The URL can be used to link to this page

Home My WebLink About201-227ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 29, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1E-114 50029232230000 204-171 1R-36 50029230570000 201-227 T40513 T40514 By Gavin Gluyas at 9:47 am, Jun 02, 2025 1R-36 50029230570000 201-227 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 1L-03A 50-029-21182-01 199037_1L-03A_HEX Plug_17Jul2022 199037_1L-03A_RBP_03Apr2022 199037_1L-03A_WFL_04Jan2023 1L-28 50-029-22951-00 199098_1L-28_LDL_29May2022 1Q-01 50-029-21247-00 184231_1Q-01_IPROF_09Jan2023 1Q-05 50-029-21233-00 184217_1Q-05_HEX Plug_18Jul2022 1R-07 50-029-21332-00 185072_1R-07_LeePPROF_14Jan2023 1R-19A 50-029-22185-01 191085_1R-19A_SBHPS CUT_18Jun2022 1R-36 50-029-23057-00 201227_1R-36_IPROFWFL_30Jun2023 1Y-19 50-029-22391-00 193107_1Y-19_PPROF_26Mar2022 1Y-32 50-029-21854-00 188093_1Y-32_PPROF_27May2023 2A-14 50-103-20040-00 185145_2A-14_LDL_23May2023 2A-19A 50-103-20197-01 201083_2A-19A_CHC_20Feb2023 5of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38351 T38352 T38353 T38354 T38355 T38356 T38357 T38358 T38359 T38360 T38361 2/29/2024 1R-36 50-029-23057-00 201227_1R-36_IPROFWFL_30Jun2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:38:59 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1R-36 KUPARUK RIV UNIT 1R-36 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 1R-36 50-029-23057-00-00 201-227-0 W SPT 6492 2012270 1623 2510 2511 2524 2543 530 640 640 640 4YRTST P Austin McLeod 5/5/2023 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 1R-36 Inspection Date: Tubing OA Packer Depth 1045 1900 1870 1870IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230506183936 BBL Pumped:1.5 BBL Returned:1.5 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.02 11:10:37 -08'00' MEMORANDUM TO: Jim Regg 72g'I19 P.I. Supervisor Iff FROM: Adam Earl Petroleum Inspector Well Name KUPARUK RIV UNIT 1R-36 IOsp Num: mitAGE190510092831 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 20, 2019 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. IR -36 KUPARUK RIV UNIT IR -36 Sre: Inspector Reviewed By: P.I. Supry 16P NON -CONFIDENTIAL Comm API Well Number 50-029-23057-00-00 Inspector Name: Adam Earl Permit Number: 201-227-0 Inspection Date: 5/8/2019 ' Monday, May 20, 2019 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IR -36 - Type lnj w • TVD 649z Tubing 2-421-4'-8 '41� 2408 - PTD 2012270 Type Test SPT Test psi 1623 -IF IA 510 11115 1875 - 1860 - - - - BBL Pumped: 19 BBL Returned: I.8 OA iso =10 sw - 510 - Interval 4vRTST P/F P Notes: MIT IA ' Monday, May 20, 2019 Page 1 of 1 illiTE OF ALASKA KRU 1R-36 AMKA OIL AND GAS CONSERVATION COMAION • • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown 1- Performed: Performed: Suspend r Perforate r Other Stimulate E Alter Casing rChange Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well E OtherHPBD 17 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 201-227 3.Address: F 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service50-029-23057-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25635,25628 KRU 1 R-36 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): n/a Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 12700 feet Plugs(measured) None true vertical 6973 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 12132 true vertical 0 feet (true vertical) 6491 Casing Length Size MD TVD Burst Collapse CONDUCTOR 117 16 158 158 0 0 SURFACE 7378 9 5/8 7419 41452 0 0 PRODUCTION 12627 7 12665 6943 0 0 a Perforation depth: Measured depth: 12284-12298, 12442-12460, 12460-12480, 12504-12510 RECEIVED True Vertical Depth: 6619-6631, 6753-6768,6768-6785,6805-6811 JAN2 0 OGCCTubing(size,grade,MD,and TVD) 3.5, L-80, 12151 MD, 6507 ND A Packers&SSSV(type,MD,and ND) PACKER-BAKER SAB-3 PACKER @ 12132 MD and 6491 ND NIPPLE-CAMCO DS LANDING NIPPLE w/NO GO PROFILE @ 512 MD and 512 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 265 1020 2075 Subsequent to operation 0 0 625 1250 2175 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r'', Development r Service F Stratigraphic 1- Copies Copies of Logs and Surveys Run 1- 16.Well Status after work: Oil r Gas r WDSPL 1- Printed Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ F WAG r GINJ r SUSP r SPLUG r 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: 314-609 Contact Mike Hazen@265-1032 Email Michael.C.Hazen@conocophillips.com Printed Name Mike Hazen Title Staff Wells Engineer _ / Signature ^ _,� Phone:265-1032 Date J I 1\f•) b Vn. z/1q/JG Form 10-404 Revised 5/2015 �/9��BDMS VL .I!'.N 2 1 2016 Submit Original Only • • 1 R-36 DTTMSTART JOBTYP SUMMARYOPS 8/5/15 FRACTURING RIH WITH FCO BHA, JET ACROSS PERF INTERVAL 3 TIMES, LAY IN SCHMOO, LET SOAK FOR 3 HOURS. RIH TO BOTTOM AND CLEAN OUT CHASING SCHMOO AND ANY SOLIDS TO SURFACE. ****TURN OVER TO DSO**** 8/7/15 FRACTURING GAUGED TBG TO 2.84"TO 12144' RKB. TAGGED @ 12400' SLM, EST. 66' FILL. MIT IA 3500 PSI, PASSED. ATTEMPTED MIT TBG 4000 PSI, FAILED. IN PROGRESS. 8/8/15 CALIPER LOGGED CALIPER SURVEY FROM CAT SV TO SURFACE. MIT TBG 4000 PSI, PASSED. IN PROGRESS. 8/9/15 FRACTURING PULLED 2.81"CAT SV @ 12144' RKB. GAUGED TBG HANGER TO 2.875" FOR TREE SAVER. READY FOR HPBD. 9/27/15 FRACTURING (AC EVAL): MITIA PASSED TO 4000 PSI. 11/4/15 PUMPING TRF FREEZE PROTECT5 BBL MEOH DOWN FLOWLINE22 BBL DSL DOWN TBGJOE 12/20/15 FRACTURING COMPLETED HPBD, PUMPED TOTAL OF 18,100#20/40 SAND DURING SCOUR STAGES AND 5100#OF ROCK SALT FOR DIVERSION STAGES WITH A MAXIMUM 27 BPM. LITTLE PRESSURE RESPONSE SEEN, WELL IS FREEZE PROTECTED WITH 25 DIESEL. a"--..\ KUP I � 1 R-36 Coma: 'Alaska tr ips Well Attribut Max Angle D TD .Inc Wellbore APEUWI Field Name Wellbore Status ncl CI MD(ftKB) Act Btm(ftKB) C.040M'liiiips 500292305700 KUPARUK RIVER UNIT INJ 69.84 3,630.97 12,700.0 ... ,.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 1R-36,1/6/201611:1210AM SSSV:NIPPLE Last W0: 2/26/2008 40.87 12/29/2001 Vertical schemabc*NO Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,400.0 8/7/2015 Rev Reason:TAG lehallf 8/14/2015 HANGER;32.7- ' Casing Strings Casing Description OD(in) ID(in) TopftKB Set Depth ftKB Set Depth(TVD)...VW/Len I...Grade TopThread ( ) P (ftKB) P ( CONDUCTOR 16 15.062 41.0 158.0 158.0 62.58 API5LGr PEB B •{111 _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE 95/8 8.835 40.7 7,419.1 4,152.4 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 38.3 12,664.8 6,943.0 26.00 L-80 BTC-MOD Tubing Strings �yuu.,,nn nn,,,o roo,uuoo,rro Tubing Description StringMa...ID(In) TopftKB Set Depth(ft...Set Depth TVD 4 (ftKB) p p (TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 31/2 2.992 32.7 12,116.2 6,478.1 9.30 L-80 EUE8RDMOD Completion Details �' Top(ftKB) Top(TVD)(ftKB) Top Incl(-) Item Des Com Nominal ID 32.7 32.7 0.06 HANGER FMC GEN 5 TUBING HANGER 2.992 511.9 511.5 5.57 NIPPLE CAMCO DS LANDING NIPPLE w/NO GO PROFILE 2.875 r12,113.4 6,475.7 32.96 LOCATOR BAKER LOCATOR 3.000 CONDUCTOR;41.0-158.0-A ; I'. 12,114.2 6,476.4 32.95 SEAL ASSY BAKER SEAL ASSEMBLY 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(IbM) Grade Top Connection TUBING Original 5.81 3.000 12,111.7 12,151.8 6,507.9 [ Completion Details NIPPLE,511.9 T 1TN 1 Top 111881 Top(TVD)(ftKB) Top Incl(°) Item Des Corn Nominal ID ... [S 12,111.7 6,474.3 3296 PBR BAKER 80-40 PBR 3.000 12,131.1' 6,490.6 32.90 ANCHOR K-22 TUBING ANCHOR 2.992 C ) 12,132.0 6,491.3 32.90 PACKER BAKER SAB-3 PACKER 4.000 12,136.9 6,495.5 32.88 XO BUSHING CROSSOVER BUSHING 2.992 • 12,143.8 6,501.3 32.86 NIPPLE 'CAMCO DS NIPPLE NO GO 2.813 [ s 12,150.9 6,5072 32.84 WLEG BAKER WIRELINE RE-ENTRY GUIDE I 3.000 ll ]j Perforations&Slots i ? Dens Shot LTop(TVD) Btm(TVD) (shots/ SURFACE,40.7-7,419.1-. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 12,284.0 12,298.0 6,619.3 6,631.2 C-1,1R-36 4/17/2002 6.0 IPERF 2.5"PJ,2506 PJ,60 deg •q ph • 12,442.0 12,460.0 6,753.0 6,768.3 A-4,A-3,1R- 4/14/2003 6.0 APERF 2.5"PJ HSD,60 deg 36 phase GAS LIFT;12058.8 .. ! 12,460.0 12,480.0 6,768.3 6,785.3 A-3,1R-36 '4/10/2003 6.0 APERF 2.5"PJ HSD,60 deg phase 12,504.0 12,510.0 6,805.6 6,810.7 A-2,1R-36 4/10/2003 6.0 APERF 2.5"PJ HSD,60 deg phase • Mandrel Inserts St ati a/ •N on Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 12,058.8 6,430.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/10/2008 LOCATOR;12,113.4 r Notes:General&Safety End Date Annotation SEAL ASSY,12,114.2 10/21/2010 •NOTE:View Schematic w/Alaska Schematic9.0 maw PBR;12,111.7 ANCHOR,12,131.1 y'I1 :II Ititi II . i PACKER;12,132.0 t1_ II NIPPLE;12,143.8 � . II WLEG;12,150.8 IPERF',12,284.0-12.298.0 ` APERF,12,442.0-12,460.0 + APERF;12,480.0-12,480.0 APERF,12,504.0-12,510.0 PRODUCTION;38.3-12,664.8, • 0 c a) E E v;. o 0 V N CD M V V CD OCx COCO CO CO LfLl N O CO N CN- CO CO In o O O oOOO ODU . ` N OOO O E � � LL. E x aE T m u coO = \U O UM U c O ti NN- N N CO f CC 0 y° V W v ! flfl Ci_ p 0 L1 1 r a3 � � QI O , U U CO j a a) a) *k r, L. U U E Q oO r O O N _c m U O M CO O O C6 CO 1 os N— U Cl) Z O N COCV O) 2 O) Q ,COcO CO C DJ r V (O CO -COC) N- CO CO - E) -0 IiU - U U L a) W U ,a2 U D a N'O Q y > (0 O j, E LO@ if7 aO n CO O O co ti O x U y— . O a) CO O O CO N- LU ) xa, a)0 , E w o a)a ON � � 2 ' a Z ~ O 'D c o m aiN O � RM N- z - :� mcE OO TE_ O rN , � -a v o) °oo o a n� o 0 0) N C Q "-\-.' N In a) N- >a) U c a o UN U O 00 f: CO CO o E S L E � a o@ U 0 T O L XOLmE C ao QE a r it m O c o� T° a o O E �cn0 ocn a a 3 0 U< E cncv na Q -o o o 1.0 U o) c c6 > an a)O �U U C 5o Y C (3 a CO ) p 0 a mw m0 Q m Q O F= : w 0 ti) U.-co c._ j a_ c 0 U t U— � o LL j i n �: aaa. CM o VC U U O - aLa) U E — C ^ a) L . L E °)� a 73 Q � U0LL C) ( Z o z oJ -0 E > (n W 'p J L U ^ L Y LL �O O Q Q N 2 > = Co U L I— (..) 0 CO N 7 (0 p 2 O Z LLE._ LL E cn (1) U z L CO CO a) V m 45 U) _ '° _ ~ ." in • S lJ LL) (O U N r CO N CO ,- 'C) O CO LO 1- CO O Ln N CO CO cr V CO CO LO O N 0 0 0 O O r 0 W CO V N O O 0 0 0 0 0 0 ‘- 000000000 O 000000 000000000000 000000 . O O O O O O O O O O O O O O O O O O Cl) 0 cn N N .71' -fes f- CO in O CO LO O N- f- N 2 O O in N CO CO CO CO N- O co co d- V N N C) O O N CO N N N CO CO C N- N. N O O O O ,- CO .- .- ,- .- N.... 001--- 0 0 0 0 0 0 0 C 00 N N 0000 000000 a) O O O O O O O O O O O O O O O O O O L Cn (0 (D 0 T C co 0 C a) @ LU co co V r..„. > O O O Lo O O LO O u7 (h V O O N O ` OOCCiV CO CO CO CO Ln O O CO _ N- in f— O O N CO N CO N" G T- NCOm0M NN V COO O CdO - CO O LC) � - CONCOO 0- N N N N O N N O N CO CO CO O N _Q N.- N- CO O CO ( .- O CO f- CO ( C N C o La C t` N- CO CO s- .- 0) .,- (N J- N CO O (0 E O L O a) -O .° G w Ci 77 a) T _O"o C C R C C > a) O_ N T O O @ (O C >, X O O C C C ,_ m O x 0 0U E C.a 0 0 N O L O -a-,• "C a) N 7 .O C C T a 0 T E C ill -c CO- CO C C C L C'O L C C m U E C N Cl O C 6 C C rn •-' O C 00 Ts O °- T(0 °0 L O U L O 'C O . C1 E O X L ? ° o 0 °> Cl.)° ° E NE, o E N ° a ` o o C GO -0,--, :C Vi O OX O 0 (0 'c O '(c J, -C U C (00 O Cn C1 E { o G c E 0 o (o a) L -0 N a (1) 0 0. m E N -co 7.1 a> L o ° c oL c ° -' m-E Cn G CO N N 0 2 0- _@ n (0 U (06 E O j o a) _ _a< 0 o U N Q N 0 Z ii).0Z N U J Q Q a)-° _G C C U.@ G 0 -O O LL O 7 -O C 3 O O O C-- Q C p)CJ 0 N O ct a) ON 3 � nu- _c C.0:5 cc T,) O N O C a a) O O O O° a O Q• a) 0 0 (n C E v T X C c C O U m o E 0 U COC O C G O O Q O O O C G E w >•o 7 2, a) a) 0 r- -0 O C O O lL C aci 0 E Lt.L.,- CO O -o O G a) N Z c • 2-01- 12.1 • • WELL LOG TRANSMITTAL DATA LOGGED q i /2015 . K.BENDER To: Alaska Oil and Gas Conservation Comm. August 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RLCOVEr' SEP 01 ZdL RE: Multi Finger Caliper(MFC) : 1R-36 nOt Run Date: 8/8/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1R-36 Digital Data(LAS), Digital Log file, Casing Inspection Report;3'D Viewer ' 1 CD Rom 50-029-23057-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: G �� Signed: Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, August 13, 2015 11:51 AM To: 'Nelson,Tim Y Cc: Wallace, Chris D (DOA) Subject: RE: 1R HPBDs (1R-23 PTD 191-101 and 1R-36 PTD 201-227) Gelled LVT Tim, Revised pump schedule is approved for the HBPD on 1R-23 and 1R-36. Gelled LVT is acceptable carrier for placing diversion rock salt. A copy of this email will be placed in both well files. Guy Schwartz Senior Petroleum Engineer AOGCC SCANNED HUu 1 4 LU l5 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). From: Nelson, Tim J [mailto:Timothy.J.Nelson@aconocophillips.com] Sent: Wednesday, August 12, 2015 3:23 PM To: Schwartz, Guy L(DOA) Subject: 1R HPBDs Guy, I thought I sent this to you before (bad memory and I can't find it in my sent emails or a reply from you) so disregard if I did. Per our conversation of several weeks ago please see the attached revised pump schedules for 1R-23 and 1R-36 HPBDs. Also attached are the original approved sundries. Please indicate you concurrence with the proposed changes. Thanks Tim Nelson 1 • , • u u ‘6 0, O o T T 2 N > 0-1 co D d --1 g Co CD EE d N Cl•• WO Z O C 0 D C O' to D A W N + O CO CO V CO N A W N + i! S P d i!01 0) W cn _y m z 3 d• -o Oo COMMm m o r - a N ha c A-0• N. c c N -o 0 m co v s ? O O acr P ET w my a ; cn (n ? 0aai v m cw Q w a o >N ONO > NONO >NO > > m 5 3 M O 'o m w 3 No O o. 0 1 z �.c w O . S oo m * a 3 y d cn p vJ fp f/l fp t� rn m ,-.O) m U p e2 w 65a S4ot"n' 3S : a o �c �1) v Er, r O a N A g O , C 0 N A V N m 00 m o r Co -i m r C T 414 W O O obi d N N N Z In m 0 c~D z 0 s. m N 4 W -I C1•.... __Cr-) O N m < 3 o d pp p x m n S M O o Q ,,Ti, S N cn m N N N A co CO CA V m ", O CA Q a to cn 4) m 0 N co co cn O co co co W in_ m CD Cn O CT 1_T g O n f) f) n m n n t) n I n A (t <t T r-93,, -I .0 Q O. N ~ F 9C 1< 9C JC JC x' 1 r o r<n y CL 10 E E E $ i E $ E E U E -0 . i , v c = 0 o N rri l » N m d r- m m .. r d .. m .. m y a s m 0 P PP• . i A 1 P. 1 4 4 S 4 4 i m Cr P n W W M 2 W m m m m m m m X O d d0 id 0 CC m n n LIm m 0 0 0 0 0 0 0 y v v '• v O) (T A W N+ >A A + W W W W�+ N N N N 9 y C Cr 1 C a v o �' m y N o .o . o 0 0 0 0 0 0 0 0 0 ; m v 3 m m -43 m m -o -o m Z m n n d d d d d z r El a n a a - pD m c T co • m r = j• o N > wC� N W N mm -I Ea-WI 3_ `O p v9 -4 '4 000000000 0000r 0 o m0 N m � 7 21 r 0 0 V ..., m m e`E 88 II n . a > > W N Z N > O O � mmdm No °IWA yyyy��CAA�77AANttpp co pq� T3 cD V 0000000000000 coi- c o �3O r r c c m m O 8 O M m CAO) ACA h3 ..e.0 o OV §§N N N m LI m 3 m VOOOOOOOOOO O O O r 0 O m 5 c T - ) w O o c s O w c p 3, O a n S i a _ v 0 az 0 a Ov + OCDNN NOWDNN NcNNO 'n ~ 0~ o v v m' 2, 0g 'm• O y N n 01a A W N pp pp pp�� N p p�N p A ). a y n • R a. g m e o c < m -r. ' -r -+ 060000 � a 000OL 1011 `m II II N N II 0 0 + V +O N W W Piv Cop C: 1 5:i A N �I . 0 u W o a I, y V 10) O)U Cn A A W W N N N O (n 1 < < 25 o N O'CO 01 N V (n O) N COW N W 0 n a n 0 0 0 c0 A A W g N 0 V CO V Cn CNNn N A N O D ; O `.3 0 D 0 CO CO CO 0 CO 0 0 0 0 0 0 0 0 0 Z 3 3 m m 0 0o ? m a o0 m 5. o l m m N O 0 v V a a am ,0 U fi o Q c 3 v° a m y n g .,--F-,.. '� — A N A N A N r WC y v D N O N O N O O N (Oj1 0 O N a O p D CO D AR } g0 0 C8B : WO t.3 01 MO) MaC y rt01 ym u u D u 414!n O)O — -.I n n A 0 N A AO CO CJ V ZA 0 : O O O O cm O C LZ m C VN CO N WVJVVW W OT tl1 CC ' 0, HcD ycDO coCD coW W W W z z -4 -I c • N N N N W co m O O O O O N N I- t o m m m m = d z D O p m m m o " co c0 N N N CO CO N N C0 CO N $ N m y E m n o ° m O m O O 0 O Co O O co O.r.o O r-m z Co H - D o vcom _. O C0o ? c A m . a i m � v in o V m 0 m Z 2 -8 p d i 1 CO A_ W N O W CO V j N -, -• N) CO c < o 03 c O P o 0 0 0 n S N N N O V .c �+_ $ H m m x • CO CA O N N CA U m > A A co O` 3 0 r 3 u II IIII II II II it IC II III II z C O o Z c 8 m • -' c A CT CA -I CD O + N N A CT m +r m N) ZJ v CD Co -I 40 N co N A �1 CA O, d!L 3 0 m x 3 A A O Co 0) U) U) (p CO 0) 0) N E. 0 i > C ''%3 .. Tk 0 0 u 0 0 m CP o 00 a 00000000 0 0 m (�D < + d m < a DD g u CO O OO OO O 0000000 0 ; o () 3d () 0000000000000 o m p 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / DATE: Wednesday,May 13,2015 P.I.Supervisor I�e 1 �G 4 l i`) SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R-36 FROM: Lou Grimaldi KUPARUK RIV UNIT 1R-36 Petroleum Inspector Src: Inspector Reviewed By-e��rr,, P.I.Supry J32— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1R-36 API Well Number 50-029-23057-00-00 Inspector Name: Lou Grimaldi Permit Number: 201-227-0 Inspection Date: 5/8/2015 Insp Num: mitLGl50508144255 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1R-36 Type Inj W-TVD 6492 - Tubing 2300 - 2300 - 2300 . 2300 - PTD 2012270 - Type Test SPT Test psi 1623 - IA 720 3010 . 2940 - 2930 - Interval 4YRTST P/F P ,-' OA 170 450 - 445 - 440 - Notes: 3.0 bbl's diesel pumped,2.5 bbl's returned.Good solid test.All required paperwork supplied prior to test. A 4 : I) cu rfv)-"wet( SGtsc, ,41 L c [..1-0 (ste (Lvt SCANNED JUL 1 0 2015 Wednesday,May 13,2015 Page 1 of 1 • dwe lajoLi3 C'a Lo C D CD '�, ' C11 s- r ,..I' 1 11 1 I . I . I. 11 I .1 r . I I 1. I, I .I 1 I ' I . 1 I. X06 - : • : : •: , - J /� --2..... (,,,? :: • i .... ( : - • ..-( : i • . . .{ N-- • CD it.— : . c ..... . . En (13 Eta ../ - • Lr) 1h. •• I • t • tr - i . • • • i ...... . • • • • • • L1._. I� [.L • - C1! ? . • •• 1 • : • i • 1_I_I ' '1 f I' 1 ' 1 1 1 '1 , 1 1 1' 1 1 ' 1 '1 ii I 0 I I' II 'I '1 (1;+ LL i d- C� C� C Ca LL O C U) C V) C' 0 lSd 4. KUP 1 R-36 " ConocoPhillips Well Attributes Max Angle&MD TD Alaska,IncWellbore APIA/WI Field Name Well Status Inst r) MD(RKB) Ad Poo INKS) LdgGoi'IVIIip, 500292305700 KUPARUK RIVER UNIT INJ 69.84 3,630.97 12,700.0 Comment H2S(ppm) Dab Annotation End Date KB•Ord(R) Rig Reba.Date Well cane.-1R-38,0/25/2012 4:00:10 PM SSSV:NIPPLE Last WO: 2/26/2008 40.87 12/29/2001 Ssheme.c.Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 12,471.0 8/2/2011 Rev Reason:WELL REVIEW osbod 6/25/2012 Casing Strings Casing Description String 0... String ID...Top(MB) Sot Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 41.0 158.0 158.0 62.58 API5L... PEB HANGER,33 "91Cuing Description String 0... String ID...Top HIKER Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd -._ _ SURFACE 95/8 8.835 40.7 7,419.1 4,152.5 40.00 L-80 BTC Cuing Description String 0... String ID...Top(ftRB) Set Depth(I...Set Depth(TVD)...String WL..String...String Top Thrd PRODUCTION 7 6.276 38.3 12,664.8 6,943.0 26.00 L-80 BTC-MOD 11191 MIF;Pil Tubing Strings Tubing Description String 0... Shing ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd TUBING WO 31/2 2.992 32.7 12,116.2 6,478.3 9.30 L-80 EUE8RDMOD Corn'lotion Details 1 r Top Depth (TVD) Top Intl No.ni... Top OMB) (NKB) r) (tam Description Comment ID(in) 32.7 32.7 0.38 HANGER FMC GEN 5 TUBING HANGER 2.992 511.9 511.4 5.31 NIPPLE CAMCO DS LANDING NIPPLE w/NO GO PROFILE 2.875 12,113.4 6,475.9 33.00 LOCATOR BAKER LOCATOR 3.000 . 12,114.2 6,476.6 33.00 SEAL ASSY BAKER SEAL ASSEMBLY 3.000 Tubing Description (String 0... IString ID...(Top(NKB) IB.t Depth(f...IB.t Depth(TVD)...ISMng WL..(Shing...(String Top Thrd CONDUCTOR, TUBING Original 5.81 3.000 12,111.7 12,151.8 6,508.0 41-158-► Completion Details Top Depth (TOD) Top Intl Nomi... - - Top((B(B) (NKB) r) Rem Description Comment ID(In) NIPPLE,512 12,111.7 6,474.3 32.96 PBR BAKER 80-40 PBR 3.000 -- 12,131.1 6,490.7 32.94 ANCHOR K-22 TUBING ANCHOR 2.992 12,132.0 6,491.4 32.93 PACKER 'BAKER SAB-3 PACKER 4.000 , 12,136.9 6,495.6 32.92 XO BUSHING CROSSOVER BUSHING 2.992 12,143.8 6,501.3 32.89 NIPPLE 2.813 12,150.9 6,507.2 32.86 WLEG BAKER WIRELINE RE-ENTRY GUIDE 3.000 Perforations&Slots CAMCO DS NIPPLE NO GO Shot Top(TVD) Btm(TVD) Doe II Top(MB)eft OMB) RUB) (MB) Zone Date (oh... Type Comment 12,284.0 12,298.0 6,619.3 6,6312 C-1,1R-36 4/17/2002 6.0(PERF 2.5"PJ,2506 PJ,60 deg ph SURFACE._._ 12,442.0 12,460.0 6,753.0 6,768.3 A-4,A-3,1R-36 4/14/2003 6.0 APERF 2.5"PJ HSD,60 deg phase 41.7419 12,460.0 12,480.0 6,768.3 6,785.3 A-3,1R-36 4/10/2003 6.0 APERF 2.5"PJ HSD,60 deg phase t--- 12,504.0 12,510.0 6,805.7 6,810.8 A-2,1R-36 4/10/2003 6.0 APERF 2.5"PJ HSD,60 deg phase Notes:General&Safety _ End Date Annotation GAS LIFT, 10/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 12,050 LOCATOR, 12,113 SEAL ASSY, 12,114 FOR,12,112 ANCH,O131R, 12 PACKER, 12,132 1111 B NIPPLE,12,144 IT a WLEG,12,161 $ t" IPERF, 12,284-12,298 iill I. i Nnii APERF. Mandrel Details 12,442-12,480 Top Depth Top Port I I (TVD) Incl OD Valve Latch Bio TRO Run 12,480-12.400 Stn Top(NKB) PROP r) Male Model (In) Sere Typ. Type (In) (pod) Run Data Com... 1 12,058.8 6,430.0 33.13 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/102008 APER 12 504-12,51F0 PRODUCTION, 38-12,885 A I\TD.12.]00 Irllage Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. dO L -,~~:z Well History File Identifier Organizing I"r'"" RESCAN 0 Two-Sided 0 Rescan Needed 0 Color items: DIGITAL DATA ~ Diskettes, No. ~ OVERSIZED (Scannable) 0 Maps: 0 Grayscale items: 0 Other. NofType 0 Other items scannable by large scanner 0 Poor Quality Originals: 0 Other: OVERSIZED (Non-Scannable) NOTES: 0 Logs of various kinds 0 Other Bf, BEVERL Y ROBIN VINCENT SHER'(G:' WINO'( DATE:.5'1 Jtt {<i/SI V\1 r Project Proofing B'(, BEVERL'( ROBIN VINCENT SHERY(~ WIND{ DATE'S,.!).4!Olf Isl VI1P = TOTAL PAGES / C' J hiP Scanning Preparation 3 x30=1° + I I DA1E:~ :J.L/!ÓLþsl BY, BEVERL,' ROBlfJ VINCENT SHER'(L JG~, WIND ( ~' Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: I {);)- Bf: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: V YES - NO BEVERLY ROBII J VINCENT SHER'(L MARIA WINO'r' DA TE ? / q J oL( 151 J1!!::o(l Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO B (: BEVERL,' ROBIN VINCEIH SHER (L MARIA WII~O'( DJ\TE ISI (SCÞlllnPJG ''5 COMPLETE AT THI!:, pOlm urLE~S '.)PECIAL ATlErHlOII IS REQUIRED 011 Ar~ IPIDIVlDLlAL PAGE BASIS DUE TO QUAUT ~. GRA\'SCALE OR COLOR IMAGES) ReScanned 1I':lf,' :,;,,' ,II' "I " I ",{", ' :,1.1 '¡',I,. .,'::',:1;' ',( .'01, '/1:" "f'II'!,""'( I"o'} -I RES CANNED Bt(: BEVERLY ROBIN VINCENT SHER'(L MARIA WINDY' DATE: ISI General Noles or Comments rtbout this file: Quality Checked "I'>If'1 12110102RellJNOTScanned wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 25, 2011 TO: Jim Regg P.I. Supervisor l q C(2-41 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R-36 FROM: Chuck Scheve KUPARUK RIV UNIT 1R -36 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry �B �'� NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT IR - 36 API Well Number: 50 029 - 23057 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110522091356 Permit Number: 201-227-0 Inspection Date: 5/21/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WCII 1R -36 %Type Inj. i N TVD 6492 IA ' 295 1 2185 1 2155 2150 - P.T.D 2012270 ' IYpeTest I sPT Test psi 1623 ; OA 30 40 40 40 Interval 4YRTST _ p/F' P Tubing , 1350 1350 1350 1350 l Notes: 10-, 'A' 6 2011' Wednesday, May 25, 2011 Page 1 of 1 ~ COr1 ~ . . ocoPh~llips Alaska P.O. BOX 100360 ANCHORAGE, AU4SKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: - - ;; ;?~lu`~ ~ .. ,'~4.>~~~i ~'»:.w:~~ t: ~..' •? ~ 4 ~~ ~~P ~ ~ 2009 ~I~~k~ Ai! ~ C~s Cana..~Q€r~ni~~iar~ ~n~~~~~~ ao i-a~-7 ~~-3 ~ Enclosed please find a spreadsheet with a list of wells from the Kupaxuk 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 S~ndry Operations. The cement was pumped August 15`" and 23rd 2009, and the corrosion inhibitor/sealant was pumped August 27~`, 28;1i and 29~' 2009. The atta.ched spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, / ~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ~ . ~ `. ~. }_ I . ~1~~' ~; „ 7(,,~ P " . . .. .....'. t .. .. ... ..c, e'~ t.... ~ -~ ConocoPhiilips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Ffeld Date 8129/09 ~p aen Weli Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls R al 1 R-01 B 50029214040200 . 2001560 13'7" 2.0 26" 8/15/2U09 5.1 8/27/2009 1 R-02 50029214050000 1851760 80' 13.30 23" 8/23l2009 4.7 8/28f2009 1 R-03A 50029214060100 2000210 15' 3.00 27" 8/15/2009 5.3 8/28/2009 1 R-04 50029214070000 1851780 15'2" 3.00 26" 8/15/2009 5.1 8/28/2009 1R-05 50029213300000 1850700 20'9" 2.20 23" 8/15/2009 3.8 8/28/2009 1 R-06 50029213310000 1850710 14' 2.00 23" 8/15/2009 3.8 8/28/2009 1R-07 50029213320000 1850720 44' S.00 24" 8/15/2009 4 8/28/2009 1R-08 50029213330000 1850730 8' 1.00 21" S/15/2009 13.7 8/28/2009 1 R-09 50029213500000 1850950 9' 1.20 25" 8/15/2009 4.3 8/28/2009 1 R-10 50029213510000 1850960 32' 5.40 22" 8/15/2009 3.4 8/28/2009 1 R-11 50029213520000 1850970 47' 6.00 38" 8/15/2009 13.9 8/28/2009 1R-12 50029213530000 1850980 38' 6.00 24" 8/15/2009 4 8/28/2009 1 R-13 50029213850000 1851500 10' 0.50 25" 8/15/2009 4.3 8/29/2009 1 R-15 50029213870000 1851520 21'4" 4.00 35" 8/15/2009 12 8/29/2009 1R-16 50029213880000 1851530 12'6" 9.00 21" 8/23/2009 3.8 8/29/2009 1 R-17 50029222120000 1911140 20" N/A 20" N/A 4.4 8/28l2009 1R-18 50029221880000 1910870 9'4" 1.20 21" 8/15/2009 3.7 8/28/2009 1 R-19A 50029221850100 1910850 18" N/A 18" N/A 10.2 8/29/2009 1 R-20 50029222070000 1911080 8'4" 2.00 19" 8/15/2009 11.3 8/29/2009 1R-22A 50029222060100 1990490 16" N/A 16" N/A 9 8/29/2009 1 R-23 50029222000000 1911010 18'8" 2.30 39" 8/15/2009 13.9 8/29/2009 1 R-25 50029221530000 1910470 7'4" 1.50 26" S/15/2009 5.1 8/27/2009 1 R-26 50029221930000 1910920 7' 3.50 38" 8/23/2009 13.9 8/28/2009 1 R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 8/28/2009 1R-29 50029221950000 1910940 18" N/A 18" N/A 4.1 8/28/2009 1R-35 50029230500000 2012100 18" N/A 18" N/A 5.3 8/29/2009 1R-36 50029230570000 2012270 19" N/A 19" N/A 5.3 8/29/2009 MEMORANDUM • TO: Jim Regg ~~~ ll~to~ ~~, P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November O5, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R-36 KUPARUK RIV UNIT 1R-36 Src: Inspector NON-CONFIDENTIAL Reviewed B~p P.I. SuprvV~~`""" Comm Well Name: KUPARUK RN UNIT iR-36 API Well Number: s0-029-23057-00-00 Inspector Name• Chuck Scheve Insp Num: mitCS08ll02141720 Permit Number : 201-227-0 i Inspection Date: I Ui/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IR-36 TYPe Inj. W TVDi- 6492 IA 900 ~ 2000 / i 2000 ~ 2000 -- _ p T 2012270 TYPeTest SPT -f- 'l'est pSl ~ ---- -- 1623 - QA --- i 230 390 390 - 390 _ -.. _ -- Interval wRKOVR p~F P / Tubing Is00 ~ Isoo Isoo Isoo Notes: ~~~~~~ I~~`1 ~ c ~Ui~ Wednesday, November O5, 2008 Page 1 of 1 Page 1 of 2 • Maunder, Thomas E (DOA) From: Packer, J.Brett [J.Brett.Packer@conocophillips.com] Sent: Monday, April 07, 2008 11:56 AM To: Maunder, Thomas E (DOA) Subject: RE: 3K-08 (186-126) & 1R-36 (201-227) Yes, it was Nordic 3. We got rid of Nab s~3S last December so now we only have the one workover rig. ,~ Brett ~ackgr Ong sL `Wefts `Wnrk~verEngineer ~ ~~R t~ `~ Zaa zv~,# 26S-6saS Ceff# 23~-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, April 07, 2008 11:52 AM To: Packer, J.Brett Subject: RE: 3K-08 (186-126) & iR-36 (201-227) Thanks Brett. That should work. If I see other items to include, f will send a message. Could you tell me what rig did the work? I suspect Nordic 3. Tom From: Packer, J.Brett [mailto:J.Brett.Packer@conocophillips.com] Sent: Monday, April 07, 2008 11:40 AM To: Maunder, Thomas E (DOA) Subject: RE: 3K-08 (186-126) & 1R-36 (201-227) Tom, I'll forward this to the workover rig supervisors and make sure they include this information on the summaries. ,~ Brett ~acfgr Bing ~ `Wells `WorfQver~Engineer 'Work# 265-6845 CeQ# 230-8377 From: Maunder, Thomas E (DOA} [mailto:tom.maunder@alaska.gov] Sent: Monday, April 07, 2008 11:29 AM To: Packer, J,Brett Cc: Eggemeyer, Jerome C. 4J7/2008 • Subject: 3K-08 (186-125) & 1R-36 (201-227) Brett, 1 am reviewing the 404s submitted for the work on 3K-08 and 1 R-36. With regard to the work summaries, the detail is pretty good however there are a few items. I am not sure how the information is best captured so it prints on the report. I have spoken with Jerome on some of these items on the drilling side. 1. The rig is not identif+ed. Might the rig name be specfied when the accept time is noted? 2. In 3K-08, the initial BOP test information is more complete than 1R-36. In particular, it is noted which Inspector waived witness of the test. This is information that should be included. Thanks in advance for you reply. Call or message with any questions. Tom Maunder, PE AOGCC Page 2 of 2 4/7/2008 STATE OF ALASKA APR 0 1 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~laska Oil & Gas Cons. Commissiarl 1. Operations Performed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 201-227 / 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23057-00 7. KB Elevation (ft): ~ 9. Well Name and Number: RKB 36' 1 R-36 8. Property Designation: 10. Field/Pool(s): _ ~ ° ADL 25628, ALiE.2561 ~ . ~ ~{ Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 12700' feet true vertical 6973' feet Plugs (measured) Effective Depth. measured 12500' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 158' 16" 158' 158' SURFACE 7383' 9-5/8" 7419' 4152' PRODUCTION 12628' 7" 12664' 6942' Perforation depth: Measured depth: 12284'-12298', 12442'-12480', 12504'-12510' true vertical depth: 6619'-6631', 6753'-6785', 6806'-6811' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12151' MD. Packers & SSSV (type & measured depth) pkr= BAKER SAB-3 PACKER pkr- Camco Landing DS nipple @ 514' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-048 Contact Brett Packer @ 265-6845 Printed Name Brett Packer `~` ~ Title Wells Engineer ~~~/D~ Signature ~--~^~? _ ~; ~ll"L.., Phone Date ~ P a Karon All -Drake 263-4612 Form 10-404 Revised 04/2006 ~ ~ ~ ~ ~ ~ A L ~'"~l ~i Submit Original Only DATE SUMMARY 1 R-36 Well Events Summary 2/3/08 SPOT EQUIPMENT, PREP FOB. REQUEST DSO ASSISTANCE T~N SSV. IN PROGRESS. 