The URL can be used to link to this page

Home My WebLink About197-132MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-32 KUPARUK RIV UNIT 1E-32 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1E-32 50-029-22788-00-00 197-132-0 G SPT 5879 1971320 1500 2874 2879 2877 2881 310 420 420 420 4YRTST P Austin McLeod 6/4/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1E-32 Inspection Date: Tubing OA Packer Depth 780 2000 1970 1970IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220605184848 BBL Pumped:1.4 BBL Returned:1.4 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:30:15 -08'00' MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 12,2018 TO: Jim Regg ` P.I.Supervisor Kett (PI'S(I 6 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1E-32 FROM: Adam Earl KUPARUK RIV UNIT 1E-32 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-32 API Well Number 50-029-22788-00-00 Inspector Name: Adam Earl Permit Number: 197-132-0 Inspection Date: 6/10/2018 Insp Num: mitAGE180611090751 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IE-32 Type Inj G 'TVD 5879 Tubing 2355 2350 . 2345- 2345 PTD 1971320 Type Test SPT Test psi 1500 IA 250 1805 - 1775 - 1770 - BBL Pumped: 2.5 'BBL Returned: 2 OA 120 - 150 150 - 150 - Interval 4YRTST P/F P Notes: MIT-IA SCOW UJ 1 Page 1 of 1 Tuesday,June 12,2018 • 110 110 Nov- ConocoPhillips RECEIVED Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 OCT 19 2017 AOGCC October 15, 2017 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 SAWED t b 1 %i;6 Anchorage, AK 99501 Commissioner Hollis French: 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 cement if needed and 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Mouser or Roger Winter at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor - • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 10/7/2016 1B-11, 1E-32, 1G-01 &1R-16 Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 1B-11 50029206570000 181-136-0 12" NA 12" NA 3.4 10/14/2017 p1E-32 50029227880000 197-132-0 7' 0.5 8" 7/16/2017 2 9/20/2017 1G-01 50029208050000 182-130-0 14'7" 2.50 13" 7/16/2017 3.4 9/20/2017 1R-16 50029213880000 185-153-0 22" 0.25 7.5" 7/17/2017 4.2 9/10/2017 STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ rti----Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Re-enter Susp Well❑ SC repair 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska,Inc. Development ❑ Exploratory❑ 197-132 3.Address: Stratigraphic ❑ Service El 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-22788-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025660 KRU 1 E-32 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10445 feet Plugs measured NA feet true vertical 6273 feet Junk measured NA feet Effective Depth measured 10443 feet Packer measured 9819 feet true vertical 6272 feet true vertical 5884 feet Casing Length Size MD TVD Burst Collapse Structural NA NA NA NA NA NA Conductor Surface 5975 9 5/8 6616 3969 NA NA Intermediate Production 9957 7 9996 5986 NA NA Liner RECEIVED Perforation depth Measured depth 10165-10302 feet MAY 172017 True Vertical depth 6093-6181 feet AOGCIC Tubing(size,grade,measured and true vertical depth) 3 1/2,L80,MD 9818,TVD _ No SSSV Nipple-Camco DS Landing Nipple W/2.812 No Go,MD 533,TVD 532 Packers and SSSV(type,measured and true vertical depth) Seal Assy-Baker GBH-22 Seal Assembly W/15'of seals,MD 9819,TVD 5884 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA - -('‘,17 ►CANNE 1 -,. 1 -- Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-581 Authorized Name: Roger Winter Contact Name: Roger Winter/Roger Mouser Authorized Title: WI Fie d Supervis Contact Email: N19270,conocophillips.com l. Authorized Signature: / Date: ✓ ( Contact Phone: 659-7506 VTL 4/1117-- RBDMS L ' MAY 1 7 20177 Form 10-404 Revised 4/2017 /d ‘77 /7 Submit Original Only r • • INV ConocoPhillips RECEIVED Alaska MAY 17 2017 P.O. BOX G C ANCHORAGEGE,,ALASKA 99510-0360 May 16, 2017 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find the 10-404 for surface casing repair on well 1E-32, PTD 197-132, Sundry 316-581. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincer ly, :my Roger Winter ConocoPhillips Well Integrity Field Supervisor Enclosures: Summary of work 10-404 Pictures of damage and repair • • • SUMMARY 12/14/2016 Remove conductor and locate hole 70" below OA. 5/10/2017 Prep surface casing for repair. 5/14/2017 Repair surface casing w/6' 9.5"X 12", 65#, .500 pipe. 5/15/2017 SCIT w/N2 to 1000 psi (no external leaks), Stateman Lou Laubenstein witness. m w , a a ,' r ., ' ;it y- `S.,g•` .r X41,- j7• .. L .":;- * ; .I _; • ... - t � ." -''' .. 4. t j i k � r m f ,; :77-7.- m.m5c 1{ „4,'-‘,,,,.-‘,,, ��r 4� #: _ m a , , , �� \ l � I 4 'k .•1) 4: —' ' ' I '— �� 1 411 t - • E o6 ' iiir _ c 1. 4474" 1 / iii, ..,,,,. ,...;;;;;,„ ..-e-'............"'"',-...."-' '-';'. ..'-'" ' *'' ''I'rl'i''''''''''''''I '..,::: '' 1 e. 8 FIt , a 1, j ..!'' O�. \-.. ,_ 4 �, %' ! , + § :s� . r =s : i 0 A._, . ti .,,., ',/,,„i„,f, ,, ,,: 3...Ni...a.,,„1,,..--z.,,,Ay- R .,:;:„ '''''..:.'i. iik'..:„,i-t-- ',...,.-,,.4,:,,,,..,:.:?!::i:l..„„t4ii..k t . er . , p�g Y§ i Y1 .?...1 ♦ '� ��. � ,qy; l� ."°•,0& Y k 4YR < e 4 . '*'._ a i *1117,,+,,,;;. w • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggqAtf�I l(7DATE: 5/15/17 P. I. Supervisor FROM: Lou Laubenstein SUBJECT: Surface Casing Repair Petroleum Inspector KRU 1E-32 CPAI PTD 1971320 — 5/15/17: Performed a visual inspection of the repair of the surface casing on well 1E-32 in the Kuparuk River Unit. Took pictures of the repair and had a discussion with the company representative that oversaw the operation. The repair looks to have been done correctly. All welds where continuous with no gaps. The work area and surrounding area was clean and in good order. Took pictures of the completed repair(attached). Attachments: 5 Photos Non-Confidential SCANNED i. 3 471117 2017-0515_Surface_Casing_Repair_KRU_1 E-32_11.docx 1 of 4 • • iiii 1,1111 11 - .. . , . . . ..... . . .. .,... , , 11 , ..,..,,, , ,. • , . . .,,-. „,..ti . . .,... , .. . . , .. . , ,.. .. . . ,.....„..... 7 ___, ..„,,_ , . ._ . . • 5 1 r t.- .,,,,_ jjj 0a r..... t°» 1 , . ` S ,1 r ; 1 T / ,1 ',"�°} N ilt7a Y A o o . b 1 R_ M Cal CU "Tr Al/ = , P4 LI. • Illir k w :,: F .4.1?,rv.. : i • en f' ON Ii 1s'Vis t . M . � a i „/)im $moi •• :S” >, l c:11CI \ '''''')'' '-''''' Q !C Ate' VrA GO O O • s, i w it 0 S` • II ''.4 5� ' '�,,'�7+;yib arillieS ' '�"'�,Q=om... It, ' £ }: Y rt .h2}k �.' d. -.."LEE*`. 1 +. .,-,,,o; ;C� '.,•,4.' hye * r LDx ' *. Oil .' , :•.•'-. . ��" „)7,.. .. s. t 14� ' 1 ems” '�: i - ��. 4 , ms' s.,..' r-•fi S` 1 r f Y ,I , ';''''.. r ,r ,,,* t p 0,1 a o �, J �. '',''',....1 *, r {1cctI i s J l '1r,rq iF :!! �,, e‘''''' i r U 4. • ,b i .''' ' . fl'! � t : o t .q.�s •4/ . y }}. N � I 4 Y £ es��l" �I'�E.u,�. �i"`*. j¢ 1 x,7 ,: t .r i�. ‘4,*(,..,, ry rpr� kf.r ,. N: •'i ''a�b '',.4 VI' '<it.•i';',.-.7... C ''',';ft;?.-i'',:''.'"' . .• .' ''''.';(:4:',Fit4rk l'e.,'.-4,„-ta. 4,..1,4,;tt .,..,,...-,..,,', . , , r:alp' ss7 t 110 4110 x U O b --'I N M W I crl N , + q,^. CZ ,o ril ect I cu U VD I WI CD . ,,,,," ',' ''.,,,,i.k. 4. O 474,,,kb tiiliklit'"— ,. ,' .. ..*:,,, ' ''''', lt. ''' ''''',"- -,-.4. ‘‘. - :'''' ' 1-,- .4 ..;•''''''' ' - A •Vp �p.{. � '''.71-7*''** � �.,3..�. ' tT4'�` rt. .4:: ifk lT� ,11;'':.-1. g itrt Y.t J �4 ' t.- ;•...4,•-,.•r '.4* i ts ii, a v, ^ '1 • ' 0 , Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, December 25, 2016 6:05 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of surface casing damage to 1E-32 (PTD 197-132, sundry#316-581) 12-25-16 Attachments: 1E-32 surface casing damage.JPG Chris Yesterday,while attempting to install an external surface casing patch to repair a known SC leak 3' below the OA valve, damage to the surface casing occurred. Although there was no release of fluids,significant plastic deformation occurred to the pipe while preheating the area in anticipation of welding the patch. An investigation into the cause is currently being pursued. At this point it is suspected that a short occurred in the heating element which caused the temperature to exceed safety limits. The well is secured with a downhole tubing plug and T/I/O's are all at 0 psi. We will be working to establish a path forward on this well. This repair work was being performed under sundry#316-581,which was approved on 11/15/16. Attached is a picture of the well. Kelly Lyons/Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224 Mobile Phone (907)943-0170 SCANNED MAY 2 3201'1 M1 V OF D .rpt--��yy,��9 THE STATE• Alaska Oil and Gas OfA Conservation COmm1SS1®n l �T . L�� 333 West Seventh Avenue - _ Anchorage, Alaska 99501-3572 *011\ GOVERNOR BILL WALKER g ._�'- Main: 907.279.1433 OFA n.eio- Fax: 907.276.7542 www.aogcc.alaska.gov Aaron Applehans Y A NSK Well Integrity Field Supervisor scAtiNED ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 1E-32 Permit to Drill Number: 197-132 Sundry Number: 316-581 Dear Mr. Applehans: 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, '<() Daniel T. Seamount,Jr. Commissioner DATED this I) day of November, 2016. RBDMS LL- NOV 1 6 2016 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 0 9 Z016 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 t 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Plug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: SC Repair 1 ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc.• Exploratory r Development r 197-132 • 3.Address: Stratigraphic r Service f� 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-22788-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA c Will planned perforations require spacing exception? Yes r No F.7 I KRU 1E-32 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025660 " Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): . 10445 • 6273 ' 10443' • 6272' 3850 NA NA Casing Length Size MD TVD Burst Collapse SURFACE 5975 9 5/8 6016' 3969' PRODUCTION 9957 7 9996' 5986' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10165-10302' • 6093'-6181' 3.5 L-80 9819 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NO SSSV NIPPLE-CAMCO DS LANDING NIPPLE w/2.812 NO GO MD=533 TVD=532 SEAL ASSY-BAKER GBH-22 SEAL ASSEMBLY W/15'OF SEALS MD=9819 TVD=5884 • 12.Attachments: Proposal Summary WellBore Schematic r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14.Estimated Date for 15. Well Status after proposed work: 11/30/16 OIL r WINJ r WDSFt r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG FT. , GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true Contact: Aaron Applehans/Roger Winter Printed Name Aaron Applehans Phone:659-7506 Email: n1927Aconocophillips.com Title: NSK Well Integrity Field Supervisor Signature t/��//�� 41.44re......_ Date://_7-(6 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \ \ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: ,* /�h fZ, O ex ..t � •.