. 20:30 - 00:00 3.50 BOPSU P DECOMP Pressure test BOPE to 250 psi low and 3500 psi high. 2/16/2007 00:00 - 00:30 0.50 BOPSU P DECOMP Pressure test BOPE to 250 psi low and 3500 psi high. 00:30 - 03:00 2.50 PULL P DECOMP Blow all Lines down to prevent freezing. Fill IA with 2 Bbls of seawater. PUMU Lubricator and Opso Lopso. Pull TWC wI Cameron onsite. T/I/O = 01010 psi. UD Lubricator and Opso Lopso. RIH wI Landing Joint and M/U TIW to secure well. 03:00 - 05:00 2.00 PULL P DECOMP R/U Sheave and Elephant Trunk. Layout Herculite between Spooler and Cable Trays. R/U equipment to pull 2-7/8" ESP completion. 05:00 - 06:00 1.00 PULL P DECOMP BOLDS. Check IA for pressure. IA = 0 psi. Pull Hanger to Floor. 50k -Ibs. to pull Hanger free. P/U weight after the Hanger was free = 45k-lbs. 06:00 - 07:00 1.00 PULL P DECOMP Attach 1/2" nylon ropes to the heat trace and ESP cables. Pull ropes through the Sheave and Elephant Trunk 07:00 - 09:30 2.50 PULL P DECOMP Start POH with ESP while pulling ropes over Spools in Spooler. Get two stands out and add start pump to circulate seawater across the top of the well and out through Flow Line for constant hole fill. Flow Line is frozen solid from outside the Rig Floor to the Mud Pits. SID and thaw out Flowline. 09:30 - 16:30 7.00 PULL P DECOMP Thaw Flowline. Remove the flexible section of Flowline and shorten it to take the belly out of it. Replace and M/U clamps. 16:30 - 00:00 7.50 PULL P DECOMP Resume POH and SIB 2-7/8" Tubing in Derrick. Threads galled on bottom of stand #3. 20 stands OOH @ 2300. Averaging 6 stands/hr. 2/17/2007 00:00 - 16:00 16.00 PULL P DECOMP POH wI 2-7/8" ESP completion while standing Tubing back in / the Derrick. Losses at 4-6 Bbllhr. 37-stands OOH @ 0330-hrs. Averaging 5 stds/hr. 50-stands OOH @ 0745-hrs. Pin end on stand #69 and box end on stand #70 have galled threads. Printed: 3/13/2007 8:43:04 AM . . ., Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-04 MPJ-04 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/14/2007 Rig Release: 2/20/2007 Rig Number: N3S Spud Date: 12/29/1990 End: 2/20/2007 2/1712007 00:00 - 16:00 16.00 PULL P DECOMP 70-stands OOH @ 1145-hrs. At ESP at 1500-hrs. 50 bands were missing according to 4ES completion tally. 16:00 - 20:00 4.00 PULL P DECOMP Break out, service, and lay down the ESP components. Pump discharge was completely packed with gummy, sticky sand/formation fines. 20:00 - 22:30 2.50 PULL P DECOMP RIH with bad joints of 2-7/8" Tubing (Jts # 7-11, 18, and 19). Break and UD bad joints. Replace bad joints with new 6.5# L-80 2-7/8" Tubing. 7 jts. replaced in total. 22:30 - 00:00 1.50 RUNCO RUNCMP P/U and M/U new ESP assembly (Centralizer, Pumpmate Sensor, 76 HP Motor, Lower and Upper Seal sections, Gas Separator with 400 internals, 170 Stage Pump, and Discharge Head). Service ESP components as RIH. 2/18/2007 00:00 - 02:30 2.50 RUNCO RUNCMP P/U and M/U new ESP assembly (Centralizer, Pumpmate Sensor, 76 HP Motor, Lower and Upper Seal sections, Gas Separator with 400 internals, 170 Stage Pump, and Discharge Head). Service ESP components as RIH. Feed ESP cable through Elephant Trunk, around Sheave and terminate. 02:30 - 13:00 10.50 RUNCO RUNCMP RIH wI ESP completion on 2-7/8", 6.5# L-80 EUE 8rd Tubing. Using Best of Life Pipe Dope. Placed LaSalle clamps on the first nine joints, then every other joint up to surface. LaSalle Clamps placed on GLM pups. 2-7/8" Tubing was made up to 2,300 ft-Ibs. Install bottom nose of Heat Trace in middle of Joint #47 @ -3,418' MD, 0600-hrs. 76-jts RIH @ 1300-hrs. 13:00 - 13:30 0.50 RUNCMP Clear and clean Rig Floor, bring more Heat Trace channels to Rig Floor, and dispose of strap cutoffs. 13:30 - 00:00 10.50 RUNCMP Continue RIH ESP on tubing from Derrick. Replace the bad joint on top of stand #39 Üt #78) at 1430-hrs. Set stand #40 in Mousehole and break out the bottom jt, but the pin and box are galled. UD both joints and P/U two from the Pipe Shed and continue RIH. 2/19/2007 00:00 - 06:00 RUNCMP Cont. RIH wI ESP completion on 2-7/8" Tubing from the Derrick. Running Heat Trace from 3418' MD. Replace Jts #148 and #149. Replaced a total of 12-joints during the running of the completion. 06:00 - 08:30 RUNCMP P/U Tubing Hanger and M/U to Landing Joint and to 10' pup at top of string. Torque and position hanger per instructions from Cameron and Centrilift technicians. 08:30 - 12:30 RUNCMP Make Heat Trace cable splice to Heat Trace Penetrator pigtails. Make ESP cable connection to ESP Penetrator pigtails. Final check on impedance for Heat Trace: 4.0-ohms phase-to-phase, 278-giga-ohms phase-to-ground. Final check on impedance for ESP Cable: 2.4-ohms phase-to-phase, 3.68-giga-ohms phase-to-ground. ESP and Heat Trace cables jewelry tally: 1825 super bands; 539-ea 6' Heat Trace channels, 10-ea 4' Heat Trace channels, 4-ea 3' Heat Trace channels; 4-Protectolizers; 2-Armsterguards; 29-LaSalle clamps. 12:30 - 14:00 1.50 RUNCO RUNCMP P/U on Landing Joint and RIH to land Tubing Hanger. RILDS and back off and UD Landing Joint. 14:00 - 19:30 5.50 RUNCO P RUNCMP Cameron Technician P/U TWC, RIH and set with dry rod. Test TWC to 1000-psi from below and above. Test rock-solid from above. Test from below (3-BPM @ 200-psi, for 10-Bbls) verifies injectivity to the formation with no leakage into BOP stack. Did Printed: 3/13/2007 8:43:04 AM <" . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-04 MPJ-04 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/14/2007 Rig Release: 2/20/2007 Rig Number: N3S Spud Date: 12/29/1990 End: 2/20/2007 POST not pump 10-Bbls of seawater through the pump to clear debris. P/U Lopso Opso and pull TWC. Pump 10-Bbls seawater through pump. Reinstall TWC and test from above to 1,000 psi and chart results. Blowdown Lines. Drain Stack. PJSM for N/D BOPE. N/D BOPE. N/U Tree. - Conduct final ESP cable conductivity checks wI Centrilift. Test Tree and Tubing Head Adapter to 5,000 psi. RlU Lubricator wI Wells Support onsite. Pull TWC. TIIIO = 0/0/0 psi. Install BPV. UD Lubricator. RID Sheave and Elephant Trunk. Release rig @ 0600-hrs. RlU Lil Red to Tree to pump Freeze Protection. Prep for rig move. Scope and lower Derrick. LRS on location @ 16:00 for freeze protection of well. Move to MPF-02 19:30 - 20:30 1.00 RUNCO 20:30 - 00:00 3.50 BOPSU P 2120/2007 00:00 - 02:00 2.00 WHSUR P 02:00 - 02:45 0.75 WHSUR P 02:45 - 04:00 1.25 WHSUR P 04:00 - 05:00 1.00 WHSUR P 05:00 - 06:00 1.00 RIGD P 06:00 - 17:00 11.00 RIGD P 17:00 - 00:00 7.00 RIGD P RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP POST POST POST Printed: 3/1312007 8:43:04 AM RE: MPJ-04 (190-098) . . Tom, I have prepared the resubmit package for well MPJ-04 correcting the pool data as well as, attaching the Operation Summary report for the Rig work over completed in February 2007. These documents will be submitted to the AOGCC this afternoon via our courier envelope. Please advise if you require anything further and thank you for your assistance with this matter. Sondra -----Original Message----- From: Thomas Maunder Ito:~om Sent: Tuesday, March 13, 2007 7:44 AM To: Stewman, Sondra D Subject: MPJ-04 (190-098) . state. aj·;:. us Sondra, I have done a little more review on the sundry dated March 7 for this well. It appears that you will need to resubmit the "packet". The attachments are for a workover performed in December 2002, not the one most recently completed February 20. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 3/13/20078:56 AM ~ . STATE OF ALASKA _ ~../A~~ ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon ~ Repair Well ~ Pull Tubing o Operation Shutdown o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 70.20 8. Property Designation: ADL 025906 11. Present well condition summary Total depth: measured 6320/ feet true vertical 4571 I feet Effective depth: measured 6008 feet true vertical 4328 feet Casing Structural Conductor Surface Intermediate Production Liner Length Size 70' 2878' 13-3/8" 9-518" 6264' 7" Perforation Depth MD (ft): Perforation Depth TVD (ft): 5524' - 5853' 3947' - 4207' Tubing Size (size, grade, and measured depth): RECEIVED MAR 0 9 2007 Alaska Oìl & Gas Cons. Commission nc orage o Re-Enter Suspended Well ~ Other Change Out ESP o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate 0 Time Extension 4. Well Class Before Work: 5. Permit To Drill Number: 181 Development 0 Exploratory 190-098 I o Stratigraphic 0 Service 6. API Number: 50-029-22073-00 9. Well Name and Number: MPJ-04 ,¡ 10. Field / Pool(s): Milne Point Unit / Kupa Plugs (measured) Junk (measured) 4554' Burst Collapse 1740 750 3520 2020 7240 5410 2-7/8",6.5# 4977' L-80 Packers and SSSV (type and measured depth): creen Assembly - 7" Otis Versatrieve Packer and a 7" A WD Perma Series Packer with a leg to 5698' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 5063', 5680' Treatment description including volum used and final pressure: Re resentative Dail Avera e Production or In"ection Data Gas-Met Water-Bbl Casin Pressure Tubin Pressure o 0 o 0 15. Well Class after proposed work: o Exploratory ~ Development 0 Service 16. Well Status after proposed work: ~ W II Schematic Diagram ~ Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify tha the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Bryan McLellan, 564-5516 13. Prior to well operation: Subsequent to operatio 14. Attachments: Oil-Bbl o o f Logs and Surveys run eport of Well Operations Printed Name Sondra Stewman Form 10-404 Revised °UK I G 1 ì\J A L Title Technical Assistant Prepared By Name/Number: Phone 564-4750 DateD -t51-D RBDMS BF"l MAR 1 9 2007 Sondra Stewman, 564-4750 Submit Original Only ~~ fV¿. -ø,? ... . STATE OF ALASKA ___ ALAS OIL AND GAS CONSERVATION COMM~N REPORT OF SUNDRY WELL OPERATIONS o o o RECEIVED 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Exploratory Service Stimulate[~} Ot~fAfill fI 4 7007 WaiverD Time Extension 0 Re-enter Su 0:. 1'!!ßàs Cons. Commission 5. Permit to Drill N_örage 190-0980 . 6. API Number: 50-029-22073-00-00 . P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 9. Well Name and Number: 70.2 KB MPJ-04 . 8. Property Designation: ADLO-025906 . 11. Present Well Condition Summary: 10. Field/Pool(s): MILNE POINT Field/ SCHRADER BLUFF OIL Pool Total Depth measured true vertical 6320 4570 feet feet Plugs (measured) Top of Frac Sand fill @ 6002' Junk (measured) None Effective Depth measured 6002 feet true vertical 4323 feet Casing Length Size MD TVD Burst Conductor 70' 13-3/8" 54.5# K-55 35' - 105' 35' - 105' 2730 Surface 2878' 9-5/8" 36# K-55 35' - 2913' 35' - 2397' 3520 Production 6264' 7" 26# L-80 35' - 6299' 35' - 4554' 7240 Collapse 1130 2020 5410 SCANNED JAN 0 8 2007 Perforation depth: Measured depth: 5524' - 5853' True Vertical depth: 3946' ·4207' - - - - Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 35' - 4979' Packers and SSSV (type and measured depth) 7" Otis Versatrieve 7" AWD Perma Series o o 5063' 5680' o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8Ft Ü 8 2007 Treatment descriptions including volumes used and final pressure: T /1/0=350/300/0 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 180 SHUT IN Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 46 154 0 o 0 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil p. Gas WAG Tubing pressure 297 o Service x Contact Gary Preble WINJ WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Data Engineer Signature Phone 564-4944 Date 1/3/2007 .6- ~/"7J Submit Original Only .-41::> (.ç: crt .. -" . . MPJ-04 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY (Acid treatment). Pump 10 bbls crude down tbg for injectivity test by 10 bbls 12% DAD acid. Flush wi 3 bbls 60/40 meth. Spot acid @ ESP 15 bbls crude. Let acid soak for 10 minutes. Start ESP against closed choke pumping crude @ .5 bpm for 5 bbls. Pump 30 bbls crude & 10 bbls diesel. well over to DSO. FWHP=550/60010. Shortly After turning well over to the Pad operator, the ESP experienced a ,/ electrical failure - Need to add to RWO list********** 12/31/2006 Flush test line & prod line wi 2 bbls neat & 5 bbls diesel each. FLUIDS PUMPED BBLS 60 CRUDE 10 12% DAD ACID 10 DIESEL 3 60/40 METH 83 TOTAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 70.2' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2787' SNL, 3307' WEL, SEC. 28, T13N, R10E, UM x = 552012, Y = 6014890 MPJ-04 9. Permit Number/ Approval No. At top of productive interval "'~ 190-098 4826' SNL, 668' WEL, SEC. 28, T13N, R10E, UM x= 554670, Y= 6o1287o 10. APl Number At effective depth ~ 50-029-22073-00 5042' SNL, 466' WEL, SEC. 28, T13N, R10E, UM x = 554874. Y -- 6012656 I I 1. Field and Pool At total depth Milne Point Unit / Kuparuk River 5189' SNL, 331' WEL, SEC. 28, T13N, R10E, UM x= 555o10, Y= 6o125o9 Sands 12. Present well condition summary Total depth: measured 6320 feet Plugs (measured) Top of Frac Sand fill at 6002' true vertical 4570 feet Effective depth: measured 6002 feet Junk (measured) true vertical 4323 feet Casing Length Size Cemented MD TVD Structural Conductor 70' 13-3/8" 500 sx Permafrost 'C' 105' 105' Surface 2878' 9-5/8" 1100 sx PF 'E', 350 sx Class 'G' 2913' Intermediate Production 6264' 7" 405 sx Class 'G' 6299' 4553' Liner Perforation depth: measured 5524' - 5540', 5562' - 5610', 5630' - 5660', 5735' - 5777', 5820' - 5853' true vertical 3946' - 3960', 3977' - 4015', 4031' - 4054', 4117' - 4146', 4180' - 4207' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 tubing to 4979' Packers and SSSV (type and measured depth) Screen Assembly - 7" Otis Versatrieve packer at 5063' and a 7" AWD Parma Series packer at 5680'. 13. Stimulation or cement squeeze summary ~ E Intervals treated (measured) Treatment description including volumes used and final pressure · "-' -~.!aska 0~ & Gas cons. g.'~missi0 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: CANNED FEB [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify thj~-,fl~eJ~re~cl.~ing is true and correct to the best of my~knowledge Signed So~~~~~~' T!*~_,~ Technical Assistant Date (-_~[ ' '~.~ ~ ~ ~ \"'~.~ ~ ~- ,~-'~ 'r' ~', ~ ~'~ '~ Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 RB[IN$ BFI ' '~-- ,.1AN 30 2003 Submit In Duplicate BP EXPLOP, AT!ON Page 1 of 2 Operations.Summe Report Legal Well Name: MPJ-04 Common Well Name: MPJ-04 Spud Date: 12/29/1990 Event Name: WORKOVER Start: 12/25/2002 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/28/2002 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To HOurs TaSk Code NPT Phase Description of Operations 12/9/2002 06'00 - 07:30 1.501 MOB P PRE RDMO NAD 4ES FROM MPE-15 TO MPJ-04. SCOPE / LOWER DERRICK 07.30 - 11:00 3.50 MOB P PRE MOVE CAMP, SHOP, SUB, PITS, PIPE SHED. 11 '00 - 12'30 1.50 RIGU P PRE LAY HERC, SET MATS, SPOT SUB, PITS, PIPE SHED, CAMP. 12:30 - 14:00 1 50 RIGU P PRE RAISE/SCOPE DERRICK REClEVE 300 BBLS 10.1 PPG BRINE 14:00 - 15:30 1.50 RIGU P PRE ACCEPT RIG AT 1400 HRS LH. - RU HCR VLV AND HARD LINES TO TREE, LAY LINES TO TIGER TANK. 15:30 - 16:30 1.00 RIGU P PRE PU LUB, PULL BPV 16:30 - 18:00 1 50 RIGU P PRE PRE SPUD MEETING WITH DAY SHIFT. TEST LINES TO 2500 PSI 18.00 - 19.00 1.00 KILL P DECOMP CIRCULATE 250 BBL140 DEG SEAWATER DOWN TBG TAKING RETURNS FROM GLM AT 4842' TO TT. 19:00 - 21.00 2 00 KILL P DEOOMP SWITCH TO 10 1 BRINE, ClRC 45 BBLS( 15 BBLS UP ANN), CLOSE ANN VLV, BULLHEAD 32 BBLS FROM 4842' TO ~5610' MID PERFS, OPEN ANN VLV AND TAKE RETURNS TO RIG PITS. LOSSlNG ~36 BPH WHILE CIRC. TOTAL BRINE PUMPED 270 BBLS 21 '00 - 22 00 1.00 KILL P DECOMP SD PUMP, MONITOR WELL 30 MIN 0 PSI ON TBGXlA. ATTEMPT TO FILL HOLE WITH 10 BBL. SPUD MEETING WITH NIGHT CREW. 22:00 - 22:30 0 50 WHSUR P DECOMP PJSM-PU LUB SET AND TEST TWC TO 2500 22:30 - 00:00 1.50 WHSUR P DECOMP DRAIN TREE, RD LINES, ND TREE 12/26/2002 00:00 - 01:00 1.00 WHSUR P DECOMP FINISH ND PRODUCTION TREE. OBSERVED BAD THRDS IN TBG HANGER. 01:00 - 04:00 3.00 BOPSUF P DECOMP NU BOPE. 04:00 - 05:30 1 50 BOPSUF P DECOMP BODY TEST BOPE AT 250/2,500 PSI PER BP/AOGCC REQUIREMENTS. GOOD TEST. STATE'S RIGHT TO WITNESS TEST WAIVEY BY J. SPAULDING. 05:30- 06:00 0.50 BOPSUF P DECOMP RU LUBRICATOR. PUL TWC. LD LUBRICATOR. 06:00 - 07:00 1.00 WHSUB P DECOMP MU DOUBLE TBG SPEAR. SPEAR HANGER. BOLDS. PULL HANGER TO FLOOR. HANGER FREE AT 55K. PUW = 43K. 07:00 - 08:00 1.00 PULL P DECOMP LD HANGER. FINISH RU TO PULL ESP/HT COMPLETION. 08:00 - 11.00 3.00 PULL P DECOMP BEGINTOOH WITH 2 7/8" TBG, ESP ASSY AND RAY-CHEM HEAT TRACE. STD PIPE BACK IN DERRICK. TALLY. 11:00 - 15:00 4.00 PULL P DECOMP FINISH TOOH WITH HEAT TRACE SECTION. RU TO LAY DOWN RICE-WRAP TBG IN SINGLES. LD 74 JTS 15:00 - 17:00 2.00 PULL P DECOMP INSPECT PUMP,OK, LD PUMP - RECOVERED 1560 BANDS AND 435 FLAT GUARDS 17:00 - 17'30 0.50 PULL P DECOMP CLEAR AND CLEAN FLOOR OF COMPLETION PULLING EQUIP AND RU TO RUN DC / DP AND RTTS. 17:30-20:00 2.50 PULL P DECOMP PU/RIHWlTH10-43/4DCAND20-31/2DP-RTTSPKR. SET AT 56'. TEST TO 1000 PSI 20:00- 20'30 0.50 PULL P DECOMP RELEASE FROM RTTS 20:30 - 00:00 3.50 WHSUR P DECOMP PJSM W/CAMERON REP. BLED PRES OFF OA, BO/LDS, PULL 7"PACK OFF AND INSTALL NEW PACK OFF. RI/LDS, TEST TO 5000 PSI. GOOD TEST 12/27/2002 00:00 - 01 30 1.50 WHSUR P DECOMP PU RTTS RUNNING TOOL. RELEASE PKR. PULL PRK AND LD. 01 30 - 02 30 1.00 WHSUR P DECOMP TOOH...STAND BACK DP AND DC. 02:30 - 04:00 1.50 CASE P DECOMP PU RTTS PKR AND TIH WITH DC AND DP TO 1336-FT. Prtnted 1/2/2003 I 21 17 PM SCANNED FEB O ,¢,t: 2OD3 BP EXPLORATION Page 2 of 2 Operations :u:mmaw.'Report Legal Well Name: MPJ-04 Common Well Name: MPJ-04 Spud Date: 12/29/1990 Event Name: WORKOVER Start: 12/25/2002 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/28/2002 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task !Code NPT phase Description of Operations 12/27/2002 04:00- 06:00 2.0( CASE P DECOMP RU TO HANDLE 2 7/8" TBG. CONTIUE RIH...PICKING UP TBG FROM PS. 06:00- 09:00 3.00 CASE P DECOMP CREW CHANGE. PJSM. FINISH TIH TO 3,720-FT. FILL HOLE (30 BBLS). SET PKR. TEST CSG TO 3,500 PSI/15 MIN. GOOD TEST. 09.00-11:30 2.50 CASE P DECOMP TOH. STAND BACK 2 7/8" TBG. LDDPANDDC. 11:30 - 12:30 1.00 CASE P DECOMP PJSM. RU HALLIBURTON S-LINE. 12:30 - 15:30 3.00 CASE P DECOMP RIH WITH 1 6" SWAGE TO 5680' SLM, WELL BECAME 'STICKY'. UPPER PERFS "N" SAND, 5524' - 5560' OPEN - LOWER PERFS "O" SAND 5735' - 5853',COVERED W/FILL. 15'30 - 17:00 1.50 CASE P DECOMP POH / RD SLICKLINE 17 00 - 18.00 1.00 RUNCOr ~' COMP PU AND SERVICE ESP PUMP ASSY. 18:00 - 19:00 1.00 RUNCOr~ COMP SAFETY TIMEOUT, REVIEW INFORMATION ON GC2 FATALITY. PJSM W / CENTRILIFT 19:00 - 20:00 1.00 RUNCOI' ~ COMP CONT SERVICE ESP PUMP ASSY. 20:00 - 21:00 1.00 RUNCOr ~ COMP TIH W / ESP, 4 JTS 2 7/8 TBG, GLM / DV, 42 JTS 2 7/8 TBG. 21:00 - 22:00 1.00 RUNCOr ~P COMP RU TO RUN CENTRILIFT HEAT TRACE. 22:00 - 00:00 2.00 RUNCOr ~ COMP TIH W / ESP AND HEAT TRACE ASSY 12/28/2002 00:00 - 06:00 6.00 RUNCOr ~ COMP CONTINUE TIH WITH ESP ASSY AND HEAT TRACE COMPLETION. 06:00 - 10:30 4.50 RUNCOi'~ COMP CREW CHANGE PJSM CONTINUE TIH WITH ESP ASSY AND HEAT TRACE COMPLETION. 10:30 - 11:00 0.50 RUNCOr ~ COMP MAKE UP TBG HANGER AND INSTALL ESP AND HEAT TRACE PENETRATORS. 11:00 - 14:00 3.00 RUNCOr ~ COMP MU UPPER CONNECTOR AND HEAT TRACE SPLICE. 14:00 - 14:30 0.50; RUNCO~ COMP PLUG IN CONNECTOR, SECURE AND TEST. 14:30 - 15:30 1.00 RUNCO~ ~ COMP LAND CAMERON HGR, PUW 43K - SOW 34K, RI / LDS, SET AND TEST TWC 1000 PSI,DRAIN STACK 15:30 - 17.00 1.50 BOPSUFP COMP ND BOPE 17.00- 19:00 2.00 WHSUR P COMP NUTREE 19:00 - 19.30 0.50 WHSUR P COMP TEST TREE 5000PSI, TEST ESP CONNECTION, OK 19:30 - 20:30 1.00 WHSUR P COMP PULL TWC AND SET BPV 20:30 - 21:00 0.50 WHSUR P COMP RD LINES FROM TREE,DRESS TREE, SECURE CELLAR. FESCO RU AND FP TBG W / 15 BBLS DIESEL, IA W / 65 BBLS CRUDE .... RELEASE RIG AT 2100 HRS .... Printed 11212003 1 21 17 PM SCANNED FEB 0 2003 Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 November 2, 1993 Mr. David Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU J-4; REPORT OF SUNDRY WELL OPERATIONS Dear Mr. Johnston, Attached are duplicate copies of the Report of Sundry Well Operations, Form 10-404, for replacing the electrical submersible pump in Milne Point Unit Well J-4, Approval No. 93-257. Please direct any questions or concerns regarding this form to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Att: cc: TdY Chevron Occidental d-4 Well File Gas Cons, (;0mlnissio~'~ /~nc~ora~e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMi,...~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing m Repair well __ Other x Replace ESP 2. 6. Datum elevation (DF or KB) Name of Operator Conoco Inc. Address 3201 C Street, Suite 305 Anchorage, AK 99503 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service 2787' FNL, 3307' FEL, Sec. 28, T13N, RIOE, U.M. NSB AK At top of productive interval 4839' FNL, 649' FEL, Sec. 28, T13N, RIOE, U.M..s.^~) 1 iNAL At effective depth 5136' FNL, 373' FEL, Sec. 28, T13N, RIOE, U.M. NSB AK At total depth KB 70.2 (MSL) 7. Unit or Property name Milne Point Unit feet 8. Well number J-4 9. Permit number/approval number 90-98/' ~7_~ -- 10. APl number 50-029-22073 11. Field/Pool Kuparuk River/Schrader Bluff 12. Present well condition summary Total depth: measured 6320 feet Plugs (measured) true vertical 4570 feet None Effective depth: measured 6208 feet Junk (measured) true vertical 4483 feet None Casing Length Size Structural Conductor 70' 13-3/8" Surface 2878' 9-5/8" Intermediate Production 6264' 7" Uner Perforation Depth: Cemented Measured depth True vertical depth Surface 105' 105' Surface 2913' 2395' TOC @ + 4200' 6299' measured 5524'-5540', 5562'-5610', 5630'-5660', 5735'-5777', 5820'-5853' 4553' true vertical 3946'-3959', 3976'-4014', 4030'-4053', 4113'-4146', 4180'-4206' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE @ 4958'MD Packers and SSSV (type and measured depth) None RE(EiVED N OV ,5 199 13. Stimulation or cement squeeze summary Intervals treated(measured) Not applicable Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 305 400 5 200 Same Tubing Pressure 200 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the forego, lng is true and correct to the best of my knowledge. Signed .jl~,~.