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200-016
V OT� • y*0`'\�►: THE STA! Alaska � OilandG4s of e T A CI(A Conservation Commissin 333 West Seventh Avenue "� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OFA S�Q. Main: 907.279.1 X133 Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek SCA( E JUN 0 '12118 Staff Well Integrity Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, Tabasco Oil Pool, KRU 2T-204 Permit to Drill Number: 200-016 Sundry Number: 318-202 Dear Ms. Simek: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this 5 day of June, 2018. DM RBS JUN 0 4,1018 1 0 • RECEIVED STATE OF ALASKA MAY 201 ALASKA OIL AND GAS CONSERVATION COMMISSION 07-S S/s! 1�' APPLICATION FOR SUNDRY APPROVALS AGCY 20 AAC 25.280 1.Type of Request: Abandon Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: Plug and Abandpn El• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development p . 200-016 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. 0. Box 100360,Anchorage, Alaska 99510 50-103-20327-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2T-204 Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569 • Kuparuk River Field/Tabasco Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 3,757' 3,310' 0 0 0 Cemented to surface None Casing Length Size MD TVD Burst Collapse Conductor 85' 16" 120' 120' Surface 3,459' 7 5/8 3,493' 3,089' Liner 291' 4" 3,670' 3,239' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 0 0 3.500" L-80 3,324' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=BAKER SC-1 GRAVEL PACKER 3379-2943 SSSV: NONE 12.Attachments: Proposal Summary LJ Wellbore schematic 121 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑'. 14.Estimated Date for 5/23/2018 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ El WDSPL El Suspended I❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 2 • 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Well Integrity Engineer Contact Email: Jill.Simek@cop.com Contact Phone: (907)263-4131 Authorized Signature: �/I}/j�/ Date: l COMMISSION USE ONLY Conditions of approval: Notify C ild) 6 ssion so that a representative may witness Sundry Number: 313 202 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance [i Other: Phatd 61ae-vvvkt�f a5 t\ rldi �a�' � af' Post Initial Injection MIT Req'd? Yes ❑ No I Spacing Exception Required? Yes ❑ No Li Subsequent Form Required: /b— g/? I. �_ APPROVED BY 6 �jC� Approved by: i COMMISSIONER THE COMMISSION Date: YTL 6%/lce ORIGINAL . 7 \V RBDMS1 JUN o 6 2018 Submit Form and /D Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 17 May 2018 Commissioner,State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon • Kuparuk River Tabasco well 2T-204(PTD#: 200-016). 2T-204 was drilled in 2000 as a single casing producer. In 2008 the well was shut in long term after the failure of the third ESP-PCP in six months. In 2013, it was determined that it was not economic to return the well to production and a cement plug was pumped to isolate the formation and suspend the well. Since then,three additional cement plugs were pumped,and the well remains suspended with cement to surface. Evaluations conducted indicate the wellbore and well location do not have any remaining utility for the Kuparuk River Unit. Per this procedure, a P&A will be performed by performing a cement top-off job, if required, followed by • excavation and removal of the wellhead. If you have any questions or require any further information,please contact me at 263-4131. Sincerely, a aL , Jill Simek WO Integrity Engineer 1'AI Drilling and Wells • • ConocoPhillips 2T-204 P&A Permit to Drill #: 200-016 The objective of the proposed 2T-204 P&A is to excavate 4 feet below original tundra level, remove the wellhead and cellar, and backfill with gravel/fill to ground level. Proposed P&A: Wellhead Excavation / Final P&A: 1. Remove the Well House (if still installed). 2. Bleed off T/I to ensure all pressure is bled off the system. 3. Remove the production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings. AOGCC v witness and photo document required. 7. Send the casing head w/ stub to materials shop. Photo document. 8. Weld %4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2T-204 PTD # 200-016 API # 50-103-20327-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. JS • • Wellbore Schematic: KUP PROD 2T-204 ConocoPhillips Wet Attributes IMaxAngle&MD TD Alaska,Ing. w.ueere 32700 Flea Remo wnmore ua0e J@nei34 MD(MB) Ace Brm 1.13) 501032032700 TABASCO PROD 34.49 3.711.68 3.757.0 "." Comment ern(Ppm) Dan Mnetetlan End Date 0R4N IRl Rg Release Dale 11-x04,3D31301//.3? PM 5550:NONE _ LBSIWO: 662000 5)12'2000 vent.ernemueleawM 'Ann*o, Mpm lhKel Eno One MrntaWn Lat Moe By Eno Date Last Tag. 3.248.0 91412007 Ren Realm:CEMENT TO COMPLETE PEA lepshkt 2.207014 lee E:: eAtIWER-.30.3 13.11 ) Casing Strings -_ - j' Cawing Deserted on 001111 ID nn) Top Ine35 Sn Depth One80Sn Depth 0VD).wvLen.58 Grade Top Thread 1 !i CONDUCTOR 16 15062 35.0 1200 120.0 62.58 H.40 WELDED CaaOd Description 00 On) (0 pre) Tap(COB) 841 Depth(804131 Set Depth(TOO)..MRA410. 'Gine Too Tareaa SURFACE /518 6.151 34.6 3.493.2 3.089.0 29.70 L-80 BTCM casing Description co lin) OW) Top 06*) Set OeptnlhKel Set Depth(TVD)..semen(L..Go. Top Thread LINER 4 3.500 3.378.8 3,670.0 3 238.5 9.50 L80 SLOT Liner Details ...I 10 lapfRKe) lap(TVD)1000) Top met7) hem0a Com (101 3378.8 2.9900 30,45 PACKER BAKER SC I GRAVEL PACK PACKER 4 000 '0Cb.:oi1C06R:3tr-t30b° . 4.38/,6 2,991,5 30.3/SLEEVE BAKER 8040 GRAVEL PACK SLIDING SLEEVE 4./00 3.390.0 2999.7 30.34 SBE BAKER 80-40 SEAL BORE EXTENS 3.980 TRG PURCOEB-DSO 3,407.0 3.014,4 30,17 KON MODEL'C'KON Size 5OEOylm Flapper 3500 3,4641 3,051.1 7992 SCREEN RAKFRWF ID GRAVE I PACK SCREEN 5'4070" ' 3500 GAUGE 3.669.5 3.238.1 30.85 0)11 PLUG BAKER BULL PLUG.SEAL LOCK HT 3.500 CMT RLUG.340 rax, CMT PLUG.34 a ORB s Tubing Strings tuning Dose rtpuon Siring Mo..10(in) Top(0K0) Set Depth 0I 3M Depth(TV01) VP 11801 Grade Top Connecn0n TUBING 312 2992 30,3 3.320.8 2.9659 9.30 L 80 EUE BN f Completion Details S � Ramiro/10 Top(itKB) Top((VD)I1MB1 Top lop Pl Item Dee tem (re) 303 303 000 HANGER 'VEICO GRAY t0IBING HANGER 3509 CMT PLUG,1114.011101 3,324.0 2.9.12.8 30.85 NIPPLE CENTHILIE I SLOTTED NIPPLE 2.8(3 3.327.0 2,945.4 30.64 INTAKE CENTRILIIT 1-TC CROSSOVER INTAKE TBG PUNCIIE8VMS 0 3,3284 7.940 3063 SEAT. CENTER'!ET TANDEM SEAT.SECTION 3.342.2 2.9555 :1(1.58 Of 41000 CCNTRAI If•GEAR RE DUCTION UNIT CMT PLUG:21090110 3.343.5 2.9596 3058 MOTOR CENTERL)FTMCD ORS'HP 1315.26 CMT PLU070005)0 3.3503 7.9654 3055 Cderahre+ CENTRAL 8T 130000 CENTRALIZER 1995 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TOD) Top Me, Top 111108) (1118) (") Des Com Run Dale 10(tn) OAS un,i,xxe4 145.0 145.0 2.14 008 TUBING PUNCHES.19115',O DEGREE PHASE,4 10/24/2013 2792 PUNCHES 0PP•40 SHOTS TOTAL 2,915.0 2,597.0 30.83 T00 TUBING PUNCHES 19116'SCALLOPED HSC,0 8123/2013 7997 PUNCHES DEGREE.4 SPE 3.257.0 2.885.2 30.84'CUT CEMENT RETAINER 7)312013 RETAINER CMT PLUG.SOW Drag CM,PLU9'261a0 Rn8. � � 3..3190 7936.5 30.57 TRO CUT TUBING CIUTw1JPT CUTTER 13.3 19',ABOVE ESP '7:157013 2047 IN GMT RETAER.3,2310 FGIIIPMFNr Stimulations S Treatments Proypam Designee Po/ IPmpPa^I In F000011On pa) (Dan 034.719X1 Stimulations&Treatments vol clean pump stga Top lone) 810Inn8) Dan 311mfrreal Fl 519 fain) 1 I Val Shin Mae T80 CUT.3,3180 I 3379.0 36700 01742(X113 1oppant Designed(Ia) Pmppat In Fanner/ion(ib) I Dane 4: 7.70'2(101 NIPPLE,0ue0 Stimulations S Treatments -- v..Clean Pump WARE 3.317.0 511(,1) Sega toplml8) Mon(110411) Dan stlevleal Field Sus) vat Slurry(0130 $ 1 3.379.0 3.670.0 71222001 BM:3338.4 Cement Squeezes Topatm 1,15 cal GEARBOX.3]433 ele Tap 81081 BotkE0 (one)ke) (6K8) pre Mal Dna Com 29(0.0 3.2570 2.6392 2.885.2 CMT PLUG 7+3112013 Pumped 59 DUI.Class G cement Lwow femme MOTOR 3.343.3 Pumped 11 bets tel class G cements up the IA, DemlaMw 33Bp 3 • 3.259.0 3.483.0 2.886.9 3.080.2 CMT PLUG 77302013 Pumped 59 bola C0Iwm oatmeal. O0 G nlobelow oatmal. Pumped 11 bels of clasp G cements up the IA, 3.094.0 3.2520 2.745.5 2,8852 CMT PLUG 7131/2013 Pumped 3 blies ol Class G 00 top at retblwt • 1061 2.198.0 2.970.9 1.9/8.8 2,6392 CM!PLUG 8126'2013 Full bete cement pub,25 D010 ASI cement 700.0 3,0940 678.7 2.746.5 CMT PLUG 97212013 PUMPED AS I CEMENT 1.945* eIIIN 168.0 2.1480 108.0 1.9788 0141 PLUG 9)2712013 PUMPED ASI CEMENT 34.6 679.0 33.6 659 6 CMT PLUG 18/2014 PUMPED ASI CEMENT 34,6 6799 33.6 659.6 CMT PLUG 153E20(4 PUMPED AS I CEMENT en Mandrel Inserts 4a Top(TVD) CMve Lakep0ll Sae TRO Run R Top.11K8) (2 8) MS. 310411 0011n) 8010 lnetatiel nM (In) (psi) 1000.11 Com I 9,2284 2,,860 7 CAMEO KRMM t E51+ UMY -OK (000 00/182013 Notes:General&Safety and Dan A lr 12/102010 NOTE.VIEW SCHE MAT IC wi Alaska Schem'atic-0.0 SOT PLUG 32190,0B she S...Rr000018.34g30 `YSS 3.37001 SY sou,3VD 0 taER.2 328 8-1870 0 Is KUP ROD 2T-204 COt10Ct�Ptllllp5 Well AttreAPI/U Max An D TD Wellbore API/U Field Name Wellbore Status 'ncl F) ) Act Btm(ftKB) Al=ISKA.1't' 501032032700 TABASCO PROD 34.49 3,713.68 3,757.0 c noon al�ris Comment H2S(ppm) Date Annotation End DateKB-Grd(ft) .Rig Release Date ••• SSSV.NONE Last WO. 6/6/2000 I 5/12/2000 2T-204,5/16/20183:0521 PM Last Tag Vencml schematic(actual) Annotation Depth(ftKB) End Date Last Mod By Last Tag: 3,248.0 9/4/2007 osborl Last Rev Reason HANGER;30.3 ^�i rla� Annotation End Date Last Mod By Rev Reason CEMENT TO COMPLETE P8A 2/20/2014 hipshkf 1� � 1f- Casing Strings ,....:';e:,,..." Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread '".""" CONDUCTOR 16 15.062 35.0 120.0 120.0 62.58 H-40 WELDED �4, � Description (in) ID(in) Top(ftKB Set Depth ftKB Set Depth(TVD)... Wt/Len(I...Grade Top Thread `4'"'4..,`�� Casing OD ) p (ftKB) p :XS' SURFACE 7 5/8 6.151 34.6 3,493.2 3,089.0 29.70 L-80 BTCM i :.' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ,, ..; LINER 4 3.500 3,378.8 3,670.0 3,238.5 9.50 L-80 SLHT ;ilk% Liner Details '~A.CONDUCTOR;35.0-120.0 ' Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl Cl Item Des Com (in) 3,378.8 2,990.0 30.45 PACKER BAKER SC-1 GRAVEL PACK PACKER ' 4.000 TBG PUNCHES;145.0 3,387.5 2,997.5 30.37 SLEEVE BAKER 80-40 GRAVEL PACK SLIDING SLEEVE 4.700 3,390.0 2,999.7 30.34 SBE BAKER 80-40 SEAL BORE EXTENS 3.980 3,407.0 3,014.4 30.17 KOIV MODEL'C'KOIV Size 5 w/Ryton Flapper 3.500 CMT PLUG;34.6ftKB.• 3,484.1 3,081.1 29.92 SCREEN BAKERWELD GRAVEL PACK SCREEN 5"x.020" 3.500 CMT PLUG;34.6 ftKB GAUGE II 3,669.5 3,238.1 33.85 BULL PLUG BAKER BULL PLUG,SEAL LOCK HT 3.500 Tubing Strings ITubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..,Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 3 1/2 2.992 30.3 3,350.8 2,965.9 9.30 L-80 EUE-8rd Completion Details CMT PLUG;168.0 ftKB Top(ND) Top Incl Nominal Top(ftKB) (ftKB) (°) Item Des Com ID(in) TBG PUNCHES;2,915.0 30.3 30.3 0.00 HANGER VETCO GRAY TUBING HANGER 3.500 3,324.0 2,942.8 30.65 NIPPLE CENTRILIFT SLOTTED NIPPLE 2.875 3,327.0 2,945.4 30.64 INTAKE CENTRILIFT TTC CROSSOVER INTAKE CMT PLUG;2,198.0 ftKB 3,328.4 2,946.6 30.63 SEAL CENTRILIFT TANDEM SEAL SECTION CMT PLUG;700.0 ftKB 3,342.2 2,958.5 30.58 GEARBOX CENTRALIFT GEAR REDUCTION UNIT 3,343.5 2,959.6 30.58 MOTOR CENTERLIFT MOTOR 5/HP 1315/26 3,350.3 2,965.4 30.55 Centralizer CENTRALIFT MOTOR CENTRALIZER 1.995 GAS LIFT;3,228.4 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) CI Des Com Run Date ID(in) 145.0 145.0 2.14 TBG PUNCHES TUBING PUNCHES-1 9/15",0 DEGREE PHASE,4 10/24/201 2.992 SPF-40 SHOTS TOTAL 3 2,915.0 2,592.0 30.83 TBG PUNCHES TUBING PUNCHES-1 9/16"SCALLOPED HSC,0 8/23/2013 2.992 CMT PLUG;3,094.0 ftKB, DEGREE,4 SPF CMT PLUG;2,970.0 ftKB CMT RETAINER;3,257.0 1!i 3,257.0 2,885.2 30.84 CMT CEMENT RETAINER 7/31/2013 RETAINER 3,319.0 2,938.5 30.67 TBG CUT TUBING CUT w/JET CUTTER @3319',ABOVE ESP 7/16/2013 2.992 I,. EQUIPMENT I Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(lb) Date TBG CUT;3,319.0 i 9/24/2000 s Stimulations&Treatments Vol Clean Pump Stg# Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid NIPPLE;3,324.0 - , 1 3,379.0 3,670.0 9/24/2000tif (bbl) Vol Slurry(bbl) Proppant Designed(Ib) Proppant In Formation(Ib) Date INTAKE;3,327.0 111111 7/22/2001 ,7or SEAL;3,328.4 t Stimulations&Treatments Vol Clean Pump GEARBOX;3,342.2 ' Stg# Top(ftKB) Btm(MB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) 1 3,379.0 3,670.0 7/22/2001 MOTOR;3,343.5 a - Cement Squeezes Centralizer;3,350.3 Top(TVD) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 2,970.0 3,257.0 2,639.2 2,885.2 CMT PLUG 7/31/2013 Pumped 59 bbls Class G cement below retainer. Pumped 11 bbls of class G cements up the IA, �E- - 3,259.0 3,483.0 2,886.9 3,080.2 CMT PLUG -7/31/2013 Pumped 59 bbls Class G cement below retainer. Pumped 11 bbls of class G cements up the IA, Ill 3,094.0 3,257.0 2,745.5 2,885.2 CMT PLUG 7/31/2013 Pumped 3 bbls of Class G on top of retainer 2,198.0 2,970.0 1,978.8 2,639.2 CMT PLUG 8/26/2013 Full bore cement job,25 bbls AS1 cement 700.0 3,094.0 678.7 2,745.5 CMT PLUG 9/21/2013 PUMPED AS1 CEMENT s 168.0 2,198.0 168.0 1,978.8 CMT PLUG 9/21/2013 PUMPED ASR CEMENT a 34.6 679.0 34.6 659.6 CMT PLUG 1/8/2014 PUMPED AS1 CEMENT 34.6 679.0 34.6 659.6 CMT PLUG 1/8/2014 PUMPED AS1 CEMENT I Mandrel Inserts MIil Z.' at �t' N Top(ND) Valve Latch Port Size TRO Run i Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,228.4 2,860.7 CAMCO KBMM 1 ESP DMY BK 1.000 0.0 7/18/2013 Notes:General&Safety End Date Annotation 12/10/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 CMT PLUG;3,259.0 ftKB SURFACE;34.6-3,493.2 10s f STIM;3,379.0 '0 STIM;3,379.0 Ms MI LINER,3,378.8-3,670.0 .1..." • • x co Barrels of Oil per Month or Barrels of Water per Month (xi NI 00 L , 0 ,-i o 0 0 O O O N O O 0 0 O v eel O .-I 0 .Oi .1 rl 0 I— le) — °eve Di III 1111111ln 1111111111111 oillb 0 I O III N N j I 0I Cr =I N ; 11111111 1111 ......_. VY zu I€ CO a II c � "'�N, , s ° as . � _ X� 1 0. m w ° ;{moLU ce ° o0 ° oIIIII o ° 11 o w 411 ns _ a — ..., — . ! : .. - .1 „ _ , , „L. . .., .. c,.. -0, „:„.. i ..... ,.. ,_ s 9.0 .00 3 ° ■► LL �nAO • 7 (J .5...., og , . ,.. ate Y I °%° ® Ii : °:;°��� � 111 11111J N •• •y • • a M . m f 000 4P/' CL J 3 J CI. OE. I 0 Z O - s V o 0 0 0 ~ se 0.. et 0 0 0 .1 0 0 .-i o .1 mi OEEea I!0-Seg JO q uoW Jad („dmi„) seg}o laa j 3Ign3 puesnoyl VOF77,, • IP gwp�\1 yy,, THE STATE � do, % Alaska Oil and Gas OfAT Q c1 k Conservation Commission -, Ll 1 V JL�l 1 lt � 1F}F2 *' ' r 333 West Seventh Avenue w GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek sCONED iyl 2 b' 2,r-iI: Staff Well Integrity Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-204 Permit to Drill Number: 200-016 Sundry Number: 317-181 Dear Ms. Simek: 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, -/-64 Cathy P. Foerster Chair DATED this it day of May, 2017. RBDMS t ,- Mkt 1 6 2017 , • RECEIVED STATE OF ALASKA MAY 0 4 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AGC C 20 AAC 25.280 1.Type of Request: Abandon dPlug Perforations El Fracture Stimulate ❑ Repair Well El Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Plug and Abandon 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development p• 200-016 ' 3.Address: 0 6.API Number: Stratigraphic El Service P. O. Box 100360,Anchorage,Alaska 99510 50-103-20327-00 • 7.If perforating: _ 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes 1:1No El J KRU 21-204 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569 Kuparuk River Field/Tabasco Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 3,757' 3,310' 0 0 0 Cemented to surface None Casing Length Size MD TVD Burst Collapse Conductor 85' 16" 120' 120' Surface 3,459' 7 5/8 3,493' 3,089' Liner 291' 4" 3,670' 3,239' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 0 0 3.500" L-80 3,324' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=BAKER SC-1 GRAVEL PACKER ` 3379-2943 SSSV- NONE 12.Attachments: Proposal Summary LI Wellbore schematic LI 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic El Development 0 • Service ❑ 14.Estimated Date for 5/21/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG El GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 - 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Well Integrity Engineer Contact Email: Jill.Simek@cop.com % Contact Phone: (907)263-4131 Authorized Signature: Date: j/ 1 1--- COMMISSION 'COMMISSION USE ONLY Conditions of approval: Noti ommission so that a representative may witness Sundry Number: 1 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance le- N`a F {(D i►- Other: P,�o �"a cl w. r✓ti f fj O Lz C r✓ w r f rI t S S co l t� e/t C 4..."--r , Post Initial Injection MIT Req'd? Yes ❑ No lE Spacing Exception Required? Yes ❑ No vc Subsequent Form Required: /d — L{- 6RBDIVIS LI- 11,-0 6017 / ' / APPROVED BY Approved by: ,, -26.2.44.4...__ COMMISSIONER THE COMMISSION Date: S_ /!--/7 AA 4/5 ?- v'T[. 5/i'/r//7 ! /gh, O R I 18 ' AL application is validSubmit Form and Form 10-403 Re ised 4/2017 pp pp for 12 months from the date of approval. Attachments in Duplicate • • Nov ConocoPhillips RECEIVED Alaska MAY 0 4 2017 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC 24 April 2017 Commissioner,State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7`''Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon Kuparuk River Tabasco well 2T-204(PTD#: 200-016). 2T-204 was drilled in 2000 as a single casing producer. In 2008 the well was shut in long term after the failure of the third ESP-PCP in six months. In 2013, it was determined that it was not economic to return the well to production and a cement plug was pumped to isolate the formation and suspend the well. Since then,three additional cement plugs were pumped,and the well remains suspended with cement to surface. Evaluations conducted indicate the wellbore and well location do not have any remaining utility for the Kuparuk River Unit. Per this procedure, a P&A will be performed by performing a cement top-off job, if required, followed by excavation and removal of the wellhead. / If you have any questions or require any further information,please contact me at 263-4131. Sincerely, Jill Simek Well Integrity Engineer CPAI Drilling and Wells e • )110 ConocoPhillips 2T-204 P&A Permit to Drill #: 200-016 The objective of the proposed 2T-204 P&A is to excavate 4 feet below original tundra level, remove the wellhead and cellar, and backfill with gravel/fill to ground level. Proposed P&A: Wellhead Excavation / Final P&A: 1. Remove the Well House (if still installed). 