+, d. -' .SV r`c› -c-2 I V aRBDMS L c- NOV 1 6 1016 Post Initial Injection MIT Req'd? Yes r No r N--;c r t, 1, in., Spacing Exception Require.? Yes r No r✓ Subsequent Form Required: /b ._zi 0 ii i1 Approved/byAPPROVED BY ( I e: COMMISSIONER THE COMMISSION Date: ! //S/ 1, /'a Il itfi - /4/6. i t• /( (0:9(t.'‘ Submit Form and Form 10-403 Revised 11/2015 0 Rr}6i4JAsL r 12 months from the date of approval.' Attachments in Duplicate • RECEIVED _, ConocoPhillips NOV 0 9 2016 Alaska P.O. BOX 100360 G` 'C ANCHORAGE,ALASKA 99510-0360 November 5, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1E-32, PTD 197-132 surface casing inspection and repair. Please contact Roger Winter or me at 659-7506 if you have any questions. Sincerely, z/eit / Aaron Applehans ConocoPhillips Well Integrity Field Supervisor • ConocoPhillips Alaska,Inc. Kuparuk Well 1E-32 (PTD 197-132) SUNDRY NOTICE 10-403 APPROVAL REQUEST November 5, 2016 This application for Sundry approval for Kuparuk well 1E-32 is for the inspection and repair of a surface casing leak. During the course of performing an MITOA this well developed a surface casing leak and was subsequently reported to your office on Oct 15,2016. ConocoPhillips requests approval to inspect and repair the surface casing. / With approval,inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with a plug(s)and/or BPV. 2. Remove the floor grate,well house, flow lines,and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and build—9' cellar or excavate to less than 20' if necessary. 4. Install nitrogen purge equipment for the conductor(and OA if necessary)so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary.Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. L.__ 8. Perform MITOA. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s)and/or BPV and return the well to production. 13. File 10-404 with the AOGCC post repair. Well Integrity Project Supervisor 11/7/2016 I y, KUP 1E-32 twang Co�ornilh &Wellfs Well Attributes Max Angle&MD TD Alaska Wellbore API/UWI Field Name Well Status Incl(°) MD(11KB) Act Btm(5KB) 4 `.„,,,,,,,,i,,. 500292278800 KUPARUK RIVER UNIT INJ 62.07 3,331.59 10,445.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date ••• Well ConfR'-1E-32,62420139:48'43 AM SSSV:NIPPLE Last WO: 48.01 7/28/1997 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mad...End Date Last Tag:SLM 10,327.0 6/22/2011 Rev Reason:DRILLING DEPTHS/DATES osborl 4/22/2013 Casing Strings HANGER,37 ' Casing Description String 0... Str ng ID...Top(ftKB) Set Depth(f...Set Depth(ND)..String Wt...Str ng...Stnng Top Thrd SURFACE 95/8 8.835 41.1 6,016.0 3,969.0 40.00 L-80 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(ND)...String Wt...String...String Top Thrd '- PRODUCTION 7 6.276 39.0 9,996.0 5,986.1 26.00 L-80 BTC-MOD Top Depth a� Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth IND)...String WE..String...String Top Thrd LINER 4 12 3 958 9,811 1 10 443 );1,E. -6-f1.8 271.8 12.60 L-80 NSCT P (ND) Top eel Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 9,811.1 5,879.9 55.81 PACKER BAKER LINER HANGER w/ZXP MECHANICAL PACKER 3.958 9,831.9 5,891.3 55.41 PBR BAKER PBR 4.000 CONDUCTOR Tubing Strings Insulated 24', Tubing Description String 0... String ID...Top(5KB) Set Depth(f_.Set Depth(TVD)... String Wt...String...String Top Thrtl 42-121 TUBING 31/2 2.992 37.2 9,826.4 5,888.3 9.30 L-80 EUE8RDMOD Completion Details Top Depth NIPPLE,533 (TVD) Top Incl Nomi... Top IRKS) IRKS) (°) Item Description Comment ID(In) 37.2 37.2 -0.62 HANGER FMC GEN IV HANGER 3.500 532.7 531.7 6.72 NIPPLE CAMCO DS LANDING NIPPLE w/2.812 NO GO 2.812 9,778.4 5,861.4 56.84 SLEEVE BAKER CMU SLIDING SLEEVE 2.750 9,819.1 5,884.31 55.66ISEAL ASSY BAKER GBH-22 SEAL ASSEMBLY w/15'OF SEALS 13.000 Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (WKB) (ftKB) Zone Date Ish... Type Comment 10,165.0 10,182.0 6,093.6 6,104.4 C-4,1E-32 11/24/1999 4.0 APERF 2 1/8"EG,BDP,Odeg phase 10,195.0 10,219.0 6,112.7 6,127.0 C-4,1E-32 11/24/1999 4.0 APERF 21/8"EG,BDP,Odeg phase 10,264.0 10,284.0 6,156.1 6,169.0 C-3,1E-32 8/30/1997 4.0 IPERF Zero deg.phasing,2 1/8"EnerJet III GAS LIFT, 2.228 10,282.0 10,302.0 6,167.7 6,180.7 C-3,1E-32 6/26/2011 6.0 IPERF 2.5,60 Deg Phase,11.1 Gram Millenium DP Charge Notes:General&Safety I End Date Annotation 9/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 SU41-6,01RFACE,8 A ' I SLEEVE,9,778 I ."Llm MI II PRODUCTION, 395,996 APERF, 10,165-10,182 - APERF, 10,195-10,219 IPERF, Mandrel Details 10.264-10.284 Top Depth Top Port OD Valve Latch Size TRO Run N...Top(ftKB) (ftKB) Ii Make Model (in) Sery Type Type (in) (psi) Run Date Com... IPERF, 1 2,227.7 2,036.3 46.25 CAMCO MMM 1 12 GAS LIFT DMY RK 0.000 0.0 7/25/1997 10292-10.302 LINER, 9,811-10,443 TD,10,445 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, October 15, 2016 1:00 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: KRU 1E-32 (PTD 197-132) Report of OAxAtmosphere communication Attachments: 1E-32 90 day TIO plot jpg; MIT KRU 1E-32 Diagnostic MIT 10-14-16.xls; 1E-32 schematic.pdf Chris, Kuparuk injector 1E-32 (PTD 197-132) was identified as having a surface casing leak up the conductor back to atmosphere. The initial diagnostics confirmed the leak but were unable to pinpoint the leak depth. Further diagnostics will be done to identify the leak depth to evaluate for repair options. Once the leak was identified, a passing MITIA was performed as well as passing tubing and inner casing packoff testing. Following the MITIA the well was shut in. Once the leak depth has been confirmed and a path forward has been established,the proper paperwork will be submitted for repair or possible continued injection. Attached are copies of the MIT form, wellbore schematic, and a 90 day TIO plot for reference. Please let me know if you have any questions. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907) 659-7000 pgr. 909 WELLS TEAM iCA$HGv FEB 2 12012 '4% ConocoPhillips, 1 • dWe j jaMOLIO • CD CD CD C) C LO CD 1.X") CD I II i i ii I 1 i •i . ti ii . .! . 11 ' ,i. II . 1 .1 . ii . . .; • T--- • - • • • • - • '--••, • • • - . : • • . . : . . ' • . : i: : • • ' . co • • . • . , - • • / • - ,g-- • : 1 . • • • • • • • • • i • z..) . . . 4-6 - . — • . . • • • • • . ••, . - • . , ••_ in • ' • . • • . • . - - :• :. :. 1:11( • - • • • . cs) _ -,- cs_ . . • • - - • • • • 0 - • :. : _ : r u) . . • • • I---÷- • IR - . : . . . -: : _----- ci) . • •„•- . • • • • . z : i co • .,.....„ ce 1 .. . - ,‘..: • I _ • • • ?' • w . • • . . t : • . ,.. T.- _ • • • . .. 1 • : : . . 4-, - : - . . • •,, :.I :. - . 1,- as 0 • • . -___ . .-., . CO 0 - : ' • . --,• 0- . • • : ,'-•_. : r---- : 1 • . . . ..:,. . Cr) • . • • • • r • ) ---- . • - D . • i • < ..... • "'-. • • •____:), :•."--. ', - - - • • - - 4 i- • • . c•N, . ' . : • • . :I, • _ _ . • • :. . . . . • . • • • (.0 . . • . . • . • • . • - • • • , 0) • • . :. • . • • < . . • . ' 1 - : . • ' - ,4— . ' . • . • \--4---j, • - : • • • . • • ----4--- • . • . . • CO • • . . . • ..:---:::::• - "4- . . • • • • • . o_ a_ . • ' 1- • . • • . -J, LI_ < • . • • • . cs, - . • • 1 . . . . • . • • i . _ . • :• i ....._- . . . • . . • i : ,______ . _ "4- . ...- • . . I Lii -11 'I l' I I I I I I' 1-11-'1-1.-14÷1"-I 1 1 I I 1 1 1 i' I I' 1 1 ' 1 6 0 i__ a_ 0 0 0 0 0 I I- < cn C i:n in ci rn 0 u 0 0 in 0 1.0 CD Co C'ssl CV ISd 19 13 Z Regg, James B (DOA) From: CPF1 Prod Engr <n1269@conocophillips.com> " ,, 4I+114, Sent: Sunday, April 03, 2016 4:07 PM l�( To: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Regg, James B (DOA) Cc: Targac, Gary; NSK Prod Engr Specialist;Autrey, Mitch C; Bacala,Amanda; Caldelas, Fede M; Gallo, Courtney C Subject: Defeated LPP/SSV on well 1E-32 Jim, The low pressure pilot(LPP) on well 1E-32 (PTD# 197-132)was previously defeated on 3/27/16, due to low wellhead injection pressure. The LPP was restored to service today, 4/3/16, and is currently injecting at a wellhead injection pressure of 1000 psi and rate at 4600 BWPD. Please let me know if you have any questions. Regards, Courtney Gallo/ Mitch Autrey CPF1 Production Engineer Email: N1269@conocophillips.com Phone: (907) 659 7493 SCANNED SEP 2 12016 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reg ( I ( /j DATE: Wednesday,June 03,2015 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-32 FROM: Jeff Jones KUPARUK RIV UNIT IE-32 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Jr — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-32 API Well Number 50-029-22788-00-00 Inspector Name: Jeff Jones Permit Number: 197-132-0 Inspection Date: 5/2/2015 Insp Num: mitJJ150505153519 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well; 1E-32 ' Type Inj W TVD 5879 Tubing! 863 865 863 864 PTD 1 1971320 Type Test SPT Test psi 1500 IA 280 2010 - 1980 • 1970 - Interval 4YRTST IP/F P i OA 350 560 , 550 530- Notes: 08 BBLS diesel pumped 1 well inspected;one exception noted;the surface pipe flutes are out of the conductor pipe allowing excessive well head movement SCANNED AL L 1 2015 Wednesday,June 03,2015 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: .~ n Poor Quality Original'- Pages: [] Other - P ages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED [] Logs of various kinds Other Complete COMMENTS: Scanned by: Bew~ Mitdred-Daretha ~Lowell Date.: ~/~,~, TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 29, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforation Record: 1E-32 Run Date: 6/26/2011 Iol 7 - k - J 2, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E -32 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22788 -00 AJAZOta) SL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: Cr 23 l 2 -o ( Signed: 1 Bea/0 d STATE OF ALASKA ALASKA•AND GAS CONSERVATION COMMISS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug FFrforations r Stimulate r Other r Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r� Re -enter Suspended Well r' 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 197 - 132 3. Address: 6. API Number: Stratigraphic r Service R. P. O. Box 100360, Anchorage, Alaska 99510 v 50 - 029 - 22788 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25660 " ` 1 E - 9. Field /Pool(s): 6., Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 10445 feet Plugs (measured) None true vertical 6273 feet Junk (measured) None Effective Depth measured 10377 feet Packer (measured) 9811 true vertical 6229 feet (true vertucal) 5880 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 5975 9.625" 6016 3969 PRODUCTION 9957 7 9996 5986 LINER 632 4.5" 10443 6272 d, 4 2.4M d c �' �! xr4 Perforation depth: Measured depth: 10165'- 10182', 10195'- 10219', 10264'- 10302' q t ""_ .,,, True Vertical Depth: 6094'- 6104', 6113'- 6127', 6156' -6181' Tubing (size, grade, MD, and TVD) 3.5, L -80, 9826 MD, 5884 TVD r_ - . * A4 ttttii- ai'liiilSSlOfi .11r4 eteig Packers & SSSV (type, MD, and TVD) PACKER - BAKER PACKER 9811' , 5880' TVD NIPPLE - CAMCO DS LANDING NIPPLE w/ 2.812 NO GO @ 533 MD and 532 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 0 5407 Subsequent to operation shut - 13. Attachments 14. Well Class after work: ,. Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 15. Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations _XXX GSTOR r VVINJ r WAG p" GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce @ 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date l / G- .c, – 7 /L4 - iii r ' a MS JUL 15 i �: a O 7/71( Form 10-404 Revised 10/2010 . 74/ � . Submit Original Only 1 E -32 Well Work Summary DATE SUMMARY , 4/25/11 TAGGED @ 10229' SLM, EST. 464/L. NEED FCO PRIOR TO RE -PERF. • 5/15/11 GREW ARRIVED ON LOCATION AND DURING THE PT NOTICED THAT THE EQUALIZING PORT ON THE BOPES WAS NOT WORKING. EQUALIZING PORT WOULD NOT TEST AND A MECHANIC WAS CALLED. JOB TO BE RESTARTED IN THE MORNING. IN PROGRESS 5/26/11 RAN IN HOLE WITH JSN AND WASHED AWAY HARD DEBRIS FROM 10247 CTMD TO 10360 CTMD WHERE WE ENCOUNTERED A HARD TAG THAT WOULD NOT WAS AWAY. POOH. RIGGED BACK UNIT. READY FOR ELINE. WELL TURNED OVER TO DSO TO PUT BACK ON INJECTION 6/13/11 ATTEMPTED TO PERFORATE W/ 20' 2.5" HSC. BRIDGED OUT AT 10260', UNABLE TO PERFORATE. 6/21/11 ATTEMPTED DRIFT TBG w/ 2.50 DD BAILER. TAGGED OBSTRUCTION @ 10220' SLM. BAILED TO 10221' SLM, RECOVERED METAL PIECES, POSSIBLE PKG, PEBBLE. IN PROGRESS. 6/22/11 BROKE THRU BRIDGE @ 10220' SLM. WITH MAGNET & BAILER RECOVERED PERF GUN DEBRIS. GAUGED TBG TO 2.71" TO 10327' SLM. DRIFTED w/ 2.7" DUMMY GUN (OAL 20.16') TO SAME. READY FOR E /L. 6/26/11 PERFORATE 10,282- 10,302 WITH 20' LONG, 2.5" 60 DEG PHASED, 6 SPF , 11.1 GRAM MILLENIUM DP CHARGES t-,� t.� l; ' KU P 1E-32 , • Co oPhit11�Ji Well Attributes _ Max Angle & MD TD - We Ilbore API/UWI Field Name Well Status 'Max () MO (ftKB) Act Btm (ftKB) •Akiskii,111C. .- 500292278800 I KUPARUK RIVER UNIT INJ 62.07 3,331.59 10,4450 toon thin - - Comment H25 (ppm) Date An atat End Dat i_ KB -Grtl (R) Rig Release Date .• W8 Co699 t s3, t pi7,2� - }, SPM �SSSV NIPPLE I Last WO 4801 _ 7/28/1997_ "" _ `� _ Aaru� _ � M lation Bepth (ftK8) End Date Annotaton Last Mod .. End Date Last Tag: SLM 10,229 0 4/25/2011 Rev Reason ADD PERFS mnam 7/13/2011 Casing Strings l l Casing Description Siring 0... 'String ID .. Top (ftKB) Set D pth (f... Set Depth (TVD) .. String W[ String String Top Thrd ir. HANGER, 37 - -- - -- _ CONDUCTOR 16 15.062 420 121.0 121.0 62.50 H WELDED >_ Casing Description String 0... String ID... Top (kKB) Set Depth (f... Set Depth (TVD) .. String Wt... Siring ... String Top Thrd SURFACE 9 5/8 8.835 41.1 6,016.0 3,969.0 40.00 L BTC Casing Description String 0... String ID ... Top (k813) Set Depth (f.. Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 39.0 9,9960 5,986.1 26.00 L - 80 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... String Top Thrd - LINER 41/2 3.958 9,811.1 10,443.0 6,271.8 12.60 L -80 NSCT simmisma Liner Details Top Depth (TVD) Top Inc! Nomi... Toe ftKB) (ftKB) 4 ") Item Description Comment ID (in) 9,811 1' 5,879.9 55.81 PACKER BAKER LINER HANGER w/ ZXP MECHANICAL PACKER 3.958 CONDUCTOR, 9,831.9 5,891.3 55 41 PBR BAKER PBR 4.000 42 -121 Tubing Strings Tubing Description Str ing O._ String ID ...ITop (ftKB) ISet Depth (f... ISet Depth (TVD) ... String Wt... String .. String Top Thrd TUBING 3 1/2 2.992 37. 9,826 .4 5,888.3 9.30 L-80 EUE8RDMOD NIPPLE, 533 1 Completion Details Top Depth (TVD) Top Inc! Nomi... 1 (WW1 (ftKB) (°) Item Description Comment ID (in) 37.2 37.2 -0.62 HANGER FMC GEN IV HANGER 3.500 532.7 531.7 6.72 NIPPLE CAMCO DS LANDING NIPPLE w/ 2.812 NO GO . -- 2.812 9,778.4 5,861.4 56 84 SLEEVE BAKER CMU SLIDING SLEEVE 2.750 9,819.1'. 5884.3 55 66 SEAL ASSY BAKER GBH -22 SEAL ASSEMBLY w/ 15' OF SEALS 3.000 Perforatwns &S � � � ��g �-'�- s� i��r, � , ,_ , -- Shot Top (TVD) Btm (TVD) Dens T• • MB B1m MB (ftKB) (ftK8) Zone - - -__ Date (shJ-Typp Comment 10,165 10,182 6,093.6 6,104 4 C-4, 1E -32 11/24/1999 4.0 APERF 2 1/8" EG, BDP, 0 deg phase GAS UFT, s -_ 10,195 10,219 6,112.7 6,127.0 C-4, 1E - 32 -_ -� 11 /24/1999 4.0 APERF 2 1/8" EG, BDP, 0 deg phase 2,226 - -- — 10,264 10,284 6,156.1 6,169.0 C-3, 1E -32 i 8/30/1997 4.0 IPERF Zero deg. phasing, 2 118" EnerJet III 10,282 10,302 6,16 /.7 6,180.7 C -3, 1E-32 6/26/2011 6.0 IPERF 2.5, 60 Deg Phase, 11.1 Gram Millenium DP Charge 11 j Notes: General & Safety { End Date Annotation i . 9/8/2010 NO I E View Schematic w/ Alaska Schematic9 0 SUA CE, _ - 41 - RF 6,016 SLEEVE, 9,778 !♦ c 7 ,v.. f ii L PRODUCTION, _ 39 -9,996 APERF,_ 10,165 - 10,182 C- APERF, 10,19510,219 IPERF, Mandrel Details 10 ,264 -10284 Top Depth Top Pon - - (TVD) Ind OD Valve Latch Size TRO Run t Stn To. ftKB (1188) 1') Make 1 Model (in) Sery Type Type (in) (psi) Run Date Com... GAS LIFT DMY R0 0.0 7/25/1997 10282-110,302 1 2,227.7 2,036.3 46.25 CAMCO MMM 1 1/21 GAS 0.00 _ -_ I LINER, 9,811 - 10,443 TD, 10,445 MEMORANDUM Ta~ Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector C~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 30, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 E-32 KUPARUK RIV iJNIT 1E-32 Sre: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv _ Comm Well Name: KUPARUK RIV UNIT 1E-32 Insp Num: mitRCN100628065227 Rel Insp Num: API Well Number: 50-029-22788-00-00 Permit Number: 197-132-0 Inspector Name: Bob Noble Inspection Date: 6/24/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~' 1>rs2 `~ Type In,l. '~W TVD 5879 ~ IA ~20~-- SPT 2480 ~ - P,'j~,D~ LTypCTeSt L ~~ TQSt pSl OA aoo 280 ~zaso ~ 460 za7o 460 za7o 46~ _ Interval 4YRTST per, P ~ Tubing 1475 1475 1475 ~ 1475 Notes: bA.tn reci `~Q -(egg-- 1soD~,: Wednesday, June 30, 2010 Page 1 of 1 • • • • ~onocoPhill~ps Alaska ~ ~ } ~` P.O. BOX 100360 ~~ `'~ ANCHORAGE, ALASKA 99510-0360 1 °~ ~ ;,, ~ ~ ~ ~ ,a March 14, 2008 ~ ;Y Mr. Tom Maunder 3 ~-- Alaska Oil 8i Gas Commission 333 West 7~' Avenue, Suite 100 ~(~~ Anchorage, AK 99501 f~~~{y7~~~~ y~ `- Dear Mr. Maunder: ,~ Enclosed please. find a spreadsheet with a list of wells from the Kuparuk field (KRII). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water 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 January 17, 2008 and the corrosion inhibitor/sealant was pumped on February 2, and March 8, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me or Perry Kiein at 907-659-7043, if you have any questions.. Sincerely, ~,,.-- r- ,~f ~~~ l . C~°` M.J. veland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field n~to 3/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 H-04 182-103 23" NA 23" NA 4.5 2/2/2008 1H-06 182-068 28' 3.2 5" 1/17/2008 5.5 2/2/2008 1H-07 182-084 9' 3" 1 11" 1/17/2008 7 2/2/2008 1 H-08 182-093 SF NA SF NA 4 2/2/2008 1E-31 .197-138 4'10" NA 4'10" NA 21 3/8!2008 1 E-32 197-132 8" NA 8" NA 3.5 3/8/2008 1 E-35 198-195 12" NA 12" NA 2 3/8/2008 1 E-36 198-213 20" NA 20" NA 4.5 3/8/2008 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: ~~~ S~::r~isor K11 b tC¡(Ù6 DATE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lE-32 KUPARUK RIV UNIT lE-32 \~ 'r \~y FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~Jge- Comm Well Name: KUPARUK RIV UNIT IE-32 API Well Number 50-029-22788-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060605135037 Permit Number: 197 -132-0 Inspection Date: 6/4/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1E-32 , I ! Well ! ¡Type Inj. i W TVD 5880 IA 650 2350 2350 2350 I I i i ~-- P T I 1971320 'TypeTest I SPT I Test psi 1500 OA 420 I 640 ! 640 640 ! . . ¡ Tubing I I Interval 4YRTST P/F P 1460 1460 1460 1460 ! Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integriy NON-CONFIDENTIAL :..;.,f" ~~MNt.:f, -&Vr ¥~ ~1·.~-· -, "''''~ i} Wednesday, June 07, 2006 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' FROM: Cammy O. Taylor Chair Tom Maunder Petroleum Engineer/~. Lou Grimaldi Petroleum Inspector DATE: October 24, 2002 SUBJECT: Mechanical Integrity Tests Conoco/Phillips 1 E Pad 1 E-32 Kuparuk River Unit Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 1E-32 I Typelnj. J S I T.V.D. I 5880 I TubingJ 1370 I 1375 I 1370 I 1370 J lntervalI 4 P.T.D.I 1971320ITypetestl P I TestpsiI ~S00 ICas,ngI 4000I 2020I 2000I 2000I P/F I P Notes: We,,I I TypeInj. P.T.D.I Type test Notes: Type. INJ. Fluid Codes F = FRESH WATER INj. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details This was the standard four year pressure test of this wells production casing. The test went well with no appreciable loss ofpressure during the thirty minute test. I passed the well for continued injection. M.I.T.'s performed: 1 Attachments: Number of Failures: None Total Time during tests: 2 hours cc: Dethlefs/Nezetiky MIT report form 5/12/00 L.G. MIT KRU 1E 10-24-02 LG.xls 10/27/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIuN 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 5085' FNL, 818' FEL, Sec. 16, T11N, R10E, UM 5. Type of Well: Development Exploratory __ Stratigraphic __ Service X (asp's 549709, 5959778) 6. Datum elevation (DF or KB feet) RKB 113 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 E-32 At top of productive interval 1910' FNL, 475' FWL, Sec. 27,T11N, R10E, UM At effective depth At total depth 2086' FNL, 4595' FEL, Sec. 27, T11N, R10E, UM (asp's 551276, 5952229) 9. Permit number/approval number 197-132 / 10. APl number 50-029-22788 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 121' SUR. CASING 5913' PROD. CASING 9887' LINER 632' LINER Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 10445 feet 6273 feet Plugs (measured) feet Junk (measured) feet Size Cemented Measured Depth True vertical Depth 16" 293 sxAS, 121' 121' 9-5/8" 552 sx ASWL, 700 sx Class G, 60 6026' 3974' 7" 120 sx Class G 10000' 5990' 4-1/2" 75 sx Class G 10443' 6272' 13. Stimulation or cement squeeze summary Intervals treated (measured) ::=::%i}X:'::::;i::-:il :;.,: }:'i::::~: ~i'' ~=~::iiiiii!:! ' ~'. i' ::N/A:iii~.::i-:. :::;:;: :;~:i~;!! :::iii~;;iiii~:i::.'i/.il :i= ':: .