2/4/08 MEASURED BHP @ 12290' RKB: 2922 PSI. SET 2.81" CA-2 PLUG IN DS NIPPLE @ 12143' RKB. IN PROGRESS. 2/5/08 SET 2.80 CATCHER @ 12112' SLM. PULLED DV @ 12048' RKB. PULLED CATCHER. ATTEMPTED PULL PRONG IN 2.81 CA-2 PLUG. -N PROGRESS. 2/6/08 PULLED 2.81" CA-2 PLUG. COMPLETE. 217/08 PRE RIG RWO T&IC POT&PPPOT (PASSED). 2/12/08 ATTEMPT TO SET 2.81" CA-2 PLUG @ 12,143' RKB. ***JOB IN PROGRESS"** 2/13/08 SET 2.812" CA-2 PLUG @ 12119' SLM, COMBO MIT TO 2500 PSI-PASSED. PULL EQUILIZING PRONG, ATTEMPT TO PULL PLUG BODY @ 12119' SLM. JOB ONGOING. 2/14/08 PULLED 2.812" CA-2 PLUG BODY, BRUSH & FLUSHED FROM PBR @ 12109' TO TTL, JOB COMPLETE. 2/15/08 SET WEATHERFORD WRP AT 12148' IN A 6' PUP JOINT BETWEEN THE DS NIPPLE AND THE SOS. WRP WAS 2.69" OD. WRP SCHEMATIC WAS INCLUDED IN THE WELL FOLDER. 2/15/08 SET 2.72" X 87" CATCHER ON TOP OF WRP @ 12113' SLM, JOB COMPLETE. 2/18/08 CIRCULATE BRINE PUMPING DOWN TUBING TAKING RETURNS UP IA TO TIGER TANK, U-TUBE FP. TOTAL FLUIDS: 334 BBLS- 9.6 PPG BRINE W/ 0.6% SAFE LUBE FOLLOWED BY 89 BBLS DIESEL FP. WELL BLED TO ZERO AND READY FOR BPV INSTALLATION. 3/10/08 REPLACED SOV WITH DV @ 12058' RKB. MIT IA 2500 PSI, GOOD. PULLED 87" x 2.72" CATCHER @ 12146' RKB. EQUALIZED WRP. IN PROGRESS. 3/11/08 PULL 2.62" WRP @ 12146' RKB, DRIFT W/ 2.70" CENT SB TO 12472' WLM, • '"`.`~ G+gnocoPhiltps Alaska, lnc. .... 7 R-36 APi: TUBING SSSV Type: (0-12109, OD:3 500 . , ID:zs92) Annular Fluid: SURFACE (0-7419, OD:9 625 . , wt:ao.oo) Reference Lo Last Taq Date: PRODUCTION (0-12664, OD:7.000, Wt:26.00) PBR ;12109-12110, OD:5.810) TUBING 1z1os-1z151, OD:3.500, ID:zssz) PKR ;12132-12133, OD:5.960) NIP ;12143-12144, OD:4.520) sos 1z1so-1z1s1, OD:3.500) Perf ;12284-12298) Perf 12442-12460) Perf 12460-12480) :,, _ ~__= • KRU 1 R-36 - - _ _ _ -~ 305700 I Well TvDe: i INJ I Anple ~~ TS: i 33 dea [a~ 12237 I PULL WRP, GLV Tuhinn Strinn -TARING Size To Bottom TVD WI Grade Thread 3.500 0 12109 6472 9.30 L-80 EUE8rdMOD 3.500 12109 Perforations Summary _ Interval TVD 12151 Zone 6507 Status Ft SP 9.30 F Date L-80 T EUE8rdMOD j Comment 12284 - 12298 6619 - 6631 C-1 14 6 4/17/2002 IPERF 2.5" PJ, 2506 PJ, 60 d h 12442 - 12460 6753 - 6768 A-4,A-3 18 6 4/14/2003 APERF 2.5" PJ HSD 60 de hose 12460 - 12480 6768 - 6785 A-3 20 6 4/10/2003 APERF 2.5" PJ HSD, 60 de hose 195nd _ 19F1n RRnR_ RR11 A_7 R R d/1n/9m3 APFRF 7 Fi" P.I HRf) Rn rfan Whose Gas Lift MandrelsNalves St MD TVD Man Mfi Man T V Mfr V T V OD Latch Port TRO Date Run Vlv ~1 12059-~64~CAMCOI KBUG I DM~ 0.0 0.000 0 3i10i20D8 Cmnt .Other (plugs, a ui ., etc.) - COM_ PLETION De th TVD T e Descrl lon ID 512 512 NIP CAMCO LANDING DS NIPPLE W/NO GO PROFILE 2.875 12108 6471 SEAL LOCATOR/SEAL ASSEMBLY STABBED INTO OLD PBR Cad 12109' 3.000 •~13a ~6+7~1 PKR BAKER SAB-3 PACKER 4.000 12143 6501 NIP CAMCO DS NIPPLE W/NO GO PROFILE 2.812 12150 6506 SOS 3.000 12151 6507 TTL 2.992 Perf :12504-12510) • l Time Low _ _ _ _ Date From To Dur S Depth E. De tp h Phase Code Subcode T COM _ 02/25/2008 19:00 19:30 0.50 COMPZ RPCOh RCST P Unseat hanger @ 100k and pull out w/ seals @ 115k. Pull to rig floor w/ han er w/ 115k u wt. 19:30 21:30 2.00 COMPZ RPCOh CIRC P Circulate surface to surface @ 4 bpm @ 560 psi. Had loss of 8 bbls filling surface a ui ment. 21:30 22:00 0.50 COMPZ RPCOh OWFF P Monitor well and fill trip tank 22:00 00:00 2.00 12,132 10,713 COMPZ RPCO PULD P PJSM, Lay down hanger, Pooh f/ 12,132'to 10,713.0' 02/26/2008 00:00 13:00 13.00 10,713 0 COMPZ RPCOti PULD P Continue to Pooh laying down 3 1/2 Production string, Strapping out of the hole 13:00 14:00 1.00 0 0 COMPZ RPCOti PULD P Clear pipe shed pulled tbg. 14:00 16:00 2.00 0 0 COMPZ RPCOh PULD P Load remainder 3-1/2 tbg to pipe shed. Stra / re same. 16:00 17:00 1.00 0 0 COMPZ RPCOh RURD P Clear floor, RU for 3-1 /2 comp. 17:00 19:00 2.00 0 0 COMPZ RIGMN SVRG P Service rig. 19:00 00:00 5.00 0 7,800 COMPZ RPCOh RCST P PJSM. RIH with new completion strin 02/27/2008 00:00 04:00 4.00 7,800 12,100 COMPZ RPCO RCST P RIH 3-1/2 comp to 12100 ft. 04:00 05:30 1.50 12,100 12,116 COMPZ RPCOh HOSO P Sting in PBR, space out, install 2ft pup. MU tbg hgr. Up 105, Dn 70, Block Wt 35 K. 9.6 brine. 05:30 10:30 5.00 12,116 12,116 COMPZ RPCO CIRC P Mix /pump inhibitor to tbg &ann, 5 bpm / 720 psi. Follow with 129 bbls brine. 10:30 11:00 0.50 12,116 12,116 COMPZ RPCOR HOSO P Sting in seals to PBR / Land tbg hgr simultaneously leaving 2 ft space out (Locator to PBR). Confirm hgr seated. RILDS. Final depths =Seal assy 12114, GLM SOV 12058, DS Nipple 512 , Tb H r 36 ft. 11:00 13:00 2.00 12,116 12,116 COMPZ RPCOh DHEQ P PJSM, Test tbg to 2500 psi with ann pen, bleed tbg to 1750 psi. Test 3-1/2 X 7 ann to 2500 psi / 30 min. Bleed tbg to "0' psi. o e searing at 1650 psi. Circ tbg to ann, confirm SOV fu{ly open. Bleed all pressures, well static. 13:00 16:00 3.00 12,116 12,116 COMPZ RPCOh NUND P PJSM, Set BPV, ND BOPE. 16:00 19:00 3.00 12,116 12,116 COMPZ RPCOh NUND P PJSM, NU prod tree 19:00 20:00 1.00 12,116 12,116 COMPZ RPCOh SFEQ P Tubing POT to 5000 psi fro 15 min. Press test tree to 5000 si for 15 min 20:00 21:00 1.00 12,116 12,116 COMPZ RPCO RURD P RD wellhead testing equipment. RU freeze rotect lines. 21:00 23:30 2.50 12,116 12,116 COMPZ RPCOCV FRZP P Freeze protect well with 140 bbl of diesel down the IA. Allow diesel to U-tube with the tubin for 1 hr. ~~ F'~tr~ 2 of 3 • Time Logs ~ Da e From To Dur S Depth E. De tp h Phase _ Code Subcode ~ T _ COM 02/27/2008 23:30 00:00 0.50 12,116 12,116 COMPZ RPCOti RURD P Rig down freeze protect lines 02/28/2008 00:00 00:30 0.50 12,116 12,116 COMPZ RPCOti OTHR P Set BPV 00:30 01:00 0.50 12,116 12,116 COMPZ RPCO NUND P Dressing wellhead. Release rig @ 01:00 am 2/28/2008. Page3uf3 • • ~~ ~-~ ~ ~ ~ ~~ ~, SARAH PALiN, GOVERNOR ~-7~A OIL ~ vra~7 333 W. 7th AVENUE SUITE 700 COI~SERQAZ`IO1~T CO1~II-IISSIOI~T , ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Von Cawvey Wells Group Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 . ~~`~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 R-36 ~,~ Sundry Number: 308-048 ~~R~~ FEB 2 4 2008 Dear Mr. Cawvey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day ff the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of February, 2008 Encl. • i li Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • ~~~~ February 5, 2008 Alaska Oil & Gay Ceps. I~~rnssec Anc~erage Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1 R-36 (PTD# 201=227). Injecting well 1 R-36 was drilled in December 2001 as a 3.5" single injector. The well failed an ~ MITIA in July 2006 and has since been shut-in. (NOTE: The well passed a Combo MIT on August 3, 2006.) Leak detection logs determined a hole in the tubing at 11'820' RKB. Later a holefinder was ran and more holes were identified. A caliper log showed multiple joints with greater than 50% wall penetration and so the well was put on the rig workover list for replacement of the 3-1/2" injection tubing. The purpose of the proposed workover will be to pull all of the existing 3-1/2" tubing string and replace it with a new 3-1/2" tubing string. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 263-4692. Sincerely, i~;~-~'-'~'' ~ ~~~~~ Owen M. Ryan Wells Engineer CPAI Drilling and Wells ORIGINAL STATE OF ALASKA ~~~,~~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR SUNDRY APPROVAL FEB 1 2 0 ~' 20 AAC 25.280 Alaska Oi6 & Gas Gins. Commis~ n 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver n raga Other ^ Alter casing ^ Repairwell ^/ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^/ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 201-227 3. Address: Stratigraphic ^ Service Q 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23057-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership chang es: Spacing Exception Requires? YeS ^ NO ^~ 1R-36 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25628,'ALK 2561 RKB 36' ' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12700' 6973' 12500' Casing Length Size MD TVD Burst Collapse CONDUCTOR 158' ~ 16" 158' 158' SURFACE 7383' 9-5/8" 7419' 4152' PRODUCTION 12628' 7" 12664' 6942' Perforation Depth MD (ft): Perforation Depth rvD ft Tubing Size: Tubing Grade: Tubing MD (ft): 12284'-12298', 12442'-12480', 12504'-12510' 6619'-6631', 6753'-6785', 6806'-6811 3-1 /2" L-80 12151' Packers and SSSV Type: Packers and SSSV MD (ft) pkr- BAKER SAB-3 PACKER pkr= 12132' Camco Landing DS nipple @ 514' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. WeII Status after proposed work: Commencing Operations: March 3, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: -Date: WAG ^ GINJ ^ WINJ ^Q - WDSPL ^ Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Owen Ryan @ 263-4692 Printed Name VOn CawveV Title: Wells Group Team Leader Signature Phone 265-6306 Date Z /( QS Commission Use Onl Sund Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ~ Mechanical Integrity Te st ' y}~ Location Clearance ^ Other: • J ~O~' ~ , ~~ ~ ~ j \ ~ S V ~~: F~~ ~ 20D6 Subsequent Form Required: t..'~~~\ APPROVED BY 1 cJ Approved by: COMMISSIONER T HE COMMISSION Date: 1 ! Form 10-403 Revised 06/2006 Submit in Duplicate Q R I G I N A ~~.~~ ~~ Y ,s-.~. • • Well: 1 R-36 API: 50-029-23057-00 ~t~~"10Ct~P'11~~ Field: Kuparuk PTD: 201-227 2008 RWO PROPOSED COMPLETION NEW COMPLETION WELLHEAD Lift threads: 3%" 8rd EUE BPV: 3" CIW H Model: FMC Kuparuk Gen V CONDUCTOR 16", 62.58 ppf, AP15LGrB, PEB A: Nipple: 3-1/2" with 2.875" DS @ 514' MD B: Gas Lift Mandrel No. MD TVD TYPE 1 12,063 6,434 1" KBMG SURFACE CASING 9.625", 40 ppf, L-80, BTC PRODUCTION CASING 7.0", 26 ppf, L-80, BTC-MOD TUBING and LINER 3.5", 9.3 ppf, L-80, 8rd-MOD PERFS C-1: 12,284'-12,298' MD A-4: 12,442,'-12,460' MD A-3: 12,460'-12,480' MD A-2: 12,504'-12,510' MD C: Seal Assembly @ 12,109' MD D: Nipple: 3-1/2" with 2.812" D profile @ 14,480' MD ®SAB-3 Permanent packer @ 14,463' MD Last Tag: 07/23/06 Tag Depth: 12,532' RKB Fill: no fill over perfs TD: 12,700' RKB Last Updated: 8-Feb-08 Updated by: OMR Kuparuk 1 R-36 General Workover Procedure PTD 201-227 Pre-Riq Work 1. Pull DV from bottom GLM 2. Set IBP. 3. Circulate in 9.6 ppg NaCI brine. 4. Set CIW 3" H BPV 5. Prepare location for arrival of Workover Rig General Workover Procedure 1. Verify Sundry approval acquired 2. MIRU Nordic #3 3. Pull BPV to verify well is dead. If not circulate full of kill weight brine. Set BPV. ND tree. ~ r~ ~ 4. NU BOPE. Set blanking plug. Pressure test BOPE to 250/2psi ~~ ~r 5. The last SBHP measurement was 2,922 psi on February 4, 2008, at 12,290' MD (6,624' TVD) which is mid-pert depth. An IBP will be set in the tubing tail to isolate the formation. Kill weight fluid with a 125 psi overbalance would be 8.9 ppg. For this workover 9.6 ppg brine will be used. The calculated maximum possible surface pressure assuming a gradient of 0.1 psi/ft is 2,260 psi.) 6, Pull 3-1/2" tubing and run new 3-1/2" tubing 7. Prior to setting new completion circulate in corrosion inhibited seawater. 8. Set new completion 9. Freeze protect with diesel 10. Set BPV and ND BOPE 11. NU tree, pull BPV, set two way check, and test tree 12. Remove two way check 13. .Set BPV and RDMO workover rig Post-Riq Work 1. Pull BPV 2. Replace SOV in GLM #1 with DV. 3. PuII IBP 4. Return to injection · . WELL LOG TRANSMITTAL 'RECE\VED ProActive Diagnostic Services, Inc. AUG 2 H 2006 AJeaka 01\ & Gas Cons. commission Anct\<)rage To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Ala~ka 99501 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1) 1 BL / EDE Disk 1R - 36 Caliper Report 14-Aug-06 2) 3) 4) 5) 6) 7) SCANNED AUG 3 0 2006 Print Name: C M/' Q~ ('-n-hIAQ fl'1.aJA/LV PIli Date: 75/ fY1/ ()/J Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 UTe.- dOl - 8d1- 0:100_ POSANC-2006\Z_ W ordlDistributionlTran.smiltal_ SheelslTran.smit_ Original.doc F lLfotf.o I I I I I I I I I I I I I I I I I I I e..>-e..ÐOI- dd1- 1i ILIOô''=>. RECEIVED Memory Multi-Finger Caliper AUG 2 9 Z006 Log Results Summary AJaskaOiI&GasCons.CoIMJi$SIOn Anchorage Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Well: 1R-36 Field: Kuparuk State: Alaska API No.: 50-029-23057-00 Top Log Intvl1.: Surface Bot. Log Intvl1.: 12,151 Ft. (MD) ConocoPhillips Alaska, Inc. August 14, 2006 7596 1 3.5" 9.3 lb. L-80 Tubing Inspection Type: Co"osive & Mechanical Damage Inspection COMMENTS: This log is tied into the bottom of the 3.5" Tubing @ 12,151' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The caliper recordings indicate the 3.5" tubing is in good to poor conéÍition with respect to corrosive damage. A possible hole is recorded in joint 341 (10,739'). The damage appears in the forms of general corrosion and isolated pitting. Penetrations in excess of 20% are recorded in 362 of the 398 joints logged. No significant areas of cross-sectional wall loss are recorded throughout the 3.5" tubing logged. Light deposits are recorded in a number of joints throughout the tubing, with a recorded minimum I.D. of 2.75" and 2.77" in joint 319 (10,063') and pup joint 122.3 (3,876'). Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum - recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Possible Hole ( 92%) Jt. 341 @ 10,739 Ft. (MD) Corrosion ( 80%) Jt. 340 @ 10,736 Ft. (MD) Corrosion ( 79%) Jt. 376 @ 11,845 Ft. (MD) Corrosion ( 79%) Jt. 358 @ 11,290 Ft. (MD) Corrosion ( 78%) Jt. 355 @ 11,179 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 16%) are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits 10,063 Ft. (MD) 3,876 Ft. (MD) Minimum 1.0. = 2.75" Minimum I.D. = 2.77" Jt. 319 Jt. 122.3 @ @ No other significant I.D. restrictions are recorded throughout the 3.5" tubing logged. I Field Engineer: J. Halvorsen Witness: J. Kralick Analyst: M. Tahtouh 77497 ProAct¡ve Diaonostic Se(',dces¡ p,o, Box 1369, Phone: (281) or (888) 565·9085 Fax: (281) 565-1369 E-mail: PDS(cÙmemorylog.com Prudhoe Sav Field Office Phone: 659-2307 Fax: 659-2314 I I I Well: Field: Company: Country: I Tubing: Nom.OD 3.5 ins I I lR-36 Kuparuk ConocoPhillips Alaska, Ine. USA Weight 9.3 f Grade & Thread l-80 Penetration ami Metal loss (% wall) penetration body metal loss body I 400 300 200 100 0 o to 1% I I 1 to 10% 10 to 20 10 40 to over 20% 40% 85% 85% I I 400 I 300 200 I 100 1 o Damage Configuration ( body) I o isolated general line ring hole I poss pitting corrosion corrosion corrosion ¡ble hole I I I I I PDS Report Overview Body Region Analysis penetration body o o Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.ID 2.992 ins GlM 1 GlM2 GlM3 GlM4 GlM 5 August14,2006 MFC 24 No. 00387 1.69 24 M. Tahtouh Nom. Upset 3.5 ins Upper len. 1.2 ins lower len. 1.2 ins Damage Profile (% wall) metal loss body 50 100 Bottom of Survey 383.6 Analysis Overview page 2 I I Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (28.5' - 12150.9') Well: Field: Company: Country: Survey Date: 1 R-36 Kuparuk ConocoPhiilíps Alaska, Inc. USA August 14, 2006 I I I Approx. Tool Deviation Approx. Borehole Profile I 50 39 I 1571 I 100 3139 GLM 1 150 4722 0 Q.¡ ~ ...Q 200 6271 +' E LL :;¡ .s: z ..s:::. ~ ~ ¡: 0.. GLM2 (!) 0 0 250 7842 I I I I 300 9437 I GLM3 350 11015 I GLM4 GLM5 I 383.6 o 50 12151 100 Damage Profile (% wall) / Tool Deviation (degrees) I I Bottom of Survey = 383.6 I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-36 Kuparuk ConocoPhillips Alaska, Inc. USA August 14, 2006 I I Joint Jt. Depth PerL Pen. Pen. Metal Min. Damage Profile No. (Ft.) ~::::(;t Body ID. Comments (%wall) (Ins.) (Ins.) 0 50 100 .1 29 0 0.04 14 3 2.87 PUP Shallow oittin\!. I .2 32 0 0.03 13 3 2.86 PUP Shallow oittin\!. Lt. Deoosits. 1 39 0 0.03 13 3 2.85 Shallow oitting. I 2 72 0 0.04 1 ( 4 2.90 Shallow oittíng. 3 102 0 0.04 I ", 2.90 Shallow nittinq. U 4 133 0 0.05 2.89 Shallow oiUínq. Lt. Denosits. 5 165 0 0.03 2.89 Shallow nittinq. I 6 196 0 0.04 2.89 Shallow nittinq. 7 226 0 0.03 2.88 Shallow oitting. Lt. Deoosits. II 8 258 n 0.05 2.91 Shallow corrosion. 9 290 0 0.03 () 2.89 Shallow oittiml.. 10 322 0 0.05 () 2.88 Shallow corrosion. 11 353 0 0.04 () 2.90 Shallow corrosion. 12 384 0 0.03 2.90 Shallow oittiml.. 13 415 0 0.04 2.90 Shallow corrosion. 14 446 0 0.03 2.89 Shallow corrosion. 15 478 0 0.04 2.90 Shallow corrosion. 15.1 509 0 0 2.88 DS Níonle 16 511 0 0.04 1 ( () 2.87 Shallow corrosion. Lt. Deoosíts. 17 542 0 0.04 ! 2.87 Shallow corrosion. 18 574 0 0.04 1 2.90 Shallow corrosion. 19 605 0.04 I 2.88 Shallow corrosion. Lt. Denosits. 20 638 I 0.04 2.89 Shallow corrosion. 21 667 I 0.03 2.90 Shallow corrosion. 22 699 I 0.04 ( 2.88 Shallow corrosion. 23 732 0 0.04 5 2.87 Shallow oitting. 24 762 0 0.04 1 r: 2.89 Shallow corrosion. 25 793 0 0.04 2.88 Shallow corrosion. tft 825 oft 2.88 Isolated nittinq. 856 I O. I 2.88 Shallow corrosion. Lt. Deoosits. 28 887 ( 0.04 2.89 Shallow corrosion. 29 919 I 0.08 I 2.90 Isolated oitting. 30 950 ( 0.05 2.90 Shallow corrosion. 31 978 0 0.06 2£ 3 2.91 Corrosion. Lt. Deoosits. 32 1009 0 0.04 1 2.90 Shallow corrosion. 33 1041 0 0.03 2.89 Shallow pitting. 34 1072 0 0.04 2.87 Shallow corrosion. 35 1103 0 0.04 2.90 Shallow corrosion. 36 1134 0 0.03 2.88 Shallow corrosion. 37 1166 0 0.08 30 4 2.87 Isolated Ditting. Lt. DeDosits. 38 1197 0 0.08 30 2.90 Isolated pitting. 39 1229 0 0.04 15 2.88 Shallow Ditting. 40 1258 0 0.11 D 2.85 Corrosion. Lt. Denosits. 41 1289 0 0.08 11 I 2q~@,,~ 42 1320 0 0.09 14 2.91 rrosion. Lt. Denosits. 43 1351 0 0.11 62 2.90 rrosion. 44 0 0.12 16 2.91 rrosion. Lt. Deoosits. 45 1414 0 0.10 41 4 2.90 Corrosion. Lt. Deposits. 46 1446 0 0.10 40 4 2.90 I Corrosion. Lt. Denosits. 47 1477 0 0.12 46 6 2.88 I Corrosion. I I I I I I I I I I I I I Body Metal Loss Body Page 1 I I I PDS REPORT JOINT TABULATION I Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf 1-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-36 Kuparuk ConocoPhillips Alaska, Ine. USA August 14, 2006 I I Joint jt. Depth PC:I Pen. Pen iV1ctal Min. Damage Pro file No. (Ft) Body I.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 48 1508 n 0.11 2.89 Corrosion. 49 1541 n 0.12 2.89 Corrosion. U. Denosi ts. 50 1571 () 0.09 2.90 Corrosion. U. Denosi ts. 51 1603 n 0.13 2.90 Corrosion. 52 1634 n 0.12 46 6 2.89 Corrosion. U. Deoosi ts. 53 1665 0 0.16 62 6 2.91 Corrosion. 54 1694 0.14 '14 6 2.91 Corrosion. 55 1725 0.1200 2.91 Corrosion. It Deposits. 56 1756 0.12 2.89 Corrosion. 57 1788 t 0.12 6 2.90 Corrosion. 58 1819 0 0.15 rig 6 2.90 Corrosion. Lt Deoosits. 59 1849 0 0.12 46 6 2.89 Corrosion. Lt Deoosits. 60 1881 0 0.11 44 2.90 Corrosion. It. Deoosits. 61 1912 0 0.14 54 2.88 Corrosion. Lt Deoosits. 62 1946 ( 0.11 t) 2.90 Corrosion. 63 1985 ( 0.15 2.89 Corrosion. l t Deposi ts. 64 I 7011 ( 0.12 2.89 Corrosion. Lt Denosits. 65 2038 ( 0.14 2.91 Corrosion. 66 2070 0 0.11 ilil Corrosion. Lt Deoosits. 67 2102 0 0.10 40 9 Corrosion. 68 2133 n 0.11 B 6 I 2.90 Corrosion. 69 2166 ( 0.14 2.90 Corrosion. 70 2197 ( 0.11 2.90 Corrosion. Lt Deposits. 71 2226 ( 0.14 2.91 Corrosion. 72 2258 ( 0.11 2.90 Corrosion. Lt. Denosi ts. 73 2290 n 0.13 2.89 Corrosion. Lt Deoosits. 74 2320 0 0.17 ( 2.90 Corrosion. 75 2353 0 0.12 ( 2.91 Corrosion. 76 2383 0 0.14 2.90 Corrosion. 77 2415 0 0.13 2.91 Corrosion. 78 2447 ( 0.15 2.89 Corrosion. 79 2479 ( 0.18 2.90 Corrosion. 80 2511 ( 0.13 2.91 Corrosion. Lt Denosits. 81 2543 ( 0.12 7 2.90 Corrosion. 82 2574 0 0.12 2.87 Corrosion. Lt. Deoosits. 83 2606 ( 0.14 n 2.90 Corrosion. 84 2636 ( ±ft13 2.90 Corrosion. 85 2668 12 2.89 Corrosion. Lt. Deposits. 86 2700 0.12 2.89 Corrosion. 87 2731 0.10 2.88 Corrosion. Lt Deposits. 88 2762 0.11 2.87 Corrosion. U. Denosits. 89 2793 0 0.12 ( 2.90 Corrosion. U. Deoosits. 90 2824 n 0.13 )( I 2.90 Corrosion. Lt Deoosi ts. I 91 2856 0 0.13 9 2.89 Corrosion. Lt. Deoosits. 92 2888 n 0.12 2.90 Corrosion. 93 2919 n 0.13 2.89 Corrosion. 94 2950 () 0.13 I 2.91 Corrosion. Lt Denosits. 95 2981 0 0.11 2.89 Corrosion. 96 3013 IJ 0.11 4 2.90 Corrosion. 97 3044 0 0.13 'i a 2.88 Corrosion. Lt Deoosits. I I I I I I I I I I I I I Body Metal Loss Body Page 2 I I I PDS REPORT JOINT TABULATION S I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-36 Kuparuk ConocoPhillips Alaska, Ine. USA August 14, 2006 I I Joint Jt. Depth Pe:¡, Pen. Pell 'Melal Min. Damage Profile No. (Ft.) Body !.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 98 3077 0 0.13 SO II 2.91 Corrosion. 99 3108 0 0.12 47 9 2.90 Corrosion. 100 3139 0 0.13 51 (\ 2.88 Corrosion. Lt. Deoosits. 101 3171 0 0.12 2.88 Corrosion. Lt. Deoosi ts. 102 3203 n 0.11 2.89 Corrosion. 103 3234 0 0.14 I 2.91 Corrosion. Lt. Deoosits. 104 3266 0.12 2.89 Corrosion. Lt. Deoosits. 105 3297 0.13 2.89 Corrosion. 106 3326 2.86 Corrosion. Lt. Deoosits. 107 3358 0.10 3 2.90 Corrosion. Lt. Deoosits. 108 3387 () 0.14 (\ 2.90 Corrosion. Lt. Deoosits. 109 3418 0 0.11 7 2.89 Corrosion. 110 3450 n 0.14 n 2.89 Corrosion. 111 3481 n 0.14 2.88 Corrosion. Lt. 112 3513 0 0.14 2.90 Corrosion. Lt. Deoosits. 113 3549 () 0.12 17 2.91 Corrosion. Lt. Deoosits. 114 3581 C) 0.13 52 2.90 Corrosion. Lt. Deoosits. 115 3612 0 0.11 42 2.89 Corrosion. 116 3644 n 0.10 7 2.90 Corrosion. 117 3675 ±±&Ii 2.90 Corrosion. Lt. Deoosits. 118 3706 2.90 Corrosion. 119 3736 n 0.15 2.89 Corrosion. 120 3768 0 0.16 I 2.89 Corrosion. Lt. Deoosits. 121 3799 0 0.16 6,'1 2.92 Corrosion. Lt. Deoosits. 122 3830 0 0.14 53 2.90 Corrosion. 122.1 3862 0 0.07 29 2 2.84 PUP Corrosion. 122.2 3868 0 0 N/A GLM 1 (Latch @ 3:30\ 122.3 3874 0.04 0.09 2.77 PUP Corrosion. Lt. Deposits. 123 3879 n 0.16 2.90 Corrosion. U. Denosits. 124 3911 () 0.15 2.90 Corrosion. 125 3943 () 0.14 2.91 Corrosion. Lt. Deoosits. 126 3974 0 0.16 (,3 2.90 Corrosion. Lt. Deoosits. 177~6 o 17 0.17 ( , 2.90 Corrosion. Lt. Deoosits. 128 037 0.14 2.90 Corrosion. 129 4068 0.16 (I 2.91 Corrosion. 130 4099 0.12 2.90 Corrosion. Iff 0.16 2.90 Corrosion. 1 4163 0 0.17 2.91 Corrosion. 4194 0 0.18 2.91 Corrosion. Lt. Deoosi ts' 4226 0 0.14 '16 9 2.91 Corrosion. 4257 0 0.16 (! 10 2.90 Corrosion. Lt. Deoosits. 13 4289 () 0.17 1:5 (\ 2.90 Corrosion. Lt. Deposits. 137 4321 n 0.14 II 2.90 Corrosion. Lt. Deoosits. 138 4352 0 0.16 2.88 Corrosion. Lt. Deposi ts. 139 4382 n 0.15 2.89 Corrosion. Lt. Deoosits. 140 4413 0 0.14 2.91 Corrosion. U. Deoosits. 141 4443 0 0.15 5a 2.89 Corrosion. Lt. Deoosits. 142 4475 0 0.14 56 7 2.87 Corrosion. U. Deposits. 143 4506 n 0.12 4a q 2.87 I rorrosion. Lt. Deposi 5. 144 4536 n 0.14 '17 10 2.90 Corrosion. I t. Deoosi ts. I I I I I I I I I I I I I Body Metal Loss Body Page 3 I I I PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L-80 Well: 1 R-36 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Ine. NominaII.D.: 2.992 in Country: USA Survey Date: August 14, 2006 I Joint ]t. Depth Pelv Pen. Pelv IV1e1al Min. Damage Profile No. (Ft.) ,IPS';: Body I.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 I 145 4568 0 0'1411i 13 2.91 Corrosion. 146 4598 0 0.15 10 2.91 Corrosion. 147 4628 0.06 0.15 II 2.89 Corrosion. Lt. Deoosits. 148 4659 +i' 0.15 2.90 Corrosion. Lt. Deoosits. I 149 4691 0.17 I i' 2.91 Corrosion. Lt. Deposi ts. 150 4722 i' 0.16 I 1 2.90 Corrosion. It. Deposits. 151 4753 0.14 ì 2~ Corrosion. Lt. Deoosits. 152 4785 ( 0.13 i' 2. Corrosion. Lt. Deoosits. 153 4815 0 0.15 , 9 2. Corrosion. Lt. Deposits. I 154 4846 0.15 60 9 2.90 Corrosion. Lt. Deoosi ts. 155 4877 : mJ5' 9 2.90 Corrosion. It. Deposits. 156 4909 o Of) , 2.90 Corrosion. 157 4940 o ()q 6 I 2.90 Corrosion. Lt. Deoosits. I 158 4972 0.16 I 2.91 Corrosion. It. Deoosits. 159 5003 O. I 0.15 2.91 Corrosion. Lt. Deposi ts. 160 5033 0.17 I 0 2.90 Corrosion. Lt. Denosits. 161 5065 0 0.14 r 1 2.91 Corrosion. I 162 5096 0 0.15 5B 12 2.91 Corrosion. It. Deposits. 163 5126 () 0.11 42 9 2.92 Corrosion. Lt. Deposits. 164 5157 0 01'i {¡¡ 1 2.92 Corrosion. Lt. Deposits. 165 5192 0 0.16 II 2.91 Corrosion. Lt. Deoosits. I 166 5222 0 0.15 n 2.90 Corrosion. Lt. Deoosits. 167 5252 0 0.16 12 2.91 Corrosion. Lt. Denosits. 168 5284 0 0.15 2.90 Corrosion. It. Deposits. 169 5316 0 0.15 15 2.90 Corrosion. Lt. Deposits. 170 5347 0 0.15 11 2.91 Corrosion. Lt. Deposits. I 171 5378 0.12 4 9 2.93 Corrosion. Lt. Deposits. 172 5410 0.18 n 2.91 Corrosion. Lt. Deposits. 173 5441 0.14 II 2.91 Corrosion. Lt. Denosi ts. 174 5472 0.12 4 I 2.91 Corrosion. Lt. Deoosits. I 175 5505 0.12 9 2.92 Corrosion. Lt. Denosi ts. 176 5535 0 0.15 59 2.92 Corrosion. Lt. Deoosits. 177 5565 f 0.14 53 10 2.89 Corrosion. Lt. Deoosits. 178 5593 0.14 56 9 2.89 Corrosion. Lt. Deposits. I 179 5624 ( 2.87 Corrosion. It. Deposits. 180 5655 ~ 2.90 Corrosion. Lt Deposits. 181 5684 0.14 \ 2.88 Corrosion. It. Deoosits. 182 5716 ( 0.15 57 L) 2.87 Corrosion. Lt. Deposits. 183 5745 0.13 ')2 11 2.89 Corrosion. Lt. Deposits. I 184 5777 0 0.16 6· '14 2.88 Corrosion. Lt. Deposits. 185 5806 0 0.17 ( 12 2.89 Corrosion. Lt. Deposits. 186 5838 ! 0.13 , 11 2.90 Corrosion. Lt. Deposits. 187 5869 I 0.13 2.90 Corrosion. U. Deposits. I 188 5901 I 0.13 ( 2.89 Corrosion. Lt. Deposits. 189 5932 I 0.13 2.89 Corrosion. Lt. Deoosits. 190 5963 ( 0.19 13 2.85 Corrosion. Lt. Deposits. 191 5994 ( 0.13 '11 2.92 Corrosion. It. Deposits. I 192 6025 (1.09 0.12 46 1-¡ 2.91 Corrosion. It. Deposits. 193 6054 ( 0.15 r¡q 13 2.90 Corrosion. Lt. Deposits. 194 6084 ( 0.15 60 9 2.87 Corrosion. Lt. Deposits. I Body Metal Loss Body Page 4 I I ------------- I PDS REPORT JOINT TABULATION S I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-36 Kuparu k ConocoPhillips Alaska, Inc. USA August 14, 2006 I I Joint )t. Depth Pen. Pen. Pen. ¡\flelal Min. Damage Profile No. (Ft.) (::::,;1 Body 1.0. Comments (%wall) (Ins.) (Ins.) 0 50 100 195 6116 0 0.13 51 II 2.87 Corrosion. Lt. Denosits. 196 6147 0 0.15 I 2.89.1 ~orrosion. U. Denosits. 197 6179 0 0.16 I 1 2.88 ·on. U. Denosits. 198 6210 0 0.13 II 2.92 Corrosion. Lt. Denosits. 199 6242 0 0.13 (1 2.90 Corrosion. Lt. Denosits. ~ 6271 0 0.14 I 2.89 Corrosion. Lt. Denosits. 6302 000 0.15 I 12 2.89 Corrosion. U. Denosi 5. 6333 011 0.16 =i 10 2.90 Corrosion. Lt Denosits. 203 6365 0 0.10 q 2.91 Corrosion. U. Denosi ts. 204 6396 0.06 0.14 In 2.90 Corrosion. U. Denosi ts. 205 6427 n 0.12 q 2.92 Corrosion. U.Denosits. 206 6457 0 0.12 <) 2.89 Corrosion. U. Denosi ts. 207 6488 nno 0.16 I 2.87 Corrosion. Lt. Denosits. 208 6519 010 0.18 2.88 Corrosion. Lt. Denosits. 209 6551 Ir 2.89 Corrosion. Lt. Denosits. 210 6582 0.14 2.90 Corrosion. U. Denosits. 211 6609 .14 2.89 Corrosion. U. Denosits. 212 6640 .17 I 2.89 Corrosion. Lt. Denosits. 213 6670 .17 I 11 2.88 Corrosion. Lt. Denosits. 214 6703 o 0.13 n 2.91 Corrosion. Lt. Denosi ts. 215 6735 o 0.10 In 2.92 Corrosion. U. Denosi ts. 216 6765 0 0.12 41 q 2.90 Corrosion. Lt. Denosits. 217 6797 o i)£) 0.11 n q 2.92 Corrosion. Lt. Denosi ts. 218 6827 0 0.11 9 2.90 Corrosion. U. Denosi ts. 219 6858 0 0.15 I 2.93 Corrosion. U. Denosi ts. 220 6889 0 0.15 I 2.90 Corrosion. U. Denosits. 221 6920 I 0.15 I/, 2.92 Corrosion. Lt. Denosits. 222 6957 1 0.11 III 2.92 Corrosion. U. Deoosi ts. 223 6988 ) 0.12 II 2.92 Corrosion. Lt. Denosits. 224 7015 0.15 9 n 2.88 Corrosion. Lt. Denosi ts. 225 7045 0 0.12 ß 2.91 Corrosion. Lt. Denosits. 226 7077 0 0.12 9 ( 2.92 Corrosion. Lt. Denosits. 227 7108 0 0.18 1 "I) 2.89 Corrosion. Lt Denosits. 228 7139 0 0.16 /,2 c 2.90 Corrosion. Lt. Denosits. 229 7170 ono 0.16 h4 14 2.90 Corrosion. Lt. Denosits. 230 7202 0 0.14 16 12 2.91 Corrosion. U. Deoosi ts. 231 7231 n 0.12 46 9 2.91 Corrosion. Lt. Denosi ts. 232 7260 0 0.17 67 I' 2.90 Corrosion. U.Denosits. 233 7292 0.10 0.16 I I 2.89 Corrosion. U. Denosi ts. 234 7324 0 0.16 I 1 2.91 Corrosion. Lt Denosits. 235 ;7355 íì íì7 0.16 1 2.90 Corrosion. Lt. Denosits. 236 7387 0.14 2.91 Corrosion. U. Denosi ts. 237 7419 0.16 11 2.92 Corrosion. Lt. Denosits. 238 7453 0.15 61 1\ 2.92 Corrosion. U. Denosi ts. 239 74~ 0.18 '0 14 2.93 Corrosion. Lt. Denosits. 240 751 0 0.16 1 11 2.92 Corrosion. Lt. Denosits. 240.1 7545 íì íì6 0.18 1 ., 2.85 PUP Corrosion. Lt. Denosits. 240.2 7551 n 0 I N/A GLM 2 {Latch @ 3:00\ 240.3 7557 íì 0.20 B 7 2.85 PUP Corrosion. Lt. Denosits. 241 7563 012 0.16 ~4 n 2.91 Corrosion. U. Denosits. I I I I I I I I I I I I I Body Metal Loss Body Page 5 I I I PDS REPORT JOINT TABULATION SHEET I Pipe: ßodyWall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L·80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-36 Kuparuk ConocoPhillips Alaska, inc. USA August 14, 2006 I I Joint Jt. Depth Pell Pen. Pen. jvletal Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) (Ins) (Ins.) 