~~' B.G. Auqustine Title Sr. ProductionEn,qineer Form 10-404 Rev 06/'15/88/ Date SUBMIT' IN' DUPLICATE MILNE POINT UNIT ,1-4 WORKOVER REPORT DATE: 10/17/93: 10/18/93: 10/19/93: 10/20/93: Description of Operations: Startup rig and associated equipment. Filter brine and heat to 140 degrees. Finish RU rig. Circulate hole with 210 bbls of brine. ND wellhead. NU BOP's. Test BOP's and associated equipment to 300/3000#. POOH with hanger and LD same. Circulate oil off top of brine. POOH. LD ESP pump and motor. Level rig over hole. Fish flatguard out of BOP. PU seal assembly and TIH to 5063', sting into packer. Test backside to 300#, OK. RU slickline. RIH to 5950'; tagged fill. POOH. Retrieved formation sand. RD slickline. POOH with tubing and LD seal assembly. PU and service pump. RIH with tubing and ESP cable. Set up Raychem to RIH. TIH with 77 joints of plain tubing with Raychem and ESP cables. Space out and install hanger and penetrators. Splice ESP cable. Land hanger and set two way check. Test hanger to 5000#. ND BOP and NU tree. Test wellhead/tree. Pull two way check and install BPV. Pump 70 bbls diesel down annulus and 5 bbls down the tubing. Install tree cap and flange on annulus valve. Released rig. & Gas Cons. Comrniss~o~, Anchorage Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 September 20, 1993 Mr. David Johnston Commissioner Alaska Oil 'and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU J-4; APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached are three copies of our Application for Sundry Approval, Form 10-403, for replacing the electrical submersible pump in Milne Point Unit well J-4. Please direct any questions regarding this Application to me at 564-7600. Sincerely, Tom Yeager SHEAR Specialist Attachment CC: BGA, TJY Chevron Occidental J-4 Well File R EE;E!VF, D o STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~,.,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well .... Alter casin'~'- Repair w'~- Plugging __ Time extention Stimulate Change approved program Pull tubing Variance Perforate '~her X Replace ESP Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB)~/~/ 2. Conoco Inc. 3. Address 3201 C Street, Suite 305 Anchorage, AK S9503 Location of well at surface 2787' FNL, 3307' FEL, Sec. 28, T13N, R10E, U.M. At top of productive interval 4839' FNL, 649' FEL, Sec. 28, T13N, R10E, U.M. At effective depth 5136' FNL, 373' FEL, Sec. 28, T13N, R10E, U.M. At total depth NSB AK NSB AK NSB AK Development Exploratory Stratigraphic Service KB 70.2 (MSL) '<.. feet 7. Unit or Property name Milne Point Unit 8. Well number J-4 9. Permit number 10. APl number 50-029-22073 11. Field/Pool Kuparuk River/Schrader Bluff 12. Present well condition summary Total depth: measured 6320 feet Plugs (measured) true vertical 4570 feet None Effective depth: measured 6208 feet Junk (measured) true vertical 4483 feet None Casing Length Size Structural Conductor 70' 13-3/8" Surface 2878' 9-5/8" Intermediate Production 6264' 7" Uner Perforation Depth: Cemented Measured depth True vertical depth Surface 105' 105' Surface 2913' 2395' TOO @ -t-4200' 6299' measured 5524'-5540', 5562'-5610', 5630'-5660', 5735'-5777', 5820'-5853' 4553' true vertical 3946'-3959', 3976'-4014', 4030'-4053', 4113'-4146', 4180'-4206' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE @ 5013'MD Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal,, ,X., Detailed operations program BOP sketch 14. Estimated date for commencing operation October 10, 1993 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ,, X Gas Suspended Service 17. I hereby certify that the fore~loing is true and correct to the best of my knowledge. Signed ~/~.~.~, ~/~L~ B.G. Augustine Title Sr. Production Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 10- · Approved by order of the Commission Origina! S::~ned By David W. Johnston Date 9/20/93 IApproval Approved Copy Returned Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MILNE POINT UNIT J-4: ESP REPLACEMENT SUMMARY PROCEDURE 6 7 8 9 10 11 12 13 14 MIRU on well Kill well ND production tree and NU BOPE and test POOH with tubing, ESP, and cable. Inspect & LD RIH with tubing and seal assembly RU slickline unit, tag fill, and RD slickline unit RU coiled tubing unit RIH with coiled tubing and clean out fill POOH with coiled tubing and RD Circulate wellbore cleanup sweeps POOH with tubing PU ESP assembly and RIH with ESP, cable, and tubing Splice cable, MU landing joint, and land hanger ND BOPE/NU tree and test and freeze protect .,onoco inc. Anchorage Division To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907} 279-1433 [] Under Separate Cover Enclosed _.acord of Shipment of Confidential Information Date From Steve Davies Conoco Inc. 3201 C Street, Suite 200 June 10, 1993 Anchorage, Alaska 99503 (907) 564-7640 Via Petroleum Couriers Subject Quantity Contents E-7 Final Drilling & Completion Report ~-7 Core Analysis Report E-7 Sidewall Descriptions Fl'-2 Final Drilling Report ~i-3 Final Drilling Report ~t~::J~'7~.. Final Drilling Report O~l~-~,'J'-4 Final Drilling Report Final Drilling & Completion Report Final Drilling & Completion Report Final Drilling & Completion Report O~ f j/Ot~/~ Core Description Report Core Analysis Report ~r~~'H-4 Final Drilling Report '1-1 Final Drilling Report ~l-~J I ~'1-2 Final Drilling Report ~1-3 Final Drilling Report -- ~1-3 No Whole Core or Sidewall Cores taken as noted on completion report. ~)1-~ D-~I-4 Final Drilling Report 1 ~..~A Core Analysis Report I ,..jr~-I Final Drilling Report c~o~5;i~-1 Core Analysis Report 1 ~.-1 Core Description Report ~l.~/,r~J-2 Final Drilling Report R E C E IV E D ~'1 --'".~r'J'-2 Completion History dUN '1 *, ~993 ~aska 0il & Gas Cons. Commission Anchorage ¢. Signed By Transmittal Approved By Date Instructions: Please ng second copy. Received By Date Remarks "~June 1 bT'1'99'3 Transmittal Copy Only To Conoco Inc. Anchorage Division Record of Shipment of Confidential Information To · Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed Date From Steve Davies Conoco Inc. Mov 5. 1993 3201 C Street~ Suite 200 Anchorage, AlaSka 99503 (907) 564-7640 ' Via Petroleum Couriers , Subject Milne Point Well Log Magnetic Tapes I-2, I-3~ I-4~ I-4A~ J-l~ J-3~ J-4~ L-7~ L-8~ L-9 Quantity Contents 1 each I-2 Magnetic Tape. ~DIT, APl #50-029-22066, Log Date: 03-NOV-90, Ref #74175. I-3 Magnetic Tape. O.H.EDIT, APl #50-029-22067, Log Date: 12-NOV-90, Ref #74203. I-4 Magnetic Tape. O.H.EDIT, APl #50-029-22068, Log Date: 19-Nov-gO, Ref #74208. I-4~ Magnetic Tape. J-1 Magnetic Tape. J-3 Magnetic Tape. J-4 Magnetic Tape. L-7 Magnetic Tape. L-8 Magnetic Tape. L-9 Magnetic Tape. O.H.EDIT, APl #50-029-22068, Log Date: 29-Nov-90, Ref #74229. Open Hole,APl #50-029-22070, Log Date: .13-Dec-90, Atlas Wireline & LIS listing. O.H.EDIT, APl #50-029-22072, Log Date: 27-Dec-91, Ref #74271 & LIS listing. O.H.EDIT, APl #50-029-22073, Log Date: 03-Jan-91, Ref #74276 & LIS Iisting.~,,¢~ O.H.EDIT, APl #50-029-22028, Log Date: 14-Feb-91, Ref #74350. ¢~0 Open Hole,APl #50-029-22074, Log Date: 17-Apr-91, Ref #74527 & LIS Iisting.¢lO~ll31) O.H.EDIT, APl #50-029-22075, Log Date: 28-Mar-91, Ref #74467. RECEIVED MAY 0 5 199;~ ~Jaska 0il & Gas Cons, C0mmlssl0n Anchorage **LIS listings not availabe for I-2, I-3, I-4, I-4A, L-7 & L-9. Verbal notification provided to H. Oakland. Waiver granted via phone conversation May 5, 1993. (~~.~~ Signed By Transmittal Approved By ~ Date Instructions: Please ackno~'i~'~ge~.~Zt~omptly by signing and returning second copy. Received By Date May 5, 1993 Remarks Transmittal Copy Only To Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 November 9, 1992 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: REPORT OF SUNDRY WELL OPERATIONS Dear Mr. Wondzell, Attached is the Report of Sundry Well Operations, Form 10-404, for the recent replacement of the Electrical Submersible Pump in Milne Point Unit Well J-4. Please direct any questions or concerns regarding this form to me at 564-7660. Sincerely, Tom Yeager "-J SHEAR Specialist Att: cc: CVL, JLA, TJY GDF/FWG, WCD/HDS Chevron Occidental J-4 Well File N0V 1 ~ 1992 Alaska 0il & Gas Cons. C0m~nissio~; Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 8 R REPORT OF SUNDRY WELL OPERATIONS GIN Al. 1. Operations performed: Operation shutdown ~ Stimulate __ Plugging Pull tubing .~X Alter casing __ Repair well __ Perforate __ Other 2. Name of Operator Conoco Inc. 5. Type of Welh Address 3201 "C" Street, Suite 200, Anchorage~ AK 99503 Location of well at surface 2787'FNL, 3307'FEL, Sec 28, T13N, R10E, U.M. NSB, AK At top of productive interval 4839'FNL, 649'FEL, Sec 28, T13N, RIOE, U.M. NSB, AK At effective depth 5136'FNL, 373'FEL, Sec 28, T13N, RIOE, U.M. NSB, AK At total depth Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KB 70,2 (MSL) feet 7. Unit or Property name Milne Point Unit 8. Well number J-4 9. Permit number/approval number 90-98 10. APl number 50-- 029-22073 11. Field/Pool Kuparuk River/Schrader Bluff 12. Present well condition summary Total depth: measured true vertical 6320 feet Plugs (measured) 4570 feet Effective depth: measured 6208 feet Junk (measured) true vertical 4483 feet Casing Length Size Cemented Measured depth Structural Conductor 70 ' 13-3/8" Su r face 105 ' Surface 2878 ' 9-5/8" Surface 2913 ' Intermediate Production 6264 ' 7 ' TOC~ +4200 ' 6299 ' Liner Perforation depth: measured 5524 ' -5540', 5562 ' -5610', 5630' -5660', 5735' -5777 ', 5820' -5853 ~ue ve~icaldepth 105' 2395' 4553' true vertical 3946'-3959' 4113' , 3976'-4014', 4030'-4053', -4146', 4180'-4206' Tubing (size, grade, and measured depth) 2-7/8', 6.5#, L-80, Packers and SSSV (type and measured depth) None 8rdEuE @ 5013' MD RECEIVED NOV 1 1992 13. Stimulation or cement squeeze summary Intervals treated (measured) None Treatment description including volumes used and final pressure None Alaska 0il & Gas Cons. Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-MCf Water-Bbl Casing Pressure 336 ' 229 3 371 252 42 13 350 Tubing Pressure 372 350 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil .~X Gas_ Suspended __ Service 17. I he~th~oing is true and correct to the best of my knowledge. ~ Signed ~¢'~, ~,, I. _(~J~- Title~~ ~C(¢-~/( Form lO-404~Rev06/15/88 (,~ Date(~'-C~-~ ~ SUBMIT IN DUPLICATE Milne Point Unit J-04 API No.: 50-029-22073 Location: Milne Point Field - J-04 Replace Inoperative ESP Current Operations: Warming up EWS Workover Rig #4 in preparation for rig move to the J-4 well to replace Electric Submersible Pump. Moved EWS Workover Rig #4 over the J-4 Well, Killed Well, N/D Tree, Install 2-way Ck Valve, & Begin N/U BOPE. ~0/~7/9Z: Finished N/U & Testing BOPE, POOH & L/D ESP, Install Wear Ring, RIH w/ 1" CS Hydril X 2-7/8" clean out string. Finish RIH w/ cleanout string, Rev Circ out 20' of sand f/5931' to 5951' -- Lost Returns. POOH w/ cleanout string -- bottom 4 jts of 2-7/8" full of sand & bottom jt of 1" plugged w/ sand. RIH w/ locator seal assy and shear out circ sub, test 7" casing and seals, shear sub, perform casing wash and circ out w/ filtered brine. Pump down 7"X9-5/8" casing annulus with 15 bbls diesel while monitoring 7" casing -- 7" casing OK. Pooh & pull wear ring. Load ESP & Rice Wrap Tubing in Pipe Shed & Assemble ESP. RIH w/ 60 jts plain 2-7/8" Tubing, P/U & RIH w/ 83 jts Rice Wrap Tubing, Replace cable spool in spooling shed and make splice. ~O/zo/gz: Finish RIH w/ Rice Wrap Tubing (Total 2-7/8" Tubing: 60 jts. Plain & 96 Jts Rice Wrap). RIH w/ E-Sub, G/L Mandrel, & Hanger -- Splice pigtail to cable, plug into penetrator, and test. Fish heated cable thru annulus valve, land hanger, B/O landing jt., install 2-way ck valve, lockdown hanger. Install electrical feed for heated tubing thru the annulus valve and test hanger seals. N/D BOPE & N/U Tree. Test Tree and hanger seals to 5000 psig. Pull 2-way ck valve and install BPV. Freeze Protect 2-7/8" Tubing, 2-7/8" x 7" annulus, and 7" x 9-5/8" annulus valve with 5, 20, and 60 bbls diesel, respectively. Note: No Dummy in GLM. Move Rig to I-4A well. Alaska Oil & Gas Cons. Commissio~ Anchorage NOTES: 9. ALL DEPTHS MEASURED RKB = 54' KDB-SL = 52' KDB-GL = 55' MAX. ANGLE = 61' @ 4210' K.O.P. = 500' SLANT HOLE: YES TREE TYPE: WKM 2 9/16", 5000# W/ 2 7/8" 8rd TREETOP CONNECTION MIN ID = 1.791" @ 5697' COMPLETION FLUID: 8.6 PPG NaC1 W/ 14% METHANOL STIMULATION: FRAC (5755'-5855') PUMPED 55,800# OF 16/20 MESH CARBO-LITE ESP ASSEMBLY: REDA DN-610 PUMP W/ 177 STAGES W/ AR, 75HP, 1100V/41.5A MOTOR, STANDARD INTAKE, TANDEM BSLSL PROTECTOR, PSI UNIT WELL No. J-4 COMPLETION SKETCH MILNE POINT UNIT (P) APl No.: 50-029-22073 PERMIT No.' 90-98 COMPLETED: 4/7/91 LAST WORKOVER: 10/19/92 --.,---- WKM TBS HANGER W/ 'H' PROFILE BPV ~ 56' 2 7/8" 6.5# L-80 8rd EUE PUP JOINT (4') 59' 2 7/8" 6.5# L-80 8rd EUE PUP JOINT (6') 45' 2 7/8" x 1" MACCO G/L MANDREL W/ 5/16" ORFICE (T) 52' 2 7/8" 6.5# L-80 8rd EUE PUP JOINT (2') 54' PTI E-SUB W/ PUPS ON BOTH ENDS BOTTOM END WRAPPED W/ E-SUB (11.00') 65' TOP OF RICE TUBINO 96 JTS. 2 7/8" 6.5# L-80 8rd EUE TUBINO EXTERNALLY COATED W/ RICEWRAP lOOmils (3012') .3078' PTI CONTACTOR --56 JTS. 2 7/8" 6.5# L-80 8rd EUE TUBING (1768') 4845' 2 7/8" 6.5# L-80 8rd EUE TUBING (6') 4851' 2 7/8" x 1.5" MACCO C/L MANDREL W/ DUMMY (8') 2 JTS. 2 7/8" 6.5# L-80 8rd EUE TUBINO (63') 4860' 2 7/8" 6.5# L-80 8rd EUE PUP JOINT (2') 4925' 2 7/8" CHECK VALVE (1') 4826' TOP OF TUBINO 2 JTS. 2 7/8" 6.5# b-80 8rd EUE TUBING (63') 4989' 2 7/8" 6.5# L-80 8rd EUE PUP JOINT ($') RECEIVED 4991' TOP OF ESP ESP CABLE-No. 2 REDA BLACK NOV 1 5 1992 Alaska Oil & Gas Cons. Commissim~ Anchorage N SAND PERFORATION DATA ME) TVD DEPTH: 5524'-5540' 5946'-5959' 5562'-561 O' 5976'- 4014' 5650'-5660' 4050'-4055' DENSITY: 12 SPF, 24 OM 0 SAND PERFORATION DATA MD TV[) DEPTH: 5755'-577T 4115'-4146' 5820'-5853' 4t80'-4206' DENSITY: 5 SPF, 57 GM 7" CASING @ 6299' 5041' BOTTOM OF ESP 5065' OTIS "VST" VERSA-TRIEVE PACKER (3.25" ID) 5089' H-S, 2 7/8" BLANK PIPE (432') 5521' H-S, 2 7/8", 12 ge. SCREEN (145', 2.44" ID) GRAVEL PACK (N-SANDS) 20/40 MESH GRAVEL 5666' 5667' 5680' ~-5697' 5698' 6002' 6208' O-RING SEAL SUB (2.0" ID) H-S, 2 7/8", 12 ga TELL-TALE SCREEN (11', 2.44" ID) OTIS "AWD" PACKER (4.0" ID) OTIS "XN" NIPPLE (1.791" ID) OTIS RE-ENTRY GUIDE (1.97" ID) FRAC SAND FILL PBTD ~CO~'IOCO~ CONOCO INC. ANCHORAOE DIVISION IAPPROVED BY: BOA DRAFTED BY: CFP DATE: 10/22/92 CAD FILE: WCOJ4 3201 C Street, Suite 200 March 27, 1992 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3oo1 Porcupine Dr. Anchorage, Alaska 99501 Dear Blair Wondzell, Please find attached the casing and cementing reports for J-2 and several other Schrader Bluff wells. Unfortunately, the foreman that completed the form did not indicate that there were full returns during the c~ment job. However, I contacted the foreman, Joe Polya, that did the cement job and he informed me that it was an oversight on his part. We have never had a problem with loss circulation on the 7" jobs on Schrader Bluff wells primarily due to the fact that we do not bring cement high enough in the wells to exceed the fracture gradient. Additionally, I contacted the foreman opposite Mr. Polya and he confirmed that loss returns or] t/tis casing string in tho Schrader Bluff wells is not a problem, I have attached other casing/cementing reports from Schrader Bluff wells to provide you with additional support. Allow me to apologize for the delay in providing you with this infon'nation and if there is anything I can do in the future do not hesitate to call (564-7~). Best Regards, Steve Bolt Division Drilling Superintendent RECEIVED MAR 2 ? ]992 Alaska Uil & Gas Cons. Commission Anchorage FROI',I COhlOCO i:::IhlCI.-tOP, i~QI~ TO Top of '~"~ ~--7].~Z ' Bo~tO~ Plug', ~, No) Top Plug: ~, No) B~ped Top ~ ~ OhS Commis _ _ I~lttil gt~tng ~cighr;~(l.b~) ~ina! L~udtng i~elght 1,~~' ___(I~8) ~a~ //~ ........ ~"na~i,~t ~~./,~. . .. ........ [/f~ .................... I STATE OF ALASKA ALAb,., OIL AND GAS CONSERVATION COMMI~,~ION APPLICATION FOR SUNDRY APPROVALS OR IG 1, Type of Request: Abandon Suspend Alter casing __ Repair well Change approved program Operation shutdown . Re-enter suspended well m Plugging __ Time extention __ Stimulate __ Pull tubing , .X. Variance Perforate Other ... Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 5, Type of Well: Development X,L~ Exploratory __ Stratigraphic ~ Service 6, Datum elevation (DF or KB) KB 70.2 (MSL) 7, Unit or Property name Milne Point Unit Location of well at surface 2787' FNL, 3307' FEL, Sec. 28, T13N, R10E, U.M. NSB AK At top of productive interval 4839' FNL, 649' FEL, Sec. 28, T13N, R10E, U.M. NSB AK At effective depth 5136' FNL, 373' FEL, Sec. 28, T13N, R10E, U.M. NSB AK At total depth 11. 8, Well number J-4 9, Permit number 90 -98 10. APl number 5O-029-22073 Field/Pool Kuparuk River/Schrader Bluff feet 12, Present well condition summary Total depth: measured true vertical 6320' feet Plugs (measured) 4570' feet None Effective depth: measured true vertical 6208' feet Junk (measured) 4483' feet None Casing Length Size Structural Conductor 70' 13-3/8" Surface 2878' 9-5/8" Intermediate Production 6264' 7" Liner Perforation Depth: Cemented Measured depth True vertical depth Surface 105' 105' Surface 2913' 2395' TOC @ ± 4200' 6299' measured 5524'-5540', 5562'-5610', 5630'-5660', 5735'-5777', 5820'-5853' true vertical 3946'-3959', 3976'-4014', 4030'-4053', 4113'-4146', 4180'-4206' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8ra EUE @ 5013'MD Packers and SSSV (type and measured depth) None 4553' RECEIVED Alaska Oil & Gas Cons. Commies ~;, Anchorage 13, Attachments Description summary of proposal X Detailed operations program ~ BOP sketch . 14, Estimated date for commencing operation April 1, 1992 16. If proposal was verbally approved Name of approver Date approved 15, Status of well classification as: Oil X Gas Suspended Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge, ~.~~-~B. G. Augustine Title Sr. Production Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test .... Su---bsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 Commissioner ....... Date o~' ~©" ~ ~; SUBMIT IN TRIPLICATE ~ I~'rLNE PO'tNT UNiT REPLACE 'rNOPER~T'rVE ESP SU~Y PROCEDURE 1. MIRU workover rig. 2. Kill well with 8.6 ppg NaC1. ND production tree. NU BOPE and test. 3. POOH with tubing, ESP, and ESP cable. LD ESP and cable. 4. RU slickline unit and RIH with 6" gauge ring to 3000'. RD slickline unit. 5. RIH with retrievable bridge plug and set at 2350'. Pressure test casing to 1500 psi for 30 minutes. Retrieve BP and POOH. 6. RIH with seal assembly on 2-7/8" tubing and sting into gravel pack packer at 5063'. Pressure test annulus to 500 psi. 7. RU slickline unit and RIH with wireline tools. Tag fill. 8. POOH with wireline tools and RD unit. 9. RU coiled tubing unit. RIH with coiled tubing and circulate out fill to PBTD. 10. POOH with coiled tubing and RD coiled tubing unit. 11. POOH with 2-7/8" tubing and seal assembly. 12. PU new ESP, motor, and cable. RIH with ESP assembly and tubing. Set bottom of pump at 4720'. 13. ND BOPE and NU production tree. RDMO rig. 14. Return well to production. RECEIVED FEB 1 Alaska 0il & 6as Cons. Cornrnissio~ Anchorage Alaska Oil Gas Conservation Commission 3001 Porcupine Drive AnchorRge. Ala:~ka gfl501-:3'! §2 901-219-1433 To:CONOCO l:le: C-gl, Receipt of the following material which was transmitted via REGULAR MAIL from Halliburton Logging Services, loc with out a transmittal and to the ATI-ENTION of JOHN BOYLE, THESE LOGS SHOULD BE ACCOMPANIED WITH A TFLANSMI~TAL !~.NI') MAll Frl TO THE A.~-. ENT!ON OF LAR.RX G!:IAHT, however data is hereby acknowledged: 1 b!ue!ine and sepia I LI..--I~ .... J um~.,,~ a.m .~epia Perforation record MPU C-01 Dated: DEC 2 3 1991 Copy sent to sender: Yes ~~ Alaska 011 & Gas Cons. Commlssio' Anchorage STATE OF ALASKA --' 0 R 16 1 N A~ AI_ASKA ,L AND GAS CONSERVATION C .,'iMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~r 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number CONOCO ]:NC. 90-98 3. Address POUCH 340045, Prudhoe Bay, Alaska 99734 4. Location of well at surface 2787' FNL, 3307' FEL, SEC. 28, T13N, R10E U.M., NSB, Alaska 8. APl Number 5o~29-22073 9. Unit or Lease Name Milne Point Unit At Top Producing Interval ~ ¢'~1~,i ~r:-rm~ ti '- ~'' ' ..... ~ 10. Well Number 4630' FNL, 890' FEL, SEC. 28, T13N, R10E At Total Depth -~ ~O ¢ ' ......... ~ .,'~ i:~,FiED_~.~ :, ~__~ 11. Field and Pool 4986' F~L, -~,' ~gL, SgC. 28, 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation ~Q~~'.'. 't'-T,t:27~J Kuparuk River Fie]:d 34 ' ~ ADL-25906 12. Date Spudded ~ 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~ 15. Water Depth, if offshore 16. No. of Completions 12/29/90 + VD ~ 1/3/91 4/7/91 ) ~/A feet MSL 2 l~.Total Depth (MD T )118. Plug Back Depth (M~D) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 6320'~/4585'TV~ 6208'~/4493'TVD YES ~ NO D NONE feetMD ~ 1800' 22. Type Electric or Other Logs Run DIL, LDT, CNL, NGT, AMS F/6101' - 2914' 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 13-3/8" 9-5/8" ' 7" WT. PER FT. 48¢~ 36# 26¢~ GRADE H-40 K-55 L-80 SETTING DEPTH MD TOP BOTTOM 35' 115' 35' 2913' 35' 6299' HOLE SIZE 30" 12-1/4" CEMENTING RECORD 485 SKS PermaFrost 1100 SKS PermaFrost~ AMOUNT PULLED 8-1/2" 405 SKS Class "G" - 25. 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 'N' Sand - 5 SPF, 37GM 5524-5540 MD, 3957'-3970' TVD 5560-5610 MD, 3987'-4025' TVD 5630-5660 MD, 4041'-4065' TVD '0' Sand - 12 SPF,;27GM 5735-5777 MD, 4125-4158' TVD 5820-5853 MD, 4192-4218' TVD 27. Date First Production Not Tested Hours Tested Date of Test SIZE 2-7/8", 6.4# 26. TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 5013 ' NONE ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) 5735 - 5777 5820 - 5853 PRODUCTION TEST Flow Tubing Casing Pressure Press. 28. CORE DATA IAMOUNT& KIND OF MATERIALUSED Frac w/100 BBL Pre-Pad~260BBL Pa.d, 204BBL Prop Slurry (51,600#'s Carbo-LJ. te ~ro IMethod of Operation (Flowing, gas lift, etc.) CALCULATED I~ I OIL-BBL GAS-MCF 24-HOUR RATE WATER-BBL WATER-BBL ICHOKESIZE GAS-OIL RATIO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED JUN 1 91991 Aiaslm Oil & 8as Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE' Submit in duplicate GEOLOGIC MARKERS NAME Top of "N" San~ Top of "0" Sand 30. F ATION TESTS MEAS. DEPTH TRUE VERT. DEPTH 5524' 5735' 3957' 4125' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NONE 31. LIST OF ATTACHMENTS Plat, Gyro Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Sr. Prod. Foreman Date 4-29-91 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location 'of the cementing tool. . Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, ShUt-in/Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 APR PROPOSED MON J-2 SOUTH Y 6,014,507.26 X 551,8t~4,,66 N 820.00 E 850.00 PROPOSED MON J--I NOR'iH Y $,015,313.25 X ,551,531,63 N I700.00 850.00 Pi ~6 Ym 6,014.,B4.2.6:~ X= 552,201,70 AS-BUILT WELL DATA BELL ~'OL Y~ 6,014,64.1.12 CONOCO NOTES: 1, 2. PRGE. 00£ MILNE PT, VICINITY MAP MILES STATE PLANE OOORDINA'lq:'_.S ARE ZONE ALL GEOOETIC POSITIONS ARE BASES) ON N.A.D. lg27, OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSIllONS. LEGEND EXqST1Ng WElL PROPOSED WELL LOCATED WITHIN SECTION 28 T. 13 N., R. 10 E.., UMIAT MERIDIAN, ALASKA PLANT A.S,P. ZONE 4. COORDS COORDS · -- LATITUDE LONGITUDE SEC. LINE OFFSETS N 1300.07 Y 6,01§,055,19 70' 27' 06,74.2' 2622' FNL J-1 E 1119.80 X ,5§1,939.18 14.9' ,34' 34..364" 3.378' FEL N 1239.64- Y 6.015.000.11 70' 27' 06.199" 2677' FNL J.-2 E 1120,47 X 551,g64,.03 14,9' ,.'34' 33.64,6' 3354' FEL N 1179. B1 Y 6,014,94.5.05 70' 27' 05.656' 273;3' FNL J-3 E 1119.81 X 551,987.4,3 149' 34' 32.9?0" 3331' FEL N 1119.59 Y 6,014,889.82 70' 27' 05.111' 2788' FNL J-4 E 1119.62 X 552,011.4-2 14-9' 34' 32.276" $307" FEL i ,1 mai SURVEYOR'S CERTIFICATE · ,, Ill [ HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY DIR--.., EOT SUPERVISION,AND THAT ALL DIMENSIONS AND .' OTHER DETAILS ARE CORRECT, .......... - . SURVEYED FOR: ...... (conoco) DRAWN: STOLL CH¢CK~: H~n~N~ AS-BUlL T ~/£t_L CONDUCTORS J0B NO.; 900~9 iiii II . i Milne Point -J No. 4 COMPLETION HISTORY -. Kuparuk River - SBP - North Slope Borough, Alaska W.I. 1.0 Milne Point J No. 4 CONFIDENTIAL AFE 10-61-1254 Location: 2787' FNL, 3307' FEL, Sec 28, T13N, R10E, U.M., NSB AK Location: Bottom hole, 4986' FNL, "424' FEL, Sec 28, T13N, R10E Objective: 5955' MD - Schrader Bluff Pool 03/30/91: Move Ewe rig from E Pad to J-4. R/U on location. @ 0600 hours 03/30/91 all compartments in place. Preparing to lift derrick. 03/31/91: R/U new modules/equipment. N/D tree. N/U BOPs. Take on 300 bbls HzO into new pit system. Begin function testing pumps., equip. Function test accumulator system. Prepare to test BOP's. 04/01/91: Continue R/U, ~esting new equipment, lines etc. Much of time spent getting bugs out of new system. RIH w/ 1 jt 2-7/8" tbg & screw into tbg hgr. Pull tbg hgr. Hgr got stuck in bottom of bell nipple. S/O. to get free. Attempt again. Could not get thru. N/D bell nipple. Found top metal & top "O" ring hung inside bell nipple. Fish out other "O" ring & metal ring. GIH w/ 2-7/8" jt & retrieve hgr. RIH w/ test plug. Begin testing BOPs. 04/02/91: Finish testing BOPs. P/U bridge plug retrieving tool & RIH. Hit ice plug @ ± 378'..Could not work through. POOH. P/U 6" bit & 1 DC. Work on pick-up machine. TIH. Tag ice. @ 280'. Work pipe thru ice to ± 380'./ Rig up rotary swivel. 