-:.i:0~i .':i;;i}:ii'il~ '~ . ':' :' ' '::'~: ' :'~': ": '' '::': ' : '"::': ' ::::':' "' :' ":"':'; ' : ::i;; ': .:: i: Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data Gas-Mcf Water-Bbl OiI-Bbl Casing Pressure : :8oo. !ii:;;:` :. ': : 800 .2609: I::i: :~' Oil :: :' : G~i:.::: i SUSpended, : service :XWAGInjector 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 (~orrect to the best of my knowledge. Signed /~~'t~~~itle ProductionEngineeringTechnician Robert D. Christensen Tubing Pressure Questions? Call Jeff Spencer659-7226 Form 10-404 Rev 06/15/88 · AUG 21 2002 SUBMIT IN DUPLICATE 1 E-32 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pedorate _X 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__ RKB 113 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 5085' FNL, 818' FEL, Sec. 16, T11 N, R10E, UM (asp's 549709, 5959778) 1 E-32i At top of productive interval 9. Permit number / approval number 1882' FNL, 4648' FEL, Sec. 27, T11 N, R10E, UM (asp's 551222, 5952437) 197-132 At effective depth 10. APl number 50-029-22788 At total depth 11. Field / Pool 2086' FNL, 4595' FEL, Sec. 27, T11 N, R10E, UM (asp's 551276, 5952229) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 10445 feet Plugs (measured) Tagged PBTD (11/22/99) @ 10295' MD. true vertical 6273 feet Effective depth: measured 10295 feet Junk (measured) true vertical 6176 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 293 Sx AS II 121' 121' SURF CASING 5913' 9-5/8" 552 Sx ASLW, 700 Sx G, & 6026' 3974' 60 Sx AS I PROD CASING 9887' 7" 120 Sx Class G 10000' 5990' LINER 632' 4-1/2" 75 Sx Class G 10443' 6272' Perforation depth: measured 1 0165 - 10182'; 10195 - 10219'; 10264 - 10284' · . ., true vertical 6094 - 6104'; 6113 - 6128'; 6157 - 6170' - Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80, Tubing @ 9826' MD. R E C E IV E D Packers & SSSV (type & measured depth) No Packer. CAMCO 'DS' LANDING @ 533' MD.FEB'1,52001 13. Stimulation or cement squeeze summary ~laska 0il & (.;as Owns. ,C0rnmi,~ir, r Intervals treated (measured) (see attached) Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 5850 2200 Subsequent to operation - 61 O0 2400 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service __.(Water Inj)__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Date Signed ~' , ~'~,~ Prepared by jo~//~ ~Peirce 265.6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001 M PL E W ATE IA L U N D ER TH IS M ARK ER C :LORIXMFII.M.DOC AOGCC Geological Materials Inventory _ PERMIT 97-132 ARCO Log Data Sent Recieved 8113 c~RRy M?T/GR/EWR4 9/26/97 9/26/97 CBL ~0-10369 2 (~ ~v-~ !~ 0,, ~ 10/14/97 10/15/97 DGR/EWR4-MD ~-10445 9/26/97 9/26/97 DGR/EWR4-TVD -~_~3969-6273 9/26/97 9/26/97 MWD SRVY ~iS~ERRY 0-10445. 9/2/97 9/10/97 Was the well cored? Are tests required? Well is in compliance Comments t..~07 Completion Date Are d~ ditch samples required? yes ~no yes yes Initial And received? Analysis description recieved? Received? -~----yes ---no ..... Box Tuesday, August 31, 1999 Page 1 of 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 9, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular Injection during the first quarter of 1999: h(1) h(2) h(3) Total for t Previous New Well Name Volume Volume Volume QuarterI Total Total 2N-315 25326 100 0 25426 I See Note #1 below25426 2L-325 I 8397 , 100 0 ] 8497 . 11883 20380 2N-321A ] 27507 100 I 0 1276071 0 27607 3K-23 15 0 0 ] 15 0 15 3K-25 42021100 0 14302 0 4302 1C-15 16695 100 0 I 16795 ~ 0 16795 [ 8654 2L-313 8554 I 100 0 ~ ] 0 8654 Note #1: Well # 2N-315. The previously reported volume of 220 barrels was pumped into this annulus during the drilling <~'the well. This was the volume required to./htsh and freeze protect the annuhts during initial drilling operations, not a vol,tree o_t' disposal./htids injected prior to the receipt of authorization JOt ann ular injection. Total Volumes into Annuli for which Injection Authorization Expired during the quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume i Volume Volume Injected Status of Annulus 1C-12 34995 i 100 0 35095 Open, Freeze Protected 1C-13 26800 ! 100 0 26900 Open, Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO's, we would like to repeat and supplement information we provided with our letter of February 26.1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska, inc. is a Subst0iary of Atlantic Richfield Company AFt3B-6003-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two I Total Total h(1) Total h(2) I Total h(3) Volume Current Status of Well Name Volume VolumeI Volume I Injected Annulus 2A-22 16749 100 0 16849 Open, Freeze Protected 2F-19 20725 100 I 0 20825 Open. Freeze Protected 3K-27 37173 100I~ 0 37273 Open, Freeze Protected 3K-26 33970 100 t 0 34070 Open, Freeze Protected 1E-31 33645 100 0 33745 Open, Freeze Protected 1E-32 45205 100 0 45305 Open, Freeze Protected 3Q-22 6245 100 0 6345 Open. Freeze Protected 1Q-24 23158 100t 0 23258 Open, Freeze Protected 1Q-26 25931 100 t 0 26031 Open. Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 27, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1E-32 (Permit No. 97-132) Revised Well Completion Report Dear Mr. Commissioner: Enclosed is the revised well completion report for the completion on KRU 1E-32. We have corrected the bottomhole location. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Development WSI/skad 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 [---] GAS [] SUSPENDED ~1 ABANDONED~ SERVICE [~] WATER INJECTOR 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-132 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22788 4 Location of well at surface 9 Unit or Lease Name 1910' FNL, 475' FWL, Sec. 27, T11 N, R10E, UM] ~]i 1 E-32 AtTotal Depth !,, '~j[~.~ !! 11 Fieldand Pool 2086' FNL, 685' FWL, Sec. 27, T11N, R10E, UM ,~ .......... KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Kuparuk River Oil Pool Rig RKB 41', Pad 72' I ~_~, ~ ADL 25660 ALK 470 12 Date15-Jul-97Spudded 13 25-Jul-97Date T.D. Reached ~ '14~20.Aug.97Date Comp., Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 NO.lOf Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+'DVD) 19-"Directional Survey 120 Depth where SSSV set'J 21 Thickness of permafrost 10445' MD & 6273' TVD 10377' MD & 6229' TVD YES U NO X~I NA feet MDI 1650' APPROX 22 Type Electdc or Other Logs Run GR/Res, GR/CCL/SLTJ 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.5# H-40 SURF. 121' 26' 293 sx AS II 9.625' 40.0# L-80 SURF. 6016' 12.25' 552 sx ASLW, 700 sx Class G, 60 sx AS I 7' 26.0# L-80 SURF. 9996' 8.5" 120 sx Class G 4.5" 12.6# L-80 9805' 10443' 6.125' 75 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5' 9826' 10264'-10284' MD 6157'-6170' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST WATER INJECTOR Date of Test Hours Tested PRODUCTION FOIOIL-BBL GAS-MOF WATER-BBI CHOKE SIZE I GAS-OIL RATIO I TEST PERIOI: Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBI OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Bdef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Total pump volumes for this event: Category 1. 45,090 Category 2. 100 Top Kuparuk C 10165' 6094' Category 3. Bottom Kuparuk C 10302' 6181' Total: 45,190 Top Kuparuk A 1 0378' 6230' Bottom Kuparuk A 10378' 6230' Total to Date: 45,190 Annulus left open - freeze protected with diesel. Annular volume limit increased to 45,000 bbl per Blair Wondzell on 8/28/97. Blair Wondzell was notified on 9/19/97 of inadvertantly exceeding the injection limit. 31. LIST OF A1ZACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 RECEIVED AJaska Oil & G~s Cons. comml~sio~'~ Anchorage Date: 9/9/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lE-32 RIG:PARKER 245 WELL ID: AK8909 TYPE: -- AFC: AK8909 AFC EST/UL:$ 2360M/ 2832M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: BLOCK: SPUD: START COMP: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22788-00 07/03/97 (D1) TD: 0' ( SUPV: DEB 0) DAILY: $ 07/04/97 (D2) TD: 0'( 0) SUPV: DEB DAILY: $ 07/05/97 (D3) TD: 0' ( 0) SUPV: DEB DAILY: $ 07/06/97 (D4) TD: 0' ( 0) SUPV: DEB DAILY: $ 07/07/97 (D5) TD: 0' ( 0) SUPV: DEB DAILY: $ 07/08/97 (D6) TD: 0'( 0) SUPV: DCL DAILY: $ 07/09/97 (D7) TD: 0' ( 0) SUPV: DCL DAILY: $ 07/10/97 (DS) TD: 0' ( 0) SUPV: DCL DAILY: $ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG MOVE Released rig from 3K-23 @ 2100 hrs. 7/3/97. Prepare rig for non-standard rig move to 1E pad and for maintenance at 1E pad. Move CPM to end of 3K pad. 6,957 CUM:$ 6,957 ETD:S2,147,483,6 EFC:$-2,145,116, MW: 0.0 VISC' 0 PV/YP: 0/ 0 APIWL: 0.0 RIG MOVE Move rig off well. 50,932 CUM:$ 57,889 ETD:S2,147,483,6 EFC:$-2,145,065, MW- 0.0 VISC' 0 PV/YP: 0/ 0 APIWL: 0.0 RIG MOVE Move derrick to 1E pad. Move utility module off 3K pad. 51,628 CUM:$ 109,517 ETD:S2,147,483,6 EFC:$-2,145,014, MW: 0.0 rISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG MOVE Continue to move utility module to 1E pad. Derrick being prepared for inspection while moving utility module. 50,740 CUM:$ 160,257 ETD:S2,147,483,6 EFC:$-2,144,963, MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG MOVE Move drilling module from 3K pad to iQ wide spot. Move camp and set up on 1E pad. 51,495 CUM:$ 211,752 ETD:S2,147,483,6 EFC:$-2,144,911, MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG MOVE Move drilling module. Clean derrick and dress for inspection. 50,719 CUM:$ 262,471 ETD:S2,147,483,6 EFC:$-2,144,861, MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG MOVE Repair hydraulic motor on #2 Lampson. Continue to move rig. Prep derrick for inspection. 50,908 CUM:$ 313,379 ETD:S2,147,483,6 EFC:$-2,144,810, MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG MOVE Clean on derrick. Install %2 mud pump, wind walls, and braces. 50,712 CUM'$ 364,091 ETD : $2,147, 48~ ~~:,~~, 759, Date: 9/9/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/11/97 (D9) TD: 0'( 0) SUPV:DCL DAILY:$ 07/12/97 (D10) TD: 0'( 0) SUPV:DCL DAILY:$ 07/13/97 (Dll) TD: 0'( 0} SUPV:DCL DAILY:$ 07/14/97 (D12) TD: 0'( 0) SUPV:DCL DAILY:$ 07/15/97 (D13) TD: 1230' (1230) SUPV: DCL DAILY: $ 07/16/97 (D14) TD: 4251' (3021) SUPV:DCL DAILY:$ 07/17/97 (D15) TD: 6026' (1775) SUPV: DCL DAILY:$ 07/18/97 (D16} TD: 6026' ( 0) SUPV: DCL DAILY:$ 07/19/97 (D17} TD: 6026' ( 0} SUPV: DCL DAILY:$ 07/20/97 (D18) TD: 7689' (1663) SUPV: DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG MAINTENANCE Rig maintenance. 50,604 CUM:$ 414,695 ETD'S2,147,483,6 EFC:$-2,144,708, MW: RIG MAINTENANCE Rig maintenance. 50,813 CUM:$ 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 Prep derrick for installation. 465,508 ETD:S2,147,483,6 EFC:$-2,144,658, MW: RIG MAINTENANCE Rig maintenance. 53,647 CUM:$ 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 Set windwalls in derrick. 519,155 ETD:S2,147,483,6 EFC:$-2,144,604, MW: 8.4 VISC: 72 PV/YP: 16/24 APIWL: 10.8 PICK UP DRILL PIPE Move drill module over well. NU diverter system. Function test diverter. Accept rig @ 1900 hrs. 7/14/97. 83,142 CUM'$ 602,297 ETD:S2,147,483,6 EFC:$-2,144,521, MW: 9.6 VISC: 91 PV/YP: 34/28 DRILLING Clean out conductor to 116' Drilling from 121' 67,178 CUM:$ 669,475 ETD:$ 687,994 EFC:$ APIWL: 6.8 to 1230'. 2,341,481 MW: 9.6 VISC: 65 PV/YP: 22/21 APIWL: 8.0 DRILLING Drilling from 1230' to 3972'. Small amount of gas cut mud at bottoms up. Drilling from 3972' to 4251'. 78,124 CUM:$ 747,599 ETD:$ 941,319 EFC:$ 2,166,280 MW: 9.7 VISC: 50 PV/YP: 17/15 APIWL: 6.2 LD BHA Drilling from 4251' to 5036' Hole sticky. Circ lo/hi vis sweep. Drilling from 5036' to 6026' . Wipertrip to HWDP. No problems. 69,732 CUM:$ 817,331 ETD'$ 1,090,161 EFC'$ 2,087,170 MW: 9.7 VISC: 45 PV/YP: 11/11 APIWL: 6.5 ND DIVERTER Circ lo/hi vis sweep. Small amount of gas at bottoms up. Held prejob safety meeting. RIH w/9-5/8" casing. CBU. No problems. Circ and condition. No loss. Pump cement. 