2. Bleed off T/I to ensure all pressure is bled off the system. 3. Remove the production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document required. 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld '/4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness ConocoPhillips 2T-204 PTD # 200-016 API # 50-103-20327-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. Js • • Wellbore Schematic: `..``,, KUP PROD 21-204 ConocoPhil lips 12 1 weft cru Max Angle&MD TD -, ,.,,L,,,,,1(hr_1,, ,:-,ii50103[1 AMAMI Field Nome 11600 Eland nal.14 MD 39914 Act@1m 114106) CmpKti,,,, 5 0 10320 32 700 TABASCO PROD .334.49 3713.68 3,757,0 ... ~•.. Comment NES(ppm) Dale Annotation End pan 06X004(K) 133 Release pan _11.180.9n3.112.2464. 80 0809:NONE Last 0*0. 06,8700 5/1211000 669641.a.14 ianNah , Annotation Dopt9(11KS) EtMOMM Anno.on IL.Moa By End OS. Loot Tag; 3,248.0 914!2007 Rev Season.CEMENT'FR COMPLETE P634 11436441 2±2032914 4664603x3 ' '41. 5 4 Casing DMM4I0100 00(In) 10(ml Top OMEN 6m DOOM(000) ISM ExmO(000).MM.Il...Ot. Tap Tnna4 j CONDUCTOR 16 15.062 350 129-0 120,6 62.68 6440 WELDER .ii i Caal0ACP0*0E 0*364 410 60) 10 611) Top(1108) '6411608011tl061 NM Dept0(TVO)_46.6.Imo-66.0. Top rnd00 II 6URF75'8 6.151 346 34932 313696 2076580 BTCM 0101,04 944639644 0041,/ I3661 Top(0318) Me 00340(40(0) 00 De.(160)...M14.00(3 dont Tog Thread LINER 4 3:500 3,378.83 :3.670.0 3.238.5 9.501.80 3516T Liner Details Nominal aD Top 11148) TOP tro8)15K8/ Top 1441(1 lam Oh: Com 616 3.378.8 2990,0 3046 PACKER 66605300 1 GRAVEL PACK PACKER 4,000 4h3`,6B4044191.84.36.4:,363 e. 4 3,387.5 29167.5 30.37 540306E OAKEN 80-10 GRAVEL PACK 6130)NG SLEEVE 4200 TMS:3 419.2 30.94"SBE �-BAKER 8040 SEAL ORE EXTEna .,.�.�..�3980 TBG R 503000 409 3.407.0 3,014,4 30.17 K0(9 MODEL'C'K01V Size 5 w12y4anFIoppoo 3,639 3,484.I 3,081.I 2992 0060)0 BAKENYM'E10GRAV1T.PACK SCREEN S"N.<(VIP :i-6;0X0 (;41&13;[ 3,66$.0 3.238.1 33.85 BELL PLUG BAKER BULL PLUG.SEAL LOCM HI 3.500 DMT 01,10.44 arca LMT PUN:4.610561 Tubing Strings gs Tirninp Dmannpeion Sarinp Ma...101:01 Top 3058) pat Dap10(0.Sat Depth ST00)(,.041 Mutt; 0090 Top Connection TUBING 312 2992 393 3,350.8 2.965.9 9.30100 E1)E640 Completion Details .. . f Nomly.I0 Top(arca) Top(119)141611T Top Inc.(1) nem Dna COM (M) :3413 303 0.00 HANGER VE1CO GRAY TUBING RANGER 3,000 CMT p1U.160X004 3324.0 2.9428" :517.65 NIPPLE GENTRII.IFT 6LOTTE04 NIPPLE 2.875" 3.3270 29454 30.64 INTAKE -CENTRILIFT'TC CROSSOVER INTAKE r65P66011e6 18115 3328;1 2.9486 30.63 SEAL C69108IFT TANDEM SEAL.SECTION 3,3422 29583 50 58 GEARBOX CE5)0111FT 0EAR REDUCTION UNIT CMT 01130)27486965 3343.5 2.609.6 30.58MOTOR CCNIERLEF`s MOTOR 30111P 131526 ' OMTF9,A4.71046K8 3,330,3' 2,9654 30.55 Cr01ra3xar CENTRAL303 F40106 CENTRALIZER 1095 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,ate.) Top 10061 Top Inc; Tod MINN) 31051 i'5 011 Com Ran Dad 30(;01 e✓. ITT 11:ae 140.0 445.0 2.14 TBG "TUBLNG PUNCHES 13915",O DEGREE PHASE.4 11082412013 2.592 1:9150803 817t.49 SHOTS TOTAL 2,9E5.0 2,5920 30.83100 TUBING.PUNCHES.E 9/16-SCALLOPED HSC,O 0.202013 2.992 PUNCHES DEGREE.4000 3,257.9 2,885.2 30.84 CMT CEMENT RETAINER 7/31/2013 60)4) ,0 CMT p.JG S,94.14 NM t6.20 3.314.0 2,FX305 3007'"RAC CUT TIMING 991 w.`,IET CUTTER 0331TY ARRVF`,ESP To61`261.3 2-992 JOT AMMER 3NT0 S # M 60131PFNT 11 Stimulations&Treatments I prepat 35.69/41 367. 11308849In F030011on dint Dan *y24r201Xt Stimulations&Treatments '_ ‘101Cha 519, P{aK9y 136,60501 36 ;r 001100tF N (14:11'''P(801 Marry 30611 108041 03100 - 1 I E 33796 3.070.1)9/7420(X) proPpantpealproed 307 P.p..In denranatiii68 DMe 7123,2001 .656 3X11,0 • Stimulations 8 Treatments tMi Em. ump *TAKE 3,630 1, 9190 Top(01(87 Nm;RIME) Dale S1tINTmat Rnld ga11p Vol Sin,(Mon a 0 3379.0 3.670970:1.'2(101 541,:.3334.) Squeezes Squeezes GEARBOX:8E411 To9)100) Btm(18 9 AE Top 16581 Eta O*K6) (6095 (0081 Cos SStat 0. Corn / 2.670.0 3,2570 2,639.2 2885-2 CM')PLUG 7/31/2013 Porlgw0 59 bias Class 0 cement bu loo le[aiopl_ MOs'3306* :T.:Z. Po0yn1G91 blas 0(33)30.00 CO cnmpnM up rile IA, Cae4a'raer:a3a93. 3259.0 3.483,0 2 886.9" 3.089.2 CMT PLUG 703132013`Pumped 39 bh0s Class G cementbe30w r0t0i0ar. 1. Ponyo d 11 b460663ass G 4991991 up 1901A, 3994.0 3.357.0 2.7459 2,885.2 CMT PLUG 7/31/7013 Poopxni 3 blas 91 Class 0 on541103et0)30, 21980 2.9700 1.9760 2.639.2 C343 PLUG 0/2612013 PullbonacamangEAT 25099 AS1 uemeM 7000 30949 678.7 2.7455 CMI PLUG 9121:2013 PUMPEGA.S7 CEMENT 1680 2198,0 166.0 19788 CMT PLUG 321(20)3 PUMPED ASI CEMENT 34.6 679.0 34.6 659.6 GMT PLUG 1/812014 PUMPED 4101 CEMENT 346 6790 34:6 659.6 CMT PLUG (/802014 PUMPED 41S1 CEtEN7 Mandrel Inserts 0' Tap 31 0) Valve Lsan PortSno TRO Eon N 704 MKS) 61101 Maao No411 00(10) Sent Type TUpe (10) I Eon WO Com 1 ?,2284 2.81X7.7 CAMEO K MM 1 ESP GMY BE 1.000 0.0'/1832015 Notes:General&Safety End Wen Annolot4n 121102010 NOTE:VIEW SCHEMATIC 6491 a6'13a SC5em61199-9 GMT 0L903246 9 NN8 Fri 41 15 8414:3 786 9119 5.244.0 *0160:3 3]166,31)06 Js • ✓ ConocoPhillips 2T-204 P&A Permit to Drill #: 200-016 The objective of the proposed 2T-204 P&A is to excavate 4 feet below original tundra level, remove the wellhead and cellar, and backfill with gravel/fill to ground level. Proposed P&A: Wellhead Excavation / Final P&A: 1. Remove the Well House (if still installed). 2. Bleed off T/I to ensure all pressure is bled off the system. 3. Remove the production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document rewired. 7. Send the casing head w/ stub to materials shop. Photo document. 8. Weld %4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo aocument. AOGCC Witness Required. ConocoPhillips 2T-204 PTD # 200-016 API # 50-103-20327-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo aocument final location condition after all work is completed. Js 0 0 Wellbore Schematic: t �,,1 KUP PROD 21-204 ConocoPhilllps i 1 VGeil Attributes Max Angle&MD �r ,in... WeElbore32700 Fie.. a I<Vt•0D btnos .('( MOM/MI AaI BMn(03,7 4tesxo2tM&re {01032032700 !TABASCO PROD 34,43 3,713.68 3,7570 ... Comment 425(ppenj Date Annot&ion Cola f3 8&631161 1RIg Rweaae Dee 31-304.,V1300/121.1. 5581/x'NONE La30040' bF✓7000 5;12[000 Y 9p4echar.,woel. s Annotation /Depth MAID End Date Annotation Let Mod eY End D. Last Tag; 3248.0 91413607 Rev Fl eared:CEMENT'TO COMPLETE 0501 Pipet* 2126120/4 04306.8 an 4 !, Casing Strings 777 7 777 7 ,,,,,,,z.-:.,7.,7,,..n Ing Only spt on nD fI 1 ID lin) top{0601 trot Deem 0IKR) S0I 0*Ri81TL0) W"...01'..4.CrhM lap 1nra%d i 4 016311/200 t6 15062 35.0 (29Q 1,230 H.4p WELDED E C 3no 0000 ptitln - DO(In) .IO fin) Top MKS) 80 DOM"MA) 800 Pepe.IVO)..WN.m1 I..GA. T 40 SLRFAC1 75,8 6151 34.6 3,41732 30890 2975 L- PTnm V 80 BTCM I Caning Msc6Mlon CD ON 0(n) 1,MAP) 111.1 Depth((0651 80 00180(0(10) WVL.n( .Gran Top Timed 1 LINER 4 3560 3,37081 36700 3 236 5 9,50 L.80 SLUT Liner Details on Top(11681 Top(796)10471) Top l03 fl Ivo pee Com No.tine!Ep 3.318,8 2,690,0 36,46 FACKEN BAKER SC'1 GRAVEL PACK,PACKER 0.000 fiMCCN1406 it.55d13R3 a'• 3.387.5 3.007.5 30.37 SLEEVE BAK660040 GRAVEL PACK SLIDING UMW 4.700 ._.� .................._ .....,,,._,._ ___...... ... 3,3908. 2,9099.74 30.89 'tf BAKERS-I0SE0.L 6012E EX'I`[1i5 "31$0 704 PlAC006 50.6 7777... 14070.............3,014. 30.)7 KON MODEL'/KOPP See 5W41ytenl')opp.. 3.500 3,464.1 3,081.1 2992 9CRFEN 6AKERWt;L I)r(380006 PACO SCREEN 1101329' 3.50X1 04!/4,0 3,669.5 1238.1 3385 BULL PLUG BAKER BULL PLUG,SEALLOCK.HT 3,508. CMTPLUG 14a8KF Dr4TpwG 14411611 Tubing Strings Timing Dawe minion Seng 4a...IDtint Top 3000 set Depth(8.. Wt OI SDepth ITVD11.. 184%1{) Grads Top Connec^1on TUBING 3173 2.992 3X).3 3.3'60.81 2.ORSR1 5301.60 160E-8,d C° Completion Details Nominal ID Top MKS) Top{ND1{1160) Tap 1n£("1 lam On dem Pd) � ,: 3073 3073 0,6X3 HANGER. VE TCCORA y)IEBINGHANCEN :3,500 007 PL LIG;'S4.)068 13240 29428' 30.65 NIPPLE CENTR11.PT 56.01101 NIPPLE 2875 3.327.0 23454 30.64 INTAKE CENTRILIFT TIC 4KR0SSOVER INTAKE reG?W£CREY,29+a4----.-.-t 3.316.4 2,446$ :30-69 SEAL CENT'RII,IF"I"TANDEM SEAL SECTION 3,342,2 2951) 30.58 GEARBOK CENTRALIPT(.0.0 REDUGr1ON UNIT 0MT 010602,186.1000 3.313.5 2.953.6 36.58 140706 CE31E61107 MOTOR 0,11101315126 097 PWG:70011Ke- 3,350,3 2965..% 30.55 Cent-Mum CENT RA[IFT'MUT OR CENTRALIZER 1.695 Other In Hole(Wireline retrievable plugs,vahros,pumps,fish,etc.) 108(0401 1op1101 48111601 (1108) ('1 Dee Cam Run Date 10(6/( GLL8P 1:101 1450 145.0 2.14 1910 1061NG PUNCHES-19116,O DEGREE PHASE_4 (0424,3013 2.902 PUNCHES SPF 40 slots T0TA1. 2,925.9 2,592.0 30.83 105 TUBING PUNCHES.19110"SCALLOPED MSC.O 8.132013 2,962 PUNCHES DEGREE,4 DPI 3.257.8' 2.8652 38&1 CMT CEMENT RETAINER 7/3112013 RETAINER OMT 4070.4,064311149 GMT PLOD;787146KIT 3,300 2.9(185' 9062 TSG CUT 7641113{GUT wldBT'CUTTER 03119`.441090 640 7116,12013 2709',{ GMT RBTA008.1.20T0 4.=' i J ACAOPMENT Stimulations&Treatments Propp110 Dex1Onoe(16) 'Propp.m In Fnmetnon p.) 162. 9124+24.38/ Stimulations&Treatments Vel Chan Gump Dag8 Top 11.00 I Aim(IOW) W) Rperldte 61814 0.861 Vat 84.09111) 704 CUT.11.3130 - 1 ',979.41 8670.0.5124'2000 Plopppn)DeOlgneo 101) a Proppwd In Korsrtafide(6o,) D. m®® mm� 7+22'2901 10(PLE,34.548 Stlmulattons&Treatments VM Chun pump iRTAIM1,32T03 .3A Top DIAS1 Rim inK81 Dae. _ StlmtTret fluid 18811 Vol 8111,03811,1 t 33700 3.(70.0 7;22.'2001 lir 3843.3324.4 '-•" Cement Squeezes Top)111)) Bon 1TV01 DEARBOX 1.1422 Top lftn8) Eno(101011 R1R.9)Si I )MK8) Don Sun Data 1 Coen 2.4700 3,257.0 2,639.2 28652 CAN PLUG 7/31/20 m 13 Pumped 59 beid Class G demomt eff ew Idteinco 40709,1.143.8 '707 Pumped I1 bM 0)04.d C cements 1p De IA, CwY44M:1.%03 32540 3,483.0 2.826.9 3.080.2 ONI PLUG 7)312012 Pumped 69 beef Class G,earned beide retuino£. Pumped H i beldOl0)41 b G c1anc 113 up(11e IA, 3,094.0 3.257,0 27455 2,885.2 CMT PLUG 7131/2013 Poo400O 301(03Dt Clads G 3)i tap lR etelde1 e 2.196.0 2370.0 1,0754 2.01902 CMTPLUG 8126/2443 51810013 deeded MIT t4 25b&)s AST 7600 3,094,0 678.7 2.7469 CMS PLUG 0121.'2013 PU*PED 4131 CEMENT a 1660 2198.0 158.0 1,976,8 CMI PLUG 9'21/2013 PUMPED AS1 CEMENT 34.6 674,0 34.6 659.6 CMT PLUG 11812014 PUMPED AS1 CEMENT 11 34.6 8790 31.5 68..6 CMI PLUG U8"2014 PUMPED AST(SEMEN)" i ME Mandrel Inserts stiM Vow w Lath P.8 Sere TKO 0en Tap 01181 48081 mate 41a4e1 00(1111 Sere 13f9* Typo, 4n1 (301 Ron Dte Com 3,228.4 7,860.7('.MCR KDT M ' 1 CSP DMV BK 10001 0.0 7113/3013 jilt i Notes:General&Safety 6Ina dale 040014164 V.. 1410/2010 NOTE:VIEW SCHEMATIC 0,01(4064 DCRe11a1109.0 IP 8110 FA:;E.3D.4fg7 Si4F013TB.0�_ 67.4.8370.0 a LBAi0,5D10A.34T00 Js Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~ ' 0//~-- Well History File Identifier RESCAN DIGITAL DATA GrOlOr items: E] Diskettes, No ayscale items: D Other, No/Type Poor Quality Originals: OVERSIZED (Scannable) D Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) B Logs of various kinds TOTAL PAGES: ~ NOTES: ORGANIZED BY; BEVERLY BREN ~SHERYL MARIA LOWELL Other Project Proofing PROOFED BY: BEVERLY BREN ~ SHERYL MARIA LOWELL DATE:/i~-~.. E3 Staff Proof By: Date: IsI ~ PAGES: 75'"'- (at the time of scanning) SCANNED BY: BEVERLY ,J~INCENT SHERYL MARIA LOWELL RESCANNED BY: BEVERLY~ VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: PAGES: Quality Checked Rev1 NOTScanned.wlxl ZOO-Okc, • , 23G OCe WELL LOG TRANSMITTAL DATA LOGGED 2212013 M K BENDER To: Alaska Oil and Gas Conservation Comm. October 25, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED NOV 19201,3 RE: Tubing Punch Record: 2T-204 Run Date: 10/24/2013 AOGGC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline&Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 matthew.cook@halliburton.com 2T-204 Digital Data in LAS format, Digital Log Image StANNED 1 CD Rom 50-103-20327-00 PLEASE S ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: k 124,3 Signed: PTO aoc - oI (- Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Tuesday,October 01, 2013 2:00 PM To: 'Wiese,Tyson M' Cc: Schwartz,Guy L(DOA) Subject: RE:Suspension 2T-204(PTD 200-016, Sundry 312-388) Tyson, III Approval is granted to proceed as outlined in your proposal. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil &Gas Conservation Commission 333 W.7th Anchorage,AK ,9950100 �� FEB 2 5 '614 Work: (907)793-1247 victoria.ferguson @alaska.gov -----Original -- -Original Message-- From:Wiese,Tyson M Imailto:Tyson.M.Wiese @conocophillips.com] Sent:Tuesday,October 01, 2013 10:28 AM To: Ferguson,Victoria L(DOA) Cc:Schwartz,Guy L(DOA) Subject: RE:Suspension 21-204(PTD 200-016,Sundry 312-388) Victoria, Attached is the updated 2T-204 Suspend proposal to bring TOC to surface in both the Tubing and the IA. Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1-907-263-4250 Cell:1-907-230-5388 Original Message From: Ferguson,Victoria L(DOA) Imailto:victoria.ferguson @alaska.govj Sent:Tuesday,October 01,2013 9:53 AM To:Wiese,Tyson M Cc:Schwartz,Guy L(DOA) 1 Subject: [EXTERNAL]Suspension 2T-204(PTD 200-016,Sundry 312-388) Tyson, Please submit a proposal to bring cement to surface in the IA and tubing and we will review this with the Commissioners. Thanx, Victoria Original Message From:Wiese,Tyson M Finailto:Tyson.M.Wiese @conocophillips.com] Sent:Tuesday,October 01,2013 8:53 AM To: Ferguson,Victoria L(DOA);Schwartz,Guy L(DOA) Subject: Emailing:Visio-2T-204 Updated Schematic for Well Suspend to Surface 10-1-13 tw.pdf Victoria,Guy, If you are available I would like to give you a call and discuss the 2T-204 P&A. After our last email, I indicated that we had found a casing leak above TOC which was causing the failing MIT-IA. Since then,we have performed a 3rd cement job(TOC now @ approx.700')to cover the casing leak,as well as a possible leak at the TAM Port Collar. We had a state witnessed tag/test and the MIT-IA failed again at approx.0.22 GPM LLR. I have attached a schematic to show where we are at now,and I wanted to get your opinion on our plan forward. Currently we do not have a fully tested cement plug,although we do have approx. 2,800'of AS1 cement in Tubing and IA,as well as a CBL that confirms TOC after the 1st cement plug @ 2,970',and LDL confirming the casing leak @ 1,925', that we covered with cement. Your thoughts/comments are appreciated! This one has been a bear. Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1-907-263-4250 CeIl:1-907-230-5388 2 2T-204 Well Suspend Permit to Drill #: 200-016 �w h-tsc 6 Proposed Well Suspend Procedure: (Non-Rig Option) E-line/ Little Red: 1. RIH w/CBL to find TOC in the IA prior to the tubing punch. 2. RIH and punch holes in tubing above TOC, as close to mid joint as possible. 3. Circulate diesel from Tubing to IA to ensure adequate rates for cementing. RDMO Schlumberger Fullbore Pumping: (cement to surface) 1. Pump 41 bbls of AS1 cement down tubing, through the tubing holes, and up the IA. 2. Monitor IA for cement returns. Take a sample of cement returns and check weight, to ensure good quality 15.7#AS1 cement to surface. 3. With good cement at surface in the IA, shut down pumps, shut in the tubing, and swap over to pump down the IA. 4. Squeeze 1-2 bbls of AS1 cement down the IA, pushing cement through the shallow casing leaks below, in an attempt to isolate these leaks and allow for a passing assin MIT-IA. 5. Clear the tree and the surface lines of cement. Wash up cementing unit. RDMO Little Red: 1. WOC for at least 24 hours prior to performing any MIT testing. 2. Notify the AOGCC Inspector 24 hours in advance to allow for witnessing of the pressure tests with cement at surface. 3. Perform MIT-T and MIT-IA to 1,500 psi. Perform T and IA DDT's. RDMO. TW TW 10-1-2013 2T-204A PTD #: 200-016 Updated Well Suspend Schematic Current Well Status 4th cement plug=800'AS1 Cement plug w/TOC @ surface 2'"'Prod.Casing Leak @ unknown depth. 16"62.58#H-40 Casing @ 120'KB 3rd cement plug=1700'AS1 Cement plug w/TOC @ approx.800'KB 2""potential leak(TAM Port Collar)@ 1,004'KB /�% I : Ultrasonic LDL found small Prod.Casing Leak @ 1.925' �� p O 111 9/21/13: Pumped 3'°cement plug(73 bbls of AS1 Cement)with planned TOC of approx.800'to 2n°cement plug=500'AS1 Cement plug w/TOC @ approx.2,500'KB cover IA casing leak and TAM Port Collar. Cement squeeze to isolate Tabasco,IA TOC found on CBL @ 2,970'KB 41 9/27/13: Drift and Tag TOC in tubing at 700'SLM. ,4010 State Witness MIT-T passed. MIT-IA failed. . SOV in GLM @ 3,228'KB 0 9130/13: DHD Performd MIT-IA to determine LLR I1„! A of 0.22 GPM. r' Cement Retainer Set @ 3,257'KB for 1"cement squeeze. ,A#= Jet Cut Tubing @ 3,319'KB. Video Log Confirmed ESP cable and Tubing was severed. i_ KI Plan Forward: 3.5"9.3#1-80 Tubing @ 3,314'KB ,410 1.)E-line to RIH wl CBL to locate TOC in IA.and ) , ' punch holes in tubing to create a circ.point. Slotted Nipple @ 3,324'KB I1 %! ammo_" 2.)SLB to pump fullbore cement job.brining /I; /P cement to surface in both Tubing and IA. 5.13"OD Tandem Seals @ 3,328'KB ✓1 3.)Post Job MIT-T and MIT-IA to 1.500 psi to be performed. T and IA DDT as well. VIEW 5 62"OD Motor(di 3,344'KB Motor Centralizer(d 3.350'KB ` o" / a Baker SC-1 Packer @ 3,379'KB �r `r Sliding Sleeve (g?3,388'KB �TOP� 5"KOIV @ 3,407'KB 5 Joints of Gravel Pack Screens-Top .! 3,484'KB / "29.7# Casing 3,493'KB 758 29.7 L-80 9 8.5"Open Hole<di 3,757'KB TW �r • K WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 9, 2013 Attn.: Makana Bender '2,00-01 333 West 7th Avenue, Suite 100 gT2oG3D Anchorage, Alaska 99501 .M K BENDER 3 J RE: Tubing Punch Record, Cement Bond Log: 2T-204 Run Date: 9/6/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 2T-204 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20327-00 Cement Bond Log SCANNED 1 Color Log 50-103-20327-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 • Fax: 907-273-3535 matthew.cook@halliburton.com Date: L ". Signed: 1. 