04/03/91: R/U power swivel. Drill on ice. Made = 8 in. in 1 hr. Stand pipe iced up. Thaw out. Prepare to circ. R/U lines to 400 bbl-trash tank. Line out mudpits. Hydraulic drive motor to mud pump not working, change out motors. Attempt to circ down DP. Bit plugged w/ ice. Could not circ. L/D power swivel. POOH. Blow ice out of bit, bottom 4 DCa. R/U power swiVel. TIH w/ bit, 4 DCa, DP. Begin tagging ice at = 280'. Drill & circ ice to 390'. Broke through ice. L/D power swivel. P/U 30. jts DP & TIH to ± 1000'. No obstructions. POOH w/ bit. P/U packer overshot. TIH'~ . 04/04/91: TIH w/ Packer overshot. Tag bridge plug @ 4967'. Rev circ 20 bbls filtered brine. Unseat bridge plug. POOH w/ bridge plug laying down drill pipe. P/U 12 jts 1-1/4" cs pipe~w/ mule shoe & TIH, 04/05/91: Finish P/U 1-1/4" BHA. P/U 2-7/8" tbg, strap, RIH. RIH to '~ ±--5063' (top of gravel Pack packer). Pump 10 bbl Hi Vis pill into annulus. Sting into- gravel pack PKR w/ 1-1/4" string " whil-e circulating. TIH. Tag bridge~at 5640'. R/U to'~circ~~ Rev circ thru bridge. ~ Broke thru_bridge after 2-3'. Lost ~almost total returns after ~ridge.~~~L~ rev long waY. Still losing returns' RIH pumping~s~wI ga~43(1/2 bbl/min).. JUN 1 9199! A!ask, a Oil & Sas Cons. Commission Anchorage Milne Point J No. Completion HistOry Page 2 Tag bottom @ 5686' (8' deeper than disc). P/U & slack off weight on bottom several times to break disc (assuming that we were on disc). Could not break thru obstruction. Note: Assumption was that disc was broken & that we were against no-go in BHA. ~POOH w/ wet string. Strap out of hole. 04/06/91: Finish POOH w/ 1-1/4" stinger. Change mule shoe jts. TIH to verify glass disc broken. .TIH to ± 5000'. Circ @ 5063'. TIH and tag fill @ 5645'. R/U to circ. Wash down 1 jt to 5668'. Pump 10 bbl Hi Vis pill. Pump pill into annulus, above GP PKR. Make connection. RIH & tag @ 5685'. Could.not pump thru. P/U & set weight down - broke thru disc. TIH to 5705' to verify no-go. Make 5 std short trip. No fill. POOH. L/D 1-1/4" string~ 04/07/91: P/U & M/U REDA pump. Service pump. Make electrical checks - OK. Connect cable, M/U flatguards. RIH w/ pump on 2-7/8" tbg. Secure cable to pipe w/ 2 bands per jt. M/U HGR, install penetrator. Splice cable to pigtail. Land HGR. M/U hold down pins. N/D BOPs. N/U tree. Test tree to 3000 psi. Pump 65 bbls diesel down 7" x 2-7./8" & 12 bbls diesel down 2- 7/8". 04/08/91: Set BPV in tree. R/D rig, prepare to move. Clean mud~"pits. Begin rig move to J-1. Rig released @ 1100 hrs on 04/08/91. . OPERATOR: CONOCO WELL: MPU J-4 PTD: 5955 MD CASING: 13-3/8" @ 110 9 5/8" @ 2916 7" @ 6299 CURRENT TD: 6320 PROGRESS: 0 DATE: 12-30-90: 12-31-90: 01-01-91: 01-02-91: 01-03-91: 01-04-91: 01-05-91: 01-06-91: 01-07-91: 01-08-91: Description of Operations: Move in & Rig Up. PU rig @ 0900 hrs 12-29-90. NU diverter. Mix mud. MU 12 1/4" BHA. Drill 110 to 782. Drill 782 to 1507. Short trip. Drill to 2422. Ream out dogleg. Drill to 2877. Drill 2877 to 2950. Circ. POOH. Tight f/2650 to 2950. RIH. Circ. POOH to 2650. Hole tight. RIH. C & C. POOH, LD BHA. Run 4 arm caliper on E/L. Run 73 jts, 9 5/8" csg, 36#, 1(-55, Butt. Circ & recip. Cmt w/389 BBI 12.1 PPG Permafrost E cmt & 72 BBI 15.8 PPG G cmt. Displace w/mud. Land csg in WH. FS @ 2916. FC @ 2829. Got 110 BBL cmt returns. Started loosing circ. Did not bump plug. ND diverter. MU Speed Head. NU BOP. Test BOP. MU 8 1/2" BHA. RIH. Drill cmt f/2663 to 2829. Test csg to 1500 psi. Drill float equip & cmt to 2913. Drill 10' new hole f/2950 to 2960. Run leakoff test to 15.7 PPG EMW. Drill to 4540. Short trip. Fin short trip. Drill 4540 to 5521. Short trip. Drill to 6000. Circ. Short trip. Hole tight f/4050 to 4520. Drill to 6100. C & C. POOH. RU E/L. Run DIL-LDT-CNL-NGT-AMS. RIH w/bit. Drill f/6100 to 6320. C & C. POOH. LD DP & BHA. RU to run 7" csg. Run 146 jts 7", 26#, L-80, BUTT Csg. FS @ 6299. FC @ 6215. Circ. Cmt w/83 BBL G cmt. Disp w/brine. Recip pipe during cmt job. Land csg. Bump plug. Test csg to 1500 psi. Run & test packoff. Change rams to 3 1/2". Test BOP's. MU bit & csg scrapers. RIH, picking up 3 1/2" DP. Fin RIH w/ csg scrapers. Circ Dirt Magnet pill around. Circ & filter brine. RU E/L. Perforate f/5853 to 5820 & f/5777 to 5735 w/5 SPF. RIH w/PKR on DP. Fin RIH wi PKR. RU Frac tanks. Heat water. RU frac equip. Pkr @ 5542'. Fin RU Frac Equip. Frac well w/569 BBL Fluid and 55,800 # 16/20 Carbolite @ 25 BPM. Max press 6700 psi. Avg press 5300 psi. ISlP 950 psi. 395 psi after 15 min. Wait on gels to break. RU w/I. RIH to tag fill. 01-09-91: 01-11-91: 01-12-91: 01-13-91: 01-14-91: 01-15-91: 01-16-91: 01-17-91: Tag fill @ 4465. Att to reverse out. DP plugged w/sand. POOH 3 stds. Reverse out sand & diesel. POOH. RIH w/bailer on DP. Tag sand @ 5511. Bail sand f/5511 to 5695. POOH.Dump bailer. 01-10-91: Test BOP's. RIH w/bailer on DP. Bail sand f/ 5562 to 5712. POOH. Dump sand. RIH w/bailer. Bail sand f/5712 to 5857. POOH. Dump sand. RIH w/bailer. Bail sand f/5857 to 6002. POOH. Dump sand. RU E/L. Run gauge ring to 5700'. Run sump pkr on E/L & set at 5680'. MU 4 1/2" perf guns & pkr. RIH w/same on DP. Space out and locate in sump pkr. Pump 36 BBL diesel down DP for 300 psi underbalance. Set pkr. RU & test lines. Drop bar. Guns did not fire. Wait on W/L unit. RIH w/WL. Tag Drop Bar @ 2850'. Knock bar down to 4800'. Bar dropped to 5467' & fired guns. POOH w/WL. DPP 105psi. Flow well 11 BBL in 1 hr. Shut in w/105 psi. Shear APR-M valve and reverse out. Circ and filter fluid. Unseat pkr. Sting into seal bore asssy of sump pkr OK. POOH w/perf assy. RIH w/gravel pack assy. Set pkr. WOE. WOE. RU surface equip for gravel pack. Pump prepack. Disp same. Reverse out. Pump gravel pack (25 BBL sand slurry). Sand out w/1800 psi. Rev out. Rec 8 BBL sand slurry. Test pack to 1500 psi. POOH w/gravel pack c/o tools. RU W/L. RIH to break glass disc @ 5678'. Tag sand at 5555' WLM. POOH. RIH w/bailer on w/l. POOH. Rec 1' sand and perf debris. Run magnet on w/I. Rec perf debris. Run bailer on w/I. RIH with slickline to 5598', attempted to bail sand with no success. PU 1.25" CS HYDRIL & XO to 3-1/2" DP and RIH to 5633' and ,washed to 5678' circulated 180 bbl. pill. POOH and L/D 3.5" DP & 1.25" slotted junk basket. RU Schlumberger & RIH with gravel pack evaluation log. Hit bridge at 5642. Unable to log boottom interval due to sand on top of rupture disc. R/D Schlumberger and R/U slickline. RIH with bailer to 5630' and attempted to bail. No success. POOH with slickine. RIH and set Halliburton Model 3L bridge plug at 4990' and tested to 2,000 psig. POOH laying down drill pipe. Displaced pipe volume with 29 bbls. diesel to freeze protect. Changed top set of pipe rams from 3.5" to 5". R/D BOPs and N/U tree. Test tree to 5,000 psig. Released rig @ 2400 hours. RIG RECEIVED: 12-29-90 SPUD DATE: 12-29-90 RIG: NABORS 27 DAYS: 19 / 21 FOREMAN: POLYA DATE: 01-17-91 SUB. SURFACE DIRECTIONAL ~URVEY r'~UIDANCE [~ONTINUOUS I-~IOOL RECEIVED ~:~ iaska Uu & Gas Cons. Commission Anchorage Company Well Name FleldlLocatlon CONOCO, INC. MPU J-4 (2787' FNL,3307' FEL,SEC 28, T13N, RIOE),. SCHRADER BLUFF, NORTH SLOPEr ALASKA Jot) Reference No. 74275 Logaed B~. BARNARD/FORMICA Date 5-JAN-91 Computed By:. KRUWELL * SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR CONOCO, INC. MILNE POINT UNIT J-4 SCHRADER BLUFF NORTH SLOPE, ALASKA SURVEY DATE: 05-JAN-1991 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- LINEAR HORIZ. DIST. ENGINEER: JEFF FORMICA Averaged deviation and azimuth PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 51 DEG 24 MIN EAST CONOCO. INC. MILNE POINT UNIT J-4 SCHRADER BLUFF NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 100.00 200.00 300 O0 400 O0 500 O0 600 O0 700 O0 80O O0 900 O0 0 O0 99 199 299 399 499 599 699 798 897 COMPUTATION DATE: 17-JAN-91 PAGE 1 DATE OF SURVEY: 05-JAN-1991 KELLY BUSHING ELEVATION: 70.20 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED .DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN -7O 20 95 29 75 95 129 75 95 229 75 95 329 75 94 429 87 529 42 629 54 728 t8 826 0 0 N 0 0 E 0.00 0 5 N 59 29 E 0.12 0 8 N 34 32 E 0.11 0 9 S 77 14 E 0.13 0 26 N 60 31 E 0.49 74 0 54 N 83 38 E 0.93 67 3 45 S 76 24 E 3,78 22 6 32 S 72 9 E 12.56 34 8 33 S 70 16 E 24.93 98 10 35 S 69 8 E 40,53 S 65 54 E 60.21 S 64 27 E 84.86 S 62 2 E 114,30 S 60 33 E 150,91 S 60 27 E 196,27 S 59 8 E 244,70 S 59 21 E 294,89 S 59 8 E 350,14 S 58 32 E 411,83 S 58 6 E 475,94 1000.00 1100.00 1091.76 1021 1200.00 1187.11 1116 1300.00 1279.93 1209 1400 O0 1368.69 1298 1500 O0 1455.88 1385 1600 O0 1542.07 1471 1700 O0 1625,06 1554 1800 O0 1703,33 1633 1900 O0 1779.67 1709 995.04 924 84 13 20 56 16 B 91 19 13 73 24 12 49 29 44 68 28 41 87 32 41 86 35 57 13 39 49 47 40 33 2000 O0 1853.49 1783 29 44 24 S 57 14 E 542.95 58 45 48 S 56 4 E 613,78 16 49 2 S 55 35 E 686.33 99 53 3 S 54 46 E 763,92 05 56 17 S 54 18 E 845,91 84 55 44 S 53 54 E 928.80 89 56 31 S 53 37 E 1011.55 21 57 10 S 53 16 E 1095,45 74 57 4 S 53 9 E 1179.24 26 56 31 S 52 40 E 1263,04 2100 2200 2300 2400 2500 2600 2700 2800 2900 S 52 35 E 1345.84 S 51 59 E 1427,47 S 51 23 E 1508,18 S 50 55 E 1590.44 S 50 44 E 1675.81 S 50 27 E 1761.90 S 50 0 E 1846,85 S 49 52 E 1931,23 S 49 55 E 2016,24 S 49 48 E 2103,23 O0 1923.78 1853 O0 1992.36 1922 O0 2055.19 1984 O0 2112.25 2042 O0 2168.04 2097 O0 2224.09 2153 O0 2278.41 2208 O0 2332.94 2262 O0 2387.46 2317 3000.00 2443.49 2373.29 55 26 3100.00 2501.24 2431.04 53 49 3200.00 2560.28 2490.08 54 16 3300.00 2617.11 2546.91 56 58 3400.00 2669.16 2598.96 59 42 3500.00 2720.03 2649:83 58 56 3600.00 2772.74 2702.54 57 39 3700.00 2826.37 2756.17 57 29 3800,00 2878,98 2808.78 59 40 3900,00 2928,23 2858,03 60 35 0 O0 0 09 0 O0 0 54 0 38 1 63 5 O5 2 14 1 82 2 58 3.18 2,60 5,19 5,50 1 ,30 1 .13 4,49 8.04 1 ,36 1 ,81 2,73 0.53 6,90 6,18 0,48 0,67 2,53 0.82 0.50 1 .36 0.99 2.05 1 .02 4.14 0.85 1 .60 0.62 0.48 3.64 I .11 0,00 N 0 07 S 0 08 N 0 19 N 0 26 N 0 59 N 0 28 N 2 45 S 671 S 1237 S 0 O0 E 0 10 E 0 20 E 0 32 E 0 84 E 1 66 E 5 06 E 14 12 E 26 55 E 41 99 E 0 O0 N 0 0 E 0 0 0 0 1 5 14 27 43 12 S 54 45 E 22 N 69 25 E 37 N 58 56 E 87 N 72 56 E 76 N 70 23 E 07 N 86 52 E 33 S 80 10 E 39 S 75 49 E 77 S 73 35 E 20 19 S 30 44 62 84 109 135 164 196 230 88 S 83.93 E 89 41 S 110.79 E 119 43 S 143.26 E 156 99 S 183,29 E 202 62 S 225.61 E 250 56 S 269,11 E 301 10 S 317,02 E 356 32 S 370,24 E 419 20 S 425.23 E 483 60.92 E 64 18 S 71 40 E 43 S 69 48 E 36 S 68 9 E 27 S 66 27 E 03 S 65 7 E 83 S 64 5 E 33 S 63 16 E 98 S 62 38 E 07 S 62 4 E 54 S 61 34 E 266 21 S 482.22 E 550 82 S 61 6 E 305 346 39O 438 487 536 586 636 686 40 S 541.57 E 621 74 S 60 35 E 28 S 601.76 E 694 28 S 60 5 E 71 S 665.59 E 771 79 S 59 35 E 38 S 732.43 E 853 60 S 59 6 E 06 S 799.65 E 936 30 S 58 39 E 04 S 866.42 E 1018 83 S 58 15 E 04 S 933,86 E 1102.52 S 57 53 E 25 S 1000,99 E 1186.09 S 57 34 E 81 S 1067,86 E 1269,66 S 57 15 E 737 09 S 1133.67 E 1352 23 S 56 58 E 786 99 S 1198.29 E 1433 837 07 S 1261.57 E 1514 888 75 S 1325.58 E 1595 942 67 S 1391 78 E 1680 997 34 S 1458 28 E 1766 1051 70 S 1523 60 E 1851 1106 06 S 1588 17 E 1935 1160,86 S 1653 18 E 2020 1216,94 S 1719 73 E 2106 61 S 56 42 E 02 S 56 26 E 95 S 56 10 E 97 S 55 53 E 71 S 55 38 E 33 S 55 23 E 37 S 55 9 E 06 S 54 55 E 76 S 54 43 E COMPUTATION DATE: 17-JAN-91 PAGE 2 CONOCO, INC. MILNE POINT UNIT J-4 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 05-JAN-1991 KELLY BUSHING ELEVATION: 70.20 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF laEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 2977.59 2907 39 60 24 4100 O0 3026.70 2956 4200 4300 4400 4500 4600 4700 4800 4900 O0 3075.38 3005 O0 3123.26 3053 O0 3171.02 3100 O0 3222.03 3151 O0 3278.70 3208 O0 3338.36 3268 O0 3401.52 3331 O0 3468.62 3398 50 6O 42 18 61 10 06 61 27 82 61 10 83 57 1 5O 54 31 16 51 59 32 49 17 42 46 36 S 49 35 E 2190 16 S 49 33 E 2277 S 49 31 E 2364 S 49 13 E 2452 S 49 8 E 2540 S 49 3 E 2625 S 48 51 E 2708 S 48 40 E 2788 S 48 44 E 2865 S 48 33 E 2939 22 53 27 O6 96 27 42 85 9O 0 33 0 10 0 98 0 40 2 12 4 88 0 61 1 61 3 93 3 78 1273 26 S 1786.00 E 2193 40 S 54 31 E 1329 1386 1443 1501 1557 1611 1664 1715 1764 76 S 1852 30 E 2280 46 S 1918 6O S 1985 08 S 2051 39 S 2116 47 S 2178 41 S 2239 62 S 2297 57 S 2353 75 E 2367 41 E 2454 85 E 2542 82 E 2628 96 E 2710 26 E 2790 46 E 2867 13 E 2941 20 S 54 20 E 25 S 54 9 E 76 S 53 59 E 31 S 53 49 E O0 S 53 39 E 11 S 53 31 E 08 S 53 23 E 34 S 53 15 E 25 S 53 8 E 5000.00 3539.67 3469 47 43 2 5100.00 3614.81 3544 5200.00 3691.78 362t 5300 O0 3769.24 3699 5400 O0 3847.76 3777 5500 O0 3926.91 3856 5600 O0 4006.04 3935 5700 O0 4085.05 4014 5800 O0 4163.86 4093 5900 O0 4242.67 4172 S 47 42 E 3010 13 61 40 1 S 47 42 E 3075 58 39 27 S 47 18 E 3139 04 38 48 S 46 32 E 3202 56 37 57 S 45 13 E 3264 71 37 33 S 44 28 E 3325 84 37 46 S 43 48 E 3385 85 37 53 S 43 15 E 3446 66 38 3 S 42 51 E 3507 47 38 4 S 42 49 E 3568 95 65 69 33 04 70 41 30 18 3 39 0 84 0 46 1 73 0 58 0 50 0 73 0 43 0 46 0 07 1811.52 S 2405 51 E 3011 33 S 53 1 E 1855.91 S 2454 1899.05 5 2501 1942.23 S 2547 1985.36 S 2592 2028.71 S 2635 2072.55 S 2677 2117.04 S 2719 2162.05 S 2761 2207.19 5 2803 30 E 3077 37 E 3140 56 E 3203 O0 E 3264 08 E 3325 70 E 3386 87 E 3446 86 E 3507 71 E 3568 01 S 52 54 E 58 S 52 48 E 49 S 52 41 E 99 S 52 33 E 55 S 52 24 E 08 S 52 16 E 67 S 52 6 E 46 S 51 57 E 26 S 51 47 E 6000.00 4321.20 4251.00 38 34 6100.00 4398.98 4328.78 39 12 6200.00 4476.59 4406.39 39 5 6208.00 4482.80 4412.60 39 5 S 42 35 E 3629.38 S 42 28 E 3691.47 S 42 29 E 3753.81 S 42 29 E 3758.80 1 .10 1 .04 0.00 0.00 2252.70 S 2845.69 E 3629.41 S 51 38 E 2299.04 S 2888.15 E 3691.47 S 51 29 E 2345.59 S 2930.76 E 3753.82 S 51 20 E 2349.31 S 2934.16 E 3758.80 S 51 19 E COMPUTATION DATE: 17-JAN-91 PAGE 3 CONOCO, INC. MILNE POINT UNIT J-4 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 05-JAN-1991 KELLY BUSHING ELEVATION: 70.20 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZZMUTH SECT]ON SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -70 20 0 0 N 0 0 E 0.00 1000.00 995.04 924 84 13 20 S 65 54 E 60.21 2000.00 1853.49 1783 29 44 24 S 57 14 E 542.95 3000.00 2443.49 2373 29 55 26 S 52 35 E 1345.84 4000.00 2977.59 2907 39 60 24 S 49 35 E 2190.16 5000.00 3539.67 3469 47 43 2 S 47 42 E 3010.13 6000.00 4321.20 4251 O0 38 34 S 42 35 E 3629.38 6208.00 4482.80 4412 60 39 5 S 42 29 E 3758.80 0.00 0.00 N 0.00 E 0.00 N 0 0 E 3.18 20.19 S 60.92 E 64.18 S 71 40 E 2.73 266.21 S 482.22 E 550.82 S 61 6 E 0.99 737.09 S 1133.67 E 1352.23 S 56 5B E 0.33 1273.26 S 1786.00 E 2193.40 S 54 31 E 3.39 1811.52 S 2405.51 E 3011.33 S 53 I E 1.10 2252.70 S 2845.69 E 3629.41 S 51 38 E 0.00 2349.31 S 2934.16 E 3758.80 S 51 19 E CONOCO, INC. MILNE POINT UNIT J-4 SCHRADER BLUFF NORTH SLOPE, ALASKA COMPUTATION DATE; 17-JAN-91 PAGE 4 DATE OF SURVEY; 05-JAN-1991 KELLY BUSHING ELEVATION; 70.20 FT ENGINEER; JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG 0 O0 70 25 170 25 270 25 37O 470 57o 670 771 872 25 25 28 61 36 59 0 O0 70 20 170 20 270 20 370 20 470 20 570 20 670 20 770 20 870 20 -7O.2O 0 0 0.00 0 5 100.00 0 7 2OO O0 0 4 3OO O0 0 22 400 oo 0 29 500 O0 2 25 600 O0 5 59 700 O0 7 58 800 O0 9 52 2325 ~;~ 2503 2684 3046 3217 3402 3595 3782 974.51 1077.59 1070 1182.13 1170 1289 34 1270 1401 74 1370 1516 35 1470 1633 56 1570 1757 07 1670 1887 54 1770 2023 51 1870 20 1000 20 1100 20 1200 20 1300 20 1400 20 1500 20 1600 20 1700 20 1800 970 20 900 O0 12 30 O0 15 29 O0 18 26 O0 23 38 O0 29 45 O0 28 55 O0 33 19 O0 39 4 O0 40 24 O0 44 59 2166 89 1970 20 1900 O0 46 52 32 207O 84 2170 82 227O 56 237O 79 2470 07 257O O7 267O 24 2770 87 2870 20 2000 20 2100 20 2200 20 2300 20 2400 20 2500 20 2600 20 2700 20 2800 O0 54 33 O0 55 42 O0 57 15 O0 56 55 O0 54 52 O0 54 31 O0 59 42 O0 57 41 O0 59 5 3985.04 2970 20 2900 O0 60 21 4189 29 3070 20 3000 O0 61 5 4398.31 3170 4585.30 3270 4751.16 3370 4902.31 3470 5041.20 3570 5172.04 3670 5301.23 3770 5428.43 3870 2O 3100 20 3200 20 3300 20 3400 20 3500 20 3600 2O 37OO 20 3800 O0 61 12 O0 54 41 O0 50 59 O0 46 32 O0 41 28 O0 39 33 O0 38 47 O0 37 47 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E N 83 41 E N 35 5 E N 53 22 E N 74 39 E N 74 13 E S 82 26 E S 72 47 E S 70 43 E S 69 48 E 0 O0 0 10 0 11 0 09 0140 0 69 2 37 9 57 21 04 35 89 0.00 0.00 0.00 0.19 0.49 1.01 4.07 1 .47 2.05 2.36 0 O0 N 0 08 S 0 02 N 0 19 N 0 17 N 0 53 N 0 59 N 1 48 S 5335 10 66 S 0 00 E 0 06 E 0 17 E 0 27 E 0 65 E 1 31 E 3 50 E 11 07 E 22 66 E 37 42 E 0 O0 N 0 0 E 0 0 0 0 1 3 11 23 38 10 S 34 8 E 17 N 81 33 E 33 N 54 50 E 67 N 74 58 E 41 N 67 45 E 55 N 80 24 E 16 S 82 22 E 28 S 76 47 E 91 S 74 6 E S 66 47 E S 64 48 E S 62 32 E S 60 33 E S 60 26 E S 59 4 E S 59 14 E S 58 46 E S 58 12 E S 56 53 E 54.70 78.92 108.63 146 60 197 12 252 51 313 03 384 74 467 90 559 40 3 57 3 37 3 73 4 99 1 19 241 1 73 2 38 0 98 241 17 9O S 28 41 60 85 113 144 182 225 26 S 78.42 E 83 73 S 105.69 E 113 29 S 139.46 E 151 41 S 184.04 E 202 66 S 232.37 E 258 92 S 284.85 E 319 10 S 346.92 E 391 93 S 418.36 E 475 55.70 E 58 51 S 72 11 E 35 S 70 11 E 63 S 68 27 E 93 S 66 37 E 90 S 65 6 E 68 S 63 56 E 59 S 63 2 E 81 S 62 18 E 46 S 61 38 E 275 21 S 496.09 E 567 32 S 60 59 E S 55 45 E 661.80 S 54 36 E 784.28 S 53 53 E 931.98 S 53 19 E 1082.69 S 52 49 E 1236.76 S 52 24 E 1384.26 S 51 16 E 1522.07 S 50 44 E 1677.60 S 50 1 E 1842.83 S 49 54 E 2001.53 613 5 67 0 50 0 67 1 36 1 51 1 52 0 86 0 68 3 52 332.41 S 581.45 E 669 76 S 60 15 E 402.49 S 682.22 E 792 488.93 S 802.21 E 939 578.41 S 923.63 E 1089 670.89 S 1046.94 E 1243 760.49 S 1164.15 E 1390 845.77 S 1272.41 E 1527 943.80 S 1393.16 E 1682 1049.11 S 1520.52 E 1847 1151.39 S 1641.93 E 2005 10 S 59 28 E 46 S 58 38 E 79 S 57 57 E 46 S 57 21 E 53 S 56 51E 86 S 56 23 E 75 S 55 53 E 32 S 55 24 E 4O S 54 58 E S 49 35 E 2177.16 S 49 31 E 2355.16 S 49 8 E 2538.58 S 48 53 E 2696.29 S 48 38 E 2828.42 S 48 32 E 2941.58 S 47 42 E 3037.73 S 47 25 E 3121.91 S 46 31 E 3203.46 S 45 1 E 3281.67 0.12 0.80 2 .O4 1 17 2 72 4 O3 3 92 0 42 1 77 1 .01 1264.83 S 1776 10 E 2180 44 S 54 33 E 1380.38 S 1911 1500.11 S 2050 1603.58 S 2169 1690 87 S 2269 1765 68 S 2354 1830 14 S 2425 1887 O0 S 2488 1942 76 S 2548 1997 68 S 2604 62 E 2357 73 E 2540 93 E 2698 32 E 283O 39 E 2942 96 E 3038 29 E 3122 13 E 3204 36 E 3282 91 S 54 10 E 84 S 53 49 E 16 S 53 32 E O0 S 53 19 E 92 S 53 8 E 87 S 52 58 E 88 S 52 50 E 26 S 52 41 E 29 S 52 31 E COMPUTATION DATE: 17-JAN-91 PAGE 5 CONOCO, INC. MILNE POINT UNIT J-4 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 05-JAN-1991 KELLY BUSHING ELEVATION: 70.20 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTh DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 5554 67 3970 20 3900.00 37 44 S 44 13 E 3358.17 5681 19 4070 20 4000.00 37 51 S 43 20 E 3434.98 5808 05 4170 20 4100.00 38 3 S 42 50 E 3512.21 5935 O0 4270 20 4200.00 38 9 S 42 44 E 3589.53 6062 91 4370 20 4300.00 39 2 S 42 29 E 3668.35 6191 77 4470 20 4400.00 39 5 S 42 29 E 3748.69 6208 O0 4482 80 4412.60 39 5 S 42 29 E 3758.80 0.43 2052 59 S 2658.41 E 3358 61 S 52 20 E 0.27 2108 63 S 2711.95 E 3435 26 S 52 8 E 0.50 2165 68 S 2765.23 E 3512 36 S 51 56 E 0.37 2223 05 S 2818.38 E 3589 60 S 51 44 E 0.54 2281 77 S 2872.35 E 3668 36 S 51 32 E 0.00 2341 77 S 2927.25 E 3748 69 S 51 20 E 0.00 2349 31 S 2934.16 E 3758 80 S 51 19 E CONOCO, INC. MILNE POINT UNIT J-4 SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER LAST READING GCT TD DRILLER COMPUTATION DATE: 17-JAN-91 PAGE 6 DATE OF SURVEY: 05-JAN-1991 KELLY BUSHING ELEVATION: 70.20 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2787' ~NL & 3307' FEL, SEC28 T13N RIOE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 6141.99 4431.52 4361.32 2318.62 5 2906.06 E 6208.00 4482.80 44'12.60 2349.31 S 2934.16 E CONOCO, INC. MILNE POINT UNIT 3-4 SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER LAST READING GCT TD DRILLER COMPUTATION DATE: 17-JAN-91 PAGE 7 DATE OF SURVEY: 05-JAN-1991 KELLY BUSHING ELEVATION: 70,20 FT ENGINEER: JEFF FORMICA ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 2787' FNL & 3307' FEL, SEC28 T13N RIOE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 6141.99 4431.52 4361.32 2318.62 S 2906.06 E 620B.00 4482.80 4412.60 2349.31 S 2934.16 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 6208.00 4482.80 4412.60 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 3758.80 S 51 19 E SCHLUMBERGER O ~ REC T ~ ONAL SURV E Y COMPANY CONOCO, INC. WELL MILNE POINT UNIT d-4 F I ELD SCHRADER BLUFF COUNTRY USA RUN ONE DATE LOOOED OS - JRN - 91 REFERENCE 74~7S WELL' I1P,U J~4 (2787' FNL, 3307' FEL, S, 28, T13N, RIOE) HORIZONTAL PROJECTION fii:l~l.E = 1/~ !N/FT SO0 1000 1 ~00 ~000 ~SO0 WELL' MP.U J.4 (2787' FNL, 3307' FEL, S. 28, T13N, RIOE) VERTICAL PROJECTION -21:)1~ -IOOO O0 ~000 ~ ~ 4000 SIX:X] ] I ! .: ]-: i [ I ] i ~ .... , . . ~ : : L :. : : : , · : :; , I ~l~ { ] { I I , , : , , . I I i ] , : i ; , - j : - : - - : - ,:I. : [ } : J L {] : I I ! i : .......... ] ......................... . .............. ~'-?' ""~~'-? "'~-~-TT'7-?~'": ...... ?-v"~'Y'T"r"7'T": .... ~::? ~ ....... ~'-?--'?~ ....... ?-','"? ...... v"~-'-?'?'-r", ...... , ........ i .~: : : : ~ ' ' PROJECTION ON VERTICRL PLI::tNE 129. - 309. I~:I:{LED IN VF. RTICI:~. 0EPTHS HORIZ SCALE = 1/I000 IN/FT AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PEFUdlT ~9 c~ C) - ~ WELL NAlvIE ~/~L~ -~'~ COMPLETION DATE ~ I ~ . ! c~J CO. CONTACT ~-~Y~O~_~ check'off or iist d~ta as it'i~ 're~eiv'~.*lr!st received date for 407. ifnot required list as NFl ~"~ !* ..... . " , , , , (~,lq, i'C>l/~ drilling hi,tow V' " ~"~"Y ! ~' I ~"ll t.=~s o l'~°re ~escriptio~ cored intc~a~ core analysis' ~. d~,ditch intc~als diolta,I data iii i ~ iii i i u Hi ,llmll i il Ill I I I I III I~ I I I . II I I J III II I III I I I II I II III I LOG TYPE RUN INTERVALS SCALE NO. (to the nearest foot] , ,[inchllO0'! .J .J I . II ]Il ~1 II J I ~) ~...-~ ...... I...... ?~,.,- c~ t~,. --. , ~ ,~¢ [ ....... !,¢q,,, ~tS ..... 5 , ~ ....... I~ I i I i I iii i 131 , ' i i iJll ii I ii Hill ~4) .. . i I I I i i A i i i I ii ~ . i1 i i i I I i ii i ii IIll I I I J I III II . ...................... ,, ,,, , ii IIII I I I Illl I I I I I I I I TO: THRU: FROM: MEMORANbUM Sta e of Alaska ALASKA OIL AND GAS CONSERVATION COMMTSSION Lonnie C. Smi~'~// .... DATE: April 24, 1991 Commtss ioner~/~ FILE NO: LG4 2 4 - 3 TELEPHONE NO: SUBJECT: Louis R. Grimaldi . ~- '~' ~'"'-~' i,., ~' ' Petroleum Engineer RIG/BOPE Inspection Conoco MPU J-4 Kuparuk Rv Field Permit No. 90-98 we.dnesdav .4[~/?.1: I performed a RIG/BOPE inspection on EWS rig #4 doing a workover on Conoco's well J-4 in the Milne Pt. Unit of Kuparuk River Field. There has been a major amount of upgrade done on this rig. All major components are unitized, protected from the elements, and well heated. I found items that were in non-compliance and pursuant to a meeting on 4/8/91 with Lonnie C. Smith, Doug Amos, myself (AOGCC) and Jim Hartford (owner EWS), the following listed will be remedied by 5/9/91: 1) Check valve on nitrogen back-up bottles (accumulator). 2) Route a line from nitrogen back-up bottles to annular control (accumulator). 3) Check valve to be installed to prevent annular preventer from bleeding off (accumulator). 4) All 45° turns to be removed and all (6) 90° turns to be targeted (kill line). 5) Revise system to isolate line coming from downstream of choke to gas buster from coming in contact with rubber hOses in mud return system, i.e.-downstream of the 6" hose andl. Upstream of a 6" valve. All lines installed to be in compliance with API RP53-3.A.3 (choke system). 6) Add ..... an audible 'alarm to the existing visual alarm (hydrocarbon alarm system). In summary: EWS #4 is shaping up to be a good workover rig and after the 30 days allowed by Lonnie C. Smith for , repairs, I believe, a return visit is warranted. Attachment. 02-00lA (Rev. 6/89) 20/ll/MEMOI.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ¢OMMIS~iON BOPE Walk-Thru Inspection Report OPERATION: Drlg Wkvr /~ UIC Operator C ~ /J C~ C ~ Permit # Location: Sec ~ ~ T /~ ~ R/~ ~ M Drlg contr ~~, Rig~ Location (gen'l) ~~ Well sign IN COMPLIANCE; yes no n/a A. DIVERTER I N COMPL I ANCE; yes no n/a 1. ( ) ( ) 2.