152,584 CUM'$ 969,915 ETD'$ 1,090,161 EFC:$ 2,239,754 MW: 9.6 VISC: 40 PV/YP: 7/ 8 APIWL: 7.4 TEST 9-5/8" CASING Clean cement f/diverter. Test BOPE to 300/3000 psi. Test casing to 2000 psi, OK. 146,130 CUM'$ 1,116,045 ETD'$ 1,090,161 EFC'$ 2,385,884 MW: 8.9 rISC: 50 PV/YP: 14/25 APIWL: 7.8 DRILLING Clean out cement from 5651' to 5854'. Test casing to 2000 psi/30 min, OK. Drill out float equipment' cement and 2 0' new formation to 6046' Performed LOT, 13.3 ppg EMW. Drill f/6046' to 7689'. 95,249 CUM:$ 1,211,294 ETD'$ 1,276,424 EFC'$ 2,294,870 Date: 9/9/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 07/21/97 (D19) TD:10000' (2311) SUPV:DCL DAILY:$ 07/22/97 (D20) TD:10000' ( 0) SUPV:DCL DAILY:$ 07/23/97 (D21} TD:10000' ( 0) SUPV:JT DAILY:$ 07/24/97 (D22) TD:10154' (154) SUPV:JT/SR DAILY:$ 07/25/97 (D23) TD'10445' ( 291) SUPV:JT/SR DAILY:$ 07/26/97 (D24) TD:10445' ( 0) SUPV:JT/SR DAILY:$ 07/27/97 (D25) TD: 10445' ( 0) SUPV: JT/SR DAILY: $ 07/28/97 (D26) TD:10445' ( 0) SUPV: JT/SR DAILY:$ MW: 9.1 VISC: 45 PV/YP: 10/18 APIWL: 6.5 POH TO RUN CASING Drilling from 7689' to 10000' Circ hi vis sweep. Condition mud. Monitor well. Pump slug pipe. POH. 112,787 CUM'$ 1,324,081 ETD'$ 1,535,660 EFC:$ 2,148,421 MW' 0.0 VISC: 42 PV/YP: 11/ 8 A?IWL: 6.7 NU BOPE Run 7" casing to 9996' Circulate, reciprocate and condition well. 195,860 CUM'$ 1,519,941 ETD'$ 1,535,660 EFC:$ 2,344,281 MW: 0.0 VISC: 54 PV/YP: 26/21 M/U TBG SPOOL TEST 3000 PSI Pump cement. N/U BOPE. Test BOPE 300/5000 psi. protect. 99,234 CUM:$ 1,619,175 ETD'$ 1,535,660 EFC:$ APIWL: 4.4 Freeze 2,443,515 MW: 12.0 VISC: 48 PV/YP: 23/18 APIWL: 4.2 TIH Test 7" casing to 3500 psi for 30 min, no loss. Drill cement, float, shoe and 10' new hole to 10018' Change out mud to 12%. FIT @ 10018' EMW 14%. Drill from 10018' to 10154' 79,882 CUM:$ 1,699,057 ETD:$ 1,637,990 EFC:$ 2,421,067 MW: 13.0 VISC: 50 PV/YP: 28/20 APIWL: 3.8 CIRCULATE BOTTOMS UP Circ out gas cut mud. Sht down and monitor well, small trickle. Drill 6.125" hole from 10154' to 10445' Circ BU, monitor slight flow. Weight up to 13 ppg. Monitor well - static. 81,145 CUM:$ 1,780,202 ETD:$ 2,233,150 EFC:$ 1,907,052 MW' 13.0 VISC' 50 PV/YP: 29/20 SAFETY MEETING Run 4.5" liner. 116,374 CUM:$ 1,896,576 ETD'$ 2,233,150 EFC'$ APIWL' 3.8 2,023,426 MW' 13.0 VISC' 50 PV/YP: 29/20 CEMENTING 4.5" LINER Cement liner. Run 3.5" liner. 127,975 CUM:$ 2,024,551 ETD:$ 2,233,150 EFC:$ APIWL: 3.8 2,151,401 MW: 8.5 VlSC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Ran 3.5" tubing. Freeze protected well with diesel. Pressure tested tubing to 3500 psi for 10 min. Lost 35 psi. OK. ND BOP. NU tubing head adapter. Released rig @ 1400 hrs. 7/28/97. 89,599 CUM:$ 2,114,150 ETD:$ 2,233,150 EFC:$ 2,241,000 End of WellSummary for Well'AK8909 KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (1E-32(W4-6)) ~qSLL JOB SCOPE JOB NUMBER 1 E-32 PERFORATE, PERF SUPPORT 0803972212.13 DATE O8/3O/97 DAY 4 DAILY WORK PERFORATE 2 1/8" ENERJET D.P. I Initial Tbg Press [FinalTbgPress IlnitiallnnerAnn {FinallnnerAnnIOPSI 850PSI 0PSI 0PSI DAILY SUMMARY UNIT NUMBER SWS-8293 SUPERVISOR BLACK Initial Outer Ann [ Final Outer Ann 1100 PSII 1100 PSI PERFORATED 10264-10284' ELM W/2-1/8" EJ DP @ 4 SPF & 0 DEG PHASING /ORIENTATION. TIME LOG ENTRY 07:30 MIRU SWS 8293 ELMORE. MU GUN ASSEMBLY. TGSM. PT 3000//. 09:00 RIH W/WT BAR-CCL-MPD-GUN. 2 1/8" El. 4 SPF. EJ II1 RDX DEEP PENETRATING CHARGE. 14 GR. EXP LOAD, 21.94" PENETRATION, .31" ENTRY. 10:00 10:35 TIE IN TO SHORT JOINTS (WITH 8/28/97 SWS SLTJ/GR/CCL). LU AND SHOOT AT 10264'-10284' ELM W/2-1/8" EJ DP @ 4 SPF & O DEG PHASING / ORIENTATION. CCL 'FO TS=4.7', CCL TO BOT/GUN=25.7'. POOH. 11:00 AT SURFACE. BD LUBRICATOR. ALL SHOTS FIRED. RELEASE RADIO SILENCE & TUP~N OVER TO PRODUC~ON. 12:30 RDMO TO 3F-13. PAGE 1 Sr-'~.RY-SUN DRILLING SERVICES - ANCHOR_AGE ALASKA ARCO ALASKA INC. KUPARUK RIVER UNIT / 1E-32 500292278800 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/29/97 DATE OF SURVEY: 072597 MWD SURVEY JOB NUMBER: AK-MM-70207 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -113.00 0 121.00 121.00 8.00 0 190.27 190.27 77.27 0 282.56 282.55 169.55 0 371.74 371.64 258.64 4 0 N .00 E .00 .00N .00E 0 N .00 E .00 .00N .00E 30 N 25.40 W .74 .28N .13W 47 S 17.98 E 1.41 .04N .llW 3 S 5.94 E 3.68 3.67S .40E .00 .00 - .30 -.07 3.68 464.51 463.99 350.99 6 554.75 553.60 440.60 6 645.89 644.12 531.12 6 734.78 732.38 619.38 6 825.16 821.98 708.98 8 47 S 2.66 E 2.97 12.41S 1.00E 41 S 2.30 E .11 23.00S 1.46E 41 S 2.66 E .04 33.62S 1.92E 58 S 3.88 E .35 44.17S 2.52E 6 S .48 E 1.34 56.01S 2.95E 12.37 22.85 33 .36 43 .83 55.53 914.01 909.66 796.66 10 1005.81 999.71 886.71 12 1096.47 1088.01 975.01 14 1189.31 1177.56 1064.56 16 1282.47 1266.32 1153.32 18 20 S 1.38 E 2.53 70.24S 3.19E 0 S 1.81 E 1.82 88.02S 3.69E 5 S 4.68 E 2.40 108.45S 4.89E 25 S 5.65 E 2.54 132.78S 7.10E 52 S 5.51 E 2.62 160.88S 9.85E 69.55 87.09 107.37 131.67 159.78 1372.65 1350.87 1237.87 21 1468.15 1438.70 1325.70 24 1560.47 1522.35 1409.35 25 1651.55 1603.21 1490.21 29 1744.96 1682.58 1569.58 34 46 S 6.81 E 3.27 192.02S 13.23E 26 S 8.51 E 2.87 229.16S 18.26E 37 S 9.57 E 1.38 267.73S 24.40E 7 S 9.65 E 3.83 309.02S 31.39E 28 S 12.82 E 6.01 357.24S 41.08E 190.99 228.40 267.44 309.30 358.49 1837.72 1757.50 1644.50 37 1929.90 1828.65 1715.65 41 2025.07 1898.39 1785.39 44 2117.24 1962.83 1849.83 46 2207.61 2024.45 1911.45 47 45 S 12.39 E 3.54 410.59S 53.00E 11 S 12.87 E 3.75 467.76S 65.82E 33 S 12.'69 E 3.54 530.90S 80.14E 41 S 11.06 E 2.63 595.36S 93.68E 20 S 9.98 E 1.13 660.35S 105.74E 413.14 471.70 536.42 602.27 668.37 2304.83 2089.53 1976.53 48 2395.56 2147.84 2034.84 51 2488.26 2203.64 2090.64 54 2581.18 2256.41 2143.41 56 2676.90 2308.49 2195.49 57 36 S 9.82 E 1.31 73i-.49S 118.16E 23 S 9.50 E 3.08 800.01S 129.81E 35 S 9.52 E 3.45 873.00S 142.04E 11 S 9.82 E 1.74 948.39S 154.89E 52 S 10.25 E 1.81 1027.46S 168.89E 740.58 810.05 884.04 960.48 1040.77 2768.99 2355.88 2242.88 2960.12 2450.84 2337.84 3147.82 2541.68 2428.68 3331.61 2628.10 2515.10 3611.53 2760.84 2647.84 60 60 61 62 61 9 S 10.72 E 2.51 1105.07S 183.25E 15 S 10.42 E .15 1268.13S 213.68E 50 S 10.51 E .84 1429.63S 243.51E 4 S 10.51 E .13 1589.12S 273.10E 18 S 11.23 E .35 1831.13S 319.57E 1119.70 1285.57 1449.79 1611.99 1858.42 ORISINAL F CEIVED S£P 10 199 Alaska Oil & Gas Co s. Committee _¢RY-SI/N DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. KUPARUK RIVER UNIT / 1E-32 500292278800 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/29/97 DATE OF SURVEY: 072597 MWD SURVEY JOB NUMBER: AK-MM-70207 KELLY BUSHING ELEV. = 113.00 OPERATOR: ARCO ALASKA INC. FT. TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 3889.24 2896.95 2783.95 59 59 S 12.24 E .57 4171.77 3040.40 2927.40 58 58 S 11.50 E .42 4451.65 3186.62 3073.62 58 1 S 9.52 E .69 4734.64 3334.51 3221.51 58 57 S 9.02 E .36 4919.44 3429.07 3316.07 59 30 S 10.51 E .75 2068.11S 368.78E 2100.44 2306.29S 418.85E 2343.80 2540.89S 462.39E 2582.40 2778.99S 501.25E 2823.53 2935.45S 528.18E 2982.25 5198.74 3567.03 3454.03 61 17 S 11.27 E .68 5388.04 3659.19 3546.19 60 26 S 12.05 E .58 5757.79 3842.00 3729.00 60 17 S 12.71 E .16 5945.69 3934.45 3821.45 60 45 S 11.98 E .41 6233.40 4075.56 3962.56 60 30 S 11.20 E .25 3173.88S 574.07E 3225.06 '3335.81S 607.48E 3390.39 3649.73S 676.39E 3711.70 3809.52S 711.36E 3875.23 4055.13S 761.73E 4125.94 6513.10 4211.97 4098.97 61 6 S 11.73 E .27 6887.84 4394.44 4281.44 60 36 S 10.72 E .27 7263.72 4583.65 4470.65 58 57 S 13.49 E .77 7634.50 4770.00 4657.00 60 42 S 11.82 E .61 8008.60 4950.71 4837.71 61 31 S 9.68 E .55 4294.43S 810.27E 4370.11 4615.47S 873.99E 4697.40 4933.00S 942.02E 5022.09 5245.69S 1012.19E 5342.43 5567.44S 1073.25E 5669.92 8382.24 5129.11 5016.11 61 25 S 9.54 E .04 8568.17 5221.93 5108.93 58 40 S 11.82 E 1.83 8755.90 5321.19 5208.19 57 29 S 12.87 E .79 8942.41 5419.08 5306.08 59 10 S 13.20 E .92 9127.01 5514.42 5401.42 58 37 S 13.22 E .30 5891.13S 1128.06E 5998.11 6049.42S 1157.86E 6159.18 6205.06S 1191.92E 6318.47 6359.70S 1227.72E 6477.10 6513.59S 1263.84E 6635.06 9405.12 5660.25 5547.25 58 7 S 12.37 E 9594.17 5761.00 5648.00 57 28 S 12.71 E 9687.54 5811.56 5698.56 56 57 S 13.08 E 9779.60 5861.83 5748.83 56 50 S 13.45 E 9873.81 5914.89 5801.89 54 35 S 13.38 E 9942.07 5955.09 5842.09 53 15 S 14.27 E 10120.33 6065.05 5952.05 50 33 S 16.58 E 10216.00 6125.75 6012.75 50 40 S 14.38 E 10359.45 6217.54 6104.54 49 45 S 14.01 E 10445.00 6272.82 6159.82 49 45 S 14.01 E .32 6744.51S 1316.29E 6871.75 .38 6900.65S 1351.02E 7031.66 .64 6977.17S 1368.54E 7110.12 .36 7052.23S 1386.23E 7187.18 .39 7127.93S 1404.29E 7264.94 .22 7181.50S 1417.47E 7320.04 .83 7316.73S 1454.73E 7459.91 .78 7387.99S 1474.46E 7533.62 .68 7494.85S 1501.49E 7643.69 .00 7558.20S 1517.30E 7708.90 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7709.00 FEET AT SOUTH 11 DEG. 21 MIN. EAST AT MD = 10445 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 168.94 DEG. TIE-IN SURVEY AT: 0.00'MD PROJECTED SURVEY STATION AT:10445'MD S. ~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. KUPARUK RIVER UNIT / 1E-32 500292278800 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/29/97 DATE OF SURVEY: 072597 JOB NUMBER: AK-MM-70207 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -113.00 .00 N .00 E 1000.00 994.03 881.03 86.81 S 3.65 E 2000.00 1880.39 1767.39 513.88 S 76.30 E 3000.00 2470.62 2357.62 1302.19 S 219.94 E 4000.00 2952.35 2839.35 2161.84 S 389.11 E .00 5.97 5.97 119.61 113.64 529.38 409.77 1047.65 518.27 5000.00 3469.96 3356.96 3003.70 S 540.85 E 6000.00 3960.99 3847.99 3855.87 S 721.19 E 7000.00 4449.91 4336.91 4711.11 S 892.80 E 8000.00 4946.61 4833.61 5559.99 S 1071.98 E 9000.00 5448.59 5335.59 6407.85 S 1239.01 E 1530.04 482.39 2039.01 508.97 2550.09 511.07 3053.39 503.31 3551.41 498.02 10000.00 5990.09 5877.09 7226.16 S 1429.13 E 10445.00 6272.82 6159.82 7558.20 S 1517.30 E 4009.91 458.50 4172.18 162.27 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S .