0 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg IK113 DATE: August 03, 2013 P. I. Supervisor ? 1( FROM: Lou Grimaldi SUBJECT: Wellbore Plug Verification Petroleum Inspector KRU 2T-204 PTD 2000160 - Conoco Phillips Alaska Inc. Kuparuk River Field/Unit � tt� („ 1 X1`6 Friday, Au�i� ZO .5: I witnessed the verification by Wireline and Pressure Test of a wellbore plug in C.P.A.I. well 2T-204 in the Kuparuk River Field. I arrived to find the wireline unit and pump truck rigged up to the well. The wireline operator, Chad Kenyon, was in charge while there was wire in the hole and the first part of the pumping job. They picked up a 4' x 2.5" bailer with a mule shoed flapper bottom to RIH with and tag. They got down to 3094 ft (RKB corrected) and tagged without going deeper. They jarred down 3 times and had to over pull to come free. They pulled out of the hole and the bailer was filled with diesel contaminated cement. Little Red Services then lined up for the pressure test on the tubing which went as follows: Pretest Initial 15 Minutes 30 Minutes Inner Annulus 60 60 60 60 Tubing 180 1530 1410 1310 This was called a {_gland the tubing pressure was brought back up by Little Red Services with the following results: Pretest Initial 15 Minutes 30 Minutes Inner Annulus 60 70 70 70 Tubing 1310 1590 1560 1540 This was called acceptable and a negative pressure test was performed on the tubing with acceptable results. Little Red rigged up on the inner annulus for a pressure test with the following results: Pretest Initial 15 Minutes Inner Annulus 380 1520 1260 Tubing 10 20 10 24,or; 4 o-tr,k lass 2013-0802 23-0802_20 13-0 8 02_W e l lbore_P lug_KRU_2 T-2 04_1 g.docx.docx 1 of 2 • This was called a fail and the inner annulus pressure was brought back up by Little Red Services with the following results: Pretest Initial 15 Minutes Inner Annulus 1190 1520 1320 Tubing 20 30 35 The IA pressure seemed to fall between 10-15 psi per minute without stabilization and the IA test was called a failure at this time. I left location at this time leaving instructions with the Little Red operator, Lee Glick, for the plug problem to be brought to the Commission for resolution. Attachments: None Non-Confidential 2013-0802_2013-0802_W ellbore_Plug_KRU_2T-204_1g.docx.docx 2 of 2 immomi■ommilmiirli■■•■•■ w w \��� ��� THE STATE Alaska Oil and Gas °fALASKA Conservation Commission Of Pt TR GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0 ��. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 �yf���� p y��».. Y- Fax: 907.276.7542 Tyson Wiese / / Wells Engineer j,k7 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -204 Sundry Number: 312 -388 Dear Mr. Wiese: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, I y Fo t 2 4 - a r Chair DATED this /9 day of October, 2012. Encl. STATE OF ALASKA V • ' AIL OIL AND GAS CONSERVATION COM•ION ` I ' APPLICATION FOR SUNDRY APPROVALS i O � 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend Rug Perforations 17 • Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development • Exploratory r 200 -016 • 3. Address: 6. API Number: Stratigraphic r Service r P. 0. Box 100360, Anchorage, Alaska 99510 50- 103 - 20327 -00 • 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r 2T -204 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25569 ' Kuparuk River Field / Tabasco Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 3757 • 3310 ' 3670' 3238' 3670' Casing Length Size MD TVD Burst Collapse CONDUCTOR 85 16 120' 120' SURFACE 3459 7.625 3493' 3089' RECEIVED . LINER 291 4 3670' 3239' ,—g AO Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner 3379' -3670' 2990' -3239' 3.5 L - 3351 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER SC -1 GRAVEL PACK PACKER MD =3379 TVD =2990 NO SSSV 12. Attachments: Description Summary of Proposal J;i 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/1/2012 Oil r Gas r WDSPL r Suspended ( . 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese © 263 -4250 Email: Tvson.M.Wiese(ilconocophillios.com Printed Name T Son Wiese Title: Wells Engineer Signature Phone: 263 -4250 Date ‘O / q /A Commission Use Only Sundry Number3i Z Conditions of approval: Notify Commission so that a representative may witness JJVV Plug Integrity BOP Test r Mechanical IntegrityTest r Location Clearance r Other: A/ .- a�?('6. 21 h�S lh AGl va vi C. of posf" �t� f p � ` 'S Spacin Exception Required? Yes III No 11 Subsequent Form Required: /t — IV 7 ( ' APPROVED BY 4 r Approved by: rd—.----- COMMISSIONER THE COMMISSION Date: G / 0 — i j / . Approved application is valid for 12 months from the date of approval. ' J • 1 - f sed 100/2012] 9 Ini2 VLr tJ ubmit Form and Attachments in Duplicate I.,' i KUP • 2T -204 . Conoco("hiflips I Well Attributes Max Angle & MD TD Alaska, Inc, Wel!bore APUUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm )ftKB) 501032032700 TABASCO PROD 34.49 3,713.68 3,757.0 "' ' Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NONE 15 11/13/2007 Last WO: 6/6/2000 5/12/2000 Well Con(9: - 2T -204, 2/1/201211:04'48 AM - Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 3,248.0 9/4/2007 Rev Reason: WELL REVIEW osborl 2/1 /2012 Casing Strings Casing Description Strung 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 30 - - CONDUCTOR 16 15.062 35.0 120.0 120.0 62.58 H - 40 WELDED L " Csing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND)... String Wt... String... String Top Thrd SURFACE 75/8 6.151 34.6 3,493.2 3,089.0 29.70 L - 80 BTCM ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String... String Top Thrd 1 LINER 4 3.500 3,378.9 3,670.0 3238.6 9.50 L-80 SLHT Liner Details Top Depth (TVD) Top Inc( Noml... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 3,378.9 2,990.0 30.45 PACKER BAKER SC -1 GRAVEL PACK PACKER 4.000 3,387.5 2,997.4 29.92 SLEEVE BAKER 80-40 GRAVEL PACK SLIDING SLEEVE 4.700 3,390.0 2,999.6 29.92 SBE BAKER 80-40 SEAL BORE EXTENS 3.980 -_ 3,407.1 3,014.3 29.92 KOIV MODEL 'C' KOIV Size 5 w/Ryton Flapper 3.500 3,484.1 3,081.1 29.92 SCREEN BAKERWELD GRAVEL PACK SCREEN 5 "x.020" GAUGE 3.500 3,669.5 3,238.2 34.49 BULL PLUG BAKER BULL PLUG, SEAL LOCK HT 3.500 CONDUCTOR, 35 -120 Tubing Strings ;? '"' Tubing Description String 0... String ID _. Top )ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 30. 3350.8 2,965.9 9.30 L -80 EUE -8rd § r Completion Details Top Depth (TVD) Top Inc! Noml... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 30.3 30.3 -4.88 HANGER VETCO GRAY TUBING HANGER 3.500 3,324.0 2,942.8 30.65 NIPPLE CENTRILIFT SLOTTED NIPPLE 2.875 3,327.0 2,945.4 30.64 INTAKE CENTRILIFT TTC CROSSOVER INTAKE GAS LTD. - 3,328.4 2,946.6 30.63 SEAL CENTRILIFT TANDEM SEAL SECTION 3,228 3,342.2 2,958.5 30.58 GEARBOX CENTRALIFT GEAR REDUCTION UNIT 3,343.5 2,959.6 30.58 MOTOR CENTERLIFT MOTOR 5/HP 1315/26 3,350.3 2965.4 30.55 CENTRALIZER CENTRALIFT MOTOR CENTRALIZER 1.995 4; I Stimulations & Treatments , , , , , , Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (MKB) Type Date Comment 3,379.0 3,670.0 2,990.2 3,238.6 STIM 9/24/2000 FORMIC ACID TRTMT 1 3,379.0 3,670.0 2,990.2 3,238.6 STIM 7/22/2001 ACID STIMULATION Notes: General & Safety NIPPLE, 3,324 • End Date Annotation 12/10/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 INTAKE, 3,327 i p „, SEAL, 3,328 ,. GEARBOX, 3,342 MOTOR, 3,344 CENTRALIZER, 3,350 _ J I I Mandrel Details Top Depth Top Port (ND) Ind OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (!n) (psi) Run Date Com... 1 3,228.4 2,860.8 30.99 CAMCO KBMM 1 ESP ' SOV BK 1.000 0.0 7/22/2008 ►7\ SURFACE, f O' STIM,3,379 • S i • STIM, 3,379 LINER, 3,3794,870 ' TD, 3,757 • • 2T -204 Well Suspend • Permit to Drill #: 200 -016 The objective of the proposed 2T -204 well suspend (P&A) is to utilize cement plugs to isolate the Tabasco - formation. This well is a single casing ESP producer, and has one barrier between the reservoir and surface. To mitigate the associated single casing risks, the formation will be isolated with a cement plug. It has been determined that it is not economic to return this well back to production at an estimated rate of Tess than 35 • BOPD. j cO ^ X' 4I'S well II Air G v,'rjIk coop/like for (PPayr , (/.f5i07Y I 1 € welt .5 71i p co d eor Proposed Well Suspend Procedure: d ec,; 5%o. (Or / //2_ Slick Line / Little Red: 1. RIH with 3 tubing Jet Cutter Dummy Drift Assembly to 3,324' KB. 2. RIH with cement retainer dummy drift (2.78" x 1.5' retainer w/ 2.20" x 8' setting tool), and drift 3.5" tubing to the ported nipple @ 3,324' KB. 3. Set catcher on top of seal assembly Y@ 3,328' KB. 4. Pull OV from mandrel @ 3,228' KB, Install DMY valve in place of OV. Pull catcher. 5. Pump 150 bbls of Diesel down tubing, through the pump intake, and up the IA. 6. RIH with D &D Hole Finder and set just above nipple @ 3,324' KB. MIT -T to 1,000 psi. 7. POOH with D &D Hole Finder, Well is Ready for E -line Jet Cutting Operations. E -Line / Little Red: 1. Ensure that the 10 -403 Sundry has been approved by the AOGCC. 2. RIH with caliper and log from top of pump seals @ approx. 3,328' KB to surface. 3. RIH and jet cut tubing @ approx. 3,319' KB, in the middle of the 10' pup joint above the slotted nipple. The ESP completion should drop into the28' rat hole below. 4. RIH with a 2 jet cutter and perform a jet cut across the exposed ESP cable. 5. RIH w/ downhole camera (w/ side view) to check tubing cut and condition of ESP cable. 6. Using Diesel, Perform step rate inj. test to verify required rate for cementing ( +/- 2 BPM). 7. Well is Ready for Coil Tubing Operations. Coil Tubing: (Isolate Tabasco Formation) 1. RIH w/ cement retainer and lightly tag the centrilift slotted nipple @ approx. 3,324' KB. 2. PUH and set the retainer @ approx. 3,257' KB (middle of full tubing joint) 3. Perform Injectivity test to ensure adequate rates for cementing operations. ( +/- 2 BPM) 4. Pump /Squeeze 59 bbls of 15.8# cement into the O.H. Tabasco Gravel Pack below. - 5. Open up the IA, and displace 11 bbls of 15.8# cement to a planned TOC of 3,000' KB. 6. Unsting from retainer, Close in IA, Open Choke, and lay in 3 bbls cement to 3,000' KB. 7. Clean out excess cement and freeze protect tubing from approx. 3,000' KB to surface. Slick Line / Little Red: 1. WOC at least 24 hours prior to tag and test. 2. Notify AOGCC Inspector (659 -2714; 659 -3607 pager) of the timing of the post- cement plug tag and PT. Provide at least 24 hour notice. 3. Tag TOC @ approx. 3,000' KB. -/ 4. Test cement plug to 1,500 psi. MIT -IA to 1,500 psi. Record Results. 5. Perform a drawdown test on the tubing and IA. TW • • • E -line / Little Red: 1. RIH w/ CBL to check for TOC in the IA prior to the tubing cut. 2. RIH and jet cut tubing mid joint above measured TOC. 3. Perform Injectivity test to ensure adequate rates for cementing ( +1- 2 BPM). 4. Well is Ready for Full Bore cement job (AS1) Schlumberger Fullbore Pumping: (Further Suspend, bringing cement to surface) 1. Pump 128 bbls of AS1 cement down tubing, through the tubing cut, and up the IA. 2. Monitor IA for cement returns. Take a sample of cement returns and check weight, to ensure good quality AS1 cement to surface. 3. Once good cement is seen at surface, clear the tree and the surface lines of cement. 4. RDMO Little Red: 1. WOC for at least 24 hours prior to performing any MIT testing. 2. Perform MIT -T and MIT -IA to 1,500 psi. TW • • 2T -204A PTD #: 200 -016 ESP Completion Well Suspend i Current Completion Proposed Pre Rip ST P&A 1.) Run Caliper All 11116. from ESP Seal �� � Assembly to Surface * 1fi' 62.58# H 40 Casing @ 120' KB ` � 2.) Cut Tubing @ ryt 3,319' KB (middle 0 of 10' pup joint) i i i /i� 3.) Cut ESP Cable @ '4 approx. 3,321' KB SOV in GLM @ 3,228' KB I_ ( dependa e nt upon n gap j$/ 4.) Perform step rate inj. I /// test through gravel inf p a ck . vl �� ,_n 3.5" 9.3# L -80 Tubing @ 3,314' KB � through gravel pack. �Y' 5 .) Set cement retainer « S lo tted Nipple @ 3,324' KB �r�� 1/ mid j3 i25 @ a �"" 4.5" OD TTC Cross Over intake @ e ; 3,327' K8 0, I 6.) Squeeze 59 bbls of Class Irl_ /� G cement through slots, past _ � �// motor, and into the gravel pack. 7.) Open IA and Pump 11 / 5 13" OD Tandem Seals @ 3,328' KB j bbls Class G cement to a / planned TOC of 3,000' KB. I ME PARIPP 1 1 ri , 8.) Close IA. Open Choke, i Lay in 3 bbls Class G 1 ii cement to planned TOC of I approx, 3,000' KB. Freeze II V Protect Well. • j� ,�' 9.) MIT -T, MIT -IA, and Tag TOC @approx. 3,000' KB, 6. 62 OD Moor @ 3,344' K2 ,/ G wi witness after 24 hours Illyo „i woc. f r 10.) Cut tubing mid joint @ 4 0 ` i approx. 2,900' KB, or — above IA TOC. rioi E o 1 Motor Centralizer @ 3,350' KB • • i t s P 11.) Confirm Circ. rate , a f 1 r 0 � I U , '/ through cut, and pump y 128 bbls of AS 1 cement to ! surface in tubing and IA. - 1wwwww■ �� Baker SC -1 Packer @ 3,379' KB ► f `i // � 1% 12.) MIT -IA and MIT -T TOE after WOC for 24 arm S liding Sleeve @ 3,388' KB � hours. 111 �r;1 X 5" KOIV @ 3 KB II 5 Joints of Gravel Pack Screens - Top @ 3.484' KB 7 5/8" 29.7# L -80 Casing @ 3.493' KB Estimated Fill `; 3.493' KB. outside of casing shoe. and around gravel pack screens. 8 5" Open Hole @ 3,757' KB TA/ 10-9 -2012 TW • • Roby, David S (DOA) From: Roby, David S (DOA) Sent: Thursday, October 11, 2012 1:30 PM To: 'Wiese, Tyson M' Cc: Nenahlo, Thomas L Subject: RE: Sundry application for well 2T -204 Thanks for the info. That takes care of my concerns. Dave Roby (907)793 - 1232 From: Wiese, Tyson M [mailto: Tyson .M.WieseCThconocophillips.com] Sent: Thursday, October 11, 2012 12:44 PM To: Roby, David S (DOA) Cc: Nenahlo, Thomas L Subject: RE: Sundry application for well 2T -204 David, Thanks for the reply. I did not include it in the 10 -403 Sundry paperwork, but below is the information I was able to find from the Drillsite Engineer regarding the decision to P&A this well. It seems that the allocated production rates for this well were not accurate before it was shut in 2008. Although the allocated production history indicated approximately 100 BOPD of production from 2T -204 before the well was shut in in 2008, it was determined that the allocated production history was not accurate and that the true oil production rate was less than 35 BOPD. In addition to the low oil production rate, it is not believed that this well would be able to remain online due to poor injection support and the inability to inject diesel in to the formation when the inner annulus is isolated with the SC -1 gravel pack packer. Well 2T -204 is located on the eastem flank of the Tabasco formation and is isolated from injection support by faulting and discontinuities in the pay sands between it and it's adjacent injector, well 2T -201. I cc'd Tommy Nenahlo, Drillsite Engineer, so he can include additional comments on the 2T -204 P&A justification if needed. Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1- 907 - 263 -4250 Cel1:1- 907 - 230 -5388 From: Roby, David S (DOA) [mailto:dave.robv@alaska.gov] Sent: Thursday, October 11, 2012 11:48 AM To: Wiese, Tyson M Subject: [EXTERNAL]Sundry application for well 2T -204 Tyson, I am reviewing your application to plug and suspend the reference well and have a question about production potential In the application you indicate the well would be expected to produce less than 35 BOPD if it was • • repaired. However, when I look at the historical production data for the well it indicates that up until about 8 months before the well went offline that it was capable of producing in the neighborhood of 300 BOPD. During the last 8 months it looks like water production began increasing dramatically and oil production started to fluctuate dramatically. Production dropped as low as approximately 70 BOPD before rebounding to nominally 150 BOPD, or so, during the final few months before going offline for good in October 2008. Could you please explain why you now believe the well would only be capable of 35 BOPD or less if repaired? Thank you, Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793 -1232 2 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 1, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: Ft a~~°~ . ~... - ©a" p~~ ~ ~ ~° `~ 2r ~~/~D ~.~~i,: ~ ~ 2d1~ ~~~~s~c~ ~~s Cer~. Ct~rt~nissio~~~ ~il0ii~31'c~~]2 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 21St. The corrosion inhibitor/sealant was pumped July 30tt', 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8101/10 2R_ 2K_ 2t pon Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 26-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31!2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30!2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n!a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 T-204 50103203270000 2000160 SF n!a 24" Na 5.1 7/31!2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 .WE'LL LOG TI~A/1/~~I/IfTTAL ,,. PaoAcrivE Diagnosric SEltvicES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) MTT Report 2] 10-May-10 2T-204 ~~ -v~ ~ 1 Report 50-103-20327-00 i ~' ~Ji~' ~ C...- A ; it Signed Print Name: ~. ,,y ° PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. (NTERNATIONAI AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-malt.: adsanchorageCrDmemorvloa.com WEBSITE : www.memorvlop.com ~~AY1i2010 Date C:\Documenffi and Settings\Diane Williams\Desktop\Transmit_Conoco.docx • • Memory Magnetic Thickness Tool Log Resutts Summary Company: ConocoPhillips Alaska, Inc. Well: 2T-204 Log Date: May 10, 2010 Field: Tobasco Log No.: 7408 State: Alaska Run No.: 1 API No.: 50-103-20327-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD Top Log Intvll.: Surtace Pipet Use: Tubing Bot. Log Intvl1.: 236 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib. L-80 BTCM Top Log Intvl1.: Surface Pipet Use: Surface Casing Bot. Log Intvl1.: 236 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl1.: Surface Pipe3 Use: Conductor _ Bot. Log Intvl1.: 120 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 3.5" tubing and 7.625" casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 15 fpm, with the 5Hz and 8Hz passes selected for analysis in this report. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surface to 236'. Changes in metal volume are relative to the calibration points at 58.2' and 120', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by the 5Hz and 8Hz passes is included in this report. This plot indicates an area of significant metal loss over the interval (4' -18') for both frequency passes, with the 5Hz pass indicating -23% relative metal loss and the 8Hz pass indicating -17% relative metal loss. Since the lower frequency magnetic signals are more capable of permeating metal further from the tool than the higher frequency signals, the response from the 5Hz pass is considered to be more representative of the relative overall metal loss from the outer concentric string(s) in this interval. A log plot of the entire 5Hz pass is included in this report. A maximum ~23% circumferential metal loss is indicated in the interval between 4' - 18' in the 5Hz pass. A maximum ^'3% circumferential metal loss is indicated in the interval between 37' - 47' in the 5Hz pass. A maximum -2% circumferential metal loss is indicated in the interval between 32' - 36' in the 5Hz pass. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Field Engineer: Wm. McCrossan Analyst: HY. Yang /J. Burton (MTT) Witness: 8. Boehme Proactive Diagnostic Services, Tnc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-i369 E-mail: P(7Svmemoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 c~UU ~ d l ~ A o`~MwErrs 51~and 8Hz Passes Delta Met~hickness Overlay 4. ~[~. F ~s 2T-204 May 10, 2010 Px°Acrivc Dinyuosric SENVICES Database File: d:lwarriortdatal2t-041overlay. db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Tue May 11 11:16:22 2010 Charted by: Depth in Feet scaled 1:150 -50 a Delta Metal Thickness 2010 (5Hz) (%) Delta Metal Thickness 2010 (8Hz) (%) 5" Tubi T Metal Thickness 2D10 2D Delta Metal Thickness 2010 40 60 80 Metal Thickness 2D10 ~-Inverted Response :tom of 16" Conductor} 50 50 100 • 120 140 160 180 200 Metal Thickness 2010 220 Delta Metal Thickness 2010 -50 Delta Metal Thickness 2010 (5Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz) (%) 50 A ~ ~O Fcs~ `~~wE"s rded Magnetic Thickness Data - 5Hz Pass ~ ~ 2T-204 May 10, 2010 PROACTIVE DIAq NOSTIC SERVICES Database File: d:\warriorldatal2t-041filt5hz.db Dataset Pathname: filt5hz Presentation Format: 1.8 scale Dataset Creation: Tue May 11 09:28:06 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness {%) 50 1.8 MTTP01 11.8 0 Line Speed (ftlmin) -200 -7 MTTP12 3 Tree Line Speed Han er - ~ - P --- ~ -_ up ~~ - - - - ~ ' i 3.5" Collar Pup 3.5" Collar ~ 23% Metal Loss 20 7 625 " Co llar . - --- Tubin Jt 1 g . 2% Metal Loss 3°I M t l L ° e a oss 4 ~ 3 5" Co llar 0 . ° 3 /R Metal Loss D lt M t l Th i k e a e a c ness r Tubing Jt. 2 ~ 60 7 625" C ll . o ar ~~ 3.5" Collar ~ ~ Bo ttom of 16" Conducto ~- r f i Tubing Jt. 3 ~ i i 100 p 3.5" Collar ~~ 625" Collar ng Jt. 4 120 Collar ~F-ll "~ f--r I~ 140 7 Tubing Jt. 5 160 5" Collar~-L ~~ I I I I~ Tubing Jt. 6 180 7.625" 5" Collar ~ 200 Tubing Jt. 7 Metal Thickness 220 625" Collar Line Speedl I I (Tubing Jt. 8 -50 Delta Metal Thickness (%} 50 1.8 ' 0 Line Speed (ft/min) -2D0 MTTP01 11.8 ~ -7 M 3 ii C' t~ ii u u ii i~ v n n ~--1~ KUP ~ 2T-204 ConocoPl'lillips I f 7 ell Att ributes An le 8 MD TD WellboreA PINWI fleltlRime Well Status ProMnJtype InG11 MDntl(B) AUBtmpI KB) "''~ " ~" ~~ 501032032700 TABASCO PROD 34.49 3.713.68 3,757.0 Comment K2S (ppm) Date ArrtotaDOn Flttl Date KB-Grtl (R) Rig RNeas e Date ... z tzn/x~a w t n zT SSSV: NONE 15 7!1/2008 Last WO. 5/12!2000 ,. e n - - emetic-A tai Ama[aUan De pth ) ~~ Aftttotatlat EnO Date Last Tag' 3,248.0 9/4/2007 Rev Reason: PULL PCP PUMP ASSEMBLY 12/7!2008 Casin Strin s String O D SMng ID Set Depfh Sel DepM (TVD) SMng Strin g Caring D esctlptlon (In) Pn1 Top (tIKB) ptlcBl (ttKB) (IbsfR) Grac e Strl To p Thtl CONDUCTOR 1 6 15.062 0.0 120.0 120.0 62.58 H-40 WELDED ' SURFACE 7 5/ 8 6.151 0.0 3,493.0 3,088.8 29.70 L-80 BTCM - ,. LINER 4 3.500 3.379.0 3.670.0 3.238.6 9.50 L-80 SLHT Tubin Strin s String 0 0 SDing ID Set Deptlt Set Depth ITVD) Sttlng Wt String 7W1 Desctl ton IIM lIN T B (~) pn®) pDSllt) Otatl e Strf T Thtl HANGER 3C TUBING 31/ 2 2.992 0.0 3,328.0 2,946.3 9.30 L-80 EUE 8RD . Other I n Hole All Jewe l .Tubin Run 8 Retrievable Fish etc. Top Depm 1~1 Topln~l T 1n~1 (°) Deswi n Commert Rut Date W 30.3 30.3 -0.88 H ANGER VETCO GRAY TUBING HANGER 6/12/2000 3.500 3.228.0 2.860.4 30.99 E SP CAMCO/KBMNVI/SOV/BK/// Comment: 2000 PSI STA 1 7Y22/2008 2.920 I~ ~t M ANDREL coNDUC7oR, ~ t'-0 3.324.0 2,942.8 30.65 N IPPLE SLOTTED NIPPLE 5/12/2000 2.875 ~ 3,328.0 2,946.3 30.63 S EAL SEAL 5/12/2000 3.980 ~' ~ 3,342.0 2.958.3 30.58 G EARBOX GEARBOX 5/12/2000 0.000 3,343.0 2,959.2 30.58 M OTOR CENTRILIFT MOTOR 5/HP KMH 1315/26 5/12/2000 3,379.0 2,990.2 30.45 G RAVEL GRAVEL PACK 5/12/2000 0.000 Est' P ACK MANDPEL. 322fi _ 3,379.0 2.990.2 30.45 P ACKER BAKER 80-00 PACKER 6/12/2000 3.500 3,387.0 2.997.0 29.92 S LEEVE BAKER SLIDING SLEEVE 6/12/2000 4.700 Stimula tions & Treatments Badom Mn Top Max Bbn Tap Depth Depth InK61 1~1 1n~1 l~Bl pate Commert ' 3,379.0 3,670. 0 2,990.2 3,238.6 S TIM 9Y24/2000 FORMIC ACID TRTMT NIPRLE.33z4 3,379.0 3.670. 0 2.990.2 3,238.6 S TIM 7/22/2001 ACID STIMULATION SEPL. 3 328 - GEARED: 3 34[ MOTOR,3343 y ~ PACKER, 3 314 p 7; SLEEVE, 3,38] I I SVRFACE. 3 493 GRAVEL PACK, 3,3]9 ST IM. 3,379 STIM, 3,379 LINER, 3 6]° TD, 3,757 2T-204 (PTD# 200-016) Report Of Failed ESP Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, December 15, 2008 8:56 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs Subject: 2T-204 (PTD# 200-016) Report Of Failed ESP Tom/Jim, Tabasco ESP producer 2T-204 (PTD# 200-0161 has been determined to have a damaged downhole mechanical coupling between the through-tubing conveyed progressive cavity pump and the motor. The well was completed on 12 May 2000 and the pump began to show indications of pertormance degradation in late 2007. A rig workover has been evaluated, but determined to be uneconomic at this time. The well will remain shut in until a workover can be justified or an alternate utility for the wellbore can be determined. Please contact me at your convenience if you have any questions or comments. Martin Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. Of11ce 907-659-7724 Cell 907-943-1720 Pager 907-659-7000 #909 r 12/15/2008 PHl.LIPS Alaska, Inc. . A Subsidiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 May 3, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2T-204 (200-016) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the formic acid treatment and ESP operations on the KRU we1l2T-204. If there are any questions, please contact me at 263-4574. Sincerely, )1, ;/If ~ M.Mooney Staff Engineer Phillips Drilling 5~NED SEP 1 3 2007 MM/skad RECE\VEO MA'{ 0 4 2001 Commission Oil &. Gas coos. þJaska />-ocl1Ofage . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate - Pull tubing_ Alter casing _ Repair well _ Other - 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development _X RKB 30 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service Kuparuk River Unit 4. Location of well at surface 8. Well number 4686' FNL, 4723' FEL, Sec. 1, T11N, R8E, UM (asp's 498945, 5970573) 2T-204 At top of productive interval 9. Permit number 1 approval number 294' FNL, 1691' FWL, Sec. 12, T11 N, R8E, UM (asp's 500079, 5969690) 200-016 1 At effective depth 10. API number 50-1 03-20327 At total depth 11. Field 1 Pool 378' FNL, 3516' FEL, Sec. 12, T11 N, R8E , UM (asp's 500152, 5969602) Kuparuk River Field 1 Tabasco Oil Pool 12. Present well condition summary Total depth: measured 3757 feet Plugs (measured) set ESP @ 3256' MD (9/29/00) true vertical 3318 feet Effective depth: measured 3256 feet Junk (measured) true vertical 2884 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 120' 16" 9 cu yds High Early 121 ' 121' SURFACE 3378' 7-5/8" 520 sx AS III, 278 sx Class G 3493' 3089' 291' 4" gravel pack screen 3670' 3242' Perforation depth: measured N/A RECEIVED true vertical N/A MAY 04 2001 Tubing (size, grade, and measured depth) 3-1/2",9.3#, L-80 Tbg @ 3328' MD. Alaska Oil & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) BAKER 80-40 PACKER @ 3379' MD. No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached description Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 54 3 8 - 233 Subsequent to operation 131 74 2 - 301 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed JA. jj~. Title Staff Engineer Date iy/ÓI Michael Mooney Prepared Sharon Allsup-Drake 263-4612 , ~ Form 10-404 Rev 06/15/88· 8U8MITlN DUPLICATE ~ . 2T-204 Event History . , Daté Comment 05/17/00 SET ESP @ 3315' RKB; SET PACK OFF @ 3277' RKB; SET 1.0" X 2000 PSI SOV @ 3231' RKB; PT'D PACK OFF, GOOD TEST. SET SLIP STOP @ 3269' RKB. [ESP WORK] o 7/1 ~/~~...u.u......¡:>.LJ~.~..E..~.F'..¡:>LJ.~.F'.u(g)u~~.~~:.V'!.~.~;u¡:>LJ.~~.~.~§:r..1.:'.~.?~~~.~.~<:)Yu(g)u~~.?~:..I3~~:J§~.~\I\I~¡:¡.I<]."u .........u...uu..... 07/31/00 TAPPED ON MOTOR SPLINE @ 3324' RKB. FREED UP SAME. [ESP WORK] 09/24/00 COMPLETED FORMIC ACID TREATMENT. PUMPED 93 BBLS OF 9% FORMIC ACID SOLUTION. INJECTIVITY IMPROVED BY -400 PSI AT 2.5 BPM WITH THE TREATMENT. [Other Stirn] 09/29/00 SET ESP PUMP @ 3256' WLM; SET PACK-OFF ASSEMBLY @ 3256' WLM; SET SLIP STOP @ 3248' WLM; PULLED 2000# SOV & SET 3000# SOV @ 3228' RKB. Page 1 of 1 5/2/01 MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc DATA SUBMITTAL COMPLIANCE REPORT 9/612002 Permit to Drill No. 2000160 Well Name/No. KUPARUK RIV U TABS 2T-204 Operator PHILLIPS ALASKA INC. MD 3757 TVD 3308 Completion Dat 6/6/2000 ~ Completion Statu 1-OIL Current Status APl No. 50-103-20327-00-00 loOIL UIC N REQUIRED INFORMATION Mud Log N_9o Sample N_.9 Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type (~ Fmt L ~ L ~ (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval OH I Start Stop CH 3488 3743 Open Dataset Received Number Comments 6/27/2000 09638/--~8-3743 PEX-TVD 5 FINAL CST 5 FINAL 9638 1 9808 1 DGR/EWR-MD 2/5 FINAL DGR/EWR-TVD 2/5 FINAL DSI-QC PLOT 2 FINAL SRVY RPT PEX-LL/HALS 5 FINAL PEX-TLD DT/NL 2/5 FINAL DSSI 2/5 FINAL 109 3725 Open 3488 3743 OH 3488 3743 OH OH OH 112 3755 OH 112 3308 OH 3490 3762 OH 0 3495 OH 3488 3743 OH 3488 3743 OH 3488. 3743 OH 9/19/2000 09808'---'1~9-3725 6/27/2000 3488-3743 6/27/2000 3488-3743 6/27/2000 9638_..~SCH LUM PEX-HALS/DSI 9/19/2000 9808 .~SPERRY MPT/GR/EWR4 9/19/2000 112-3755 4/16/00 THRU 9/19/2000 ~-33~8 4/16/00 THRU 5/31/2000 ~90-3762 4/28/2000 ~ SPERRY 0-3495 6/27/2000 3488-3743 6/27/2000 3488-3743 6/27/2000 3488-3743 Well Cores/Samples Information: Name Interval Start Stop Sent Dataset Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? Analysis R~.n~.iv~.d? Daily History Received? ~)/N Formation Tops ~/N Permit to Drill No. 2000160 DATA SUBMITTAL COMPLIANCE REPORT 9/612002 Well Name/No. KUPARUK RIV U TABS 2T-204 Operator PHILLIPS ALASKA INC. MD 3757 TVD 3308 Completion Dat 6/6/2000 Completion Statu 1-OIL Current Status APl No. 50-103-20327-00-00 1-OIL UIC N Comments: Compliance Reviewed By: Date: ppi LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 3, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2T-204 (200-016) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the stimulation treatment on the KRU well 2T-204. If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad RECEIVED Alaska Oil & Gas Cons. Commissio. Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4686' FNL, 4723' FEL, Sec. 1, T11 N, R8E, UM At top of productive interval 294' FNL, 1691' FWL, Sec. 12, T11 N, RSE, UM At effective depth At total depth 378' FNL, 3516' FEL, Sec. 12, T11N, R8E, UM 5. Type of Well: Development __X Exploratory _ Stratigraphic __ Service__ (asp's 498945, 5970573) (asp's 500079, 5969690) (asp's 500152, 5969602) 6. Datum elevation (DF or KB feet) RKB 115 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-204 9. Permit number / approval number 200-016 / 10. APl number 50-103-20327 11. Field / Pool Kuparuk River Field / Tabasco Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 120' SURFACE 3378' LINER 291' 3757 feet Plugs (measured) 3318 feet 3256 feet Junk (measured) 2884 feet Size Cemented Measured Depth True vertical Depth 16" 9 cu yds High Early 120' 120' 7-5/8" 520 sx AS III, 278 sx Class G 3493' 3089' 4" gravel pack screen 3670' 3242' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ~:;~::??~:?~:?~:~::??~?~:~?::~:::~:::~::??~?~:~:~:~:?~::~??:~:::~::?:~::~::?:?:?:~:~?~:::::::: ::::::::::::: ::::?::::::::::::::::::::::::::::?:::::::::::::::?::?:::?: x:: ::::5::::::5::::::;:::::::: ::::::5::5::::::::::::::; ::5:::: ::: ::: ::::5::::::::::;::: ::::: :::::::::;:::: :::.: ::: :::::::::. ::::: :,::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~:~¢'~ ~.~.¢'~.~.~.~/~ *~ X~,,/~/~ Title Staff Engineer Michael Mooney ~ Representative Daily Average Production or Injection Data .......................... ...O.!!..'.!~b..! ............................................................... G~S;!~. Wa!~r:Bbq Ca~!ng P~e~ssure ...... ~u.b!~g ~re~re.. .:.:~:~:.:~:~:~:~:~:~:~:~:.:~:~:.:.:<~:.:.:.:~:.:.:.:<.:.:-:.:~:.:.:.:-:-:.:.:.:-:-:.:.:.:~:.:.:-:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:.:.:~:.:~:~:~:~:.:~:~:~~.:~:~:.:~:~:.:.:<.:.:.:~:~~~:~:~:~:.:.:~:~:.:. .:.:.:.:.:.:.:.:.:.:..:.:-.:.:.:.:.:+ >>u>>> > :. > >... > > .:... u. <. >,. >......<.......... <<. <. <.. <<qo. <. <<<+x+>.<+u:<. <<. <<<<< Questions? Call Mike Mooney 263-4574 Prepared by Sharon A//su~Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 2T-204 Event History 07/20/01 O7/22/O 1 07/23/01 PULLED 1" SOY @ 3228' RKB. POCKET OPEN.LOAD CSG W/110 BBLS OF DIESEL. [GLV] COMPLETED ACID STIMULATION WITH 7.5% HCL/3% ACETIC ACID MIXTURE & 70% QUALITY N2 FOAM DIVERTER. SAW LITTLE PRESSURE RESPONSE DURING THE TREATMENT. LEFT BOTH THE TBG & IA COMPLETELY DISPLACED WITH DIESEL. [OTHER STIM] SET 1" SHEAR VALVE(PINNED FOR 3000 PSI TBG SHEAR) @ 3228' RKB. [GLV] Page 1 of 1 9/7/01 D R I LL_I I~1 r'~ To: State of Alaska Ataska:;Oit.mvff_ .6a~Co~~omm Atm.: Lori Taylor Anchorage, Alaska 9950 September 19, 2000 The technical data listed below is being submitted herewith. Please address any problems or concerns mthe-~on of. 2T-204: 50~ 2"x 5" TVD Resistivity & Gamma Ray Logs: .~ ~,~ ~ 03~26~27-00 FRtueline ~_ Eold~ Sepia 1 Blueline RECEIVED SEP 19 2000 ~.~ Oil& Gas Oons. ¢ommiss! ~chorag.~ 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2T-204, 1 LDWG formatted Disc with verification listing. API#: 50-103-20327-00 September 7, 2000 AK-MM-00022 PLEASE~~DGE. RECEI~..B¥ S!GNI~.G A~NB-RETL~.~L~ .G A-COPY OF. ~----"TI~d~J!TTAL' l~a~zl~RTO ~FItE-~~ON Sperry-Sun Drilling Service ~ JLm Ga!~ 5631 Silverado Way, Suite G. Anchorages. Alaska 99518 RECEIVED Date: $~ 'l,q ~nnn Naska Oil & (las Cons. Commission Anchorage Signed 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [~1 Gas r-] Suspended O Abandoned E] Service E] 2. Name of Operator ~~ ·7. Permit Number Phillips Alaska, Inc.~'""?'~~ 200-016 / 300-072 3. Address ~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 :, ,~_. 50-103-20327-00 Location ofwell at surface ~ 9. Unit or Lease Name 4. 592' FSL, 556' FWL, Sec. 1 T11N, R8E, UM (ASP: 498944.6 5970572) ~'~'~: .... Kuparuk River Unit At Top Producing Interval ~ 10. Well Number 294' FNL, 1691' FWL, Sec. 12, T11N, R8E, UM (ASP: 500079, 5969690)~.~¢~ 2T-204 At Total Depth ~ ~-b~,.~S ~ 11. Field and Pool 388' FNL, 1770' FWL, Sec. 12, T11N, R8E, UM (ASP: 500160, 5969591.5) ~~~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) ]6. Lease Designation and Serial No. - RKB 30 feet~ ADL 25569 ALK 2667 Tabasco Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. ~ 15. Water Depth, if o~hore 16. No. of Completions April 16, 2000 May 4, 2000 June 6, 2000 ~ N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey ~20. Depth where SSSV set 21. Thickness of Permafrost 3757' MD / 3308' TVD 3670' / 3238' TVD YES ~ No ~~ N/A feet MD 1567' (approx) ~22. Type Electric or Other Logs Run MWD/GWRes, E-line T-combo w/laterolog; sidewall cores 23. CASING, LINER AND CEMENTING RECORD S~ING DEPTH MD CASING SIZE WT. PER ~. GRADE TOP BO~OM HOLE SIZE CEME~ING RECORD~ AMOUNT PULLED 16" 62.5¢ H-40 Sudace 117' 24" 9 cu. Yds High Early 7.625" 29.7¢ L-80 Surface 3493' 9.875" 520 sx AS III, 278 sx Class G 4" 9.5¢ L-80 3379~ 3670' 8.5" gravel pack screen 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 3349' 3379' N/A 26. AOID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUOTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 22, 2000 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 6/30/2000 20.8 Test Period > 349 10 10 176~ 59 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY - APl (corr) press. 