() () 3.() () 4. ( ) ( ) S.() () 6.() () 7. ( ) ( ) () 2.(kl () 3.(20 () ~.(Xg () () 6.() 7. {~h~J ( ) 8.() () 10. ¢'0, () 11. ( ) ~2. (,X) () 13. {~ ( ) ~. (~9 () ~. (24 () REMARKS: line sz & length line conn& anchored bifurcated & dwn wind 90~ targeted turns vlvs: auto & simultaneous annular pack-off condition B. BOP STACK wellhead flg wkg press stack wkg press annul ar preventer pi pe rams blind rams stack anchored chke/kill line sz 90° turns targeted (chke & kil~~ HCR vlvs (chke manual vlvs (chke & kill) connections (flgd, whd, clmpd) drl spool flow nipple flow monitor control lines fire protected C. CLOSING UNITS wkg press fluid level oprtg press press gauges sufficient vlvs regulator bypass 4-way vlvs (actuators) blind handle cover driller control panel remote control panel 11. ~ ( ) ( ) firewall 12. ( ) ~ ( ) nitrogen power source (back-up) 13. (~ ( ) ( ) condition (leaks, hoses, etc) () 2. (~ ( ) 3. T>~.l () -~e~. ( ) () s.(~ () 6.(~ () 7. ( ) ~ 8. 0 () ~ 1. (/'x,) ( ) 2. (.~ () 3..(,><~ ( ) ~.() 6.() Cx3 7. () () 8.~ () 1. ('.~)) () 2 () () ~.() 5..~) ( ) 6.() () D. MUD SYSTEM pit level floats installed flow rate sensors mud gas separator degasser separator bypass gas sensor chke In corm trip tank E. RIG FLOOR kelly cocks (upper,lower,IBOP) floor vlvs (dart vlv, ball vlv) kelly & floor vlv wrenches driller's console (flow monitor, flow rate indicator, pit level indicators, gauges) kill sheet up-to-date gas ~etection monitors (H-S & methane) hydr chke panel chke manifold F. MISC EQUIPMENT flare/vent line 90 ° turns targeted (dwn strm choke lns) reserve pit tankage personnel protective equip avail all drl site suprvs trained 2for procedures H S probes rig housekeeping RECORDS: Date of last BOP inspection: Resulting non-compliance: Non-compliances not corrected & why: Date corrections will be completed: BOP test & results properly entered on daily record? Date of last BOP test: Kill sheet current? Inspector C.0013 (rev 03/29/91) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISb,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ..... .... Suspend .. Operation shutdown Re-enter suspended well Alter casing Repair well __ Plugging __ Time extention __ Stimulate __ Change approved program __ Pull tubing Variance __ Perforate Other X Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 2787' FNL, 3307' FEL, Sec. 28, T13N, RIOE, U.M. At top of productive interval 4630' FNL, 8,90' FEL, Sec. 28, T13N, RIOE, U.M. At effective depth 5. Type of Well: Development X Exploratory __ Stratigraphic __ NSB AK NSB AK At total depth 4986' FNL, 424' FEL, Sec. 28, T13N, RIOE, U.M. NSB AK 6. Datum elevation (DF or KB) KB 35 AGL feet 7. Unit or Property name Milne Point Unit 8. Well number J-4 11. g. Permit number 10. APl number 50-029-22061 Field/Pool j<~ ~'1~1~ ~i~ ~ v./ Schrader Bluff 12. Present well condition summary Total depth: measured 6320 feet flue vertical 4550 feet Effective depth: measured feet true vertical feet Casing Length Size Structural Conductor 11 O' 13-3/8" surface 2951' 9-5/8" Intermediate Production 6334' 7" Uner Perforation Depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth Surface 80' 80' Surface 2916' 2420' T.O.C. @ 4200' 6299' 4535' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation April, 1991 16. If proposal was verbally approved Name of approver LO,J..h~ ~--~d ~/~_7 /'~1 Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signc~L~.~-_ ~. Van Lineberger Title Sr. Production Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test ~ Mechanical Integrity Test __ Approved by order of the Commission Form 10-403 Rev 06/15/88 Date '~"~/~/fl [ Location clearance Subsequent form required 10-' ORIGINAL SIGNED BY LONNIE C. SMITH [Approval No. ApproVed CoPY Returned ' Commissioner Date SUBMIT IN TRIPLICATE MILNE POINT UNIT J-4 WELL PROPOSED CLEANOUT/COMPLETION PROCEDURE - SUMMARY 4/4/91 - CVL NOTE: Hold frequent on site safety/environmental meetings prior to all potentially hazardous tasks. 1. MIRU on J-4 well. Test BOP's. · · · ® GIH to retrievable bridge plug @ 4990'. well clean. Latch plug and POOH. Reverse circulate PU 650' of 1-1/4" tubing and GIH. Wash debris from isolation disk @ 5678'. Set down and break disk. POOH. PU and run electric submersible pump (ESP) on tubing. Freeze protect. ND BOP's and NU tree. Leave well shut in until surface equipment installation is complete. Sr. Prod. Engineer Milne Point Well J-4 Well Completion Procedure (Cont'd) Well Information Casing: Bridge Plug: Packers: Sand Bridge: Isolation Disc: PBTD: RA Tag: KB: Ground Level: Deviation: Workstring: Perforations: Fluids: Disposal: 7" 26 ~ ID = 6.276" Capacity = 0.03826 bbl/ft = 0.2148 ft3/ft Halliburton Model "3L" @ 4990 MD Otis VST @ 5063 MD otis AWD Sump @ 5680 MD 5640 MD (in gravel pack screen) 5678 ft MD 6002 ft (frac sand) 5300 ft 34 ft (Nabors 27 E, original drilling data) 70 ft MSL 60.8 degrees maximum hole angle @ 4210 ft MD. 37 degrees through perforation intervals. 4" 14# S-135 (#-1/2" XH Connection) Drill Pipe Inner Diameter: 3.34" Capacity = 0.01084 bbl/ft (92.251 ft/bbl) Annular Capacity (tbg x csg) = 0.0227 bbl/ft (44.053 ft/bbl) Note: No allowance for upsets 5524 - 5540 MD 5560 - 5610 MD 5630 - 5660 MD (3957 - 3970 TVD) "N" Sand (3987 - 4025 TVD) (4041 - 4065 TVD) 5735 - 5777 MD 5820 - 5853 MD (4125 - 4158 TVD) "O" Sand (4192 - 4218 TVD) 8.6 ppg NaC1 with 12% Methanol Ail contaminated brine, diesel, produced fluids, frac fluids, etc., will be disposed of by injection down the 9 5/8 by 7 annulus Page 3 TO: THRU: FROM: MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smi~~.~ Commissioner / DATE: FILE NO: April 2, 1991 HH4291 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection Conoco MPU J-4 Permit No. 90-98 Kuparuk Rv Field Harold R. Hawkins Petroleum Inspector Saturday March.30,~ 199_1: I performed a RIG/BOPE inspection at Conoco MPU J-4 on rig EWS #4. There were a few infractions. A check valve on hydraulic line to annular needs to be installed, the stack needs anchors installed and there are several long 45 degree turns in kill line from cellar to mud pump that are questionable. I filled out a RIG/BOPE inspection report attached. In summary: The RIG/BOPE inspection was satisfactory with the exception of the infractions above. The owner of EWS said the infractions would be in order by next rig move. His name is Jim Hartford. Attachment. 02-00lA (Rev. 6/89) 20/11/MEMOl.PM3 OPERATION: Drlg Wkvr Operator, ~'~/(~ Location: Sec Drlg contr ~' Location (gen'l) I N COMPL I ANCE yes n_o_o ,n/,a A. D I VERTER ~TATE OF ALASKA ALASKA 01L AND GAS CONSERVAT I ON COMM I SS m uN 1. ( ) 2.() 3.() 4.() S.() 6.() 7. ( ) u,c Permit # ~ 0 R ]~: dM Rig# Wel 1 sign 1.(X) () 2.(~) () 3.(~) () ~.~) () 7. (~O (,) 8.(~) () ~o. 0<) () 11. (~) ( ) 12. (~.) ( ) 13. (k) ( ) 1~.(k) () 15. (~) () ( ) (~) line sz & length ( ) (~) line conn& anchored ( ) (X) bifurcated & dwn wind ( ) (~) 90° targeted turns ( ) (~) vlvs: auto & simultaneous ( ) (~) annular pack-off ( ) (X) condition B. BOP STACK ( ) wellhead flg wkg pressrun/~/ BOPE Walk-Thru Inspection Report ( ) stack wkg press ( ) annular preventer ( ) pipe rams ( ) blind rams ( ) stack anchored ( ) chke/kill line sz ~. 2. (X,.) 3. 4. (El 7. (~) 8. (~J 9.(~ '1o. ~) ( ) 90° turns targeted (chke & kill ln) ( ) HCR vlvs (chke & kill) ( ) manual vlvs (chke & kill) ( ) connections (flgd, whd, clmpd) ( ) drl spool ( ) flow nipple ( ) flow monitor ( ) control lines fire protected C. CLOSING UNITS ( ) ( ) wkg press ( ) ( ) fluid level ( ) ( ) oprtg press ( ) ( ) press gauges N) ( ) sufficient vlvs ( ) .( ) regulator bypass ( ) ( ) 4-way vlvs (actuators) ( ) ( ) blind handle cover ( ) ( ) .driller control panel ( ) ( ) remote control panel DATE: Representative' ~/-~ Well name ~g-U Representative_ ~/~ /~/~ I N COMPL I ANCE; yes no o/a 11. ~) ( ) ( ) firewall 12. (~) ( ) ( ) nitrogen power source {back-up) 13.{~) ( ) ( ) condition (leaks, hoses, etc) 2. 3. ~) 5. (~) 6. 7. pO 8. (~) D. MUD SYSTEM ( ) ( ) pit level floats installed ( ) ( ) flow rate sensors ( ) ( ) mud gas separator ( ) ( ) degasser ( ) ( ) separator bypass ( ) ( ) gas sensor ( ) ( ) chke In conn ( ) ( ) trip tank 2. (,X) E. RIG FLOOR ( ) ( ) kelly cocks (upper,lower,IBOP) ( ) ( ) floor vlvs (dart vlv, ball vlv) ( ) ( ) kelly & floor vlv wrenches ( ) ( ) driller's console (flow monitor, flow rate indicator, pit level indicators, gauges) 5. (') ( ) 00 kill sheet up-to-da~e 6. ()~) (,~ ( ) gas ~etection moni~orsfW',--~ ~ $ (H-S & methane) , 7. ( ) (~ ( ) hydr chke panel 8. (~) ( ) ( ) chke manifold F. MISC EQUIPMENT 1. (~ ( ) ( ) flare/vent line 2. (~) ( ) ( ) 90~ turns targeted (dwn strm choke lns) 3. (~) ( ) ( ) reserve pit tankage (JO ( ) ( )_ personnel protective equip avail ( ) ~) ( )%all drl site suprvs trained Od~DT~"~t~/'"6~/?for procedures 6. ( ) (~) ( ) H-S probes 7. ~) ( ) ( ) rig housekeeping RECORDS Date of last BOP inspection: Date of last BOP test: Resul t~n f a ~ I u r e J~'~-//~£y~ x ~ ' ~ ' ~/A Date corrections wi]] be completed: ~ ~r ~<<~ ~C~~ BOP test & results properly entered on daily reeord?~ Ki]] sheet C.0013 (rev 03/18/91) STATE OF ALASKA . ALASKA ~JIL AND GAS CONSERVATION COMMISb,ON APPLICATIO# FOR $11NDRY APPROVALS 1. Type of Request: Abandon Suspend __ Alter casing . Repair well Change approved program __ Operation shutdown X Re-enter suspended well Plugging __ Time extention .. Stimulate __ Pull tubing ~ Variance ~ Perforate ~ Other Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 2787' FNL, 3307' FEL, Sec. 28, T13N, RIOE, U.M. At top of productive interval 4630' FNL, 890' FEL, Sec. 28, T13N, RIOE, U.M, At effective depth 5. Type of Well: Development x... Exploratory Stratigraphic Service NSB AK NSB AK At total depth 4986' FNL, 424' FEL, Sec. 28, T13N, R10E, U.M. NSB AK 6. Datum elevation (DF or KB) KB 35 AG L 7. Unit or Property name Milne Point Unit 8. Well number J-4 9. Permit number 90 -98 10. APl number 50-029-22061 11. Field/Pool Schrader Bluff feet 12. Present well condition summary Total depth: measured 6320 feet true vertical 4550 feet Plugs (measured) Effective depth: measured feet true vertical feet Junk (measured) Casing Length Size Structural Conductor 110' 13-3/8" Surface 2951' 9-5/8" Intermediate Production 6334' 7" Liner Perforation Depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Cemented Surface Surface T.O.C. @ 4200' Measured depth 80' 2916' 6299' True ve~icaldepth 80' 2420' 4535' RECEIVED FEB 1 4 t991 Alaska Oil & Gas Cons. C0mmiss't0t Anchorage 13. Attachments Description summary of proposal Detailed operations program Shutdown Operations with Rig 27E Pending Completion with EWS 4 BOP sketch 14. Estimated date for commencing operation October 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~q/~ f R.S. Rossberg Title Sr. Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: No Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test __ Su----bsequent form required lO-- 'ed CoPY .%ngrO~ ' ORIGINAL. SIGNED BY LONNIE C. SMITH Approved by order of the Commission _.~----~~ner Form 10-403 Rev 06/15/88 Date ~)..///~.,, / (~ / , JApprova, NO.~// .-- O J'"-/, ! SUBMIT IN TRIPLICATE SCHLUMBERGER WELL SERVICES DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-21 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineber_ger ~blE REPLY TO SCHLUMBERGER WELLSERVICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley (~entlemen: Enclosed ore 2 Rl. prints of the Company CONOC0, Inc Well Milne Point Unit L-7 BGT, Run 1, 1/25/91 on: Field Milne Point /Kuparuk River Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dair7 Ashford Houston, TX 77079 A~tn: George Lamb - OF 2018 PER Counly, Nmrth Slope State Alaska _l_BL__prints, 1RF Sepia CONOCO~ Thc. 1000 South Pine Ponca City, OK 74603 Attn: Glenn Welch 7~60RDW 1 BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Pgata_Dri~. Midland, TX 79710 Attn: John Carrol *(915/685-5600) _l~rints, 1RF Sepia Chevron U.S.A. 11111 South W~lcre~t_ Hou~ton~ T~w~ 77~qq Attn: Priscilla MacLeroy ~13/561-3652 //~A1.BL nrints, 1 q~7--~ las~a Oil & Gas Cons'e-r-.yation "Commission ~ 3001 ?orc'upine Drive kx ~ Anchorage, AK 99501 The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints ,,. prints prints Very truly yours, SCHLUMBERGER WELL SERVICES Sw.~-- 1327,F David M,.. $aalwaechter DISTRICT MANAGER SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 772~ 1-2 17~ JAN 2 3 1991 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineber$er ~EAIE REPLY TO SCHLUMBERGER WELL ~ICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed are_2__BL_prints of the Gravel Pack Log, run 1, 1/15/91 Company CONOCO, Inc. on: Well Milne point Unit J-4 Field Milne Point Additional prints are being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 A~tn: George Lamb - OF 2018 PER County North S]ope State Alaska _l_BL_prints, 1 RF Sepia C~NQC~; Tnc~ 1000 South Pine Ponca City. OK 74603 Attn: Glenn Welch 7~60RDW 1BL prints, 1RF Sepia OXY U.S.A., Inc. ~ Desta Drive Midland, TX 797i0 Attn: John Carrol *(915/685-5600) ~rints, 1RF Sepia Chevron U.S.A. :11111 South_Wj]cramt_ Hm~t~n~. T~wn~ 77~qq Attn: Priscilla MacLeroy _.*?13/561-3652 ~ mrints, 1RF Sepia (Alask~ Oil & Gas Conservati~p Commission 3001 Porcupine Drive ~Anchorage, AK 99501 ~-~n: John Boyle The film is returned to Conoco; Log LJ brary. We oppreciote the privilege of serving you. prints prints prints Received by: Date: r lVED I\L~_ L I ,JAN ~ ~ 19~1 Alaska 0ii & Gas 0ans. u0mmiss7 Very truly yours, Anchorage SCHLUMBERGER WELL SERVICES SwS-- ! 327-F David M. Saalwaechter DISTRICT MANAGER SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 7725 ! -217S CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 AHention' Van Lineberger ~$E REPLY TO SCHLUMBERGER WELL ~RVICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore_2_BL_prints of the Company CONOCO, Inc, , Well Milne Point Unit J-4 GCT/Perforating Depth Control, Run 1, 1/5/91 on: Field Milne P..oJnt/Schrader BI uff Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 A~tn: George Lamb - OF...2018 PER.. County Nnrth Slope State Alaska _l_BL_prints, I RF Sepia 1000 South Pine Ponca City, OK 74603 Attn: Glenn Welch 7~60~DW 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive ..~idiand, TX 79710 Attn: John Carro] *(915/685-56OO) _l_~rints, 1 RF Sepia Chevron U.S.A. 11111 South Wi]cre.~t_ _ HOllSt~n~ T~w~.~ 770qq Attn: Priscilla MacLeroy _~'713/561-3652 1 BL?mrints, 1--RF~Sepi~ x. ~.~[~aska 011 & Gas Cons ,? ~'~' Commission 5. 3001 Porcupine Drive ~) ,' Anchorage, AK 99501~ Attn: John BoYle The film is returned to Conoco, Log Library. We appreciate the privilege of serving you, prints prints prints B~s Cons. ReceJ Med by; ~.lask~ 0~ ~ Date: Very truly yours, SCHLUMBERGER WELL SERVICES __David M. Saalwaechter DISTRICT MANAGER SWS-- 1327-F SCHLUMBERGER WELL SERVICES A DIVISION OF $CHLUMBERG£R TECHNOLOGY CORPORATION HOUSTON. TEXAS ?7251-2 ! 75 ,JAN ! 3 1991 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van ~inebe~ger IH,.EAIE REPLY TO SCHLUMBERGER WELL ~ERVICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed are_2__BL_prints of the. Packer Rec, Run 2, 1/09/91 Company CONOCO, Inc, Well Milne Point J-4 .on: I Field Milne Point /Schrader B],,Ef Counly North Slope State Additional prints ore being sent to: ! BL prints CONOCO, Inc... 600 North Dairy Ashford Houston, TX 77079 At,n: George Lamb - OF 2018 PER Alaska _l_BL_prints, 1RF Sepia CONOCO~ Tnc~ 1000 South Pine Ponca City, OK 74603 Attn: Glenn We]ch 7q6ORDW _ 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland,.TX 797~0 A~tn: John Carrol *{915/685-5600) ~rints, 1RF Sepia Chevron U.S.A. _11111 South Wjlcramt_ _Hm~t~n= Tew~ 77~q~ , Attn: Priscilla MacLeroy ~713/561,3652 ~ BL nri~~~ Ai~.~'OJl & Gas Conseb~ation G~mmissJon ~01 POrcupine Drive horage, 99501/ ~ttn: John Bo¥1~.~. The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints prints Very truly yours, SCHLUMBERGER WELL SERVICES .David M, Saalwaechter SWS-- ! 327-F SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 PI. EASE REPLY TO JAN 0 8 lggl sc.~u~.E.~E. WELL S~RWCES Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van ~ineberger Gentlemen: Enclosed ore_2_BLprints of the Company CONOCO, Inc. Well Milne Point Unit J-4 ~ / / / / Phasor DIL/NGT/Raw Data/Porosity/Cyberlook, Run 2, 1/3/91 ,on' Field Milne Point/Schrader Bluff Additionalprintsare being sentto: 1BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 A~tn: George Lamb - OF 2016 PER County~ Nmr-t~e State Alaska _l~rints, 1RF Sepia CONOCO; ThC, 1000 South Pine Ponca City, OK 74603 Attn: Glenn Wel~h 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Pesta Drive Midland., TX 797~.0. At,n:. John Carrol *(915/685-56OO) _l_[lL_prints, 1RF Sepia .Chevron U.S.A. . ~_11111South_W~]crmmt_ _Houstnn; T~n~ 77~qq Attn: Priscilla MacLeroy ~*Z13/561-3652 ~.~a Oil & Gas Conservatio~ /-CommissiOn h 300~ Porcupine Drive /., , Anchorage, ~ 9,9501 ,.// ~..~ttn: John Boyle ~ The film is returned, to Conoco, Log Library. prints prints prints ~ ~c~J ~v Il Al .... Date: We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES David .M,, Saalwaechter DISTRICT MANAGER SWS-- ! 327.F SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 JAN 0 2 1991 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: V. an Lineberger Pi. USE REPLY TO SCHLUMBERGER WELL SERVICES:Pouch 340069 :Prudhoe Bay, AY, 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore_2_BL_prints of the Borehole Geometry Log, Run 1, 12/31/90, Company CONOCO, Inc. Well Milne Point Unit J-4 on: I Field Milne Pojnt/Schrader Bluff County.. North Slope Additional prints ore being sent to: I BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX .77079 Attn: George Lamb.- OF 2018 PER ... State Alaska _l~rints, 1RF Sepia C~N~CO~ Thc- 1000 South Pine Ponca City, OK 74603 ~Attn.: Glenn Welch 7360RDW I BL prints, 1RF Sepia OXY U.S.A., Inc. _~_6Desta Prive Midland, TX 7971~ Attn: J.ohn Carrol ~(915/685-5600) _l_~rints, I RF Sepia .Chevron U.S.A. .... 11111South.Wticrest. . H~u~t~n~ T~w~ 77~qq Attn: Priscilla MacLeroy 7713/561-3652 rvation / , Commission _ _ , . 3°°I,,P°rcup!~e ~' , ~ Anch0'ra~e,-AK 99501 ,,. / k~tn.' -iofin Boyle ~ The film is returned to Conoco~_ Log Library. We appreciate the privilege of serving you. prints prints prints RECEIVED ,JAN 8 !991 A!~ska Oi! & Ras Cons. Commission Anchorage Received by: Date: Very truly yours, SCHLUMBERGER WELL SERVICES 5w$-- ! 327-F Dpvid M, Saa!waechter 'DISTRICT MANAGER July 27, 1990 Telecopy~ (907)276-7542 David L. MountJoy Sr. Drilling Foreman Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Re: Mtlne Point Unit No. Conoco Inc. Pe~tt No. 90-98 Sur. Loc. 2787'FNL, 3307'FEL, Sec. 28, T13N, R10E, ~. Btmhole Loc. 4986'FNL, 424'FEL, Sec. 28, T13N, R10E, UM. Dear Mr. Mountj oy.. Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting dete~inatlons are made. The Commission will advise you of those BOPE tests that it wishes to witness. Very truly yours, David W. J~hn~ton Commis stoner o~ Alaska Oil"and~Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ...... ~ ALASKA ;IL AND GAS CONSERVATION ( VIMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill lb. Type of well. Exploratory ,'~ Stratigraphic Test ~,,.De elopment O~1 Re-Entry __ Deepen Service '- De,velopement Gas ~ Single Zonef~X: Multip!e Zone ,,~- 2. Name of Operator :5. Datum Elevation (DF or KB) 110. Field and Pool CONOCO INC. ' KB 35 AGL feetJ) KUPARUK RIVER 3. Address 6. Property DesignatiOn Pouch 340045; Prudhoe Bay: AK 99734 ADL-25906 I FIELD .... 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 2787' FNL, 3307' FEL, SEC. 28, T13N, RIOE Attop of productiveinterval U.M., NSB, AK 4630' FNL, 890' FEL, SEC. 28, T13N, RIOE At total depth 4986' FNL, 424' FEL, SEC.28, T13N, RIOE 12, Distance to nearest ' I 13. Distance to nearest well property line I 4390 feetI 60'F/`]-3 @ 500' feet 16. To be completed for deviated wells Kickoff depth 500 feet Maximum hole angle 570 18. Casing program size Hole Casing ~/R · ARC 12 ]/4 · 8.5 Specifications Weight I (~rade l Coupling I Lengtf u-anl ,WELD ~ Rn, GR~oE I 19. To be completed for Redrill, Re-entry, and Deepen O Present well condition summary Total depth: measured feet trUe vertical feet MILNE PO)NT UN)T 8. Well number Effective depth: measured feet true vertical feet ,]-4 9. Approximate spud date NOVEMBER 24, 1990 14. Number of acres in property 2560 BLANKET Number 8086-15-54 Amount 15. Proposed depth ~,MO and TVD) i955'MD. 4297'TVD*feet ,. 17. Anticipated pressure (see 20 AAC 25,035 le)(2)) Maximum surface 1900 pslg At total depth fTVD) Setting De .p. th Top Bottom 35' I CiR' I llR' I llR' 1 }erations. Plugs (measured) 2000 Junk (measured) Quantity of cement (include stage data) ±485 SKS PERMAFROST C ±744 SKS PERMAFROST E +263 SKS CLASS G .~90 SKS PERMAFROST E +387 SKS CLASS G DOWNSQUEEZE +327 SKS PERMAFROST C +60 BBLS ARCTIC PACK Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True Vertical depth RECEIVED 'JUL ' ..... ~ Oil& Gas "An ora SKETCH X 20. Attachments Filing fee:~3 Property plat ~ BOP Sketch)E: DiverterSketchX2 Drilling programX; Drilling fluid program]~G Timevs depth plot)~ Refraction analysis ~. Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed :~_,¢~~"~..:~,>.¢ ¢'~~C Title SP~ DRILLING FOREMAN Date ommission Use nly Permit Number I APInumber ) Approvaldate ) See cover letter '~O" ¢'~' 50-o~_.~- 2. Z.o '~3 07/27/90 for other requirem(;rlts Conditions of approval Samples required !~_~ Yes ~ No Mud Icg requif, e, cl ;_: Yes /h~ No Hydrogen sulfide measures ~% Yes.~,_~'~ No Directional survey required ,,~ Yes i~ NO Required working' pressure for BOPE ",.~¢.M; ¢2 3M; ~ 5M; ~ 10M; [2 15M Other: (....._...~----~% ~. ,~.--~'--~-' ~ --'~· by order of e./__~'~7/~ A p p roved'~"'"-,~, j (_¢""%~ Commissioner the comm,ssion Oat ~ , Form 10-401 Rev. 12-1-85 SubrT~ i~1 triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT J-4 Conoco Inc. P. O. Box 340045 Prudhoe Bay, Alaska 99734 I. Casing and Cementing Program ae The 13-3/8" conductor will be set at ±80' below the surface, then cemented to the surface with ±485 sacks of Permafrost Type "C". Be The 9-5/8" surface casing will be cemented with ±744 sacks of Permafrost "E" cement followed by ±263 sacks of Class "G" Cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±90 sacks of Permafrost "E" cement pumped around the casing shoe followed by ~387 sacks of Class "G" cement. The secondary cement job will consist of +327 sacks of Permafrost "C" cement followed by ±60 barrels of Arctic Pack pumped down the 7"x 9-5/8" annulus. II. Drilling Fluid Program ae 0' - 3137' 9.0 ppg freshwater spud mud. B. 3137' - 5043' 9.2 ppg low solids non-dispersed. C. 5043' - TD 9.4 low solids non-dispersed. III. Drilling Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River Field (Upper Cretaceous-West Sac). The mud system will be low solids, non-dispersed with a mud weight in surface hole of 9.0 ppg. Mud weight at TD will be 9.4 ppg. A 20", 2000 psi diverter will be installed on the 13- 3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. BOP's, choke manifold, upper and lower kelly safety valves will be tested to 500 psig and 5000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is J-3 with a closure of 60 feet at a depth of 500'. The well will not be completed or tested at this time. ae Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Be Drill a 12-1/4" surface hole to ±2500' TVD 3137' MD and set 9-5/8" casing. Co Drill a 8-1/2" production hole to ±4297' TVD to 5955' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YD PV VIS FL 0 0 Gravel 1-1-4 9.0 32 20 90 15 500 500 Sand/Clay 1-1-4 9.0 25 20 65 15 3348 4687 "K" Sand 1-1-4 9.2 25 15 35 10 3598 5043 "M" Sand 1-1-4 9.4 25 15 35 10 3818 5330 "N" Sand 1-1-4 9.4 25 12 35 05 3997 5564 "O" Sand 1-1-4 9.4 25 12 35 05 4297 5955 TD 1-1-4 9.4 25 12 35 05 *The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD, a Sundry Notice will be submitted. I II II I I II NOTE& ~N~ POINT UNIT 1. STATE PLANE COORDINATES ARE ZONE 4~ Y~ JAY 2. ALL GEODETIC POSITION8 ARE BASED ON ~ ~,m,n'I, ^¢CE~ ~,~ ..... ~ \ N.A.D. 1927 .o~ ~~~ ~ .,K~ 3. OFFSETS TO SECTION LINES ARE COMPUTED ~/ / o, SECTION CORNER POSTION$ MILNE PT. VICINITY MAP o · MILE8 '~ ]7- , ~ ~ ~ I LOCATION IN :~ J..SEC' 28, T13N, R1OE, UMIAT. MERIDIAN.. 