~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA INC, KUPARUK RIVER UNIT / 1E-32 500292278800 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/29/97 DATE OF SURVEY: 072597 JOB NUMBER: AK-MM-70207 KELLY BUSHING ELEV, = 113,00 FT, OPERATOR: ARCO ALASKA INC, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -113.00 113.00 113.00 .00 213.00 213.00 t00.00 313.02 313.00 200.00 413.24 413.00 300.00 ,00 N ,00 E ,00 ,00 N ,00 E ,00 ,00 ,46 N ,22 W ,00 ,00 ,68 S ,03 E ,02 ,01 7,06 S ,69 E ,24 ,22 513.87 513.00 400.00 614.55 613.00 500.00 715.25 713.00 600.00 816.09 813.00 700.00 917.40 913.00 800.00 18,23 S 1,26 29,97 S 1,75 41,81 S 2,36 54,73 S 2,94 70,85 S 3,20 E ,87 ,63 E 1,55 ,69 E 2,25 ,70 E 3,09 ,84 E 4,40 1,31 1019.40 1013.00 900.00 1122.23 1113.00 t000.00 1226.27 1213.00 1100.00 1332.06 1313.00 1200.00 1440.00 1413.00 1300.00 90,85 S 3,78 114,70 S 5,40 143,23 S 8,14 177,51 S 11,57 217,81 S 16,61 E 6,40 1,99 E 9,23 2,83 E 13,27 4,04 E 19,06 5,78 E 27,00 7,95 1550.11 1513.00 1400.00 1662.80 1613.00 1500.00 1782.17 1713.00 1600.00 1909.25 1813.00 1700.00 2045.58 1913.00 1800.00 263,31 S 23,66 314,49 S 32,35 378,14 S 45,80 454,63 S 62,83 544,94 S 83,30 E 37,11 10,10 E 49,80 12,70 E 69,17 19,37 E 96,25 27,08 E 132,58 36,33 2190,72 2013,00 1900,00 2340,73 2113,00 2000,00 2504,42 2213,00 2100,00 2685,39 2313,00 2200,00 2883,84 2413,00 2300,00 648,12 S 103,59 758,26 S 122,76 885,99 S 144,22 1034,53 S 170,16 1202,99 S 201,70 177,72 45,14 227,73 50,01 291,42 63,69 372,39 80,97 470,84 98,46 3087.04 2513.00 2400.00 3299.38 2613.00 2500.00 3511.87 2713.00 2600.00 3720.18 2813.00 2700.00 3921.33 2913.00 2800.00 1376,94 S 233,74 1561,12 S 267,91 1745,38 S 302,54 1924,61 S 338,13 2095,26 S 374,67 E 574,04 103,19 E 686,38 112,34 E 798,87 112,49 E 907,18 108,30 E 1008,33 101,15 4118.59 3013.00 2900.00 4312.50 3113.00 3000.00 4501.48 3213.00 3100.00 4692.93 3313.00 3200.00 2261,63 S 409,76 2424,45 S 442,74 2582,58 S 469,39 2743.69 S 495,65 E 1105,59 97,26 E 1199,50 93,91 E 1288,48 88,98 E 1379,93 91,45 S. .tRY- SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. KUPARUK RIVER UNIT / 1E-32 500292278800 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/29/97 DATE OF SURVEY: 072597 JOB NUMBER: AK-MM-70207 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4887.78 3413.00 3300.00 2908.63 S 523.21 E 1474.78 94.85 5086.26 3513.00 3400.00 3077.13 S 554.79 E 1573.26 98.48 5294.30 3613.00 3500.00 3256.03 S 590.50 E 1681.30 108.04 5497.11 3713.00 3600.00 3428.58 S 627.29 E 1784.11 102.80 5699.26 3813.00 3700.00 3600.13 S 665.20 E 1886.26 102.16 5901.79 3913.00 3800.00 3772.05 S 703.40 E 1988.79 102.53 6106.32 4013.00 3900.00 3946.62 S 740.24 E 2093.32 104.53 6309.46 4113.00 4000.00 4120.08 S 774.59 E 2196.46 103.14 6515.24 4213.00 4100.00 4296.27 S 810.65 E 2302.24 105.78 6721.88 4313.00 4200.00 4473.39 S 847.09 E 2408.88 106.64 6925.55 4413.00 4300.00 4647.70 S 880.17 E 2512.55 103.67 7125.52 4513.00 44-00.00 4817.26 S 915.36 E 2612.52 99.98 7320.62 4613.00 4500.00 4980.40 S 953.39 E 2707.62 95.09 7518.02 4713.00 4600.00 5146.27 S 991.38 E 2805.02 97.41 7722.36 4813.00 4700.00 5320.68 S 1027.88 E 2909.36 104.34 7929.50 4913.00 4800.00 5498.89 S 1061.56 E 3016.50 107.14 8139.27 5013.00 4900.00 5680.67 S 1092.56 E 3126.27 109.78 8348.56 5113.00 5000.00 5861.96 S 1123.15 E 3235.56 109.28 8550.91 5213.00 5100.00 6034.95 S 1154.87 E 3337.91 102.35 8740.67 5313.00 5200.00 6192.54 S 1189.06 E 3427.67 89.76 8930.53 5413.00 5300.00 6349.77 S 1225.39 E 3517.53 89.87 9124.28 5513.00 5400.00 6511.32 S 1263.31 E 3611.28 93.75 9315.66 5613.00 5500.00 6670.30 S 1300.02 E 3702.66 91.38 9504.90 5713.00 5600.00 6827.24 S 1334.46 E ~791.90 89.25 9690.18 5813.00 5700.00 6979.33 S 1369.04 E 3877.18 85.28 9870.54 5913.00 5800.00 7125.34 S 1403.67 E 3957.54 80.36 10037.28 6013.00 5900.00 7254.53 S 1436.86 E 4024.28 66.73 10195.88 6113.00 6000.00 7372.91 S 1470.59 E 4082.88 58.60 10352.42 6213.00 6100.00 7489.64 S 1500.19 E 4139.42 56.54 10445.00 6272.82 6159.82 7558.20 S 1517.30 E 4172.18 32.76 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 10/14/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11439 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk ,, 1 E-32 .C.~.'~ . i.':,-.,~-. ,.~, b~-. CBL 970828 1 1 3K-26 ~1'"! '~ (5"-~""1 CEMENT MAPPING TOOL 970722 I 1 ,, 3K-30 ~.v/.._ I1.~ CEMENT MAPPING TOOL 970721 1 1 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: OCT 1 5 1997 0 F:t I L.I-- I IM CS WELL LOG TRANSM1TFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs September 24, 1997 1E-32, AK-MM-70207 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Yn'n Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22788-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Ino. Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 19, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1E-32 (Permit No. 97-132) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1E-32. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Development · DKP/skad September 2, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 q q/ Re' MWD Survey 1E-32 Dear Sir/Madam, Enclosed is two hard copy of the above mentioned file(s). Well 1E-32 MWD survey Tie-In point at 0.00 and a Projected survey at 10445'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. SEP 10 1997 Alaska O~l & Gas Cons. C, ommis.sior~ Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska_ 99510-0380 Yeiepho~e 907 276 12!5 July 24, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1E-32 Dear Mr. Commissioner: Enclosed please find a LOT plot, cementing detail and the casing detail sheets for Kuparuk Well 1E-32. These forms are to satisfy AOGCC's request for information on this well prior to ARCO beginning annular disposal operations. Rig operations which occurred after those discussed in the Cementing Details, but which pertain to the surface cementing success: · On the second stage of the cement job, the rig was unable to bump the plug against the stage tool (as described in Cementing Details). 15 bbls displacement fluid were pumped over the calculated required casing volume. At this point the rig stopped pumping, as the first stage displacement volumes had been accurate. Further pumping would displace cement in the surface annulus. · The rig waited a few hours for cement to begin setting. They nippled up and tested the BOPE. · When running in with a bit, the rig tagged the plug 15' above the top of the stage tool. There should have been some amount of contaminated cement on top of the plug; there was not, indicating that the rig had pumped by the plug during cementing operations. The rig pressured up against the plug to perform the standard pressure test prior to beginning any operations on the stage tool. The plug was pumped 15' downhole to land in the closing profile, and the rig was able to pressure up against the plug and close the stage tool. The equipment was subsequently drilled out and tested with no problems. If there are any questions, please call 263-4183. Sincerely, D. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad cc: Blair Wondzell AB3B-6003-93 242 2603 CASING AND LEAK-OFF FRACTURE TESTS Well Name: Supervisor: KRU 1 E-32 Date: 7/21/97 Donald Lutrick 9 5/8", 40.0#, L-80, BTC Casing Size and Description: Casing Setting Depth: Mud Weight: 8.45 6 01 6 TM D 3969' PPg EMW = Leak-off Pressure (PLO) 0.052 x TVD LOT = 1000 psi/(0.052 x 3969 ft) + 8.45 ppg = 13.3 ppg Fluid Pumped = 2.2 bbls. TVD + MW Hole Depth (md)= 4897' Pump output -- .101 bps 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 ~,lask.-: 0i-& ~,nchor -- -- ' -- LEAK-OFF TEST } --~!-- CASING TEST ~/ 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 STROKES ARCO Alaska, Inc. Cementing Details Well#: 1.00E-32 Field: KUPARUK Date: 7/1 9/97 Casing Size Hole Diameter Hole Angle Shoe Depth Float Depth J % washout 9 5/8" 12.25" 70° 6,016' 5,927' I Centralizers State type used, intervals covered and spacing7 30 Gemco centralizers.l-28 I on each jt above and below cementer 1 on each side of cementer Mud Weight YP(prior cond) YP(after cond) I PV(prior cond) PV(after cond) 1 0.0/9.7 18 lbs/100 ft2 11 lbs/100 ft21 20 cP 11 cP Gels before Gels after Total Volume Circulated 6/8 4/5 750 bbls Spacer Type Volume Weight Water 50/20 8.3 PPG Lead Type IMix wtr temp No. of sacks Weight Yield Cement ASLW I 60 230/322 10.5/10.5 4.41 STAGE 1/2 Additives G + 3.5% DO44, .6% D©46, 30% D53, 1.5% DO79, 50% D124, 1.5% SO©1 Cement G/AS 1 60 700/60 15.8/15.8 1.15/0.93 STAGE 1/2 STAGE 1: G, 2.66% DO29, .2% DO46, .3% DO65, 1% SOO1 STAGE 2: ASI Displacement Rate(before tail at shoe) Rate(tail around shoe) Str. Wt. Up 9 9 320k Reciprocation length 15 Theoretical Displacement 446/1 63 Reciprocation speed 10 fpm Actual Displacement 451/178 STAGE 1/2 Bumped plug Floats held yes/no yes/n/a Str. Wt. Dn. 120k Str. Wt. Mud Calculated top of cement CIP 7/18/97 2500'/surface 04:30 / 01:50 Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. ,~tage 1' Reciprocated csg until cement rounded shoe. Circ 750 bbls mud w/no loss. Pumped lead and tail slurries. Displaced w/ rig pumps. Had 100% returns through out entire job. bumped plug. check floats. Load closing plug. Stage 2: Press csg to 3800 psi to open cementer. Circ 450 bbls mud w/full returns. Had contaminated mud and cement in returns. Circ until clean. Pumped 2nd stage lead and tail slurries w/ 100% returns through out entire job. Pumped 253 bbls lead cement. Switch to tail. Displace w/ rig pumps. 10.5 cement to surface. Pumped 15 bbls over calculated displacement. Plug did not bump. Shut in csg. Check surface equipment. WOC Cement Company I Rig Contractor Dowell I Parker JSignature Donald Lutrick CASING / TUBING / LINER DETAIL ARCO ALASKA /Subsid/ary of Atlantic R/chfield WELL: 1E-32 DATE: 7/17/97 PAGE 1 of 1 # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH 9 5/8" SURFACE CASING TOPS Above RKB -3.87 Landing Joint 45.00 -3.87 9 5/8", 40#, L-80 Fluted mandrel hanger 1.52 41.1 3 47 Jts 9 5/8", 40#, L-80, BTC, R-3, Class ^ 2070.41 42.65 B Jt 9 5/8", 40~, L-80, BTC, R-3, Class A-BakerLocked 37.02 2113.06 Gemeco 754 PDC Stage Tool 1.79 2150.08 A Jt 9 5/8", 40#, L-80, BTC, R-3, Class A-BakerLocked 43.31 2151.87 83 Jts 9 5/8", 40#, L-80, BTC, R-3, Class A 3684.95 2195.18 1 Jt 9 5/8", 40#, L-80, BTC, R-3, Class A 46.43 5880.13 Gemoco 9 5/8" Float Collar 1.52 5926.56 2 Jts 9 5/8", 40#, L-80, BTC, R-3, Class A 86.21 5928.08 Gemoco 9 5/8" Float Shoe 1.71 6014.29 Shoe set @ 6016.00 Gemeco Cementer and lock Jts (A & B)between jt # 86 and #87 TD = 6026.00 PBTD= 5880.13 RATHOLE = 10.00 I Parker 245 RKB to Wellhead = 41.1 5 FLUTED HANGER GOES IN TOP OF JT. #133 **Jts 134 through 147 (14 its.) stay in the shed ** BAKER-LOCK TO TOP OF BAFFLE COLLAR JT. National lead free mod. (BOL 2000) TORQUED TO BASE OF TRIANGLE (avg 9000 R-Lbs) RAN: 30 Bow spring centralizers Jt #1 - 28 JtA- B RIG SUPERVISOR: Donald Lutrick MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David J o...bJ~, Chairm~ DATE: July 19, 1997 TFIRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor FROM: Chuck Scheve ~- ~ SUBJECT: Petroleum Inspector aaxkgsee.doc BOPE Test Parker 245 ARCO / KRU / 1 E-32 PTD - 97-132 Saturday July 19~ 1997: i traveled to ARCO's Kuparuk River Unit to witness the BOPE Test on Parker Rig 245. The AOGCC BOPE Test Report is attached for reference. The choke was tested while waiting on the surface cement job to set up. I was not able to witness this portion of the BOPE Test, I was given the opportunity to review the chart and found the test to be OK. The rest of the test went quite well lasting two hours with no failures. ! found the rig to be clean and appeared to be in very good shape. The location was well organized allowing good access to all areas of the rig. Summary: i witnessed the initial BOPE Test on Parker 245 Drilling Well 1 E-32 Parker 245, 7/19197, Test Time 2 hours, 0 failures Attachments: aaxkgsee.xls X Unclassified Confidential (Unclassified if document removed) Confidential Author: Dave Johnston at DOA-AOGCC Date: 7/14/97 2:24 PM -~-~. r Priority: Normal TO: Shelly Hebert Subject: Re: Ven. mtg Message Contents No meeting, I need to see my dentist again at 3:00. Please let them know that their participation is welcomed. We should have a free flowing dialog. If they have comments, they are encouraged to speak _ up. I don't see any need for prepared statements, etc. Although I may ask them to help out with a topic, as appropriate. Reply Separator Subject: Ven. mtg Author: Shelly Hebert at DOA-AOGCC Date: 7/14/97 1:09 PM Two C's - Jack Hartz, Blair Wondzell (maybe), Howard Okland and Wendy Mahan would like to participate in the meeting tomorrow morning. Please advise if you want a meeting this afternoon with these people. Thanks, Diana TONY KNOWLE$, GOVERNOR ALASK& OIL AND GAS CONSERVATION COMMISSION July 14, 1997 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Michael Zanghi, Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1E-32 ARCO Alaska, Inc. Permit No. 97-132 Sur. Loc. 190'FSL, 816'FEL, Sec. 16, TllN, R10E, UM Btmhole Loc. 2147'FNL, 673'FWL, Sec. 28, T1 IN, R10E, UM Dear Mr. Zanghi: 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. This approval includes annular disposal of drilling wastes and is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT) - cementing records, FIT data, and any CQLs are to be submitted to the Commission prior to the start of disposal operations. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by ccor3me~ the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson Commissioner BY ORDER OF THE COMMISSION dlffEnclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK/--~ ...,L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC P__,~.005 ia. Type of Work Drill X Redrill [] I 1 b Type of Well /'Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen []I Service X Development Gas [] Single Zone X ,-'"/Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41' Pad 72' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25660, ALK 2560 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 190' FSL, 816' FEL, Sec. 16, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1960' FNL, 632' FWL, Sec. 28, T11N, R10E, UM 1E-32 #U-630610 At total depth 9. Approximate spud date Amount 2147' FNL, 673' FWL, Sec. 28, T11N, R10E, UM 7/1 4/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1E-17 10508' MD 632' @ Tar~let feet 12.2' @ 300' feet 2560 6280' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 60.16° Maximum surface 2357 psig At total depth (TVD) 4000 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 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 40.0# L-80' LTC 5995' 41' 41' 6036' 3981' 1820 Sx Arcticset III & HF-ERW 560 Sx Class G "'~.5" 7" 26.0# L-80- BTCMOE 10091 41' 41' 10132' 6017' 80SxClassG 6.125" 4.5" 12.6# L-80 NSCT 576' 9932' 5931' 10508' 6280' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) ,JUL true vertical feet Effective depth: measured feet Junk (measured) Alaska Oil & Gas Cons. 60rnmission true vertical feet Anchorage Casing Length Size Cemented Me as u red ~1~1~ 1¢~' ~l,,~ ~-r~VL~'tt~"~ de pth Structural Conductor Surface IntermediateJUL 0 Production Liner Alaska 0il & Gas Cons. C0mmissi0rl Perforation depth: measured Anchoran¢. true vertical 20. Attachments Filing fee X Property plat E] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Drill Site Develop. Supv. Date '7// For questions, please call Denise Petrash Commission Use Only Permit ,umbe,~..~.,../,,..~.2.. IAPl number50- O-~-.,-? --' ,,~ ~ ~ ~2' ~2' IAppr°val date 7--1~7~'~ ~ ISee c°ver letter f°rother requirements Conditions of approval Samples required ~ Yes ~ No Mud Icg required BI Yes [] No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~] Yes E~ No Required working pressure for BOPE [-1 2M r~ 3M ~ 5M E~ 1OM [-1 15M Other: ORIGINAL SIGNED BY by order Of Approved by Ro~rt N. Christenson Commissioner the commission Date IZnrm 1(I-4(31 I~nu 7.74-RCl .q~,hmit in trinlinntn GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 1 E-32 1. Move in and rig up Parker #245. 2. Install diverter system. . Drill 12.25" hole to 9-5/8" surface casing point (6,036')according to directional plan. , , Run and cement 9-5/8" casing, using stage collar placed at least 200' below the base of the permafrost, and light weight lead cement. Install and test BOPE to 5000 psi. Test casing to 2000 psi. . Drill out cement and 10' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 7. Drill 8.5" hole to intermediate TD (10,132') according to directional plan. 8. Run and cement 7" intermediate casing string. Note: . If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Test breaks in BC)PE to 5000 psi. Test casing to 3500 psi. 10. Drill out cement and 10' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 11. Drill 6-1/8" hole to total depth (10,508') according to directional plan. 1 2. Run open hole evaluation logs or LWD tools as needed. 13. i, · 14. 15. Run and cement 4-1/2" NSCT liner with Baker liner-top packer and hanger. Hydraulically set packer +200' inside surface casing shoe to provide appropriate liner lap. A ~,..~.1:;1^ ,,.,|11 [-,,.., r, ,r, '71"1 ....... ~.j ........ H ............. [., .......~ ..... [~ .....i~ ...................... jj ..... + h~, brought ,,,~,h~,~ ~nn, ,-,f ,,,,, f,,+ ....... f,',r~tlnn Pressure test liner to 3500 psi.~' Run completion assembly. Sting into polished seal bore with seal assembly pressure test tubing and annulus. 1 6. ND BOPE and install production tree. 17. 18. Shut in and secure well. ~-r".I2s!"~ 0ii & Ga,,; 0o,,;s. ~ ~ '- ' - Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: As a dedicated injector, cased hole cement bond logs (SLT-J or CBT) will be run to establish isolation after the cleanout is completed, but prior to perforating. DRILLING FLUID PROGRAM Well KRU 1E-32 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-4O 10-12 9.5-10 _+10% Drill out to 7" interm, casing 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes- Drill out to TD 12.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,357 psi could be reached. Maximum anticipated surface pressure is calculated using a intermediate casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3,562 psi could be reached. Therefore, ARCO Alaska, Inc. will do a one-time test of the BOP equipment to 5000 psi, retesting only broken flanges or after 7 day limit. The nearest existing well to 1 E-32 is 1 E-17. As designed, the minimum distance between the two wells would be 12.2' @ 300' MD. Drilling Area Risks: Risks in the 1E-32 drilling area include lost circulation and high pressures in the Kuparuk formation. Both are addressed by setting intermediate casing above the Kuparuk. Careful analysis of pressure data from offset wells shows that a mud weight of 1 2.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" and 7" casing shoes will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 1E-32 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. (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 1E-32 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1 E-32 be permitted for annular pumping occurring as a result of drilling'"~ operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation J markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set +200' vertical below the base of the West Sak into the heart of the shales, The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AC)GCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3984 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 . BTC 3090 2627 5750 4888 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). C :iVFD A~hora~o ARCO ALASKA, Inc. Pad 1E 32 slot #32 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref = 32 Version #5 Our ref = prop2144 License ~ Date printed : 19-Jun-97 Date created : 31-Mar-97 Last revised : 19-Jun-97 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 35 26.769 Slot location is nT0 18 3.184,w149 35 50.559 Slot Grid coordinates are N 5959775.600, E 549711.015 Slot local coordinates are 190.00 N 816.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath C(34) Version #3,,C(34),Pad 1E D(35) Version #1,,D(35),Pad 1E GMS <0-7420~>,,24,Pad 1E G~MS <0-7512~>,,12,Pad 1E ~MS <0-7750'>,,13,Pad 1E GMS <O-7190'>,,14,Pad 1E G~MS <O-8435~>,,15,Pad 1E G~MS <0-7715~>,,16,Pad 1E ~ <O-7885~>,,17,Pad 1E G~MS <O-8150~>,,18,Pad 1E GMS <O-7898~>,,19,Pad 1E GMS <0-8650'>,,20,Pad 1E GMS <0-7420~>,,21,Pad 1E ~MS <0-9480~>,,22,Pad 1E GMS <0-8350~>,,23,Pad 1E G~MS <0-7467~>,,25,Pad 1E GMS <0-8017~>,,26A, Pad 1E MSS <2370-3605'>,,26,Pad 1E GMS <0-6800~>,,27,Pad 1E G"~S <O-7665~>,,28,Pad 1E G~S <0-6835'>,,29,Pad 1E G~MS <0-7310'>,,30,Pad 1E TOTCO Survey,,WS-2,Pad 1E GMS <O-7310'>,,1A, Pad 1E MSS <2819-7345~>,,1,Pad 1E Closest approach with 3-D Minimum Distance method Last revised Distance 6-May-97 6-May-97 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 480.2 234.1 559.1 612.8 492.8 373.0 252.7 132.9 12.2 684.1 655.1 631.9 612.5 599.4 591.1 580.0 170.0 161.7 82 7 107 8 75 3 143 0 1975 8 179 0 179 0 M.D. Diverging from M.D. 300.0 300.0 280.0 280.0 1275.0 1275.0 300.0 300.0 300.0 300.0 20.0 20.0 180.0 180.0 300.0 300.0 300.0 300.0 20.0 20.0 260.0 260.0 20.0 300.0 20.0 325.0 325.0 325.0 160.0 160.0 1375.0 10508.2 2840.0 2840.0 2960.0 2960.0 2050.0 2050.0 2019.0 2019.0 1850.0 1850.0 1550.0 1550.0 3880.0 3880.0 580.0 580.0 580.0 580.0 G~MS ¢O-8440'>,,2,Pad 1E G~MS ¢0_8905~>,,3,Pa~ 1E GMS <0-9150~>,,4,TM 1E GMS <0-7195~>,,5,TM 1E GMS <0-9837~>,,6,TM 1E G~S (0-9310~>,,7,TM 1E ~S <0-7590~),,8,TM 1E GMS ¢0~7000~,,9,TM 1E GMS ¢0~7811~>,,10,TM 1E GMS ¢0-8754~>,,11,TM 1E D-P2(33) Version ~4,,1D-P2,P&d 1E 31 Version #10,,31,Pa~ 1E 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 16-Ju~-97 10-Jun-97 207.4 288.0 323.7 497,9 611.4 726,5 841.9 973.0 850.8 733.0 590.8 360.0 300.0 300.0 1625.0 300.0 20.0 325.0 325,0 20.0 325.0 20.0 600.0 300.0 300,0 300.0 1625.0 300,0 20.0 325,0 325.0 20,0 325,0 20.0 600.0 8333.3 500 5OO 1000 1500 2000 2500 (~ 3000 ,_ (D 3500 >. 4000 450o 5000 55OO 6000 650O ARCO ALASKA, Inc. Structure : Pad 1E Well : 32 Field : Kuparuk River Unit Location : North Slope, Alaska Creoled by finch For: D PETRASH [~te p~tted : 19--Jun--97 I Plot Reference is 32 Version ~5. ! 68.94 AZIMUTH 7571' (TO TARGET) ***Plsne of Proposol*** RKB ELEVATION: 113' KOP TVI]=~O0 TMD=300 DEP=O 3.00 END INITIAL ANGLE BUILD TVD=466 TMD=467 OEP=7 CONTINUE BUILD & TURN TO TARGET TVD=799 TMD=800 DEP=36 5OO 0 I I I SURFACE LOCATION: 190' FSL, 816' FEL SEC. 16, T11N, RIOE East (feet) -> 500 1000 1500 End Initial Angle Build Continue BuilF:l & Turn to Target Bose Permafrost EOC TARGET LOCATION: 1960' FNL, 632' FWL SEC. 28, T11N, RIOE TARGET TVD=6120 TMD=10259 DEP=7571 Top West Sok Sands WSlO (B/ West Sok) 7 5/8 Casing Companion SS 7.96 SOUTH 7430 .... 