'i{, (Ins.) 0 50 100 242 7594 0 0.15 59 9 2.93 Corrosion. Lt. DelJosi ts. 243 7626 0 0.11 [) 7 2.93 Corrosion. Lt. DelJosi ts. 244 7657 0 0.16 (3 12 2.92 Corrosion. Lt. Deoosits. 245 7689 0 0.15 '·13 9 2.93 Corrosion. Lt. Deoosits. 246 7719 0 0.11 n 2.92 Corrosion. Lt. Deoosits. 247 7749 n 0.14 r 11 ~ Corrosion. Lt. Deoosits. 248 7780 I 0.12 on. Lt. Deoosits. 249 7812 IU 17 0.12 I) 2.91 Corrosion. Lt. Deoosits. 250 7842 13 10 2.90 Corrosion. Lt. Deoosits. 251 7873 C 0.11 9 2.91 Corrosion. Lt. Deoosits. 252 7907 0 0.10 6 2.92 Corrosion. U. Denosi ts. 253 7939 0.12 ¡ 6 2.90 Corrosion. Lt. Denosi ts. 254 7970 n 14 0.14 f: ¡C, 2.92 Corrosion. Lt. Denosits. 255 8000 0.12 2.91 Corrosion. U. Deoosi ts. 256 8032 0.17 I 2.91 Corrosion. Lt. Deoosits. 257 8064 0.12 2.90 Corrosion. Lt. Deoosits. 258 8O~ 10 2.92 Corrosion. Lt. Deoosits. 259 8125 6 2.88 Corrosion. Lt. DelJosits. 260 815 q 2.88 Corrosion. Lt. Denosits. 261 8186 C 0.12 2.92 Corrosion. Lt. Denosits. 262 8219 C 0.09 2.92 Corrosion. L1. Deoosits. 263 8250 () h 0.15 2.83 Corrosion. Lt. Deoosi ts. 264 8280 O. C) 0.12 2.88 Corrosion. Lt. Deoosits. 265 8310 0.0 8 0.17 65 J3 2.89 Corrosion. Lt. DelJosits. 266 8342 0.0 6 0.18 19 14 2.91 Corrosion. L1. DelJosits. 267 8372 0 0.16 13 1J 2.89 Corrosion. Lt. Deposits. 268 8404 0:11\ 0.16 ) It 2.89 Corrosion. L1. Denosits. 269 8437 0.- IS 0.13 2.91 Corrosion. L1. Deoosits. 270 8468 0.12 2.90 Corrosion. Lt. Deoosi ts. 271 8499 0.12 2.91 Corrosion. Lt. Deoosits. 272 8527 O. 10 0.11 2.90 Corrosion. L1. Deoosits. 273 8560 0 0.13 I n 2.92 Corrosion. L 1. DelJosi ts. 274 8601 0.12 0.13 ¡ 2.86 Corrosion. Lt. DelJosits. 275 8655 I 0.13 2.88 Corrosion. L1. Deposits. 276 8687 Oi )7 0.12 2.88 Corrosion. 1.1. Denosi ts. 277 8719 0.09 2.88 Corrosion. I.t. Deoosits. 278 8750 0.10 2.91 Corrosion. Lt. Denosits. 279 8780 0.12 2.90 Corrosion. Lt. DelJosits. 280 8811 0.15 1 II 2.85 Corrosion. L1. Deoosits. 281 8843 0 0.13 5 7 2.89 Corrosion. L1. Deposits. 282 8875 0 0.12 :1 2.92 Corrosion. Lt. Deoosi ts. 283 8907 011 0.12 2.91 Corrosion. Lt. Denosi ts. 284 8938 0.12 2.95 Corrosion. Lt. Deoosits. 285 8969 0.12 2.93 Corrosion. Lt. Denosi ts. 286 9001 0.: 14 0.14 2.93 Corrosion. 1.1. Deoosits. 287 9031 0.1 17 0.13 2.93 Corrosion. L1. Deoosits. 288 9060 0 0.19 15 2.91 Corrosion. 1.1. Denosits. 289 9091 0011 0.16 I Ii) 2.90 Corrosion. Lt. Deoosits. 290 9122 0 0.18 It 2.88 Corrosion. L1. Deoosits. 291 9152 0 0.13 13 2.89 Corrosion. L1. Deoosits. I I I I I I I I I I I I I Page 6 I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-36 Kuparuk ConocoPhillìps Alaska, Inc. USA August 14, 2006 I I Joint J1. Depth 1)('11. Pen. Pen. ,'vlelal Min. Damage Profile No. (Ft.) Body to. Comments (%wall) (Ins 1 (Ins.) (Ins.) 0 50 100 292 9184 0 0.14 57 7 2.88 Corrosion. Lt. Deoosits. 293 9?1h 0 0.13 52 9 2.88 Corrosion. L1. Deoosits. 294 9246 008 0.19 '5 'I' 2.89 Corrosion. Lt. Denosi ts. 295 9278 0 0.17 15 jJ 2.91 Corrosion. Lt. Denosi ts. 296 9311 ( 0.13 9 2.93 Corrosion. U. Denosi ts. ~ 9343 IL :~ itttt 1 H 2.92 Corrosion. Lt. Denosi ts. 9374 I 1 2.91 Corrosion. Lt. Denosits. 299 9405 0 1 2.91 Corrosion. Lt. Deoosits. 300 9437 ( 0.14 2.90 Corrosion. U. Deoosi ts. 301 9468 ( 0.15 2.92 Corrosion. Lt. Deoosits. 302 9500 IC, 19 0.12 46 a 2.93 Corrosion. Lt. Deoosi ts. j03 9531 0 mr 2.93 Corrosion. Lt. DeDosits. 304 9562 o.oa 0.1 2.91 Corrosion. U. Denosi ts. 305 9594 0.05 2.92 Corrosion. Lt. Denosits. )06 9625 n.' 16 0.11 2.93 Corrosion. Lt. Denosi ts. 307 9656 0.13 2.93 Corrosion. Lt. Deoosi ts. 308 9688 0.18 I? 2.89 Corrosion. Lt. Deoosi ts. 309 9718 0.14 9 2.91 Corrosion. Lt. DeDosits. 310 9749 n 0.16 65 í4 2.91 Corrosion. Lt. Denosi ts. 311 9782 0 0.15 1 J 2.93 Corrosion. Lt. Denosits. 312 9814 00'1 0.17 1 2.93 Corrosion. Lt. Deoosits. 313 9845 0 0.14 2.95 Corrosion. Lt. Deoosits. 314 9875 0 0.14 2.92 Corrosion. Lt. DeDosits. 315 9906 OiO 0.17 7 10 2.91 Corrosion. Lt. Deoosits. 316 9936 D 0.17 0 II 2.93 Corrosion. Lt. DeDosits. 317 9968 0 0.19 16 H 2.92 Corrosion. Lt. Deposits. 317.1 9995 0.07 0.19 13 2.89 PUP Corrosion. Lt. Denosits. 317.2 10001 ) 0 0 N/A GLM 3 (Latch @ 10:00\ 317.3 10007 0.12 ,; 2.93 PUP Corrosion. 318 10016 0' )g 0.15 8 2.91 Corrosion. Lt. Deoosits. 319 10048 0.18 ) 4 2.75 Corrosion. Deoosits. 320 10083 0.14 q 2.91 Corrosion. Lt. Deoosits. 321 10116 0.16 10 2.94 Corrosion. Lt. Deoosits. 322 10146 II 0.19 15 2.90 Corrosion. Lt. Deposits. 323 10175 euo 0.19 13 2.91 Corrosion. Lt. Denosits. 324 10207 0.15 1 2.92 Corrosion. Lt. Deoosits. 325 10239 0.16 1 2.92 Corrosion. Lt. Deoosits. 326 10269 0.20 J 2.91 Corrosion. Lt. Deoosits. 327 10302 0.' 19 0.18 1 2.93 Corrosion. Lt. DeDosits. 328 10332 O. i3 0.15 61 )' 2.92 Corrosion. Lt. Deposits. . I 329 10362 U 0.17 7 14 2.91 Corrosion. Lt. Deposits. 330 10393 O. ie} 0.18 13 2.94 Corrosion. Lt. Deposits. 331 10425 0.19 I) 2.93 Corrosion. Lt. Deoosits. 332 10456 0 D? 0.17 II 2.91 Corrosion. Lt. DeDosits. 333 10487 J 0.17 II 2.91 Corrosion. Lt. Deoosits. 334 10519 ) 0.16 10 2.91 Corrosion. Lt. Deoosits. 335 10549 ) 0.18 Ie¡ 2.91 Corrosion. Lt. Deposits. 336 10581 0 0.19 74 14 2.92 Corrosion. Lt. Deposits. 337 10613 onh 0.19 7'1 q 2.92 Corrosion. Lt. Deoosits. 338 10648 0 0.14 '16 7 2.93 Corrosion. Lt. Deoosits. I I I I I I I I I I I I I Page 7 I I I PDS REPORT JOINT TABULATION S EET I Pipe: Body Wall: Upset Wall: NominaILD.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-36 Kuparuk ConocoPhillips Alaska, Inc. USA August 14, 2006 I I I Joint Jt. Depth Pen Pen. Pen. ¡\!Ietal Min. Damage Profile No. (Ft.) Body 1.0. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 339 10678 0 0.18 ! 2.90 Corrosion. Lt. Denosi ts. 140 10706 0 0.20 1 2.89 Corrosion. Lt. Denosits. 341 10738 0 0.23 1 2.89 Possible HOLE! 342 10769 0 0.20 I 2.87 Corrosion. Lt. Denosits. 343 10802 0 0.18 I 2.90 Corrosion. Lt. Deoosits. 344 10833 0..00 0.16 Ii: 2.92 Corrosion. Lt. Deoosits. 345 10862 0 0.17 1, 2.94 Corrosion. Lt. Deoosits. 346 10894 11 0.19 I 2.92 Corrosion. Lt. Deoosits. 347 10924 J. IJ 0.17 ! 2.89 Corrosion. Lt. Denosits. 348 10953 \ 0.19 I 2.86 Corrosion. Lt. Denosits. 349 10985 IH Wt±1 2.90 Corrosion. Lt. Deoosits. 350 11015 1 2.92 Corrosion. Lt. Deoosits. 351 11053 0.' )() 0.191. 2.91 Corrosion. Lt. Deoosits. 352 11085 0.19 75 (I 2.91 Corrosion. U. Deoosits. 353 11114 0 0.19 74 n 2.90 Corrosion. U. Deoosits. 354 11146 0 0.17 12 2.91 Corrosion. Lt. Deoosits. 355 11176 0 0.20 1.S 2.91 Corrosion. Lt. Denosits. 356 11206 0.17 ¡ 1 2.85 Corrosion. U. Denosits. 357 11238 0.17 PI 2.92 Corrosion. U. Deoosits. 358 11267 0.20 12 2.89 Corrosion. Lt. Deoosits. 359 11297 0.15 ¡ 3 2.87 Corrosion. Lt. Deoosits. 360 11328 011 0.17 hS 1 'j 2.91 Corrosion. Lt. Deoosits. 361 113 60 0.10 0.19 74 15 2.91 Corrosion. U. Deoosits. 361.1 11391 O.DB 0.09 7 4 2.86 PUP Corrosion. U. Denosits. 361.2 11396 0 0 0 N/A GLM 4 (Latch @ 11 :30\ 361.3 11403 o.on 0.11 I 2.79 PUP Corrosion. Lt. Deoosits. 362 11409 010 0.18 I 2.90 Corrosion. Lt. Deoosits. 363 11439 0 0.19 I 2.91 Corrosion. Lt. Deoosits. 364 11470 CLOB 0.16 I, 2.94 Corrosion. Lt. Deoosits. 365 11501 0.10 0.19 76 12 2.92 Corrosion. U. Deoosits. 366 11532 0.01 0.18 72 14 2.92 Corrosion. Lt. Deposits. 367 11564 01 0.16 ,I 1 ¿ 2.94 Corrosion. U. Deoosits. 368 11595 o Oi 0.16 1. 2.90 Corrosion. Lt. Denosits. 369 11630 0.01 0.15 1 2.85 Corrosion. Lt. Deoosits. 370 11 660 0 0.19 I 2.90 Corrosion. U. Deoosi ts. 371 11688 UII 0.16 I 2.93 Corrosion. Lt. Deoosits. 372 11720 0 0.17 1 2.92 Corrosion. Lt. Deposits. 373 11747 01 J 0.19 I 2.92 Corrosion. Lt. Deposits. 374 11781 0 0.17 I 2.91 Corrosion. Lt. Denosits. 375 ~'813 0.1), 0.18 2.9 on. U. Deoosi ts. 376 11842 iOl 0.20 2.91 Corrosion. U. Denosits. 377 11875 I 0.19 2.90 Corrosion. Lt. Deoosits. 378 1905 ¡.on 0.17 2.92 Corrosion. U. Deoosits. 379 11935 HJ 0.18 0 12 2.90 Corrosion. U. Deposits. 380 11964 0.1 J 0.18 I 2.89 Corrosion. Lt. Deoosits. 381 11994 0 0.19 2.90 Corrosion. Lt. Deoosits. 1m 12027 (1) 0.19 2.90 Corrosion. U. Denosits. 382.1 12058 0 0.18 2.84 PUP Corrosion. Lt. Deoosits. 382.2 12066 0 0 N/A GLM 5 (Latch @ 8:30\ 382.3 12072 O.W 0.16 1 10 2.83 PUP Corrosion. U. Deoosits. I I I I I I I I I I I I Body Metal Loss Body Page 8 I I I I Pipe: Body Wall: Upset Wall: NominaII.D.: I I PDS REPORT JOINT TABULATION SH 3.5 in 9.3 ppf 1.-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 R-36 Kuparuk ConocoPhillips Alaska, Inc. USA August 14, 2006 Joint Jt Depth No. (Ft.) Comments I 383 383.1 383.2 383.3 383.4 383.5 383.6 I I I I I I I I I I I I I I 12077 12112 12122 12139 12143 12145 12151 Page 9 Damage Profile (%wall) o 50 100 Body Metal Loss Body ............ Well: Field: Company: Country: Tubin : ............- - .. PDS Report Cross Sections 1 R·36 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L·BO Survey Date: Tool Type: Tool Size: ,"10. of Fingers: Anal st: August 14, 2006 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 341 at depth 10739.19 ft Tool speed = 62 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 95 % Tool deviation = 67 0 Finger 13 Penetration 0.234 ins Possible Hole 0.23 ins = 92% Penetration HIGH SIDE = UP Cross Sections page 1 .. .. .. .. ------ ------- .. ----- PDS Report Cross Sections Well: Field: Company: Country: Tubin : 1R·36 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L·80 SUlvey Date: Tool Type: Tool Size: No. of Fingers: Anal st: August 14,2006 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 340 at depth 10735.63 ft Tool speed 59 NominallD 2.992 Nominal 00 = 3.500 Remaining wall area = 96 % Tool deviation = 65 0 Finger 11 Penetration = 0,203 ins Corrosion 0.20 ins = 80% Penetration HIGH SIDE UP Cross Sections page 2 ------ ------- ------ PDS Report Cross Sections Well: Field: Company: Country: Tubin : 1 R·36 Kuparuk ConocoPhi!lips Alaska, Inc. USA 3.5 ins 9.3 f L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: August 14, 2006 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 319 at depth 10062.88 it Tool speed 59 NominallD 2.992 Nominal 00 = 3.500 Remaining wall area = 93 % Tool deviation = 77 0 Finger 14 Projection -0.232 ins Deposits Minimum 1.0. = 2.75 ins HIGH SIDE = UP Cross Sections page 3 I KRU 1R-36 I API: 500292305700 Well Tvoe: INJ Anale (â) 33 dea (â) 12237 TUBING SSSV Type: Nipple Orig 4/17/2002 Angle @ To: 31 deg @ 12700 (0-12151, Comoletion: 00:3.500, 10:2.992) Annular Fluid: lastW/O: Rev Reason: TAG Fill, PUll PLUG Reference Loa: RefLoa Date: Last Undate: 8/6/2006 Last T aa: 12500 TO: 12700 ftKB ~8/6/2006 Max Hole Annie: 70 den (fjJ 3631 ~ SURFACE Ton (0-7419, Descrintion Size Bottom TVD Wt Grade 00:9.625, CONDUCTOR 16.000 0 158 158 62.58 PI5LGrE wt:40.oo) SURFACE 9.625 0 7419 4152 40.00 L-80 BTC 7.000 0 12664 6942 26.00 L-80 BTC-MOD 1"ÛbìniiStt¡nn/..~ / 'ROOUCTION Size Ton I Bottom Ii WI H~. I Thread (0-12664, 3.500 I 0 T 9.30! L-80 I EUE8rdMOD 00:7.000, Wt:26.00) Interval TVD lone S Date Tvna Comment 12284 - 12298 6619 - 6631 C-1 6 4/17/2002 IPERF 2.5" PJ. 2506 PJ, 60 deg ph 12442 - 12460 6753 - 6768 A-4,A-3 6 4/14/2003 APERF 2.5" PJ HSD. 60 deg phase 12460 - 12480 6768 - 6785 A-3 6 4/10/2003 APERF 2.5" PJ HSD 60 den chase 12504 - 12510 6806 - 6811 A-2 6 411 0/2003 APERF 2.5" PJ ~SD. 60 f phase I 8t MO TVO Man Man Type V Mfr V Type VOD Latch Port TRO Date Mfr Run Cmnt 1 3864 2701 CAMCO KBUG CAMCO DMY 1.0 BK-5 0.000 0 2/28/2001 2 7542 4204 CAMCO KBUG CAMCO DMY 1.0 BK-S 0.000 0 2/28/2001 3 9992 5194 CAMCO KBUG CAMCO DMY 1.0 BK-5 0.000 0 2/28/2001 4 11386 5904 CAMCO KBUG CAMCO D~ 0.000 0 2/28/2001 ~ CAMCO DMY 0.000 0 4/4/2002 ~ Descrintion 10 ~ LANDING DS NIPPLE WINO GO PROFILE 2.875 12109 PBR BAKER 80-40 PBR 3.000 12132 6491 PKR BAKER SAB-3 PACKER 4,000 PBR 12143 6501 NIP CAMCO DS NIPPLE WINO GO PROFILE 2.812 12109-12110, II! 3.000 00:5.810) 07 TTL 2.992 PKR 7/27/2 UBING LEAK DETECTED (fjJ 11 820' ELMD 12132·12133, 00:5.960) NIP 12143-12144, 00:4.520) 50s 12150-12151, 00:3.500) -- - Perf - -- 12284-12298) -- -- - ~ -- ~ Perf - ~ 12442·12460) - ~ Perf --. -- 124ro-12480) - .-- - -- Perf - I-- 12504-12510) -- -- - 1--- = I----- 1--- - I-- ... !io. I I I I I I I I I I I I I I I I I FW: lR-36 (201-227) . . Tom & Jim, In regards to 1 R-36, diagnostics have been completed. The tbg condition is beyond patch repair as two tbg leaks were confirmed and the tbg caliper indicates there may be multiple tbg leaks in the vicinity of the known leaks. The well will remain SI until the tbg is replaced. Marie -----Original Message----- From: NSK Problem Well Supv Sent: Sunday, August 13, 2006 5:04 PM To: 'Thomas Maunder' Cc: 'Jim Regg' Subject: RE: 1R-36 (201-227) ,; C. *,,-1 j\Î. '&;. ÍJ. W~;n:, r. I;~... (,." , \J .~ ~k Tom, 1 R-36 Injection profile was completed on 8/6/06. The well was SI on 8/9/06 at 10am. The well remains SI while preparing for a tbg patch. Marie McConnell Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Friday, August 04,20069:15 AM To: 'Thomas Maunder' Cc: Jim Regg Subject: 1R-36 (201-227) Tom, Injection we1l1R-36 (201-227) had a passing CMIT TxlA yesterday and the TIP was subsequently pulled. Per prior agreement with the Commission, the well will be brought back online 8/4/2006 for not more than 7 days to get an injection profile. After which it will be SI and prepared for a tubing patch and the Commission notified of the SI date. The CMIT data is as follows: Initial 800/800/0; Starting 2490/2525/0, 15 min 2450/2500/0, 30 min 2430/2490/0; 2nd attempt initial 2430/2490/0, starting 2510/2565/0, 15 min 2510/2550/0, 30 min 2510/2550/0 - Pass The CMIT data will be submitted to the Commission on a standard MIT form if desired. 10f2 8/16/20062:22 PM FW: lR-36 (201-227) . . MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 20f2 8/16/20062:22 PM RE: lR-36 Produced Water Injector (PTD#201-227) . . Tom, Thanks for the feed back. CPAI will CMIT 1 R-36 before pulling the plug and contact you when we initiate injection and again once we S/I the well. Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, August 02, 20063:56 PM To: NSK Problem Well Supv Cc: Jim Regg Subject: Re: 1R-36 Produced Water Injector (PTD#201-227) Perry, It is acceptable to return the well to service for the injection profile you describe. Since it appears that you could inject with the IA pressure up to 2500 psi, it is appropriate to conduct a CMIT on the well to a minimum of 2500 psi. Please message when you initiate injection and when the well is S1. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 8/2/20061:25 PM: Tom, The last passing MITIA was a 4 year state witnessed test to 2200 psi on 05/14/06. After failure it has a liquid leak rate of 2.1 gpm at 3000 psi. Perry -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, August 02, 2006 1: 15 PM To: NSK Problem Well Supv Cc: James Regg Subject: Re: 1R-36 Produced Water Injector (PTD#201-227) lof2 8/16/20062:22 PM RE: lR-36 Produced Water Injector (PTD#201-227) . . Perry, When was the last MIT on the well? Tom NSK Problem Well Supv wrote, On 8/2/2006 12:46 PM: Tom & Jim, CPAI would like permission to put 1 R-36 (PTD # 201-227) on injection for up to 7 days in order to log an injection profile (lPROF). The well is currently S/I and secured with a CA-2 Plug in the DS nipple at 12143' 07/24/06. Electric line identified one leak at 11820' on 07/27/06. CPAI plans to submit for approval, a plan to patch 1 R-36 pending results from an upcoming caliper log of the tubing. To aid in the decision making process, the production engineers would like an IPROF pre patch since logging tools will not fit through the patch. While on injection the IA would be monitored daily and the tubing pressure regulated such that the IA is limited to 2500 psi or less. If approved CPAI will notify AOGCC when injection commences and again once the well is S/!. Call or write with any questions Sincerely, Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 «1 R-36.pdf» 2 of2 8/16/20062:22 PM RECE\VED ,ÄU~ () 15 2006 08/01/06 Scblumbepgep ~ On & Gas Cons. CQ!T',rr;~ Anchorage NO. 3899 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth " ~ 'ì\\\¡Î:¡ _. '" 1 1 C. ¡ I::. '-J-' '.,.{'c(}.NN,I-C; ;,ViA .~ ::n...l~';.) ,'~ "1.-.- Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ') í í' 80 \ -dd1-' t, ".-1-- \..,...../ Field: Kuparuk Well Job # Log Description BL Date Color CD 1J-101 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1 D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1G-05 11249932 INJECTION PROFILE 07/28/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 1 D-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25/06 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1Y-32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1 1Y-24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1D-107 11216309 INJECTION PROFILE 07/12/06 1 1 D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 . 11213788 PROD PROFILE W/DEFT 07/26/06 1 1Y -05 11216310 LDL 07/27/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . lR-36 (PTD 201-227) Report of TxIA comm e Tom & Jim, Injection we1l1R-36 (PTD 2012270) has TxlA communication. A diagnostic MITIA failed on 7/13/06 after operations reported the IA could not be maintained below the 2000 psi max operating pressure and was equalizing with tbg water injection pressure earlier in the day. The wellhead pressure prior to the MITIA attempt while on water injection was TII/O = 2225/2150/470. The IA was pressured up to 3000 psi to start the MITIA, falling off to 2650 psi in 10 mins. The IA was bumped back up to 3000 psi two more times with a similar fall off rate, establishing a leak rate of 2.1 GPM at 3000 psi. The IA pressure bleed back down to 2150 psi 30 mins after the final pump up. A tbg leak is suspected due to the direct 2 way communication. Tbg packoff testing completed during the MITIA passed, the packoffs are not the suspected leak path. The well will be freeze protected and SI as soon as possible. Diagnostics will be performed to locate the tbg leak to evaluate repair options. A sundry or administrative relief request will be submitted as needed. The well has been added to the failed MITIA report. Attached is a 90 day TIO plot and well bore schematic. The bleed event history for 1 R-36 is also listed below for your reference. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 {;:'> r"",; {;c «1R-36.pdf» «1R-36 90 day TIO plot 7-13-06.gif» 13-JUL-06 14:43 Well Annulus Test Report DS WL TIME DURATION STR-PRES END-PRES DIF-PRES CASING SERVICE MATERIAL COMMENTS 1R 36 13-JUL-06 13:45: +000:15 2250 1900 350 INNER PWI diesel 1R 36 11-JUL-06 08:12: +000:10 2200 1950 250 INNER PWI diesel 1R 36 10-JUL-06 22:14: +000:08 2150 1350 800 INNER PWI diesel lR 36 13-JUL-03 14:09: +000:05 1100 750 350 OUTER PWI diesel lR 36 01-SEP-02 16:22: +000:15 1950 950 1000 INNER PWI diesel Content-Description: lR-36.pdf Content-Type: application/octet-stream Content-Encoding: base64 lof2 7/14/20061;11 PM 1R-36 (PTD 201-227) Report of TxIA comm lR-36 90 day TIO plot 20f2 e e Content-Description: lR-36 90 day TIO plot 7-1 Content-Type: image/gif Content-Encoding: base64 7/14/2006 1; 11 PM e e KRU 1 R-36 API: 500292305700 Well Tvoe: INJ Anole (ij) TS: 33 deo (ij) 12237 TUBING SSSV Tvoe: Nioole Orio Comoletion: 4/17/2002 Ana Ie (ij) TO: 31 den /ñ} 12700 (0-12151, Annular Fluid: Last W/O: Rev Reason: TAG FILL 00:3.500, Reference Loa: Ref Lon Date: Last Update: 5m2006 10:2.992) Last TaQ: 12302' RKB TO: 12700 ftKB Last ¡¡lite: 5/6/2006 Max HOle~3631 DescriDtion I Size I TOD Bottom TVD Wt I Grade I Thread I CONDUCTOR I 16.000 I 0 I 158 158 62.58 IAPI5LGrB PEB SURFACE 9.625 I 0 I 7419 4152 40.00 I L-80 I BTC SURFACE 7.000 0 12664 6942 26.00 I L-80 I ~ (0-7419, ,~UlIIUN 00:9.625, ii1!ti Wt40.oo) Size I Too I Bottom I TVD I Wt I Grade I ¡ill 3.500 I 0 I 12151 6507 9.30 I L-80 I l!f~if~-¡~tiiñi1'iâ" ~RODUCTlON Interval TVD Zone Status Ft SPF Date TVDe Comment (0-12664, 12284 - 12298 6619 - 6631 C-1 14 6 4/17/2002 IPERF 2.5" PJ, 2506 PJ, 60 den nh 00:7.000, 12442 - 12460 6753 - 6768 A-4,A-3 18 6 4/14/2003 APERF 2.5" PJ HSD, 60 deo ohase Wt26.00) 12460 - 12480 6768 - 6785 A-3 20 6 4/10/2003 APERF 2.5" PJ HSD, 60 deo ohase - 6806 - 6811 .. 6 6 12.5" PJ~OhaSe St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt 1 3864 2701 CAMCO KBUG CAMCO DMY 1.0 BK-5 0.000 0 12/28/2001 2 7542 4204 CAMCO KBUG CAMCO DMY 1.0 BK-5 0.000 0 12/2812001 3 9992 5194 CAMCO KBUG CAMCO DMY 1.0 BK-5 0.000 0 12/28/2001 4 11386 5904 CAMCO KBUG CAMCO DMY 1.0 BK-5 0.000 0 12/28/2001 5 12058 6429 _ MMG CAMCO DMY 1.5 RK 0.000 0 4/4/2002 Depth TVD TVDe DescriDtion ID 514 514 NIP CAMCO LANDING OS NIPPLE WINO GO PROFILE 2.875 12109 6472 PBR BAKER 80-40 PBR 3.000 12132 6491 PKR BAKER SAB-3 PACKER 4.000 12143 6501 NIP BAKER OS NIPPLE WINO GO PROFILE 2.812 12150 6506 SOS 3.000 12151 6507 TTL 2.992 PBR (12109-12110, 00:5.810) PKR (12132-12133, 00:5.960) NIP (12143-12144, 00:4.520) SOS (12150-12151, 00:3.500) --- ....... Perf -........ ---.-. ;12284-12298) - t--- - t--- - t--- Perf - f---- :12442-12460) - t--- Perf - f---- :12460-12460) - t--- ........ ____m .-..... -.--- Perf -..... m..__ :12504-12510) .-.-- - --. - ---. --- ----. ... .. TUBING SURFACE "ROOUCTION PBR '""" 005810) PKR 005.960) NIP .,,,. "'" 004.520) c,",c .< 'YV"< ,y, Perf ....-.- l= 12284.12298) --- - -- ----- -- I-- Perf -- 12442-12460) - Perf --. 12460-12480) - '...---- ------ ;--...-- ...- '--- Peri f-------- 12504-12510) - ...--~ ---- 1--'" O. -- API: SSSV Type: "'iI"UI"" "UIY. 1m' LaSt! ao: IL::J':¡L KI\!:5 ~~oo ~' "°7" Too I 0 TVI 650 ~~~ 11NJ Orig ¡ 4/ , II¿VV¿ ~~: Ref LOQ ø te: D: 12!OO ftKB ZEI W 1 :JOO i25 100 j Bottom I , A-, ,-3 t\-: t\-: Z,)re 158 7419 ~_126~4 NIPPL~Y)¡{1'JQGO DRn¡;:!! Ä-2 B~!\I\::ìPLUG ON 112,)/,\, t:::, "D 1 ~ ~o!e 4 '.58 ¡ 40.00 Thread PES BTC 2284 - 2298 UQ 2442 -- 2460 &:71:;'" :7&:2 iI: ª~ ~:;;¡; r- h 6429 i CA:CO ' . R ~ ¡DING DS NIPPLr:: R ~ P IG . ð!: I L.ð SOS TTL v ¡PERF I Ai"'!:l"ir ¡Z5" PJ I 1 GOd I, VOD Latch _,~oPo" : TRO = 11 Cm.. O. i I 1 RK PROF!! F 2.875 WOO .000 .812 ~ of ¡ R-36 \ MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg Ki -,ktlc (,,~ P.I. Supervisor \ ?'t4' DATE: Wednesday, May 17,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IR-36 KUPARUK RIV UNIT IR-36 ·L Src: Inspector ~~1 ~ 0\ ,~ FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Reviewed By: (f-;:)f) P.I. Suprv , ¡ D~ Comm Well Name: KUPARUK RIV UNIT IR-36 API Well Number 50-029-23057-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060515060718 Permit Number: 201-227-0 Inspection Date: 5114/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I IR-36 !Type Inj. ¡ W ¡ TVD 6491 i IA i 3lO j 2200 , 2200 , 2200 P.T. i 201227Ó ITypeTest I SPT : Test psi , -- i ! -- 1622. 75 j OA I 150 I 400 400 400 I Tubing! 2150 , 2150 , 2150 2150 Interval 4YRTST P/F P I I , Notes Pretest pressures were observed and found stable, Well demonstrated good mechanical integrity SCANNEú, JUN : ;12008 Wednesday, May 17,2006 Page 1 of 1 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc I 7 1'111 'f) ). !.~ (> r.{ DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Permit to Drill 2012270 Well Name/No. KUPARUK RIV UNIT 1 R-36 MD 12700 ./' TVD 6973 .-- Completion Date 4/17/2002 ------- ----- -- -- ----------- - - --- --- - - ---- - -- ---- REQUIRED INFORMATION Mud Log No --------. --- -------- ---- - - - - - - ---- --- - DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type MedlFrmt QÆD ¿ó' I ~DÚd' :'~ I I Electr Dataset Number Name --- 4-6766 LIS Verification ~26 See Notes "^ ( {t"~ r () V"I '- f,v'r~ Y Ij ~ I ~<)g I I 1J.P9 ~.ffljection Profile -Spinner I lLGg I Temperature ..------ Pressure ! L- ~ Log --- ----- Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y ~ / Chips Received? " V I N Analysis Received? ~ -- -- -- ---- ------- ------- --------- ----------- --- - ---_.- Operator ç I fJ1 ¿ i ð J~ ~ f CONOCOPHILLlPS ALASKA INC APi No. 50-029-23057-00-00 r:-~ Curre~~ ~~~~~~-- WAGI~_- - ~~~~ê ~--~--= ",,"' Completion Status ~~- Samples No Directional Survey -~~ ~ --- ---- --._- ---------- (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No ----- ----- ------- 1 Interval OH I Start Stop CH Received Comments ---------- ------- .- 139 12651 Open 4/19/2002 I 139 12700 ~ 12/6/2002 Digital Well Logging Data I ¡ C: rtc---. Rate of Penetration, Dual 1') L- Gamma Ray I Electromagnetic Wave Resistivity 5 Blu 12202 12464 Case 7/23/2003 Injection Profile - Spinrremp/Press 5 Blu 12202 12464 Case 7/23/2003 Injection Profile - Splnrremp/Press 5 Blu 12202 12464 Case 7/23/2003 Injection Profile - Spinrremp/Press 5 Blu 12202 12464 Case 7/23/2003 Injection Profile - Splnrremp/Press ------------- -- - -----.- -- Sent Sample Set Number Comments Received Daily History Received? tJl N @N Formation Tops - ----- -- --- --- - --- ----- -- - ----- - -- ------ --- ---. -- ---- -- -- - --- --- Comments: -- ---- - - -- Permit to Drill 2012270 MD 12700 - - --- - -- - ---- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Well Name/No. KUPARUK RIV UNIT 1 R-36 Operator CONOCOPHILLlPS ALASKA INC TVD 6973 Completion Date 4/17/2002 Completion Status WAGIN Current Status WAGIN UIC Y -- --~=--~.. Date: API No. 50-029-23057-00-00 If-.flIK)=~ ~..~c. Mike Mooney Wells Team Leader Drilling & Wells y ConocoPhillips P O. Box 100360 Anchorage. AK 99510-0360 Phone: 907-263-4574 May 21,2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 R-36 (201-227) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforating operations on the Kuparuk well 1 R-36. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )A. J{~ M. Mooney Wells Team Leader CPAI Drilling RECE~\/E[) MAY 2 7 2003 MM/skad Alaska Oil [2 Gas Cons. Comm1;;sior¡ Anchorage ~'VN.fJ ~O Alter Casing Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage. Alaska 99510 7. KB Elevation (ft): RKB 36' 8. Property Designation: ADL 25628, ALK 2561 1, Operalions Performed. Abandon STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS D Suspend D Operation ShUTdown D D Repair Well D Plug PerforaTions D D Pull Tubing D PerforaTe New Pool D Other D Variance 0 Annular Dlsp D 0 0 Perforate [] Stimulate D Time Extension Re-enter Suspended Well 4. Current Well Status: Developmenl D Stratigraphic D Exploratory D ServIce 0 5 Permit to Dnll Number: 201-227 I 6. API Number: 50-029-23057 -00 9. Well Name and Number: 1 R-36 10. Field/Pool(s): Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: measured 12700' feet true vertical 6973' feet measured 12588' feet true vertical 6877' feet Length Size MD 158' 16" 158' 7383' 9-5/8" 7419' 12628' 7" 12664' Plugs (measured) Junk (measured) TVD Burst Collapse 158' 4152' 6942' Measured depth: 12284'-12298',12442'-12480'.12504'-12510' RECEI\/ED MAY 2 7 2003 Alaska Oil & Ga~ Cons. Commission Anchorage true vertical depth: 6619'-6631', 6753'-6785', 6806'-6811' Tubing (size. grade. and measured depth) 3-1/2", L-80, 12151' MD. Packers & SSSV (type & measured depth) pkr= BAKER SAB-3 PACKER pkr= t2132' SSSV= NIP SSSV= 514' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl N~ 1700 NIA 3100 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: OilD GasD WAG0 GINJD WINJ D 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: Oil-Bbl NIA NIA Casinq Pressure Tubinq Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Contact Printed Name Signature WDSPL D Mike Mooney @ 263-4574 Mike Mooney Þf.1I/~ Title Phone Wells Group Team L;.~:er ~¡.Z 71t. Prr?pare,' t'I' Sharon AI/;lJ~lke 263-4612 ORIGINAL SUBMIT IN DUPLICATE Form 1!?-~_~4 _Revi,s~_d ,2/2003. U\ '~',," ':j . i ~.;tjl\~!,,~~" \~"Ir:- ,)c. ¡rr./:- ~ ';'J Date 04/05/03 04/06/03 04/10103 04/11/03 04/14/03 1 R-36 Event History Comment TAGGED @ 12,588' RKB, EST 290' OF RATHOLE; ATTEMPTED TO DRIFT WI 20' DMY GUN FOR E-LlNE, IN PROGRESS. [PERF] BRUSHED TBG FROM 3200' TO 12,100' WLM; DRIFTED TBG WI 22' X 2.625" DUMMY GUN TO 12,583' RKB. [PERF] PERFORATE THE INTERVAL 12504-12510 USING 2.5" HSD POWERJET HMX 6 SPF 60 DEG PHASED GUNS. CHARGES ARE 2506 PJ HMX API PENETRATION = 25.2", ENTRANCE HOLE = 0.32". DIFFICULTY FALLING THRU 8450', 8800', 9620', 10400'. PERFORATE 12460'-12480' USING 2.5" HSD GUNS 6 SPF 60 DEG PHASING RANDOM ORIENTATION. TIED IN TO SWS PERF RECORD DATED 17 APRIL 2002. API CHARGE DATA: 2506 POWERJET HMX. PENETRATION: 25.2". ENTRANCE HOLE: 0.32". PERFORATE THE INTERVAL: 12442' - 12460' USING 2.5" HSD GUNS LOADED 6 SPF, 60 DEG PHASING WITH 2506 POWERJET HMX CHARGES (API DATA: 25.2" PENETRATION, 0.32" ENTRANCE HOLE). PUT WELL BACK ON INJECTION. Page 1 of 1 sn/2003 ~ ., ConocoPhillips Alaska, Inc. r. 1 R-36 TUBltJ". API 500292305700 (0-12151, SSSV Type' Nipple OD 3 500 []I ID 2 ~92) AnnulaT FlUid Reference Log. Last Tag 12588 - Last Tag Date: 4/5/2003 Casing String. ALL STRINGS Description Size CONDUCTOR 16000 SURFACE 9625 PRODUCTION 7.000 Tubing String. TUBING Size I Top 3 500 0 peñorations Summary Interval TVD 12284 - 12298 6619 - 6631 ,12442 - 12460 6753 - 6768 12460 - 12480 6768 - 6785 12504 - 12510 6806 - 6811 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 3864 2701 CAMCO KBUG CAMCO 2 7542 4204 CAMCO KBUG CAMCO 3 9992 5194 CAMCO KBUG CAMCO 4 11386 5904 CAMCO KBUG CAMCO 5 12058 6429 CAMCO I'v1MG CAMCO Other (Jlugs, equip., etc.: - JEWELRY Depth TVD Type 514 514 NIP 12109 6472 PBR 12132 6491 PKR 12143 6501 NIP 12150 6506 SOS 12151 6507 TTL PVR ( 12132-12133, OD 5 9601 Perf ( 1228.t-122981 P",rf (12~2.1246ül Perf ( 12460-12.