0~.. , j WELL FROM EAST LINE FROM NORTH LINE , ,. J--1 8378' 2622' " J-2 3364' 2677' - --- · ,.i .., j U-3 3331' 2732~j~'~'-~ ~) {~) ,'O J-1 [__. {~) J-4 3307' 2787' ' ' ' -J ~o '0 J-2 ;: ~ i 'O: J-3 '-D "* " , ,0..__ ~, . --'-.a': '"- 40' '/¥' ~j~ -i ,-, J-'4-r~ ' STATE PLANE i b l~o' ' I WELL Y : ~, J-' o, ~. -j_, 6,015,055.21' 55t939.,~9'" 'L 1 ., !I ,I ',-,,' ~----- 30' J-3 6,O14,945.30' 551,987.53' 290' "~1' J-4 6,O14,890.35' ,552.Oll.60' J PAD <'" GEODETIC POSITIONS NAD 1927 IO' 170' ~ ~ 80' ! 40.~ ~! ~ ,, WELL "NORTH LATITUDE WEST LONGITUDE ~:- -~0' 20'i ~ [ ~ ~ f 'J-1 70-27'06.7426- 14~- 34'34.3s~- '~ ~/...:..~.~!~.::...~:i`~:..~:~:~..:.:~:~(~:~:~?~F:~!~:.~:`~:~:.:.~::~:i:~.-~1 Ir-'/.:i'.::)'.:::.:.:';.-.~. Lo 3-2 70'27'O6.2OO5' 149'34'33.662" "" ' "' ' ...... "' "' ""'" "' :' " ...... ' :'"' .... J-3 70° 27'05.6583" 149° 34'32.967" J-4 70° 27'O5.1163' 149' 34'32.271' ,TYPICAL ,SECTION ~ NO SCALE ~ I[ I I I _ ~. Robert_,~ IllJl I I II I I I I ,SURVEYED FOR: _ o ^w. I. OClllO 8 ~ ~ ~ aza~,mas CHECKED DLR ~ ~ ~.'m s~"t"a ~t FIELD BOOK ~ ~xa,s=4 ~ ,SCALE 1'=200' JOB NO. 87033 . FF.B.8400Z lily.ri. LOC J'~'LL I I Jl I ~ 1' 13 N R 9 E T 13 N R 10 E T 13 N R I I E MILNE POIN] IIII I I ~ II I I! L II II Illll III I e Co.o o,, ® ~ Unit Boundlry CoNoc ET 7. a 11 7 ~-255~ 2533AC ADL-47434 ,2560 AC ADL-47433 ~60 AC, 18 17 . 16 ; 15 14 13 23 14 21 22 : 23 24 21 22 ~ ADL-25516 ADL-47439 ADL-3 ADL-~ 15~4B' ~Rn A~ ADL'47438 2544~C 1280 AC .~2"O ACI .... ~-25514 2550 AC ADL-25515 2~4 AC l~eo Ac ...... ADL-47437 25~0 AC 30 29 2a 27 26 · 25 30 29 ~ EXI 31 3~ 33 34 aeeed on Utah 35 36 31 32 Mllee 0 A~'25517 ~ A~ ADL-28231 2555 AC :, 2235 AC 20 ~DL-25~ 2560 AC ADL-25518 2560 AC~ ~ , ~ ~ II UNIT 35,744 Acrel 6/84 CHE¥, ~OHlO 41BIT A ilNT UNIT AREA Meridiln.Alalk I I 2 $ClII CONOCO INC,--NA O S 13-5/8" 51808a BOP SYSTEM Fill Llne A~'I 13-5/8' ~M x 11' ~M AF'I 11' 5M Threaded Correction Flow Line Annular Preventer Ram R~m Choke Line: 3" 5000~ Manual Gate Valve & 3" HCR VALVE Kilt Line: Two 3" 5000~ Manual Oa~e Valves Ram Tublng Spool w/ 2"-5888a Side Outlets Casing Spool w/ 3"-seee~ Side Outlets 9-5/8" SunFace Ca~tng 13-3/8" Conductor Casing 1, BOP STACK SIZE RATING MEETS APl RP53 & SPEC 6A FOR CLASS 5H 2, DOPE TO BE OPERATED EACH TRIP AND TESTED WEEKLY, 3, BOP HYDRAUL]C CONTROL SYSTEM TO INCLUDE (5) STATION CONTROL MANIFOLD LOCATED REMOTE WITH 168 OALLON ACCUMULATOR, RESERVOIR UN]T, & AUXILIARY ENERGY SOURCE FOR SYSTEM ACT]VAT]ON, ~r, MINIMUM ONE SET BLIND RAMS & TWO SETS APPROPRIATE PIPE RAHS, 5, CHOKE & KILL MAN]FOLDS SHOWN SEPARATELY TO MEET AP] RP 53 CLASS 5H REQUIREMENTS, KILL MANIFOLD FROM REM, OTE HIGH ,.----1~ m--' PRESSURE PUMP --*' NOTE: I. N'~DR~ULIC CC, NJ'ROt S¥ST£u FOR 8~ ~ACK 6 CHO~ uAN:FOLD TO INCLUDE (51 STATI~ CCNTROL MANIFO~ L~ATED REMOTELY ~ITH ~0 PSI ACCUUULATOR 160 6~. RESE~R 8 AUX. ENERGY STA ~NTROL ~ANIFO~ PLUS VARIABLE CHOKE ~T~L TO BE ~CATED ON RIG FLOOR. Z K~LL 8 CHO~ ~ANIFOLDS ~ MEET ~. KILL UANIF~D SIZe- RATING 2'- 5000 4. CHOKE: ~ANIFO~ SIZE - RATING 3"- 5~0 FROM MUD REMOTE PRESSURE GAGE SENSOR ~ HYDRAULIC CONTROLLED j REMOTE OPERATED DRILLIN$ SPOOL HYDRAULIC CONTROLLED REWROTE OPERATED -- REMOTE PRESSURE GAGE SENSOR :~ CHOKE ADJUSTABLE ADJUSTABLE MANIFOLD ! I d h CHOKE REMOTE --,= TO SHAL~ SHAKER BLEED LINE TO PIT TO ATMOSPHERIC MUD/GAS SEPARATOR CHOKE 8 KILL MANIFOLDS FOR ci~/8'~ 8 7" OD CASING BOP STACK BOP I,IANIFOLD LAYOUT- CONOCO, INC. : CONOCO, INC. MILNE POINT UNIT DIVERTER STACK FOR 13 3/8' CONDUCTOR ~0' IELL #IPPLE _ :- 1'0° APl ~000 pi, Ar~NuL~R PRCV[i, dTCIII ~'~'~ . OIYERTCR QUICK CONNECT ASSEMBLY I} 3/1' C~SIhG .-~ · ' ;;.:.. ~: ~' '~ . ..~ . ':'.~.~ :.-..- ~.~ ./ 1. ~e hydraulic control syst~ will ~ in a~rda~e wi'th API specifications a~ ~ r~uirements. a. The HCR valve will open ~en the preventer closes. A single 10a relief line will run off of the drilling s~ol HCR valve and will have a targeted downsteeam tee for downwind dive--ion. Valves on ~th' sides of the t~ will be full opening a~ linked together to enable one to always be o~n aM the other to ~ closed. / I/'~"~ FROM SALAMANC£R$ .® ._5: L------' L,~...~ ..... I_. HOLE FILL TANK I MUD TROUGH MUD CLEANER PUMPS w A T ~..R PUMP HCLE FILL MiX CH ~-;~GE CHARGE Pb,¥,P 2 P~k'P I PUMP 2 P'noJ(cr R~G 22' £ 12GO r, 8: ICL~O FLOW SHEET ~._____.~:.. ,. AXELSEN INDUSTPJES LTD. EDMONTON, AL.~ERTA PHONE (4~3) 465.9242 ¼ _t,_,'-: ~,,:,4':" ,47~-o~ __. AGITATO.q -"~/I--- HuT rE,FLY VALVE ~ GATE VALVE ,~.(:~ MUD GUN I:~-,.'~.'- PSv SUCTION VALVE $UCTICN CR DISCHARGE ( NO VALVE ) TIME ESTIMATE J-4 A. De Ee F. G. He Ie F. Rig up Drill Surface Hole Run Casing and Cement Drill Out and Test Drill Production Hole Log Open Hole Condition, POOH, L. DP. Run Production Casing Cement Production Casing Move Rig Hours 10 57.6 36 112.8 36 20 16 10 10 Days 0.42 2.4 1.5 0.33 4.7 1.5 0.83 0.67 0.42 0.42 Cum. days 0.42 2.82 4.32 4.25 8.95 10.45 11.28 11.95 12.37 12.79 TOTALS 316.4 12.79 12.79 MILNE POINT INIT WELL :',~'~., ,:"] C; 2.0 0 4.0 0 6.0 0 8.0 0 10.0 0 1 '2.0 O i, 4.0 0 ! 6.0 0 18. O 0 R ! G DAY S CONOCO, !nc. Pad J, Well No~ 4 MI Ine Point Unit, Rev leed Propoeal North Slope, Aleeka 1000_ 2000 _ 3000. 4000 _ 5000 _ 0 RKB ELEVATION~' KOP TVD=500 TMD=500 DEP=O 3 , 9 15 21 BUILD 3 DEl3 ;~? PER loo ~'T MAX l HUM ANGLE :n 57 DEG 17 HI N EOB TVD=2107 TMD=2410 DEP=878 '~~ CSG; PT TVD=2500 TMD=31:37 DEP=1490 $?'"~ BEGIN ANGLE DROP TVD=3219 TMD=4467 DEP=2609 -'Si "% K SNDS TVD=3348 THD=4687 DEP=2786 DROP 3 DE~ 45 pDERORPiiooDFE~ 4540 ~ TARGET ! FI SNDS TVD--3595 TFID=5043 DEP=3040 TD / 7" LINER TARGET ANGLE TVD=4297 THD=5955 DEP=3626 40 DEG I I I I 1 000 2000 :3000 4000 t: VERTICAL SECTION HORI ZONT^L PROJECT I ON SCALE 1 IN. = 1000 FEET CONOCO. I~,c. Pad J. We I I No = 4 Rev I sed P~opoea ! MI I ne 13o Int Un I ~:. Noeth SI ope, Al ael~a SURFACE LOCAT[ON~ 2787' FNL. 330Z' FEL SEC. 28. T13N. RtOE z 1000 1000 2000 3000 WEST-EAST 1 000 0 1 000 2000 I I I 3000 I SURFACE TD LOCATION~ 4986' FNL, 424' FEL SEC. 28. T13N, RIOE S 52 DEG '~: 3040' CTO 40 MTN E TARGET) TARGET / M SNDS TVD=3598 TMD=5043 DEP=3040 SOUTH 184.3 EAST 2417 TARGET LOCAT[ON~ 4.630' FNL. 890' FEL SEC. 28. T13N. RI OE 2550 _ 2600 _ 2650 _ 2700 _ 275 _ 2800 _ 2850 _ 2900 _ 2950 _ :3500 3450 3;400 3:350 I I I I ! ! ~' ~roo · 500 50O TOO · ~0~00 33u~ 3250 3200 I I I 1 O0 _ 255~ I I j _ 260C I ~/I- 265( _ 270¢. _ 275r 280C 'i i 3500 :3450 3400 1100 ~',900 1 3O0 3350 I 3300 I 'tjoo I I :3250 '1 :3200 _ 285( _ 2900 _ 2950 CHECK LIST FOR NEW WELL PERMITS Company ..~.~'~:"~'-(~ Lease & Well No. NO £?c .......................................... -- (2) Loc 2. Is well to' be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4 Is well located proper distance from'other wells .................... 5 Is sufficient undedicated acreage available in this pool ............ 6 Is well to be deviated and is we!!bore plat included ................ 7 Is operator the only affected party ......... i ....................... //~Z.~7-~-?~ 8 Can permit be approved before fifteen-day wait ....... ' ............... (8) (3)Admi~ ~C 7~-~ 9. Does operator have a bond in force .................................. ~9 thru i3)' 10. Is a conservation order needed ...................................... ~,~~~ 7-~- ~ 11. Is administrative approval needed ................................... (10 and 13) 12. Is the lease number appropriate ..................................... ~--- 13. Does the well have a unique name and number ......................... (14 thru 22) 14. Is cdnductor string provided ........................................ ~ . 15. Will surface casing protect all zones reasonably expected to sez~e as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover ail known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burs:.. Is this well to be kicked off from an ezis=ing wellbore ............. .~ Is old we!lbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ (23 thru 28) 16. I7. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is a dive:re: system required ....................................... Is the drilling fluid program schematic and list of equipment adequate,,/~ Are necessary diagrmm~ and descriptions of dive:re: and BOPE attached.~ Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/AP! RP-53 (May 84) .................. Is the presence of H2S gas probable ............................. ~... (29 thru 31) Geology: Engineering: DW~~-----LCS BEW rev: 01/30/89 6.011. · For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential ore:pressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. ~ Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , · 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. A[,ASKA COMPUTING CENTER ~mmmmmmm~mm~mmmmm~mm~m~m~mmmm~ SCHLUMBERGER ~m~mmmemmemmmmmmmemmmmm~mmeem* ORiGiNAL COMPANY NAME : CONOCCI INC~ WEl, b NAME " : MIbNE"POIN~ UNIT FIELD NAME : SCHRADER BLUFF 8OROUGH : NORTH $50PE STATE : ALASKA API NUMBER : 50-029-22073-00 REFERENCE NO : 74276 RECEIVED MAY 0 5 ~99& IS Tar.~e verification Llsting .-,hlU~ber,,~er ~laska Computing Cent. er 25-jAN-1991 15:14 **** REEL HEADER **** SFRVICF NAME : EDIT DnTE : 91101/25 ORIGI~ : FLIC REEL ~E : 74276 COnTINUATIOn! ~ : , PREVIOUS COMMENT ~ CONOCO INC.,SChRADER BLUFF,MILNE POINT UNIT J-4,50-oPg-22073-O0 **** TAPE HEADER **** SFRvlC~ NA~E : EDIT DATE : 91/01/25 O~ICI~ : FLIC C~MT!NUATION # : 1 P~EVI~U$ TAPE : Cm~Eb!T : CONOCO INC.,SCHRADER BLUFF,~ILNE POINT UNIT J-4,50-029-22073-00 **** FILE !!EADER **** FI[.,~. NA,~4E : EDIT ,001 SFRVJCE : FLIC VY~$~O~-.~ : 001An6 [)Aff'F ~ 91/01/25 ~A.X REC 5IZ~ : 1096 F[LW TYPE : ~,~S~ FILE ******************************************************************************* ******************************************************************************* ** ** ** SCHLUMBERGER WELL SERVICES ** ** ** ******************************************************************************* ******************************************************************************* CONPA~Y ~}ANE: CONOC~ INC, NFl,L: ~ILNE POINT UNIT J-4 ~ELD: SCHRADER BLUFF BOROU~N: MORTH SLOPE APl U[.!!~BER: 50-0~9-22073-00 2787' F~I, & 3307' FEb TOWNSHIP: IBN RANGE: IOE PE!~A~}E~IT DATUN: ~$L ELEVATION: 0 bag ~EASURED FRO~ RgB 70.2 ABOVE PERMANENT DATUN h].umberqer ALaska Compt]tinq Centex' 25-jAN-199! 15:14 PAGE~ E~-,EV~TION8 KB: 70.2 DATE LOGGE~): 3!-DEC-9I T~ L~]GGER: 2411 DFt 68.7 GL: 35,2 BIT SIZE !: 12 !14" TYPE FLUID IN }lObE: SPUD ~UD DENSITY: 9.6 PH: 9 MUD RESISTIVITY: F!LTR~TE RESISTIVITY: ~!~D CAKE RESISTIVITY: VISCOSITY~ 52 FLUID LOSS: 7 6,88 a 68 3,6 ~ 68 4.54 68 CIRCULATION ENDED': 02~0 DEC 31 LOGGER 0~ BOTTOM: 08:45 DEC 31 ~AX!Nt.I~ TEMP RECORDED: 66 [~O(;G!NG DISTRICT: LOGGING ENGINEER: ~ITNESS: PRUDHOE BAY D,.WARNER D, MUUNTJOY TOOl.., NUmBFRS: NL~-BC 1338 SGC-JC 3109 8GC-5 858 RGM-AA 1722 BGS-A 875 REMARKS: TWO 3" STANDOFFS WERE USED ON THE TOOL STRING, OPERATORS: H, CALLEN/V.. BROPHY D~TE JOB STARTED: 24-JAN-91 ***************************************************************************** DATE bOGGED: 03-jAN-9! R~N ~!.3~SER: .TWO TD DRILLER: 6100 TD LOGGER: 6101 BIT SIZE I: 8,5 TYPE FLUID IN HOLE: LOW sOLIDS DENSITY~ 9,199999 VISCOSITY: 44 PH: 9,5 FLUID LOSS: 6.2 ~D ~ESISTIVITY~ 2,52 0 67 S Tape Verification ListinQ ~hlUm~erqer Alaska Computin~ Center 25-JAN-1991 15:14 FILTRATE RESISTIVITY: mUD CAKE PESISTIVITY: 2.64 2.38 m~ 67 067 TIe~.E CI~C[~LATION ENDED: 23:00 LOGGING DISTRICT: LOGGING PRUDHOE BAY T, WEST D. ULDRICH / D, MOUNTjOY AN~ AA 724 ~GD 739 [ORS 4969 TCC A 123 NGC 1934 NSC 793 PGGD 868 DIC 15 RAN FO[JR 3" STANDOFFS ON THE TOOL TO CENTRALIZE. DaTE JOB STARTEDI 24-JAN-91 JOB ~EFE~ENCE MO: 74276 [.,DP/ANA: R. 8IN~S PAGE~ ****************************************************************************** FI!.,~ - EDIT.O0! COHOCO INC. SCHRADER BLUFF KI!.,NE POINT UNIT J-4 50-029-22073-00 RUN TWO DTE/bDT/NGT/CNb & RUN ONE BGT ~ERGED PHASOR PROCESSING INCLUDED DATA SAMPLED EVERY -,5000 FEET DATa TOOL EXTENSION TOOL TYPE USED NAME DIT-E ,DTE OIT-E .PHA LOT .bDT CNT-A/D/H ,CNb NGT ,NGT 6CT ,BGT PHASOR DUAL INDUCTION SFb PHASOR PROCESSED DATA LITHO DENSITY COMPENSATED NEUTRON NATURAL GAMMA SPECTROSCOPY BOREHOLE GEOMETRY TOOL ****************************************************************************** $ rape. ',terif~catlon Llstinc~ 25-JAN-1991 15:!4 PAGE: 4 ~hl,.~mberqer ^los~a ComDuttnq Center ,- TUNI VALU DEFI CN CONOCO INC, Company Name SCHRADER BLUFF MILNE POINT UNIT d-4 50-029-22073-00 2787' FNL & 3307' FEb 28 RIOE NORTH S~OPE ALASKA USA 'U D~ O, RK.B 70,2 70.2 68,7 610 2914. LOW SOLIDS 9,199999 9'5 4~ 2~52 6~I 0 23 0~ -999,25 / D. MOUNTjOY Field Name ~ell Name AP1 Serial Number Field l, ocatton Section Township Range Countv State or Province Nation Latitude Longitude Witness' Name Service.Order ~umber Permanent datum Elevation of Perm, Datum boq Measured From .ABOVE PERMANENT DATUM I 8 shin~ Elevation of Kelr[cKu Elevation of Der FlOor Elevation of Ground Level Total Depth - Driller Total Depth - begger Bottom bog Interval To? boq Interval Dr~ltfi~ Fluid Type Drl lind Fluid Density Drill~n~ Fluid Ph Drilling FlUid Viscosity DrilliOd Flui, d Loss " ResistiVity of Mud Sample Mud, Sample TemPerature' Resistivity of mud filtrate s Mud. ~ ltrafeFi Sample Temperatu Resistivity of Mud CaKe SamPl Mud Cake Sample Temperature Time Circulation Stop,ed Surface Temperature Bottom Hole Temperature $ Tape verification Listing 'hlumber~er AlasKa Computin~ Center 25-jAN-199! 15:14 TAEI.!E TYPE : CURV Death Channel Name SF5 Resistivity [uDaveraged) ~edlum Induction Stamdard Processed Resistivity Deep Inductio~ Standard Processed Resistivity Spontaneous Potential MEDII~M INDUCTION ENHANCED RESOLUTION PHA$OR RESISTIVITY DEEP INDUCTION ENHANCED RESOLUTION PHA$OR RESISTIVITY INDUCTION DEEP PHASOR RESISTIVITY INDUCTION MEDIUM PHASOR RESISTIVITY Induction Calibrated Freauenc¥ IDOF DEEP INDUCTION Q[IAbI'TY FACTOD IMOF NED !~DUCTION DUALITY FACTOR INDUCTIOn; DEEP PHASOR CONDUCTIVITY INDUCTI(3~; ~EDIUM PHASOR CONDUCTIVITY Deed Induction Peal Intermediate Conductivity ~ee¢ Indtlction Ouad Intermediato Conductivity ediu~ !nductton Real Intermediate Conductiv tY Spectroscopy Gamma-Ra~ Com~uted GR ~rom Thor um, Uranium, Potassium Tension MUd Temperature MUD ~eslstivtt¥ Head Tension Density Porosity Bulk Density De~t~ RHO Photoe]ectric Factor Ou~lltv control of lon~ spacin~ ~or bDT OBaltt9 control oD short sDacin~ for bDT l.,on~ SP~cln~ ~omDuted Count Rate (Lb+LU/2) IonQ UD er i- W~ndow Count Rate (LUI+LU2) Lo~ bo~er Window Count Rate Lttholog window Count Rate Short Soactn~ I window Count Rate Short Spacin~ ~ Window Count Rate bon~ SpacinQ High VoltaQe Output S~ort SDaci6~ High Volt~ge Loop OUtpot Short Spaci. n~ 1 Density bon~ suacin9 RHOB ~Oncorrected) t.,onq l.J~oer ~HflB Cali~er' S~ect. roscopV Gamma-Ray Computed GR from T~orium, Uranium, Potassium Tension ~ud Temperature ~,ij~ Resistivity Head TeDsion ~eutron PorosJ~tv Raw '['Dermal weutron Ratio · hermal heutron Poroslt~ Calibrated Thermal Neut oD Ratio PAGEI lumber(:er Alaska Computin<~ Center 25-JAN-199! 15514 DEFI ~PO~ ~eutro~ Porosity output f'tom an APplication Program RCNT RC~T RCF~ RCFT . CNTC CNTC CFTC CFTC SGR Spectroscopy Gamma-Ray CCR Computed GE from Thorium, Uranium, Potassium CAb? Caliper TFNS Tension ~RES ~UD Resistivity sTEM ~ud Temperature HTEN Head Tensiom SOP Spectroscopy Gamma~Ra~ CGR Computed G~ from T. or Um, Uranium, Potassium T~O~ Thorium POT~ Potassium u~A~ i.]ran~um WiNG Window 1 (,150 w~N~ Window 2 (,5 - 1,'1 MEV) W3~C Window 3 (1,1 - 1,6 ~E¥) W4NC Wlmdow 4 (1,6 - WSN~ wlmdOw 5 (~ - 3 ~EV) TFNS Tension ~TE~ ~ud Temperature ~RES ~UT) Resistivity CS Cable Speed HTE~ Head Tenslon GR Gamma Pav C1 Caliper ! - 3 C~ Caliper 2 - 4 TENS Tensto~ PAGE: DATA FORe, AT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ~YPE ~EPR CODE V~hUE I 66 0 2 66 0 3 73 328 4 66 5 66 6 73 ~ 65 8 68 0,5 9 65 FT 1~ 66 3 12 68 S Tane verification Llstl, mq hlUmberoer AlasKa Computing Center 25-JAN-1991 15:14 PAGE: TYPE REPR CODE VALUE 13 66 0 ! 4 65 FT 15 66 68 16 66 1 0 66 0 ............. ';'ii'; .... ?'T 548186 O0 000 O0 0I.{~ 548186 O0 000 O0 OH~ 548186 O0 000 O0 OH~. 548186 O0 000 O0 ~V 548186 O0 000 O0 OHMM 548~86 00 000 O0 OM~M 548186 O0 000 00 OH~M 548186 00 000 00 OHM~ 548186 O0 000 O0 HZ 548186 O0 000 O0 548~86 O0 000 O0 548186 00 000 O0 ~}.tO 548186 O0 000 O0 ~}{0 548186 O0 000 O0 gMHO 5481~6 O0 000 O0 ~HO 54~186 O0 000 O0 ~0 548186 O0 000 O0 (;APl 548186 O0 000 O0 GAP! 548186 O0 000 O0 [,~ 548186 O0 000 O0 DEGF 548186 O0 000 O0 O~N~ 548186 O0 000 O0 LB 548186 O0 000 O0 PU 548186 O0 000 O0 G/C3 548186 O0 000 O0 G/C3 548186 O0 000 O0 548186 O0 000 O0 548186 O0 000 O0 ~48186 O0 000 O0 CPS 548186 O0 000 O0 CPS 548186 00 000 O0 CPS 548186 O0 000 O0 CPS 548186 O0 000 O0 CPS 548186 O0 000 O0 CPS 548186 O0 000 O0 V 548186 O0 000 00 V 548186 O0 000 O0 G/C3 548186 O0 000 O0 G/C3 548186 O0 000 O0 G/C3 549]86 O0 000 O0 DEPT SFLU DTE I[.,M DTE ILD DTE SP DTE IM~ PHA lO~ PH~ IDP[4 DTBi I~PW DYE IFDE DTE IDOF DTE CIDP DTE CIMP DT~ I!RD DTE IIXD DT£ II~ DTE SG~ DTE CG~ DTE TE~8 MTE~ DTE ~RES DTE HTE~ DTE DPHI bDT ~OF LDT D~Ha LDT PEF LDT OL$ bDT DSS LOT L$ bDT LII LDT LL LOT SSi LDT 8S2 LOT DSHV 88NV bDT 81~M LDT LS~W LOT [,U~" bDT I P b NUMB N!.I~B SiZE REPR PROCESS SS M~D N~MB SA.P £D~M CODE (HEX) 0 I 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 I 1 1 4 68 0000000000 0 I 1 1 4 68 0000000000 0 I 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 I 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 i I 1 4 68 0000000000 0 1 1 I 4 68 0000000000 0 I 1 1 4 68 0000000000 0 1 I 1 4 68 0000000000 0 I 1 I 4 68 0000000000 0 I 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 I 1 1 4 68 0000000000 0 1 1 I 4 68 0000000000 0 1 I 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 I I 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 I I 1 4 68 0000000000 0 1 I 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 I 1 I 4 68 0000000000 0 ! 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 i ! I 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 i 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1. 1 1 4 68 0000000000 0 ! 1 1 4 68 0000000000 ~ Ta~e verificat, lon l,lstinq 'hlum~erner Alaska Computing Center 25-dAN-1991 15:14 NAME SERV -UNIT SERVICE API AP! API API FlbE NUMB NUMB SIZE REPR PROCESS ~n ORDER ~ LOG TYPE CbASS MOD NUMB SAMP ELE~ CODE (HEX) '~ -------------------------------------------------------------------------------~ I~ 8 0 I 68 0000000000 O0 000 00 0 1 I 1 4 68 0000000000 SGR !.,DT GAP! 548186 CGR LOT GAPI 548186 00 TENS LOT I.,~ 548186 O0 ~TE~ LDT DEGF 548186 00 MRE$ LDT OH~ 548186 O0 HTEN LDT [,B 548186 00 NPH] CNL Pi{ 548186 00 RTNP CN[, 548186 00 TNPH CN!, Pt! 548186 00 TNRA C~L 548186 O0 NPOR CNL PI! 548186 O0 RCNT CNL CPS 548186 O0 RCFT CNL CPS 548186 O0 NTC CN[, CPS 548186 O0 FTC CNL CPS 548186 SGR C~L GAPI 548186 O0 C~R_ CNL (;APl 548186 O0 CALl CNL I~ 548186 O0 TENS CNL LB 548186 00 MRES C~b OHMM 548186 O0 ~TE~ C~![,, DEGF 548186 00 HTE~ CNb LB 548186 00 SGR NGT GAPI 548186 O0 CGR NGT GAPI 548186 O0 TNOP NGT PP~ 548186 O0 POTA NGT P!,] 548186 00 URAN NGT PP~ 548186 O0 WiNG NGT CPS 548186 O0 W~NG NGT CPS 548186 O0 W]NG NGT CPS 548186 O0 W4NC NGT CPS 548~86 O0 W5~G NGT CPS 548186 00 TENS NGT [.[~ 548186 00 MTE~ NGT DEGF 548186 00 ~RE$ ~!GT O}'{H~ 548186 O0 CS NGT F/HR 548186 O0 HTEN ~GT LB 548186 O0 GR BGT GAPI 548186 O0 Cl. ~GT I~ 548186 O0 C2 B~T tN 548186 O0 TENS ~GT b~ 548186 00 000 00 0 1 1 1 4 68 0000000000 000 00 0 I 1 1 4 68 0000000000 000 00 0 1 1 ! 4 68 0000000000 000 00 0 ! I 1 4 68 0000000000 000 00 0 1 1 ! 4 68 0000000000 000 00 0 1 I I 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 000 00 0 1 1 I . 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 000 00 0 I 1 1 4 68 0000000000 000 00 0 i I I 4 68 0000000000 000 O0 0 ! t 1 4 68 0000000000 000 00 0 I 1 1 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 000 00 0 1 1 ! 4 68 0000000000 000 00 0 1 1 I 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 000 00 0 I 1 1 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 000 00 0 I 1 1 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 000 00 0 1 1 I 4 68 0000000000 000 00 0 ~ 1 i 4 68 0000000000 000 00 0 1 1 I 4 68 0000000000 000 00 0 ! 1 I 4 68 0O00000000 000 O0 0 1 1 I 4 68 0000000000 000 00 0 I 1 1 4 68 0000000000 000 00 0 I 1 I 4 68 0000000000 000 00 0 i 1 ! 4 68 0000000000 000 00 0 1 I 1 4 68 0000000000 000 00 0 1 1 1~ 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 000 00 0 1 1 i 4 68 0000000000 000 00 0 i 1 I 4 68 0000000000 000 00 0 1. 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 00 0 I 1 1 4 68 0000000000 ** DATA ** D~PT. 6164.000 SFbU.DTE 2.604 IbM,DTE SP.D'r~ -24.188 IMER,PHA 2,752 IDERiPHA I~PH,DTE 2.752 IFRE.DTE 20:0 O0 IDOF,DTE CIOP ~)"' ,~..~E 364,000 CIMP,DT~ 363 250 IIRD,DTK 2.742 ILD.DTE 2 752 IDPH.DTE 3i000 IMOF.DTE 304 250 IIXD.DTE 2 719 2:746 2.000 46,,906 S Tame verification i...istlng hlumberqer Alaska Computing Center I!R~.DTE 3:]9,000 MTE'.DTE 90.500 RHOB,LDT 2'169 OSS,LDT 0,021 LITe.bDT 174,125 SSH¥,LDT !355,000 CALI,LDT 3,193 MTE~.LDT gO,500 RTNP.CNL 3 656 RC~T.C~L 2202i610 SG~,CN[., 96 288 ~ES,CNL ! 894 CG~.NGT 0,000 WlNC,NGT 319,861 ~5NG,NGT 4,619 CS,NGT 6416,000 C2.BGT -909,250 SGR,DTE ~RE$,DTE DRHO,bDT kS,bDT SSI,bDT SIRH,bDT SGR,LDT ~RE$,LDT TNPH,CNL RCFT CNL CGR CNL MTEP CN5 THOR NGT W2NG NGT TENS,NGT MTEN,NGT TENS,BGT DEPT. 6100,000 8P,DTE -22 063 I,PN,DT~ 2~752 CTDP,DTE 363,500 IIR~.DTE 339,000 MTE~.DTE 90,500 R~OB.LDT 2.169 ~S$.LDT 0,021 LIT~.LDT 174"i25 SS~V,LOT 1356.000 CALl,bDT 3.!93 ~TE~.LDT 90,500 ~TNP.C~L 3.656 RCN~,CN[., 2202,6~0 SG~.CNL 96,28~ ~[:$.C~L 1,894 CG~.NGT !8,512 .NGT ~.779~000 C2.BGT -999,250 SF.bU,DTE I~ER,PHA IFRE.DTE CIMP,DTE MRE DTE DRHO bDT SSI.LDT S1RH.DDT SGR,LDT MRES,LDT TNPH.CNL RCFT,C~D CGR CNL ~TE~:CNL THOR.NGT W2NG.NGT TENS'NGT HTEN NGT TENS~BGT DEPT. 6000.000 SP.I)TF -24.359 I"FM.DT~ 3.252 CIDP.D?E 306,500 IIR~.DTE 2~6.250 ~TE~.DTE 90.68~ R~O~.LDT 2,336 OSS.I. DT 0,021 I.,!T~.bDT 105,813 SSHV.LDT 1356,000 C~LI.LDT 9,039 gTE~.LDT 90.688 RCNT.CNb SGP.C~iL !00,496 SFLU,DTE IMER P~A IFRE:DTE CIMP,DTE SGR,~TE gRES DTE ORHO:LDT LS,LDT SSI,bDT SIRH,LDT SGR.LDT MRES.,bDT TNPH.CNb RCFT,CML CGR.CNb 25-dAM-1991 151!~[ 96.288 CGR,DTE 1.894 HTE~.DTE 51~!072 PEF,hDT 000 LU,L~T 250 750 $S2,bDT bSRH,hDT 1.938 96,288 CGR,bDT 1,894 HTEN.LDT 41,020 TNRA,CNb 594,599 CNTC,CNL 0 000 CAbI,CNL 90:500 HTEN,CNb 0.000 POT~,MGT 140,878 W3NG,NGT 2470,000 ~TEN,~GT -212,!25 GR,BGT -999,~50 2,604 2 752 2O:OOO 3~3.250 . 4 51~ '072 .000 250,750 1.938 96,~88 1 94 41 021 594 599 18 512 90 500 1.14! 140.878 4345,000 660 500 -999:250 3.137 2~,232 .000 307 250 100~496 1,865 0,010 342,500 217,750 2 287 100~496 1 865 695 4 65.826 IbM,DTE XDER,PHA IDOF,DTE IIRD,DTE CGR.DTE HTEN,DTE PEF,DDT bU,bDT SS2,bDT bSRH,bDT CGR,bDT HTEN,LDT TNRA,CNb CNTC,CNb CALI,CNb HTEN,CNL POTA,NGT W3NG.NGT MTE~,NGT GR,BGT ILM,DTE IDER,PHA IDOF,DTE IIRD,DTE CGR,DTE HTEN,DTE PEF,bDT bU,LDT SS2,LDT LSRH,LDT CGR bDT HTEN:GDT TNRA,CNL CNTC,CNL CAbI,CNb 0 000 0 000 481 250 364 250 ~ 096 0 000 -212 125 3 437 2186 711 3!193 -212 125 0 000 50i808 90 500 -999 250 2 742 2 754 0 000 304 250 18 512 660 500 2 768 481 250 364 250 2 096 18 512 660 500 3 437 2186 736 3 193 660 500 0.910 50.808 90 500 -999:~50 3 260 3i238 0 000 260 750 65.826 707.000 2,922 321.250 305.250 2.326 65.826 707.000 3.078 6.423 2229.039 TENS,DTE DPHI,LDT OhS,bDT bt.,.bDT LSHV,LDT LURH LDT TgN8:bDT NPHI*CNL NPOR.CNL CFTC,CNb TENS CNL SGR:NGT URAN.NGT W4NG.NGT ~RES,NGT C1.BGT ILD,DTE IDPH.DTE !MOF.DTE IIXD.DTE TENS.DTE DPHI,LDT OhS.bDT Lb.bDT LSHV,LDT LURH.bDT TENS.bDT NPHI,CNL NPOR,CNL CFTC.CNL TEM$,CNb SGR.NGT URAN.NGT W4NG.NGT MRES.NGT C~.BGT tbD.DTE IDPH,DTE I~QF.DTE IIXD DTE TENS:DTE DPHI'LDT OhS,bDT bb,bDT LSHV,LDT bURH,LDT 'rENS,LDT NPHI.CNb NPOR,CNL CFTC CNL TENS:CML PAGE: 2470 000 29 140 -0 021 276 500 1705 000 2 098 2470 000 48 496 41,020 644,765 Z .ooo ,288 0,000 19,630 1 894 -999:250 2 719 0.000 46 906 29,i40 2~0 021 .6~500 170~'000 ,098 4345'000 48,496 41,021 644,765 4345,000 96,288 10,569 ~9,630 1,894 '999,250 3,229 3,260 0,000 33,344 4410,000 19,007 0,006 181.750 1706,000 2 336 4410 000 35 1.17 33 375 716 878 4410.000 AlaSka Computin~ Center iIP~.DTE 139.625 SGR.DTE ~TE"..DTE . 