1452 ~F~ ~' ,~? r-.,l~. ~'~,.~ 4500 k 19.92 DLS: 3.00 deg per 100 ft )~ [*; ~, 25.91 57.91 B/ PERMAFROST WD=1845 TMD=1944 DEP=459 '-' 43.90 ~ .'--'r 't ~ 49.90 _ , ~,; ~ ~'~,~r, ('qqS ~/~[)'!~'HIUblu~ 5500 % I TD LOCATION: ~ I 2,47' FNL, ~7~' ~L I SEC. 28,M T11N, RIOE I C40 (K-5) 60. t 6 ~ Beg~n Angle Drop~ 7000 ~SlO (~ ~ s,~) ~~ T~e=~~a4% ~os~ ~,z~ ~ 5/8~~5/8" cso PT ~D=5981 ~6~6TMD=5056 DEP=Sg55~ ~ ...... ~%t ~r~ DEP=3933~ m~bcm - m/ ~D~O TMD=~6 ~P=4514~ Top C1 ~ ~ ~ 7500 TD - Casing Pt 8000 L _ . ~" DLS: 2.00 deg per 59.19 55.19 51.19 TARGET ANGLE vCl. WD=6182 TMD=10356 OEP=7645 v ~ ~o=~1~ TMO=lO;~ ~,=~ 50 DEG ~¢ 4q~' T,-CS~,T T~=6~SO T~=tO~O. 2O00 i ( 500 0 5O0 1000 1500 2000 2500 3000 0 3500 4000 I v 1 O0 ft I I I I I I I I I I ; i i ! i i i i i i i r i i i t i i i ] i i T i 0 500 1000 1500 2000 2500 5000 5500 4000 4500 5000 5500 6000 6500 7000 7500 8000 Vertical Section (feet) -> Azimuth 168.94 with reference 0.00 N, 0.00 E from slot //32 8500 Ic~o~ ~ n.=~ For: D PETRASH] Do~e plotted : 19-dun-97 / Plot Reference is 52 Version ~45. / Caordinotes are in feet r~erence spot ~52. J AkCO ALASKA, ]fnc. 24O 280 320 360 Structure : Pad 1E Well : 52 Field : Kuperuk River Unit Location : North Slope, Alasko East (feet) -> 280 24-0 200 160 120 80 4-0 0 40 80 120 160 200 240 280 320 360 4OO 40 O0 "~ 2300 40 / ~ 7 '", ~oo 2600/ // ~ o o ~ .¢'~ 300 ,, ~o.~/ i.~o R ,q~oo ',,, ? 1500 ~ '"', 80 120 , ?x2r~ 120 ~ i~ ~°° ~' 28oo ! ~6oo 18og', soo i?O0 700 200 200 ~ "~ 900 ~ ~% 190( ",,,1000 , 900 ' "~, 11 O0 500 ', 400 200C I '"' 76~00 500 ' i '.,, 1200 ] 5900 i 1 600 ", ~ ssoo ~,> l?oo : ~ oo 'k ~ 300 , 1800 ,~, ; ; 400 5600 \ 300 220( ',, 400 5500 ~eO0 400 ~ t 400 440 ~400 ~00 ~1~ 440 2300 · 48O 1 ~00 4gO _~ 520~ 2400 51 O0 3600 520 52O 5000 24OO ~ 4900 i 4700 5~0 1800 ', ~500 5t50 2500 6OO 21500 ~00 640 2700 [ 640 2800 '" 68O ',, ~700 68O ~ 2700' 250 240 200 160 120 80 40 0 40 80 120 160 200 240 280 320 360 East (feet) -> 240 0 280 --i- 520 --I- 360 1 F_.-32 Injector Completion, I. 3-1/8" 5M FMC tubing hanger with 3-1/2" L-80 EUE 8rd pin down. H. 3-1/2", 9.3#, L-80 EUE 8rd MOD tbg to surface. G. 3-1/2" CAMCO 'DS' landing nipple with 2.812" ID No-Go profile set at_+500' 6' L-80 flow coupling made-up on bottom & 6' L-80 handling pup on top. Surface csg: 9-5/8" 40# L-80 BTC F. 3-1/2", 9.3#, L-80 EUE 8rd Mod tubing to 'DS' landing nipple. E. 3-1/2" x 1-1/2" CAMCO 'MMM' mandrel w/dummy valve & RK latch. Set @ 2000' TVD. 6' L-80 handling pups installed on mandrel. D. 3-1/2", 9.3#, L-80 EUE 8rd Mod tubing to GLM. Top of Liner @ _+995O' MD Intermediate csg: 7" 26# L-80 BTC-Mod set above Kup (_+10150' MD) C. 3-1/2" Baker 'CMU' sliding sleeve w/2.75" ID Camco 'D' No-Go profile (run in closed position). 6' L-80 handling pup installed on top and 4' or 6' pup on bottom. B. 1 jt 3-1/2" L-80 EUE 8rd MOD tbg. A. Baker 3-1/2" seal assembly w/15' of seals and special Iocator to locate in liner tieback sleeve. Locator 5.125" OD, seals 4.0" OD. 6' L-80 handling pup installed on top. Liner packedhangedPBR assembly: · 6' C-2 tieback sleeve with Iocator · ZXP mechanical liner-top packer · HMC hydraulic liner hanger · 17' PBR w/4" ID and XOto 4-1/2" NSCT Liner run on 3-1/2" 15.5# G105 drillpipe w/3-1/2" IF connections. Future Thru-Tubing C Sand Perforations Liner: 4-1/2" 12.6# L-80 NSCT (+_10780' MD) 4-1/2" NSCT landing colladFS/FC DKP 06/11/97 KuPARUK RIVER UNIT 20" DIVERTER SCHEMATIC 6 I4 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , MAINTENANCE & OPERATION 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. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 13 5/8" 5000 PSISTACK 7 6 5 4 3 1. 16"- 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"-5000 PSI VARIABLE PIPE RAMS 5. 13-5/8" - 5000 PSi DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 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 AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 3000 PSI ONLY. 5. OPEN ANNULAR PREVENTOR 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 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOWAND 5000 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 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI 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 ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PSI HIGH · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~',~_ .,/'~:) ~ INIT CLASS WELL NAME/~/~f/ //~-- ~ PROGRAM: exp [] dev [] redrl, [] serv~;~ellbore segU ann. disposal para req .~,.. OEOk AREA ~? (::::3 UNIT# I?.,/,~'0 / ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING A,a~~DAT~ L IN GEOLOGY REMARKS 14. Conductor string provided ................... (,,~NN 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. I'~1 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. ./ 23. If diverter required, does it meet regulations .......... trJ,-' v 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ...... ~-.._ ....... N 26. BOPE press rating appropriate; test to ,z2~ psig. N ('W-',/ 27. Choke manifold complies w/APl RP-53 (May 84) ........ N V 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. N 30. Permit can be issued w/o hydrogen sulfide measures ..... Y 31. Data presented on potential overpressure zones ....... ~(//N //(/~,/'"/ 32. Seismic analysis of shallow gas zones ............. ~Y N / 33. Seabed condition survey (if off-shore) ........... .~. Y N 34. Contact name/phone for we,eklyj3ro¢lress reports .... /(.. Y N lexp~ora~ory only] GEOLOGY: ENGINEERING: COM~~-- R,[~~ BEW ~O(_.,t~7'lq::: DWi,z Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 07/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part .of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Tue Sep 16 12:04:05 1997 Reel Header Service name ............. LISTPE Date ..................... 97/09/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... LTNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/09/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API AK3M~ER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 2 AK-MM-7 02 07 B. HENNINGSE D. LUTRICK ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: ,SEP 2 6 ~99 Aiask~ Oil & Gas r..;onso An,~ora9~ 1E-32 500292278800 ARCO ALASKA, INC. SPERRY-SLfN DRILLING SERVICES 16-SEP-97 MWD RUN 3 AK-MM-7 0207 K. FERGUSON J. TRANTHAM 16 lin 10E 190 816 L ~ '. .... ,,..., . kJ ~ ..' .00 112.80 71.70 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 6016.0 8.500 7.000 10004.0 6.125 10445.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) . 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND DENISE PETRASH OF ARCO ALASKA, INC. ON 04 SEPTEMBER 1997. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10445'MD, 6273'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. 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 ....... 97/09/16 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: FILE StIMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX .5000 START DEPTH 5975 0 6018 0 10000 0 10000 0 10000 0 10000 0 10000 0 STOP DEPTH 10370 5 10444 5 10378 0 10378 0 10378 0 10378 0 10378 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 2 6018.0 10001.0 3 10001.0 10445.0 MERGED MAIN PASS. $ 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 ...................... -999.25 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 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 RPX MWD OHlViM 4 1 68 12 4 RPS MWD OHI~I~ 4 1 68 16 5 RPM MWD OHPIM 4 1 68 20 6 RPD MWD OHPIM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NaRIs DEPT GR ROP RPX RPS RPM RPD FET Min 5975 30 8919 12 3053 1 4413 1 1805 1 4733 1 5049 0 6824 FirSt Max Mean Nsam Reading 10444.5 8209.75 8940 5975 428.1 119.436 8792 5975 817.671 205.655 8854 6018 2000 24.3135 757 10000 2000 26.7176 757 10000 2000 28.4095 757 10000 2000 24.4931 757 10000 71.7486 3.36009 757 10000 Last Reading 10444.5 10370.5 10444.5 10378 10378 10378 10378 10378 First Reading For Entire File .......... 5975 Last Reading For Entire File ........... 10444.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/16 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 ....... 97/09/16 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5975.0 ROP 6018.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MLAXIMUMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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): STOP DEPTH 9958.0 10001.0 21-JUL-97 ISC 5.06 CIM 5.46/SP4 5.03 'MEMORY 10001.0 6018.0 iO00i.~ 53 .3 61.5 TOOL NUMBER P0791CG6 8.500 8.5 LSND 171.20 50.0 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.8 6OO 7.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 50.1 Name Min Max Mean Nsam DEPT 5975 10001 7988 8053 GR 39.4475 428.1 122.546 7967 ROP 20.9732 817.671 218.37 7967 First Reading 5975 5975 6018 Last Reading 10001 9958 10001 First Reading For Entire File .......... 5975 Last Reading For Entire File ........... 10001 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/16 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 ....... 97/09/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUI~BER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9955.0 10370 5 ROP 9996.0 10444 5 FET 10000.0 10378 0 RPD 10000.0 10378 0 RPM 10000.0 10378 0 RPS 10000.0 10378 0 RPX 10000.0 10378 0 $ LOG HEADER DATA DATE LOGGED: 25-JUL-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 49.7 MAXIMUM ANGLE: 50.7 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: ISC 5.O6 CIM 5.46/SP4 5.03 MEMORY 10445.0 10001.0 10445.0 TOOL NUMBER P0669SP4 P0669SP4 6.130 6.1 LSND 250.00 5O.0 8.5 MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHPS~) 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5OO 3.8 3.500 2.237 3.000 4.000 .6 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 3 AAPI 4 1 68 RPX MWD 3 OHI~4 4 1 68 RPS MWD 3 OHHM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 ROP MWD 3 FT/H 4 1 68 FET MWD 3 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 ' 24 28 8 53 .9 Na/ne DEPT GR RPX RPS RPM RPD ROP FET Min 9955 30 8919 1 4413 1 1805 1 4733 1 5049 12 3 053 0 6824 Max Mean Nsam 10444.5 10199.8 980 279.904 89.261 832 2000 24.3135 757 2000 26.7176 757 2000 28.4095 757 2000 24.4931 757 217.338 91. 6759 898 71.7486 3.36009 757 First Reading 9955 9955 10000 10000 10000 10000 9996 10000 Last Reading 10444.5 10370.5 10378 10378 10378 10378 10444.5 10378 First Reading For Entire File .......... 9955 Last Reading For Entire File ........... 10444.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/09/16 Origin ................... STS Tape Name ................ LrNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/09/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library.~ Library. Scientific Scientific Physical EOF Physical EOF End Of LIS File