\801 Perf (125û.t-12510¡ ,~-.. ß~ ~" \. ~- J 1 I ~ ~ I I~I ì I ~ L-J ì!';, ~ ~ -*~"~ t=.'. :: E ~ Ï- ~ f Bottom 12151 Zone C-1 A-4.A-3 A-3 A-2 KRU Well Type INJ Orlg 4/17/2002 Completion Last WIO Ref Log Date TO. 12700 ftKB Max Hole Angle. 70 deg @ 3631 Top 0 0 0 Bottom 158 7419 12664 TVD 6507 Wt 9.30 Status 1 R-36 Anqle @ TS 33 deq @ 12237 Angle @ TO 3' deg @ 12700 Rev Reason. PERFS Last Update 4/16/2003 TVD 158 4152 6942 Wt Grade Thread 62.58 API5LGrB PES 40 00 L-80 BTC 26.00 L-80 BTC-MOD I Grade I L-80 Thread EUE8rdMOD Ft SPF Date 14 6 4/17/2002 18 6 4/14/2003 20 6 4/10/2003 6 6 4/10/2003 Type Comment IPERF 25" PJ, 2506 PJ, 60 deg ph APERF 25" PJ HSO, 60 deg phase APERF 2.5" PJ HSD, 60 deg phase APERF 25" PJ HSD, 60 deg phase V Mfr V Type VOD Latch Port TRO DMY 1.0 BK-5 0.000 0 DMY 1 0 BK-5 0000 0 DMY 1.0 BK-5 0.000 0 OMY 1.0 BK-5 0000 0 DMY 1.5 RK 0000 0 Date Vlv Run Cmnt 12/28/2001 12128/2001 12/28/2001 12/28/200 , 414/2002 Description CAMCO LANDING OS NIPPLE WINO GO PROFILE BAKER 80-40 PBR BAKER SAB-3 PACKER BAKER OS NIPPLE WINO GO PROFILE ID 2875 3.000 4000 2812 3.000 2992 ¿;{D/ ..;;)¿) J ) I "I dl(J \VELL LOG TR<\NSI\'IITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa \\'eepie 333 \\\~st 7th A venue. Suite 100 .--\nchorage. Alaska 99501 No\'t~mber 22. 2002 RE: 1\ 1\\,'0 Fomlation Evaluation Logs 1 R-36. :-\K-1\11\1-11210 The technical data listed belo\\' is being submitted herewith. Please address any problems or conce1l1S to the attention of: Rob Kalish~ Spell)'-SlUl Drilling Services. 6900 :-\.rctic Blvd.. Anchorage. AK 99518 1 R-36: Digital Log Images 50-029-23057-00 1 CD Rom RECEIVED DEe 06 2002 Ala8k8 Û¡,¡ &. Ga~ Cons. Lommission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission JtJ TO: Cammy O. Taylor r Chair r:J.. rw, SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder f<;J1.r ~-, Conoco/Phillips Petroleum Engineer \ ~\ ~o) 1 R pad ') 1 R-36 FROM: Lou Grimaldi Kuparuk River Unit Petroleum Inspector Field NON. CONFIDENTIAL DATE: October 24,2002 Well 1 R-36 Type Inj. P.T.D. 2012270 Type test Notes: Well P.TD. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING s P Packer Depth Pretest Initial 15 Min. 30 Min. TV.D. 6491 Tubing 2350 2350 2350 2350 Interval I Test psi 1623 Casing 1100 1800 1800 1800 P/F e Type Inj. Type test TV.D. T est psi Tubing Casing Interval P/F Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Vanance W= Test during Workover 0= Other (describe in notes) Test's Details This was the initial pressure test of this wells production casing. The test went well with no appreciable loss of pressure 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/Nezetikv M IT report form 5/12/00 L.G. MIT KRU 1 R 10-24-02 LG.xls 10/27/2002 ~ PHilLIPS Alaska, Inc. .(Ð. A Subsidiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 May 24, 2002 Conlmissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage. Alaska 99501 Subject: Completion Report for 1 R-36 (201-227) Dear Commissioner: Phillips Alaska. Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well 1 R-36. If you have any questions regarding this Inatter. please contact Scott Lowry at 265-6869. Sincerely. ~\~- Kuparuk Drilling Team Leader P AI Drilling RT/skad RECEIVED JUN 0 5 2002 ORIGINAL AJaska Oil & Gas GOffS. WIh~mSSlor¡ Anchorage STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG P. O. Box 100360, Anchorage. AK 99510-0360 ,.-. ----.,. '-~. ~. - J.,r~_", 1. 4. Location of well at surface ~'! .,¡ 9. Unit or Lease Name . "',. \ "r . -~""J.' ~ I j ~ .', f"' .':. -'.'. (ASP: 539830. 59~~J :fl.- ' .. lr. \. . '. . . '.~.~ "'':..,A.'.'....- -.. 871' FNL, 2628' FEL, Sec. 8, T12N, R1OE, UM , .', f:)" ~11 ' (ASP: 542256. 6000906) At Total Depth ; .~-l:i- : 659' FNL. 2559' FEL. Sec. 8. T12N. R10E, UM -- --'.-'.-...-. (ASP: 542323. 6001118) 5. Elevation In feet (indicate KB. DF. etc.) 6 Lease Designation and Senal No. RKB 36 feet ADL 25628, ALK 2561 12. Date Spudded 13. Date T.D. Reached 14.j)ale COJ1p.. -,:usPj. 9r~~and. 15. Water Depth. If offshore 16. No. of Complellons December 10. 2001 December 22, 2001 Æ~~trn~Qr'20. 2-Ó01- 2.- ..AD N/A teel MSL 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. DirecTional Survey 20. Depth where SSSV set 12700' MD 16973' TVD 12581' MD /6871' TVD YES 0 No 0 Camco Nipple @ 515' 22. Type Electric or Other Logs Run GR/Res/PWD, USIT 23. , Status 01 well Od 0 Gas 0 2 Name of Operator Phillips Alaska, Inc. 3. Address 0 Abandoned 0 Service 0 Suspended 1ì"" . t'Jr"" ~,~ ~ lr~~\:1.....7""....,~ 606' FSL. 145' FWL, Sec. 17, T12N, R1OE, UM At Top ProduCing Inlerval CASING SIZE 16" 9.625" 7" CASING. LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 158' Surface 7419' Surface 12665' Classlflcalion of Service Well WAG InlectOr 7. Permit Number 201-227 I 8. API Number 50-029-23057 -00 Kuparuk River Unit 10. Well Number 1 R-36 11. Field and Pool Kuparuk River Field Kuparuk River Pool 21. Thickness of Permafrosl 1730' HOLE SIZE 24" 12.25" 8.5" CEMENTING RECORD 308 sx AS 1 610 sx AS Lite. 850 sx L,teCrete GRADE H-40 L-80 L-80 WT. PER FT. 62.6# 40# 26# 290 sx GasBLOK 24. Perforations open to Production (MD + TVD of Top and Bottom and interval. size and number) AMOUNT PULLED 3.5" TUBING RECORD DEPTH SET (MD) 12152' PACKER SET (MD) 12132' 25. SIZE 12284' - 12298' MD 6619' - 6631' TVD 6spf 26. ACID. FRACTURE. CEMENT SQUEEZE. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED NIA 27. Dale First Production PRODUCTION TEST Method of Operation (Flowing. gas lilt. etc.) Injector Production for OIL-BBL Test Period> WATER-BBL Date of Test Hours Tested GAS-MCF Flow Tubing press. pSI Casing Pressure Calculated 24-Hour Rate> OIL-BBL GAS-MCF WATER-BBL 28. CORE DATA Brief description of lithology. porosity. fractures. apparent dips and pressence of oil. gas or water. Submit core chips. N/A N/A CHOKE SIZE GAS-OIL RATIO OIL GRAVITY - API (corr) RECEIVED .JUN 0 5 2002 ,"- ~ r.'" ! .. ~ ;¡ ¡' I :1 , I." ' 1 r, i( :~. ~ 'r Ii ,: ' . I ~ I.' t , I Alaska Oil & Gas COfaS. IjOlliiW:>S,ll}f I Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE RBDMS BFL Submit in duplicate II If, I 29 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT DEPTH Include interval tested, pressure data. all fluids Tecovered and gravity. GOR. and time of each phase. Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A 12237' 12299' 12426' 12557' 6580' 6632' 6739' 6851' RECEIVED JUi'J 0 5 2002 Alaska Oil & Gas GOilS. ~UlllmlsSlor, Anchorage Annulus left open - freeze protected with diesel. 31. LIST OF A IT ACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following IS true and correCllO the best of my knowledge. Questions? Call Scott Lowry 265-6869 Slgned~~~ Title R. Thomas Kuparuk Drilling Team LeadeT Date 5 (~c.I'(O~ Prepared by Sharon Allsup-Drake 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 l'~" j: (", r ,,~'. ~ :'. :; ,':, ~ .,' ~ ". , ',.' ,,; ~ ¡' .J ,"'11 ~~- ~, T¡t¡I ~~ Page 1 of 8 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 1 R-36 Common Well Name: 1 R-36 Event Name: ROT - DRILLING Contractor Name: n1268@ppco.com Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 12/9/2001 03:00 - 09:30 6.50 MOVE MOVE MOVE 09:30 - 12:00 2.50 MOVE OTHR MOVE 12:00 - MOVE OTHR MOVE 12:00 - 20:00 8.00 WELCTL NUND SURFAC 20:00 - 21 :00 1.00 DRILL PULD SURFAC 21 :00 - 22:00 1.00 WELCTL BOPE SURFAC 22:00 - 00:00 2.00 DRILL OTHR SURFAC 12/10/2001 00:00 - 00:30 0.50 DRILL SFTY SURFAC 00:30 - 02:30 2.00 DRILL PULD SURFAC 02:30 - 00:00 21.50 DRILL DRLG SURFAC 12/11/2001 00:00 - 12:30 12.50 DRILL DRLG SURFAC 12:30 - 14:00 1.50 DRILL CIRC SURFAC 14:00 - 17:30 3.50 DRILL WIPR SURFAC 17:30 - 00:00 6.50 DRILL DRLG SURFAC 12/12/2001 00:00 - 16:30 16.50 DRILL DRLG SURFAC 16:30 - 17:30 1.00 DRILL CIRC SURFAC 17:30 - 20:30 3.00 DRILL TRIP SURFAC 20:30 - 22:30 2.00 DRILL OTHR SURFAC 22:30 - 23:00 0.50 DRILL OTHR SURFAC 23:00 - 23:30 0.50 DRILL TRIP SURFAC 23:30 - 00:00 0.50 DRILL TRIP SURFAC 12/13/2001 00:00 - 03:30 3.50 DRILL TRIP SURFAC 03:30 - 12:00 8.50 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 12/14/2001 00:00 - 02:30 2.50 DRILL DRLG SURFAC 02:30 - 03:00 0.50 DRILL CIRC SURFAC Spud Date: 12/10/2001 End: 12/29/2001 Group: Start: 12/9/2001 Rig Release: 12/29/2001 Rig Number: 245 Description of Operations Prepare and move rig f/ 1 R-35 to 1 R-36. 60' move away from CPM. Organize and PU rig prior to acceptance. Dr op curtains for Lampsons. Accept Rig @ 1200 hrs 12/9/01. Well 1R-36 Nipple up diverter system, prepare spud mu d. Load rig floor with drilling tools f/ 12 1/4" h ole. Function test diverter system. Witness waiv ed by AOGCC inspector, Chuck Sheeve. PU/MU BHA. Orient motor and Sperry tools. Diverter drill while program tools. Diverter drill, Pre spud meeting. PU/MU BHA. fill hole, check fl leaks. Directional drill 12 1/4" hole f/ 158' to 1548 '(1390') Gyro and MWD survey as needed. (TVD= 1509') ART = 6.6 hrs AST = 6.5 h rs Directional drill 12 1/4" hole fl 1548' to 306 7' (1519') (TVD=2408') ART = 4.38 hrs AST = 3.48 hrs Circulate and condition mud and hole f/ shor t trip. Monitor hole. Pump dry job. Wiper trip to 1500'. RIH. Little bit of tight h ole @ transition from permafrost. Directional drill 12 1/4" hole fl 3067' to 378 4' (717') (TVD = 2655') ART = 3.55 hrs. AS T = .89 hrs Direct' drill 12 1/4" hole f/ 3784' to 5276' (1492') (TVD = 3267') ART = 9.74 hrs. AST = 2.66 hrs. CBU prior to POOH f/ Bit # 2. POOH f/ bit # 2. Monitor well @ BHA. Continue POOH, download sperry, change m otor bend to 1.15 deg, change out bits, uplo ad sperry MWD/LWD tools. Shallow test MWD tools. RIH wI 5" HWDP. RIH wI BHA # 2, bit # 2 on 5" DP. RIH wI BHA # 2 & bit # 2. Break circ @ 3500 I and 4800'. Precautionary ream last 95' to bottom (5181' -5276') Directional drill 12 1/4" surface hole f/ 5276 I to 6022' (746') (TVD = 3565') ART = 4.73 hrs. AST = 1.78 hrs. Directional drill 12 1/4" surface hole II 6022 , to 6768' (746') (TVD = 3875') ART = 4.45 hrs. AST =2.8 hrs. Directional drill 12 1/4" hole fI 6768' to 695 5' (187') (3952'TVD) ART = .89 hrs AST = 1.0 hrs. Circulate. Pnnted: 1/2212002 11"23:20 AM ~~ ~ ~ Page 2 of 8 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 1 R-36 Common Well Name: 1 R-36 Event Name: ROT - DRILLING Contractor Name: n1268@ppco.com Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 12/14/2001 03:00 - 10:00 7.00 DRILL DRLG SURFAC 10:00 - 11 :30 1.50 DRILL CIRC SURFAC 11 :30 - 18:00 6.50 DRILL WIPR SURFAC 18:00 - 21 :00 3.00 DRILL CIRC SURFAC 21 :00 - 00:00 12/15/2001 00:00 - 02:30 3.00 DRILL TRIP SURFAC 2.50 DRILL TRIP SURFAC Spud Date: 12/10/2001 End: 12/29/2001 Group: Start: 12/9/2001 Rig Release: 12/29/2001 Rig Number: 245 Description of Operations Directional drill 12 1/4" hole fI 6955' to 743 0' (475') (TVD = 4158') ART = 3.12 hrs. AS T = 2.45 hrs. Circulate and condition mud and hole @ TD. Circ 10300 strokes. (1037 bbls). Pump dry i ob for wiper trip. LID a single. POOH to 1736' (61 stands out) , RIH, fill pipe @ 4625', continue RIH, PU si n g Ie. Fill pipe, break circulation, circulate and co ndition mud and hole for 9 5/8" casing. Pum p Hi density - Hi vis sweep after on bottom. Pumping @ 154 spm/2400 psi fl 18000 strok es. Pumped total of 1813 bbls mud prior to dry job. Monitor well. Pump dry job. POOH to run 9 5/8" surface casing. Continue to POOH fl 9 5/8" casing. Lay dow n and change out 2 joints of 5" drill pipe. 0 ne, slip cut middle of 5th stand. One, scarri ng in middle of tube first joint above HWDP. 02:30 - 03:30 1.00 DRILL PULD SURFAC LID x - 0, s tab, 3 fie x de. B rea k bit, d r a i n m t r 03:30 - 04:00 04:00 - 05:00 05:00 - 06:30 06:30 - 07:00 0.50 DRILL OTHR sURFAC 1.00 DRILL PULD sURFAC 1.50 CASE RURD sURFAC 0.50 CASE sFTY sURFAC 07:00 - 12:30 5.50 CASE RUNC sURFAC 12:30 - 14:00 1.50 RIGMNT RGRP SURFAC 14:00 - 17:00 3.00 CASE RUNC sURFAC 17:00 - 18:30 1.50 CASE CIRC SURFAC 18:30 - 20:30 2.00 CASE RUNC sURFAC 20:30 - 21 :30 1.00 CASE RURD SURFAC 21 :30 - 00:00 2.50 CEMENTCIRC SURFAC Download MWD data. LID float sub, MWD and mud motor. RU to run 9 5/8" surface casing. Pre job safety meeting wI team members on 9 5/8" casing job. Run 9 .625" casing to 3400'. Circulate 2555 strokes(257 bbls) @ 55 spm & 300 psi. Casing collar caught inside lip on slip joint riser and caused flow line to disconnect whi Ie reciprocating casing. This resulted in a s pill outside of secondary containment in cell ar area. Re- install flow line and thaw out s tand pipe @ gooseneck. Continue to run 9 5/8" surface casing to 583 5' (145 joints). Circ mud and hole @ 5835'. Pump csg volum e 4400 strokes (442 bbls) @ 55 spm (5.5 bp m) & 300 psi. PU wt 270-275k, SO wt 125- 130k Continue to RIH wI 9 5/8" casing f/ 5835' to 7394' (184 jts in hole). LID Frank's fill up tool, MU FMC csg hngr an d landing joint. Land csg on landing ring wit h shoe @ 7419'. RU Dowell cement head & R U cement hose. Break circ. After pumping (6 BPM & 450 psi )80 bbls, st art recip casing with 10' stroke (2-2 1/2" str etch + 7 1/2-8' pipe movement). Initial: PU wt 350 k SO wt 140 k after picked up & recip: Pnnred: 1/22/2002 l' 23:20 AM /~8.. ~ ~~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date PHILLIPS ALASKA INC. Operations Summary Report 1 R-36 1 R-36 ROT - DRILLING n 1268 @ ppco.com Nabors 245 Sub From - To Hours Code Code Phase 12/15/2001 21:30 - 00:00 12/16/2001 00:00 - 02:00 12/17/2001 02:00 - 02:30 02:30 - 05:30 05:30 - 07:30 2.50 CEMENT CIRC SURFAC 2.00 CEMENTCIRC SURFAC 0.50 CEMENT SFTY SURFAC 3.00 CEMENT PUMP SURFAC 2.00 CEMENT DISP SURFAC 07:30 - 09:30 2.00 CEMENT RURD SURFAC 09:30 - 11 :30 2.00 WELCTL NUND SURFAC 11 :30 - 14:00 2.50 WELCTL NUND SURFAC 14:00 - 18:00 4.00 WELCTL NUND SURFAC 18:00 - 19:00 1.00 WELCTL BOPE SURFAC 19:00 - 23:30 4.50 WELCTL BOPE SURFAC 23:30 - 00:00 00:00 - 01 :00 01 :00 - 03:00 03:00 - 03:30 03:30 - 09:30 09:30 - 13:30 13:30 - 22:30 0.50 WELCTL OTHR 1.00 RIGMNT RSRV 2.00 RIGMNT RSRV 0.50 DRILL PULD 6.00 RIGMNT RGRP SURFAC INTRM1 INTRM1 INTRM1 INTRM1 4.00 DRILL OTHR INTRM1 9.00 RIGMNT RGRP INTRM1 22:30 - 00:00 1.50 DRILL OTHR INTRM1 12/18/2001 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 01 :30 - 02:00 0.50 DRILL PULD INTRM1 02:00 - 03:30 1.50 DRILL CIRC INTRM1 Page 3 of 8 Spud Date: 12/10/2001 End: 12/29/2001 Group: Start: 12/9/2001 Rig Release: 12/29/2001 Rig Number: 245 Description of Operations PU wt 310 k-320 k SO wt 140 k aft er 1 csg volume pumped: PU wt 290-300 k SO wt 140K Circulate and reciprocate 9 5/8" casing prio r to cement job. PU wt = 325 k SO wt = 1 40 k Pre job safety meeting wI team members on cement job. Tourpusher watching rig while s till recip and circ. Total pumped was 18,20 Ox strokes (1832 bbls) Final circ pressure @ 6 bpm = 250 psi. PU wt = 355 k SO wt = 130 k Line up on Dowell. Pump 10 bbls CW 100, te st lines @ 3500 psi, another 40 bbls CW100, drop bottom plug, 50 bbls mud push XL(wit h dye), 470 bbls lead, 361 bbls tail, drop to p plug, kick out wI 5 bbls H2O. Rig displace wI 551 bbls 9.4 ppg mud. Bum p plug @ calculated strokes (5472) wI 1500 psi. Hold 5 min. Bleed off pressure to check floats, OK. CIP @ 0716 hrs 12/16.2001. Flush out diverter stack. LID landing joint, elevators, and long bales. LID cement head. N/D Diverter stack. NU and orient FMC wellhead equipment. NU 13 5/8" BOPE stack. RU to test BOPE. Test BOPE. Test annular to 250 low and 350 0 psi high. Test All other valves and rams t 0 250 psi low and 5000 psi high. Witness of test waived by AOGCC inspector John Crisp. RID test equipment. Set wear bushing. Service rig & Top Drive. Slip and cut drilling line. Prepare to PU BHA. Work on brakes on drawworks. After cutting drilling line and adjusting brakes, they appe ar to be spongy and won't hold load easily. PU/MU Sperry MWD/LWD tools, bit and mota r. Orient motor to tools. Program Sperry too Is. Put tools in hybernation mode. Trouble shoot problem wI drawworks brake s ystem. Check linkage, prepare to change bra ke bands. MPI spare brake bands. Change 0 ut brake bands with spare set dressed wI ne w blocks. Finish Mu/Pu BHA. Hold safety meeting wI S perry Sun on radioactive sources. RIH wI BHA up to HWDP. PU 3 joints of 5" DP fI pipe shed. Torque up pip e. MU top drive. Pump @ 23 spm & 165 psi. Ro Printed: 1/22/2002 11 23:20 AM /~'\\ T¡I'jI ~ Page 4 of 8 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 1 R-36 Common Well Name: 1 R-36 Event Name: ROT - DRILLING Contractor Name: n1268@ppco.com Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 12/18/2001 02:00 - 03:30 1.50 DRILL CIRC INTRM1 03:30 - 04:00 0.50 RIGMNT RGRP INTRM1 04:00 - 04:30 0.50 DRILL OTHR INTRM1 04:30 - 12:00 7.50 DRILL TRIP INTRM1 12:00 - 13:00 1.00 DRILL CIRC INTRM1 13:00 - 14:00 1.00 DRILL DEQT INTRM1 14:00 - 16:00 2.00 DRILL DRLG INTRM1 16:00 - 20:30 4.50 DRILL CIRC INTRM1 20:30 - 22:00 1.50 DRILL FIT INTRM1 22:00 - 22:30 0.50 DRILL DEQT INTRM1 22:30 - 00:00 1.50 DRILL DRLG INTRM1 12/19/2001 00:00 - 12:00 12.00 DRILL DRLG INTRM1 12:00 - 00:00 12.00 DRILL DRLG INTRM1 12/20/2001 00:00 - 15:30 15.50 DRILL DRLG INTRM1 15:30 - 16:30 1.00 DRILL CIRC INTRM1 16:30 - 00:00 7.50 DRILL DRLG INTRM1 12/21/2001 00:00 - 09:00 9.00 DRILL DRLG INTRM1 09:00 - 11 :30 2.50 DRILL CIRC INTRM1 11 :30 - 12:00 0.50 DRILL OBSV INTRM1 12:00 - 15:00 3.00 DRILL WIPR INTRM1 15:00 - 16:00 1.00 DRILL crRC INTRM1 16:00 - 18:30 2.50 DRILL FIT INTRM1 18:30 - 19:00 19:00 - 22:00 0.50 RIGMNT RSRV INTRM1 3.00 DRILL WIPR INTRM1 Spud Date: 12/10/2001 End: 12/29/2001 Group: Start: 12/9/2001 Rig Release: 12/29/2001 Rig Number: 245 Description of Operations tate full stand down @ approx 20 RPM while circ. This will put bit below TAM port collar. Pressure up to 500+ psi to test Tam port c ollar. Leaking. Circ hole volume to get air 0 ut of system. Appears that fill up line leak in g on stand pipe. Blow down standpipe. Repair fill up line on stand pipe. Test TAM port collar/casing @ 600 psi. OK. Blow down Top Drive. Continue to PU 5" DP f/ pipe shed & RIH wI bit # 3. Tag cmt at 7334'. Circ and condition mud for casing test. Pressure test 9-5/8" casing to 2550 psi. He Id solid for 30 min. Record pressures on ch art recorder. Drill through float collar, cement, and shoe. Drill 20' new hole to 7450'. Circ and condition mud for FIT. Perform FIT. Mud wt=9 ppg. Max press=162 5 psi. FIT EMW=16.5 ppg. Bled down to 12 80 psi in 10 min. Pumped 5.1 bbls. Bleed 0 ff pressure and recovered 3.5 bbls. Perform PWD baseline test. Drill ahead from 7450' to 7621' (4235' TV D). ART=1.25 (total for tour). Drill ahead from 7621' to 8643' (4649' TVD). ART=6.25 AST=1.25 Drill ahead from 8643' to 9951' (5176' TVD). Pump high weight low vis sweeps at 8735' and 9668'. ART=7.5 AST=.25 Drill ahead from 9951' to 11257' (5820' TVD ). Pump weighted low vis sweep at 10695'. ART=7.5 AST=3.0 Circ and condition mud. Displace hole with new 10.4# mud. Drill ahead from 11257' to 11629' (6078' TV D). ART=2.5 AST=1.75 Drill ahead from 11629' to 12049' (6423' TV D) ART=3.25 AST=1.75 Pump weighted low vis sweep. Circ and con dition mud for short trip. Monitor well. Short trip to shoe @ 7419'. Circ and condition mud for FIT. RU test equipment. Perform FIT w/ Dowell p ump. Mud weight in hole = 10.5. Pressure up to 1186 psi and SI for 10 min. Pressure bled off to 1053 psi. Pumped 6.5 bbls. Ble d back 4 bbls. EMW at 9-5/8" shoe=16 ppg. EMW at 12049' MD (6422' TVD)=14.1 ppg. RD test equipment. Lubricate rig and service top drive. Trip in hole to 11908'. Pnnted: 1122/2002 1 '"23:20 AM ~'þ ~ '!:Ø Page 5 of 8 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1 R-36 Common Well Name: 1 R-36 Event Name: ROT - DRILLING Contractor Name: n 1268 @ppco.com Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 12/21/2001 22:00 - 23:00 1.00 DRILL REAM INTRM1 23:00 - 00:00 1.00 DRILL DRLG INTRM1 12/22/2001 00:00 - 12:30 12.50 DRILL DRLG INTRM1 12:30 - 15:00 2.50 DRILL CIRC INTRM1 15:00 - 17:00 2.00 DRILL WIPR INTRM1 17:00 - 21 :00 4.00 DRILL CIRC INTRM1 21 :00 - 00:00 12/23/2001 00:00 - 05:00 3.00 DRILL TRIP INTRM1 5.00 DRILL TRIP INTRM1 05:00 - 05:15 0.25 DRILL SFTY INTRM1 05: 15 - 06:00 0.75 DRILL PULD INTRM1 06:00 - 07:00 1.00 DRILL PULD INTRM1 07:00 - 09:00 2.00 DRILL PULD INTRM1 09:00 - 10:00 1.00 CASE RURD INTRM1 10:00 - 10:30 0.50 CASE SFTY INTRM1 10:30 - 16:00 5.50 CASE RUNC INTRM1 16:00 - 17:00 1.00 CASE CIRC INTRM1 17:00 - 20:30 3.50 CASE RUNC INTRM1 20:30 - 22:30 2.00 CASE CIRC INTRM1 22:30 - 00:00 1.50 CASE RUNC INTRM1 12/24/2001 00:00 - 00:30 0.50 CASE RUNC INTRM1 00:30 - 01 :00 0.50 CASE CIRC INTRM1 01 :00 - 02:30 1.50 CASE CIRC INTRM1 02:30 - 05:00 2.50 CASE RUNC INTRM1 05:00 - 06:00 1.00 CASE CIRC INTRM1 06:00 - 08:30 2.50 CASE RUNC INTRM1 08:30 - 19:00 10.50 CEMENTCIRC INTRM1 Spud Date: 12/10/2001 End: 12/29/2001 Group: Start: 12/9/2001 Rig Release: 12/29/2001 Rig Number: 245 Description of Operations Ream from 11908' to 12049'. Circ bottoms u p. Drill from 12049' to 12096' (6461' TVD). AR T=.25 Drill ahead from 12096' to TD at 12700' MD (6973' TVD). ART=7.36 AST=.75 Condition mud. Circ weighted sweep. Circ bottoms up. Monitor well. Short trip to 11355'. No probl ems encountered. Monitor well. RIH to bott om. No fill. Circ and condition mud. Pump weighted swe ep and circ around. Monitor well. No flow. Mud weight in hole=10.6 ppg. Pump dry jo b. POOH wI 45 stands to 8463'. POOH to shoe at 7419'. Monitor well. No fl ow. Continue POOH. Perform Kick while tri pping drill. Continue POOH to HWDP. Moni tor well. No flow. Continue POOH to collar s. LD jars. PJSM w/ Sperry Sun. Discuss procedures fo r removal of radioactive source. Remove radioactive source. LD flex DC's. Download MWD data. LD MWD. Drain Motor. LD bit. Orient moto r to 0 deg. LD motor and remainder of BHA. Pull wear bushing. RU to run 7" casing. RU Frank's fill up tool PJSM - discuss casing running procedures. PU shoe jt and float jt. Check floats. RIH w/ 7" casing to 3857' (91 jts). Condition mud and circ casing volume at 3 - 4.5 BPM and 300 psi. No losses. Run casing to 7402' (above 9-5/8" casing sh 0 e). Condition mud and circulated 1 full circulati on. No losses. Continue running casing to 8759'. RIH w/ csg to 9150'. Try to circ. Cup leaking on Frank's fill up t 001. RU circ swage. Break circulation. Increase rate to 3 BPM a t 700 psi. CBU. No losses. PU Frank's fill up tool. RIH w/ csg to 10920 Break circulation. Increase rate to 5 BPM. CBU. No losses. RIH wI csg to 12624'. Total of 297 jts. MU landing jt and hanger. Land casing at 1266 5. Break circ at 2 BPM. Inc rate to 5 BPM. Ho Printed. 1/22/2002 l' 23:20 AM ~.~ T¡T¡I ~ Page 6 of 8 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-36 1 R-36 ROT - DRILLING n1268@ppco.com Nabors 245 Date Sub From - To Hours Code Code Phase 12/24/2001 08:30 - 19:00 10.50 CEMENTCIRC INTRM1 19:00 - 22:30 3.50 CEMENT PUMP INTRM1 22:30 - 00:00 1.50 CEMENTOTHR INTRM1 12/25/2001 00:00 - 03:00 3.00 CEMENTOTHR INTRM1 03:00 - 04:00 1.00 CASE DEQT INTRM1 04:00 - 07:00 3.00 WELCTL EaRP INTRM1 07:00 - 09:00 2.00 RIGMNT RSRV INTRM1 09:00 - 09:30 0.50 RIGMNT RSRV INTRM1 09:30 - 21 :30 12.00 DRILL PULD INTRM1 21 :30 - 21 :45 0.25 WELCTL SFTY CMPL TN 21 :45 - 00:00 2.25 WELCTL BOPE CMPL TN 12/26/2001 00:00 - 03:30 3.50 WELCTL BOPE CMPL TN Spud Date: 12/10/2001 End: 12/29/2001 Group: Start: 12/9/2001 Rig Release: 12/29/2001 Rig Number: 245 Description of Operations Ie began taking fluid., Reduce rate to 3 bp m hole taking 123 bbl/hr, RU cmt head. Wr ong XO for BTC. RU circ swage. Circ and c ondition mud. Recip pipe. Still loosing flui d. RU cmt head wI proper XO. Reduce pum p rate to 2 BPM w/20 bbl/hr losses. Return mud wt=10.8 at 300 vis. Start decreasing m ud wt with 20 bbl/hr water. Continue to circ and condition while reciprocating. Return rate picked up as return mud thinned out. I nc rate to 4.5 BPM with no losses., Check w ell for breathing-Well flowing slowly, Pumpe d a total of 2247 bbls. Final circulation rat e 4.5 BPM at 700 psi. Hold PJSM for cemen t job while circulating. Cement batch mixed at 1845 hrs. Pump cement job as planned. Pump 20 bbls CW100, drop 1st bottom plug, and follow w ith 50 bbls MudPush XL. Drop 2nd bottom pi ug and pump 62 bbls 15.8# cement. Drop to p plug and follow with 5 bbls water. Displac e with rig pump. Plug bumped wI 4680 stks (4722 calculated). CIP at 2205 hrs. Pressur ed up on plug to 1500 psi. Holding good. C heck floats. Holding good. Annulus flowing back a small amount of mud. Close in annu lar preventer and WOC. Monitor annulus pr essure on chart. (Note; Total mud lost while circulating & cementing 226 bbls) RD cement equipment and casing equipment. RU 5" elevators and bales. wac. Cleanup rig floor. Prep cellar for ra m change. Bleed pressure off annulus at 02 45. Bled back 4 gal of mud. Annulus is n ot flowing. Set 7" packoff in wellhead. Test void to 50 00 psi. Held good for 5 min. Change upper pipe rams to 3-1/2"x6" and 10 wer pipe rams to 2-7/8"x5". Change out sav er sub on top drive. RU for BOP test. Clean up rig floor. Prep to slip and cut drlg line. PJSM - discuss procedures for slip a nd cut. Slip and cut 98' drlg line. Lubricate rig. Service top drive. Lay down 5" HWDP and DP out of derrick. L eave 15 stds on off drillers side to support 3.1/2" tubing when racked in derrick. PJSM - discuss procedures for BOP test. RU test equipment. Begin BOP test. Jeff J ones of AOGCC waived witnessing the BOP t est. Complete weekly BOP test. Annular tested t 0 3500 psi. All other components tested to Pnnted: 1/22/2002 l' 23:20 AM ~. ~ ~ Page 7 of 8 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 R-36 1 R-36 ROT - DRILLING n1268@ppco.com Nabors 245 Date From - To Hours Code Sub Phase Code 12/26/2001 00:00 - 03:30 3.50 WELCTL BOPE CMPL TN 03:30 - 04:00 0.50 CMPL TN SFTY CMPL TN 04:00 - 17:00 13.00 CMPL TN TRIP CMPL TN 17:00 - 20:30 3.50 CMPLTN CIRC CMPLTN 20:30 - 00:00 3.50 CMPL TN TRIP CMPL TN 12/27/2001 00:00 - 03:30 3.50 CMPL TN TRIP CMPL TN 03:30 - 03:45 0.25 LOG SFTY CMPL TN 03:45 - 05:00 1.25 LOG RURD CMPL TN 05:00 - 10:00 5.00 LOG ELOG CMPL TN 10:00 - 12:00 2.00 LOG ELOG CMPL TN 12:00 - 20:30 8.50 LOG ELOG CMPL TN 20:30 - 22:00 1.50 CMPL TN DEQT CMPL TN 22:00 - 00:00 2.00 CMPL TN OTHR CMPL TN 12/28/2001 00:00 - 01 :30 1.50 CMPL TN OTHR CMPL TN 01 :30 - 02:00 0.50 CMPL TN SFTY CMPL TN 02:00 - 13:00 11.00 CMPL TN RUNT CMPL TN 13:00 - 14:00 1.00 CMPL TN OTHR CMPL TN 14:00 - 15:00 1.00 CMPLTN CIRC CMPL TN 15:00 - 16:00 1.00 CMPL TN PCKR CMPL TN 16:00 - 17:30 1.50 CMPL TN crRC CMPL TN 17:30 - 18:30 1.00 CMPL TN SOHO CMPL TN Spud Date: 12/10/2001 End: 12/29/2001 Group: Start: 12/9/2001 Rig Release: 12/29/2001 Rig Number: 245 Description of Operations 5000 psi. Install wear ring. RD test equip ment. Blow down surface equipment. PJSM - discuss procedure for picking up tub ing and running scraper. MU 6-1/8" bit, bit sub, 7" 26# scraper, & XO Pick up and RIH wI 3-1/2" tubing. Tag flo at collar at 12581'. Circ and condition mud. Circ 48 bbls weight ed high vis sweep. 10# mud wt coming out of hole after sweep. Pump dry job. POOH wI tbg to 7280'. LD 20 jts tbg. Stand back remainder in derrick. Pull seal rings on broken connections. POOH wI 3-1/2" tbg. LD bit and scraper. PJSM wI Schlumberger. Discuss procedures for rigging up E-Line. RU to run E-Line. RIH wI US IT tool. Slow going through sail s ection. Going 50 ft/hr at 9200'. POOH wI E-line. Remove Gemoco centralize r. RIH wI E-Line. RIH wI E-Line. Run US IT log from 12560' to 11000'. TOC 11268'. Pressure test 7" casing to 3550 psi. Pressu re bled off to 3510 in 30 min. Bleed off pre ssure. RU to perform LOT on 9-5/8"x7" annulus. St art pumping. Pressure coming up very quick Iy. SO and check all valves. OK. Perform LOT. 1975 psi max pressure with 10.5 ppg mud in hole. Pump 3 bbls past breakdown. SI wI 1700 psi on annulus. Pressure bled d own to 1350 psi in 10 min. EMW at 9-5/8" s hoe=19.65 ppg. RD test equipment for LOT. Pull wear bus hi ng. Prep floor to run tbg. LD top 2 jts on s t d 1. PJSM - Discuss procedures for running comp let ion. PU BHA including packer. RIH installing ga s lift mandrels and jewelry per procedure. S top wI packer at 12132'. Flush 9-5/8"x7" ann ulus wI 300 bbls fresh water. Freeze protec t annulus wI 70 bbls diesel. Change bales. RU to drop ball Pump 100 bbls seawater to flush around pac ker at max rate of 3 BPM. Drop ball. Pump down with seawater. Set p acker at 12132'. Blowout shear out sub. P ull up out of PBR. Flush and Displace 7"x3-1/2" annulus with 8 75 bbls seawater. Space out tubing. MU tubing hanger and Ian Punted" 1/22/2002 1123:20 AM ~. ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 12/28/2001 17:30 - 18:30 18:30 - 21 :30 Page 8 of 8 PHILLIPS ALASKA INC. Operations Summary Report 1 R-36 1 R-36 ROT - DRILLING n1268@ppco.com Nabors 245 Sub Hours Code Code Phase 1.00 CMPL TN SOHO CMPL TN 3.00 CMPL TN DEOT CMPL TN 21 :30 - 22:00 0.50 CMPL TN RURD CMPL TN 22:00 - 22:30 0.50 CMPL TN OTHR CMPL TN 22:30 - 00:00 1.50 WELCTL NUND CMPL TN 12/29/2001 00:00 - 01 :00 1.00 WELCTL NUND CMPL TN 01 :00 - 04:00 3.00 CMPL TN NUND CMPL TN 04:00 - 12:00 8.00 CMPL TN RURD CMPL TN Spud Date: 12/10/2001 End: 12/29/2001 Group: Start: 12/9/2001 Rig Release: 12/29/2001 Rig Number: 245 Description of Operations d tubing. Run in lock down screws. RU test equipment. Test tbg to 1500 psi. G ood. Test annulus to 3500 psi. Good. No c ommunication with tubing. Bleed off tubing and shear the shear-out valve in GLM #5. R D test equipment. LD landing joint. Install 2.way check in tub ing hanger. LD long bales. PU drilling bales. ND BOP. N D BO P. Install tree. Test to 250 psi low and 5000 p si high for 5 min. Test packoff to 5000 psi. Prep cellar to lift. Prep rig to skid. Win terize pumps and pits. Secure board. LD 15 stands 5" DP out of derrick. Freeze p rotect 7"x3-1/2" annulus and tubing with 80 bbls diesel at 2.5 BPM and 450 psi. Blow d own lines. U-tube annulus and tubing. Con tinue prep rig for rig move. Move Camp to 1 C. Rig released at 1200 hrs. Pnnted: 1/22/2002 1123:20 AM Date 04/04/02 04/05/02 04/17/02 1 R-36 Event History Comment REPLACED SHEARED SOV @ 12,058' RKB W/ DV, PT TBG TO 1000# & I/A TO 3000# [GL V. PT TBG-CSG] CLEANED OUT MUD/FILL TO 12,570' CTM W/ SLICK SEAWATER. SLICK DIESEL, AND DIESEL GEL USING A 1.75" VORTECH DOWN-JET/SIDE-JET NOZZLE. WELL FREEZE PROTECTED W/ DIESEL TO 2500'+. [FCO, VORTECH] RIG UP RUN 14',2.5" 6 SPF, 60 DEG PHASED. 2506 POWERJET. TIE IN, PERFORATE 12284'-12298', WHP IMMEDIATE ROSE FROM 200 TO 1000 PSI. RIH FOR PRESSURE TEMP SURVEY AFTER PERF, FOUND BHP @ 12291 (MID PERF) WAS 3746 PSI @ 158 DEG. PRESSURE @ 12191' WAS 3709 PSI @ 155 DEG. Page 1 of 1 5/22/2002 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 1 R-36 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD , MD (if applicable) 'MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ';i".O\ - dd. 7 28-Dec-01 t~E(~E,I\/ED DEC 2 8 2001 :1,3E;~d 'oj"~ ú Ga~ \~(III$" '''';Olnmissio¡"¡ ,.:!,nr'¡ f"'1fagE ~øt:t.~~~." -,o-.~ . - . DEF NITIVE Kuparuk River Unit North Slope, Alaska Kuparuk 1 R, Slot 1 R-36 1 R-36 Gyro Job No. AKMM11210, Surveyed: 22 December, 2001 28 December, 2001 r~~C,EJ\JEO r\ 5..:... ...... D~C L ß '2.~Q' " .\"'1'\ ", ..,.' '''orTi\\I\S5 UI ..", ¡; (:'i::>~ VOl'''' v \ I 'rn ," vti" Þlaß~á"'" 'J þ.,f\t~?Ofagë. SURVEY REPORT Your Ref: API 500292305700 Surface Coordinates: 5991810.24 N, 539829.55 E (70023' 18.8471" N, 149040' 33,6960" W) Surface Coordinates relative to Project H Reference: 991810.24 N, 39829.55 E (Grid) Surface Coordinates relative to Structure: 760.14 N, 3.84 E (True) Kelly Bushing: 83.80ft above Mean Sea Level 5pe'-''-'V-5iuf1 CRILLING SERVICes A Halliburton Company Survey Ref: svy9746 Sperry-Sun Drilling Services Survey Report for 1 R.a6 Gyro Your Ref: API 500292305700 Job No. AKMM11210, Surveyed: 22 December, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (a/100ft) 0.00 0,000 0.000 -83.80 0.00 O.OON 0.00 E 5991810.24 N 539829.55 E 000 Tolerable Gyro 175.00 0.300 132.000 91.20 175.00 0.31 S 0.34 E 5991809.94 N 539829.89 E 0.171 -0.21 266.00 ° 250 286.000 182.20 266.00 0.41S 0.33 E 5991809.83 N 539829.88 E 0.589 -0.31 354.00 2.000 296.000 270.18 353.98 0.31 N 1.24W 5991810.55 N 539828.31 E 1.994 -0.02 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.986" (09-Dec-01) The Dogleg Severity is In Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 15.2900 (True). Based upon Minimum Curvature type calculations. at a Measured Depth of 354.0Oft., The Bottom Hole Displacement is 1. 28ft. , in the Direction of 284.268° (True). Survey tool program for 1 R-36 Gyro From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 354.00 353.98 Tolerable Gyro -------- -- 28 December, 2001 - 10: 13 Page20f2 DrillQuesI2.00.09.003 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 1 R-36 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD (if applicable) 12,700.00' MD ~Q ,- ;;:;;J.I 28-Dec-0 1 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEI'Jl::D Of:C 2 8 2001 Alaska Oil &. Gas Cons. COmm¡S31ùl Ancborage DEF N TIVE ",- Kuparuk River Unit North Slope, Alaska Kuparuk 1 R, Slot 1 R-36 1 R-36 Job No. AKMM112101 Surveyed: 22 December, 2001 SURVEY REPORT 28 December, 2001 Your Ref: API 500292305700 Surface Coordinates: 5991810.24 N, 539829.55 E (70023' 18.8471" N, 149040' 33.6960" W) Surface Coordinates relative to Project H Reference: 991810.24 N, 39829.55 E (Grid) Surface Coordinates relative to Structure: 760.14 N, 3.84 E (True) Kelly Bushing: 83.8Oft above Mean Sea Level spsrtrtY-SUl1 DRILLING SERVices A Halliburton Company Survey Ref: svy9747 Sperry-Sun Drilling Services . ~ Survey Report for 1 R-36 Your Ref: AP/500292305700 Job No. AKMM11210, Surveyed: 22 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Verllcal Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 354.00 2.000 296.000 270.18 353.98 0.31 N 1.24W 5991810.55 N 539828.31 E -0.02 MWD Magnetic 476.82 4.610 289.960 392.78 476.58 2.94 N 7.80W 5991813.14 N 539821.73 E 2.141 0.78 568.52 7.110 306.800 484.00 567.80 7.60N 15.81 W 5991817.75 N 539813.70 E 3.281 3.16 659.21 9.990 305.930 573.68 657.48 15.58 N 26.68 W 5991825.68 N 539802.79 E 3.179 7.99 751 .78 11 .360 314.860 664.65 748.45 26.72 N 39.65 W 5991836.75 N 539789.76 E 2.316 15.32 839.71 12.080 322.780 750.75 834.55 40.1 6 N 51.35 W 5991850.12 N 539777.99 E 2.002 2520 933.61 14.150 331.820 842.21 926.01 58.10 N 62.72 W 5991868.01 N 539766.52 E 3.097 39.51 1023.23 14.950 338.660 928.96 1012.76 78.53 N 72.10 W 5991888.38 N 539757.04 E 2.113 5674 1117.60 16.300 339.090 1019.84 1103.64 102.24 N 81.25 W 5991912.04 N 539747.75 E 1.436 77.19 1211.30 18.160 341.270 1109.33 1193.13 128.35 N 90.64 W 5991938.11 N 539738.23 E 2.101 9991 1301.78 20.190 343.730 1194.79 1278.59 156.70 N 99.54 W 5991966.41 N 539729.18 E 2.414 124.90 1395.73 20.860 346.800 1282.78 1366.58 188.55 N 107.90 W 5991998.21 N 539720.65 E 1.349 153.42 1489.23 22.640 349.900 1369.62 1453.42 222.48 N 114.86 W 5992032.10 N 539713.51 E 2.265 184.31 1582.27 25.580 354.770 1454.54 1538.34 260.12 N 119.83 W 5992069.72 N 539708.33 E 3.813 219.31 1675.30 27.860 356.890 1537.63 1621.43 301.83 N 122.84 W 5992111.41 N 539705.10 E 2.656 258.75 1767.61 31.950 357.150 1617.64 1701.44 347.78 N 125.23 W 5992157.35 N 539702.47 E 4.433 302.45 1860.33 36.400 359.210 1694.33 1778.13 399.82 N 126.83 W 5992209.38 N 539700.59 E 4.958 352.22 1954.85 42.560 2.590 1767.26 1851.06 459.86 N 125.77 W 5992269.42 N 539701.33 E 6.900 410.42 2047.94 47.030 5.610 1833.31 1917.11 525.24 N 121.02 W 5992334.83 N 539705.74 E 5.317 474.74 2143.59 49.820 7.120 1896.78 1980.58 596.35 N 113.06 W 5992405.97 N 539713.31 E 3.147 545.42 2238.16 54.010 9.420 1955.10 2038.90 669.98 N 102.32 W 5992479.66 N 539723.66 E 4.826 619.28 2330.85 56.520 11 .280 2007.91 2091.71 744.89 N 88.62 W 5992554.65 N 539736.97 E 3.170 695.16 2425.56 59.190 13.010 2058.30 2142.10 823.27 N 71.73 W 5992633.12 N 539753.44 E 3.215 775.22 2519.16 62. 11 0 14.840 2104.18 2187.98 902.44 N 52.08 W 5992712.39 N 539772.66 E 3.555 856.77 2613.16 64.420 16.280 2146.47 2230.27 983.31 N 29.55 W 5992793.38 N 539794.76 E 2.813 940.71 2705.59 67.060 18.140 2184.44 2268.24 1063.79 N 4.61 W 5992873.99 N 539819.27 E 3.395 1024.92 2799.39 67.890 18.260 2220.38 2304.18 1146.09 N 22.45 E 5992956.44 N 539845.90 E 0.893 1111.45 2891.97 67.250 18.010 2255.70 2339.50 1227.42 N 49.09 E 5993037.90 N 539872.10 E 0.735 1196.92 2985.66 67.150 18.130 2292.01 2375.81 1309.53 N 75.88 E 5993120.15 N 539898.45 E 0.159 1283.19 3075.83 67.890 17.270 2326.48 2410.28 1388.90 N 101.21 E 5993199.66 N 539923.36 E 1.204 1366.43 ---- ----.- - 28 December, 2001 - 10:53 Page2of7 Drll/Quest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 1 R-36 Your Ref: API 500292305700 Job No. AKMM11210, Surveyed: 22 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azlm. Depth Depth Northlngs EIstlngs Northlngs Elstlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 3168.83 68.920 17.370 2360.71 2444.51 1471.45 N 126.95 E 5993282.35 N 539948.66 E 1.112 1452.84 3260.47 69.190 17.630 2393.47 2477.27 1553.08 N 152.69 E 5993364.11 N 539973.96 E 0.396 1538.37 3353.82 67.620 18.870 2427.83 2511.63 1635.50 N 179.86 E 5993446.68 N 540000.70 E 2.087 1625.04 3447.15 67. 150 18.970 2463.72 2547.52 1717.00 N 207.80 E 5993528.33 N 540028.20 E 0.513 1711.02 3539.31 68.690 18.930 2498.36 2582.16 1797.77 N 235.53 E 5993609.24 N 540055.50 E 1.671 1796.25 3630.96 69.840 19.760 2530.81 2614.61 1878.64 N 263.92 E 5993690.26 N 540083.46 E 1.514 1 881 .74 3725.18 68.480 19.100 2564.33 2648.13 1961.68 N 293.22 E 5993773.46 N 540112.31 E 1.585 1969.57 3817.95 67.190 16.620 2599.33 2683.13 2043.44 N 319.57 E 5993855.36 N 540138.23 E 2.839 2055.38 3912.04 66.970 16.730 2635.97 2719.77 2126.46 N 344.44 E 5993938.51 N 540162.66 E 0.257 2142.02 4005.12 66.450 16.330 2672.77 2756.57 2208.42 N 368.76 E 5994020.59 N 540186.54 E 0.684 2227.50 4097.41 67.140 15.920 2709.14 2792.94 2289.91 N 392.32 E 5994102.21 N 540209.67 E 0.852 2312.31 4190.95 67.800 15.890 2744.98 2828.78 2373.00 N 416.00 E 5994185.42 N 540232.90 E 0.706 2398.71 4284.67 68.840 15.500 2779.60 2863.40 2456.84 N 439.56 E 5994269.39 N 540256.01 E 1.175 2485 79 4376.88 67.520 16.980 2813.88 2897.68 2539.03 N 463.49 E 5994351.70 N 540279.51 E 2.066 2571.38 4470.40 66.330 16.210 2850.53 2934.33 2621.48 N 488.06 E 5994434.28 N 540303.64 E 1.481 2657.39 4564.19 64.970 17.050 2889.20 2973.00 2703.35 N 512.51 E 5994516.28 N 540327.66 E 1.664 2742.81 4658.98 65.520 16.400 2928.89 3012.69 2785.79 N 537.28 E 5994598.85 N 540351.99 E 0.851 2828.86 4752.87 65.790 17.050 2967.60 3051.40 2867.71 N 561.90 E 5994680.90 N 540376.17 E 0.693 2914.38 4844.97 66.320 17.370 3004.98 3088.78 2948.11 N 586.81 E 5994761.44 N 540400.65 E 0.657 2998.50 4937.96 65.840 17.220 3042.68 3126.48 3029.27 N 612.08 E 5994842.73 N 540425.48 E 0.537 3083.45 5029.92 65.660 16.850 3080.45 3164.25 3109.44 N 636.64 E 5994923.03 N 540449.62 E 0.416 3167.26 5122.48 65.460 17.230 3118. 75 3202.55 3190.01 N 661.33 E 5995003.72 N 540473.88 E 0.432 3251.49 5213.98 65.840 17.690 3156.47 3240.27 3269.53 N 686.35 E 5995083.38 N 540498.47 E 0.618 3334.79 5305.76 65.730 17.600 3194.12 3277.92 3349.29 N 711.72 E 5995163.28 N 540523.42 E 0.150 3418.42 5400.17 66.310 18.660 3232.49 3316.29 3431.27 N 738.56 E 5995245.39 N 540549.82 E 1.196 3504 58 5493.12 66.630 19.640 3269.60 3353.40 3511 .77 N 766.52 E 5995326.04 N 540577.35 E 1.026 3589.60 5583.52 65.240 18.970 3306.46 3390.26 3589.67 N 793.81 E 5995404.09 N 540604.23 E 1.680 3671.94 56'16.37 65.020 19.600 3345.51 3429.31 3669.18 N 821.63 E 5995483.75 N 540631.62 E 0.660 3755.97 5772.95 66.060 19.540 3385.50 3469.30 3752.01 N 851.07 E 5995566.73 N 540660.63 E 1.078 3843.64 5866.98 67.270 18.000 3422.74 3506.54 3833.76 N 878.85 E 5995648.63 N 540687.97 E 1.979 3929.81 - - - -- -- ---- - .-- . - -.-. ---- ---- - 28 December, 2001 - 10:53 Page 3 of 7 DrIllQuesI2.00.09.003 .... . Sperry-Sun Drilling Services Survey Report for 1 R-36 Your Ref: API 500292305700 Job No. AKMM11210, Surveyed: 22 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local CoordInates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (It) (ft) (ft) (It) (ft) (ft) (ft) (°/1 OOft) 5961.20 66.260 17.890 3459.91 3543.71 3916.12 N 905.52 E 5995731.13 N 540714.20 E 1.077 4016.30 6055.34 66.460 16.180 3497.67 3581.47 3998.58 N 930.79 E 5995813.72 N 540739.03 E 1.678 4102.49 6148.00 67.070 14.640 3534.22 3618.02 4080.66 N 953.41 E 5995895.92 N 540761.21 E 1.663 4187.63 6240.42 66.170 14,050 3570.90 3654.70 4162.84 N 974.43 E 5995978.21 N 540781.79 E 1.137 4272.45 6334.71 65.030 13.120 3609.85 3693.65 4246.31 N 994.60 E 5996061.78 N 540801.52 E 1.506 4358.28 6427.28 65.610 14.600 3648.50 3732.30 4327.97 N 1014.75 E 5996143.55 N 540821.23 E 1.582 4442.37 6519.25 64.650 14.570 3687.18 3770.98 4408.72 N 1035.76 E 5996224.41 N 540841.81 E 1.044 4525.80 6615.01 65.250 15.670 3727.73 3811.53 4492.46 N 1058.39 E 5996308.28 N 540864.00 E 1.215 4612.55 6707.20 65.530 14.900 3766.12 3849.92 4573.31 N 1080.49 E 5996389.24 N 540885.66 E 0.818 4696.36 6800.50 65.570 17.870 3804.74 3888.54 4654.79 N 1104.44 E 5996470.84 N 540909.18 E 2898 4781.27 6894.00 65. 180 17.800 3843.70 3927.50 4735.70 N 1130.47 E 5996551.89 N 540934.78 E 0.423 4866.18 6989.54 63.970 18.440 3884.72 3968.52 4817.70 N 1157.31 E 5996634.04 N 540961 .18 E 1.404 4952.36 7082.69 64.660 19.120 3925.09 4008.89 4897.18 N 1184.33 E 5996713.66 N 540987.78 E 0.991 5036.15 7176.48 64.330 18.850 3965.48 4049.28 4977 .22 N 1211.87E 5996793.85 N 541014.89 E 0.437 5120.62 7271.08 64.990 19.220 4005.97 4089.77 5058.05 N 1239.76 E 5996874.82 N 541042.35 E 0.782 5205.94 7369.03 64.890 17.350 4047.46 4131.26 5142.29 N 1267.59 E 5996959.21 N 541069.74 E 1.732 5294.54 7451.02 65.430 16.380 4081.90 4165.70 5213.49 N 1289.18 E 5997030.53 N 541090.94 E 1.260 5368.92 7545.16 64.890 15.510 4121.45 4205.25 5295.64 N 1312.65 E 5997112.79 N 541113.97 E 1.016 5454.34 7639.23 64.420 15.310 4161.72 4245.52 5377.59 N 1335.24 E 5997194.87 N 541136.13 E 0.535 5539,36 7732.98 63.950 14.640 4202.54 4286.34 5459.12 N 1357.05 E 5997276.51 N 541157.50 E 0.816 5623.75 7825.31 64.750 15.240 4242.51 4326.31 5539.54 N 1378.51 E 5997357.04 N 541178.53 E 1.046 5706 98 7919.57 66.110 16.840 4281.70 4365.50 5621.92 N 1402.20 E 5997439.55 N 541201.78 E 2.113 5792,69 8011.84 66.440 17.940 4318.83 4402.63 5702.53 N 1427.44 E 5997520.29 N 541226.60 E 1.149 5877,10 8105.24 66.110 17.330 4356.41 4440.21 5784.01 N 1453.35 E 5997601.91 N 541252.07 E 0.694 5962.54 8195.28 66.980 17.560 4392.25 4476.05 5862.81 N 1478.11 E 5997680.84 N 541276.41 E 0.994 6045.08 8289.45 67.060 18.040 4429.01 4512.81 5945.36 N 1504.62 E 5997763.53 N 541302.48 E 0.477 6131.69 8382.46 66.650 17.390 4465.57 4549.37 6026.83 N 1530.64 E 5997845.14 N 541328.07 E 0.779 621 7 14 8474.28 67.720 19.070 4501.18 4584.98 6107.21 N 1557.12 E 5997925.66 N 541354.12 E 2.050 6301.66 8567.33 67.570 18.340 4536.57 4620.37 6188.72 N 1584.72 E 5998007.31 N 541381.28 E 0.743 6387.56 86!57.37 67.450 18.830 4571.01 4654.81 6267.57 N 1611.23 E 5998086.31 N 541407.38 E 0.520 6470.61 ----- -._-- - -- - --- ,- - ----- - - --- ---- - -- 28 December, 2001- 10:53 Page 4 of 7 DrIllOuesI2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 1 R-36 Your Ref: API 500292305700 Job No. AKMM11210, Surveyed: 22 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8752.04 67.170 18. 160 4607.53 4691.33 6350.40 N 1638.94 E 5998169.28 N 541434.64 E 0.717 6557.82 8844.98 66.830 17.780 4643.84 4727.64 6431.78 N 1665.33 E 5998250.80 N 541460.60 E 0.525 6643.28 8937.21 66.770 17.570 4680.18 4763.98 6512.55 N 1691.07 E 5998331.71 N 541485.91 E 0.219 6727.97 9031.77 66.710 17.420 4717.52 4801.32 6595.41 N 1717.19E 5998414.70 N 541511.58 E 0.159 6814.78 9125.90 66.560 16.990 4754.85 4838.65 6677.95 N 1742.75 E 5998497.38 N 541536.70 E 0.449 6901.15 9217.29 66.240 16.960 4791.44 4875.24 6758.05 N 1767.20 E 5998577.61 N 541560.73 E 0.351 6984.86 9311.92 65.760 16.420 4829.93 4913.73 6840.86 N 1792.03 E 5998660.54 N 541585.11 E 0.727 7071.28 9405.44 65.710 16.150 4868.36 4952.16 6922.69 N 1815.93 E 5998742.51 N 541608.58 E 0.269 7156.52 9498.10 65.240 15.930 4906.82 4990.62 7003.71 N 1839.23 E 5998823.65 N 541631.45 E 0.551 7240.82 9591.58 65.910 17.280 4945.48 5029.28 7085.27 N 1863.55 E 5998905.34 N 541655.34 E 1.498 7325.91 9683.49 66.310 17.770 4982.70 5066.50 7165.41 N 1888.86 E 5998985.61 N 541680.21 E 0.653 7409.88 9780.01 65.920 17.350 5021. 78 5105.58 7249.55 N 1915.48 E 5999069.89 N 541706.39 E 0.567 7498.06 9874.06 65.430 16.880 5060.52 5144.32 7331.45 N 1940.71 E 5999151.93 N 541731.18 E 0.692 7583.72 9966.32 64.900 16.890 5099.27 5183.07 7411.57 N 1965.02 E 5999232.17 N 541755.07 E 0.575 7667.41 10059.51 66.640 16.670 5137.52 5221.32 7492.93 N 1989.56 E 5999313.66 N 541779.17 E 1.880 7752.36 10151.17 66.980 16.690 5173.61 5257.41 7573.64 N 2013.74 E 5999394.50 N 541802.92 E 0.371 7836.59 10243.90 66.450 15.930 5210.27 5294.07 7655.39 N 2037.66 E 5999476.37 N 541826.41 E 0.945 7921. 75 10335.94 65.040 15.580 5248.08 5331.88 7736.15 N 2060.45 E 5999557.25 N 541848.76 E 1.571 8005.66 10431.36 63.590 15.340 5289.43 5373.23 7819.02 N 2083.37 E 5999640.25 N 541871.24 E 1.536 8091.65 10525.53 63.190 16.11 0 5331.61 5415.41 7900.07 N 2106.19E 5999721.41 N 541893.63 E 0.845 8175.84 10618.52 61 .370 15.790 5374.87 5458.67 7979.21 N 2128.81 E 5999800.68 N 541915.83 E 1.981 8258.15 10711.33 59.390 15.850 5420.73 5504.53 8056.83 N 2150.80 E 5999878.42 N 541937.41 E 2.134 8338.83 10803.39 59.110 17.020 5467.80 5551.60 8132.72 N 2173.18E 5999954.42 N 541959.39 E 1.134 8417.93 10898.02 57.000 17.770 5517.87 5601.67 8209.34 N 2197.18 E 6000031.17 N 541982.98 E 2.329 8498.1 f) 10990.23 54.400 16.710 5569.83 5653.63 8282.08 N 2219.77 E 6000104.03 N 542005.17 E 2.975 8574.29 11084.86 52. 1 00 16.820 5626.45 5710.25 8354.68 N 2241.64 E 6000176.74 N 542026.65 E 2.432 8650.08 11178.48 50.660 16.630 5684.88 5768.68 8424.73 N 2262.69 E 6000246.90 N 542047.33 E 1.546 8723.20 11271.52 49.930 16.220 5744.31 5828.11 8493.38 N 2282.93 E 6000315.66 N 542067.21 E 0.855 8794.76 11364.89 47.910 17.830 5805.67 5889.47 8560.68 N 2303.52 E 6000383.06 N 542087.44 E 2.524 8865.11 11458.74 44.910 18.970 5870.37 5954.17 8625.17 N 2324.95 E 6000447.67 N 542108.53 E 3.315 8932.97 -------- - 28 December, 2001 - 10:53 Page 5 of 7 DrlllQue!òt 2.00.09.003 ~ . . Sperry-Sun Drilling Services . ~ Survey Report for 1 R-36 Your Ref: API 500292305700 Job No. AKMM11210, Surveyed: 22 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local CoordInates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs E.atlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11549.93 42.680 19.170 5936,19 6019.99 8684.82 N 2345.57 E 6000507.43 N 542128.83 E 2.450 8995.94 11644.30 39.940 19.390 6007.07 6090.87 8743.61 N 2366.13 E 6000566.33 N 542149.08 E 2.908 9058.08 11738.85 36.560 17.500 6081.31 6165.11 8799.12 N 2384.68 E 6000621.93 N 542167.33 E 3.783 9116.51 11831.03 34.090 14.170 6156.52 6240.32 8850.36 N 2399.27 E 6000673.26 N 542181.64 E 3.397 9169.79 ',-. 11923.93 33.550 15.040 6233.70 6317.50 8900.40 N 2412.30 E 6000723.36 N 542194.41 E 0.781 9221.49 11971.34 33.500 16.200 6273.23 6357.03 8925.61 N 2419.35 E 6000748.61 N 542201.33 E 1.355 9247.67 12023.93 33.510 19.620 6317.08 6400.88 8953.23 N 2428.28 E 6000776.27 N 542210.10 E 3.589 9276.66 12112.40 32.960 20.040 6391.08 6474.88 8998.84 N 2444.72 E 6000821.97 N 542226.31 E 0.674 9325.00 12205.93 32.660 18.530 6469.69 6553.49 9046.67 N 2461.46 E 6000869.89 N 542242.79 E 0.932 9375.55 12300.27 32.310 17.680 6549.27 6633.07 9094.83 N 2477.21 E 6000918.13 N 542258.28 E 0.610 9426.16 12391.81 32.170 17.680 6626.70 6710.50 9141.36 N 2492.04 E 6000964.74 N 542272.87 E 0.153 9474.95 12486.03 31.890 17.810 6706.57 6790.37 9188.95 N 2507.27 E 6001012.41 N 542287.84 E 0.306 9524.87 12578.68 31.230 17.870 6785.52 6869.32 9235.11 N 2522.13 E 6001058.65 N 542302.45 E 0.713 9573.32 12621. 1 2 31.070 17.710 6821.84 6905.64 9256.01 N 2528.83 E 6001079.59 N 542309.05 E 0.424 9595.25 12700.00 31.070 17.710 6889.40 6973.20 9294.79 N 2541.22 E 6001118.44 N 542321.22 E 0.000 9635.92 Projected Survey All dala is in Feet (US) unless otherwise staled. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.970° (28-Dec-01 ) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 15.290" (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12700.0011., The Bottom Hole Displacement is 9635.92ft., in the Direction of 15.291 ° (True). - - --- . -. - ---. _. - . - -. -- -- -_. -.- ---- - -- - -.- - -- -. - ----- - ------ 28 December, 2001 - 10:53 Page 6 of 7 DrlflQuest 2.00.09.003 . ,I.:, ,. . . Kuparuk River Unit Comments Measured Depth (ft) 12700.00 '. Sperry-Sun Drilling Services Survey Report for 1 R-36 Your Ref: API 500292305700 Job No. AKMM11210, Surveyed: 22 December, 2001 . 9294.79 N Survey tool program for 1 R-36 North Slope, Alaska Kuparuk 1 R Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) 6973.20 From Measured Vertical Depth Depth (ft) (It) 0.00 354.00 - ---- -~----- - . 0.00 353.98 28 December, 2001- 10:53 - -- . -- . - - - - - - - - --- To Measured Vertical Depth Depth (ft) (It) Comment 2541.22 E Projected Survey Survey Tool Description 354.00 12700.00 353.98 Tolerable Gyro (1 R-36 Gyro) 6973.20 MWD Magnetic (1 R-36) - --. - - ----------- Page 7 of 7 DrlllQuest 2.00.09.003 do{-d..~, \\,'ELL LOG TRANSI\fi1TAL To: State of Alaska Alaska Oil and Gas Conservation Comm Attn.: Lisa Weepie 333 West 7\J1 Avenue, Suite ]00 Anchorage, A1aska .-\pril 10, 2002 RE: J\1\VD Forn1ation EvaJuation Logs I R-36, AK-MM-11210 1 LDWG fonnatted Disc \";th verification listing. API#: 50-029-23057-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING j\ COP\" OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 995 18 RECEIVED Date: ¡ ~:-'- .; í) :¡10? .. ." . . 11....", - Signe~-7\~Álà- ~ AtaskaOil & Gas Cons,. Commission Ancborag€' óbl- d~ ~t) I-00q ó\OI-''=l~ aOI~ dÒo :::10\' aa 4 âO)- I L-I d ,¿ () ) -' I ~ ~ Scblum_epgep Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Sherrie Well Job # 2P-415A 2P-417 2P-420 1C-135 1R-36 2N-348 2P-420 22010 22009 22011 22008 Log Description PRESSITEMP STATION LOGS STATIC BOTTOM HOLE PRESS SURVEY PRESSITEMP STATION LOGS USIT USIT SCMT SCMT SIGNE&-lrr}.(~(pp~ Date 12/24/01 12/13/01 12/23/01 12/18/01 12/27/01 12/09/01 12/22/01 DATE: 01/15/02 NO. 1725 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Sepia CD Color 1 1 1 1 1 1 1 1 1 1 --<ECEIVE[ .JAN ? 5 Î~O? Alaska Oil & Gas Cons. Cormnission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Anchorage ~ PHILLlP~ Alaska, Inc. ,~ A Subsidiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Chuck Mallary Phone (907) 265-6434 Fax: (907) 265-1535 Email: crmalla@ppco.com December 7, 2001 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application to Amend Permit to Drill, Injector 1 R-36 Dear Commissioner Taylor: Phillips Alaska, Inc. hereby applies for a revision of Permit to Drill #201-227 which was originally approved 12/4/01 for an onshore injector well, KRU 1 R-36. The planned bottom-hole location has been moved more than 500' from the original plan. Also, the well will now be completed as a producer. The Kuparuk "C1" sand thickness was re-mapped after electric logs obtained from 1 R-35 were interpreted. The "C1" sand is believed to thin-out near the original target location. Thus, it was decided to move the target crossing location. It is believed the oil-water contact was observed in the "A3" sand on 1 R-35. Based on this interpretation of the "A3" sand, it was decided to change the service of the 1 R-36 well to a producer. 1 R-35 will be a producer initially, but it is anticipated that we will request to change 1 R-35 from a producer to an injector at a later date. Attached is the revised application that reflects changes in the directional plan, casing points, cement volumes, and proposed completion arrangements. If you have any questions or require any further information, please contact Scott Lowry at 265-6869. SinCerel , &~j I:' n .7. L., , ¡/['Ui, .,~ Chuck Mallary G Drilling Engineering Supervisor 1/# l.~ 2 c~ t) I RECEIVED DEe () 7 2001 AI_Oil & Gas c A OIJs. Commi,ssion , nchorage ~~fÆ~~ : F fÆ~fÆ~~~fÆ I ! ALASKA OIL AND GAS CONSERVATION COMMISSION TONYKNOWLES,GOVERNOR 333 W. rr" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck MallaI)' Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage Alaska 99510 Re: Kuparuk lliver Unit 1 R-36-Re\;sed Phillips Alaska, Inc. Pennit No: 201-227 Sur. Loc. 606' FSL, 147, FWL, Sec. 17, T12N, RIOE, Ut\.1 Btmhole Loc. 673' FSL, 2571' F\VL, Sec. 8, TI2N, RlOE, UM Dear 1\11". f\1allary: Enclosed is the approved revised application for permit to drill the above referenced well. This revision was requested due to drilling infonnation obtained from KRU IR-35. The proposed bonornhole location has been changed by more than 500'. The pem1it to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Kuparuk River Unit lR-36 must comply "rith the requirements and limitations of 20 AAC 25.080. Approval of this pennit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use tbat well for disposal purposes for a period longer than one year. 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 MC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the 1\1] 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 contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, J~~~~~; t=l-GLl/:a/v/ Commissioner BY ORDER OF THE COl\'Il\IISSION DATED this 7th da~' of December, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation wio encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 1a. Type of work: Drill 0 Rednll 0 Re-entry 0 Deepen 0 2. Name ot Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location ot well at surtace 606' FSL. 147' FWL. Sec. 17. T12N, R1OE. UM At top of productive interval 877'FNL,2634'FEL, Sec. 8, T12N, R10E, UM At total depth 673' FNL, 2571' FEL, Sec. 8. T12N, R10E, UM 12. Distance to nearest property line 13. Distance to nealest well 2571' @ TD feet 1 R-34 17' @ 600' 16. To be cDmpleted for deviated wells Kickoff depth: 296 MD 18. Casing program size 20 AAC 25.005 1b. Type of well Exploratory 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) RKB 41 feet 6. Property Designation ADL 25628 ALK 2561 Maximum hole angle 66° Hole Casing Weight 24" 16" 62.5# 12.25" 9.625" 40# 8.5" 7" 26# 6.125" 3.5" 9.3# Spec~ications Grade CDupllng H-40 Weld L-80 BTC-Mod L-80 STCM L-80 SLHT Length 120' 7371' 11974' ~' s;-:~ t 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: feet feet measured true vertical Effective Depth: measured true vertical feet feet Casing Conductor Surface Length Size Cemented Production Pertoration depth: measured true vertical feet 7. Unit or property Name Kuparuk River Unit 8. Well number 1 R-36 9. Approximate spud date December 7,2001 14. Number of acres in property 2560 /rId-A Development Oil 0 Multiple Zone 0 10. Field and Pool Kuparuk River Field Kuparuk River Pool 11. Type Bond I:>ee 20 AAC 25.02511 Statewide Number #5952 180 Amou nt $200,000 15. Proposed depth IMD and TVDI 12690' MD 16982' TVD 17. Anticipated pressure (see 20 AAC 25.035 leH211 Maximum surface 3177 pSlg At total depth (TVD) 3905 psig Setting Depth Commissioner by order of the commission Top Boltom TVD 161' 4154' 6400' 6982' Quantity of Cement (Include stage data) 420 sx AS 1 610 sx AS Lite, 850 sx LiteCrete 160 sx Class G 200 sx Class G wI GasBlok True Vertical depth RECEIVED Okil;tÙVÞ. DEG 0 '7 2001 Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot DReflaction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21.1 hereby certifï7t thtr,~~s Irue an:,rl1lO the best of my knowledge Questions? Call Scoff Lowry 265-6~6! Signed \!. '" I~' UL ~t:~T' Title: Or,¡¡,ng Engmeeflng Supen//$or Date 'i-.¿)e L~ k"rO I c. Mal/ary PreDared bv Sharon Al/suD-Drake , Commission Use Onl} Permit Number I API number I Approval df} I See cover leMer a-O \- () d'\ 50- OdC;-d~\j-S~'" Ql) t>C(:~.." ;)~Q' forotherrequirements Conditions of approval Samples required 0 Yes .~ No Mud log required 0 Yes '3 No Hydrogen sulfide measures ~ Yes 0 No Directional survey required -.sL. Yes 0 No , Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M;D ~s,saD~~, ~\~\IrVI..'V.."",,\ ~'C5V~~ Other: MD 41' 41' 41' .",)K' , \ \<¡.~ TVD 41' 41' 41' 6278' MD 161 ' 7412' 12015' 12690' Approved by OR~GINf'.! ~IGNí:T' f~~Y ,1 Nt. rieusse~ Form 10-401 Rev. 12/1/85' Plugs (measured) Junk (measured) Measured depth Date i I 1 1 '~I Submit in triplicate P 'ion to Pennit to Drill. Well 1 R-36 \ Saved: 7-Dec-01 Permit It - Kuparuk Well 1 R-36 Revision Application for Permit to Drill Document MaximizE Well ~olul; Table of Contents 1. Well Name................................................................................................................. 2 Requirements of 20 AAC 25.005 (f)............................. ............................................,. ............................. 