90.563 MRES, DTE RUOS.LDT 2.27! DRHO.LDT OSS.LDT 0.010 L$,LDT [.!TW.LDT 113.250 SSI.LOT SS}!V.LDT ~356,000 S1RH.LDT CALI.L~T 9.2~7 8~R.LDT MTE".LDT 90.563 MRES,LDT RTN~.CNL 3.851 TNPH,CNL RCNT.CNL 2~68.741 RCFT.CNL SG~.CNL 80.300 CGR.CNh ~E$.CNL 1.886 MTEM.CNU CGR.~GT 52~271 THOR.NGT WJNG.NGT 247,170 W2NG.NGT WLNC.NGT 5,660 TENS.NGT CS.MGT 1718,000 MTEN.NGT C2.~GT -999.250 TEN$.BGT D~P?. 5600,000 SFLU.DTE SP.DTE -35,031 IMER.PHA I~PH.DTE 5.797 IFRE.DTE C!OP.DTE !53.125 CIMP.DTE IIR~.DTE 163.000 SGR.DTE ~TE~.DT~ 89.813 MR£S.DTE R~{OB,LDT 2,343 DRHO,LDT OSS.LOT 0.024 LS.LDT b!TH.LDT 102.063 SS~.LDT ~ E~,b!)T 89.a13 MRE LD. RTNP,CNL 3.662 TNPH,CNb RCNT.C~L 2!67,9~3 RCFT.CNL SGR.CNL 70,168 CGR.CNL ~RES.CN5 1,'910 MTEM CNL CG..: NGT 63 323 THOR.NG~ w1. NG,NGT 233 ~19 W2NG,NGT W5~G.~GT "!0:~77 TENS.NGT CS NGT ~700,000 HTEN,NGT C2~BGT 999.250 TEN$.BGT DEPT. 5500,000 SFbU.DTE SP.OTE -39.813 IHER,PHA I~P~.DT.E 4,973 IFRE'DTE CIDP.DTE 2!3.875 CIMP.DTE IIR~. DTE 189,750 SGR. DTE ~'~ DTF 89 125 ~RES DTE RNOB,LDT 2,353 DRHO,LDT OSS. LOT O. 025 LS. LDT LITe, L~T ~ Ol, 875 SSi. LOT SSHV.LDT 1357.000 S1RH bDT CAL~, LOT 8,977 SGR', LOT MTE".LDT 89.125 MRES, bDT RTN~.Ci~!b 3.462 TNPH.CNL RC~3T.CNL 2183.648 RCFT.CNL SGP.C~.~b 78. 456 CGR. CNL ZL-J~N-1991 15:14 80,300 1,886 '0,003 374,250 213,375 2,285 80,300 1,886 40,600 599,659 52.271 90,563 126 708 421~ 585 000 713 500 -999 250 5.078 5'383 20,000 72,375 170,168 1,910 ,01033 .500 2i7,625 2,291 70,168 ,9104 ,238 569,130 63.323 89.813 8*385 . 0 4,930 5 094 20 000 2O 1 936 0 010 332 750 217 000 2.301 78.456 !,936 38,816 607,29~ 56,358 CGR,DTE HTEN,DTE PEF,LDT LU,LDT $$2,LDT LSRH,LDT CGR.bDT HTEN,LDT TNRA,CNL CNTCeCNb CALI.CNL HTEN.CNb POTA,NGT W3NG,NGT MTE~,NGT GR,BGT IbM, IDER. IOOF, IIRD CGR: HTEN, PEF, Lb. 'SS2, LSRH, CGR, HTEN, TNRA, CNTC. CALl, HTEN. POTA. W3NG, MTEM, GR' IDER, IOOF' IIRD. CGR, HTEN, PEF* 5U, $S2., LSRH, CGR, HTEN, TNRA, CNTC. CALI. DTE PHA DTE DTE DTE DTE .[..,bT bDT bDT LOT bDT LOT CNb CN'b CN L CNL NGT NGT NGT BGT DTE PHA DTE DTE T. D E bDT bDT bDT LOT LOT LOT CNL CNb 52 271 713 500 2 889 348 500 307 250 2 273 52 271 713.500 214 845 227 713 500 1 716 41. 5O9 90 563 '999 250 5.777 5.453 0.000 !31 875 63 323 728 000 3 O49 319 250 303.500 2,332 63.,323 728000 3i445 2122 921 8 8].3 72e:ooo 2 016 44!340 89:813 '999,!250 4.949 5.039 0.000 ~87 625 56 358 796 5O0 3 4 306 ~6 50 301. 750 2:342 56.,358 796.500 3 405 8.977 TENS.DTE DPHI.LDT OLS.LDT Lb.LOT LSH¥,LDT LURH.LDT TENS.LOT NPHI.CNL NPOR.CNL CFTC.CNL TENS.CNL SGR.NGT URAN,NGT W~NG.NGT MRE$.NGT C~.BGT ILD.DTE IDPH.DTE IMOF.DTE iIXD.DTE TENS.DTE DPHI.LDT ODS.bDT LL.LDT LSHV.LDT bURH.LDT TENS.bDT NPHI.CNL NPOR CNL C TC:C b TENS.CN5 SGR.NGT URAN.NGT W4NG.NGT MRES,NGT C~.BGT ILD.DTE IDPH.DTE IMOF.DTE IIXD.DTE TENS.DTE DPHI bDT QLS~I.,DT L.b,LDT LSHV.LDT LURH.LDT TENS.bDT NPMI.CNL NPOR.CNL CFTC.CNL TENS.CNL PAGEI 4215,000 22,947 0.007 200,000 1706.000 2,287 4215.000 42,351 40,422 633,727 4215,000 80,300 3,626 8,491 1'886 -999:250 6,266 6,523 0 000 7 355 4120 000 1~ 628 0 000 178 875 1707 000 2 340 4120,000 42 167 39:606 634,948 4120,000 7§,168 ,769 9,43.4 1,910 '999,250 4,645 4,672 0,000 4065, 0 17 991 0 037 ~79 375 1706 000 2 365 4065 000 41 206 39 149 669 628 4065 000 ll Verification !.,i stlno hlUmberoer .Alaska Co~'~putinq Center DEPT. 5400.000 SFLU.DTE SP.DTE -40.094 IMER.PHA I~PH.DTE 4.586 IFRE.DTE C!DP DTE 2~.6 625 CIMP DTE i~RU:DTE 207:875 SGR:DTE MTE~.DTE 88.750 MRE$.DTE RHOR.LDT 2.315 DRHO,LDT O~S.LDT 0.021 L$,LDT [,!T~.bDT !15.438 S$1.LDT SSHV.bDT ~356,000 SIRH bDT CAI..I.LD? 8.75R SGR:LDT gTEg.b~T 88.750 MRES.LDT RTiqP.C~L 3.305 TMPH.CNb RCNT.CNL 2293.416 RCFT.CNb SG~.Ct~L 86.806 CGR,CNb ~ES.CML !.946 ~TEM,CNL CG~.MGT 66,963 THOR.NGT WlNG.NGT 274.52~ W2NG NGT wSNG,NGT 9,434 TENS:NGT C$.NGT 1716,000 HTEN,NGT C?.BGT -999,250 TEN$.BGT DEPt. 5300.000 SFLU.DTE SP.DTE -76.250 IMER,PHA I~P~.DTF 3,176 IFRE.DTE CIDP.DT~ 304.750 ClMP.DTE IIRM.DTE 290.750 SGR.DTE MTE~.DTE 88.000 ~RES DTE R~Og,I,DT 2,12~ DRHO:LDT OS$.L~T 0.027 b$.LDT L?TH bDT 212.875 S$1 bDT SSHv~LI)T 1.356'000 S1RHiBOT CALI.LDT 9.906 SGR bDT MTE~.LDT 88.000 MRES.LDT RTNR.C~L 3,698 TNPH.CNb RCNT.CML 2269.244 RCFT.CNL SGR.CNL 34,694 CGR.CNL ~RES.CNL 1,963 MTE~,CNL CGR.NGT 15.886 THOR,NGT WI~)~.NGT !15.094 W2NG.NGT W5N'G.NGT 2,830 TENS.NGT CS.NGT 1828.000 HTEN,NGT C~.BGT -999.250 TENS.BGT DFPT. 5200,000 SFbU.DTE SP.DTE -44.125 I~ER.PHA I~PN.DT~ 6.270 IFRE,DTE CIDP.DTE 1.51.500 CIMP.DTE 25-JAN-1991 15114 89,125 HTEN.CML 7.194 POTA.MGT 96.805 W3NG.NGT 4065.000 ~TEM.NGT 796.500 GR.BGT '999.250 - 4.938 4 59O 20i000 2~7 ~75 86 06 1.946 o o06 354i000 216 500 2 285 8 :8o6 1.946 36 219 66 963 88:750 9 267 140 566 4030 000 731 500 -999 250 3.488 3.~07 20. 00 314,750 34.694 1.963 0.037 534 0o0 241~250 3~ '986 .694 . 963 3 ,529 673.684 15,886 88,000 2,210 46.226 3960 000 788:500 -999.250 5,691. 6,273 20,000 159,375 IbM,DTE !DER,PHA IDQF,DTE IIRD,DTE CGR,DTE HTEN.DTE PEF,bDT LU.LDT S$2,LDT LSRH,bDT CGR,LDT HTEN.bDT TNR~:CN5 CNT CNb CAbX,CNb HTEN,CNL POTA,NGT W3NG,NGT MTE~,NGT GR,BGT iLM.DTE IDER'PHA IDOF,DTE IIRD,DTE CGR,DTE HTEN,DTE PEF,LDT LU,bDT SS2,LDT bS.RH,LDT CGR.LDT HTEN,bDT TNRA.CNb CNTC,CNb CALI.CNL MTEN.CNb POTA,NGT W3NG,NGT MTEM,NGT GR,OGT ILM.DTE IDER.PHA IDQF.DTE IIRD.DTE 796.500 1.860 45.11~ 89125 -999~250 4.512 4.598 0,000 187.125 66.963 73 777 331.000 305,000 2'309 66.963 731.500 .3,156 2218,690 8 758 1' ,500 732,034 45.283 88.750 -999.250 3 209 3 115 0 000 253 875 15 886 788 500 2.281 5.750 i o.,oo 2 084 15 886 788 500 3 338 2337 021 9 906 788 5O0 0:480 16,981 88.000 -999.250 6.234 6.586 0.000 131.875 SGR.NGT URAN.NGT W4NG.NGT NRES.NGT CI.BGT ILD.DTE IDPH.DTE IMOF.DTE IIXD.DTE TENS.DTE DPHI.LDT OLS.LDT bL.bDT hSH¥.bDT bURH.LDT TENS.bDT NPHI,CNL NPOR,CN[., CFTC,CNL TENS.CNL SGR,NGT URAN,NGT W4NG'NGT MRES,NGT CI,BGT I'LD.DTE IDPH DTE IMQFiDTE IIXD.DTE TENS.DTE DPHI.bDT OhS.bDT Lb,bDT LSBV,LDT LURH.LDT TENS,bDT NPHI CNL NPOR:CNL CFTC.CNL TENS.CNb SGR.NGT URAN.NGT W4NG.NGT MRES.NGT C1.BGT ILD.DTE IDPH.DTE IgQF.DTE IIXD.DTE PAGE: 12 78.456 2.908 3.759 1 936 -999:250 4.586 4,613 0,000 21,641 4030.000 20.304 0,007 188,375 t705.000 2,318 4030 000 36 964 35 121 718 266 4030 000 86 806 2,916 11.321 1,946 -999.250 3,230 3 277 OiO00 28 969 3960 000 31:949 -0.020 286.000 1705.000 2 082 3960 000 38 569 40 196 711 315 3960 000 34 694 2 417 8.491 1,963 -999~250 6,586 6 594 0:000 9,102 l~ '~s~:; Verification Listing chlumberqer Alaska Computing Center IIRU.DI'E 151.125 SGR.DTE MTE~.DTE · 87,625 MRE$.DTE ~HOB.L[;T 2.277 DRHO.LDT OSS.bDT 0,031 LS,LDT bYT~.LDT 139,250 S$1.LDT SSHV.LDT 1356.000 S1RH.LDT CAb!.I.DT 9.O39 SGR.LDT ~TE~.LOT 87.625 HRES.LDT RTN~.CNL 3.563 TNPH.CNL RCNT.CNL 2361.522 RCFT.CNL $CR,CNb 81.178 CGR,CNL M~$.CNL 1.976 MTEM,CND CG~,NGT 55,650 THOR.NGT WSN¢.NGT 9,036 TEN NGT CS.NGT 1779.000 HTEN,NGT C2,BGT -999,2~0 TEN$,BGT DKPT. 5100.000 SFLU,DTE SP.DTE -54.000 IMER.PHA IMPH.DTE 6,262 IFRE.DTE CIDP.DTE 1.53.625 CIMP.DTE IIR~. DTE _I. 52. 375 SGR,DTE MTEW.. DTE '87 !.25 RHOB:LDT 2:276 DRHO,bDT OSS. bDT O. 001 hS, bDT blTH. bDT 123,813 SSi.bDT SSHV.LDT !356.O00 S1RH. bDT CaboT. bDT 8,64.i SGR .M'I'E~.LDT 87 · 125 MRES~LDT ~T~ CNL 3.161 TNPH:CNL PCMT:CN[.. 2209.891 RCFT.CNL SGR. CNL 73,660 CGR. CML b~RDS. CNb I ,991 MTEM.CNL CGm. ~,(~T 51.553 THOR NGT N1 ~':~.NGT 252.155 W2NG:NGT WSNG. ~G.T ~0,776 TBNS,NGT CS.NGT 1803.000 HTEN,NGT C2.BGT -999,250 TENS.BGT DEPT. 5000,000 SFLU,DTE SP.DTE '50.250 IMER.PHA I~.PH DTE 7,699 IFRE.DTE ClDP:DTM 111.375 CI~P.DTE IIR~.DTE 1.21,563 SGR,D~E gTM~.DTE 86.813 RHO~.bDT 2,289 DRHO,bDT 0SS.LDT 0.017 bS,bDT LITH bDT 123,250 SS~.LDT SSi~V:LDT 1357,000 $1RH,LD~ CALI..I,DT R.867 SGR.bDT MTE~.LOT 86,813 MRES,LDT RTNP.CSb 3,92~ TNPH..CNb RCMT.CN~ 20.43,352 RCFT CNb SG~.C~,'L ~7,690 25-dAN-1991 15:14 81.178 CGR.DTE 55.650 1 976 HTEN,DTE 887.500 0:030 mEF.LDT 2 439 395.500 - ' · LU,SDT 368.250 229.500 SS2,bDT 322.000 2,~62 bSRH,~DT 2.246 81,.78 CGR,LDT 55.650 1.976 HTEN,bDT 887.500 38.057 TNRA,CNb 3.~10 698,197 CNTC.CNL 2312. 38 ~,650 CAbI.C~L 9.039 .625 HTENoCNb 887.500 8.071 POTA.NGT' 1.600 i19.478 W3NG,NGT 27.108 4105,000 MTEM,NGT 87.625 887.500 GR.BGT -999.:250 '999.250 6.2~7 159.6 .73,660 370.750 2~0 625 72 311 .3 660 3~ 991, 194 632 854 51.553 87 125 643 10~ 681 3810 000 850i000 -999'250 6,!60 7.473 2 5 87 690 1.999 0.009 372 500 219 875 ~. 44 9 9 43 704 540 947 68 089 IbM,DTE IDER,PHA IDOF,DTE IIRD.DTE CGR,DTE HTEN,DTE PEF,bDT LU,bDT $$2,LDT LSRH,LDT CGR,bDT HTEN,LDT TNRA CNb C~!TC: CALI,CNb HTE~.CNL POTA.NGT W3NG,NGT MTEM,NGT GR,BGT ILM,DTE IDER,PHA IDOF'DTE IIRD,OTE CGR,DTE MTEN,DTE PEF,LDT LU,DDT 882 bDT CGR.bDT HTEN,bDT TNRA,CML CMTC,CNL CAbI,CNb 6.184 6,531 0 000 134i000 51 55~ 850 000 2 734 342 750 306 500 2 51 553 850.000 3 248 8'641 85O 000 li197 29 095 87..125 -999.~50 7 ,770 0 000 93!688 68 089 755.000 2 643 347:250 312 750 2,279 68.089 755.000 3.467 2063'586 8.867 TENS.DTE DPHI.LDT OhS.bDT LL.LDT bSHV.I. DT LURH.LOT TENS.bDT NPHI.CNL NPOR.CNL CFTC.CNL TENS.CNL SGR.NGT URAN.MGT W4NG.NGT MRES,NGT C1,BGT ILD.DTE IDPH.DTE IMOF.DTE IIXD.DTE TENS.DTE DPHI.LDT OhS.bDT Lb. LDT LSMV.LDT LURH.LDT TENS.bDT NPHI CNL NPOR:CNL CFTC.CNL TEM$.CN[, SGR,~GT URAN.NGT W4NG.NGT ~RES,NGT CI,BGT ILD.DTE IDPH.DTE IMQF,DTE IIXD.DTE TENS.DTE DPHI.bDT QLS,I,DT LL,LDT LSHV.LDT LURH,LDT TENS.bDT NPMI.CNL NPOR CNL CFTC:CNL TENS.CNL PAGEI 4105,000 22.579 0,002 211,500 1705,000 2,254 4105 000 37~525 37.442 718,755 4105,000 81,178 3,370 5 020 1!976 -999 250 6.457 6 504 oiooo 0 250 38 0 000 22 641 0 019 199 375 1705 000 ]81~ 297 000 38 834 36 743 7~9 722 3810,000 73 660 2 964 9 698 1 991 -999 25O 9,039 8,969 0.000 2,900 3640,000 21',893 0 OO6 198 875 1705 000 2 289 3640 000 42 488 44,548 579,382 3640'000 13 '$ TaDe verification Listing ~hlumberger Alaska Computin~ Center M~E~.CN[.~ 1.999 MTEM,CNL CGR.NGT 6R.089 THOR.NGT w~NG NGT 295.181 W2NG.NGT WSNG~NQT 15,060 TEN$.NGT CS.NGT 1.829,000 HTEN NGT C2,mGT -999.250 TENS:BGT DEPT. 4900.000 SFLU.I)TE SP.DTE -46.031 IMER.PHA IPPH.DTE 5.344 IFRE.DTE CIDP.DTE 171.750 C!MP.DTE IIR~.DTE 176.500 SGR.DTE ~TEM.DTE 86.250 MRE$.DTE RMOB.LDT 2.2~3 DRHO.LDT OSS.LDT 0.003 LS.bDT bITS.LOT 128.375 SS1,LDT ss~V.LDT 1356'000 SI. RH'LDT C~LI.LDT 9,01.6 SGR.LDT ~TE~.L[)T R6.250 ~RES bDT RCNT,CNt, 1.945.819 RCFT'CNL SGP.CNL 88,895 CGR,CNb MRES.CNL 2.018 MTEM.CNL NGT CGm NG'r 59,435 THOR. ~T ~.~_~.N(;T 271.169 W2NG, WSNG.NGT 6.045 TENS.~T CS.NGT 1832,000 HTEM.NGT C~.BGT -999.250 TEN$.BGT DEPT. 4800.000 SFbU.DTE SP.DTE -61.906 IMER,PHA IMPH.DTE 23.578 IFRE,DTE CIDP.DTE 43,i88 CIMP.DTE IIR~.DTE 42.500 SGR,DTE MTE~.DTE 85.750 ~RE$.DTE RHO~.LDT 2.16~ DRHO bDT OSS.LOT 0,0~O L$:LDT LIT~4.LDT 167.500 SSI.bDT SSUV.L[)T 1356.000 SIRH bDT CAL!.LDT 9,297 SGR:LDT ~TE~.I.D? 85.750 MRES.LDT RT~R.CN[~ 3.466 TNPH,CNL RCNT,CNL 2467.264 RCFT CN[. 'SG~.CUL 46.186 CGR:CNb ~ES.CNL 2.035 STEM.CML CGR.NGT 38.471 THOR.NGT WI~'~G.~'GT 148 594 W2NG.NGT WSNG.N(;T '"5:020 TENM.NGT CS.NGT 1840.000 HTEN.NGT C~.BGT -999.250 TEMS.BGT DFPT. 4700.000 SFLU.D?E SP.OTE -47.000 IMER.PHA IMPH.DTE 5,660 IFRE DTE CT~P.DTE !.60.375 CI~P:DTE 25-JAN-199! 15:14 86,813 I~ 593 ~6 0 755 000 -999 250 4.531 5 305 20i000 87'000 !88 895 2.018 8 250 215 875 2 ~ 2 018 45 950 59 5 86 ~50 8 888 148 85 3605 [00 8!7 000 -999 250 26 281 24 109 20 000 42 375 46 186 2.035 -0.001 46~.500 220.875 2 166 3~ 035 044 734 7bO 38 471 85 75O 5 902 6~.~65 330 ,000 740.000 -999.250 4.887 5.629 20.000 176.500 HTEN.CNb POTA.NGT W3NG,NGT NTEM.NGT GR.BGT ILM.DTE IDER,PHA IDQF.DTE IIRD.DTE CGR.DTE HTEN.DTE PEF,GDT LU,LDT SS2.LDT bSRH bDT CGR:LDT HTEN.bDT TNRA.CNL CNTC,CNL CALI,CNb HTEN.CNb POTA,NGT W3NG,NGT ~TEM,NGT GR.BGT ILM,DTE XDER'PHA IDOF'DTE IXRD,DTE CGR,DTE HTEN,DTE PEF,LDT LU*LDT S$2,LDT bSRH,bDT CGR.bDT HTEN.bDT TNRA,CNL CNTC.CNL CAbI,CNL HTEN,CNL POTA.NGT W3NG,NGT MTEM,NGT GR,BGT IbM,DTE IDER,PHA IDQF,DTE IIRD,DTE 755.000 1 538 . 34.137 86.81.3 -999.250 5.328 5.684 0.000 148.750 59.435 817.000 2 896 3s :ooo 316'750 2.225 59.435 817.000 3.877 193~.339 .016 817.000 1.643 44,355 86.250 -999.250 2.344 .000 44.625 38.471 000 74~:428 425.750 321.000 2.162 38.471 740 000 2548.792 9.297 740 000 1~027 ~6.064 85.750 -999.~50 5,664 6.164 0 000 38;5oO SGR.NGT URAN.NGT a4NG.NGT MRE$ NGT C~:BGT ILD.DTE IDPH.DTE I~QF.DTE II×D.DTE TEN$.DTE DPHI.LDT OLS.LDT Lb. LDT LMHV.LDT LURH.LDT TENS.bDT NPHI.CNL NPOR.CNL CFTC.CML TENS.CML SGR.NGT URAN.NGT W4NG.NGT MRES.NGT C1.BGT ILD.DTE IDPH.DTE IMOF.DTE IIXD.DTE TENM.DTE DPHI.LDT QLS.t, DT Lb.bDT LSHV.LDT bURH LDT TENS:bDT NPHI.CML NPOR.CNL CFTC.CNL TENS.CML SGR,NGT URAM.NGT W4NG.NGT MRES.NGT CI,flGT ILD.DTE IDPH.DTE IMQF.DTE IIXD.DTE PAGE{ 14 87,690 2,412 8 32 -999.250 5.770 ~,816 0.000 5,664 3605.000 25.906 -0.008 217.~75 1705. 00 2.232 3605.000 49.778 46.123 522,959 3605.000 88 895 3:873 15,!21 2'018 '999,250 21 281 23 141 0 000 2 459 3300 000 29 617 0 001 248 750 1705:000 2.168 3300,000 40.2~2 38,804 805,465 3300,000 46.186 0 895 4:016 2'035 -999.250 6,215 6.230 0,000 8.336 IS Tare Verification Listing :hlUmberger AlasKa ComDuting Center MTE~..DTE . 85,]75 ~RES.DTE RHOB.LDT 2,17~ DRHO,LDT OSS.[.L~T O.OlO DS,bDT L~T~.DOT ]48.250 SS1,LDT SS~V.LDT ~355,000 S1RH.LDT CA[.?.LOT 9.344 SGR,LDT MTE~{.LDT g5.375 ~RES.DDT RTNR.CNL 4.~05 TNPH.CNL RC~T.C{'~L 2018,30b RCFT,CNL SGP.CNL 79.910 CGR,CN~ ~RES.C~L 2.037 YTEM,CNL CG~.NG? 64.431 THOR.NGT W~NG,~bGT ~60.776 W2NG.NGT WLN~.~GT I4.009 TEN!!NGT C$.NGT 1.839,000 HTE N~T C2,BGT -999,250 TEN .BGT DEPT. 4600,000 8FLU. SP. DT.F -46. 250 IMER. IMPH.DTE 6.703 IFRE, C!DP,DTE 143,625 CIMP, I !R~. DTE t43,125 SGR MTE~I.DTE 84,625 ~RE$, RHOB. I, DT 2,223 DRHO, OS8,LDT 0,025 LITH bDT 136,~5 SS1, SSHV:LDT 1355.000 C4LI.LDT 8.977 SGR ~TE~.~, bDT 84,6~5 RTNR* CNL 3,762 TNPH RCNT.CNL 2076,595 RCFT SGR. C~I. 88. 959 CGR HRES,C.~L 2.057 MTEM, CG~,NGT 70 438 THOR, W I~G. A{GT 291:165 W2NG, WLNC,NGT. 15.060 TE CS,NGT !~36,000 HTEN, C~,BGT 999.250 TENS, D~PT. 4~0,000 SFLU. SP.DTE ... 7.438 IMER, I"P".DTE 9,016 IFRE, ClOP.DTE 105,688 CIMP, IIR~.DTE 107.250 SGR, MTE~.DTE 84,188 MRE$, R~OS.LDT 2,!17 DRMO. OSS.LDT 0.009 LITH.LDT 180,500 $$HV.LDT !.356,000 S1RH, CAbI.bDT 8,648 SGR, MTE~.bOT 84,188 MRES, RTN~.CNL 3,667 TNpH. RCNT.CH[, 2460,630 RCFT, SG~.C~L 52,868 CGR, DTE PHA DTE DTE DTE DTE bDT bDT bDT bDT bDT bDT CNb CNL CNL NGT NGT NGT NGT BGT bTM PHA DTE [TE DTE DTE bDT LDT LDT LDT bDT bDT C N b CNL CN b 25=JAN-lg91 15:14 79.910 2.037 -0,006 445,000 216,750 2.2O5 79,910 2.037 47,1~6 492.275 .375 8 10 ' 0 -999 250 5.746 6.750 2~,000 14 o000 88,959 2 O57 o o° 2 .,oo ! 93 5~0 38 84 625 11 938 534 810 5O0 -999 250 8.1~1 9.0 0 20.0O0 110.875 52,868 2,072 -0.013 490,000 215,750 4~ 072 005 656 CGR,DTE HTEN,DTE PEF,bDT bU,LDT 8S2,bDT bSRH.bDT CGR,bDT HTEN,LDT TNRA CNb CAhI,CNL HTEN,CN5 POTA,NGT W3NG.NGT MTEMtNGT GR.BGT ILM,DTE IDER,PHA IDOF,DTE CG DTE HTEN,DTE PEF,bDT bU,bDT SS2,bOT bSRH,bDT CGR,LDT HTEN,bDT TNRA,CNb CNTC,CML CAbI.CNb HTEN CNL PDTA:NGT WLNG,NGT MTE~.NGT G~.BGT Ib~.DTE IDER.PHA IDQF DTE XIRD:DTE CGR,DTE HTEN.DTE PEF.LDT LU.LDT SS2.LDT bSRH,bDT CGR.bDT HTEM,bDT TNRA.CNb CMTC.CNL CALI.CNb 64.431 765 5O0 2 768 414 25O 317 75O 2 178 64 431 765.5O0 3.736 2040,239 344 5O0 930 42,026 . 85,375 999,250 6 586 7 098 0 000 127 688 70 438 500 81~-732 389 250 316 250 70 500 Bl~ 764 1955 679 8 977 810 500 I 84 625 -999 250 8 813 9:617 0.000 96.063 48.582 727,000 2.479 45~ 50O 319.750 2,129 48.582 727.000 3,302 2454,102 8.648 TEN$.DTE DPHI.LDT QLS.LDT Lb. LDT bSHV.LDT LURH.LOT TENS,bDT NPHI.CNL NPOReCNL CFTC.CNb TENS.CNL SGR.NGT URAN.NGT W4NG.NGT NRE$.NGT C1.BGT ILD.DTE IDPH,DTE IMQF.DTE IIXD.DTE TENS,DTE DPHI.LDT OLS,LDT Lb.bDT LSHV,LDT LURH,LDT TENS.bDT NPH! CNb NPORiCNL CFTC CNL TENS.C~b SGR.NGT URAN.NGT W4NG.NGT MRES.NGT C1.BGT ILD.DTE IOPM.DTE IMOF.DTE IIXD.DTE TENS.DTE DPHI.BDT OhS.bDT Lb,bDT LSHV,LDT LURH,bDT TENS.bDT NPHI.CNL NPO~,CNL CFT .~NL TENS. Nb PAGE: 3410,000 28.896 '0.009 237 875 1705 000 2 184 3410 000 46 702 48 069 538 047 3410 000 79 910 2 036 5,388 2,037 =999,250 6,863 6 10 219 3275 000 25 878 -o ooo 17 3271 221 000 47 162 41 54 1 88 959 2 469 1! 044 2 057 -999 250 9 242 9!453 0 000 7,410 29~5 000 32 285 -0 003 264 250 1705 000 2:135 29~5 000 39 8O7 737, 3 2915'600 15 $ Tape verification Listing .hlumberqer Alaska Computing Center IIR~.OTE ~05,250 SGR,DTE ~TE~.DTE 82,063 MRE$.DTE RH[)P.LDT 2,104 DRHO.bDT OSS.LDT 0.009 b$.DDT LIT~.LDT 182,000 SSi,bDT SSHV,LDT 1355,000 SIRH,LOT CAL!.LDT 8,602 SGR,LDT ~TE~.LDT 92.063 MR£$.LDT Ci<I.. 3 913 TNPH,CNL RTN,i~.. · RCN .¢!,!I., 2376.606 RCFT,CNb SGPoC~iL 56.196 CGR,CNb NRES.CNL 2.115 ~TEM.CNL CG~.NGT 4!.9~3 TROR.NGT w~!.~.NGT 18~.11~ W2NG, MGT WS~G.~GT 4,3~0 TEN$.NGT C~.M(;T ~890.000 HTEM.NGT C~.bGT -999.250 TEN$'BGT DEP~. 4100.000 SFLU,DTE SP !)T~i -62.65h IMEiR PHA I~PH~DTE 10.219 IFRE~DTE CIDP.DTE 95.688 CI~P,DTE IIR~.!')T~ 94.250 SGR,DTE MTE~.DT~ 8!.563 MR£S, DTE RWO~.I..,DT 2.103 DRHO.LDT O6$.bDT 0,025 bS,bDT blTM.LDT 189 625 SSI,bDT SSHV.LDT 1355~000 S1RH.LDT CILI.LDT 8,672 SGR,LDT ~TE~.bDT 81,563 MRE$,bDT RTNP.C~L 3,700 TNPH,CNL RCMT.CNL 2411.046 RCFT.CbL SG~.CbIL 51.4~8 CGR.CNb ~RES.CNL ~,143 MTEM CNb CGR.NGT 51,231 THORiNGT WlNG,MGT 161,638 W2NG NGT Wh~iG,NGT 7,543 TEN$!NGT CS.NGT 1885 000 HTEN NGT C2.BGT -999:250 TENS,BGT DEPT. 4.000.000 SFbU.DTE SP,DTE -56,063 IMER,PHA I~PM.DT~ 8,195 IFRE.DTE ~PP OT~ !16.6~ CI~P,DTE R~DTE 1!7.250 SGR,DTE }iTEM.bTM 81.063 MRES,DTE R~OP.bDT 1,974 DRHO.LDT bDT OSS.LDT 0,016 [,S.I LI~n.L~T 239.500 SS1. ~D..' SSHV.I~DT 1355.00~) S1RH,LDT CALI.LDT 8,711 SGR.LDT MTE".L9T ~1,063 MRE$ LDT RTNR,CNT, 4'262 TMPH:CNb RCNT.CMT, ~816.624 RCFT.CNL SGR.C~:L 65,151 CGR.CNL 25-jAN-1991 15:14 56.196 CGR,DTE 2.115 HTEN,DTE -0.019 PEF,LDT 496,250 LiJ.LDT 212,7~0 S$2,LDT 2 1 5 bSRH,bDT 56:196 CGR,LDT .1 15 HTEN,bDT 4 ,736 TNRA,CNL 54.~1 CNTC.CNL 641. 3 CALI,CNb 82.063 HTEN,CNL 3 241 POTA,NGT 94i828 W3NG,NGT 910 000 MTEM,NGT 738 000 GR,.BGT .999 250 9,836 10,211 20.000 97 750 .143 0 004 518i500 22~ 375 .082 51.428 2,143 40,694 711 726 '51 231 81 563 6 314 89 440 2810 000 713 500 -999 250 6,516 8.242 20,000 121.938 65'151 2.146 '0 010 635~500 224,375 2 025 65 151 2 146 5O 284 31 973 455 723 IL~.DTE IDER,PHA IDOF,DTE IIRD,DTE CGR DTE HTEN:DTE PEF,LDT LU,LDT SS2,LDT LSRH.LDT CGR,bDT HTEN,LDT TNRA.CNb CNTC,CNL CALI,CNb HTEN,CNL POTA,NGT W3NG,NGT MTEM.NGT GR,BGT IL~,OTE IDER,PHA IDOF,DTE IIRD,DTE CGR.DTE HTEN.DTE PEF,LDT LU,bDT SS2.bOT LSRH.bDT CGR,LDT HTEN,LOT TNRA,CNL CNTC.CNL CA[,I,CNL 41 983 738 000 2 395 447 250 315 750 2 121 41 983 738 000 3 441 2324 444 8 602 738.000 1.904 31 250 82~063 -999,250 10.039 0,508 10.000 87,750 51 2~1 713:500 2 441 479i250 331 250 2 098 51.231 71 .500 3,374 2416.168 8 672 713:500 1 746 32~328 81.563 -999,250 8 055 8i789 0 000 105 188 55 723 693 500 2 311 578 000 338 5nO 1,984 55,723 693.500 4,148 1888.6!0 8.711 TEN$.DTE DPHI.LDT ObS.LDT Dh.bDT LSHV LOT LURH:LDT TENS,bDT NPMI.CNL NPOR.CNL CFTC.CNL TENS.CNL 5GR,NGT URAN.NGT W4NG.NGT MRES NGT ILD.DTE IDPH.DTE IMQF.DTE IIXD.DTE TENS.DTE DPHI.bDT OhS,bDT LL.LDT LSHV.LDT LURH.LDT TENS.bDT NPHI,CNb NPOR.CNL CFTC.C~b TENS.CNL SGR.NGT URAN.NGT W4MG NGT MRESiNGT C1BGT ILD,DTE IDPM.DTE IMOF.DTE IIXD.DTE TENS,DTE DPHI.LDT OLS.LDT Lb.bDT LSHV.LDT bURH.LDT TEMS.LDT NPHI.CNb NPOR.CNL CFTC.CNL TENS.CNL PAGE: 17 2910,000 33,081 0,027 272 500 o4:oo 2,14 2910,000 42 421 41 032 676 470 2910 000 56,196 1,875 5,388 2 il5 -999~250 10.180 10.445 0 000 8:o8 2810.000 33,174 -0 0i2 278i750 1704 000 2'102 2810,000 41,078 41,131 716,737 2810,000 51'.428 0,198 1,078 2,143 -999,250 8,398 8,563 0.000 7 934 2760:000 40,972 0,022 346,500 1704.000 1.998 2760 000 55!186 52 841 476.756 2760.000 Is }ape ~.~it icotion I,istin~ 2h!u~berr!er Alaska Compt]ting Center MRES.CN[.. 2,146 CGg.NGT · 55,723 W1. NG.NGT 219,880 WhNG.NGT 9,036 CS.NGT 1813,000 C2.gGT '999.250 DEPT. 3900.000 SP.DTE -57,875 IMPH.OTE 10,172 IDP.DTE 94,875 !~.DT~ 95,500 ~TEM.DTE 80.813 RHO~.LOT 2,109 OSS.LDT 0,0!9 LITH.L~T 182,.375 SSHV.LDT 1355.000 CILI.LDT ~TE~.LBT ~0,813 RTN~,CNL 3.753 RCNT.CNL ~269,244 SG~.CNL ' 54,358 ~PE$.C~b 2 164 ' CGR.NGT 48:854 W1N~.NGT 159,639 WhN~.NGT 6'024 C$.NGT 1809,000 C2.BUT -999.25() ]800,000 I~P~:DT~ 9!344 CIDP.DTE 1!0 250 IIRM.DTE 100,68~ MTM~.DTE 79.938 RHOB.bDT 2.1~1 bDT 0 022 [,IT"~LoT 1.78~750 SSHV.LOT 1354,000 C~LI,LDT 8,672 ~TE~.L[)T 79,938 ~¢~m.C~L ~101,565 SG~.CNL 63,746 M~ES.CNb 2,1~8 CG~.~3GT 45.517 W{.NG.NGT 209,677 WhNG.M(;T 8.065 C$.NCT ~799.000 C2.hGT -999,25(> DEPT. ]700,000 SP.DTM -57,969 IMPW.i)TE 9'750 CIDP.DTE 9~.31.3 MTEM.CNL THOR.NGT W2NG,NGT T~N$,NGT HTEN.NGT TEMS,BGT SFbU,DTE IMER.PHA IFRE,DTE CIMP.DTE SGR,DTE MRES,DTE DRHO,LDT SiR~ 'bDT ,LDT SGR,LDT MRE$,LDT TNPH,CNL RCFT.CNL CGR.CNL ~TE~.C~b THOR,NGT W2NG.,NGT TENS,NGT HTEN,NGT TENS.BGT SFLU'DTE IMER,PHA IFRE,DTE CIMP,DTE SGR,DTE MRE$,DTE DRHO,hDT bM,bDT LDT $1R SGR LDT MRES,LDT TNPH CNL RCFT!C~L CGR CNb ~TEN'CNL IHOR NGT 2NG NGT TENS.NGT HTEM,NGT TEN&.BGT SFbU,DTE I~ER.PHA IFRE.DTE CI~P.DTE Zb-J/%N-199! 15:14 81,063 MTEN,CNb 8,276 POTA'NGT 84,337 W3NG,NGT 2760.000 MTEM,NGT 693,500 GR,BGT '999,250 10,195 10 1 o:gio 98, ,164 s;°. 2,143 54,358 2,164 40 919 630~297 48,854 80,813 5,787 78 313 2710 000 722 000 -999 250 8 172 ,2~ 234 000 106 938 63 .146 2 88 000 225 750 O0 2 8 55~ 289 45 810 7 637 2665 000 675 500 -999 250 8.769 9.773 20,000 102.438 IL~,OTE IDER,PHA IDOF,OTE IIRD,DTE CGR.DTE HTEN,DTE PEF,LDT LU,LDT $S2,bDT bSRH,bDT C~R,bDT HTEN,bDT TNRA.CNb CNTC CNL HTEN.CNL POTA,NGT W3NG,.NGT ~TE~,NGT GR,BGT XLM,DTE XDER,PHA IDOF,DTE IIRD,DTE CGR, DTE HTEN, .DTE PEF,bDT LU,bDT SS2,LDT DSRH,LDT CGR,LDT HTEN,LDT TNRA,CNL CNTC'CNb CAbI,CNL HTEN,CNL POTA,NGT W3NG.NGT MTEN,NGT GR,BGT Ih~,DTE IDER,PHA IDOF.DTE IIRO,DTE 693.500 1 555 33,133 81,063 -999.250 9.906 10.727 0,000 87.438 48.854 722,000 2.475 464,500 322,500 2,115 48,854 722.000 3,431 2287.189 8,773 722.000 1,722 32 129 80~813 -999.250 9,30! 000 101000 675,500 2,459 462,000 9,750 322,107 45,517 675 500 3 750 2201 279 8 672 675 500 1.502 34,274 79.938 -999,250 9.555 10.508 0,000 85.688 SGR.NGT URAN.NGT W4NG.NGT MRES.NGT Cl.BGT ILD.DTE IDPH.DTE INOF.DTE IIXD.DTE TENS.DTE DPHI,LDT OhS,bDT LL.LDT DSHV.LOT LURH,LDT TENS.bDT NPHI.CNL NPOR.CNL CFTC,CML TENS,CNL SGR.NGT URAN,NGT ~4NG.NGT MRES,NGT C1,BGT i£,D,DTE IDPH.DTE IMOF'DTE IIXD,DTE TENS,DTE DPHI.LDT 0LS,LDT bL.LDT LSHV,LDT LURH,LDT NPH! Nh NPOR,CNL CFTC.CNL TENS,CNb SGR.NGT URAN.NGT W4NG.NGT MRES.NGT CZ,BGT ILD.DTE IDPH.DTE !MQF.DTE !iXD.DTE PAGe: 65,151 1.186 4,016 2,146 '999,250 10'242 10,531 0,000 5,938 2710,000 2,802 ~0.009 270,000 1704.000 2.!19 2710.000 41 983 41!631 675 647 2710 000 54,358 0,611 3,012 ~2,164 -999.250 :805 °° 1 766 266 000 32,695 0 12 04,000 0 47 . 966 46,852 613,895 2665.000 63,746 2,353 8,065 2,188 -999,250 10,367 10,594 0,000 5,863 18 S Tone ver.ificatlom Listina hlumberqer AlasKa Comput. in~ Center IIRu l)'r~: q9 000 SGR,!)TE .TEU~DT~ 79:375 MRES,DTE RUf)B, I.DT 2.18! DRHO. bDT OSS. LOT 0. 027 LS. BDT CALI.LDT 8,906 SG. :LDT-~ ~TE~,LDT 79,375 gRE$.bDT ~TNR,C~L ~,5~7 TNPH'CNB ~CUT.C~I, 1893.215 RCFT,CN5 SG~.cNL 85.890 CGR.CNL ~RES.CNL 2,188 MTEM,CNL WSNG~NGT 10,081 ~,EN NGT CSoNGT 1794,000 HTEN,NGT C2,BGT -999,250 TENS,BGT DEPT. 3600,000 SP,DTE -66,188 [~PH.DTE 11.375 C!DP,DT~ 91,750 IIR~.DT~ 85,3!3 gTE~'DTE 78,938 ~HOB.LOT 2,109 DSS,bDT 0,008 LITH.LDT 193.000 SSHV.LDT 1354.000 CALI.LDT 8.297 MTE",LDT 78,938 RTN~.CNL 3.440 RCNT.C~L ~361.522 S(;~.C~,!L 50.653 ~RES.CNL 2.2!.7 CG~.