275 psi N/A 24-Hour Rate > 368 10 10 N/A 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. To be sent under separate cover Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. Top Tabasco NAME Base Tabasco GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 3116' 3525' 3652' 3123' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations and Directional Survey 32. I I~reby certify that the following is true and correct to the best of my knowledge. d¢.f-/ Title Drilling Team Leader Randy Thomas Questions? Call Tom Brockway 263-4135 INSTRUCTIONS Prepared by Sharon AIIsup-Drake 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain Item 28: If no cores taken, indicate "none". Form 10-407 Date: 06/22/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2T-204 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TABASCO SPUD:04/16/00 START COMP: RIG:NABORS 16E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20327-00 04/13/00 (D1) TD/TVD: 117/117 SUPV:FRED HERBERT MW: 0.0 VISC: ( 117) MOVE RIG 0 PV/YP: 0/ 0 APIWL: 0.0 Prepare rig for move. PJSM. Move rig module around pad to move off iL pad. 04/14/00 (D2) TD/TVD: 117/117 SUPV:FRED HERBERT MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) REMOVE BOOSTER WHEELS FROM DRILL MODULE. ON 2T PAD ~ 0 Continue with rig move to 2T pad. 04/15/00 (D3) TD/TVD: 117/117 SUPV:FRED HERBERT MW: 0.0 VISC: ( 0) MIX SPUD MUD 0 PV/YP: 0/ 0 APIWL: 0.0 Move modules to 2T pad. Rig up. Spot rig over hole. Nipple up diverter system. Rig accepted on 2T-204 ~ 23:00 hrs. 04/16/00 (D4) TD/TVD: 255/252 SUPV:FRED HERBERT MW: 8.6 VISC: 155 PV/YP: 34/33 (138) DRILLING AHEAD ~ 788 APIWL: 9.6 NU diverter system and perform diverter test. Drilling from 117' to 255' 04/17/00 (D5) MW: 9.6 VISC: 155 PV/YP: 40/44 APIWL: 6.0 TD/TVD: 2881/2562 (2626) CIRC & COND SUPV:FRED HERBERT POOH. Drilling from 255' to 816'. Circ slow, change shaker screens. Drilling from 816' to 2505'. Circ densified sweep around. POOH to 1555'. RIH to bottom, small bridge ~ 2270' Circ bottoms up. Drilling from 2505' to 2881' 04/18/00 (D6) MW: 9.6 VISC: 152 PV/YP: 40/45 APIWL: 5.8 TD/TVD: 3495/3090 (614) CIRC BEFORE CEMENTING. SUPV:FRED HERBERT/G.R. WHITLOCK Drill from 2881' to 3495' Pump sweep and circ till shakers clean. Short trip to hwdp. RIH. Proper fill, no problems. Circ. Monitor well, POOH. PJSM. Run 7-5/8" casing° CBU. Date: 06/22/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/19/00 (D7) TD/TVD: 3495/3090 SUPV:G.R. WHITLOCK MW: 0.0 VISC: 152 PV/YP: 0/ 0 0) RIG RELEASED APIWL: 0.0 Run 7-5/8" casing to 3493' Safety meeting. Pump cement. Bump plug and check floats. N/D diverter system. Install tree and test to 250/5000 psi. Prepare rig for move. RDMO. Release rig 4/20/00 @ midnight. 05/02/00 (D8) TD/TVD: 3495/3090 ( SUPV:FRED HERBERT MW: 9.7 VISC: 62 PV/YP: 23/25 0) RIH W/ DRILLING ASSY. P/U DP APIWL: 5.8 PJSM. Move rig from 2T-218 to 2T-204. Rig accepted on 2T-204 ~ 0330 hrs. ND tree. NU BOPE and test to 250/5000. PJSM. Hit ice plug ~ 213' 05/03/00 (D9) MW: 9.2 VISC: 45 PV/YP: 14/24 TD/TVD: 3685/3250 ( 190) POOH TO WIRELINE SUPV:FRED HERBERT APIWL: 4.4 Wash thru ice bridges e 210', 704', 983'. Wash thru ice bridges ~ 1200', 1690', 1875'. Tag cement ~ 3245' Displace well w/LSND. POOH. Circ bttms up. Drill cement from 3245' to 3362'. CBU. Test casing to 3200 psi. Drilling cement, float equipment. Drilling from 3495' to 3515'. Circ and cond for FIT. Perform FIT. Pump lo hi vis sweep and mud. Drilling from 3515' to 3685' 05/04/00 (D10) MW: 9.2 VISC: 48 PV/YP: 16/ 0 TD/TVD: 3755/3308 ( 70) POOH W/ DP. TAGGED SAND PLUG ~ 3664' SUPV:FRED HERBERT APIWL: 3.8 Drilling from 3685' to 3755'. Circ sweep around. Monitor well. POOH to 3000'. RIH to bottom. No fill. Circ sweep around. Monitor well, Ok, no losses. POOH slow to prevent swabbing. Monitor well for gains/losses, OK. PJSM. Run log #1 and #2. Change tools and run w/sidewall core. RIH with DP to set sand plug. 05/05/00 (Dll) TD/TVD: 3755/3308 ( SUPV:FRED HERBERT MW: 0.0 VISC: 48 PV/YP: 0/ 0 0) CLEAN PITS APIWL: 0.0 RIH tag bttm ~ 3755' Circ and cond mud for sand plug. Hold PJSM. Spot sand plug. POOH to 3460'. Let sand settle. Circ bttms up. RIH tag sand @ 3664'. Circ bttms up. Monitor well. POOH. RIH w/underreamer to 3494'. Open underreamer. Open hole to 8.5" from 3494' to 3664'. Circ sweep around. Monitor well, no losses. POOh to 2850'. RIH tag sand ~ 3670'. Circ sweep around. Monitor well, no losses. Pump slug and POOH. RIH w/tandem scraper assy. Date: 06/22/00 ARCO ALASKA INC. WELL SIIMMARY REPORT Page: 3 05/06/00 (D12) TD/TVD: 3755/3308 ( SUPV:FRED HERBERT MW: 9.2 VISC: 0) CLEAN PITS 0 PV/YP: 0/ 0 APIWL: 0.0 RIH to 3483' w/tandem scrapers. PJSM. Clean pits and surface equipment for well displacement and wellbore cleanup. 05/07/00 (D13) TD/TVD: 3755/3308 SUPV:FRED HERBERT MW: 9.2 VISC: 28 PV/YP: 0/ 0 0) RIH W/ GRAVEL PACK SCREENS ON DP APIWL: 0.0 PJSM. RIH tag ~ 3670'. Pump brine, xan vis pill. Spot pill on bottom. PJSM. Pump caustic wash and filtered brine. Rig up to pump formic acid for pickle job. PJSM. Pump acid. Reverse out acid. RIH and tag ~ 3670'. POOH for gravel pack screens. 05/08/00 (D14) TD/TVD: 3755/3308 SUPV:FRED HERBERT MW: 9.2 VISC: 0) P/U 3-1/2" TUBING 0 PV/YP: 0/ 0 APIWL: 0.0 POOH w/casing scrapers. R/U to run gravel pack screens. PJSM. RIH w/gravel pack screens, rabbit pipe to 3370' PJSM. RIH to 3670' Set packer, shear off. Pump gravel pack job. 05/09/00 (D15) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 3755/3308 ( 0) RUNNING ESP COMPLETION SUPV:RICK OVERSTREET Pull out of gravel. Monitor returns. Pump last of mudzyme pill and brine. Monitor well. Static no losses. POOH. PJSM. P/U 3.5" tubing and muleshoe. Reverse out sand from top of packer to 3385' (no sand). Circ 2 bttms up. Test BOPE to 250/5000 psi. PJSM. 05/10/00 (D16) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 3755/3308 ( 0) FREEZE PROTECT EQUALIZING. (U-TUBING) SUPV:RICK OVERSTREET PJSM. RIH w/ESP on 3.5" tubing installing heat trace and sentry guage. ND BOPE. 05/11/00 (D17) TD/TVD: 3755/3308 SUPV:FRED HERBERT MW: 0.0 VISC: 0 PV/YP: 0/ 0 0) RIG RELEASED F/ 2T-204 ~ 08:00 HRS. APIWL: 0.0 PJSM. NU tree and test to 250/5000, OK. Freeze protect with diesel. Rig released from 2T-204 ~ 0800 hrs. 5/11/00. Date: 06/22/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 REMEDIAL AND COMPLETION OPERATIONS WELL:2T-204WO RIG:NABORS 16E STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TABASCO BLOCK: SPUD:06/04/00 START COMP:06/04/00 FINAL: ---- WI: 0% SECURITY:0 API NUMBER: 50-103-20327-00 06/04/00 (C1) TD: 3755' PB: 3670' 06/05/00 (C2) TD: 3755' PB: 3670' 06/06/00 (C3) TD: 3755' PB: 3670' 06/07/00 (C4) TD: 3755' PB: 3670' N/D ESP EQUIPMENT MW: 0.0 SUPV:FRED HERBERT / SCOTT GOLDBERG Move rig from 2T-217A to 2T-204. Accept rig at 03:30 hrs. 6/4/00. Circulate well to 9.2 ppg KC1 brine. Monitor well, static. Set 2-way check valve. ND tree. NU BOPE and test to 250/3000 psi. Pull tubing hanger to floor. Circulate one hole volume. PJSM. Pull tubing. RUNNING ESP COMPLETION WI MW: 9.2 BRINE SUPV:FRED HERBERT / SCOTT GOLDBERG Continue pulling ESP assembly. New test plug leaked by into annulus. Install new test plug and test to 250/3000 psi. RIH with junk basket and 6.75" guage ring. Tag up at 1004' POOH. RIH with junk basket and 6.6" gauge ring. Tag up at 3384' work junk basket. POOH. Assemble ESP components. Megger power cable unsuccessfully. Repaired and meggered power cable successfully. PJSM. Continue running 3.5" tubing using Nova clamps. Start heat trace. Continue running ESP completion on 3.5" tubing. TESTING BOPE MW: 9.2 BRINE SUPV:FRED HERBERT / SCOTT GOLDBERG PJSM. Continue running in hole with ESP completion on 3.5" tubing. Megger all components successfully. N/D BOPE. N/U tree and test to 5000 psi. Make final megger test of ESP power cable, test failed. PJSM. N/D tree. N/U BOPE. RIG RELEASED MW: 0.0 SUPV:FRED HERBERT / SCOTT GOLDBERG Continue N/U BOPE. Re-install rams and tighten Hydril cap. Test BOPE. Pull tubing hanger to floor. Re-megger test equipment unsuccessfully. Re-splice new penetrator connector. Megger test all three cables successfully at rig floor. Set two way check. N/U tree and test to 250/3000 psi. Freeze protect well. secure well. Release rig ~ 2400 hrs. 6/7/00. North Slope Alaska Alaska State Plane 4 Kuparuk 2T 2T-204 Surveyed: 18 April, 2000 SURVEY REPORT 26 April, 2000 Your Reft A PI-501032032700 Surface Coordinates: 5970572.46 N, 498944.62 E (70° 19' 50.9979" N, 150° 00' 30.8168" W) Kelly Bushing: 114.80ft above Mean Sea Level 13 R I I.. L I I~11~ S e= IR V ! r- ,,~ ~, Survey Ref: svy9180 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 2T-204 Your Ref: API.501032032700 Surveyed: 18 April, 2000 0.00 0.000 0.000 -114.80 110.00 0.000 0,000 -4.80 194.62 5.180 76,760 79.70 290.00 10,960 74,190 174.10 398.73 13,930 76.490 280.26 488.66 16,770 78.820 366.98 575.77 20,550 80.940 449.50 655.98 23,800 82,210 523.76 750.49 26,170 83,920 609.42 838.63 28.120 85,200 687.85 930.49 28.620 90.780 768.69 1021.73 29.090 94.510 848.61 1116.57 . 29.090 99.790 931.50 1214.29 28.980 108.570 1016.98 1308.17 29.630 116.430 1098.88 1402.44 30,940 125.460 1180.32 1495.39 30.240 134.430 1260.38 1590.71 30.010 140.970 1342.85 1685.70 30.540 140.300 1424.88 1780.36 30,690 140.610 1506.35 1875.18 30.880 138.580 1587.81 1968.69 31,070 143.770 1668.00 2063.28 31.300 145.390 1748.92 2158.00 31,330 144.840 1829.84 2251.24 31.420 144.460 1909,45 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (,) (") (~) (~) (") 0.00 0.00 N 0.00 E 5970572.46 N 498944.62 E 110.00 0.00 N 0.00 E 5970572.46 N 498944.62 E 194.50 0.88 N 3.72 E 5970573.33 N 498948.34 E 288.90 4.33 N 16.65 E 5970576.79 N 498961.27 E 395.06 10.21N 39.32 E 5970582.66 N 498983.94 E 481.78 15.26 N 62.58 E 5970587.71 N 499007.20 E 564.30 20.10 N 90.02 E 5970592.55 N 499034.64 E 638.56 24.51N 119.96 E 5970596.96 N 499064.59 E 724.22 29.31 N 159.59 E 5970601.74 N 499104.21 E 802.65 33.10 N 199.62 E 5970605.53 N 499144.24 E 883.49 34.62 N 243.19 E 5970607.04 N 499187.82 E 963.41 32.57 N 287.16 E 5970604.99 N 499231.78 E 1046.30 26.84 N 332.87 E 5970599.25 N 499277.49 E 1131.78 15.26 N 378.74 E 5970587.66 N 499323.36 E 1213.68 2.32 S 421.10 E 5970570.08 N 499365.72 E 1295.12 26.77 S 461.73 E 5970545.63 N 499406.34 E 1375.18 57.03 S 497.92 E 5970515.36 N 499442.53 E 1457.65 92.36 S 530.08 E 5970480.02 N 499474.69 E 1539.68 129.38 S 560.46 E 5970443.00 N 499505.06 E 1621.15 166.56 S 591.15 E 5970405.82 N 499535.75 E 1702.61 203.51S 622.60 E 5970368.87 N 499567.20 E 1782.80 240.97 S 652.75 E 5970331.40 N 499597.33 E 1863.72 280.88 S 681.13 E 5970291.48 N 499625.71 E 1944.64 321.27 S 709.29 E 5970251.09 N 499653.86 E 2024.25 360.86 S 737.37 E 5970211.50 N 499681.94 E Dogleg Rate (°/lOOff) 0.000 6.121 6.070 2.769 3.231 4,408 4.095 2.621 2.309 2.936 2.039 2.706 4.359 4.153 5.022 4.964 3.451 0.662 0.230 1.114 2.863 0.920 0.303 0,233 Alaska State Plane 4 Kuparuk 2T Vertical Section (ft) Comment 0.00 0.00 2.38 10.38 24.55 39.68 58.22 79.00 107.14 136.22 169.49 2O5.27 244.71 287,90 332.04 379.08 426.24 473.37 520.15 567.27 614.85 661.72 708.73 755.84 802.42 Continued... DrillQuest 1.05.05 26 Apri~ 2000-11:23 -2- Sperry-Sun Drilling Services Survey Report for 2T-204 Your Ref: API-501032032700 Surveyed: 18 April, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 2346.01 31.490 144.090 1990.29 2105.09 401.01 S 766.25 E 2440.53 31.500 142.240 2070.89 2185.69 440.53 $ 795.85 E 2534.45 31.260 140.310 2151.07 2265.87 478.68 S 826.44 E 2633.37 30.950 140.040 2235.77 2350.57 517.92 S 859.16 E 2725.85 30.700 139.350 2315.19 2429.99 554.06 S 889.82 E 2817.83 31.450 146.250 2393.99 2508.79 591.84 S 918.45 E 2911.62 30.830 146.030 2474.27 2589.07 632.12 S 945.48 E 3003.52 30.860 145.470 2553.17 2667.97 671.07 S 971.99 E 3095,20 31.180 144.870 2631.74 2746.54 709.85 S 998.98 E 3191.26 30.980 142,880 2714.01 2828.81 749.90 S 1028.21 E 3289.51 30.770 141.610 2798.34 2913.14 789.76 $ 1059.08 E 3379.67 30.450 141.420 2875.94 2990.74 825.70 S 1087.65 E 3431.90 29.920 140.330 2921.08 3035.88 846.07 S 1104.21 E 3495.00 29.920 140.330 2975.77 3090.57 870.30 S 1124.31 E 5970171.34 N 499710,81 E 5970131.82 N 499740.41 E 5970093.67 N 499770.99 E 5970054.41 N 499803.71 E 5970018.27 N 499834.36 E 5969980.49 N 499862.99 E 5969940.21 N 499890.01 E 5969901.26 N 499916.52 E 5969862.47 N 499943.50 E 5969822.42 N 499972.72 E 5969782.55 N 500003.59 E 5969746.61 N 500032.15 E 5969726.24 N 500048.72 E 5969702.01 N 500068.80 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Sudace is 26.377° (16-Apr-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 128.270° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 3495.00ft., The Bottom Hole Displacement is 1421.79ft., in the Direction of 127.742° (True). Dogleg Rate (°/lOOff) 0.217 1.023 1.100 0.344 0.468 3.955 0.672 0.314 0.485 1.089 0.697 0.371 1.460 0.000 Alaska State Plane 4 Kuparuk 2T Vertical Section (ft) Comment 849.95 897.67 945.31 995.32 1041.77 1087.65 1133.81 1178.75 1223.96 1271,71 1320.63 1365.32 1390.95 1421.73 Projected Survey Continued... 26 April, 2000- 11:23 -3- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for 2T-204 Your Ref: API-501032032700 Surveyed: 18 April, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 2T Comments Measured Depth (ft) 3495.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3090.57 870.30 S 1124.31 E Comment Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 3495.00 3090.57 Survey Tool Description MWD Magnetic DrillQuest 1.05.05 26 April, 2000 - 11:23 - 4 - SURVEY CALCULATION AND FIELD WORKSHEET Job N.o, 0450-0OO23 Sidetrack No. ...... Pa~e .. I of. ..... 2. · ~ Com,c~ar~/ PHILUPS ALASKA, INC. Rig Contractor & No. Nabors - RIG 16E Field KUPARUK RIVER UNFT Well Name & No. PAD 2T/204 Survey Section Name Definitive Survey BHI Rep. L HENSLEY WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S 592.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 556.00 Magn. Declination 26.380 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m[~ 10m[~ Vert. Sec. Azim. 128.27 Magn. to Map Corr. 26.380 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length -I-VD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (ET) (DD) (DD) (FT') (FT) (F'I~ (FT) (Per lO0 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 16-APR-00 MWD 110.00 0.00 0.00 110.00 110.00 0.00 0.00 0.00 0.00 0.00 8' M 1C 1.7 DEG AKO 16-APR-00 MWD 194.62 5.18 76.76 84.62 194.50 2.38 0.88 3.72 6.12 6.12 0.00 16-APR-00 MWD 290.00 10.96 74.19 95.38 288.90 10.38 4.33 16.65 6.07 6.06 -2,69 17-APR-00 MWD 398.73 13.93 76.49 108.73 395.06 24.55 10.21 39.32 2.77 2.73 2.12 17-APR-O0 MWD 488.66 16.77 78.82 89.93 481.78 39.68 15.26 62.58 3.23 3.16 2.59 -- 17-APR-00 MWD 575.77 20.55 80.94 87.11 564.30 58.22 20.10 90.02 4.41 4.34 2.43 17-APR-00 MWD 655.98 23.80 82.21 80.21 638.56 79.00 24.51 119.96 4.10 4.05 1.58 17-APR-00 MWD 750.49 26.17 83.92 94.51 724.22 107.14 29.31 159.59 2.62 2.51 1.81 17-APR-00 MWD 838.63 28.12 85.20 88.14 802.65 136.22 33.10 199.62 2.31 2.21 1.45 17-APR-O0 MWD 930.49 28.62 90.78 91.86 883.49 169.49 34.62 243.19 2.94 0.54 6.07 17-APR-O0 MWD 1021.73 29.09 ,94.51 91.24 963.41 205.27 32.57 287.16 2.04 0.52 4.09 17-APR-00 MWD 1116.57 29.09 99.79 94.84 1046.30 244.71 26.84 332.87 2.71 0.00 5.57 17-AP R-00 MWD 1214.29 28.98 108.57 97.72 1131.78 287.90 15.26 378,74 4.36 -0.11 8.98 17-APR-O0 MWD 1308.17 29.63 116.43 93.88 1213.68 332.04 -2.32 421.10 4.15 0.69 8.37 17-AP R-O0 MWD 1402.40 30.94 125.46 94.23 1295.09 379.06 -26.76 461.71 5,02 1.39 9.58 17-AP R-00 MWD 1495.39 30.24 134.43 92.99 1375.18 426.24 -57.03 497.92 4.96 -0.75 9.65 17-AP R-O0 MWD 1590.71 30.01 140.97 95.32 1457,65 473.37 -92.36 530.08 3.45 -0.24 6.86 -- ~. ~ -'~-~'-~', ~ ~ ..... 17-AP R-00 MWD 1685,70 30,54 140,30 94199 1539.68 520.15 -129,39 560,46 0.66 0,56 -0,71 17-APR-O0 MWD 1780.36 30.69 140.61 94.66 1621.15 567.27 -166.56 591.15 0.23 0.16 0.33 __ ~'~ 17-APR-O0 MWD 1875.18 30.88 138.58 94.82 1702.61 614.85 -203.51 622.60 1.11 0.20 -2.14 -- 17-APR-00 MWD 1968,69 31,07 143,77 93.51 1782,80 661.72 -240,97 652,75 2.86 0.20 5.55 17-APR-O0 MWD 2063,28 31,30 145.39 94,59 1863,72 708,73 -280,89 681,13 0,92 0.24 1,71 _ 17-APR-00 MWD 2158,00 31,33 144.84 94.72 1944,64 755,84 -321,27 709,28 0,30 0.03 -0,58 " " SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00023 Sidetrack No. Page 2 of 2 Company PHILLIPS ALASKA, lNG. Rig Contractor & No. Nabors - RIG 16E Field K.U__PARUK RIVER UNIT Well Name & No. PAD 2T/204 Survey Section Name Definitive Survey BHI Rep. L HENSLEY i ~li~r~l~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S 592.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS[~ Target Description Target Coord. E/W Slot Coord. E/W 556.00 Magn. Declination 26.380 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: 100ft~ 30mE] 10m[~ Vert. Sec. Azim. 128.27 Magn. to Map Corr. 26.380 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (Fr) (FT) (FT) (FT) i(Per 100 ~ Drop (-) Left (-) 17-APR-00 MWD 2251.24 31.42 144.46 93.24 2024.25 802.42 -360.86 737.37 0.23 O. 10 -0.41 - 17-APR-00 MWD 2346.01 31.49 144.09 94.77 2105.09 849.95 -401.01 766.25 0.22 0.07 -0.39 17-APR-00 MWD 2440.53 31.50 142.24 94.52 2185.69 897.67 -440.53 795.85 1.02 0.01 -1.96 17-APR-00 MWD 2534.45 31.26 . 140.31 93.92 2265.87 945.31 -478.68 826.43 1.10 -0.26 -2.05 17-APR-00 MWD 2633.37 30.95 140.04 98.92 2350.57 995.32 -517.93 859.16 0.34 -0.31 -0.27 17-APR-O0 MWD 2725.85 30.70 139.35 92.48 2429.99 1041.77 -554.07 889.82 0.47 -0.27 -0.75 17-APR-00 MWD 2817.83 31.45 146.25 91.98 2508.79 1087.65 -591.84 918.45 3.96 0.82 7.50 18-APR-00 MWD 2911.62 30.83 146.03 93.79 2589.07 1133.81 -632.12 945.47 0.67 -0.66 -0.23 18-APR-00 MWD 3003.52 30.86 145.47 91.90 2667.97 1178.75 -671.07 971.99 0.31 0.03 -0.61 18-APR-00 MWD 3095.20 31.18 144.87 91.68 2746.54 1223.96 -709.85 998.98 0.49 0.35 -0.65 18-APR-O0 MWD 3191.26 30.98 142.88 96.06 2828.81 1271.71 -749.90 1028.21 1.09 -0.21 -2.07 18-APR-00 MWD 3289.51 30.77 141.61 98.25 2913.14 1320.63 -789.76 1059.08 0.70 -0.21 -1.29 18-APR-00 MWD 3379.67 30.45 141.42 90.16 2990.73 1365.32 -825.70 1087.64 0.37 -0.35 -0.21 ',.