2 2. Location Su mmary ................... ................................................................................ 2 Requirements of 20 AAC 25.005(c)(2) ..................................... ......... ....,...... .............. ............................ 2 Requirements of 20 AAC 25.050(b)....... ....................... ............ .......... ..... ..... ..... ..................................... 2 3. Blowout Prevention Equipment Information .........................................................3 Requirements of 20 AAC 25.005(c)(3) .. ....... .................................... .... .,........ ........................................3 4. Dri II i ng Hazards Information......................................... .......................................... 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests ...........................................3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program................................................................ ............. 3 Requirements of 20 AAC 25.005(c)(6) ... ....... ...,............ .............. ......... .,...... ..... ..... ....... ..................... ....3 7. Diverter System Information................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Dri II i ng FI u id Program.............. ........... .................................... ................................ 4 Requirements of 20 AAC 25.005(c)(B) ................................................................................................... 4 9. Abnormally Pressured Formation Information...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) . ..........., ............. ..................... .............. ...................... ............... 5 1 o. Se ism i c An a I ys is...................................... ................................................................ 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Cond ition Analysis...... .... ............. .............................. ................................ 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bondi ng ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Dri II i ng Program..................... .................. .............................................. 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 1 R-36 PERMIT IT #2. DOC 0 n ~ G NA Page 1 of 6 i_printed: 7-Dec-01 ~' 'Ion to Permit to Drill. Well 1 R-36 ~ Saved: 7-Dec-Ol 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) .......................................................... .............................. ........6 15. Attachments............ .................................................................... ............................. 6 Attachment 1 Directional Plan ..... ............................................,.. .............. .............................................6 Attachment 2 Drilling Hazards.............. ""'..'."'.'. .. ... .......... . .. ................. ............ ... .... ........ ..6 Attachment 3 Well Schematic......................................... ".".'.'.'.." """'.'."""..."".'. ..."..... ,.6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Idei1lified b,v a umque name deS/gn;Jtr:'d by tl,l2 operator anJ a umque API number as,C:lgn2d LJy tilt' ,~Ofnm6."ltln undc:r )0 AAC 25. fMO(b). For CJ ¡<.--eIII...'I!h llll/ltJplr3 H'r!I/ bumcllò' ['dell bran(lJ flI/6t _"If/ltldr(v /.JI:! Identllied by a unique ndn/r3 and API numLler by adding a suffix to [tIe name d251gnated k1r tlli:! ¡,,,,'¿>¡'I by tile operator and to the numbe!:'r assIgned to the v¡¡ell by rl7¿; CO!7lITl/5...';,IOn. The well for which this application is submitted will be designated as 1R-36. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) ,4n apP/¡ci)[¡on tOt a Penmt to Onll must be acccmpanÙ?d bV r.:adl [Ii th:-' folio! rmg den/51 (~,\cept fN an Ih~m alri'."adv' on ri/e t ¡'ll!1 tlh: l-ommi5slÒn and Idc?/Itifìed If7 the app/Jl~rJtion.. (.?) a pl:"1f Identlf} /ilg tIle;' property anri tIle pr,7/-Jr:Yf,t"'.; f)W/lr?/:':; an,} ,'~;II":nl'¡nq ,ANile!:' Lu()rl.líndle'.s of tile! prD¡'YJse!J I'¡XdtlJII o.r tile' we'll éJf tilt' SUrr~JCt'., ell llle! fl'//.' c.v. rai./) oty~u.::tn'e! íormdt/()f/, and at t,)tal d2ptll rel2:'f!nct'll to giwe'flllI1e!lItal sr?dll)f/ liflt:'..; (8) the CUQ/iilfldtð (,If the pf(/po5cd /OCJ!IOf! o/th:..' It'ell dt tlie 5urlJce, rel"erl?n.::~d to tIle gate p¡~;¡në' courdll7¡¡tc s}'stetn ror tlJl'j stdle} ðS l1umtal/k.'d b,~ the N,."ltic.JI7dl G~'odct;c SUll¡CY If! the.' /V.:Jtt(Y'!dl o..,-l'dmc and Atfl7{)sphl...'(/L ~1Jf/7lfJJ5tratlonl. ((.I N/(~ propD5(":d dt'pth of tilt' l-rell at tile to,u of each OhhytivIC' /i."lt,.'7hìfl,,-ln and ~lt hJt31 dcptl/: 1606' FSL, 145' FWL, Sec 17, T12N, RIDE, UM RKB Elevation Pad Elevation Location at Surface NGS Coordinates Northings: 5,999,810 Eastings: 539,832 Location at Top of Productive Interval - (Kuparuk "Cl" Sand) NGS Coordinates Northings: 6,000,900 877' FNL, 2634' FEL, Sec 8, T12N, R10E, UM Eastings: 542,250 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: Location at Total Depth 1673' FNL, 2571' FEL, NGS Coordinates Northings: 6,001,105 Eastings: 542,311 Sec 8, TI2N, R10E, UM Measured Depth, RK8: Total Vertical Depth, RK8: Total Vertical Depth, 55: and (D) other ¡l,ti)rmd!IOI1 !equir,;:J or /0 ,.4,4C .J.), ViO, ll),' 84.2' AMSL 42.9' AMSL 12,262' 6612' 6528' 12,690' 6982' 6898' Requirements of 20 AAC 25.050(b) J(,:1 [¡1e;'11 IS /0 /"2. mtentiol/dllv deL'ldted tll.;' application {or r7 Pemlll h} Onll (FD,"n.l 10 -1(lI) trIlISt' (J.J Includt' CJ pla(, drawn to a su/tali/t" f-oL'J/t', sllL./! Vlf/£'/ tile pattI of t¡'¡¿; prupLJ:~;r::d H'c:://b(I(t.', mäudtng all d.dl.:-N_~':'!nt ¡'!'t'l.lbofr::'S ¡,vitiI/O ,100 ¡~d of any pJ/bollot thi! preJpose-J ¡¡Iel.,~' Please see Attachment 1: Directional Plan ând ( .?,J 'i)r all ¡,,¡¡ell.,,; ¡ ,'it/I/n ,"JOG' It!r?t (..llihc' pr:''P('.<;2d ¡1't"//bor¡;> c rG 'NA~ 1 R-36 PER""lIT IT #2, DOC Page 2 of 6 Printed: 7-Dec-01 1 ion to Permit to Dnll. Well 1 R-36 Saved: 7-Dec-01 (,-'1) list (,'7e na:nes or me ooer-ators of tnose ~~,t3l/s.. to {lie? c:xtent that tno_~;? .. ¡a..nes art? ,.'<ncw..n or OI5.:.ì.7¡,'eratJle ..n J]L.I;/IC rt?cords, .Joe! s/7.:;:¡.' t,'-¡at eaC17 namerJ c;œrator lias bec?n rl.1rnl5/v3ä d COp 1,,' ,,'( (oe dC'{,l,.caîIL'n Dr ct?'7..,rìc?d ¡nail. cr (B) statt? tflat the .=JJ]f-v..cant is tile only atlected 01 roer. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(e)(3) A,r: dPp:'lc3tlon for d Perm:! to Dnll must be acc....",npamr:::o' hy eCleh ù({l7è ,.'('//01'.'1..19 ..tèms, r::XCr3Dt fa,.. an item alrecJù}' on rile ¡','Ifh {¡'7e COnJl7II':>Slon ¿.¡neJläentdìed if} the dpDlicatlon: (3) a C/iagrarn and descnptlOn of thE' b/CI\Ðut preventIOn e,1U~Dl77ent (BOPE,J 3:: ,"eC¡ú!rE'd LJV ..?O AAC 25.035. 20 AAC 2S.0J[', or 2Lì AAC 25.lU7 as appllcable-- Please reference BOP schematics on file for Nabors 245E. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (e)(4) An dpp/¡c:atlo/J kJr.:1 PermIt to Of/llmu;:;t bi:! aa:ornpamed by 2aâl of the lÒI/rw'>lfI!-I ¡(2m.'>,. r:},<Ci?pt ré all l!r::rTl already on tilt' u'ltll If Ie L.c.lml1l/~'::.JO(] ami IdentJIìed If7 tile! application: (I) mlùlll/<Jtl(1n 0/7 dnl!lfIy hazards, /I1c/lIdlng (A) the maximum dOH-nhole plt.'55ure that mall be enCOlllìlt:'rt'.1. cfltef"lJ USc..Y) to dt.'ft.'I/TJIfI¡} It, and ma:<IlnUfil putentlal slIlface plC'55/Jrc..' baseL10/7 c1 n7(~rhane gladlent: Based on offset well data, the expected reservoir pressure in the C-l Kuparuk sand for lR-36 is -3000 psi at 6600' tvd, 0.45 psi/ft or 8.7 ppg EMW (equivalent mud weight). The C-l sand could have a maximum reservoir pressure of -3900 psi at 6618' tvd, 0.59 psi/ft or 11.4 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling lR-36 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the C-l Kuparuk sand target at 6618' tvd: MPSP =(6618 ft)*(0.59 - 0.11 psi/ft) = 3177 psi (B) Jdta C.l17 potcntl<Jll}dS zones; The well bore is not expected to penetrate any gas zones. and (C) (/d!,] OJ(7CcYflÚIQ pofentÙ11 causes" aí ho/(7 o((,'hlen7:i :;Vcil as abnCJrmal/v l)e()pre:::.~~urt'lI.';trd(a, lo-;;t orculation . 'ones, and /.Ollc!-:ï that IlëJL'::; d propt'íI....'l,v íor dlffer217tktl stlckmq,' Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (e)(5) An d{Jpllt~atlon fnr a Pc."ml! to Df/II must lJr:.' ac compal7led ¿w eddl (ì( till.? fclkJI1'lil[l r!r.'f77S. C'x::cpt (vr an ,rtem illready on fìlt~ !11th t/ìt' cnmml.,sïon and identified Ii7 th~ appltcatrnl7: (5) ..'1 de.';cn~J!i()f7 01 the proœdure for cOl7äucting formatlof) Ùlh?qnl,v test:.: as re(¡Uirei1 unä~r ./0 AAC l5.030(f),. Drill out surface and intermediate casing shoes and perform LOT test or FIT (maximum of 16 ppg EMW) in accordance with the Kuparuk LOT / FIT procedure, that Phillips Alaska has on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(e)(6) An .7P,i¡I~'(at!í.'n f:.ìr a Permit to Dn/I must be /]("(1 Jm,o,Jl7!f'J /.1)' 2,)(.11 00112 In//[1l vll7~7 ltc:>m,>:,. exo:!j)t for an Item alrr"a('~v on !lie ! uth 1/1<3 Lti({U,','¡j':-IOf7 ..mt./ IUr;;ntirìeu /II till;:' appäL""'iliol/: ,6,.1.} ( ,.;'fr,~[)ltdc: P/('post-:d (<,}:5lng dnâ cemen/In!} pl(lÿrdlïl d::i ft',ïuirö::cJ [IY /0 AAC /:1 (Ij'O. afld d (/r-;:.cllplio/J Ol,"¡ll)' slotted 1/IIc"(. cle- perfÓuh.'t/ //fICf, or :;r.Jt.Y..'/7 to be In,:;ollcd: . G NA- 1R-36 PERMIT IT #2. DOC Page 3 of 6 Printed: 7-Dec-01 ... . ~ R" 'Ion to Permit to Drill. Well 1 R-36 ~ Saved: 7-Dec-01 9.3 L-80 EUE 8rd 11,824' Mod An open-hole leak-off test will be performed on the 8 '12" open hole interval after reaching casing point. If the leak-off test indicates sufficient formation integrity, drilling will continue to total depth of the well. In this case, a selective single completion will be used. If 7" casing must be top-set above the Kuparuk sands in the lower Kalubik, a 3 '12" production liner will be used. Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weigh Length MOITVO MO/TVO 00 (in) (in) t (Iblft) Grade Connection (ft) (ft) (ft) 16 24 62.5 H-40 Welded 120' 41'/41' 161'/161' 9-5/8 12-1/4 40 L-80 BTC 7371' 41'/41' 7412'/4154' 7 8-1/2 26 L-80 BTC-Mod 11,974' 12,015'/6400' 41'/41' 3-1/2 6-1/8 9.3 L -80 825' 11,865'/6278' 12,690'/6982' SLHT 3-1/2 41'/41' 11,865'/6278' Cement Program 420 sx 15.8 ppg ASl Lead: 610 sx 10.7 ppg AS Lite Tail: 850 sx 12.0 ppg 'LiteCRETE'. (Yield=2.40 cuft/sk) Planned TOC=Surface 160 sx 15.8 ppg 'G' w/ add. Planned TOC=11,215' 200 sx 15.8 ppg 'G' w/ Gasblok Planned TOC=11'665 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An appl/¡~atlOl7 k:rrJ Pr'H Imt to 0111/ must ¿h.;' accom¡"\-7111('d bY' ('("]:.-/1 ,O7l tilr.? lclltJll'/IIq Itc;,m...-, c.'(ü:(}r (01 an Item a/ready en tìlc~ ¡lH11 {he commi.'iSI()lI anä IdentifIed IrJ fhc.~ application: (..~),.} ,1/~Ì9f::7m ann äl'5Cnpf¡(Jn of the d/l'2,"'FJ( 5)''itt:3fIJ c7." required tv./O AA{~ .?S. 0]5; un/I;''':;s th/ç li~'r¡UIrpl7.1t:'nt IS m.7/1Hi ¿w the ammllSSIOtl und2f ,)0 AAC ),I).03.'J(II)(2); Please reference diverter schematic on file for Nabors 245E. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An dppIIG:'¡{lon ¡är a PL'rmil to Dn/! rmlst be d....-ccmpafllcd by c:lCJ.:./J 0/ the fol/()I!"I"'~llti.'mS, cxcc:ut ¡¿'r al1ltcm d/rr..:.Yidv un lIIe H.ltl] t!1c.~ commission and Id,::nMir'd 111 tile appltcation: «~) a äflllinq flUId pm~}lan.~, mcludmq ù dlr](}rc:ml and dr,StTlptlon at the' dlllllng tlwd s'r'stem, as reL7ulf<".1 t'v ,,?O AAC 2.5.0]3: Drilling will be done using mud systems having the following properties: Spud to surface casing point Extended bentonite slurry Intermediate Hole Freshwater LSND Density (ppg) Funnel Viscosity(sec) Yield Point (cP) Plastic Viscosity (lb/100 sf) - 10 sec. Gel (lb/100 sf) - API Filtrate (cc) PH Solids (%) 8.5-9.4 60- 300* 25-50 20-40 15-40 4-15 8.5-9.5 3-8 8.5-10.4 35-55 8-25 5-25 3-10 5-15 9-9.5 3-10 CQIG/^'I. Drill out to TO Freshwater LSND 10.5 50-65 15-25 12-24 3-10 HTHP < 10 9-9.5 3-9 1R-36 PERMIT IT #2. DOC Page 4 of 6 Printed: 7-0ec-01 R: . -ion to Permit to Drill, Well 1 R-36 \ Saved: 7-Dec-01 *Spud mud should be adjusted to a FV between 200-300 sec/qt to drill gravel beds Diagram of Nabors 245E Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application fur a Permit (0 Dnl/ must be a:..-compamed ¿IY eacl,1 l':li th~ fDI!o~wng Items, except (Dr an Item a/read,V on .fiie ~ ~'It!i t/ie comml5-<::icn and ,den/l/'led //Ï rhe a{'p/I(~::Jti:Jn: (9) for an exp/orarcrv Llr ::;rra{igrdpiu,:: tesr I¡'~!/. èI rabul.-'ltlon Sl3ltlf7~¡ out the dep(lJ5 of pred.rcred aDnul/lla/l:v gec'.[}r;3SSL(ej -","{lara dS reQilIred by ,?O AAC .?5, 03J(t); N/ A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) ,4n application tOl a PC'mllt ro Dril! must be ,](-l-cmpanH...'d l)'/ L'<1ch of the fol!owm~7Item5, e.!(cept for dn ¡{(.¡m a/r('at1~ 0/7 rile 1I'Ith tIle; commlS510n and Id(~n{¡firyj JI7 rnC' JUplll~...Jtlon: (10) for an e.'>;p!mö/nry 01 stratlÇlfilphlC tt',~.t ,,'Ve//. a :>PI.';;m/(~ rr?lra(-{¡/ln or ri'l1ectm/1 allah'Sl::; 3,<; requirt?d I.if)() A4C .?t:;.Ofi!(c7): N/ A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An .1PfJ!/I:.~..,tlun fc.'r d Pt'rrr/lt to Dnll muS[ t'e accofllpanteJ by t'â{.h (It (tIe rLIII()P/m~.7 It~m!>~ e>,c2pt f()I dO itt''', dlr.::dtJ¡- '.}(! IiI... nl!/¡ ¡he COmr/7l551On and Idc=:ntJ/ìc:.'J Ù7 the appllcatloll.' (11) lor a n't'l/ dnllc.'d from, m otfS/70fe plattor m. Illí.."/J¡fe ÙJ{[om -roundc..'d ~lructurc.', }dek - up nD, or lIudtm~ I ällll/fl~l l'.:'sSCI. ,)í/ af/d/} 'SIS ol,.,eabed CDI70ItlOn.S.:7S refill/fed b~' 20 AAC2SJJ61(h,l: N/ A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) ,.1n applIcation /or a I-i?nmt to £1nll 11I/l5( I."e âcc(!mpr:7f11ed Ö,v eád7 {ì( ¡,'lie iÓ/I()¡¡'lilq ¡{em:>, P..kr:'J( for an Hem alr2clrJ,¡: 1711 tile> WI/II f/7e cur/lm(')"Sl()fI dnd Idt::nblÌc:d /f1 the! dl'Ph a{:()rJ: (.l2) c:!!/ldt'f7i:e !>17ol: /fl9 thdt tl12 r..:,~llJ1rem2nt:; of ./0 AA C ,',15 (US {8ûmjliïq}/Jav2 b¿:é;'/Î flIt:t; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An ap,UI¡CcltJon fur iJ Pällllt to Doll must ¿If} accotrlf.ul7lcY} by ...'<lel7 oltflc..' (0//011'1179 ItL'frIS, except r'or an ¡(t.'/l1 ,J/lL'ddV of/lile ¡1'lr!] liJe cmr¡mlSSltm rJnd IdC'ntliied In the appl.,cDtl0I7: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 245E. 2. Install diverter system. 3. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" 40#, L-80 STC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, perform stage or top job. Install and test SOPE to 5000 psi. Test casing to 2500 psi. 5. Drill out cement and 20' of new hole. Perform LOT/FIT, but do not exceed 16.0 ppg EMW. 6. Drill 8-1/2" hole to intermediate casing point according to directional plan. Run LWD logging equipment with GR and resistivity. Perform second LOT to evaluate long string option. (If LOT is adequate to long string, POOH and P/U neutron density tool, drill to well total depth, and run 7" 26# L -80 STCM casing to surface and cement. In this case, a selective single completion will be 1 R-36 PERMIT IT #2. DOC lA' r Page 50f 6 (J I~¡ I Cf t I V - Printed: 7-Dec-01 RI'" . 'ion to Permit to Dnll, Well 1 R-36 ~ Saved: 7-Dec-01 used. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C).) 7. Run and cement 7" 26#, L-80 BTC-Mod intermediate casing string. Pressure test casing to 3500 psi. Note: If significant hydrocarbon zones are present above the intermediate casing point, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 8. Drill out cement and 20' of new hole. Perform LOT/FIT, but do not exceed 16.0 ppg EMW. 9. Drill 6-1/8" hole to TD according to directional plan. Run LWD logging equipment with GR, resistivity, and density-neutron tools. 10. Run 3-1/2" 9.3#, L-80 SLHT liner on drill pipe with Baker liner top packer and hanger and cement liner. 11. Pressure test liner to 3500 psi. 12. Run 3-1/2" 9.3#, L-80 8rd EUE 8rd-Mod gas-lift completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3500 psi. 13. Set TWC and ND BOPE. Install and pressure test production tree. 14. Secure well. Rig down and move out. 15. Handover well to Operations Personnel. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) All dpp!lcdtlon fOf a Pc.'lflllt to Drill /TIustc be dr:.~~Ot1If..'alllc.;'d h' t}(Jch Df t/ie lòllolHnrj items,. r:.'xœpt lor JfI item alrL'J<!'l on till:.' ! I'¡{II tllt: comm6,<;hln and Iden(¡ficJ In tht.? application: (14) d qenerc71 dc'scnptlOn Of/lOU' tlic~ ¡'Jl1('latDf plal1~ to ri/S¡J(l5C Df" dnlfll79 mild ,1.110' CllrttilqS and a sta!¡-~mcnt of IvIJet/¡{lf the o/JNator mtend_,,- to reqIJr?5t aurllorvat'(J1) und::Y /0 AAC /5 OliO It)r an annUlar äl~ïJl'':or]/ iJ,(k~rc7li()n In the ~1'c?lI.,. Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 1R pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 1R pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 1R- 36 for annular pumping of fluids occurring as a result of future drilling operations on 1R pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. 0: G NA- lR-36 PERMIT IT #2. DOC Page 6 of 6 Printed: 7-Dec-01 Proposal Data for 1 R-36 WP04 Venical Origin: Well Horizontal Origin: Well Measurement Units: It North Reference: True North 31'2" 12689 811 MD '-,)1",1 [":'í)ll' , 1 :~L<"! t .:fl:.ìr'I,L,I:'~:.' 11lfrr..r,1 69824« rvD ;1::r,/ P'C,or.: :~'::L: (', . i:.;,~; I r'.1 ')~,:--1 II~I --'r End Dir. Start Sail @ 30.000" : 12162.37ftMD,6525.60ftTVD "'):"7' Dogleg severity : Degrees per 100 leet (US) Vertical Section Azimuth: 15.243" Vertical Section Description: Well , Vertical Section Origin: 0,00 N.O.OO E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate (I (10 Ol)((¡ 0 .~O5 0.1)(1 0.00 N 000 E 0 (XI ~,¡ó]O 0 oou 0 .~)5 ~tJtj l(J OOON 0.00 E 000 0 1100 7Q(. ~ù I \.I (H:~) 305 'XII) 79.~ 67 2-1 9ó N .~5.65 W 1-17) 2000 11)75 ellJ 31 tl(¡() .~5:;.iXIO 1t>ln:'. 305.7-1 N 119.97 \\ 263.-1:; 3.025 ~()) ~ -12 062:<.1 17 Ü40 1115,;'\5 'N] 68 N II. 24 W 95-180 -I (){~) I().~-t~ ~I 66 1~1 17 tHO :B3519 775'S 96 N 2062 56 E S(Ø;'~7 0.000 I] 1<)].37 300W 17.t).JO b525 60 lJOl9 26 N 2-15189 E '-)356,1-1 2000 1:11)1 J7 30.000 17040 bC:,12.20 (I\.) 77 Ob N 146b.55 E l)-I0621 0 000 116~9.~,-I <0 lIOO I 7 ü-UJ 6l)82 -10 l)1~ I -II N 25~9. J X E 9619 (O!-I U, lJ{J(J ( I '.. "l;,) "I, ! I ~,'. "1 .' I.lJJ.!.~'J 1\1.1')/,;'-,1"', \. .'J,',(, ~'.J. II -' '. 1(/ ill ~" " - \ -,' I \ 1 _'f. '.1 II I Begin Dlr @ 2.000'/10011 : 10348,31 It rV1D, 5335,1911 TVO - T l~~J r;ll[ '~"(' I,' . (.','1.. F':"l. 1,1-, :~"."- I I 0 2000 Scale. llnch = 2000h Relerer..:e ,s TrlJe t-Jortr, Eastlngs (Well) Kuparuk River Unit North Slope, Alaska Kuparuk 1 R 1 R-36 WP04 sper-'-''ý-5ull C"R i~. ~'friG:-' !;fç{8\/ (t; ,ï;¡f$ A Halliburton Company ..T 12~ RWE See,!? - 606 FSL.. 145 FWL 0- Begin OIl' @, 2,a'JO",lOOI! : 296,2011 MO, 296,2011 TVO " IncreasE: In O'l' Rate 19 3,025':100ft: 796,2011 MD, 793.67ft TVD 2000 - "\,Inc,e"" In Oi, Ra,e ,§ 4,000':10011: 1675.0011 MO, 1613.7811 NO /End Oir. Start Sail @ 66281' : 2618.42ftr..m,2225,85ftTVD End Dir, Start Sail @ 66,2810 . 2618,42fIMO.2225.85ItTVO, '~........ d -iCJ3t --.-.° ~ <1000- 'L - :; ==-:: ~ r--r 0 0 ~ 6000 - Increase In Olr Rate 'g' .f.OOO'/100it: 1675.001t MD, 1613.78ft TVD ------ Increase IÍI Dir Rate {G.' 3,025"100f!: 796,2011 rJ1o. 793,67tl TVO ---- -- Begin Dlr 12.' 2,OOO:'/1001t : 296.20ft rv10, 296,20ft TVO ---\, :Begin D¡r :'~ 2,OOO..100ft: 1034.8,.311t MO, 5335,1911 TVO .c. 'j .::; 7" 12015.3h MD ~.. ,'End Dir, Start Sail @', 30.000~ : 12162.37ftMD.6525.60ftTVD 6400.2« rvo ,," \~/~':.:~-i\:''''''':~:l: ~.~~:~::;~' ':','4r.'/ti~:':I~'~, ',~I,:';I~:;:;~_' ,-,t,,':,,'u'f;IÞ, ';II;",-,~.,-,'" I~f"., .~¡ ~~ 3 1/2" I I 12689.8h MD 8000 10000 6982.4 11 rvD Section Azimulh. 15.2<13' (True Nonh¡ :!i ICi u 'J) (" / ::~".1:' l., H..1" I ... '~.I.:', /,'/1,'/ ~I' ,". ...:-. / '1., .1,", J /- I 0 Scale: Ilnch = 200011 OnIlQu8.SI ? (XI 09 (¡({) 1 2000 I I 4000 6000 Vprtir.;:¡1 Spr.tinn (Wpll) 12015311MD 6400.211 rvD - 8000 - 6000 ã) ~ (/) Q) .~ ..c 1:: - 4 000 ~ - 2000 .%:: 0 0 0 C', J:: U S - 0 11: ;;¡ U ~..J Vi C) ::c - G""') - :2: ::t:> r-- MD (ft) , I' 296.20 796.20 1675.00 ""'''')1-' ,- 2618.42 ~) I~_.\"I_~,I -I:~ :-.. :..:.~ ~~ ~\ ~ ~ ~:,I:'~, .. ~~. ~..\ '. ~I -, :", 1 ~ ~ ::'0 ; ;,-:. ~., t 10348.31 i '; ...1. '~~ 1 .~~ ::'~ 1 i e.:-. ~:, >/'~ ~ 1 '.:.;:: ï ~ ,~~: ,> ¡ , -' í -I a~:' -1 .-".: , :-: ~"'I 12162.37 ",., --". .. 1 .: "'J- i -:.. :..' ,:~ '- 1 --~, ¡ \." ' ~ I '.~: '~:..~:'~~ l' = ~- Phillips Alaska, Inc. Inc (Deg) :.'.'.",'1 Azim. SSTVD TVD (Deg) (ft) (ft) ,'¡,')") .,~'_: ,21,-", C,'.-:) 0.00 0,00 212.00 296.20 10,00 304,70 709.47 793.67 32.00 354.70 1529.58 1613.78 ::,~~,I::~;.:I 3:)(','J:.~" ~\7;:,(_\'~~} 1G[:'~~i.~':1 66.28 16.74 2141.65 2225.85 ~J~;, ~>2 êìl::',~d :.-;t ,.~ ~~ ¡~~~: ~~r: I_!'..:;. ;~!~~ 66.28 J. -I, Ó 1 ,:,,:t> ',-\ , -+ l '.'1.'" -:2 ',' ... "I '~~ '. 't 1 --I", I -,I ;:~ 30.00 .:t i,;'.. . ~..., '::- -, '. I I ~ ": ,'.,,: ; "".0',111., '~',~.~', u:...: , ,":.1 1 ¿ ~~J ~>::: = ~r-,I::':I 2:1~11.~,=' NIS (ft) E/W (ft) y (ft) X (ft) DLS V.S. r¡10Oft) (ft) 1 R-36 (wp03) Comment .),,: ': ;~,<,<, E: ~!~~;-~t"~!'.::!,~:J:~ i: E,~.~«-1,e,:;:: :}':"~' ~: '~{i -:;1 IL l1~iJ F'~I:)E S",-: 17 0.00 N 0,00 E 5991809.93 N 539831,84 E 0.00 0,00 Begin Dir @ 2,000"/10011 : 296.2011 MD 24.77 N 35,78 W 5991834.70 N 539796.06 E 2.00 14.71 Increase in Dir Rate @ 3.025'/100ft : 796.2011 MD 305.10 N 121.59 W 5992115.03 N 539710.25 E 3.03 263.45 Increase in Dir Rate @ 4.000<'/10011 : 1675.00ft MD ,:~ !~' :):~ ~'. 992.61 N :<~~ ~:, 7() ~": ~:5,:'i ::,~?¡,;.~ C':" 23F13.2'.> 1 1=\ -;'-''t ':, i ~:7 ,(";'-,1 ',32 ,~~ -, . :~::-J :'~2 :~2 (I} :\¡ \:::,2:3.11 " ~;.::,7.1 ~~:j/I~. ~..~) 3~?.:~.2:~¡ /~i~/1.:.~) :,; ~¿; ~,._~ .:I")/'t.)'CI,~ -11 ~4,:,:,'1~) :J1~:':. ~~-I f'j '..'.,. r ' .:,' ::~,~I~.1¿ 1 ~::,.(~If~ ;'J ~: ::,~~'/ ~:'t:, c,;' ~ :.¡, .,';.: ;,,::) , ,,~: : :::~,s"~~eJ ~_J, 6~) :..j ~J~.:~~:\ -4 Ü2.ê.2 f"~ :~3':'~~'~31.~ I~I'! ¡'J ,~,,~~'~~é:7.~Ór:~!, ~-" !'1 ,:"~IJ"?"_,<I~J ,~..~ ~ :úr..' 2>:,8,,) E: ::'-j.I",~,',_.E. ~.1 E :L.~IJ~,;7 (.7 E 5-1~',~~~~:,g,c.:) E ~ .¡ 1,.~~'~"S,~, ('.)? E 16.53 W 5992802.54 N 539815,31 E 4.00 954.80 3~~,~,;:.. t~~. 2 ~~ 2 .:) :'~'~.' ~'~ :..! ':~ : C: ',:: 1 ~- :::::;7';: 1 <: ~~ ;~ .:; ~,~¡ ;-. :~,: l-. :~: :.: ':-! ~:I, ~','~ F ~2~~'=¡"':' ~'~: ~.~ ::: ¡,;',1 ':.':: ~ ...:"r~~:. ?,~ c~ ~: ~~ f_Î .-~ , ~,:~ t~:' f -: 1.~ ~~ -\ l' ::1 -t ~ ,.., '~: ~'- ..: " !.J .' ~, 1 ':.~ ;~::.:'2: ¡""~: ::~'î I, ,_I 01-~: ::;", ~I~ ~;17~~,::'<1 . "~~~~':~"-"~~~' ;".J ~'~:~.;.I -: ,~. r: ~' ~!)':_'. 9 ~ ~ ~I.':'I'!~~ .:: ,', ::. ~" '~. :.~\ . -.: ;' . 2;:;: '~/ E .~~,~ ~ .:' r:: 7,~S,2,~, E 1 ' 1(...1 ,=, E. <:'..'j;~,:-,::: c O,C<~ ~~ ',~,1 ~.~) 1 .~:; U.I.'I;~' ;~i, :_~O ~~:'~'JSi.G4 C' ~~~~I -l ~~ ~,'; ~-; t~,..! :'1 :"", ~<:,¡ 1 Ó~ 1 c:: 7,~ CO~'? .l.~ :.: ;j ~I 1 1 . ~: ,~ 16.74 5250.99 5335.19 7769.84 N 2021.20 E 5999579.77 N 541853.04 E 0.00 8028.27 ¡ ~~: ."¡ -4 ~'~~',-~ ~ J.>J ~,tlJ.~5. ¿:) I:.!'~,~ 1 '~~..:.1 ~~ r. J ~' ¿ ¡ C" ~~,~, t:. c',.' I=~!!~~ ~( =~ 7 ~'.j .: 421 ('a, .: I~I E ~ ~)~I ::~.~ 1 0. ;) " ,] ":,1 ~~~, ~ ~I 1 :~:: 7.1 I) ~i C i .r>:~1 j¿~~~.l:::. ~ :',1 1,~:' ?'-~ çj2:.¡-:,i=::~" G J .~;Iw....:.., .j I:' ',- ~ f_-I:~ ~~ :-¡ ,'~ 1 ,~'.'~ (I'~,~.? 1 ; I, ::', i r ':':1., ~_I I"f~' ¡:,...j':, i'i,:;:" 16.74 6441.40 6525.60 9042.19 N 2403,ì6 E 6000852.12 N 542235.60 E 2.00 9356.24 .:..:~ :.~ :,-~\~.:~I,,~' I}~: r;~=;-I~: ::"'1 \F.,=:'..:' ~:'f' ~, ?:"~', 1~~, f ~,,:'~.'.., II,:' iY'- t,: :.. ~-:'¡I;.::.' 1..1- F.: '.' ~.'_'i ~J~-.'r., ':-,-' Ii. ..,-+1~.: ~)~ .: i_~:, ~ 1 ¡.~'i:, '~.I ~ i~: "w.', \.~ 7' ï ,,~; , '2 '-~,' r,:!,c."~I} :~,~: '~'EI,:<:~: r'J ¡', ,¡ '.>~ ""~,:,':"',' ~J ~., ".:.:; :~:.J i :-~. ~'.¿ 13';- :!'_;,I~ ~~: dié.':1 ~FI r.l 82;~::=: ,..1.¡ :', ,'3:}.~:'.~.9.~ f'. ':';~~~:.~:' (,l} r.~ :.~ 1.-,1 i ~.' .:~;; r. J ~):_\,,~~. .:'I....~- '~)'l ~~! ~~:, " ::: I~, ~>=I'~: -:- ~~; .~,~? ¡ '. .:/~' ',~'~'!,:' '7~I, ,:'-~ ~ ,,I ;~:~'-~\~'.:.~ :R, ['i ;: ¡'~:'~, :.) ;"")~, t~ I,' : J ~. :,:,r-J< ~:.~ ~.,I :..''-; ¡ ,I ,- '.'{,I ~+'J":l ,,:,.', ,:w ':' ~t~,'.: ~...1 -:1 ,': ;"( r-'I,R,I.'IP'".':.I . ¡;.. ,,: ~ ... - ... ~ "',, - I '.,:: ',:,.~, ~j '.:~ '.::,.: I.> r J :-}.:'~ ~~ ,S-: t.: t::.:',~" ')2,~ ~" L ~> I ~ ~I_:' ~ '~I.~.: E: ~ --I .~'. :~~. .1 ~'. !,-'I f:: :: '1;~~~-:-:~'-' ~'::' ~ .~ ""'r~: :'~ :'.2 ~-~ '.: L ~: -~ ~ -~' .,::'':; ~~ ':, ::.: ~,<::<;:'7 ','~,~ ;;: ~~;:'~. '.: 1 ;,;:.11:; ~~.~¿! ~'~ _: .L~ ~ .:,2, ,I~ j E .:.C':1'r.:..: ,:;,~ :J ::.;~.::,i1.:',\ ::. ~ ::.. -~ :-:1, , ',', r:: ~ ..'.' , I Cll i' 7,:", ~, .-},.I .: t:.: (..: +... ,~~ ':.: .' ,{:..,~~< . '., " '~: .:': ,.~ E:,. .-: ~., I " -'...' . .,-< :}--~ i:":~ ~ :-; :,} :: ' ~ :~.. -~ :J ::' ,- '.'.' } '~, 1 :), ":: ~;. ., '-I .,¡:-:~ ~ .~. e..: Eé1~,':: h:'ln',:Îlr0"t Start Sail @ 66.281 <> : 2618.4211MD Tc,p U'.(ld G,:1~>' 1.'IjlUI 'r :',' ¡ :" \:',,' S' <"! S r1 k 6.,-j~.:, V/':::,1 ~'dk ~~'I ~ .~-' I~ :'J ~.-" I r, q Begin Dir @ 2.000'/100ft : 1 0348.31 tt MD C 7(; Tq:: I-WZ l':),~:¡:' t IF,¿ I,; l-:'o¡l¡lt'"f, 1<',1 'L - '::"'" r~-I'I.i.'I~. ,'-, ,"I': II I'J T( ¡', 1:',.1' I"l" Start Sail @.' 30.000':' : 12162,37f1MD i \,~';~' (: 1 l- :~,' ~V~! !"'I";I,',t (1 :':,r":II',''':'.'.'' II,' .:; 1 =' Lil h;[ .~:: T ~) [; r ¡' /L , r ' 1-' ":" " T 'I¡.. :.: E":J:~,' f'.-ur-'°¡ll. ¡.. -r..ADIDsp!h 12úf/j,e.¡I!.t.'1D Kuparuk River Unit North Slope, Alaska Kuparuk 1 R, Slot 1 R-36 1 R-36 WP04 Revised: 7 December, 2001 PROPOSAL REPORT 7 December, 2001 <J ::x:J ---- C":) ---- <: ::t::=.. r-- Surface Coordinates: 5991809.93 N, 539831.84 E (70023'18.8439" N, 149" 40'33.6289" W) Surface Coordinates relative to Project H Reference: 991809.93 N, 39831.84 E (Grid) Surface Coordinates relative to Structure: 759.82 N, 6.13 E (True) Kelly Bushing: 84.20ft above Mean Sea Level sper'~Y-5UI! çÜ:'!IÇ~)'_~. Çi-~-j:(~(~r5.!It:;:~~Ü~ A Hallibunon Company Proposal Ref: pro9725 Sperry-Sun Drilling Services Proposal Report for 1 R-36 WP04 Revised: 7 December. 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -84.20 0.00 0.00 N 0.00 E 5991809.93 N 539831.84 E 0.00 T12N R10E Sec.17 - 606 FSL. 145 FWL 100.00 0.000 0.000 15.80 100.00 0.00 N 0.00 E 5991809.93 N 539831 .84 E 0.000 0.00 200.00 0.000 0.000 115.80 200.00 0.00 N 0.00 E 5991809.93 N 539831 .84 E 0.000 0.00 296.20 0.000 0.000 212.00 296.20 0.00 N 0.00 E 5991809.93 N 539831.84 E 0.000 0.00 Begin Dir @ 2.000'/10011: 296.2.o.t! MD, 296.20ft TVD 300.00 0.076 305.000 215.80 300.00 0.00 N 0.00 E 5991809.93 N 539831.84 E 2.000 0,00 400.00 2.076 305.000 315.78 399.98 1.08 N 1.54 W 5991811.00 N 539830.29 E 2.000 0.64 500.00 4.076 305.000 415.63 499.83 4.16 N 5.94W 5991814.05 N 539825.88 E 2.000 2.45 600.00 6.076 305.000 515.23 599.43 9.23 N 13.18 W 5991819.09 N 539818.61 E 2.000 5.44 700.00 8.076 305.000 614.46 698.66 16.30 N 23.27 W 5991826.10 N 539808.48 E 2.000 9.60 796.20 10.000 305.000 709.47 793.67 24.96 N 35.65 W 5991834.70 N 539796.06 E 2.000 14.71 Increase In Dir Rate @ 3.025"/100ft . 796.20ft MD, 793.67ft TVD 800.00 10.049 305.598 713.21 797.41 25.35 N 36.19 W 5991835.08 N 539795.51 E 3.025 14.94 900.00 11 .670 319.220 811.43 895.63 38.09 N 49.89 W 5991847.75 N 539781.74 E 3.025 23.63 1000.00 13.767 329.165 908.98 993.18 55.96 N 62.60 W 5991865.56 N 539768.94 E 3.025 37.54 1100.00 16.156 336.376 1005.59 1089.79 78.93 N 74.28 W 5991888.47 N 539757.14 E 3.025 56.63 1200.00 18.725 341 .716 1100.99 1185.19 106.93 N 84.89 W 5991916.40 N 539746.38 E 3.025 80.85 1300.00 21 .410 345.783 1194.92 1 279. 12 139.87 N 94.4 1 W 5991949.29 N 539736.68 E 3.025 110.13 1400.00 24.172 348.971 1287.11 1371 .31 177.67 N 102.81 W 5991987.05 N 539728.08 E 3.025 144.39 1500.00 26.987 351.535 1377.30 1461.50 220.22 N 110.07 W 5992029.56 N 539720.60 E 3.025 183.53 1600.00 29.841 353.645 1465.24 1549.44 267.40 N 116.17W 5992076.70 N 539714.25 E 3.025 227.45 1675.00 32.000 355.000 1529.58 1613.78 305.74 N 119.97 W 5992115.03 N 539710.25 E 3.025 263.45 Increase in Dlr Rate @ 4 000 "/1 004-' . 1675.00ft MD, 1613.781\ TVD C) 1700.00 32.832 356.035 1550.69 1634.89 319.10 N 121.01 W 5992128.38 N 539709.13 E 4.000 276.06 1730.30 33.851 357.229 1576.00 1660.20 335.73 N 121.99W 5992145.00 N 539708.07 E 4.000 291.84 Base Permalrost :::0 1800.00 36.235 359.748 1633.06 1717.26 375.72 N 123.02 W 5992184.99 N 539706.82 E 4.000 330.16 --- 1900.00 39.736 2.895 1711.88 1796.08 437.22 N 121.53 W 5992246.50 N 539707.98 E 4.000 389.89 ~ 2000.00 43.310 5.608 1786.74 1870.94 503.31 N 116,56 W 5992312.61 N 539712.60 E 4.000 454.95 ---- :c:: ~ r-- 7 December, 2001 - 12:40 Page 2 of 9 Dri/lOuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 1 R-36 WP04 Revised: 7 December. 2001 North Slope. Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 2100.00 46.939 7.981 1857.29 1 941 .49 573.65 \J 108.14 W 5992382.99 N 539720.65 E 4.000 525.03 2200.00 50.613 10.087 1923.18 2007.38 647.90 N 96.29 W 5992457.31 N 539732.10 E 4.000 599.79 2300.00 54.321 11.981 1984.10 2068.30 725.71 N 81.09 W 5992535.20 N 539746.89 E 4.000 678.86 2400.00 58.055 13.706 2039.74 2123.94 806.69 N 62.60 W 5992616.28 N 539764.95 E 4.000 761.85 2500.00 61.811 15.295 2089.83 2174.03 890.45 N 40.91 W 5992700.15 N 539786.19 E 4.000 848.37 2600.00 65.584 16.777 2134.14 2218.34 976.59 N 16.13 W 5992786.42 N 539810.51 E 4.000 937.99 2618.42 66.281 17.040 2141.65 2225.85 992.68 \J 11.24 W 5992802.54 N 539815.31 E 4.000 954.80 End Dir. Start Sail @ 66.281" . 2618.42f1MD.2225.85fITVD 2700.00 66.281 17.040 2174.46 2258.66 1064.09 N 10.65 E 5992874.06 N 539836.82 E 0.000 1029.45 2800.00 66.281 17.040 2214.69 2298.89 1151.62N 37.47 E 5992961.74 N 539863.18 E 0.000 1120.96 2900.00 66.281 17.040 2254.91 2339.11 1239.16 N 64.30 E 5993049.41 N 539889.54 E 0.000 1212.47 3000.00 66.281 17.040 2295.14 2379.34 1326.69 N 91.13 E 5993137.09 I'J 539915.90 E 0.000 1303.98 3100.00 66.281 17.040 2335.36 2419.56 1414.23 N 117.96 E 5993224.76 N 539942.26 E 0.000 1395.49 3200.00 66.281 17.040 2375.59 2459.79 1501.76 N 144.79 E 5993312.44 N 539968.63 E 0.000 1486.99 3300.00 66.281 17.040 2415.81 2500.01 1589.29 N 171.62 E 5993400.12 \J 539994.99 E 0.000 1578.50 3400.00 66.281 17.040 2456.04 2540.24 1676.83 N 198.44 E 5993487.79 N 540021.35 E 0.000 1670.01 3500.00 66.281 17.040 2496.26 2580.46 1764.36 N 225.27 E 5993575.47 N 540047.71 E 0.000 1761.52 3600.00 66.281 17.040 2536.49 2620.69 1851.90 N 252.10 E 5993663.14 N 540074.07 E 0.000 1853.03 3700.00 66.281 17.040 2576.71 2660.91 1939.43 N 278.93 E 5993750.82 N 540100.43 E 0.000 1944.53 3800.00 66.281 17.040 2616.94 2701.14 2026.96 N 305.76 E 5993838.49 N 540126.80 E 0.000 2036.04 3800.15 66.281 17.040 2617.00 2701.20 2027.10 N 305.80 E 5993838.63 \J 540126.84 E 0.000 2036.18 Top Ugnu 3900.00 66.281 17.040 2657.16 2741.36 2114.50 N 332.59 E 5993926.17 N 540153.16E 0,000 2127.55 4000.00 66.281 17.040 2697.39 2781.59 2202.03 N 359.41 E 5994013.84 N 540179.52 E 0.000 2219.06 4100.00 66.281 17.040 2737.61 2821.81 2289.57 N 386.24 E 5994101.52 N 540205.88 E 0.000 2310.57 4200.00 66.281 17.040 2777 .84 2862.04 2377.10 N 413.07 E 5994189.20 N 540232.24 E 0.000 2402.07 <:::> 4300.00 66.281 17.040 2818.06 2902.26 2464.63 N 439.90 E 5994276.87 N 540258.60 E 0.000 2493.58 ::J:¡ 4400.00 66.281 17.040 2858.29 2942.49 2552.17 N 466.73 E 5994364.55 N 540284.97 E 0.000 2585.09 ~ 4500.00 66.281 17.040 2898.51 2982.71 2639.70 N 493.56 E 5994452.22 N 540311.33 E 0.000 2676.60 ~ 4600.00 66.281 17.040 2938.74 3022.94 2727.24 N 520.38 E 5994539.90 N 540337.69 E 0.000 2768.11 4700.00 66.281 17.040 2978.96 3063.16 2814.77 N 547.21 E 5994627.57 N 540364.05 E 0.000 2859.61 ---- 4800.00 66.281 17.040 3019.19 3103.39 2902.30 N 574.04 E 5994715.25 N 540390.41 E 0.000 2951.12 ~ ~ r--- 7 December. 2001 - 12:40 Page 30f9 Dr;//Quest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 1 R-36 WP04 Revised: 7 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 4900.00 66.281 17.040 3059.41 3143.61 2989.84 N 600.87 E 5994802.93 N 540416.77 E 0.000 3042.63 5000.00 66.281 17.040 3099.64 3183.84 3077.37 N 627.70 E 5994890.60 N 540443.14 E 0.000 3134.14 5100.00 66.281 17.040 3139.86 3224.06 3164.91 N 654.53 E 5994978.28 N 540469.50 E 0.000 3225.65 5200.00 66.281 17.040 3180.09 3264.29 3252.44 N 681.35 E 5995065.95 N 540495.86 E 0.000 331 7.1 5 5242.05 66.281 17.040 3197.00 3281.20 3289.24 N 692.63 E 5995102.82 N 540506.94 E 0.000 3355.63 Base Ugnu 5300.00 66.281 17.040 3220.31 3304.51 3339.97 N 708.18 E 5995153.63 N 540522.22 E 0.000 3408.66 5400.00 66.281 17.040 3260.54 3344.74 3427.51 N 735.01 E 5995241 .30 N 540548.58 E 0.000 3500.17 5500.00 66.281 17.040 3300.76 3384.96 3515.04 N 761.84 E 5995328.98 N 540574.94 E 0.000 3591.68 5508.05 66.281 17.040 3304.00 3388.20 3522.09 N 764.00 E 5995336.04 N 540577.07 E 0.000 3599.04 Top West Sak 5600.00 66.281 17.040 3340.99 3425.19 3602.57 N 788.67 E 5995416.65 N 540601.31 E 0000 3683,19 5700.00 66.281 17.040 3381.21 3465.41 3690.11 N 815.50 E 5995504.33 N 540627.67 E 0.000 3774.69 5800.00 66.281 17.040 3421.44 3505.64 3777.64 N 842.32 E 5995592.01 N 540654.03 E 0.000 3866.20 5900.00 66.281 17 .0~0 3461 .66 3545.86 3865.18 N 869.15 E 5995679.68 N 540680.39 E 0.000 3957.71 6000.00 66.281 17.040 3501.89 3586.09 3952.71 N 895.98 E 5995767.36 N 540706.75 E 0.000 4049.22 6100.00 66.281 17.040 3542.11 3626.31 4040.24 N 922.81 E 5995855.03 N 540733.11 E 0.000 4140,73 6200.00 66.281 17.040 3582.34 3666.54 4127.78 N 949.64 E 5995942.71 N 540759.48 E 0.000 4232.23 6300.00 66.281 17.040 3622.56 3706.76 4215.31 N 976.47 E 5996030.38 N 540785.84 E 0.000 4323.74 6400.00 66.281 17.040 3662.79 3746.99 4302.85 N 1003.29 E 5996118.06 N 540812.20 E 0.000 4415.25 6500.00 66.281 17.040 3703.01 3787.21 4390.38 N 1030.12 E 5996205.74 N 540838.56 E 0.000 4506.76 6600.00 66.281 17.040 3743.24 3827.44 4477.91 N 1056.95 E 5996293.41 N 540864.92 E 0.000 4598.27 6700.00 66.281 17.040 3783.46 3867.66 4565.45 N 1083.78 E 5996381.09 N 540891 .28 E 0.000 4689.77 6800.00 66.281 17.040 3823.69 3907.89 4652.98 N 1110.61 E 5996468.76 N 540917.65 E 0.000 4781.28 6900.00 66.281 17.040 3863.91 3948.11 4740.52 N 11 37.44 E 5996556.44 N 540944.01 E 0.000 4872.79 6915.14 66.281 17.040 3870.00 3954.20 4753.77 N 1141 .50 E 5996569.71 N 540948.00 E 0.000 4886.64 Base West Sak 7000.00 66.281 17.040 3904.14 3988.34 4828.05 N 1164.26 E 5996644.11 N 540970.37 E 0.000 4964.30 7100.00 66.281 17.040 3944.36 4028.56 4915.58 N 1191.09 E 5996731.79 N 540996.73 E 0.000 5055.81 C noo.oo 66.281 17.040 3984.59 4068.79 5003.12 N 1217.92 E 5996819.47 N 541023.09 E 0.000 5147.31 -"'--, 7300.00 66.281 17.040 4024.81 4109.01 5090.65 N 1244.75 E 5996907.14 N 541049.45 E 0.000 5238.82 ...,:: 7400,00 66.281 17.040 4065.04 4149.24 5178.19N 1271.58 E 5996994.82 N 541075.82 E 0.000 5330,33 -.~~ 7412.34 66.281 17.040 4070.00 4154.20 5188.99N 1274.89 E 5997005.64 N 541079.07 E 0.000 5341.62 9 5/8" Casing ~-, -...-"'- ~.. ~ :r:-~ r--- DrillQuest 2.00.09.006 7 December, 2001 - 12:40 Page 4 019 Sperry-Sun Drilling Services Proposal Report for 1 R-36 WP04 Revised: 7 December, 2001 North Slope. Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/100ft) 7500.00 66.281 1 7 .040 4105.26 4189.46 5265.72 N 1298.41 E 5997082.49 N 54 11 02.1 8 E 0.000 5421 .84 7600.00 66.281 17.040 4145.49 4229.69 5353.25 N 1325.23 E 5997170.17 N 541128.54 E 0.000 5513.35 7700.00 66.281 17.040 4185.71 4269.91 5440.79 N 1352.06 E 5997257.84 N 541154.90 E 0.000 5604.85 7800.00 66.281 17.040 4225.94 431 O. 1 4 5528.32 N 1378.89 E 5997345.52 N 5411 81.26 E 0.000 5696.36 7900.00 66.281 17.040 4266.16 4350.36 5615.86 N 1405.72 E 5997433.19 N 541207.62 E 0.000 5787.87 8000.00 66.281 17.040 4306.39 4390.59 5703.39 N 1432.55 E 5997520.87 N 541233.99 E 0.000 5879.38 8100.00 66.281 17.040 4346.61 4430.81 5790.92 N 1459.37 E 5997608.55 N 541260.35 E 0.000 5970.89 8200.00 66.281 17.040 4386.84 4471.04 5878.46 N 1486.20 E 5997696.22 N 541286.71 E 0.000 6062.39 8300.00 66.281 17.040 4427.06 4511.26 5965.99 N 1513.03E 5997783.90 N 541313.07 E 0.000 6153.90 8400.00 66.281 17.040 4467.28 4551 .48 6053.53 N 1539.86 E 5997871 .57 N 541339.43 E 0.000 6245.41 8500.00 66.281 17.040 4507.51 4591.71 6141.06N 1566.69 E 5997959.25 N 541365.79 E 0.000 6336.92 8600.00 66.281 17.040 4547.73 4631.93 6228.59 N 1593.52 E 5998046.92 N 541392.16 E 0.000 6428.43 8700.00 66.281 17.040 4587.96 4672.16 6316.13 N 1620.34 E 5998134.60 N 541418.52 E 0,000 6519.93 8800.00 66.281 17.040 4628.18 4712.38 6403.66 N 1647.17 E 5998222.28 N 541444.88 E 0.000 6611.44 8900.00 66.281 17.040 4668.41 4752.61 6491.20 N 1674.00 E 5998309.95 N 541471.24 E 0.000 6702.95 9000.00 66.281 17.040 4708.63 4792.83 6578.73 N 1700.83 E 5998397.63 N 541497.60 E 0.000 6794.46 9100.00 66.281 17.040 4748.86 4833.06 6666.26 N 1727.66 E 5998485.30 N 541523.96 E 0.000 6885.97 9200.00 66.281 17.040 4789.08 4873.28 6753.80 N 1754.49 E 5998572.98 N 541550.33 E 0.000 6977.47 9300.00 66.281 17.040 4829.31 4913.51 6841 .33 N 1781.31 E 5998660.65 N 541576.69 E 0.000 7068.98 9400.00 66.281 17.040 4869.53 4953.73 6928.87 N 1808.14 E 5998748.33 N 541603.05 E 0.000 7160.49 9500.00 66.281 17.040 4909.76 4993.96 7016.40 N 1834.97 E 5998836.00 N 541629.41 E 0.000 7252.00 9600.00 66.281 17.040 4949.98 5034.18 7103.93 N 1861.80 E 5998923.68 N 541655.77 E 0.000 7343.51 9700.00 66.281 17.040 4990.21 5074.41 7191.47 N 1888.63 E 5999011.36 N 541682.1 3 E 0,000 7435.01 9800.00 66.281 17.040 5030.43 5114.63 7279.00 N 1915.46 E 5999099.03 N 541708.50 E 0.000 7526.52 9900.00 66.281 17.040 5070.66 5154.86 7366.54 N 1942.28 E 5999186.71 N 541734.86 E 0.000 7618.03 10000.00 66.281 17.040 5110.88 5195.08 7454.07 N 1969.11 E 5999274.38 N 541761.22 E 0.000 7709.54 a 10100.00 66.281 17.040 5151.11 5235.31 7541.60 N 1995.94 E 5999362.06 N 541787.58 E 0.000 7801 .05 ::0 10200.00 66.281 17.040 5191.33 5275.53 7629.14 N 2022.77 E 5999449.73 N 541813.94 E 0.000 7892.55 10300.00 66.281 17.040 5231 .56 5315.76 7716.67 N 2049.60 E 5999537.41 N 541840.30 E 0.000 7984 06 ---- 10348.31 66.281 17.040 5250.99 5335.19 7758.96 N 2062.56 E 5999579.77 N 541853.04 E 0.000 8028.27 Begin Dlr @ 2.000':/100tt : 10348,31t (;":) MD, 5335.19ft TVD ---- ~ ......... DrillOuest 2.00.09.006 7 December, 2001 - 12:40 Page 5 of 9 Sperry-Sun Drilling Services Proposal Report for 1R-36 WP04 Re vised: 7 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 100.100.00 65.247 17.040 5272.21 5356.41 7804.02 N 2076.37 E 5999624.90 N 541866.61 E 2.000 8075.38 10500.00 63.247 17.040 5315.66 5399.86 7890.13 N 2102.76 E 5999711.1 5 N 541892.54 E 2.000 8165.40 10600.00 61.247 17.040 5362.22 5446.42 7974.74 N 2128.69 E 5999795.90 N 541918.02E 2.000 8253.85 10700.00 59.247 17.040 5411.84 5496.04 8057.74 N 21 54.1 3 E 5999879.03 N 541943.02 E 2.000 8340.62 10800.00 57.247 17.040 5464.46 5548.66 8139.04 N 2179.05 E 5999960.46 N 541967.50 E 2.000 8425.60 10900.00 55.247 17.040 5520.02 5604.22 8218.53 N 2203.41 E 6000040.08 N 541991.44 E 2.000 8508.70 11000.00 53.247 17.040 5578.45 5662.65 8296.12 N 2227.19 E 6000117.79 N 542014.81 E 2.000 8589.81 11100.00 51.247 17.040 5639.67 5723.87 8371.71 N 2250.36 E 6000193.51 N 542037.58 E 2.000 8668.84 11200.00 49.247 17.040 5703.62 5787.82 8445.21 N 2272.89 E 6000267.13 N 542059.71 E 2.000 8745.68 11300.00 47.247 17.040 5770,20 5854.40 8516.54 N 2294.75 E 6000338.57 N 542081.19 E 2.000 8820.24 11400.00 45.247 17.040 5839.35 5923.55 8585.59 N 2315.91 E 6000407.74 N 542101.99 E 2.000 8892.43 11431.99 44.608 17.040 5862,00 5946.20 8607.19 N 2322.53 E 6000429.37 N 542108.49 E 2.000 8915.01 C 70 11500.00 43.247 17.040 5910.98 5995.18 8652.30 N 2336.36 E 6000474.56 N 542122.08 E 2.000 8962. 17 11600.00 41.247 1 7.040 5985.01 6069.21 8716.58 N 2356.06 E 6000538.94 N 542141.44 E 2.000 9029.37 11655,39 40.140 17.040 6027.00 6111.20 8751.11 N 2366.64 E 6000573.52 N 542151.84 E 2.000 9065.46 Top HRZ 11700.00 39.247 17.040 6061.33 6145.53 8778.35 N 2374.99 E 6000600.81 N 542160.04 E 2.000 9093.94 11800.00 37.247 17.040 6139.86 6224.06 8837.54 N 2393.13 E 6000660.09 N 542177.86 E 2.000 9155.81 11826.47 36.718 17.040 6161.00 6245.20 8852.76 N 2397.80 E 6000675.34 N 542182.45 E 2.000 9171.73 Base HRZlTop Kalubik 11900.00 35.247 17.040 6220.50 6304.70 8894.07 N 2410.46 E 6000716.71 N 542194.89 E 2.000 9214.91 11 955.34 34 .14 1 17.040 6266.00 6350.20 8924.18 N 2419.69 E 6000746.87 N 542203.96 E 2.000 9246.39 K 1/Lower Kalublk 12000.00 33.247 17.040 6303.16 6387.36 8947.87 N 2426.95 E 6000770.60 N 542211.09 E 2.000 9271.15 12015.34 32.941 17.040 6316.01 6400.21 8955.88 N 2429.40 E 6000778.62 N 542213.50 E 2.000 9279.53 ì" Casing 12100.00 31 .247 17.040 6387.73 6471,93 8998.88 N 2442.58 E 6000821 .69 N 542226.46 E 2.000 9324.48 12108.50 31 .077 17.040 6395.00 6479.20 9003.08 N 2443.87 E 6000825.90 N 542227.72 E 2.000 9328.88 Top Kuparuk 12162.37 30.000 17.040 6441.40 6525.60 9029.26 N 2451.89 E 6000852.1 2 N 542235.60 E 2.000 9356.24 End Dlr. Start Sail @ 30.000' . C 12162,37ttMD,652560ftTVD ::0 12200.00 30.000 17.040 6473.99 6558.19 9047.25 N 2457.41 E 6000870.14 N 542241 .02 E 0,000 9375.04 ---- 12262.37 30.000 17.040 6528.00 6612.20 9077.06 N 2466.55 E 6000900.00 N 542250.00 E 0.000 9406.21 Top C 1 Target C""-) Target - C 1 Sand RevIsion 2 12282,00 30.000 17.0"¡0 6545.00 6629.20 9086.44 N 2469.42 E 6000909.40 N 542252.83 E 0.000 9416.02 Top B .......... 12300.00 30.000 17.040 6560.59 6644.79 9095.05 N 2472.06 E 6000918.02 N 542255.42 E 0.000 9425.02 ~ 12376.68 30.000 17.040 6627.00 6711.20 9131.71 N 2483.30 E 6000954.74 N 542266.46 E 0.000 9463.34 Top A4 ......... 7 December. 2001 - 12:40 Page 60f9 DrillOuest 2.00.09.006 c. -..-, -i-- ..... . c- ~ -..... c:;;.. ::l:- r--- Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 12385.92 30.000 17.040 6635.00 6719.20 12400.00 30.000 17.040 6647.19 6731.39 12436.73 30.000 17.040 6679.00 6763.20 12489.84 30.000 17.040 6725.00 6809.20 12500.00 30.000 17.040 6733.80 6818.00 12600.00 30.000 17040 6820.40 6904.60 12689.84 30.000 1 7.040 6898.20 6982.40 Sperry-Sun Drilling Services Proposal Report for tR-36 WP04 Revised: 7 December, 2001 North Slope, Alaska Kuparuk 1 R Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (°/1 OOft) 9136.12 N 2484.65 E 6000959.16 N 542267.79 E 0.000 9467.96 Top A3 9142.86 N 2486.71 E 6000965.90 N 542269.82 E 0.000 9474.99 9160.41 N 2492.09 E 6000983.49 N 542275.10 E 0.000 9493.35 Top A2 9185.81 N 2499.88 E 6001008.92 N 542282.75 E 0.000 9519.89 Base Kuparuk 9190.66 N 2501.36 E 6001 013.ï8 N 542284.21 E 0.000 9524.97 9238.47 N 2516.02 E 6001061.67 N 542298.61 E 0.000 9574.95 9281.41 N 2529.18 E 6001104.68 N 542311.54 E 0.000 9619.84 Total Depth' 12689.84ftMD,698240ftTVD 3 1/2" Liner All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are lelative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 15.243') (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12689.84ft.. The Bottom Hole Displacement is 9619.84ft., in the Direction of 15.243' (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 296.20 796.20 1675.00 2618.42 0.00 N 0.00 N 24.96 N 305.74 N 992.68 N 0.00 296.20 793.67 1613.78 2225.85 10348.31 12162.37 12689.84 7758.96 N 9029.26 N 9281 .4 1 N 2062.56 E 2451.89 E 2529.18 E 5335.19 6525.60 6982.40 7 December. 200 t - 12:40 0.00 E 0.00 E 35.65 W 119.97 W 11 .24 W Comment T12N RlOE Sec.17 - 606 FSL, 145 FWL Begin Dir @ 2.000'/100f1: 296.20ft MD. 296.20ft TVD Increase in Dir Rate @ 3.025</100ft : 796.20ft MD. 793.67ft TVD Increase in Dir Rate @ 4.000"/100ft: 1675.00ft MD, 1613.78f1 TVD End Dir, Start Sail @ 66.281';' : 2618.42ftMD.2225.85ftTVD Begin Dir @ 2.000C'/1QOtt : 10348.31 It MD, 5335.19ft TVD End Dir. Start Sail @ 30.000" : 12162.37ftMD,6525.60ftTVD Total Depth: 12689.84tIMD,6982.4OttTVD Page 7019 DrillOuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 1 R-36 WP04 Revised: 7 December. 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Formation Tops Formati on Plane Profile Penetration Poi n t (Below Well Origin) Measured Vertical Sub-Sea Sub-Sea Dip Dip Dir. Depth Depth Depth Northings Eastings Formation Name (ft) Deg. Deg. (ft) (ft) (ft) (ft) (ft) 1 576.00 0.000 0.305 1730.30 1660.20 1576.00 335.73 N 121.99 W Base Permafrost 2617.00 0.000 0.305 3800.15 2701.20 2617.00 2027.10 N 305.80 E Top Ugnu 3197.00 0.000 0.305 5242.05 3281 .20 3197.00 3289.24 N 692.63 E Base Ugnu 3304.00 0.000 0.305 5508.05 3388.20 3304.00 3522.09 N 764.00 E Top West Sak 3870.00 0.000 0.305 6915.14 3954.20 3870.00 4753.77 N 1141.50 E Base West Sak 5862.00 0.000 0.305 11431.99 5946.20 5862.00 8607.19 N 2322.53 E C 70 6027.00 0.000 0.305 11655.39 6111.20 6027.00 8751.11 N 2366.64 E Top HRl 6161.00 0.000 0.305 11826.47 6245.20 6161.00 8852.76 N 2397.80 E Base HRlrrop Kalubik 6266.00 0.000 0.305 11955.34 6350.20 6266.00 8924.18 N 2419.69 E K 1/Lower Kalubik 6395.00 0.000 0.305 12108.50 6479.20 6395.00 9003.08 N 2443.87 E Top Kuparuk 6528.00 0.000 0.305 12262.37 6612.20 6528.00 9077 .06 N 2466.55 E Top C1 Target 6545.00 0.000 0.305 12282.00 6629.20 6545.00 9086.44 N 2469.42 E Top B 6627.00 0.000 0.305 12376.68 6711.20 6627.00 9131.71 N 2483.30 E Top A4 6635.00 0.000 0.305 12385.92 6719.20 6635.00 9136.12 N 2484.65 E Top A3 6679.00 0.000 0.305 12436.73 6763.20 6679.00 9160.41 N 2492.09 E Top A2 6725.00 0.000 0.305 12489.84 6809.20 6725.00 9185.81 N 2499.88 E Base Kuparuk C ::0 ---- ~ ---- i;: r--- - 7 December. 2001 - 12:40 Page 80f9 Dril/Quest 2.00.09.006 c ~...:: f- "-: ~ i.- Kuparuk River Unit Casing details Fro m Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> To Measured Vertical Depth Depth (ft) (ft) 7412.34 12015.34 12689.84 Targets associated with this wellpath Target Name C1 Sand Revision 2 7 December, 2001 - 12:40 4154.20 6400.21 6982.40 Sperry-Sun Drilling Services Proposal Report for 1R-36 WP04 Revised: 7 December, 2001 Casing Detail 9 5/8" Casing 7" Casing 3 1/2" Liner Mean Sea Level/Global Coordinales: Geographical Coordinates: Page 9 of 9 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 6612.20 6528.00 9077.06 N 2466.55 E 6000900.00 N 542250.00 E 70" 24' 48.1200'. N 149' 39' 21.3152" W North Slope, Alaska Kuparuk 1 R Target Target Shape Type POint DrillQuest 2.00.09.006 Sperry-Sun A.nticollision Report Compan.\': Field: Reference Sill': Reference Well: Reference \\'ellpaLh: Phillips Alaska Inc. Kuparuk River Unit Kuparuk 1 R Pad IR-36 1 R-36 Dale: 1217:'2001 Timl': 11'46:52 P~e: Co-ordinate(NEI Rl'ferl'nCt': \'l'rtiraJ (T\ 1) I Refen:ncc: Well: 1 R-36, True North 1 R-36 W P03 @ 84.2 ASL 84.2 Dh: Oracle GLOBAL SCAN .\PPLlED: All \\ellpaths "ithin 200'+ 100/1000 of reference Interpolation !\Iethnd: MD IntervaJ: 100.0 II Depth Range: 40.1 to 12689 8 II 1\.1 a.ximum Radius: 1563.3 It Reference: Errnr I\lndl'l: Scan i\lethod: Error Surfan: Plan: 1 R-36 WP04 & NOT PLANNED PROORAI ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Ca.,ing rninlo; 1\10 T\'I..) Uiameter Hnle Si7e Name II ft In in 72123 4073.7 9.625 12.250 9 5i8" 12413.0 6742.7 7.000 8.500 7" 13625,5 7793.0 3.500 6.125 3' 2" Plan: 1 R-36 W P04 Dale Compo'icd: 11/19/2001 \'er'iion: 1 PrindpaJ: Yes Tied-to: From Well Ref. Point SlImmarJ' <--u------------------ Offset Well path _n-n--_____---------> Referem:e Of''iet Ctr-Or Nu-(;o .-\ II II "l.\ hie Sit(. Well \\'elJpath 1\10 1\1() Distance .\rea Oe\iation Warning II ft ft It It East Ugnu #1 East Ugnu It 1 Ugnu # 1 V2 Plan: Plan 5858.2 3500.0 286.9 0.0 286.9 Pass: Minor 1/100 Kuparuk 1 R Pad 1 R-12 1R-12 V1 1113.6 1100.0 305.3 18.7 286.7 Pass: Major Risk Kuparuk 1 R Pad 1 R-13 IR-13V1 399.4 400.0 30.8 7.9 22.9 Pass: Major Risk Kuparuk 1 R Pad 1 R-14 1R-14V1 398.3 400.0 90.3 7.4 82.9 Pass: Major Risk Kuparuk 1 R Pad 1 R-15 IR-15V1 397.1 400.0 149.8 8.7 141.1 Pass: Major Risk Kuparuk 1 R Pad IR-16 1 R-16 VI 396.0 400.0 210.6 8.0 202.6 Pass: Major Risk Kuparuk 1 R Pad 1 R-17 lR-17 V1 950.3 900.0 343.9 20.4 324.1 Pass: Major Risk Kuparuk 1 R Pad 1R-18 IR-18VO 1883.1 1800.0 225.3 51.5 177.8 Pass: Major Risk Kuparuk 1 R Pad 1 R-19 lR-19VO 200.0 200.0 91.6 5.0 86.6 Pass: Major Risk Kuparuk 1 R Pad 1 R-19 1R-19A V2 200.0 200.0 91.6 5.0 86.6 Pass: Major Risk Kuparuk 1 R Pad 1 R-20 1 R-20 V1 502.7 500.0 65.6 12.5 53.1 Pass: Major Risk Kuparuk 1 R Pad 1 R-21 1 R-21 V1 700.1 700.0 20.8 14.3 6.5 Pass: Major Risk Kuparuk 1 R Pad IR-22 1R-22 VI 589.6 600.0 120.1 14.0 106.2 Pass: Major Risk Kuparuk 1 R Pad 1 R-22 1 R-22A VO 589.6 600.0 120.1 11.0 109.2 Pass: Major Risk Kuparuk 1 R Pad 1 R-23 IR-23 VI 683.2 700.0 186.9 14.5 172.5 Pass: Malor Risk Kuparuk 1 R Pad IR-32 1 R-32 VO 300.0 300.0 77.8 5.7 72.1 Pass: Major Risk Kuparuk 1 R Pad 1 R-33 1 R-33 VO 1824.8 1800.0 75.3 46.0 32.7 Pass: Major Risk Kuparuk 1 R Pad IR-34 IR-34 VI 600.1 600.0 17.3 10.4 6.8 Pass: Major Risk Kuparuk 1 R Pad 1 R-35 Rig - 1 R-35 V24 398.2 400.0 59.9 7.6 52.2 Pass: Major Risk 0 = 'G^ J .- -~J -50 -38 ~5 I3 -027°\ \ \'\ ~~O --3R -50 9\3 13 15 .. I..... , '~ ., ,". , , ..-." ''', .. , .. ~. ., . , Cok\ur T¡"l Í\ID ~OO :'00 600 700 800 1300 1800 .::!.,OO )300 ~300 ':;300 6300 7300 S300 l))00 "10300 11300 12600 " ..,'... "' "' ",1)0 '. "' " III h'. "il'" :,;: ~:! .., ... II. I'. ~ .t.. ~ I ,-, Irl~ .. 1.,' Tit ,\I L" T 'II :- .~.' .L ',', --- ......- ----~ /. .// ",/'/ \. \ \, "'. . --- - - r3' " ".1' »" ,,:'-~ ,:, ,Y:,: ~r ~~; l~~ii:~ j '.::::-!': :::~ ,01 ..,,' \ ., ~. ~:, ~ ';11 -. . ~" I,~ : :"'. , - ::: ~ ,', < ~ J ,'" I:: r:"< '- ['SftJin] ~ e Separation -- . - C\~nlrè to C. entr ~ ZI [-1"1""] \ ~ . 1'1-"0+:\) L c-= . :t C"lmder AZll1luth I TrJ\ ellm~ ". "II' ¡-..", - ;~,~'-"I"IJ 1'1..", '-1,.... '. ~.. i ,.!'~..I 1.11" I ~ :'~. ¡ 'J 11,I0Il. '.'::: .,,1'::.; ;'1; "I' ;'::: ,,,:'::1:': IJIF"I I ....JI 'I" ,,' ...\ I ,~" J J. II~" ,.. Ila ". J' UhjLlduL 1 R-36 Drillin{.1 Hazards Summary 12-1/411 Hole /9-5/8" CasinQ Interval Event Conductor Broach Well Collision Hydrate gas G ravel and sand sloughing Shoe Fracture/Lost Returns during cement job Risk Level Low Moderate Moderate Low Moderate 8-1/2" Hole /7" CasinQ Interval Event Shale stability in HRZ and K-1 intervals High ECD and swabbing if higher MW is required Hole cleaning in long, high angle tangent Drilling too deep into possibly elevated pressure of Kuparuk sands. Risk Level Moderate Low Moderate Moderate 6-1/8" Hole /3 1/2" Liner Interval Event Drill into higher than anticipated reservoir pressure. Hole cleaning in long, high angle tangent Barite sag if higher mud weight are required. Risk Level Low Low Low Mitiflation StrateflY Set 120' of conductor (instead of 80') and monitor cellar continuously durinÇJ interval. Careful well planning and surveying, adherence to anti-collision policy. Use coldest water available to mix in mud to keep it cool. Elevated mud viscosity from spud; Hi dens sweeps. Reduced pump rates, and lightweight tail cement M itiflation StrateflY Control with higher MW and proper drilling practices. Control mud rheology closely, and monitor surge/swab pressures with PWD tool. Pump out on trips as necessary. Good drilling practices. Monitor GR/Res logs closely and work closely with geologist to ensure 7" casing point is placed as planned. After open-hole LOT, risk of drilling ahead may be deemed acceptable. I M itiflation StrateflY 1 R-35 may re-define the maximum reservoir pressure in the fault block. Set 7" casing shoe in good shale to provide adequate kick tolerance. Good drilling practices. Use Baroid hole cleaning program as a double-check to prevent problems. Watch mud properties closely. Control mud chemical additions (lubes) to prevent barite settling. Follow guidelines provided. 1R-36 Drilling Hazards Summary 11-19-01.doc J : 'ff'N¡~~ Pad and SurroundinQ Area Event H2S encountered while drilling. Produced levels of H2S in the range of 160 ppm have been noted in well 1 R-20. Risk Level Low M itiCiation StrateCiY Approved Hydrogen Sulfide contingency measures will remain in effect during the drilling of 1 R-36. If it becomes necessary to notify the AOGCC of an H2S encounter, drillinq will be suspended and will resume only after the development of detailed remedial and contingency procedures, full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49, and approval of the AOGCC. 1R-36 Drilling Hazards Summary 11-19-01.doc SCali L Lowry . Page, 2 q,f 2 V I ¡ i' \:/ i I \:JA L KRU 1 R-36 Product. Proposed Completion Schematic T opset Base Case ~ PHIL\LIPS Alaska, Inc. T¡1"¡t A Subsidiary of PHilLIPS PETROLEUM COMPANY ~ r ~ ~ ~ ~ ~ 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ... ~ ~ ~ ~ ~ ~ ~ ~ ~ 3-1/2" Cameo 'DS' nipple wI 2.875" No-Go Profile. Set at +1- 500' MD ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 16" 62.6# ~~ ~ ~ ~~ ~ ~ I ~ @ +1- 120' MD ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ TAM 9-5/8" Port Collar ~ ~ ~ ~ 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple ~ ~ ~ Stnd. Grade BTC Threads § ~ ~ § ~ ~ ~ (+1- 1000' MD I 993' TVD) ~ ~ ~ § , ~ I ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Depths are ~ ~ ~ ~ ~ ~ based on ~ ~ ~ ~ ~ ~ Nabors 245E ~ ~ I ~ GLM Placement TBD ~ ~ RKB ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Surface csg. ~ ~ ~ ~ ~ ~ ~ ... 9-5/8" 40.0# L-80 BTC ~ ~ ~ ~ (+1-7412' MD 14154' TVD) ~ ~ ~ ~ ~ I ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ 3-1/2" x 1-112" Cameo 'MMG' mandrel wI shear valve and latch (Max. OD 5.968", ~ ~ ~ ~ ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling ~ ~ ~ ~ pups installed above and below. ~ ~ ~ ~ ~ ~ 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing ~ ~ ~ ~ ~ !EEl ~ ~ ~ 3-1/2" Cameo 'DS' nipple wI 2.813" No-Go profile. ~ ~ ~ ~ ~ ~ ~ ~ 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing ~ ~ ~ ~ 5.125" x 3" Baker locator sub ~ ~ ~ ~ 4-1/2" Baker GBH-22 casing seal assembly wI 15' stroke, 3-1/2" L-80 ~ ~ ~ ~. ,¡o:: .- EUE8RD box up l7i'h?/A Intermediate csg. 7" 26.0# L-80 BTCM (+1- 12,015' MD 16400' TVD) Production Liner 3-1/2" 9.3# L-80 SLHT (+1- 12,690' MD 16982' TVD) ~ ~ - Liner Assembly (run on drillpipe), set (ã) +1- 11,865' MD Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flexlock' Liner Hanger Baker 17' Seal Bore Extension XO Sub,S" Stub Acme box x 3-1/2" SLHT pin 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" 9.3# L-80 SLHT liner as needed 3-112" Cameo 'D' nipple wI 2.75" No-Go, 3-1/2" SLHT box x pin 3-1/2" Baker Landing Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Shoe 0 ,~ --):1 .-~ ~1 '~I A' ií¡1Í;l7¡ot~lLJ L Future Perforations KRU - 1 R-36 Prot. .cer Proposed Completion Schematic Selective Single Completion ~ PHilLIPS Alaska, Inc. .fÐ¡ A SUbs;d,ary 01 PHILLIPS PETROLEUM COMPANY 16"62.6#@ ~ ~ ~ ~ ~ ~ +1- 120' MD ~ ~ ~ ~ ~ ~ ~ ~ ~ TAM 9-5/8" Port ~ ~ ~ Collar Stnd ~ ~ ~ Grade BTC ~ i Threads (+1- ~ ~ 1000' MOl 993' ~ ~ TVO) ~ ~ ~ ~ ~ ~ Surface csg. ~ ~ 9-5/8"40# L-80 ~ ~ BTC (+1- 7412'.......a ~ MD 14154' TVD) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ C1, Sand Peris MD - ~ìi1'1 ~ ~ :~\ÐJ ~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ¡r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Z ~ ~ ~ ~ ~ Z ~ ~~ ~~ ~~ ~ Z ~ ~ ~ ~ ~ ~ ~ ~ ~ za...... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~- .. r ..... ~ 1"- L Ii""- r- ~ ~ ~ ~): ~ r-- ~ - , ',..'- ~ ~ ) ~ ~ ' ~ .'L.hf'""< '""~ ~-g--' .~ ~ ~ ~ ~ ~ " ~ ~,:<' ~ ~ ,'<\:.1, {yn ~ :i! "'"' ~ ~ ~ ~ ~"-- II: ,. ".ïi" .::.- ""~ r- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ J::.ff+~1¡¡::l A3 Sand Peris MD Production csg. 7" 26# L -80 BTCM (+1- 12,690' MOl 6982' TVO) .J. -:)): .\~ ~ ~ --1 .:(: 3-1/2" FMC Gen V tubmg hanger. 3-1/2" L-80 EUE8RO pm down. 3-1/2", L-80, 9 3# EUE8RD Spaceout Pups as Required. 3-112" Cameo OS Landing Nipple with 2.875" ID No-Go profile set @ +1- 500' MD. GLM Placement TBD 3-1/2" x 1-1/2" 'MMG' GLM wI OCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2" 'FHL' Relrievable Packer +1- 150' above top planned perf. Minimum ID through the packer 3.00". 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing to Packer. 3-1/2" x 1-1/2" 'MMG' GLM wI 6' L-80 handling pups installed on top and bottom of mandrel. 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing to GLM. 3-1/2", Blast Rings, enough to cover C sand perfs and 5' on each side. Baker Sliding Sleeve with Cameo 2.81" DS Profile (Lock has 2.856" NO-GO ring). 6' Pup Joint 3-112", L-80. 9.3# EUE 8rd Mod Tubing. Baker 'GBH-22' Locator Seal Assembly (5' seals wI locator). Baker 'FB-1' Hydraulic Set Permanent Packer wI 5' Seal Bore Extension set between base of C1 and top of A3 sands (4" ID through SBE - 2.985" min bore through seals). 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Cameo D Nipple @ 'w/2.75" No-Go 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" Shear Out Sub wI WL Re-entry Guide. TO @ 12,690' Scott L Lowry 12/07101 v1 :J Hili i A A,~ TRANSMlT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER ~ . <..\~" 1 ~d \3 H L '\ CHECK 1 STANDARD LETTER DEVELOPMENT / DEVELOPMENT REDRlLL EXPLORATION INJECTION WELL INJECTION \VELL REDRILL \VELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL <-)NO ANNULAR DISPOSAL L-) YES ANNULAR DISPOSAL THIS WELL l TL-~\o "CLUE" The permit is for a Dew wellbore segment of existing well --' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSA~L INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill tbe above referenced well. The permit is approved. sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. ~~!Æ~E : F L~~~~~~fÆ .I I / / / TONY KNOWLES, GOVERNOR AlASKA OIL AND GAS CONSERVATION COMMISSION 333 W. T~ AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck tv1allary Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 ..