~GT ]9,580 Wl.N~,NGT 166,33l WLNG.NGT 1.008 CS.NGT 1837'000 C2oBGT -999.250 SFLU.DTE I~ER,PHA IFRE,DTE CINP,DTE SGR DTE ~RES DTE DRHO bDT kS bDT SSi bDT S1RH bDT SGR~LDT MRES,LDT TNPH,CNb RCFT.CNL CGR,CNL M'rEM,CNL THOR.NGT W2NG.NGT TENS.NGT HTEN,MGT TENM,BGT DEPT. 3500,000 SP.DTE '63,469 IMPH DTE ~0 531 CIDP'OTE 07i418 I!~:DTE 92 313 MTE~.DT~ 78.188 QSS.LLT 0.025 LITH.LDT !q~,~75 SSHV.L~T 1.354,000 C!i~t .bi)* 8.461 ~iT~u.[,~T 78.18~ ~Ta~. C~'~L 3.70~ ~c~'r.c~l~ 21 ~5.48o $(lP.ChI., 62.252 SFLU,DTE IMER.PHA IFR. E,DTE CIMP.DTE SGR.DTE ~RE$.DTE DRMO.LDT LS.LDT SSI,LOT S1RH.LDT SGR.LDT ~RES.,LDT TNPH.CNb RCFT.CNb CGR.CNL 25-dAN-lO9! ~5114 85,890 2.188 444'500 221,500 2,172 85.890 2 188 44 701 467 956 66 34 79 ~75 10 54~ 002 o 641 000 999,250 11,320 11383 olooo 87.813 50,653 2,217 -0 013 499 000 216 25 653 2 217 39 718 63 854 ]~ 580 78 938 3 789 79 637 6 '999 250 10.375 10.578 0,000 4,938 62.252 2.229 0 001 52 i 00 2.080 62.252 2.229 41.052 624 410 s6198 CGR,DTE HTEN,OTE PEF,DDT blJ,LDT SS2,bDT DSRH,LDT CGR,LDT HTEN,bDT TNRA,CNb CNTC,CNL CAbI,CNb HTEN,CNb POTA NGT W3NG:NGT NTEM,NGT GR,BGT ILM,DTE IDER,PHA IDQF,DTE IIRD'DTE CGR,DTE HTEN,DTE PEF,LDT LU,bDT SS2,LDT LSRH,bDT CGR,bDT HTEN,LDT TNRA,CNL CNTC,CNb CAbI,CNL HTEN,CNb POTA,NGT W3NG,NGT MTEM NGT GR:BGT ILM,DTE IDER,PHA IOOF DTE IIRD:DTE CGR,DTE PE bDT LU,bDT SS2,bOT bSRH,bDT CGR,LDT HTEN,LDT TMRA,CNb CMTC,CMb CAI,,I.CNL 66.234 641 000 2 799 412 750 317 000 2 180 66 234 641 000 3 780 1898 126 8 9O6 641 000 1.630 46 371 79i375 -999 25O 11.094 10.930 0.000 85.500 39.580 628.000 2,279 450,750 121 39.580 628,000 3.493 2366.144 8,297 628,000 1.615 30,242 78 938 -999:250 10.250 11,484 0 000 80i313 56 983 7.500 602,566 493.750 330..500 2.086 56 983 o::soo 2188.665 8.461 TENS.DTE DPHI.LDT OhS.bDT Lb.LOT bSHV,LDT bURH.bOT TENS.LOT NPHI.CNL NPOR.CNL CFTC.CNL TENS.CNL SGR.NGT URAN.NGT W4NG.NGT MRES.NGT C1,BGT ILD.DTE IDPH.DTE IMQF.DTE IIXD.DTE TENS DTE DPHI:LDT OhS.LOT Lb.bDT LSHV.LDT LURH.LDT TENS.bDT NPHI,CNb NPOR.CNL CFTC.CNL TENS,CNL SGR,NGT U~N.NGT ~4NG.NGT MRES.NGT C1,BGT ILD.DTE IDPH.DTE IMOF.DTE IIXD.DTE TENS.DTE DPHI.bDT OLS.LDT LL.LDT LSHV.LDT DURH,LDT TENS.bDT NPHI,CNb ~POR.CML CFTC.CML TENS.Cab PAGE~ 19 2545,000 0 006 238 125 1704,000 2,186 2545,000 48,170 45,192 523.613 2545,000 85,890 2 823 12:097 2,188 '999,250 10.484 10,891 0.000 6,383 2555,000 32,792 27 500 170 000 2.135 2555,000 43.816 40.140 714,864 2555.000 50,653 1,524 4,032 2,217 '999,250 11.125 11 422 0 000 4 801 2395 000 34 057 -0 022 282 750 1704 000 2,084 2395,000 40,375 41.461 644.959 2395.000 chlumherqer Alaska Computing Center I~R~.OT~: 65.250 SGR.DTE OSS. LI)T O. 005 nS. bDT LTTH.Lr.)~ 274. 500 $S1. bDT $SHV.LOT 1354.000 S~H.LDT C~bI. LOT ~ 1. 336 SGR. bDT ~TE". bDT 76,6~5 MRES,LDT RT~;P.CN[. 3.884 TNPH.CNL RCNT.CN[~ ~78.3~5 RCFT.CND SGP.CNL 28.411 CGR.CNb ~RES. CMl.. 2.266 MTEN,CNL CGR.NGT ~0.160 THOR.NGT W~NG NGT 107.430 W2NG'NGT WSNG~NGT 2.008 TENS,NGT C8.NGT !850.000 HTEN.NGT C~.BGT -999.250. TENS. 5GT D~PT. )100,000 SFLU,DTE SP.DTE -66.000 IMER,PHA I~FH.OTF 13,578 IFRE,DTE CIDP.OTE 70.250 CI~P.DTE I)R~.OTE 72.313 SGR DTE ~TE~.DTE 75.438 MRES~DTE RHOB. bDT 2. 027 DRHO bDT QSS. bDT O. 008 LS.LDT LITH. LD~ 243. 625 SSi,bDT SS~)V.LD.. 1354,000 SiRH,LDT C~[.~.[.DT 8 789 SGR,LDT MTE~.LDT 75 ~ 438 MRES,LDT PTMP.C~![. 3.506 TNPH CNb RC.~:T. C~b 2494.i42 RCFT~CNb SG~ .C.5~L 29,421 CGR.CNL ~RES,C~iL 2,297 NTE~,CNb CGP. f.]GT 31.010 THOR,NGT WlNG.~iGT 86.694 W2NG.NGT WSt.~.NGT 4.032 TENS.NGT CS.~GT 1826.000 HTEN.NGT C~. 8GT -999. 250 TENS.SGT D~PT. 3000.000 8FbU.DTE SP.DTE -64.563 IMER.PHA IMPN,DTE 9,078 IFRE,DTE C!DP.DTE 101,188 CIMP,DTE I IR~. DTK 106. 250 SGR, DTE MTE~. DTE 75,625 MRES.DTE RHOB.bOT 2.232 DRHO.bDT OSS. bDT O, 035 bM, bDT LITH. I,DT ~ 49,500 SS~. bDT SSHV. [.DT J 354,000 SIRH.LDT C~LI. bDT 1 O. 469 SGR. bDT MT~]P. [.DT 75,625 MRES,LOT RTH~, C:~[, 4.3~7 TNPH,CNL RCNT. C{.,]L 1785.627 RCFT.C~b SGP. C~.~L 79.193 CGR. C.NL 25-daN-199! 15:14 28,411 2.266 6~ 0,006 1.000 226,875 ,0162 ,411 2 266 44 5 20 160 76 625 1 974 43 i73 24~0 000 722 000 -999 250 11.570 13 617 20 000 73 563 421 2~ 297 '0.008 58 000 . 066 29,4] 1 61 ~ 2 4 5 60 i 4 77 0 '999 .2 ~0 8.078 29,102 0.000 110,063 93 45 , 50 243.375 2.027 79.193 2.340 46 6 59.963 CGR,DTE HTEN,DTE PEF.LDT LU,LDT $S2,LDT bSRH.LDT CGR.bDT HTEN.LDT TNRA,CNL CNTC,CNb CALI,CNb HTEN,CNL POTA,NGT W3NG,NGT ~TEM,NGT GR.BGT IDM,DTE IDER,PHA IDOF,DTE IIRO,DTE . CGR,DTE HTEN,DTE PEF,LDT LU,LDT $S2,LDT bSRH,LDT CGR bDT HTE~:LDT TNRA,CNL CNTC,CNL C~bI,CNL HTEN,CNL POTA,NGT W3NG,NGT ~TEM,NGT GR.BGT ILM,DTE IDER,PHA IDQF,DTE IIRD.DTE CGR,DTE HTEN,DTE PEF,LDT LU.LDT SS2,LDT bSRH.LDT CGR,bDT HTEN,LDT TNRA.CNb CNTC.CNb CALI.CNL 20.160 722.000 1.902 583,500 346.750 1,993 20.160 722.000 3.667 2179.O04 11,336 722.000 22,. 8 76.625 -999.250 13.109 14.453 0.000 65.875 31.010 770,000 1,933 534.000 337.500 2'035 31.010 770 000 3 480 2450 783 8 789 770 000 0 968 I6 .129 75 438 -999 250 8 891 9 977 :0 000 93 000 59 963 748 500 2 904 420 250 343 250 2!168 59963 748 500 3 967 1764i721 10 469 TEN$.DTE DPHI.bDT QLS.LDT Lb.LDT LSHV.LDT LURH.bDT TENS.bDT NPHI.CNb NPOR.CNL CFTC.CNL TENS.CML SGR,NGT URAN.NGT W4NG.NGT MRES.NGT C1.BGT IbD.DTE IDPH.DTE I~OF.DTE IIXD.DTE TENS.DTE DPHI,LDT QLS,bDT Lb.bDT LSHV.LDT bURH,bDT TENS,bDT NPHI.CNb NPOR,CNL CFTC,CML TENS.CML SGR,NG.T URAN.MGT W4NG,NGT MRES,NGT C1,BGT ILD.DTE IDPH.DTE IMQF.DTE IIXD,DTE TENS.DTE DPHI.LDT ~LS.LDT LL,bDT LSHV.bDT LURH.LDT TENS.bDT NPHI.CNb NPOR.CNL CFTC.C~b TENS.CML PAGE) 21 2430.000 40 126 '0:003 339,500 1703.000 1,992 2430.000 42,801 40.392 589.687 2430,000 28,411 1'219 1.004 . 266 -99 .250 14. 9 ,000 .961 2370'000 37'729 750 1703,000 000 42,852 4~,796 7~ ,i92 23 0.000 29,421 -0 097 5 040 297 -99~ 250 9,6'17 9.875 :ooo 9~0 2200,000 007 242'625 1704,000 176 220 '000 49:246 46 434 46]:27 2200.000 Tape YerJ. f.icatlon LiSting nlUmberoer Alaska Computlnq Center M ~ 6:S. C.:'.. L 2.340 MTEM.CNb CG;.NGT 59.963 ~HOR,NGT WlN~.NG? 251.004 W2NG.NGT WbNG.NGT 6.024 TENS.NGT CS.NGT ~776.000 HTEN,NGT C2.BGT -999,250 TENS.BGT D~PT. 2900.000 SP. ~?E -63.063 t'~4P~. DTE ! 950. 000 C?DP. DTE 6.8 . 188 I]R~.DTE -268.500 ~'.TE~ . DTE 74. 938 RMO~., bDT 1 , 951 OSS, LDT -0 104 LITM, LDT 22 ~ 35g c~.[,~ ~ 75~ MTE~.LDT RTNP .CNb 4.368 RCN!'.C~L 1328.208 SGR CNL 46.655 ~8~S ~ CNL 2. ]44 C~p~ NGT 31 , 699 W1NG.NGT 164,659 WSNG.N'GT 6.024 CS. NC, T 1773.000 C9. BGT -099. 250 SFLU,DTE IMER,PHA IFRE,DTE CIMP.DTE SGR,DTE MRE$.DTE DRHO.LDT L$.bDT $S1,LDT S1RH,LDT SGR,LDT MRES,LDT TNPM,CNb RCFT CNL CGR CNL MTEM CNL THOR MGT W2NG NGT TENS NGT HTEN,NGT TENS.BGT DEPT. ~800.000 SFLU,DTE SP.DTE -999.250 IMER,PI'{A ! ~'". DTS: -999,2S0 IFRE,DTE ..~iVt~ -999.250 SGR:DTE ~TE~,~TE -999.250 ~RE$ DTE PHO~. [~T -999,:50 DRMQ:LDT , OSS.L~? -999.250 LS,bDT LITF.LOT -999.250 S$1,I.,DT S$~.LDT 2999'250 S!RH,LDT CALI.I, OT 999.250 SGR.LDT mTE~.LDT -999,250 MRES.bDT RTNR.CNL -999,250 TNPH,CNL RCNT.CNL -999.250 RCFT.CNL SG~.CNL -999,250 CGR,CNb ~gS.CN[. -999,250 MT£M'CNb ~ CGP.NGT -999,250 T}~OR'NGT WJ.~G,~GT -999,~50 W~N~:NGT WbN~,NGT -999,250 TEN NGT C$,NGT -999,250 HTEN,NGT C2,~GT -999,250 TEN$,OGT 25-jAN-1991 15:14 75.625 8 784 133 534 2200 000 748 500 -999 250 9696.000 1.950i000 20000 59 750 246 655 2.344 230 667 1;625 78,625 4.051 46,655 .3 44 5 . 026 699 74 938 5.i91 67,269 2285 000 748:500 -999,250 -999.250 -999 250 -999.250 -999.250 -999.250 -999.250 2999 250 -9 .250 -999.250 -999.250 -999,250 -999.250 -999,250 -999'250 '999i250 -999 250 -999.250 -999.250 HTEN,CNL POTA,NGT W3NG,NGT MTEM,NGT GR,BGT ILM.OTE IDER'PHA IDQF,DTE IIRD.DTE CGR,DTE HTEN DTE PEF:LDT bU,bDT $$2,LDT bSRH,bDT CGR,bDT bDT TNHT~:CNL CNTC,CNb CALI,CNL MTEN,CNL POTA,NGT W3NG,NGT MTEM,NGT GR,BGT IbM,DTE IDER'PHA IDOF'DTE IIRD,DTE CGR,DTE HTEN,DTE PEF,bDT LU,bDT SS2,bDT bSRH,LDT CGR,LDT HTEN,LDT TNRA.,CNL CNTC,CNb CAbI,CNL HTEN,CNb POTA'NGT W3NG,NGT MTEM'NGT GR'BGT DEPT. 2700.000 SFLU.DTE -999.250 IbM,DTE SD.DTE -999.250 IMER.PM~ -999 250 IDER,PHA IMP~.DTE -999.250 IFRE.DTE -999:250 IDQF,DTE CTOP.DTE -999.250 CIMP.DTE -999.250 IIRD,DTE 748.500 ! 7o~ , 34.J37 75,625 -999,250 !950.000 9 984 0~000 64 250 31 699 748 500 23 313 198 250 129 250 2 617 31.699 748.500 4,125 1323,338 8.758 748.500 0.766 21.084 74,938 -999.250 -999.250 '999.250 -999 250 -999!250 -999 ~50 '999 250 '999 250 -999 250 '999 250 '999 250 '999 250 '999 250 '999 ~50 '999 250 -999 250 '999 250 '999 250 '999 250 -999250 -999 250 '999.250 '999 250 -999i250 -999 250 SGR.NGT URAN.NGT W4NG.NGT MRE$.NGT Ci.BGT ILD.DTE IDPH.DTE I~0F.DTE IIXD.DTE TENS.DTE DPMI.LDT OhS.bDT bb.bDT LSHV,LDT bURH.LDT TENS.bDT NPHI.CNb NPOR,CNL CFTC,CNL TENS.CNb SGR.NGT URAN,NGT W4NG.NGT MRES.NGT CI..BGT ILD.DTE IDPH.DTE IMQF.DTE IIXD.DTE TEN$.DTE DPHI.I.,DT QLS.LDT Lb,LDT [,SHV.LDT LURH'LDT TENS.bDT NPHI,CNL NPOR,CNL CFTC,CNL TENS,CNb SGR,MGT URAN.NGT W4NG,NGT MRES.NGT Ci.BGT ILD.DTE IDPH.DTE iMOF.DTE I!XD.DTE PAGE: 22 79.193 2,645 ! 3 052 -999.250 13,898 14,656 0,000 367 25O 42 367 0.051 102 563 1707 000 2 666 2285 000 54 715 52 226 325,636 2285 000 46 655 1 966 5 O2O 2 344 -999 250 -999,250 -999 250 -999 25O -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999:250 -999.250 -999,250 J,;-, 'ra~e Veriftcation !,]stin~. Ch].~mberner A l, as~a Com[>uting Center i~R~oDT'E -9~9.250 SGR,!ITE ~T~~' DT~ -q99.250 MRES.DTE R~O~.L~T -999.250 DRHO,[.DT QSS.bDT -999,250 LS,bDT LIT~.LDT -999,250 SSI,bDT SSHV.bDT -999.250 S~RH,LDT CAL?.LDT -959.250 SGR,L~T ~TE~.LDT -999,250 MRE$.LOT RTNR.CNL -999 250 TNPH.CNL RC~T.CNL -999:250 RCFT.CNL SG~.CNL -999.250 CGR,CNL ~ES.CNL -999.250 ~TE~.CN5 CGR.NGT -999,250 THOR,NGT W~NG.NG.? -999.250 W2NG,NGT w5NG,NGT -999,250 TE~S,NGT C$.NGT -999 250 HTEN,NGT C~.BGT -999:250 TEN$,BGT DFPT. 2600,000 SFLU.DTE SP.DTE -999,250 IMER,PHA I~PH.DTE -999.250 IF~E,DTE C~DP DTE -999,250 CIMP DTE I~R~:~TE -999,250 SGR:DTE MTE~.DTE -99'9,~50 MRES,DTE R~O~.LDT -999.250 DRgO,LDT OSS.LDT -999,250 LS,LDT LXTH.LDT -999.250 SSI.'LDT SSHV.LDT -999.250 S!RH,bDT CAbI.[.~T -999,250 SGR,LDT ~T~ b[..T' -999.250 ~RE$'LDT RTNR:C~L -999,250 TNPH,CNL RCNT,CNL -999.250 RCFT.CNL SGR'CNL -999,250 CGR.CNb MRES,C~L -999,250 ~TEM,CNb CG~.~GT -999.250 THOR.NGT W1~G,NGT -999'250 W2NG'NGT WbNG.NGT -999,250 TENS,NGT C$,NGT -999,250 HTEN:~T C2.BGT -999,250 TEN$...~T DEPT. 2500,000 SFbU,DTE SP,DTE -999,250 IMER,PHA I~P~.DTE -999,250 IFRE,DTE CIDP,DTE -999,250 CIMP,DTE I!R~ DTE -999,250 SGR.,DTE ~TE~:OTE -999,250 MRES DTE R~OB,L~T -999,250 DRHO:LDT OSS.LDT -999.250 b$,LDT L~TH.LDT -999.250 SSI,bDT SSHV,LDT -999'250 $~RH,LDT C~LI.LDT -999,250 6GR,LDT ~TE~, bDT -999,250. ~ ~RES.LDT. ~TNR.CNL -999.~50 TMPH CNL RCNT.CYL -999.250 RCFT:CNL SGP.C~b -999,250 CGR,CNL 25-JAN-199! 15.'14 ' 9,250 '999.250 '999.25O '999.250 '999.250 '999,250 '999.250 '999.250 999.250 -999.~50 -999 250 -99~ 250 '99 250 -99 50 -999.250 -999 ~50 -999 250 -999 25O -999 250 -99~ 250 -99 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999250 -999 250 -999 250 -999:250 -999.250 '999.250 '999,250 '999.250 '999'250 "999'250 '999 250 '999 250 "999 250 '999 250 '999 250 '999,250 '999,250 '999,250 '999.250 -99 0 CGR,DTE HTEN.DTE PEF,LDT LU,LDT S$2,LDT LSRH,LDT CGR.bDT HTEN,bDT TNRA,CNL CNTC,CNb CADI,CNb HTEN,CNL POTA,NGT W3NG,NGT ~TE~,NGT GR,BGT XLM,DTE ZDER,PHA IDQF,DTE XXRD,DTE CGR.DTE HTEN,DTE PEF,bDT LU,bDT SS2,LDT LSRH,LDT CGR bDT HT~:LDT TNRA,CNL CNTC,CNL. CAbI,CNb HTE.N,CNb PoTA,NGT W3NG,NGT ~TE~,NGT GR'BGT ILM,DTE IDER,PHA IDOF,DTE' IIRD,DTE CGR DTE HT'EN:DTE PEF,LDT bU,LDT S$2,'LDT LSRH,LDT CGR'bDT HTEN.bDT TNRA.CNL CMTC.CNL CALI,CNL 999,250 TENS,DTE ~999.250 DPHI.LDT 999,250 OLS,LDT 999,250 Lb,bDT 999.250 LSHV,LDT -999.250 LURH.LDT 2999.250 CFTC,CNL -999, NS CN! . -999,250 C1.BGT -999.250 -999,250 -999.250 -999,250 -999,250 -999.250 -999,250 -999 50 -999 ~50 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ILD,DTE IDPH,DTE IMOF.DTE IIXD.DTE TEN$.DT£ DPHI.LDT Qb$.LDT Lb bDT LSHViLDT bURH bDT TENS,bDT NPHI,CNb NPOR.CNb CFTC CNL TENS:CNL SGR.NGT URAN,NGT W4NG,NGT ~RES,NGT C~,BGT -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 999.250 999.250 999.250 It, D,DTE IDPM,DTE I~OF,DTE IIXD.DTE TENS,DTE DPHI,LDT QLS.LDT Lb,bDT LSHV.LDT bUSH,bDT TENS.bDT NPHI,CNb NPOR,CNI, CFTC.CNL TENS.C~JL PAGE~ 23 -999 250 -999 250 '999 250 -999 250 -999 250 '999 250 -99 250 -99 25O -999.250 -99 250 -999'250 2999'250 999:250 '999,250 '999,250 '999,250 '999 250 '999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 -999,250 -999,250 -99 250 -99 250 -999,250 -999 250 '999i250 -999 250 5 Ta~e verification Listing ~lumberger ~laska Computing Center M~ES.CNb -999.250 MTE~ CML CG~,NGT -999,25© THOR~NGT ~INO.NGT -999.~50 W2NG.NGT / 5NG.~GT -999,250 TENS.NGT C$.NGT -999.~50 HTEN MGT C2.BGT -999.250 TEN$:BGT DEPT. 2400.000 SFbU.DTE SP.DTE -999.250 .I~ER,PHA I~PH.DTE -999.250 IFRE,DTE CIDP.DTS: -999.250 CIMP DTE IIR~ DTE -999,250 SGR:DTE HTE~DT~ -999.250 NRES.DTE ~,OB.LDT -999.250 DR~O.LDT QSS.LDT -999.250 DS,bDT DIT~.bDT -999,250 SSI,bDT SSHV.bDT -999.250 S~RH bDT CA[.I.I~DT -999.250 SGR~bDT ~TE~,LDT -999.250 ~RES,LDT RTN~,C~L -999,250 TNPH,CN[, RCNT.C~b -999,250 RCFT,CNL SG~.CNL -999.250 CGR.CNL MRES,CNL -999,250 MTEM.CNL ~CG~,NGT -999,250 THOR.NGT W'NG.NGT '999.250 W~NG,NGT Wb~.NGT '999.250 TEN$,NGT c~NGT '999,250 HTEN,NGT ~GT 12,9~4 TENS.,BGT DEPT. 2300,000 SFLU.DTE SP.DTE '999.250 IMER.PMA IMPM.DTE -999.250 IFRE.DTE C]D~.DTE -999.250 ClMP,DTE IIR~.DTE -999.250 SGR.DTE ~TEW.DTE -999,250 ~RE$.DTE RHOR.LDT -999,250 DRHO.LDT OSS.LDT -999,250 DS,bDT L~T'~.LDT -999 250 $$I bDT SS,,¥.bDT -999!250 S1RH!LDT C'L'.LDT '999 250 SGR bDT STEM.bDT -999 250 MRE8 bDT RTN~.CN[. -999!250 TNPH:CNL RCNT.CN!~ -999 250 RCFT.CNb SG~.CNb -999.250 CGR.CNb ~E$.CNb -999 250 MTEM.,CNL CGP N~T -999:250 TH~R,NGT W1~'~4~ -999,250 W~NG,NGT WbNG:NGT -999.250 TEN$.NGT CS.~(;T -999.250 HTEN.NGT C~.BGT 1.3,016 TENS.BGT DEPT. 2200,000 SFbU.DTE SP.DT~ -999,250 IMER.PHA I~PH.DTE -999.250 IFRE.DTE CIDP.DTE -999,250 CI~P.DTE 25-JAN-199~ ~999 50 999 ~50 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 -999 250 '999 250 -999 250 '999 250 '999 .250 -999 ~50 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 · 999 250 -999.250 14 ,000 -999.~50 -999,250 -999.250 -999, 0 -999,250 -999,250 -999 250 -999 ~50 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 250 -999250 -999 250 -999 250 -999 250 -999 250 1545,000 -999 250 -999'.250 -999,250 -999,250 HTEN,CN5 POTA,NGT W3NG,NGT MTEM,NGT GR,BGT ILM,DTE IDER,PHA IDQF,DTE IIRD.DTE CGR,DTE MTEN,DTE PEF,bDT LU,bDT SS2,LDT bSRH,bDT CGR,bDT HTEN,LDT TNRA,CNL CNTC,CNL CALl,CML HTEN,CNL POTA,NGT W]NG,NGT MTEM,NGT GR,BGT IGM,DTE IDER,PHA IDOF,DTE IIRD OTE CGR:DTE HTEN'DTE PEF,bDT LU,bDT SSa.bDT LSRH,LDT CGR,LDT HTEN'bDT TNRA,CNb CNTC CNL CAbI:CNb HTEN,CNb POTA'NGT W3NG,NGT MTEM,NGT GR,BGT ILM,DTE IDER,PHA IDQF,DTE IIRD,DTE -999.~50 -999.~50 -999.~50 .-999.250 999.~50 -999.250 -999.250 -999 250 - 99.250 -999 250 -999i250 -999 250 -999.~50 i999.250 999,~50 999.250 -999,~50 -999 ~50 -999 250 -999 250 -999 250 -999 250 -999 ~50 65 25O -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999..250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 .250 -999 ~50 -999 250 -999 250 -999 250 -999 250 63 063 -999 250 -999:250 -999 250 -999:250 $GR.NGT URAN.MGT W4NG.NGT MRES.NGT C1.BGT ILD.DTE IDPH,DTE IMOF.DTE I!XD.DTE TENS.DTE DPHI.LDT ODS.bDT Lb,bDT LSHV,LDT LURH.LDT TENS.LDT NPHI CML NPOR:CNL CFTC.CNL TENS.CNL $GR,NGT URAN,NGT W4NG.NGT MRES'NGT Ci.BGT ILD,DTE IDPH.DTE IMQF.DTE IIXD DTE TENS:DTE DPHI.bOT ODS.bDT Lb.DDT LSHV.LDT bURH.LDT TgNS.bDT NPHI.CNL NPOR.CNL CFTC.CML TENS.CML SGR.NGT U~AN.NGT W4NG.NGT MRES.NGT C1.BGT IbD,DTE IDPH.DTE IMQF.DTE IIXD.DT£ PAGE~ 24 -999 250 -999~250 -999.250 -999,250 -999,250 '999,250 -999 250 '999 250 '999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 -999 ~50 -999 250 -999 250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,~50 13,508 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 250 -999 ~50 -999 250 -999,250 -999,~50 -999.250 12,836 -999 250 -999~~250 -999 250 -999 250 chIumberger Alaska Comput~nq Center I?P~.DTFi -999.250 SGR.DTE ~TE~.DTE · -999,250 MRE$.DTE RPO~.LDT -999.250 DRHO.LDT OSS.bDT -999.250 L$,LDT LTTH.LDT -999.250 8S!.LDT SSHV.!..DT 999,250 SIRH,LDT CALI.LDT ~999.250 SGR,LDT ~TE~.LDT -999.250 MRES.GDT RTNg.CNb -999,250 TNPH,CNG RCNT.CNL -999,250 RCFT,CNG SGP.C~L -999.250 CGR,CNL MRES.CHL -999,250 MTEM,CNL CGR.NGT -999.250 THOR,NGT W~N~.NGT -999,250 W2NG,NGT WbN~.NGT -999.250 TEN$.NGT CS.MGT -999.250 HTEN,NGT C~.BGT 12,68~ TENS,BGT DRPT. 2100.000 SFLU DTE SP.DTE -999.250 IMER:PHA IMPH.DTE -999..~50 IFRE.DTE ClDP.DTE -999.250 CIMP,DTE I~R~.DTE -999,250 SGR,DTE ~TE~.DTE -999,~50 MRE$.DTE RHOB,bDT .999,250 DRHO,LDT QSSoL[)T ~999,250 L$.LDT L~T~.LDT -999.250 $S1,LDT SSHV.LDT -999.250 S1RH.LDT CAbI.LDT -999.250 SGR.LDT MTge'.DDT -999.250 ~RES,LDT RTNR.CNL -999.250 TNPH.CNL R. CMT.CML '999.250 RCFT.CNb SC~,... CNG -999,250 CGR,CNL MRES.CNL '999.250 MTE~.CNL CG NGT '999.250 THOR.~GT~ W~N~,~GT -999.250 W2NG, WbNG.NGT '999,250 TENS.NGT CS.NGT -999,250 HTEN,NGT C2.BGT 13,~81 TENS.BGT DFPT. !000,000 SFhU,DTE SP.DTE 999,250 IMER,PHA I~P!~.DT.E 999.250 IFRE.DTE CIDP.DTE -999,250 CI~P.DTE II~ DTE -999,25¢) SGR, DTE ' " . DT~.. -999,250 ~RE$* DTE RFO~.b[)T -999,250 DRHO,LDT OSS, GDT -999,' '2.50' b$. GDT bIT',bDT -999,250 SSi bDT SSHV.LOT -999,250 S1RH:LDT CALl. bDT -999, ~.50 SGR, bDT MTE~. LD.T -999' 250 ~LRES. L[)T 'RTNR.CNb -999,250 TNpH 'CNG R.C~T.CML -999,250 RCFT;Cb~b SG~. CNG -999,250 'CGR. CNG 25-JAN-!991 15:].4 ~999 250 999:250 -999,250 '999.250 -999,250 '999,250 '999.250 "999,250 '999,250 "999.250 '999.250 -999 250 '999 250 -999 ~50 -999 50 -999 250 1445 000 '999 250 '999 250 '999 250 '999 250 -999 250 -999 250 ~999 250 -999 250 -999 250 '999 250 -999 250 -999 250 '999 250 '999 250 -999. 50 -999 50 -999 250 ~999 250 -999 250 199 250 43 000 '999 250 ~999 ~999 50 -999 '999 .50 -999 ~50 -999 250 -999 250 -999 250 2999 2so 999 250 '999 250 !999,250 -999,250 -999,250 CGR.DTE HTEN,DTE PEP,bDT LU,GDT $S2,bDT bSRH,LDT CGR,GDT MTEN,LDT TNRA,CNb CNTC,CNL CALI,CNb HTEN,CNb POTA,NGT W3NG,NGT ~TEM,NGT GR,BGT ILM,DTE IDER,PHA IDQF,DTE XIRD DTE CGR:DTE HTEN,DTE PEF.LDT LU,GDT M$2.LDT GSRH,GDT CGR,LDT HTEN.bDT TMRA,CNG CNTC,CNL CALI,CNb HTEN,CNb POTA,NGT W3NG'NGT MTE~,NGT GR.BGT 'ILM.DTE IDER,PHA iDOF,DTE IIRD,DTE CGR,DTE HTEN,DTE PEF'GDT LU*bDT S$2,bDT bSRH,LDT CGR,LDT HTEN,bDT TNRA'CNL CNTC,CNL CALl,CML -999 250 -999' .250 '999,~50 -999.250 -999.250 999,250 999.250 999,250 999,~50 2999.250 -999 250 -999 ~50 -999 250 -999 ~50 -999 250 43 000 -999 250 -999 250 -999 250 -999 250 -999250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.25o -999.250 .999,250 999,250 209o.. so .999,250 .999,~50 .999,~50 31,969 -999.~50 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 ~50 -.999 250 -999 250 -999 250 -999 ~50 :999.250 .~99'.250 .~99'250 999.~50 TENS.DTE DPHI.LDT OLS.[.DT GL.GDT [,SHV.LDT bURH.LDT TENS.GDT NPHI,CNL NPOR,CNL CFTC,CNG TENS.CNG SGR.NGT URAN.NGT W4MG.NGT MRES.NGT C1.BGT ILD,DTE IDPH,DTE IMQF.DTE IIXD.DTE TENS,DTE DPHI.LDT OLS,LDT GL.bDT DSHV.DDT LURH.bDT TENS GDT SPOR,CNL CFTC,CHL TENS,CNG SGR.NGT URAN.NGT W4NG,NGT MRES,NGT C1.BGT IbD.DTE IDPH.DTE IMOF.DTE IIXD.DTE TENS,DTE DPHI,GDT QGS,LDT Lb,LOT LSMV,LDT LURM,bDT TENS,bDT NPHI.CNL NPO~.CNL CFTC.CNG TENS.CNG PAGE~ 25 '999 250 '999 250 '999 250 -999 250 '999 250 '999 250 °999 250 -999 250 -999,250 '999,250 '999,250 '999,250 '999,250 -999,250 '999,250 12,648 '999.250 -999 250 -999 250 '999 250 '999 250 '999 250 '999 250 -999 250 '999 250 '999 250 '999 250 '999 250 -999 250 '999 250 -999 250 '999 250 -999 250 '999 250 '999 250 I3 766 -999,250 -999,250 ~999,2.50 .999,250 .999,250 999'250 '999,250 '999,250 :999,250 .999,'250 '999,250 '999,250 i999,:250 999,250 999,250 $ Tape verification Listino hlumberoer Alaska ComPutin~ Center ~FS.CN5 -999,25(; MTE~.CNL CG~.NGT -999.250 THOR.NGT W!NG.NGT -999,250 W2N~:NGT w5~G,NGT -999,250 TEN NGT CS.~GT -999,250 HTEN.NGT C2.BG? 12,883 TENS,BGT DEPTo 1900.000 SFLU.DTE SP.DT~ ~999 250 IMER,PHA I~PH.DTE -999:250 IFRE.DTE CIDP.DTE -999.250 CIMP.DTE IIR~.DT~ -999,250 SGR.DTE ~TE~.DTE -999,250 MRES.DTE RHOB.LDT -999,250 DRHO,LDT bDT -999.250 LS,LDT OSS'b~T -999 250 SSi.LOT LITM, . $SHV.LDT -999,250 S1RH bDT CAL!.LOT -999.250 :GR:LDT ~TEU,LDT -999,250 MRES.LDT RTN~,CNL -999.250 TNPH.CNL RCNT.C~b -999,250 RCFT.CNL SGR.CNL -999,250 CGR,CNL ~RES.CNL -999 250 CGP.NGT -999:250 THOR:NGT W1NG.NGT -999,250 W~NG,NGT WSNG.NGT -999,250 T~NS,NGT S. N~T -999,250 HTEN,NGT ~.BGT 13.625 TEN$.BGT DEPT. 1800.000 SFLU,DTE :P.DTE -999,250 IMER.PHA I~PH.DTE -q99,250 IFRE,DTE CIDP.DTE -999.250 CIMP.DTE IIR~.DTE -990,250 SGR,DTE RHOR,LDT 999:250 RHO.LDT '~OSS.I.~DT 999.250 L$,LDT LIT~.LDT -999.250 :$1.LDT SSHV,LDT -999.250 S!RH.LDT CALl.LOT -999,250 SGR.LDT MTE~.LOT -999.250 MRES.LDT ~TN~.CNL -999.250 TNPH.CNb RCNT.CNL -999,250 RCFT.C~L SG~.CNL -999,250 CGR.CNL ~ES.CNL -999,250 MTEM.CNL CG~.NGT -999.~50 THOR NGT WiNG NGT -999'250 W2NG'MGT. WLNG:NGT -999,250 TENS,NGT CS,MGT -999.250 HTEN.NGT C~.~GT ~5.2~7 TENS.BGT DEPT. 1700.000 SFLU.DTE SP.~TE -999 250 IMER,PHA I~PH.DT~J -999~50 IFRE.DTE CIDP,DTF, -999.250 CI~P,DTE 25-jAN-199! I5:1~ -999 250 -999 ~50 -999 50 -999 250 2 000 -999.250 999.250 -999.250 -999.250 -999 25O '9991250 -999 25O -999 250 -999.250 -999.250 o -999.250 -999 25O -999:250 -999 25O ~999 250 -999 250 -999 25O 1270 000 -999 250 '999i250 -999 250 -999.250 -999.250 :999.250 999,250 -999.250 -999,250 '99 250 '9 ~50 '99 250 '99 250 '999 250 -999!~50 -999 250 '999 250 250 -999 250 '999i250 -999 250 -999.250 HTEN,CNb POTA,NGT W3NG.NGT MTEM,NGT GR,BGT ILM,DTE IDER,PHA IDOF,DTE IIRD,DTE CGR,DTE HTEN,DTE PEF,bDT LU,LDT SS2,LDT LSRH,LDT CGR,LDT HTEN,LDT TNRA,CNb CNTC CN[, CAbI:CNL HTEN,CNL POTA,NGT W3NG,NGT MTEM,NGT GR,BGT ILM,DTE IDER,PHA IDOF,DTE IIRD,DTE CGR,DTE NTEN DTE PEFiLDT LU bDT SS2,LDT bSRH,LDT CGR,bDT HTEN.LDT TNRA,CNL CNTC,CNb CALI..CNL HTEN,CNL POTA,NGT W3NG,NGT MTEM,NGT GR.BGT IL~ DTE IDER',PHA IDQF,DT~ IIRD,DT~ -999 250 -999 250 -999 250 -999 250 43 844 -999.250 -999.250 -999 250 -999:250 -999.250 -999.250 -999.250 -999 250 -999 25O -999 25O -999 250 -999 25O -999 25O -999 25O -999 250 -999 250 -999 250 -999,250 -999,~50 60.188 -999 250 -999 250 -999 250 -999 25O -999 250 -999 250 -999 25O -999 25O -999.250 -999,250 -999.250 -999 25O -999 25O -999 250 -999 25O -999 25O -999 25O -999 250 -999 250 82 500 -999.250 -999.250 -999.250 -999.250 SGR.NGT URAN.NGT W4NG.NGT ~RES.NGT Cl.BGT ILD.DTE IDPH.DTE IMOF.DTE IIXD.DTE TENS.DTE DPHI.LDT OLS.LDT LL.I.,DT LSHV.LDT LURH.LDT TENS.LOT NPHI.CNL NPOR.CNb CFTC.CNL TENS.CNL SGR.NGT URAN NGT W4NG:NGT MRES.NGT C~.BGT ILD.DTE IDPH.DTE IMQF.DTE IIXD.DTE TEN$.DTE DPHI.LDT OLS.LDT LL.LDT LSHV bDT TfNS,6DT NPHI,CNL NPOR,CNL CF~C,CNL TENS.CNb SGR,NGT URAN.MGT W4NG.NGT MRES.NGT CI.BGT ILD,DTE IDPH.DTE I~OF.DTE IIXD.DTE PAGE{ 26 -999 250 -999 250 -999 250 -999 250 13 344 '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 2999.250 .999o250 .999,250 '999,250 -999 250 -999 250 -999 250 -999 250 -999 250 999:250 -999,250 '999,250 ~,~56 '999 250 '999i250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 13,023 99 250 -999'250 -999:.~50 [$ ?at~e Yer~ficat. ion I, isting chlumber¢~er Alaska Computing Center I!R~.DTE -999.250 SGR.DTE ~TEg~DTE · -999.250 MRE&,DTE ~HOB.LDT -999,250 DRHO.LDT O$S.LDT -999.250 LS.LDT I.~T~.I.OT -~99.250 SS1.LDT 6SHV.I..DT -999.250 SIRH.bDT C~L!.LDT -999.250 SGR.LDT MT~.LD? -999.250 MRE$.LDT RTe'.CML -999,250 TMPH.CNL RCNT.C~L -999.250 RCFT.CNL SG~'CL, b -999.250 CGR,CNL ~PE$.C~L -999.250 ~TEM.CNL CG~.NGT -999.25fl THOR,NGT W~!'~G.NGT -999.250 W2NG,NGT W5~.NGT -999.250 TEN$,NGT CS.NGT -999.250 HTEN.NGT C2.