~- 18-APR-O0 MWD 3431.90 29.92 140.33 52.23 3035.88 1390.95 -846.07 1104.21 1.46 -1.01 -2.09 -- 04-APR-00 MWD 3537.66 31.61 140.15 105.76 3126.76 1443.87 -887.66 1138.81 1.60 1.60 -0.17 6-3/4' HOLE * ROTARY ASSEMBLY 04-APR-00 MWD 3630.69 33.28 140.84 93.03 3205.26 1492.64 -926.17 1170.56 1.84 1.80 0.74 04-APR-00 MWD 3713.67 34.49 141.01 82.98 3274.15 1537.78 -962.08 1199.72 1.46 1.46 0.20 04-APR-(X) MWD 3755.00 34.49 141.01 41.33 3308.21 1560.61 -980.27 1214.44 0.00 0.00 0.00 PROJECTED DATA - No Survey _ -- -- PH,_LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 July 27, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Well Completion Report for 2T-204 (200-016 / 300-072) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Well Completion Report for the drilling operations on 2T-204. If there are any questions, please contact me at 265-6830 or Tom Brockway at 263-4135. Sincerely, R. Thomas ~'/ {'~ Kuparuk Drilling Team Leader Phillips Drilling RT/TAB/skad Sch berger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 274 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 6/20/00 Field: Kuparuk Well Job # Log Description Date BL Sepia CD 2T-204 20197 PEX/HALS/DSI 000504 1 2T-204 20197 PEX-LATEROLOG RES-HALS 000504 I 1 2T-204 20197 PEX-TLD DENSITY/NEUTRON 000504 I 1 2T-204 20197 DSl 000504 I 1 2T-204 20197 CST 000504 I 1 2T-204 20197 PEX-TVD 000504 I 1 , SIGNED DATE: II II~! m'7 ~(~ Please sign and return one copy of this transmiffal to Sherrie at the above address or fax to (907) 561-8317. Thank ~ 0[I & Gas CO~s. ~o~SS~0D Anchorage 5~24~00 Sch mberger NO. 185 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1A-03 PRODUCTION PROFILE W/PSP 000517 I 1 1A-06 L~.! r,~ INJECTION PROFILE 000515 I 1 1D-04 ~ , LEAK DETECTION LOG 000513 I 1 1F-16 LEAK DETECTION LOG 000512 I 1 2M-04 C(/C INJECTION PROFILE 000516 I 1 3A-04 ~ INJECTION PROFILE 000514 I 1 2T-204 20196 DSl 000504 1 · r' ~%11'!% Sm. ED LA DATE: MAY 3 1 2000 Alask~ Oil & Gas Ca~s. ~;ommission Please sign and return onec~y of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Tl~a~n~/[oal~,B Re: 2T-204 Workover --. Subject: Re: 2T-204 Workover Date: Wed, 24 May 2000 15:05:16 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Thomas A Brockway <TBROCKW~ppco.com> CC: torn_matmder~admin.state.ak.us, Chip Alvord <CALVORD~ppco.com> Tom, You didn't give dates, but it appears reasonable that this is still part of the original completion covered by the Permit To Drill. As such, no 403 is needed. Sincerely, Blair Wondzell, 5/24/00. Thomas A Brockway wrote: Dear Blair, I have received word that the PCESP pump that we ran in the recent 2T-204 completion (APD # 200-016) failed to operate during the initial start-up attempt. Following this initial start-up effort several troubleshooting procedures were attempted, but with no success. The next most likely step will be a workover to pull the tubing and replace the PCESP motor unit. Since the well has never been produced, I was wondering if a 403 Sundry form will be required for this work or does it still fall under the scope of the original APD . Thanks, Tom Brockway Operations Drilling Engineer 263-4135 tbrockwSppco, com 1 of 1 5/24/00 3:27 PM 26-Apr-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2T-204 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: ProjeCted Survey: 'MD 'MD 3,495.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) RECEIVED APR 2_8 2000 Alaska Oil & 6as Cons. Cornmissio~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson, Chairman THRU: FROM: Blair Wondzell, P. I. Supervisor Tom Maunder, ~¢,~,,_ Petroleum Engineer DATE: April 17, 2000 FILE NO: Dvtrinsp. Nabors 16E.DOC SUBJECT: Diverter Inspection AAI KRU 2T-204 ("~p.~TD 200-16"~ April 16, 2000: I traveled to Nabors 16E to witness the Diverter function test on well 2T-204 in the Kuparuk River Field for Arco Alaska Inc. The AOGCC test report is attached for reference. All equipment was in place when I arrived. The controls were actuated and the diverter valve opened as the bag closed. In addition to the function test, an accumulator test was performed. 200 psi recovery was accomplished in 36 seconds with full charge achieved in just under 3 minutes. The rig gas detectors were being checked while I was at the rig and I witnessed the activation of the H2S and methane sensor at the driller's console. Both sensors activated their respective alarms. SUMMARY: I witnessed the successful Diverter function test on Nabors 16E and the activation of the driller's console H2S and methane gas detectors in KRU on well 2T-204 for AAI. No failures witnessed. Test time I hour. Attachments: Diverter N 16E 2T-204 4-16-2000TM cc; NON-CONFIDENTIAL Dvtrinsp Nabors 16E 4-16-2000 Drlg Contractor: Operator: Well Name: Location: Sec. .... STATE OF ALASKA ALASK,:,, OIL AND GAS CONSERVATION COMIC, Diverter Systems Inspection Report Nabors Arco Alaska Inc. 2T-204 T. 11N R. Operation: Development Rig No. 16E PTD # Oper. Rep.: Rig Rep.: 8E Merdian UM JION Date: April 16 2000 X Exploratory: 200-16 Rig Ph. # 659-7562 Fred Herbert Jimmy Greco ~ TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK Reserve Pit: N/A (Gen.) DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: Well Sign: Drlg. Rig: Flare Pit: 20 Yes Yes 16 90' N/A Yes Yes N/A OK OK N/A in. in. ACCUMULATOR SYSTEM: Systems Pressure: PreSsure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 2900 psig 1800 psig min. 36 sec. 2 min. 50 sec. 6 @ 1900 MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: GAS DETECTORS: Methane Hydrogen Sulfide: Light Alarm N/A N/A OK OK N/A N/A Light Alarm OK OK OK OK psig DIVERTER SCHEMATIC 20" .ann 1 6" Knife vlv 16" X~ Nabors Rig 16E Fuel Tank CPM Non Compliance Items Remarks: Repair Items Within Day (s) And contact the Inspector @ 659-3607 Distribution orig, - Well File c - Oper/Rep c - Database c - Trip. R~ot,~File Ft-02z I~ev. 7/93 c - Inspector AOGCC REP.: Diverter N 16E 2T-204 4-16-2000 TM.xts OPERATOR REP.: Tom Maunder Fred Herbert ~Re: Tabasco 2T-204 and 2T-218 Procedure Changesl- Subject: Date: From: Organization: To: CC: Re: Tabasco 2T-204 and 2T-218 Procedure Changes Tue, 04 Apr 2000 09:22:08 -0800 Blair Wondzell <blair_wondzell~admin. state.ak.us> State of Alaska, Dept of Admin, Oil & Gas Thomas A Brockway <TBROCKW~mail.aai.arco.com> Chip Alvord <CALVORD~mail.aai.arco.com>, Thomas W Mc Kay <TMCKAY~mail.aai.arco.com>, "Randy L. Thomas" <RLTHOMAS@mail.aai.arco.com> --or(:, 2T-204 PTD 200-016 and 2T-218 PTD 200-018 Tom, I read this e-mail and to my question, you said that when you top-set and leave 204 and go to 218, the shoe will not be drilled out in 204, and like-wise, when you top-set and leave 218, the shoe in 218 will not be drilled out. This e-mail should be sufficient notification and approval for this change to both drilling programs. Sincerely, Blair Wondzell, 4/4/00. Thomas A Brockway wrote: Blair, As I mentioned on the phone this morning, I was wondering about a change in the proposed drill and complete procedures which have been submitted for the upcoming Tabasco wells 2T-204 and 2T-218. The rig that is scheduled to drill these wells, Nabors 16E, is currently +/- 17 days ahead of schedule on it's current project and these wells have been accelerated to the point that completion equipment will not arrive on the slope before the rig will need it. In order to prevent having to shut down the rig to wait on completion equipment I would like to do the following: 1) Drill and case the surface hole on 2T-204, topsetting the Tabasco production interval as per plan 2) Suspend 2T-204 and move to 2T-218 3) Drill and case surface hole on 2T-218; drill intermediate hole; run and cement intermediate liner string topsetting the Tabasco production interval as per plan 4) Suspend 2T-218 and move back to 2T-204 5) Drill out and complete 2T-204 as per plan 6) Move to 2T-218 7) Drill out and complete 2T-218 as per plan No other drilling or completion procedures will change from the original submitted APD's and Nabors 16E will still be used to drill and complete the wells as per the original permits and sundries. Could you please let me know if I will need to fill out any 403 Sundry forms to reflect these scheduling changes or will this e-mail suffice in this case. Thanks for the help. 1 of 2 4/4/00 9:43 AM North Slope Alaska Alaska State Plane 4 Kuparuk 2T 2T-204 Surveyed: 18 April, 2000 SURVEY REPORT 26 April, 2000 ORIGINAL Your Ref: API-501032032700 Surface Coordinates: 5970572.46 N, 498944.62 E (70° 19' 50.9979" N, 150° 00' 30.8168" W) Kelly Bushing: 114.80ft above Mean Sea Level RECEIVED APR 28 2000 Alaska 0il & Gas Cons. Commission Anchorage DRILLINI~ SERVICES SurveyRef:svy9180 Sperry-Sun Drilling Services Survey Report for 2T-204 Your Ref: API-501032032700 Surveyed: 18 April, 2000 North Slope Alaska Measured Depth Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 0.00 0.000 0.000 -114.80 0.00 110.00 0.000 0.000 -4.80 110.00 194.62 5.180 76.760 79.70 194.50 290.00 10.960 74.190 174.10 288.90 398.73 13.930 76.490 280.26 395.06 488.66 16.770 78.820 366.98 481.78 575.77 20.550 80.940 449.50 564.30 655.98 23.800 82.210 523.76 638.56 750.49 26.170 83.920 609.42 724.22 838.63 28.120 85.200 687.85 802.65 930.49 28.620 90.780 768.69 883.49 1021.73 29.090 94.510 848.61 963.41 1116.57 29.090 99.790 931.50 1046.30 1214.29 28.980 108.570 1016.98 1131.78 1308.17 29.630 116.430 1098.88 1213.68 1402.44 30.940 125.460 1180.32 1295.12 1495.39 30.240 134.430 1260.38 1375.18 1590.71 30.010 140.970 1342.85 1457.65 1685.70 30.540 140.300 1424.88 1539.68 1780.36 30.690 140.610 1506.35 1621.15 1875.18 30.880 138.580 1587.81 1702.61 1968.69 31.070 143.770 1668.00 1782.80 2063.28 31.300 145.390 1748.92 1863.72 2158.00 31.330 144.840 1829.84 1944.64 2251.24 31.420 144.460 1909.45 2024.25 Alaska State Plane 4 Kuparuk 2T Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (fi) (°/lOOff) (ft) 0.00 N 0.00 E 5970572.46 N 498944.62 E 0.00 0.00 N 0.00 E 5970572.46 N 498944.62 E 0.000 0.00 0.88 N 3.72 E 5970573.33 N 498948.34 E 6.121 2.38 4.33 N 16.65 E 5970576.79 N 498961.27 E 6.070 10.38 10.21 N 39,32 E 5970582.66 N 498983.94 E 2.769 24.55 15.26 N 62.58 E 5970587,71 N 499007.20 E 3.231 39.68 20.10 N 90.02 E 5970592.55 N 499034.64 E 4.408 58.22 24,51 N 119.96 E 5970596.96 N 499064.59 E 4.095 79.00 29.31 N 159.59 E 5970601.74 N 499104.21 E 2.621 107.14 33,10 N 199.62 E 5970605.53 N 499144,24 E 2.309 136.22 34.62 N 243.19 E 5970607.04 N 499187.82 E 2.936 169.49 32.57 N 287.16 E 5970604,99 N 499231.78 E 2.039 205.27 26.84 N 332.87 E 5970599.25 N 499277.49 E 2.706 244.71 15.26 N 378.74 E 5970587.66 N 499323.36 E 4.359 287.90 2.32 S 421.10 E 5970570.08 N 499365.72 E 4.153 332.04 26.77 S 461.73 E 5970545.63 N 499406.34 E 5.022 379.08 57.03 S 497.92 E 5970515.36 N 499442.53 E 4.964 426.24 92,36 S 530.08 E 5970480.02 N 499474.69 E 3.451 473.37 129.38 S 560.46 E 5970443,00 N 499505.06 E 0.662 520.15 166.56 S 591,15 E 5970405.82 N 499535.75 E 0.230 567.27 203,51 S ~ 622.60 E 5970368.87 N 499567.20 E 1.114 614,85 240.97 S 652.75 E 5970331.40 N 499597.33 E 2.863 661.72 280.88 S 681.13 E 5970291.48 N 499625.71 E 0.920 708.73 321,27 S 709.29 E 5970251.09 N 499653.86 E 0.303 755.84 360.86 S 737.37 E 5970211.50 N 499681.94 E 0.233 802.42 Comment RECEIVED APR 2 8 000 Continued... 26 April, 2000 - 11:23 -2- Alaska 0il & Gas Cons. Anchorage DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for 2T-204 Your Ref: API-501032032700 Surveyed: 18 April, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 2T Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Dogleg Vertical Rate Section (°/~OOft) (ft) Comment 2346.Ol 31.49o 144.09o 1990.29 2105.o9 401.01 S 766.25 E 2440.53 31.500 142,240 2070.89 2185.69 440.53 S 795.85 E 2534.45 31.260 140.310 2151,07 2265.87 478.68 S 826.44 E 2633.37 30.950 140.040 2235,77 2350.57 517.92 S 859.16 E 2725.85 30.700 139.350 2315.19 2429.99 554.06 S 889.82 E 2817.83 31.450 146.250 2393.99 2508.79 591.84 S 918.45 E 2911.62 30.830 146.030 2474.27 2589.07 632.12 S 945.48 E 3003.52 30.860 145.470 2553.17 2667.97 671.07 S 971.99 E 3095.20 31.180 144.870 2631.74 2746.54 709.85 S 998.98 E 3191.26 30.980 142.880 2714.01 2828.81 749.90 S 1028.21 E 3289.51 30.770 141.610 2798.34 2913.14 789.76 S 1059.08 E 3379.67 30.450 141.420 2875.94 2990.74 825.70 S 1087.65 E 3431.90 29.920 140,330 2921.08 3035.88 846.07 S 1104.21 E 3495.00 29.920 140.330 2975.77 3090.57 870.30 S 1124.31 E 5970171.34 N 499710.81 E 5970131.82 N 499740.41 E 5970093.67 N 499770.99 E 5970054.41 N 499803,71 E 5970018.27 N 499834.36 E 5969980.49 N 499862.99 E 5969940.21N 499890.01E 5969901.26 N 499916.52 E 5969862.47 N 499943.50 E 5969822.42 N 499972.72 E 5969782.55 N 500003.59 E 5969746.61N 500032.15 E 5969726.24 N 500048.72 E 5969702.01N 500068.80 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 0.217 849.95 1.023 897.67 1.100 945.31 0.344 995.32 0.468 1041.77 3.955 1087.65 0.672 1133.81 0.314 1178.75 0.485 1223.96 1.089 1271.71 0.697 1320.63 0.371 1365.32 1.460 1390.95 0.000 1421.73 Projected Survey Magnetic Declination at Surface is 26.377° (16-Apr-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 128.270° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 3495.00ft., The Bottom Hole Displacement is 1421.79ft., in the Direction of 127.742° (True). RECEIVED 26 April, 2000 - 11:23 - 3 - / PR 28 &laska 0il & Gas Cons. Anchorage Continued,,. DrillQuest 1.05,05 Sperry-Sun Drilling Services Survey Report for 2T-204 Your Ref: API-501032032700 Surveyed: 18 April, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 2T Comments Measured Depth (ft) 3495.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3090.57 870.30 S 1124.31 E Comment Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 3495.00 3090.57 Survey Tool Description MWD Magnetic RECEIVED APR 2 8 2000 26 April, 2000 - 11:23 - 4 - DrillQuest 1.05.05 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other Change of Rig 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 592' FSL, 556' FWL, Sec. 1, T11 N, RSE, UM At top of productive interval 281' FNL, 1661' FWL, Sec. 12, T11 N, RSE, UM At effective depth At total depth 366' FNL, 1737' FWL, Sec. 12, T11N, R8E, UM 5. Type of Well: Development ~X Exploratory __ Stratigraphic _ Service _ 6. Datum elevation (DF or KB feet) RKB 110 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-204 9. Permit number/approval number 200-016 10. APl number 50-103-20327 11. Field / Pool Kuparuk River Field/Tabasco Oil Pool 12. Present well condition summary Total depth: measu red true vertical Effective depth: Casing Conductor Surface measured true vertical Length Production Liner Size feet feet feet feet Cemented Plugs (measured) Junk (measured) Measured Depth True vertical Depth Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) RECEIVED MAR 2! 1 2000 Oi[ & Gas,Cons. Commissl.on Anchora~to 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __X 15. Status of well classification as: 14. Estimated date for commencing operation April 10, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __ Service Gas__ Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~- IV'~~~~'''~'~ Title: Drilling Team Leader Paul Mazzolini FOR COMMISSION USE ONLY Questions? Call Tom Brockway 263-4135 Date Prepared b~/ Sharon AIIsup-Drake 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 ORIGINAL SIGNED, BY Robert N. Chdstenson Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Diverter Schematic Nabors 16E Flowline 21 lA" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 21 lA" 2,000 psi WP DRILLING SPOOL w/16" Outlet 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. Nabors #16E 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE 1 w/hydraulic actuator / J / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE ~J _ __ ~i~/ hydraulic actuat°r ~ CHOKE LINE 13-5/8" 5,000 psi WP DRILLING SPOOL L-!'~'~ w/two 3" 5M ~si WP outlets I I SINGLE 13-5/8" 5,000 psi WP, - HYDRIL MPL BOP w/pipe rams Drilling Fluids System - Nabors Ri.q 16E 3 - Derrick Shale Shakers Desander Desilter Mud Cleaner Centrifuge Degasser Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor Fluid Agitators 1 TAB, 03/17/00, vl ARCO Alaska, Inc. AAI Drilling Post Office Box 100360 Anchorage, Alaska 99510 March 20, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Revision of Application for Permit to Drill Permit # 200-016 Kuparuk River Unit 2T-204 Tabasco Producer, Tabasco Oil Pool Dear Sirs: ARCO Alaska, Inc. hereby requests a revision of permit #200-016 referencing Tabasco well 2T- 204 located in the Kuparuk River Unit. Due to rig scheduling issues, ARCO proposes to drill and complete this well using Nabors Rig 16E rather than Nordic Rig 3 as stated in the original permit application. No changes from the oriqinal permit application are planned in the drill and complete procedure, fluid program, casing program, or directional profile. Please find attached a listing of the Nabors 16E Drilling Fluids System and schematics detailing the diverter and BOP systems which Nabors 16E will use on this well. Please note that the revised anticipated spud date for this well is April 10, 2000. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Paul Mazzolini at (907) 263-4603. Sincer~?~ _ Thomas A. Brockway Operations Drilling Engl~eer Attachments: cc: KRU 2T-204 Well File Paul Mazzolini ATO-1066 Tom Mckay ATO-1060 Jack Walker ATO-1148 Larry Gipson ATO-1146 Lewis Ledlow ATO-1063 RECEIVED IAR 2 1 2000 & Gas Con~. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COI~MISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONEi (907) 279-1433 FAX: (907) 276-7542 Paul Mazzolini Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2T-204 ARCO Alaska, Inc. Permit No: 200-016 Sur Loc: 592'FSL, 556'FWL, Sec. l, TI 1N, R8E, UM Btmhole Loc. 366'FNL, 1737'FWL, Sec. 12; T11N, R8E, UM Dear Mr. Mazzolini' 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 determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 2T-204. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus ora well approved for annular disposal on Drill Site 2T must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space ora single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice :nay be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sinc fy, / Chair BY ORDER OF THE.