~GT ~4.336 TENS.BGT DEPT. 1600. SP.DTE -999. IMPM.DTE -999. CIDP.DTE -999. IIRM.DT~ -999 MTEM.DTE -999 R~OB.LDT -999 OSS.LDT -999 ~T ..bDT -999, RTN~.C~b -999. RCNT'.C~L -999. SGR.CNL -999' MRES.CNL -999, CGR.SGT -999. W!NG.NGT -999, WLMG.NGT -999. C~.NGT -999. C .BGT 000 SFLU.DTE 250 IMER.PHA 250 IFRE.DTE 250 CIMP DTE 250 SGRiDTE ~50 MRE$ DTE 250 DRHO,bDT 250 L$.LDT 250 SSI.,GDT 250 250 SGR.LDT 250 ~RE$.LDT 250 TNPH,CNL 250 RCFT,CNL 250 CGR,CNL .250 ~TE~,CNL 250 T~OR;MGT 250 W2NG.NGT 250 TEN$,NGT 555 TE~S.BGT D~PT, 1500, SP.DTE -999. CYDP.D?E 999 ~TE~:DTE -999' ~OB,L[)T :999, ROSS.LDT 999, LIT~.LDT 999, SSHV.LDT :999, CAbI.I. DT -999, MTE~{.LDT -999. RTNR.CNb -999, RCDT,C~{[~ -999. SGP.ChL -999, 25-JAN-1991 15:]4 -999.250 -999.~50 -999,250 '999.250 -999.250 -999.250 -999.250 -999.250 '999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 !240 000 -999 250 -999 250 -999 250 -999 250 ~999 250 .999 250 '999 250 999 25O -999 250 -999 50 -999 ~50 -.999 250 ~999 25 -999 25~ -999 250 -999 250 -.999 250 '999! 50 1230 ~00 000 SFGU.DTE -999.250 250 INER.PHA -999.250 250 IFRE DTE -999,250 250 CIMP:DTE -999.250 250 MRE :DTE 999'2 0 ~50 DRHO.LDT -999;2~0 250 L$.LD~ -999'2 0 250 SSI,bDT -999,2~0 250 NRES.bDT 999.2 0 250 TNPH.CNL ..999.250 250 RCFT CNb 2999;250 250 CGR:CN5 -999i ~50 CGR,DTE MTEN.DTE PEF,bDT bU.bDT SM2.LDT bSRH.LDT CGR,bDT HTEN bDT CNTC,CNb CALI.CNb MTEN,CNb POTA.NGT W3NG,NGT MTEN,NGT GR,BGT IbM DTE ~DER:PHA IDQM,DTE IIRD,DTE CGR.,DTE HTEN,DTE PEF,bDT LU,bDT 8S2.,bDT bSRH'bDT CGR~bDT HTEN,bDT TNRA,CNL CNTC,CNL CALl,CML HTEN"CNL POTA,NGT W3NG,NGT MTE'~.NGT GR,BGT ILN,DTE IDER.PHA IDQF,DTE IIRD,DTE CGR,DTE HTEN,DTE PEF,LDT LU~DT S$2:. DT 'LSRH,hDT CGR'bDT HTEN,bDT TNRA,CNb CNTC.CNL CALI.CNL -999.250 -999.250 -999.250 -999.250 -999.250 -999.25O -999.250 -999.250 -999 25O -999 ,250 -999 25O -999 250 -999 25O -999,250 -999.250 62.063 '999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 RLO -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 65..125 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 25O -999 25O -999 250 -999 250 -999 25O -999~50 -999 250 -999 250 -999 .250 TENS.DTE DPHI.LDT OBS.LDT LL.LDT bSHV.LDT LURH bDT TENS:LDT NPHI,CNL MPOR.CNL CFTC.CML TENS.CNL SGR.NGT URAN.NGT ~4NG.NGT NRES.NGT C1.BGT ILD.DTE IDPH.DTE IMQF.DTE IIXD.DTE TEN$.DTE DPHI,LDT ODS.bDT bb,LDT bSHV,LDT bURH,LDT TENS LOT NPHI:CNL NPOR CNL TENS.CNL SGR.NGT URAN.NGT W4NG,NGT ~RES.NGT C1.BGT ILD.DTE IDPH.DTE IMQF.DTE IIXD,DTE TENS.DTE DPHI.DDT 'QLS.LDT LL.LDT bSMV.bOT bURH.LDT TEN$.LDT NPHI.CNL NPOR.CNL CFTC.C~L TENS.CML PAGE~ '999.250 '999 250 -999 250 -999 250 -999 250 '999 250 -999 250 -999 250 -999 250 -999,250 -999.250 '999.250 -999.250 '999.250 -999'250 12.719 '999,250 '999.250 '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 '999,'250 '999.250 '999,250 '999,250 '999.250 '999,250 '999,250 '999.250 2999 50 '999.250 13.242 '999,250 '999 250 '999 250 '999 250 -999 .250 '999 250 '999 250 -999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999'250 -999'250 27 $ TaDe veri. f]catlon Listinq :hlUmberser Alaska ComDutlno Center ~PES.C~ib -999.250 ~TE~.CND CGR.NGT ~999 250 THOR.NGT W1NG.N(;T 999~250 W2NG.NGT WSNG.NGT -999.250 TENS.NGT CS,NGT -999.250 HTEN.NGT C~.BGT 26.3!3 TENS.BGT DEPT. 1.400.000 SFLU.DTE 8P.DTE -999.250 IMER.PHA IMPN.DTE -999.250 IFRE.DTE CIDP.DTE -999.250 CIMP.DTE IIR~.DTE -999.250 SGR.DTE ~TE,.DT~ -999.250 MRES.DTE RHOB,LI)T -99g.~50 DRHOiLDT OSS bDT 1999 250 L$.LDT LITN~!.,OT -999~250 SSI.bDT SSHV.b[>T -999.250 SIRH.LDT CALl.bDT -999 250 SGR.LDT NTE~.LDT -999:250 ~RES.LDT RTN~.C~L -999.250 TNPH.CNL RCNT.C~b -999,250 RCFT,CNL SGR.C~L -999.250 CGR.CNb M~ES.CkL -999.250 ~TEM.CNL CG~.NGT -999.250 THOR.NGT WlM~.NGT -999.250 W2NG.NGT WBN~.NGT -999.250 TENS.NGT C$.~GT -999.250 HTEM.~GT Cg.BGT 14.211 TENS.BGT DEPT. 1300,000 SFbU.DTE SP.DTE -999.250 IMER.PHA IMP~.DT~ -999.250 IFRE.DTE ~DP DTE -999.250 CIMP DTE R~:DTE -999.250 SGR:DTE ~TE~.DTE -999.250 MRES.DTE RHOR.I, DT -999.250 DR~O.LDT DSS.bDT -999.250 LS.LDT L!TN. LDT -999,250 SS1, LDT SSHV.[.DT -999.250 S!RH.LDT CALI.LOT -999.250 SGR.LDT ~TE~.LDT -999,250 MRES.LDT RCNT.CNL '999,250 RCF CNL - 99.Z5o CGR'C CGP.NGT -999.250 THOR.NGT WlNG.NGT -999,250 W2NG,NGT WSNG.NGT -999,250 TENS.NGT CS.MGT -999.250 HTEM.NGT C?.~GT 15,~88 T£NS.BGT DF..PT, 1200.00(.} SFbU.DTE ,~P DTE -999 250 IMER.PHA I~.~M~DT~; -999:250 IFRE.DTE CIDP.DT~ -999,250 CI~P.DTE 25-JAN-1991 15:14 '999 250 HTEN.CNL '999:250 POTA.NGT '999.~50 W3NG.NGT '999.250 ~TE~.NGT '999.~50 GR.BGT 1110.000 -999.250 -999 250 -9 0 250 '999 250 '999 250 '999 250 '999 250 :999,250 999.250 -999.250 -999,250 -999 250 -999~250 -999 ~50 -999. 50 '99~,250 10! ,000 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 ~999.250 -99 250 -99 250 -99 250 -999.250 -999.250 5O -999.~50 900.O00 -999.250 -999.250 -999.250 -999.250 IbM.DTE IDER,PHA ID~F,DTE IIRD DTE CGR:DTE HTEN.DTE PEF.LDT bU,GDT SS2.LDT LSRH,LDT CGR.bDT HTEN.LDT TNRA.CNL CNTC.CMb CALI.CNL HTEN.CNb POTA.NGT W3NG.NGT MTE~,NGT GR,BGT ILM,DTE IDER,PHA IDOF,DTE IIRD,DTE CGR,DTE HTEN,DTE PEF'LDT LU,bDT S$2.LDT LSRH.LDT CGR,bDT HTEN,LDT TNRA,CN5 CNTC,CNb CALI.CNL HTEN CNL POTA:NGT W3NG.NGT MTEM,NGT GR.BGT IDM,DTE IDER,PHA IDOF.DTE IIRD,DTE -999 250 -999 250 -999 250 -999 250 49 375 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 250 -999 250 -999 250 -9991250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 73.06] -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 ~50 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 72.938 -999.250 -999.~50 -999.250 -999.250 SGR.NGT URAN.NGT W4NG.NGT MRES.NGT CI..BGT ILD.DTE IDPH.DTE IMOF.DTE IIXD DTE TENS:DTE DPHI.LDT QLS.LDT bb.bOT bSHV,LDT bURH.LDT TE~S.LDT NPHI C~L NPOR~CNL CFTC.CNL TENS.CNL SGR.NGT URAN.NGT w4NG.NGT MRES.NGT CI.BGT IbD.DTE IDPH.DTE IMQF.DTE IIXD.DTE TENS.DTE DPHI.LDT QLS.LDT LL.LDT I, SHV.LDT LURH.LDT TENS.bDT NPHI.CNL NPOR.CNL CFTC.CNL TENS.CN[. SGR.NGT URAN.NGT W4NG.NGT MRES.NGT C1.BGT ILD.DTE IDPN.DTE I~QF.DTE IIXD.DTE PAGE: 28 '999.250 '999.250 .'999.250 999.250 2~.453 ~999.250 999.250 .250 -999 250 -999i250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 13,391 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 =999 25O -999 250 -999 25O 999.250 :999,250 -999,250 -999.250 13,008 -999.250 i999..250 999.250 999.250 Tame Yer~ficatlon Listing chlUmbermer Alaska ComPuting Center I;R~,DTE -999,250 SGR,DTE MTE~.DTE · -999,250 MRES,DTE R~OP.LOT -999,250 DRHO,LDT OSS,LDT -999,250 DS,DDT LIT",L~T '999,250 SS1,LDT SSHV,LOT '999,250 S1RH,LDT C~BI,LDT '999,250 SGR,LDT ~TE~.BDT -999,250 ~RE$,LDT RTN~.CNL '999,250 TNPH CNb RCLT,CNL '999.250 RCFT,CNL SG~.C~L -999.250 CGR,CNL .RE$,CNL -999,250 ~TE~,CNL CGP.NGT -999.250 THOR,NGT w1NG,NGT -999,250 W2NG,NGT WLNG.NGT -999.250 TENS,NGT CS.NGT -999,250 HTEN,NGT C2.BGT 16.063 TEN$,BGT DEPt. 1100,000 SFbU,DTE SP.F)TE -999 250 IMER,PHA I~PN.D:CE -999~250 IFRE,OTE C!{)P.DT~ -999.250 CIMP,DTE IIRU,DTE -999 250 SGR,DTE ~TE~.DTE -999:250 NRES,DTE R~O~.LDT -999,250 DRHO BDT OS~.LDT -999.~50 D$1LDT LfT~,LOT -999,250 SSi bDT SSHV.I..OT -999,250 S1RH DDT CALl,bDT -999,250 SGR,LDT M~E~.LDT -999,250 MRES DDT RTN~.CNL -999,250 TNPH:CNL RCNT.CNL -999.250 RCFT CNL SG~,CNb -999,250 CGR~CND MRES,CNL -999,250 MTEM,CN5 CG~ NGT -999'250 THOR,NGT W~,N~:.N~T -999,250 W2NG,NGT wLN~ NGT -999,250 TEN$,NGT CS'NGT -999,250 HTEN NGT C~,EGT ~7,094 TEN&,BGT DEPT. 1000,000 SFbU.DTE 8P,DTE '999,250 I~ER.PHA I~P~.DTE '999,250 IFRE DTE CIDP,[.Tg -999,250 CI~P DTE II~.[>TE -999,250 SGR,DTE ~TE~.[)T~i -999.250 MR~S,DTE RHOB,bDT -999,250 I.)RMO.LDT OSS,[.DT -999,250 DS,BDT LITW DDT -999,250 SSi LDT o~{V bDT -999,250 S1RH:bDT CALI.LDT -999,250 SGR,LDT MTE~.LDT '999,250 MRES, I, DT RTNR.CNL -999,250 TNPH,CNL RC~T,CNL -999,250 RCFT CNL SGR,Ci~L -999,250 CGR:CNL 25-JAN-1991 15:14 -999,250 -999,250 -999 ~50 '999 50 "999 250 "99 50 '99~ 2 25O "999 250 '999,250 '999 250 "999:250 '999,250 '999 ~50 '999 250 '999 ~50 '999 50 745 000 "999,250 '999,250 '999 250 '999 250 '999 250 '999 -9 250 '999 250 '999 250 '999 250 '999 '999 50 '999 250 -99 0 '999 250 "999 ~50 610 000 -999 250 '999 ~50 '999 ~0 '999 250 '999 ~50 '999 250 '999 ~50 -999 50 -999 250 -999 250 -999 250 -999 250 -999 250 :999 250 999 25O CGR,DTE HTEN,DTE PEF,LDT LU,GDT SM2,bDT bSRH,LDT CGR,bDT HTEN,bOT TNRA,CNb CNTC,CNb CADI,CNL HTEN,CNL POTA,NGT W3NG,NGT ~TEM,NGT GR,BGT ILM,DTE IDER.PHA IDOF,DTE IIRD,DTE CGR,DTE HTEN,DTE PEF,bDT LU,bDT SM2,LDT bSRH,BDT CGR,bDT HTEM,bDT TNRACNL CNTC!CNb CAbI CNL gTEN,CNb POTA'NGT W3NG,NGT ~TE~.~MGT GR~BGT IbM,DTE IDER,PHA IDQF,DTE IIRD,OTE CGR,OTE HTEN'DTE PEF,LDT DU,LDT SS2,bDT bSRH,LDT CGR bDT HTEN:BDT TNRA.CNb CNTC,CNb CALl,CML -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 '999.250 -999.250 999,250 66,875 -999,250 -999 25O -999!250 -999 250 -999.250 99.25O -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 -999 250 -999 .250 -999 ~50 59 219 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 999,250 -999.250 TENS.DTE DPHI,LDT OLS.bDT LL.LDT GSHV,LDT LURH.bDT TENS,bDT NPHI.CNL NPOR.CNL CFTC.CNb TENS,CNL SGR,NGT URAN,NGT W4NG,NGT MRES.NGT C~.BGT ILD.DTE IDPH,DTE IMOF,DTE IIXD DTE TENSiDTE DPHILDT ODS,DDT LL.LDT LSHV,LDT LURH.LDT TENS BDT NPHI'CNB. NPOR,CNb CFTC,CNb TENS,CN[, SGR.NGT URAN'NGT W4NG NGT NRES:NGT C1.BGT IbD. IDPH. IMOF. IIXD.. TENS. DPHI. Lb. bSHV. bURN. TENS NPHI~ NPOR, TE~S: DTE DTE DTE DTE DTE LDT BDT LOT bDT bDT bDT CNb CNL CNL C N L PAGE: 999 250 -999.250 -999.250 -999.250 -999,~50 -999,250 -999,250 '999,250 '999,250 '999 250 '999 250 '999 250 '999 250 '999 250 ~3,883 '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 "999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 "999,250 '999,250 13,,016 '999,250 '999,250 '999.250 '999.250 '999,250 '999.250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999'250 999,250 29 .q ~'a~e Yertfication [.isting blUmberc~er AlasKa ComputinO Center MPYS.C~iL -999.25(, MTEM.CNL CGP.NGT -999.250 THOR,NGT W]NC.NGT -999,250 W2MG,NGT WL~!G.NGT -999.250 TEN$.NGT C$.NGT -999,250 HTEN.NGT CP.BGT 16,156 TENS,BGT D~PT, 900,000 SFLU,DTE SP.DTE -999,250 IMER,PHA I~PN.DTE -999.250 IFRE,DTE CIDP,DTE -999,250 CIMP,DTE IIR~,DTE -999,250 SGR,DTE ~TE~.~TE -9g9,250 MRES,DTE RHOF,LDT -999,250 DRHO,LDT OSS.5DT -999.250 LS,hDT LITH.bOT -999.250 SSi,LOT SSHV.L~T -999,250 SIRH,LDT C~LI.L~T -999.~50 SGR.LDT ~TE~,LDT -999.250 ~RES,DDT RT~P.C~]L 2999 250 TNPH,CN5 RC~,T,CUL 999~250 RCFT,CNL SGP.Ci~L -999.250 CGR.CNb ~ES.C~\iL -999.250 ~TEM CNL CG~.MGT -999.250 THOR:NGT wlN(;.NGT -999.250 W2NG,NGT w5~.NGT -999.250 TENS,NGT CS,~GT -999,250 HTEM.NGT CP.BCT ~7.734 TENS.BGT OEP?. 800.000 SFLU.DTE SD.DTM -999.250 IMER,PHA I~PH,DTK -999,250 IFRE.DTE CIDP.DTE -999,250 CIMP.DTE IIRm.DRTE -999.250 8GR,DTE ~TE~.D.E -999.250 MRE$,DTE ~O~.[,OT -999.250 DRHO.LDT OSS,[..DT -999.250 LS,LDT LITe. LOT -999 250 $81 bDT ,bDT -999:250 SIRH:bDT C~LI.LDT -9g9.250 SGR,LDT MTE~.[..OT 999 250 ~ES.LDT PTN~.CNL :999:250 TdPH'CNL RCNT,C~L -999,250 RCFT,CNL SG~.C6!L -999.250. CGR,CNL M~ES.C~L -999,250 ~TEM CNL CG~.~GT -999,250 THORiNGT W~G.~GT -999,250 W2NG NGT wLNG.NGT -999,250 TENS.NGT CS.NGT -999.250 HTEN.NGT C2.i~CT 1.7.016 TENS.BGT DEPT. 700,000 SFbU,DTE SV.DTE -999,250 IMER.PHA !~P~.DTE -999.250 IFRE.DTE C!DP.DTK -990.250 CIMP.DTE 25'JAN-1991 15:14 -999,250 -999 250 -999 250 -999 250 -999 250 460 000 -999.250 -999,250 -999,250 -999,250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999:250 -999,250 999.250 999'250 -999.250 -999 250 -999~250 -999.250 365,000 -999.250 -999.250 -999.250 -999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999,250 '999,250 -999, 0 -999,250 -999,250 -999,250 -999,250 999.250 999.250 999.250 340.000 .~999 250 999."250 2999,250 999.250 HTEN,CNL POTA.NGT W3NG,NGT MTEM,NGT GR,BGT XL~,OTE IDER,PHA IDOF,DTE IIRD,DTE CGR,DTE MTEN,DTE PEF,LDT LU,LDT SS2,LDT bSRH,LDT CGR.bDT HTEN,LDT TNRA,CNb CNTC,CNL CALI,CNb HTEN,CNL POTA'NGT W3NG,NGT MTE~,gGT GR,BGT ILM,DTE IDER,PHA IDOF,DTE IiRD,DTE CGR,DTE HTEM,DTE PEF,bDT bU,bDT SS2,LDT bSRH,LDT CGR'bDT MTEN,bDT TNRA,CNb CNTC,CNb CAbI,CNb POT W3NG,NGT MTEM,NGT GR,BGT ILM,DTE IDER.PHA IDQF,DTE IIRD,DTE -999 250 -999 250 -999 25O -999 250 64 625 -999,250 -999.250 999,250 999,25O 999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999 ~50 -999 50 -999 250 -999 250 -999 250 -999 ~50 -999.250 59o875 -999'250 -999:250 -999.250 -999.250 -999'250 -999.~50 -999. 50 -999.250 -999,250 -999 250 -999:250 -999.250 -999,250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 7~ 938 -999 250 -999:250 -999.250 -999.250 SGR.NGT URAN.NGT W4NG.NGT ~RES.NGT C!.BGT ILD.DTE IDPH.DTE IMOF.DTE IIXD.DTE TENS.DTE DPHI bDT QLS:LDT LI,.LOT bSHV.bDT LURH.bDT TENS,bDT NPHI.CNL NPOR.CNL CFTC.CNL TENS.CNL SGR.NGT !IRAN.NGT ~4NG.NGT MRES.NGT C1.BGT ILD.DTE IDPH.DTE I~OF.DTE IIXD DTE TENS:DTE [)PHI bDT 'QLS:LDT bb.LDT LSHV.LDT LURH.bOT TENS.bDT NPHI.CNL NPOR.CNL CFTC CNL TENS:CNL SGR,NGT URAN.NGT W4NG,NGT MRES,NGT Cl.BGT ILD.DTE IDPH.DTE I~QF.DTE II×D.OTE PAGE: 30 -999 250 '999i250 -999 250 -999 250 13,297 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '9991250 -999 250 -999 250 -999 R50 -999 250 -999 250 -999,250 :999,250 999,250 9 250 -999,250 -999.250 14,148 '999,250 '999,250 '999,250 '999,250 '999,250 '999,~50 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999,250 '999,250 '999,250 '999,250 13.625 ~999,250 999,250 -999,250 -999,250 :hlumherqer Alaska Comoutinq Center IIR~.D~ -999,250 SGR,DTE ~TE~.r~?F · -999,250 MRE$.DTE ~HDP.[,DT -999.250 DRHOi bDT OSS.bDT -999.250 bS,LDT LI?~.LOT -999,250 881.LDT SSHv.LDT -999.250 S1RH.LDT CALl.bDT -999,250 SGR,bDT ~TE~.LDT -999.250 ~RE$,LDT ~TN~.CNL -999,250 TNPH,CNL RCNT.CNb -999,250 RCFT,CN5 SG~.CN!5 -999,250 CGR,CNL MRES.CNL -999.250 ~T£M.CNL CG~.NGT -999.250 THOR,NGT W~NG.NGT -999,250 W2NG,NGT W5NC.NGT -999.~50 TEN$,NGT C$.NGT -999,250 HTEN,NGT C~.~GT 18.172 TENS,BGT DEPT. 600,000 SFLU.DTE SP.DTE -999.250 IMER.PHA I~FH.DTE -999,250 IFRE.DTE CIDP.DTE -999,250 CIMP,DTE tIR~.DTE -999 ~50 SGR.DTE ~TE~'~.DTE '999i250 MRE$,DTE RMOB.LDT -999 250 DRHO,BDT QS$.[,DT i999,250 bS.LDT b!TH.L. DT 999,250 SSI'bDT $$Hy.t. DT 999,250 S1RH.bDT CAI......[.,DT -999.250 SGR.LDT MTE~,LDT -999.250 ~RES,LDT RT~!~.CNL -999,250 TNPH.CNL RCNT,CS]iL -999.250 RCFT,CNL SG~.CNL -999 250 CGR.CNb M~ES.CNL -999:250 ~TEM,CNL CGR,NGT -999,250 THOR,NGT W~NC.NGT -999,250 W2NG,NGT w5NG,NGT -999'250 TE~$'NGT CS NGT -999,250 HTEN,NGT C~:BGT 18,64~ TEN$,BGT DEPT, 500, SP.DTE -999 I~PH D~E -999"~ C.XDP: OTE -999 .I. ! R P..DTE -999 ~TEM,DTE -999 RHOB. L, DT -999 OSS. Li)T -999 blTN, [..,DT -999 SSHV. L[)T -999, CA!..,I'LDT -999, MTE~, [,,DT -999, RTNR, C~[.,, -999. $GP. C ~:,~ [,, -999 ' 000 SFbU.DTE 250 I~ER,PHA 250 IFRE,DTE 250 CIMP,DTE 250 SGR,DTE 250 MREM,DTE 250 DR~O,bDT 250 LS.LDT 250 SS1 bDT 250 $1RH:bOT 250 SGR.LDT 250 MRES,LDT 250 TNPH,CNL 250 RCFT,CNL 250 CGR,CNL Mb'dAN-1991 15114 -999.250 -999.250 :999 250 999 250 -999 250 -999 250 -999 250 -999 250 '999 250 -999 250 -999 250 -999 25O ~999 250 -999 250 -999 250 -999 250 260 000 -999.250 -999,250 -999,250 -999,250 -999 250 -999 250 ,999 250 .999 250 -999 250 '-999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 230 000 -ggg ~50 -999 50 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 -999,250 -999,250 CGR,DTE HTEN,DTE PEF,bDT bU,bDT 8$2,LDT bSRH,bDT CGR,bDT HTEN,bDT TNRA,CNb CNTC,CNL CAbI,CNb HTEN,CNb POTA,NGT W~NG,NGT MTEM.NGT GR,BGT I[,M.DTE IDER,PHA IDOF,DTE IXRD DTE CGR DTE HTEN DTE PEF bDT LU LDT 852 bDT LSRH:bDT CGR bDT HTEN:LDT TNRA CNL CMTC:CNL CAbI,CNL HTEN,CNb POTA,NGT W3NG,NGT MTEM'NGT GR,BGT ILM,DTE IDER,PHA iDQF PTE IIRD DTE CGR DTE "HTEN DTE PEF bDT LU BDT SS2'bDT LSRH,bDT CGR,bDT HTEN,bDT TNRA CNb CNTC:CNL CALI,CNb -999 25O -999 250 -999 250 -999 250 -999 250 -999 25O -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 57 25O -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999:250 -999 250 -999 250 -999 250 -9gg 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999250 65 750 -999 250 -999 250 -999 250 -999 250 -999250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TENS,DTE DPHI,LDT OhS,bDT Lb,bDT [,SHV,LOT LURH.LDT TENS.bDT NPHI,CNL NPOR.CNL CFTC.CNb TENS,CNb SGR.NGT URAN.NGT W4NG.NGT MRES,NGT C1.BGT ILD.DTE XDPH.DTE IMQF.DTE IIXD.DTE TENS,DTE DPHI,bDT QLS.LDT bb bDT LSHV:LDT LURH,bDT TENS,bDT NPH!,CNL NPOR.CNL CFTC,CNL TENS.CNL SGR,NGT URAN.NGT W4NG,NGT ~RES.NGT CJ.BGT IbD.DTE IDPHDTE IMQFiDTE IIXD DTE TENS DTE DPHI,LDT QLS,LDT LL.bDT LSHV.bDT LURH.LDT TENS.BDT NPHI,CNL NPOR.CNb CFTC,CNb TENS,CML -999. -999, -999, -999, -999, -999, -999, -999, -999 -999 -999 -999 -999 -999 -999' ~4, -999, -999, -999. -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 '999: -999. 999 31 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 078 250 250 250 250 250 250 250 ,250 250 250 250 250 250 25O 250 250 250 250 250 078 250 250 250 250 250 250 250 250 250 250 250 250 250 25O .250 .IS la~e Verification blstln~ chlumberqer Alaska Comptjting Center ~RES,CK!L -999.250 MTEg,CNL CGR.~.!GT -999.250 THOR,NGT w!.t{G,NGT -999.250 W2NG,NGT WS~G.N~T -9~9,250 TENS.NGT C$.~'~GT -909,250 HTEN.NGT CP.BG? 18,57~ TEN$.BGT DMPT. {00,000 SFb!I,DTE SP.DT~ -999,250 IMER,PHA I~PH.DT~ '999,250 IFRE,DTE CIDP.QTE '999.250 CI~P,DTE IIR~.DTE '999,250 SGR,DTE MTE~.DTE -999,250 MRES,DTE ~HOB.I. DT 1999 ~50 DRHO LDT OS$.LDT -999:250 kS:bDT UITH.LDT '999,250 SSI,bDT SSHU.bDT '999,250 $~RH,LDT CALI,L~T :999,250 SGR,LDT ~TE~.bDT 999,250 MRES,LDT RT~R,C~b -999,250 TNPH,CNL RCNT,CNL '999.250 RCFT,CNL SGR,CNL '999 250 CGR,CNL MRES.CNL -999!250 ~TEM,CNL CG~oNGT -999 250 THOR NGT WJNG,N,i.%T -999,250 W2NG:N~T WSNG,NGT -999,250 TEN$,NGT CS.~GT -999,250 HTEN,NGT C~.BGT 15.836 TENSoBGT 300,000 SFLU, DTE SP. [')TI{ -999.250 IMER.PHA 1' ~", r,, ~. [',., T E -99g.250 IFRE, I.)TE C~DP,DTE -999.250 CI~P.DTE DTE -999,250 SGR, DTE DTE -999,25,9 ,,RES DTE PHOIq. Li)? -999.259 DRHO:LDT I,D? -999. 250 kS. bDT bDT -999,250 SS l, bDT SSMV, [.L.T -999.250 S1RH,LDT bDT -999. 250 SGR. bDT LDT -999,250 gRES,LDT RTNR. C~J!~. -999,250 TNPN.CNb RCNq".CNL -999,250 RCFT,CNL C~.~L -999,250 CGR.CNL ~RES,CNL -999 250 ~TEM,CNL NGT -999: 250 THOR. NGT NI. NG, NGT -999,250 W2NG NGT WSNG.NGT -999,250 TENS:NGT CS.NGT -999,250 HTE.N, NGT C~.SGT 16,39! TENS.BGT DEPT. 200.000 SFbU,DTE SP.DTE -999.250 IMER,PHA I~P~,DTE -999.250 IFRE.DTE CIDD.DTE -999.250 CIMP.DTE 2b-dAN-1991 15:14 '999,250 -999.250 -999 ~50 -999 50 -999 250 285 000 -999,250 '999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999 ~50 -999 250 -999 250 -99~ 250 -99 250 -999 250 -999 250 -999 ~50 -999 250 -999 250 325.000 -999,250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.~50 -999,250 -999.250 -999,250 -999 250 -999~250 -999,250 -999,250 -999,250 -999.250 -999'250 -999!250 385 000 '999,250 '999.250 '999,R50 '999.250 HTEN,CNb POTA.~GT W3NG,NGT MTEN,NGT GR,BGT Ib~,DTE IDER,PHA IDOF,DTE IIRD,DTE CGR,DTE HTEN,DTE PEF,LDT LU,LDT SS2,5DT bSRH.LDT CGR,bDT HTEN bDT CNTC,CNb CALI,CNb HTEN,CNL POTA,NGT W3NG,NGT STEM GR~BGT IbM,DTE IDER.PHA IDOF.DTE IIRD DTE HTEN.DTE PEF,bDT LU,bDT SS2,LDT bSRH,bDT CGR,LDT HTEN,bDT TNRA'CNL CNTC,CNb CAbI,CNb HTEN,CNL POTA NGT W3NG:NGT STEM,NOT GR,BGT IBM DTE IDER:.PHA IDQF DTE IIRD:DTE -999.250 -999 250 -999:250 -999,250 34,594 -999,250 -999 250 -999 250 -999250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 '250 -999 250 -999 250 -999 250 45 469 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999:250 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 25O -999 25O -999i250 -999 250 .. .281 -99g.250 -999.250 -999.250 -999.250 SGR,NGT URAN.NGT W4NG NGT MRES:NGT CI,BGT IbD.DTE IDPH.DTE IMQF,DTE IIXD,DTE TENS,DTE DPHI.bDT OLS.LDT Lt,,LDT bSWV,bDT bURH.LDT TENS.bDT NPMI CNb CFTC,CNb TENS.CNb SGR.NGT URAN,NGT W4NG,NGT ~RE$.NGT C1.BGT !LD,DTE IDPH.DTE IMOF.DTE II×D.DTE TENS.DTE DPHI.bDT QLS.LDT Lb. LDT LSHV,LDT bURH.LDT TENS.bDT NPHI.CNL NPOR.CNt, CFTC.CNb TEM$.C~L SGR,NGT URAN,NGT ~4NG.NGT ~RES.NGT Ci.BGT IbD.DTE IDPH.DTE IMQF.DTE IIXD.DTE PAGE: 32 '999,250 '999,250 '999,250 '999,250 16,422 -999,250 -999 250 -999:250 -999,250 -999,250 -999,250 -99 250 -99 250 -99 ~50 999,250 -99 250 -99 250 -999,250 -999,250 -999.250 15.453 '999,250 '999.250 '999,250 '999.250 '999.250 '999.250 '999.250 '999.250 '999.250 -999,250 -999.250 -999'250 '999,250 '999,250 '999,250 '999.250 2999'250 999,250 -999,250 16,672 -999,250 -999.250 -999.250 -999.250 hlumberqer Alaska Computing Center IIRM.DTE -999,250 SGR,DTE MTE~.DTK · -999,250 MRES,DTE R~OR.LDT -999,250 DRHO.bDT OS$,L~T -999,250 b$,LOT LITH,LDT -999,250 SSI,bDT SS}IV,GDT -999,250 SIRH.LDT CALt.Lr>T -999.250 SGR.LDT STEm.bDT -999'250 MRES.LDT RTN~.CNL -999.250 TNPH,CNL RCNT.C~L -999,250 RCFT,CNL SG~.C~b -999,250 CGR.CNL MRE$,C~I.. -999,250 ~TE~,CNL CG~.~GT -999,250 THOR.NGT WlMG.~GT -999,250 W2NG'NGT WL~.MGT -999,250 TENS,MGT CS NGT -999,250 NTEN,NGT C2:BG¢ 23'703 TENS.BGT DEPT. 100,000 SP.DTE -999,~50 I~PM.DTE -999,250 CIDP,DTE -999,2~0 II,~.DT~ :~99 250 99: 250 RHOB,I.UT '999,250 OSS.LDT -999,250 LITNoI.,DT -999,250 SStiV.I.{)T -999,250 CALI.LDT -999,250 MTEU.LDT -999,250 RTNR.C~L -999,~50 RCNT.C~.~b -999.250 8G~.CNb -999,250 ~RES.CNL -999,250 WING ~[G'T _999 50 . 999 50 WSNC. mT CS.NC; -999 25O SFbU.DTE IMER,PHA IFRE,DTE CI~P.DTE SGR,DTE MRES,DTE DRHO'LDT LS,LDT SSl,t, DT S1RH,LDT SGR,LDT MRE$.bDT TMPH CML, RCFT:CML CGR.CNL MTEM.C~L THOR NGT W2~G:NGT TENS NGT HTEN:NGT TENS.BuT DFFT. 94,000 SFbO,DTE BP. 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C ~,~ [, -999. 250 CGR, CML Zb-daN-1991 lb:14 -999 250 -999~50 -999,250 "999 250 '999 250 '999 250 '999 250 '999 250 '999,250 '999 250 '99~ 250 '99 250 99 250 -999 250 25O 4 . 0 999i250 999 250 999 250 -9 ~50 '999 ~50 so 999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 315 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 50 -999 250 -99~ 250 '999 0 -999,250 CGR,'DTE HTEN,OTE PEF,bDT LU,bDT SS2,bDT LSRH,bDT CGR,LDT HTEN,LDT TNRA,CNb CNTC,CNb CAbI,CNb HTEN,CNL POTA,NGT W3NG,NGT MTEM,N~T GR,BGT ILM,DTE IDER,PHA IDOF,DT~ IIRD,DTE CGRDTE HTEN:DTE PEF,bDT GU,bDT SS~,LDT bSRH.LDT CGR.bDT HTEN,.LDT TNRA,CNL CNTC,CNL CAbI,CNL HTEN,CNL POTA,MGT W3NG,NGT NGT ~TEM, C GR'B~T IL~,DTE IDER,PHA IDOF,DTE IIRD DTE CG~ DTE HTEN .DTE PEF bDT bU bDT $$2,bDT bSRH,bDT CGR.,LDT HTEM,bDT TNR~,CNL CNTC,CNb CALl,CML -999 250 TENS.DTE -999 250 DPMI.LDT -999 250 -999 250 GL.bDT -999 250 bSHV.LDT -999 250 LURH.LDT -999 250 TENS.bDT -999 250 NPHl,CNb -999 250 NPOR,CNb -999 250 CFTC,CNG -999 ~50 TENS,CNG -999 250 SGR,NGT -999 250 URAN.NGT -999 ~50 W4NG.NGT -999 250 MRES.NGT 34.219 CI.BGT -999 250 IDD.DTE -999 250 IDPH.DTE -999 250 IMQF.DTE -999 250 IIXD.DTE -999 250 TEN$.DTE -999 250 DPHI.LDT -999 250 QLS.LDT -999 250 GL.bDT -999 ~50 bSHV.LDT -999 50 I,U~.H.LDT -999 ~50 TENS,LDT -999 250 NPMI.CNb -999 250 NPOR CNG -999 ~50 CFTC:CNG -999 ~50 TENS,CNG -999 50 SGR,MGT -999 250 URAN NGT -999 250 W4NG:NGT -999 250 MRES,NGT 21.297 CI,BGT -99.9,250 ILD.DTE -999 250 IDPH.DTE -999!250 IMQF.DTE -999 250 IIXD.DTE -999 250 TENS DTE -999 250 DPHI!LDT -999 250 OhS bDT -999 250 I.L bDT -999 -Egg -999 -999 -999 -999 -999 250 I, SHV bDT 50 LURH bDT 50 TENS bDT 250 NPHI CNG ~0 NPO~ CNb 0 CFTC:CNG 250 TENS,CML -999,250 '999,250 -999,250 '999,250 '999.250 i999,250 999,250 999,250 999,250 '999,250 '999,~50 '999,250 '999 250 '999:250 '999,250 23,938 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 25O -999 250 -999 25O -999 250 -999 250 -999 ~250 -999 250 -999 250 -999 .250 -999 250 -999 250 -999 250 12 953 -999,250 -999,250 '999,'250 '999.250 -999 250 -999 250 999 ,250 999 250 -999 -999 250 -999 250 ~999 250 -999 250 -999 250 Verification Listing :hlumberaer ~!as~a Computing Center 25-JAN-1991. 15:14 PAGe: M~E$,CNb -999,250 MTEM,CNL CG~,~iG7 -999,250 TgOR,NGT W~.N~.Nc~'.. ,,, -999.250. w~.~NG NGT wSNG.NGT -999.250 T NS$NGT CS,NGT -999.250 HTEN,NGT C~.~GT 12,89! TENS, BGT -999.250 HTEN.CNL -999.250 SGR.NGT -999.250 POTA,NGT -999,250 URAN.~GTN -999 250 W]NG,NGT -999.250 W4NG.NGT -999:250 MTEM.NGT -999.250 MRE$.NGT -999' 250 GR.BGT 20.000 C~.BGT 370.000 -999 250 '999i250 -999 250 -999.250 12.984 **** FILg TRAILER **** FILE NA~ : ~DIT .00~ S~RV!C~ : FLIC VFRSIO~i : O01A06 DAT~ : 91/0!/25 ~× REC S~Z~ : !096 F1L? TYPE : I.,~ST FILE **** 'rAPE TRalbER **** [.>aTr : 91/01/25 TA-P~ Nn~E : 74276 CONOCO INC.,SC~4RADEP BI, UFF,MIbME POINT UNIT d-4,50-029-22073-00 .POINT UNIT d-4,50-029-22073-00