~0MMISSION DATED this ~ ~ ~='~ day of February, ;~000 dlf/15nclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork: Drill r~l Redrill D I ,~.Type ofwell. Exploratory D StratigraphicTest D Development Oil r~l Re-entry D Deepen DJ Service D Development Gas D Single Zone [~] Multiple Zone D 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 110 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25569 ALK 2667 Tabasco Oil Pool (proposed) 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 592' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 281' FNL, 1661' FWL, Sec. 12, T11N, R8E, UM 2T-204 #U-630610 At total depth 9. Approximate spud date Amount 366' FNL, 1737' FWL, Sec. 12, T11N, R8E, UM March 1, 2000 $200,000 12. Distance to nearest property line J 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 281' @ Target feetJ 2T-31 20.4' @ 623' feet 2560 3703' MD / 3269 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 200' MD Maximum hole angle 32.65 Maximum surface 1711 psig At total depth (TVD) 2054 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 10' 110' 110' 120' 120' ± 200 CF 9.875" 7.625" 29.7# L-80 BTCM 3341' 110' 110' 3451' 3056' 296 sx AS III, 402 sx Class G & Open Hole Gravel Pack 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feetORIGINAL Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production RECEIVED Liner FE,3 09 2000 Perforation depth: measured Naska 0il & Gas Cons. C0flliflissJ~il true vertical Anchorage 20. Attachments Filing fee r~ Property Plat E] BOP Sketch r~ Diverter Sketch [] Drilling program r'~ Drilling fluid program r~ Time vs depth plot DReffaction analysis D Seabed report E] 20 AAC 25.050 requirements [~] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Tom Brockway 263-413~ Signed Title: Drilling Team Leader Date Paul Mazzolini Pr~n~r~d bv 5~haron AIl.¢un-r)r~k~ Commission Use Onl~ Permit Number APl number ~ Approval date/) JSee cover letter ~'~-~/~ ~0-/O~'""'~'~27"'-'t_~ ¢'~,'"~f''~')~ Jfor other requirements Conditions of approval Samples required E] Yes ~ No Mud Icg required E] Yes ~ No Hydrogen sulfidemeasures E] Yes N~ .No Directional surveyrequired ,~ Yes E] No Required working pressure for BOPE E~2M;~3M; D SM; D 1OM;F1 Other: ORIGINAL SIGNED. BY by order of '3 . f~¢.., i 'J Approved by Robert NJ Chdstenson Commissioner the commission Date :¢-~ ~' ,.'2~ ~ C ~ Form 10-401 Rev. 12/1/85 · Submit in triplicate ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510 February 7, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: Tabasco 2T-204 592' FSL, 556' FWL, Sec 1, T11N, R8E, UM 281' FNL, 1661' FWL, Sec. 12, T11N, R8E, UM 366' FNL, 1737' FWL, Sec. 12, T11N, R8E, UM Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well to the prospective Tabasco interval from 2T Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the Tabasco sands in the vicinity of 2T pad. The well is designated as a producer and is planned to penetrate the Tabasco sands using a 7- 5/8" surface casing string and an open hole gravel pack completion technique for sand control purposes. The well will be drilled and completed using Nordic Rig 3. Completion plans call for running a 3-1/2" production tubing string with a wireline retrievable progressive cavity ESP and heat trace. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 8) 9) 10) 11) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f). Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: A) B) Completion Report (20 AAC 25.070) Geologic Data and Logs (20 AAC 25.071) Sharon AIIsup-Drake, Drilling Technologist 263-4612 Steve Moothart, Geologist 265-6965 Please note that the anticipated spud date for this well is March 1, 2000 If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Paul Mazzolini at (907) 263-4603. Sincerel. v,¢~ ~ / mas A. Brockway /'"'/ Operations Drilling Engine~ Attachments: CC: KRU 2T-204 Well File Paul Mazzolini ATO-1066 Jack Walker ATO-1148 Larry Gipson ATO-1146 Lewis Ledlow ATO-1063 GENERAL DRILL AND COMPLETE PROCEDURE TABASCO PRODUCER 2T-204 General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up Nordic Rig 3. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to 7-5/8" surface casing point (+/3451 MD') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 7-5/8" 29.7# L-80 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with mud. Note: TAM Port Collar will be placed in the 7-5/8" casing 1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results. 6. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 7. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 8. Drill 6-3/4" hole to well total depth (+/- 3703') according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH. 9. Run open hole wireline logs as needed. 10. RIH with underreamer assembly and open hole to +/- 8-1/2". POOH 11. RIH with clean out BHA. Scrape casing. Displace well to completion brine. 12. Pump caustic wash. Pump pickle job. Circulate brine. 13. Pump acid pill across formation. Reverse out with brine. POOH 14. Run in hole with 4" Gravel Pack screen assembly. Set gravel pack packer. 15. Pressure test lines. Pump gravel pack sand and pack screens. 16. Reverse out excess sand. Circulate well to non-freezing, clean completion brine. POOH 17. RIH with ESP assembly on 3-1/2" 9.3# L-80 BTCM production tubing with power cable and data gathering information wire attached to tubing. 18. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost. 19. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. Make surface electrical connections as required. 20. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up horizontal production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 2T-204 Page I TAB, 02/07/00, v.1 21. Freeze protect well. Make final conductivity check of ESP cable and instrumentation wire. Set BPV. Release rig and turn well over to production. 2T-204 Page 2 TAB, 02/07/00, v. 1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Tabasco 2T-204 Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 7-5/8" surface casin¢ 8.5-9.6 16-26 25-50 150-250* 10-20 10-30 8-15 8-10 4-6% Drill out to TD 9.1 4-7 15-30 60-120 2-4 4-8 8-15 8.0-8.5 4-7% Drilling Fluid System - Nordic Riq 3 Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 200-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using an expected surface casing leak-off of 12.9 ppg EMW (0.67 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1711 psi. The leak off EMW was chosen based on an open hole LOT on 2T-215 taken to 12.9 ppg at 3084' TVD (0.67 psi/ft). Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3056 ft)(0.67-0.11) = 1711 psi Based on offset well data, reservoir pressures in the Tabasco sands in the vicinity of 2T pad are expected to be 1250 psi (0.41 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 8.7 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 3090'. Well Proximity Risks: The nearest existing well to 2T-204 is 2T-31. As designed, the minimum distance between the two wells would be 20.4' at 623' MD. Drillin,q Area Risks: Risks in the 2T-204 drilling area are limited to lost circulation, potential borehole instability, and below normal pressures in the Tabasco formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous DS 2T drilling results, 9.6 ppg mud should be adequate to control both the West Sak and Tabasco formation pressures without resulting in lost circulation. The 7-5/8" casing shoe will be tested to leak off or a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well on 2T Pad. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-204 3-1/2" x 7-5/8" tubing annulus will be filled with kill weight brine and diesel after setting the 3-1/2" production tubing string and prior to the drilling rig moving off of the well. TabasCo 2T,204 cer Proposed Completion Schematic Open Hole Gravel Pack @ 120' MD TAM 7-5/8" Port Collar Stnd. Grade BTC Threads (+/- 1000' MD / 967' TVD) Depths are based on Nordic 3 RKB Suflace csg. 7 5/8" 29.7# L-80 BTCM (+/- 3451' MD / 3056' TVD) Open Hole G~avel Pack TD < 40' below Tabasco base (< 3703' MD / 3269' TVD) ARCO Alaska, I nc; 3~1/2" Vetco-Gray Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod Pup Joint, ESP Power Cable Penetrator, He~t Trace Penetrator and TEC Wire Per~et[at0r, 3-1/2" 9.3# L-80 EUE 8rd Mod Spaceout Pups as Required for Heat Trace. Raychem Heat Trace @ +/- 3000' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to Surface 3-1/2" x 1" Camco 'KBMM' GLM run oper~ 6' handling pups installed on top and bottom, After the rig moves off location, the wells group will install a Shear Circulating Valve (pinned for 3000 psi Tbg / Csg differential) 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 1 Joint 3-1/2" 93# L~80 EUE 8rd Mod Tubing Baker Sentry BHP Gauge (attached to 2nd 10' Pup Joint above the Slotted Nipple). 10' Spaceout Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 10' Handling Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing Centrilift ESPCP (components as listed below) w/bottom set @+/- 3221' MD (total length = 70.3') Centrilift 3-t/2" Slo(ted Nipple Centrilitt TTC Crossover Centrilift Tandem Seal Section: GST3 4B IL H6 PSF Centdlift PC Pump and Flex Shaft Assembly: Tubing Deployed, +/- 43.5' Centrilift Gear Reduction Unit: 525 Series, 9:1 Centrilift Motor: 57 HP KMH 1315/26 Centrilift Motor Centralizer Baker Gravel Pack Assembly (run on drillpipe) Baker Model SC*I Gravel Pack packer, 7-5/8% set @ +F 3301' 4 its, Baker 4" blank tubing, Hunting Seal Lock threads Baker plastic flapper valve Baker 4" Gravel Pack screen, Hunting Seal Lock, 20 gauge (0,02") screen Open Hole Gravel Pack using 12-20 US mesh gravel pack sand TAB, 2/4/00, vl IARC0 Alaska, Inc. Structure : Pad 2T Well : 204 / Field: Kuparuk River Unit Location : North Slope, Alas 180 0 180 360 540 720 900 1080 1260 =,i=- (D 1440 1620 1800 I--- 1980 I V 2160 2340 2520 2700 2880 5060 3240 East (feet) -> 1 O0 0 1 O0 200 300 400 500 600 700 800 900 1000 11 O0 1200 I I I I I I I I I I I I I I I I I I I I I I I I I I I rr~L Lvw,Ec2fJMIA~Fr'?TION: I 100 SUR Estimated RKB Elevation: 110' ~ ...... .. 592' FSL, 556' FWL I)0 &~ ~eg[n rnm I~lo/mrn SEC. 1, T11N, R8~E J KOP ~e Build~ EOC 5 O0 ~x. Bose Permafrost ' Begin Angle Build 8.00 ~p Ugnu 12.00 16.00 DLS: 4.00 deg per 100 ft ~,~ 20.00-- ~ 24.00 Begin ~nl Bid/Tm ~2;:.041 %Top W Sok% 24.72 DLS: 4.00 deg per 100 fl: 'k~ 31.21 EOC ~l'ZlE(~CosePermafrost ~ lop ugnu Top Tabasco ! ~ Target - Tabasco ~ Bose Tabascok TANGENT ANGL ,ooo 3~.65 DEG ~, TD LOCATION: ~ 366' FNL, 1737' F~L ~. [ SEC. 12, T11N, RSE J op W Sok ~ 128.27 AZIMUTH ~ Bo. WSo~ 1520' (TO TD) ***Plane of Proposal*** 7 5/8 Cosing Target - Tabasco P'~'X Top Tabasco \ ~ B°ST~T°b°sc° 5420 , I [ [ I I [ ] I [ [ I ! ] ] I [ [ | ] ] 180 0 180 560 540 720 900 1080 1260 1440 1620 VerticalSection (feet)-> Azimuth 128.27 with reference 0.00 N, 0.00 E from slot #204 0 1 O0 2OO 3oo 0 4OO 500 I ~oo 700 BO0 900 c~t~ ~/nn~ For: T Brockway Dele plotl~cl: 5-Feb-~ ~l~s ~ In f~t mfe~ s~t ~2~. Creoted by finch FO:I': T Brook-way Dote plotted: 5-reb-2000 Plot Reference ~a 204 Vets;on Coordinates are ;n few reference slot ~204. Vert;c;l Depl;hs are reference Est. RKB(Nord;c 3). INT~Q ARCO Alaska, Inc. Sfructure: Pad 2T Well : 204 Field : Kuporuk River Unlf Loootlon : North Slope, Alosko PROFILE COMMENT DATA KOP Point MD Inc 200.00 0.00 Dir TVD North Eost 80.00 200.00 0.00 0.00 V. Sect Deg/ ) 0.00 0.00 Begin Angle Build Begin Fnl BId/Trn EOC 333.33 858.33 1557.60 4.00 80.00 333.23 0.81 4.58 3.10 3.00 25.00 80.00 838.66 23.51 133.31 90.10 4.00 32.65 138.22 1462.38 -95.85 410.00 380.00 4.00 Base Permafrost 1566.66 32.65 138.22 1470.00 -97.47 413.25 384.81 0.00 Top Ugnu 1772.11 52.65 158.22 1 645.00 - 180.12 487.09 493.97 Top W Sak 2469.24 32.65 138.22 2230.00 -460.57 737.63 864.37 0.00 O.oO Base W Sak 3006.05 32.65 1 58.22 2682.00 -676.52 950.55 11 49.59 7 5/8 Casing 3450.59 32.65 138.22 5056.52 -855.56 1090.32 1585.79 Top Tabasco 3490.59 32.65 1 38.22 3090.00 -871.45 1104.69 1407.04 Target - Tabasco Base Tabasco 3491.77 32.65 138.22 3090.99 -871.92 1105.12 1407.67 3603.42 32.65 138.22 3185.00 -91 6.84 1145.24 1466.99 0.00 0.00 0.00 0.00 0.00 TD 3703.42 32.65 138.22 3269.21 -957.07 1181.18 1520.12 0.00 Crmated by t~nch For: T Brockway Date plotted: 3-Fab-2000 Plot R~for~n~ tm 204 Version ~15. Caord~nate9 are rn f~ r~erence ~ ~2~. True Vertical Depths are r~emnce E~. RKB(Nordfc ~). ARCO Alaska, Inc. Structure: Pad 2T Well: 204 Field: Kuparuk River Unit Looation : North Slope, Alaska 8O 6O 4O 6O 40 20 0 20 40 I 100 500 1000 20 1300' 700 600 ~ ~00 20 11 ee 4o 0 60 ~ ~,~ \ ~2oo600 b % \ oo X h 700 ~oo ~ooX 5,00 ~oo ~ooh ~ 500~900 2000 140 300 ~ 8O0 1 ~ 700 ~ 60 800 ~300 1900 180 000 200 / 60 40 20 0 20 40 6O 700 1 O0 60 8O 1500 East (feet) -> 100 120 140 150 180 200 220 I I I I I I I I 1000 900 240 260 I I I I 1200 1 ,:7,00 1400 1500 1500 ~ 900 ~ 800 1400 600 '" ~__.~1700 1000 ~ ~ ~ .~ 1800'" \ "'-- ~..1100 1900 \ \ 2000 \ \ 2100k\ 2200 200 3400 3300 1300 1200 3000 ~1 oo 80 1 O0 120 140 160 180 200 220 240 260 East (feet) -> 280 300 ~20 I I I I I I 120~' 5500 500 2300 2400 x % 2500 \ \ 2600 N, 280 1600 900 2700 \ % 2800 340 360 I I I I \ 2900 \ \ 3000 \ \ 3100 \ \x32oo \ ~ 33oo i ! 520 340 580 80 60 40 20 0 20 40 '~ 120 , , , 200 560 580 0 c' Cr~tod ~ *~.ch For: T Brockway Dote plotted: 5-Fob-2000 Plot Reference ;- C=ord;nates are ~n fe~ r~emnce True Ve~;c;I Depths ore rMerence EM. RKB(Nordrc ~), Zh'T~Q ARCO Alaska, Inc. Structure: Pad 2T Well: 204 Field: Kuporuk River Unit Loooflon : North Slope, Alasko 40 0 4O 80 120 160 200 240 V 280 320 360 40O 440 480 East (feet) -> 240 280 320 360 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 10BO I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1800 \ \ 2200 \ ~_~_5_0_0 /' ~. ~ 300 -~ N ~6oo ' ~. 2700 / ,-j;oo ', / k "oo , o / ~ ~ooo / % 5100 /~oo X~2oo / .... X~O %1¢00 ~ 2900 / , ~~ 2~oo 2400 X 6 2300 X 1900 \ \ \ \ 2000 % \ X \ 2100 \ \ \ \ % 2200 X X i i i i I i i i I i i I i i i I I i i i i i I i i i i t i i i I i i i i i i i i i i i 240 280 320 360 400 440 4BO 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 East (feet) -> 40 40 BO 120 160 ~ o C 2OO 240 ~ 280 ~, 52O 360 400 440 480 Cr~3ted by t;nch For: T Brook-way D~t.e plotted: 5-F'eb-2000 Plot Reference i-, 204 Verm~an ~115. Coord[nates are ;n feat raference slot True Ver~;¢al Deaths are reference Est. RKB(Nord;c 3). ARCO Alaska, Inc. Sfrucfure: Pad 2T Well : 204 Field : Kuparuk River Unlt Looaflon : North Slope, Alaska 200 500 400 East (feet) -> 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 100 ~..~1 I I I I I I I I I I I I I I I I I I I I I I t I I I I I I I I I I I I I I I I I I 100 200 500 400 500 6OO -i,,,. ~ 700 · 4-- 800 0 90O I V 1000 1100 1200 1500 1400 2300 \ \ 2500 2500 270O 1500 4500 1500 2900 3100 1700 4700 4900 2500 \ \ \ X 2700 \ \ \ 2900 \ \ \\,51 O0 \ \ 3500 ~-~5269 3500 3700 1900 3900 4100 500 600 0 700 800 900 1 O0 200 300 400 500 600 700 800 900 1000 11 O0 1200 1300 1400 1500 1600 1700 1800 1900 2000 21 O0 2200 2300 East (feet) -> 1200 1300 1400 1100 1000 ARCO Alaska, Inc. Pad 2T 204 slot #204 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 204 Version #15 Our ref : prop3057 License : Date printed : 3-Feb-2000 Date created : 15-Ju1-1998 Last revised : 3-Feb-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.172,w150 0 47.034 Slot location is n70 19 50.994,w150 0 30.801 Slot Grid coordinates are N 5970572.076, E 498945.178 Slot local coordinates are 592.00 N 556.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <4135-4496'>,,207,Pad 2T PMSS <0-4082' Depth Shifted NIII>,,209,Pad 2T PMSS <4022-4690'>,,209DO,Pad 2T PMSS <469-10632'>,,18,Pad 2T PMSS <0-9845'>,,19,Pad 2T PGMS <0-8250'>,,lO,Pad 2T PMSS <4410-4967'>,,215DO,Pad 2T PMSS <5041-5752>,,220DO,Pad 2T MSS <4046-4427'>,,202,Pad 2T PMSS <0-4749'>,,30 PMSS <4627 - 10686'>, PGMS <0-6370'> PGMS <0-6975'> PGMS <0-8208'> PGMS <0-7670'> PGMS <0-8160'> PGMS <0-8445'>, PGMS <0-7868'>, PGMS <0-6789'>, PMSS <3115 - 3645 ,,9 ,7 ,6 ,5 ,4 17 13 11 Pad 2T 30A,Pad 2T Pad 2T Pad 2T Pad 2T Pad 2T Pad 2T Pad 2T Pad 2T Pad 2T 12,Pad 2T PGMS <O-6725'>,,12B,Pad 2T PMSS <4757-6800'>,,12A,Pad 2T PMSS <1287-1725'>,,2,Pad 2T PGMS <0-8890'>,,2A,Pad 2T PMSS <0-10570'>,,29,Pad 2T PMSS <380 - 11400'>,,31,Pad 2T PGMS <O-7650'>,,8,Pad 2T Closest approach with 3-D Minimum Distance Last revised Distance M.D. Diverging 6-Apr-1999 6-Apr-1999 6-Apr-1999 21-0ct-1998 23-Jan-1998 23-~an-1998 6-Apr-1999 5-Apr-1999 26-Aug-1998 16-~u1-1998 16-~u1-1998 23-Jan-1998 23-Jan-1998 23-~an-1998 23-~an-1998 23-~an-1998 23-~an-1998 23-Jan-1998 23-~an-1998 23-~an-1998 23-~an-1998 23-Jan-1998 26-Aug-1998 26-Aug-1998 23-2an-1998 23-~an-1998 23-~an-1998 method 38 0 61 2 61 2 627 9 644 9 440 0 136 6 199 3 143 6 52 2 52 2 364 9 315 0 145 6 264 4 239 7 614 9 189 6 465 0 489 3 489 3 489 3 190 0 190 0 7O 0 2O 4 340 0 8O 0 463 3 463 3 300 0 222 2 100 0 433 3 266 7 493 3 363 3 363 3 180 0 O0 1480 0 244 4 233 3 140.0 3703 4 O0 277 8 277 8 277 8 O0 O0 100 0 623 3 O0 from M.D. 80.0 463.3 463.3 300.0 222.2 100.0 433.3 266.7 493.3 363.3 363.3 180.0 0.0 1480.0 244.4 233.3 1680.0 3703.4 1580.0 1620.0 1620.0 1620.0 463.3 463.3 100.0 623.3 0.0 PMSS <5917-7957'>,,16A,~ 2T PGMS <0-8947'>,,16B,Pad 2T PMSS <1604-3625'>,,16,Pad 2T PGMS <0-7625'>,,15,Pad 2T PGMS <0-8262'>,,14,Pad 2T PMSS <650 - 11080'>,,37,Pad 2T PMSS <921-10235'>,,20,Pad 2T PMSS <0-12821'>,,21,Pad 2T PMSS <0 - 9210'>,,26,Pad 2T PMSS <741-15471'>,,36,Pad 2T PMSS <918 - 10193'>,,22,Pad 2T PMSS <0-4175'>,,201,Pad 2T PGMS <0-7897'>,,3,Pad 2T PMSS <893 - 12977'>,,23,Pad 2T PMSS <918' - 10890'>,,28,Pad 2T PMSS <0-5340'>,,210,Pad 2T PMSS <0-9298'>,,27,Pad 2T PMSS <853-4995'>,,220,Pad 2T PMSS <0-2140'>,,220PB1,Pad 2T PMSS <1664-4645'>,,220PB2,Pad 2T PMSS <12144-13360'>,,38A,Pad 2T PMSS <0-5924'>,,32,Pad 2T PMSS <4850 - 5918'>,,32A,Pad 2T PMSS <5497-13787'>,,32B,Pad 2T 23-Jan- 23-Jan- 23-Jan- 23-Jan- 23-2an- 23-2an- 23-2an- 23-Jan- 23-2an- 23-2an- 23-2an- 26-Aug- 26-Aug- 25-Aug- 23-Jan- 4-Dec- 23-2an- 3-Feb- 3-Feb- 3-Feb- 23-2an- 24-Feb- 24-Feb- 24-Feb- 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1999 1999 1999 1998 1998 1998 1998 590.0 590.0 590.0 565.0 539.1 686.9 261.2 674.9 115.0 577.0 175.0 352.5 214.9 160.0 85.0 70.9 99.9 199.3 199.3 199.3 527.0 25.0 25.0 25.0 0.0 0.0 0.0 0.0 255.6 443.3 1800.0 180.0 200.0 100.0 100.0 100.0 211.1 100.0 200.0 443.3 233.3 266.7 266.7 266.7 100.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 255.6 443.3 1800.0 180.0 200.0 100.0 100.0 100.0 211.1 100.0 200.0 443.3 233.3 266.7 266.7 266.7 100.0 0.0 0.0 0.0 Port Collar Cementinq Practices · We will run a TAM Port Collar (see below for running details). · Circulate with casing on bottom at 10 bpm or greater if possible without losing returns. Equipment for the stage job consists of: · TAM Port collar · TAM Combo tool · TAM Choke Ensure that all connections are compatible or that there are appropriate crossovers available. If needed, TAM personnel can be available on site to check the equipment and confirm shear pin settings with prior notice. Run and cement with the Port Collar as follows: I. Check that all materials are at the rig site · 7 5/8" TAM Combo Tool, with 3-1/2" EUE Box by Pin and 7 5/8" 29.7 ppf Packer Cups · 7 5/8" TAM Port Collar with 7 5/8" BTCM Box x Pin Connections · Choke Sub with 3-1/2" EUE Box by Pin, pinned with 5 pins for 2225 psi shear. Uses 1.25 setting ball · All appropriate crossovers II. Ensure that all connections are compatible or there are appropriate crossovers available III. Pick up and run 7 5/8" 29.7 ppf casing with Port Collar placed at 1000' TVD. Note: If packing off problems were seen around this depth when drilling or tripping, consult with the Drilling Engineer. · Install centralizers in the center of the joints above and below the port collar. IV. Pump first stage of cement job (spacer, lead and tail) as specified in Drilling Plan. Pump until the plug bumps and pressure up to 500 psi above circulating pressure to insure the plug has landed. If floats do not hold, maintain 1500 psi on casing for a minimum of 4 hours before rechecking. V. If cement is not returned to surface, a top job or use of the port collar will be required. The Arco company representative should review the attached decision tree is order to determine which method should be used. · Do top job using 1" tubing if good lead slurry cement did not circulate to surface. Run 1" tubing and tag top of previous cement job. If tubing does not tag, run it as deep as possible and contact the Arco drilling engineer or engineer on call to discuss options. Circulate while RIH to keep tubing from packing off. Flush annulus with water, then circulate annulus to cement. · AOGCC and Arco drilling engineer (or engineer on call) must be contacted prior to beginning top job, Do not proceed with top job without AOGCC approval. VI. If the Arco company representative determines that it is necessary to use the Port Collar, run in the hole with the 4" drillpipe until the Combo Tool dogs engage the profile in the Port Collar. Workstring should be run in hole as quickly as possible to reduce chances of cement setting up. Port Collar Practices 1 TAB, 02/07/00, v.1 · In order to trip in with the 4" drillpipe and open the Port Collar, it is necessary to land the casing in the hanger as planned. Landing the casing above the hanger, and thus off the rig floor, would create a situation where the Port Collar could not be used. · Laying down the landing joint prior to using the Port Collar is preferred, as opposed to rigging up a false rotary table, which could take a couple of hours. In the meantime, cement could be setting up above or adjacent to the Port Collar. VII. Drop 1.25" setting ball and circulate to seat. Pressure up on workstring to 1000 psi to test Combo Tool. Bleed off workstring pressure VIII.Open Port Collar by bumping down on workstring with 10,000 to 15,000 lbs. IX. Establish circulation rate and pressure X. Cement casing as required to ensure visual confirmation that cement is at the surface · Slightly overdisplace the cement job so no cement remains in the workstring or casing Xl. While holding pressure on workstring, bump up with 10,000 to 15,000 lbs. to close Port Collar XlI. Pressure up on workstring to confirm collar is closed Xlll.With workstring at neutral, slowly pick up while rotating to the right to release from the Port Collar XlV. Run in 1 joint of tubing. Pressure up on workstring to 2225 psi to expel the ball choke in Choke Sub XV. Reverse out excess cement as required XVI. Pull out of hole with tools Port Collar Practices 2 TAB, 02/07/00, v.1 Kuparuk River Unit Operat,ons TAM Port Collar Utilization Decision Tree Cement above Port Collar (1000' TVD)/ Perform Top ,Job as per requirements of AOGCC Nipple Up and Test BOP's Continue with Completion Begin Primary OneI Stage Cement Job / No Cement / to Surface / Cement below Port Collar (1000' TVD)/ If Top Job is ineffective or unacceptable to AOGCC Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Nipple Up and Test BOP's Cement to Surface Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Continue with Completion Greater Kuparuk Area Leak-Off Test Standard Draft 4 There are several reasons for performing the Leak Off Test at the surface casing shoe, to determine maximum mud weights and maximum allowable shut in pressures are two of these reasons. In the Greater Kuparuk Area it has been decided that the LOT at the shoe would not exceed a 16 ppg EMW. This 16 ppg EMW allows the wells to be permitted through AOGCC for annular injection and exceeds any known required mud weights to control the reservoir pressure. In some cases the AOGCC may require an additional LOT that goes to break down. Check the well plan or with the AAI drilling engineer assigned to the rig to determine if a second test is required and if so, how much additional hole needs to be drilled prior to performing the test. If a second test is required to satisfy the AOGCC do not exceed the 16 ppg EMW at the shoe prior to consulting the AAI Drilling Engineer assigned to the rig. Contact the project Team Leader if the Engineer can't be reached. Previous tests above 16 ppg EMW at the shoe have damaged the casing cement job. Leak-Off Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. The upper limit of the test will not exceed 16 ppg EMW at the casing shoe without prior consent from the AAI Drilling Engineer assigned to the rig. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 2. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 3. Pull bit into casing shoe and close the annular preventer or pipe rams. 4. Determine the surface pressure required to obtain 16 ppg EMW at the shoe with the weight of mud in use. 5. The AOGCC requires this test to be charted. Make sure chart recorder is working and ready. Send chart to the AAI Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the formation breaks down or the 16 ppg EMW is reached. Do not exceed 16 ppg EMW. If the well breaks down prior to reaching the 16 ppg EMW continue pumping an additional three bbls of mud prior to shutting down the pumps, to satisfy AOGCC requirements. Record the breakdown pressure and record the bleed off pressures at one minute intervals for a minimum of 10 minutes. The AOGCC suggests that a good test will have a stabilized pressure for 10 minutes (this may be incorporated into the new regulations). If pressures have not stabilized after holding the test for 15 minutes total, check for surface leaks. If surface leaks are discovered repair them and do the test over. 7. Bleed back mud from the well and compare with volume pumped on the test. o Contact the AAI Drilling Engineer assigned to the rig if the LOT is below the minimum outlined in the well plan, prior to drilling ahead. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 9. Plot the casing and leak-off tests on the most current excel spreadsheet and fbrward to thc off icc. RLM 7/31/98 Greater Kuparuk Area Formation Integrity Test Standard Draft 4 Some wells do not need to go to full leak-off. In those cases, a Formation Integrity Test will be performed. For instance, if it is known that the Kuparuk formation will be top set, a Formation Integrity Test is all that is necessary. Consult with the AAI Drilling Engineer assigned to the rig if it is unclear whether you need to do a Leak-Off Test or a Formation Integrity Test. Formation Integrity Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. 1. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 2. Pull bit into casing shoe and close the annular preventer or pipe rams. 3. Determine the surface pressure required to obtain the desired EMW at the shoe. 4. This test needs to be charted. Make sure the chart recorder is working and ready. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. 5. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the desired surface pressure is reached. Record the initial shut in pressure and record the pressure at one minute intervals for a minimum of 10 minutes. If pressure is bleeding off check for surface leaks. If surface leaks are discovered repair them and do the test over. 6. Bleed mud back from the well and compare with volume pumped on the test. 7. Contact the AAI Drilling Engineer assigned to the rig if the well breaks down before reaching the desired EMW, prior to drilling ahead. Contact the Drilling Team Leader if the Engineer can't be reached. 8. Plot the casing and formation integrity tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 16" DI~,-:RTER SCHEMATIC- ordic Rig 3 Kuparuk River Unit Operations J 3 Open ! Closed ," ~ ~_ _ Closed __..~ · To Accumulator I I~- .... From Accumulator Open Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 16" Diverter Spool with APl 21-1/4" 2000 psi Flanges 5. 21-1/4" Schaefer 2000 psi Annular Preventer 6. 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 7. 16" Diverter Line TAB, 07/19/99, v2 11" 50 '9 psi BOP Stack-- Nord- ic Rig 3 Kuparuk River Unit Tabasco Operations - Producer Wells ¼ 7 Kill Line ~ ~ Choke Line ~ 4 Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and alt valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Double Flange Adapter/Spacer Spool 4. 11" 5000 psi Hydril Type V Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ manual locks 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 6. 11" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 7. 11" 5000 psi Hydril Annular Preventer TAB, 09/30/98, v.1 2'1'-210 Ammlar Disposal Subject: 2T-210 Annular Disposal Date: Tue, 15 Feb 2000 11'14:01 -1000 From: "Thomas A Brockway" <TBROCKW,¢)mail.aai.arco.com> To: blair_wondzel l~admin.state.ak, us CC' tom_maunder@admin, state.ak, us, x~ endy_mahan ~Qadmin. state, ak. us Blair, After our conversation this morning, I went back and took a closer look at the well records from Tabasco injector well 2T-210. At this time it does not look like this well is a viable candidate for annular disposal on 2T Pad due to the topset of the surface casing immediately above the Tabasco formation. Consequently, as we discussed this morning, all incidental fluids developed from drilling operations on well 2T-204 will be hauled to the nearest permitted disposal well as there are currently no open disposal annuli available on 2T Pad. If you have any further comments or questions, please do not hesitate to give me a call. Thanks, Thomas A. Brockway Operations Drilling Engineer 263-4135 PAY' .... TO THE ORDER OF: . STATE OF ALASKA ALASKA:'.:'O:IL & GAS',i:CONSERYATION COMM! 300i PORCUPINE DRIVE :0997'58:7 · 'i The Firs~ National Bank of Chicago-0710 Chicago, Illinois Payable Through Republic Bank Shelbyvi lie; Kentucky. TRACE NUMBER: 230102432 ll'P~Oi, OPh~,p,' ~-'O~.~,c3oh2r=;~.' 0 ~ ti? 5,°, ?,' . 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. ~.~ (O, O~ 13. i~NGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. ,. 23. 24. 25. F/; DATE 26. '::z/to"~:~ 2?'. 28. 29. GEOLOGY 30. 31. 32. .~ DATE 33. 2,, ,/O .~2:) 34. . ANNULAR DISPOSAL 35. APPR DATE serv __ wellbore seg ann. disposal para req __ Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15~day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diveder required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ~.-)~_4~_~.___psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H~S gas probable ................. Permit can be issued w/o hydrogen sulfide measures ..... (~N Data presented on potential overpressure zones ...... Seismic analysis of shallow gas zones ............ .._,~?:A/ Y N Seabed condition survey (if off-shore) ............./I,//-/ Y N Contact name/phone for weekly progress repods [exploratory only/~ N .................................................... With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not conlaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMM~ ,PCr. WM H DWJ .JA ' JDH RNC SFD,/~ ~_ Comments/Instructions: 0 z 0 -.~ · . z c:\msoffice\wordian\diana\checklist (rev. 09/27/99) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. .o Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Sep 12 06:31:40 2000 Reel Header Service name ............. LISTPE Date ..................... 00/09/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ........ 2 .... LISTPE Date ..................... 00/09/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KuparukRiver Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 2T-204 501032032700 PHILLIPS Alaska, Sperry Sun 25-AUG-00 MWD RUN 1 MWD RUN 2 AK-MM-00022 AK-MM-00022 N. HERNANDEZ T. MCGUIRE FRED HERBERT FRED HERBERT 1 liN R8E 592 556 .00 Inc. RECEIVED SEP l 2000 Gas Cons. oomrmssion Anchorage DERRICK FLOOR: 114.80 GROUND LEVEL: 80.20 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 7.625 3493.0 6.750 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ~_RE DIRECTIONAL WITH DUAL GAMMk~ RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE PHASE 4 RESISTIVITY (EWR4) . 3.~ GAMMA RAY LOGGED BEHIND CASING FROM 3459' MD, 3059' TVD TO 3493' MD, 3089' TVD. 4. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE REFERENCE GR LOG (SCHLUMBERGER GR OF 5/5/00) WITH KBE = 114.8' A.M.S.L.. AFTER SHIFTING TO REFERENCE GR, MWD BECOMES PDC. ALL MWD HEADER DATA RETAINS ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUN 1 AND 2 REPRESENT WELL 2T-204 WITH, API #50-103-20327-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 3755'MD, 3308'TVD. SROP = SMOOTHED RATE OF pENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH SGRC 109.0 3725 0 SEDP 109.0 3732 0 SEMP 109.0 3732 0 SESP 109.0 3732 0 SEXP 109.0 3732 0 SROP 109.5 3751 5 SFXE 109.5 3732 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 109 0 3478 5 3509 5 3517 5 3519 5 3525 0 3533 5 3551 5 3559 5 3565.0 3570.0 3574.5 3577.0 3579 5 3584 5 3587 0 3610 0 3615 5 3619 5 3627 5 3635 0 3642 5 3659 0 3664 5 3667 5 3674 5 3711 0 3716 0 3719 5 3722 0 GR 112.0 3481.5 3512.5 3520.0 3522.5 3527.5 3536.0 3556 0 3563 5 3569 0 3573 5 3577 5 3581 0 3585 5 3588.5 3590 5 3614 0 3619 0 3623 5 3631 0 3639 5 3646.5 3662 5 3668 5 3671 5 3677 0 3715 0 3718 0 3721.0 3725.5 EQUIVALENT UNSHIFTED DEPTH -- 3751.5 3755.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 112.0 3495.0 3495.5 3755.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum sPecification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 FET MWD HRS 4 1 68 24 7 GR MWD API 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 109 3751.5 1930.25 7286 ROP MWD FT/H 4.5 4909.09 292.902 7285 RPX MWD OHMM 1.2 1302.15 37.1312 7247 RPS MWD OHMM 1.45 2000 75.0757 7247 RPM MWD OHMM 1.06 2000 134.645 7247 RPD MWD OHMM 1.85 2000 196.112 7247 FET MWD HRS 0.05 382.57 4.82354 7246 GR MWD API 10.01 137.21 72.0482 7233 First Reading 109 109.5 109 109 109 109 109.5 109 Last Reading 3751.5 3751.5 3732 3732 3732 3732 3732 3725 First Reading For Entire File .......... 109 Last Reading For Entire File ........... 3751.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 112.0 3452.0 RPM 112.0 3452.0 RPX 112.0 3452.0 GR 112.0 3459.5 RPD 112.0 3452.0 FET 112.5 3452.0 ROP 112.5 3495.0 $ LOG HEADER DATA DATE LOGGED: 18-APR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 65.41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 3495.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 5.2 MAXIMUM ANGLE: 31.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA TOOL NUMBER PB01486HRG6 PB01486HRG6 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 9.875 3493.0 Spud 9.60 155.0 9.0 40O 9.6 4.000 2.590 4.000 3.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HRS 4 1 68 28 8 63.0 101.0 63.0 63.0 Name Service Unit Min Max Mean Nsam DEPT FT 112 3495 1803.5 6767 ROP MWD010 FT/H 4.5 4909.09 311.618 6766 GR MWD010 API 10.01 134.63 69.8426 6696 RPX MWD010 OHMM 2.13 500.81 39.1647 6681 First Reading 112 112.5 112 112 Last Reading 3495 3495 3459.5 3452 RPS MWD010 OHMM 2.38 2000 RPM MWD010 OHMM 2.64 2000 RPD MWD010 OHMM 2.1 2000 FET MWD010 HRS 0.05 3.67 79.4184 136.979 195.46 0.413171 6681 6681 6681 6680 112 112 112 112.5 3452 3452 3452 3452 First Reading For Entire File .......... 112 Last Reading For Entire File ........... 3495 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 3452.5 3735.5 RPD 3452.5 3735.5 RPM 3452.5 3735.5 RPS 3452.5 3735.5 RPX 3452.5 3735.5 GR 3460.0 3728.5 ROP 3495.5 3755.0 $ LOG HEADER DATA DATE LOGGED: 04-MAY-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 4.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPER3tTURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 3755.0 31.6 34.5 TOOL NUMBER PBO1414GR4 PBO1414GR4 6.750 Baradrill-N 9.20 45.0 8.5 26000 9.4 .130 .110 .100 .198 62.0 74.4 62.0 62.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HRS 4 1 68 8 12 16 20 24 28 Name Service Unit Min Max DEPT FT 3452.5 3755 ROP MWD020 FT/H 5.14 140.34 GR MWD020 API 44.18 137.21 RPX MWD020 OHMM 1.2 1302.15 RPS MWD020 OHMM 1.45 1795.97 RPM MWD020 OHMM 1.06 2000 RPD MWD020 OHMM 1.85 2000 FET MWD020 HRS 0.31 382.57 Mean 3603.75 48.9753 99.5168 13.098 23.785 106.922 203.48 56.7748 First Nsam Reading 606 3452.5 520 3495.5 538 3460 567 3452.5 567 3452.5 567 3452.5 567 3452.5 567 3452.5 Last Reading 3755 3755 3728 5 3735 5 3735 5 3735 5 3735 5 3735 5 First Reading For Entire File .......... 3452.5 Last Reading For Entire File ........... 3755 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/09/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/09/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