\nchorage Alaska 99510 Re: Kuparuk River Unit lR-36 Phillips Alaska, Inc. Permit No: 201-227 Sur. Loc. 606' FSL. 147, FWL, Sec. 17, T12N, RI0E, UM Btmhole Loc. 784' FSL, 2474' FWL, Sec. 5, Tl2N, RIOE, illvl Dear Mr. Nlallary: Enclosed is the approved application for pem1it to drill the above referenced well. The pemllt 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 pem1itting detenninations are made. Please note that any disposal of tluids generated trom this drilling operation which are pumped down the surtàce/production casing annulus of a wen approved for annular disposal on Kuparuk River Unit 1 R-36 must comply \\lith the requirements and limitations of 20 AAC 25.080. Approval of this peI111it to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. 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 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test perfonned before drilling below the surtàce casing shoe. must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely. Î" î J I'~W" ~J1~t~,~~,~ () Cammy ~jchsli Taylor Chair BY ORDER OF THE COl\'l\-1ISSION DATED this 4th day of December, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc1. ~S\ PHIL(.PS Alaska, Inc. ~I A Subs;diary 01 PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Chuck Mallary Phone (907) 265-6434 Fax: (907) 265-1535 Email: crmalla@ppco.com November 26, 2001 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ?''' Avenue Suite 1 00 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, injector 1 R-36 Dear Commissioner Taylor: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well, KRU 1 R-36, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, .. {! £'7114r2~~r Chuck Mallary .......1 Drilling Engineering Supervisor RECEIVED NOV 2 6 2aOl Alaska Oil & Gas Cons. CommiSSIon Anchorage ORIG NA. ST ATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 1a. Type 01 work: Drill ø Rednll 0 Re-entry 0 Deepen 0 2. Name 01 Operalor Phillips Alaska, Inc. 3. Address PO, Box 100360 Anchorage. AK 99510-0360 ~. Location 01 well at surface 606' FSL. 147' FWL. Sec. 17. T12N. Rl0E, UM At top 01 ploduclive Interval 208' FSL, 2335' FWL. Sec. 5, T12N, RlOE, UM Allotal depth 784' FSL. 2474' FWL, Sec. 5. T12N. Rl0E. UM 12. Dislance to nearest property line 13. Distance 10 nearesl well 2474' @ TD leet 1 R-34 16' @ 550' 16. To be completed lor deviated wells ~KICko" depth: 300 MD 18. Casing program size 20 AAC 25.005 1b. Type 01 well. Exploratory 0 StratigraphIc Test 0 Service 0 Development Gas 0 Single Zone ø 5. Datum elevatlDn IDF or KB) RKB 41 feet 6. Property Designation ADL 25628 ALK 2561 7. Unit or property Name Kuparuk RIVer Unit 8. Well number 1R-36 9. Approximate spud date December 5. 2001 14. Number of acres in property 2560 Maximum hole angle 65" Hole Casing Weight 24" 16" 62.5# 12,25" 9.625" 40# 8.5" 7" 26# 6.125" 3.5" 9.3# Specnlcations Grade Coupling H-40 Weld L -80 BTC-Mod L -80 BTCM L-80 SLHT length 120' 7154' 12407' 1375' 19. To be completed tor Redlill. Re-entry. and Deepen Operations Presenl well condnion summary Total Depth: measured lrue vertir.al leet leet Etfeclive Depth: measured true vertical leet feet Casing Conductor Surface length Size Cemented Production Pertorallon depth: measured true vertical Permn Number ;;.c: 1- ;¿ 2- '7 feet bdt:L Developmenf Oil 0 Multiple Zone 0 10. Field and Pool Kuparuk River Field Kuparuk River Pool 11. Type Bond (see 20 AAC 25.0251 I Statewide Number #5952 180 Amount $200,000 15. Proposed depth IMD ar,d 1VD\ 13673' MD 16898' TVD 17. Anticipated pressure .see 20 AAC 25.035 lell211 Maximum surface 3177 psig At total depth (TVD) 3905 psig Setting Depth Top Bonom Quantity of Cement MD TVD MD TVD (include stage data) 41' 41' 161' 161' 420 sx AS 1 41' 41' 7195' 4158' 600 sx AS Lite, 860 sx liteCrete 41' 41' 12448' 6379' 170 sx Class G 12298' 6316' 13673' 6898' 290 sx Class G wI GasBlok Plugs (measured) Junk (measured) Measured depth True Vertical depth RECEIVED NQV 2 6 2001 Alaska Oil & Gas Cons, Commission AnChorage I See cover lel1er tor other requirements ; 0 Yes 18] No i ŒJ Yes 0 No ~~ i ~5()\J~" ~\~\''('I\..~'" ~a~~T= 1ïI. Approved by by order of 0 R'~ _'he COmmi$IDn 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 DivertH Sketch 0 Drilling plogram ø : Drilling tluid program 0 Time vs depth p, ORelraction analysis 0 Seabed report 0 20 AAC 25.050 requiremenls 0 i 21. I hereby <~. Ine lore~yue and ,ecilo tne "&:: mé~Ih':::i,-.q.e 'f Questions? Call SCON,L(Ojry 26L86~ ' Signedl~t:/ C7~' Title: Dnl/,r,g Er,g,"E<ef,"g SupðnMOf Date I Z"tD{ C. M3/1ary PreDared bv ShMon AlfsuD-Or;:¡kE: Commission Use Onl~ API number I Approval date I I I 50- (~Z c¡ - 2-3t)~-7-C() + L{ 0 ! Conditrons 01 approval Samples required 0 Yes ~ ND Mud log required Hydrogen sulfide measures fgJ Yes 0 No Directional survey required Required wol1<ing pressure for BOPE D2M; 0 3M: 0 5M; 0 10M; 0 Other: ~ \\~ '-.cc. W\.Ç. ~~ ~~O \\~'i ~\ Original Signed By CaUlIlIY Oechsli Form 10-401 Rev. 1211/85. Date 1...)./4/0 I Submit in triplicate 'licatlOn for Permit to Drill. Well 1 R-36 Revision No.O Saved: 21-Nov-01 Permit It - Kuparuk Well 1 R-36 Application for Permit to Drill Document MCI:(imiz~ Well Vghn Table of Contents 1. Well Name............................... ..... ............................................................................. 2 Requirements of 20 AAC 25.005 (f)... .................... .............. ......,...... ........................................... ...........2 2. Location Sum mary ................... .......................................... ................... ....... ............2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25. 050(b). ...................................................... .................................. ...............2 3. Blowout Prevention Equipment Information .........................................................3 Requirements of 20 AAC 25.005(c)(3) ...... .................... ............. ............................................... .............3 4. Dri II i ng Hazards Information..... ....................................... ........... ............................ 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................3 6. Casing and Cementing Program .... ........................................... ........... .... ........... ....4 Requirements of 20 AAC 25.005(c)(6) ....... .... ................ ................. ......, ............................... ................. 4 7. Diverter System Information ............................................................................ ....... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Dri II i ng FI u id Program............ ................................................................................. 4 Requirements of 20 AAC 25.005(c)(B) .. ..... "" ................ .................. ..... .......... .............................. .........4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seism ic Analysis.................................. .................................................................... 5 Requirements of 20 AAC 25.005 (c)( 1 0) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bond i ng.............. .... ....................................... ............ ..................... ...... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................5 13. Proposed Dri II i ng Prog ram.................................................................. .................... 5 OR G NA~ 1 R-36 PERMIT IT. DOC Page 1 of 6 Printed: 21-NoL'-01 'ollcation for Permit to Drill. Well 1 R-36 Revision No.O Saved: 21-Nov-01 Requirements of 20 AAC 25.005 (c)( 13) ................................,............ ...................................................5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments.. ......................... ........................................... ....... ................................6 Attachment 1 Directional Plan..................... ........................................................................................... 6 Attachment 2 Drilling Hazards....... "'.".". ........... . .......,. ..,. .....,............ .............. ... ... ...... ..... ..6 Attachment 3 Well Schematic........... ................................................................................. ..6 1. Well Name Requirements of 20 AAC 25.005 (f) Each ¡veIl mllst Dc Id17nNied bv a un/Cluc name- dC5/ÿnJti...Y¡' hV ti,IL' ()pIY,.Jwr and.:1 /.ill/que 11PJ number r155/L,m:::d by the..' ClJil1m/,.;;s.'on under )() AAC /5~ 040(b). For ¡J 1 l/â/lVllh m{//tIJ'/~ n~/I tJrancllr?:::, t?actJ ,t)ra(l,-II rnu:,t SlIllll.olrl¡: hI? 1(ft:'nli,~'eJ hJ' a /lmqu,~ nam:;; .In.i 4P/ num!.1r;:'r /l,;, dOi1:nq r7 s/lii/x to lilt' n.-Jn7(' d2:>I~lfIal,~ä fcr' file well hy 1172 1~{J2rah'l and to tilt' ournl.)er .-l5:>l,~lnr?d 10 tile L've!.i bV I/k' comml5si¡ IfI, The well for which this application is submitted will be designated as 1R-36. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An a,L~{)/iCdÖOI7 /Òr d Pemllt to Dnl/ must tic dCC()mpdflll'd tJ~, edL'fJ of the /o/I¡..IH'ItI(J Itcm~: r.:Yi. 'l"pt /()r dn ,tcm .:J/;~L'dd¡ 1)17 ¡iii..' ad/! tlk' l':ommISSIL'n dnd Identifit'ä /17 (.'71..' applt.:rJtlon: (2..' a p{rt Identl(l'mq th~ propcrtv am) the ,!.JriJp'-:lt}':j (")! mä 5 and SIhJII,'mq (A)tllc? ~~oor,j/nati?:' t)( tilt;> ,orl.Jpu:;;t;>d IOl~JlIOn (V"I/JI:~ : 1'r?li at rh-,' sud"Jc.-? at tlJ¡;' tr'~{) 0/ ,'?ad7 l'/J¡"f'("tll.e ií::rrmatl,JII" add .,-J! t,Jt,,J1 a,;:~tltn, f-r.ii;Yt"oced to ,Llf,Wl?(¡ In It;?lI!JI St>,'~íl""n .l10t;><;. (8) t/ìt' C 0,'" dirldh::,~ ~)í tilt" J n~[I()!::-'f::'.llo.: . ~"ï(.1r¡ 01" {/I.'::-' ,( ¡.t'I/ df tlìt: :.;ur(..;!{.e'.. It'lc>ri:!na;'Li fl') tht: .<;/:--11,-> f-,I.Jflt:' (,'( Icr(//fI..Jtr. s}'::>tt'm 1(.11 t/;:::;. ,.:,Idlt:' ,J,':'" mainldl1l2J 01' tlit' IVdtlOl!dl G"t:'ou21¡(: SL."n'ë',~ ¡¡¡ llie Na{lf)l!al Oct"JlJIC dnd At,"NiJSphr?n.:: Aaf!!mlStr.-ftIÒn; ((' the: ¡:/oj)(}.c,'tJd J2,otlll';f Ilk! wt:'/I...-It tl¡t;:; tJp ul t'~j(.l/ (lL!Ic'(t/!'c l(Yflld/tOn anrl ,4 turdl (/e¡;t!¡; Location at Surface NGS Coordinates Northings: 5,999,810 Eastings: 539,832 1606' FSL, 147' FWL, Sec 17, T12N, R10E, UM RKB Elevation Pad Elevation 84.2' AMSL 42.9' AMSL Location at Top of Productive Interval (Kuparuk "Cl" Sand) NGS Coordinates Northings: 6,001,981 208' FSL, 2335' FWL, Sec 5, T12N, R10E, UM Eastings: 541,929 Measured Depth RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 13,012' 6618' 6530' Location at Total Depth I 784' FSL, 2474' FWL, NGS Coordinates Northings: 6,002,564 Eastings: 542,065 Sec 5, T12N, R10E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 13,673' 6898' 6810' and (D) other m/orrnaflon h'quircJ hv 217 AAC 25.0S0(LJ); Requirements of 20 AAC 25.050(b) ¡( a /l'el.' IS to N' Jl7tent/(7nallv dT/3tt'ä, ftï(~ a,,'1/JI;',,:,at¡,lf7 r~" a Pcrmlt tù Dnll (¡c<./rm 1(J -,101.1 .7ìll5t (!) mr:lu.1e a rlar, drdHlI m a _'::;ilItd/)/\~ :;'::,7l'r, s/,1..m'l/IÇ! //1,':> palll ,"if fil::' {Jrlpo_"-r:yj 11,:;>II(Ji'.Jl-r.. IIk-Illd/or-! all .'ld.ucf"nt l¡.'c"'llllcJr;,,;,Ç t'~'thl!,1 '-'00 (2..:>r of any p:)rllon ,)( ,fiJ::;' pr;-,pœ.;pd ¡ ¡'::'/I' Please see Attachment 1: Directional Plan O~ G ^A. 1 R-36 PERMIT IT. DOC Page 201 6 Printed: 21-Nol'- 0 1 lication for Permit to Dnll. Well 1 R-36 Revision No.O Saved: 21-Nov-01 and (2) ,for ail' m31ls ¡¡.¡tllm 200 ,f~e[ of {he p'~i...ìl-'osed 1I.'r3/lLJ.)(f! (4,1 1~'5( tile nan.'é'." Df [he operators o¡- ti'ïose m311s, it) t/~e extent r/7al thL'se names aré' knOI'in or üi'5~-ol'eraLI:'é' /17 DUl')I:( recc.r.:fs. and SIIOL'.,' tllar c!.3c1111.~meO operater has been .fL.fTl:S,'12d a CODy (Jl ttle .-7Dpllca(,on tor ~-erNied r17a:/" or (8.' state that the applicant IS (he only affected Qn'ner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An appllca{lon ror a Pc..'/fnft to Drill il/Ust be a.:.cùmpani2u b~ è'dC17 ~l( rl72 /o/"ùtl'/ng 1ft',?!::,: except lOf an Item aheady L"f! !ile 1,.'1[/7 tne comml55fon ar¡ä IIJentlfied In tile appltca{¡on: (J) a dia~Jïam ana'dcsC/fptlon of tl7t? blol'o'/}ut preL'entIL)(J equl¡.'Jfl/c'nt (BOPE,J as feqUired [1,/ 20 AAC 25.0.15, 20 AAC 25.036, ot lù ,4AC ?5.0J7, as applIcable: Please reference BOP schematics on file for Nabors 245E. Schematics will be re-submitted by 12/7/01. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/,'C:Jlll'n for â Pé'rmit to Drill muSl br! cll'L:(l¡I~udmo::d ¿IV c'dâl t'(t/lt::! rd/OIl'fflÿ flo::ll7::;, r:;'xcept fur an ftr;!flI dlrr?:J(/y on 171e ¡'y'Ù'll me comnJ6Sl0i7 and IdentlfÎed m tile' c,fppllc.atlQIJ: (~/) miomJtJt¡(1f! on dll//If1~/lId.?alJ..::;, mäudmy (~1) the m.7.W17urn do¡ I'nh(1/r~ pressfJ!;';' rlJat mal¡ b(~ r.VÏ¡':cuntcrt:'(1, o'¡[err(ì USryj to d,_'tcrmmc":.' it, and mtl.\'I/17l1m fJ(1{:'n{,lal.':;iJrfd(-:~ cre-;::;l1rc' ha5L"d on a fl/r~fhan(~ ~7/adft..'/1t: Based on offset well data. the expected reservoir pressure in the C-1 Kuparuk sand for 1R-36 is -3000 psi at 6600' tvd, 0.45 psi/ft or 8.7 ppg EMW (equivalent mud weight). The C-l sand could have a maximum reservoir pressure of -3900 psi at 6618' tvd, 0.59 psi/ft or 11.4 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling 1R- 36 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the C-1 Kuparuk sand target at 6618' tvd: MPSP =(6618 ft)*(0.59 - 0.11 psi/ft) = 3177 psi (B) data 0/1 polcntl<11 pas ZOfll'~; The well bore is not expected to penetrate any gas zones. ¿'od (() t.-!....:¡t..:¡ t:':'ìf1C2minp potf?nt/ôl CdU::;Ò' of hule pruNc:fJJs ~:UL/J ,.-15 aÖflcJrllld/i¡' ~lt'oprr:'::;!::o/!rf?ä slhltd.. /os! urCfI/::JtIOil /.'o(}ò.. :mli. '(Jrk'S ("'-¡dt Ihwe oJ pn~[1('lblt.~ for rllft2'.rcnllal stlckmu: Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) ...111 apl.7/icatton tor ç7 P~rtnlt /0 Dn/I must /.'c? aCCOfllj.k'Jllled b~ r:YJ.-..11 or {ilE' 1;)llon'lng Items, e>r.'cept ,r,}( ,J/] ilem a/r..'.3f1\' on ¡ì/(' Hïth I!Je C()l7Imi5S1011 and ¡'¡~'~Jntiíii?d 111 tile applicatirm: C>.J 2 dCSCfIi'ìtwn of {hI? pux2dwt' (ur conducting /Òrflidli'(){/ intr?iji/ty tt'sts. as rc:'qtlifetlulJ(/rjr /0 AAC )5: 030( fì,.. Drill out surface and intermediate casing shoes and perform LOT test or FIT (maximum of 16 ppg EMW) in accordance with the Kuparuk LOT / FIT procedure, that Phillips Alaska has on file with the Commission. OR GNA. 1 R-36 PERMIT IT. DOC Page 3 of 6 Printed: 21-NOI'-01 ~plicatlon for Permit to Drill. Well' R-36 Revision No.O Saved: 21.Nov-01 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An dDpÙcatlùn tor a Pr;31 md to Dnll must œ accomJ1a/ì.lé'c L'v 23C/7 ot [,~'2 r~Î,I/\..lL I'ln(, lfé':ns, excé'pc íCI .3n I[em c7/:.eacr C',.'ì fi/2 ~~'I["] Ihe ((}mmI55lù17 ar,u Identilìeä ill tlle applIcation: (6) ð campieti::' .orûp~:..'Ìt'd i..:ëJSlliU and cemé'nt/n£7 Or09rð/T! as r:=>ql.1IIed D/ 10 MC 15. 030, ,::mä a ûr:".SC,":Dt/~ìlI cf any' s,'otteu ll.'ie?I, ,cre- pi'rf.:;rateo Mer, or scrë'en ro oe mstah'eo; Casinq and Cementin9 Program Hole Top 8tm Csg, Tbg Size Weigh Length MDITVO MO/TVO 00 (in) (in) t (Ib,.'ft) Grade ConnectIon (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 120' 41'/41' 161'/161' 420 sx 15.8 ppg AS! 9-5/8 12-1/4 40 L-80 BTC 7154' 41'/41' 7195'/4158' Lead: 600 sx 10.7 ppg AS Lite Tail: 860 sx 12.0 ppg 'LiteCRETE'. (Yield==2.40 cuft/sk) Planned TOC==Surface 7 8-1/2 26 L-80 BTC-Mod 12,407' 41'/41' 12,448'/6379' 170 sx 15.8 ppg 'G' w/ add. Planned TOC== 11,648' 3-1/2 6-1/8 9.3 L-80 SLHT 1375' 12,298'/6316' 13,673'/6898' 290 sx 15.8 ppg 'G' w/ Gasblok Planned TOC==12,098' 3-1/2 9.3 L-80 EUE 8rd 12,257' 41' / 41' 12,298'/6316' Mod An open-hole leak-off test will be performed on the 8 '/2" open hole interval after reaching casing point. If the leak-off test indicates sufficient formation integrity, drilling will continue to total depth of the well. In this case, a selective single completion will be used. If 7" casing must be top-set above the Kuparuk sands in the lower Kalubik, a 3 '/2" production liner will be used and an exception to 20 AAC 25.412 (b) is requested. The distance between seals at the top of the 3 '/2" liner and the top perforation will exceed 200' MD. In the top-set case, the distance between the seals and the top perforation will be 1V700' MD / 300' lVD. An adequate leak-off test of the 7" casing shoe, combined with a cement bond log of the liner section below the 7" casing shoe will provide proof of zonal isolation between the seals and the perforated interval. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An 3ppllcaÖon /or d Pcm7l1 t,] Dn/I must bc dccc)mpJfJ/t.'d bf' C,/Ll¡ lJl thL' ti:.JI/Oj ¡ ¡fJ(J item:::, t'xccpt fix Jrt ltCtn Jlr¡;'d:1~ on /í/c Ivltll tl7c:.' romrmS51Òn and Irf,'''otl/ied In the appf.oirl(ion: (7J a di3çfaln and dr}Sr7lptlOlI 0/ tht~ dwertcr s~:<;t..'m.:75 rt:YJUllc£1 tJi- 10 .4AC 2S.035, unle..:;sllu5 ICLllJlrc'ment I~ [,.'iJiL/I..'d t.J,v tilt" c..ìlnm/.,O;¡Ofl unäer"?O .4AC )S,03S(II)(2): Please reference diverter schematic on file for Nabors 245E. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) ,Jln J¡:'~-'/¡L:atltÌf/ ¡¿if" d Päll7lt to Dm! must [iL' dCLOlr(L1.:f!7lc.'d D~' t.'dc!1 of" (he.' fÒl/c)! .'1.17£1 dr..'i,'b, CXCL'pt for .:m It071 <:II l'eldy (It,' tilc' I ~./t 1/ tl7e comrT/l~s/ùn dfld /äi:!rlt/f/e.} m tile dppÙ(atlOn: is) .:7 dnlltn~? {lwei (lllJçram. /lI.-ludmç a ~~".79Ii7m and t.1c.'i.::npiloo ¡)f ch.:' d/i'NIiI~.7 fhl/dq,~"h_'m, as feq/.llrä1 L'r]O ....IAC 25.t'UJ; Drilling will be done using mud systems having the following properties: ORG NA- 1 R-36 PERMIT IT. DOC Page 401 6 Printed: 21-Nol'-01 IJlicatlon for Permit to Drill, Well 1 R-36 Revision No.O Saved: 21 -Nov-01 Spud to surface casing point Extended bentonite slurry Intermediate Hole Freshwater LSND Drill out to TD Freshwater LSND Density (ppg) Funnel Viscosity(sec) Yield Point (cP) Plastic Viscosity (lbllOO sf) 10 sec. Gel (lb/100 sf) API Filtrate (cc) PH Solids (%) 8.5-9.4 60- 300* 25-50 20-40 15-40 4-15 8.5-9.5 3-8 8.5-1004 35-55 8-25 5-25 3-10 5-15 9-9.5 3-10 10.5 50-65 15-25 12-24 3-10 HTHP < 10 9-9.5 3-9 *Spud mud should be adjusted to a FV between 200-300 secjqt to drill gravel beds Diagram of Nabors 245E Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c){9) An a¡Jplk"3IIUn (,:)1" n Pc'f'flllt (0 DoH must b~ ,A'L'Ompamed ly t:!ddluOllè ¡dlu[ 1'1119 i!c:'.nïS. C','(i't'Pl Ii: '(.JlJ I(ern dl/'r.:'ddy un /Ì/r. ~~/llï !/ïé' COrWrIISf,lun and J¡'jr?rIt/rit>d III l/le dfJP/lcdtion.' (9) l'c>( 3.'1 e~p/(,Iratùn' or str,JtlpI3p/71C lcst 11'c.'/I, a t.~~DlJ/JtIDf7 ::>âtmf) out tl,le:.' lit...'AII~ (I/'¡J/I...'t./ILlr..'J dÖourmi:/llr £/CO-f..'rÒ5vlc,j st!3td as rcqum..'d [Jr J(J AilC .?5. OJ3(1t Nj A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) All appIID'1/II.lf7 ,fix d Pr?/mi/ [lì Dr:Z¡ mu."it be al~COll7f.I,'Jflir::'d Öyedcll ,.l! the IÒNOI ¡''iflq rlt;'m:>~ 2XCt'nl' r~)/' an rtt?m (}lrf'.;Jl1~ on lile [I'itl! tl.¡e c~}mmr~':;.')/w'll and ,,1e¡ltlrìt?,} Ii1 t17r? a¡:y"J/lc.Jt/on.' (I (~) I()r ali t>\plm~Jt(v')' (}(' :,,l:r'cJtrqraphlc te',:{ ¡,veil.. a f'e/<;mlc (¿liar:: tll-"17 Of relit', 'Öon dfldi¡ s/.o; (7,':: rf'f/uirt?d /If )0 AA'c" /5. Ofj 1('1); Nj A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) --1n d¡,p'Ication tor d Pcrn.w to Drill ml6t oe dCCOfllpdrJIf...'d ¿w eac.h 0/ the.' /o/!(,'nÙl:7 ¡[L'm:;, c.',\'Cl:l't (or an Itcrn d/rr::.'ùdv iil1 ri/c 110'1[11 tl7e:.' commC::;SIO(1 and Idc.'nMicd /11 the dppl/cdtlon.' (J 1) (iX.:1 well .1nlle,i tlOn¡ ad ortshore platf,m.1'7, mobile bottom' found(.:d structflr..'. pck up ,'h7, or rk'.:7tm~7 t1nil''{iq I'e.,ser~ an .:7IhJiV5'S ¡}f<;eaoc:d ccnt:!I{i('n.'i .:1,'::: rl :qulI ed h,~' Zt7 AA C .?S. 06 J (Ö. : NjA - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An ,J,OpliCd!il)(/ lor a I~'-rf//t to (J1l//lflUS" {It:! à'Ll"Ompameu by f',;J(h o( tl/2 íolk)i.\iny rtt'?rtJ.:.. (.lvcr:'pt f..yan irem .Jl.r2djv l:Jf} lìit' ¡¡'Il/! ¡l,e (i)fI.'II!/.~'~-IU{} .-/1.'''/ !äfmttlìC'd III tlie 3ppl¡c,¡ii/)n; (1./) r..'I'ldr:.oncC' ':':'/JOWlfI(7 l/7:'It the h'qwrð/k'lIts of .?O ,..1AC 25. 025 {B,JnJm(7}/lrJl:e bc.'t..'1] rnd: Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) .417 ,-}r¡JI,'{~.:7rfvll k),.- d Pr7"-lmr iû Drr/I must t~(: .:1cU)f!~oall/¿'d b~' "'<7<.-ì'ltìf toc'! rOl;'oil'.'m.è ¡feIn,':;. ¿',h-~~{}t /IJ( an ¡(cm a/rc.:1dr on riA: .v//// (,'Ie COl1lf1l/:;,"'-'O/7 ,:Hld ,I,:lä7tlli.'d /f7 t/lr. ,lp{J!,cafli,1n OR 'G NA- 1R-36 PERMIT IT. DOC Page 5 ,J! 6 Printed: 21-No\'-01 -'olication for Permit to Drill. Well 1 R-36 Revision No.O Saved: 21-Nov-01 The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 245E. 2. Install diverter system. 3. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" 40#, L-80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, perform stage or top job. Install and test BOPE to 5000 psi. Test casing to 2500 psi. 5. Drill out cement and 20' of new hole. Perform LOT/FIT, but do not exceed 16.0 ppg EMW. 6. Drill 8-1/2" hole to intermediate casing point according to directional plan. Run LWD logging equipment with GR and resistivity. Perform second LOT to evaluate long string option. (If LOT is adequate to long string, POOH and P/U neutron density tool, drill to well total depth, and run 7" 26# L -80 BTCM casing to surface and cement. In this case, a selective single completion will be used. ) Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with 20 MC 25.030(d)(3)(C). 7. Run and cement 7" 26#, L-80 BTC-Mod intermediate casing string. Pressure test casing to 3500 psi. Note: If significant hydrocarbon zones are present above the intermediate casing point, sufficient cement will be pumped for isolation in accordance with 20 MC 25.030(d)(3)(C). 8. Drill out cement and 20' of new hole. Perform LOT/FIT, but do not exceed 16.0 ppg EMW. 9. Drill 6-1/8" hole to TD according to directional plan. Run LWD logging equipment with GR, resistivity, and density-neutron tools. 10. Run 3-1/2" 9.3#, L -80 SLHT liner on drill pipe with Baker liner top packer and hanger and cement liner. 11. Pressure test liner to 3500 psi. 12. Run 3-1/2" 9.3#, L-80 8rd EUE 8rd-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3500 psi. 13. Set TWC and ND BOPE. Install and pressure test production tree. 14. Secure well. Rig down and move out. " ~ 15. Handover well to Operations Personnel. ßti'<.J \ c~ ~IC:.\ ~ \'\ItcJ . ßt:-;yyV) \) I;;> 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An ,]Pf'/¡~dt/on fur d PLumt [0 Dill! mustc bc .1l.-.:.ompdfltë:J [IV c.YIc!] at the.' lÒ/¡'-:;'11"iI7~i /h.'177::>, L'\'Ü:pt rel'- an Itr~'!lI.:1IIC.iU}' {XI t/le ¡¡ltl? tIlt' cr;mmsS/(;rn and /,}cnt¡li2d If) t/¡¡~ app/¡catf,JiI: (J.1) rì çf.'lIcr2! de,,,cnprl,JII ,)t hO~ii tile'! operator pl.717S to d/5pose oi"r/"Ihn(l mud and cuttll7(lS and ù st.;ff,"ment ,)i n-hetl1t::r the tpädtor IfItf.>(1¿f::; tD (é'qur":,1 ,]ut!/¡J..-...ldr'Of1 un(]t;;'r .:'0 At.lC ,7.5' OliO le.'r an ,'Jlin/J/;:;¡r d6.o¡):..:1! ¡ì¡.'r:?rar/on If] th:J !I'2//., Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 1R pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 1R pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 1R- 36 for annular pumping of fluids occurring as a result of future drilling operations on lR pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. OR G NA- 1 R-36 PERMIT IT. DOC Page 60f 6 Printed: 21-No\I-O 1 <::::) ::0 ---- ~ ---- <::: ::t::... r-- ¡----- I-- I Vertical Origin: Horizontal Origin: I Mea~LJremenl Uni1s : North Reference: , -- I Dogleg severily . , Vertical Section Azimuth: I Vertical Section Description: Vertical Section Origin: ------- Proposal Data for 1 R-36 WP03 I I I ----- ----l i I I I ---- --'---1 ----------- Well Well H True North ------------ Degrees per 100 feel (US) 12035" Well 0 00 N,O.OO E -- Measured Incl. Azim. Vertical Northi ngs Eastings Vertical Dogleg I Depth Depth Section Rate I I lì ¡"lIj f 1)111) () 305 I) no IJ I.II N ( rJi) E ( n( I 3(1(1 1)1) ( (101) Ü 3u5 )IJU 1)0 0.1)11 N (I r)fJ E '-'.1.11.' 1),1)(10 .';'!)IIJUj Ii) I)OU ]1I::i,()Úf, -,,~.¡-; ::'-1 9ó N 3~JI~ W Ih <is ::' ,1.1(11.1 \ h ï:os 80 3 ~ .IU)O 355 0i:1I1 Inl~.5~ 31/5 ~-1 r,; II c:¡ '1- \\' : - -1.1) I 3,1/~:'\ 25659-1 6~.";>; I U.-II-I ::' 1(1) lJ' <i:'\ 1.61 N -1~ ~~ \\' l¡ 21.-1 I -1 ,jf/I) 1 y,-, I: 3-1 6-1 lJ;o;l I~ql-l 66 I ~ IFJ 1f/15\ 6~ ,,,, :'151.18E 11)3:-!-1.8' ( (¡Üf) ! :-:::'/:1(J.6~ (i-1 o}x I 13 -11-1 6~:3 1.1(' III:Pg -1~ N :':1) y -1 ~ [' I 1J6IN.:-! \ 1).')(11) 136-3 :'\0 ()-1 'J:-i I 13 -11-1 6~1J"i.61 lu~ ,E -II N :::'(1) :-, E I (,IJ:-:;y 8-1 1.1.1)\.11.1 ------ -- -- - - ---- ------- - I T12N R10E Sec.1ï - 606 FSL, 147 FWL () ---- Be.gin Dir @.20DQ'/J_OQit :_30Q.Oûft MD. 300.00ft TVD Increase in Dir Rate @ 3.025'f100ft: BOO.OOft MD 797.4ìft TVD \ Increase in Dir Rate @ 4.000"l100ft . 1678.80ft MD, 1617.58ft TVD \ \ ,~a,' @ 64.981" , 2565.94ftMD.2200.08ftTVD - Q) ~ .c ã Q) £:) 2500 - ro u t ~ Kuparuk River Unit North Slope, Alaska Kuparuk 1 R 1 R-36 WP03 lilll il.'\ fU'-". S". i. '~JI.\I.. .'4'11111 Total Depth 1367350ftMD.6897.t31ftTVD ~ .~ 5.",.1 1.-.'.;..1(1/1 0, "¡¡-.\.J,~ \. .'_,,,, J' I Fi ",/i "'. I '". ""I; C I .\L",d ilL"! I ..~..' (, (, I \J/,} 1'1 (I. h'I'" I. J \. _.'1 ¡ 1--' ~ I. 11.'\ Rhl[ .5". -,. .'I"~ rsL. .';~ç i III ~~ ~ ....~ Q'.o /';'C ~ú'o. ~ ""(5)$0 ~ 15>-r;. ;\'(5) 4;. ?' & ~ -?r:)) ~/ <9@ ~.... "'(5) ~) &..") ~. @ "69 ð. """"(5) 9'12 .9<9 "r - '~J vo. ?,' \~ ~ ..)0 'l;~" '0. ~<' °a Ue, í?o u> ~ ,S' , I'Q.~. 9~ . /Q 0..<:. 0..... 1'/.1 o-? 'r. . 6' ~ "0 , ,,? 6'00 C::?,... .~~ Vo '1.2 ~ 00 "?Q v1- <::> OóJ ~;:r 1'6' 1'0 ~J- I "0 .....? -> ¿'O . .), .9.... ,.5'Ó'/. Vo 7, I J- 'Oa ....~. ,;,-:.'.'"f\.. ( ~ /t..-. v /f-... ð ()- ------. -- (! S.!/hl Rl'l'';l,l (,[,I,~,'-',i II O. !lil"¡,I,J \, .'I.'I..'S I. II.' \ F; II.iF 'n.' - .',i,~ FSL. .'-' ~ç fill. i; :,000 - :5 ol) N I' £ ~ 5pE!~~Y-5UIl DRILLING SERVIC:E5 A Halliburton Company 7' 12-1~8. 1 ft r.m 6379.4ft T'iO---- ~, , 3 1/2" RHI. . - ----~ 13673.SI\ MO 1/.'\ Rh'l. S".. ,- -.\-If.\1.. .'rJfll/. .. G897.6ftTVO (ù rn u f.I) I 0 ~r;.,lp 1 ;nr.h := ?o:;nnFr OrlllOlJ~ì 2 ((, (¡9 (¡(18 I 5000 7 SOO 1000(' C:;prt,r'lro A7;mlltt't 1) n~~!i' (Trill'- Nnrth) 2::',00 Vartic~1 Saction (Wall) ~.~ S,.¡,I "'"-'.~JlIllI {I. I(/.'"s J,\ \. -'_"-i.;.~- E R",1;'J... I.:¡'.' I)ti/i 3 IlL' 136 7:~ Sft MD 6897 6f1 TVD - 10000 - 7~,OO ã: ~ v. i? - f,OOO E t: C Z - 2500 t= 0 a II"" (\ 'I 5 ~ - 0 .v 8 en T 121 J F: lIÆ S'õ(. 17 - t)1~lf, F:~,L 1-1/ FIN L I 0 Reference is True Nonn Scale 1men.= 250011 Eastings (Well) Sperry-Sun Drilling Services Proposal Data - 1 R-36 - 1 R-36 WP03 --r-~~ l-~~~~-r~!:n 1 0.00 0.00 2 30000 300.00 0.00 3 800.00' 500.00 10.00 4 1678.80 878.80 32 00 5 2565.94 887.14 6.!.98 6 13012.34 10446.40 64.98 7 13260.62: 248.281 64.98 ' 1 8' 13673.50 412.87 64.98 20 November, 2001 - 19:27 AzImuth 1,- TVD'¡ Northlngs (") (ft) (ft) 0.00 0.00 0.00 0.00 300.00 0.00 305.00 797.47 24.96 N' 355.00 1617.58 305.74 N 13.41 2200.09 951.67 N 13.41 6618.00 10159.64 N - --- - -. - - - -- 13.41 6723.00 103ì8.48 N 13.41 6897.61 10742.41 N Eastings I' Dogleg (ft) (" f1 OOft) 000 0.00 35.65 W 119.97 W 44.78 W 2151.28 E 2203.47 E 2290.27 E OR G NA. - 1 - 0.00 200 302 4.00 0.00 0.00, 0,00 A. BUild (" f1 000) 0.00 2.00 2.50 3.72 0.00 0.00 0.00 TooIface I VS (c12") : ("\ I eft) i 0.00 0.00 0.00 305.00 16.98 65.13 274.01: 29.54, 921.411 0.00 10384.89 0.00 10609.81 0.00 10983.84 DrillQuest C ::0 --- ~ --- :æ: ~ r-- Kuparuk River Unit North Slope, Alaska Kuparuk 1R, Slot 1R-36 1 R-36 WP03 Revised: 20 November, 2001 PROPOSAL REPORT 20 November, 2001 Surface Coordinates: 5991809.93 N, 539831.84 E (70'" 23' 18.8439" N, 149040' 33.6289" W) Surface Coordinates relative to Project H Reference: 991809.93 N, 39831.84 E (Grid) Surface Coordinates relative to Structure: 759.82 N, 6.13 E (True) Kelly Bushing: 88.00ft above Mean Sea Level SPEl""''-'k/-5iiun D ft 1 I- 1-1 N G seA v I t: != s A HalllCurton company Proposal Ref: pro9712 Sperry-Sun Drilling Services . Proposal Report for 1R-36 WP03 Revised: 20 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (Q 11 OOft) 0.00 0.000 0.000 -88 00 0.00 0.00 N 0.00 E 599180993 N 539831.84 E 0.00 100.00 0.000 0.000 12.00 100.00 0.00 N 0.00 E 5991809.93 N 539831.84 E 0,000 000 200.00 0.000 0000 112 00 200.00 0.00 N 0,00 E 5991809.93 N 539831.84 E 0.000 000 300.00 0.000 0.000 212.00 300.00 0.00 N 0.00 E 5991809.93 N 539831.84 E 0.000 000 Begin Dlr @ 2 000"/100ft . 300 OOft MD. 300 OOft TVD 400.00 2.000 305.000 311 98 399.98 1.00 N 143W 5991810.92 N 539830,41 E 2,000 068 500.00 4.000 305 000 411.84 499.84 4.00 N 5.72W 5991813.90 N 539826,10 E 2.000 272 C 600.00 6.000 305,000 511.45 599.45 9.00 N 1 2.86 W 5991818.86 N 539818.94 E 2.000 6.12 700.00 8.000 305.000 610 70 698.70 15.99 N 22.84 W 5991825.80 N 539808.92 E 2.000 10.88 ::a:. 800.00 10.000 305.000 709,47 797 47 24.96 N '35.65 W 5991834.70 N 539796.06 E 2.000 16.98 Increase In Dlr Rate @ 3025'"11 OOtt . --- 800 OOft MD. 797 47ft TVD c-) 900.00 11.598 318775 807.71 895.71 37.51 N 49.39 W 599184717 N 539782 25 E 3.025 26.38 ~ 1000.00 13.681 328.843 905.29 993.29 ,55.19 N 62.14 W 5991864.79 N 539769.41 E 3.025 41.02 1100.00 16.061 336.141 1001,94 1089.94 77.97 N 73.85 W 5991887,50 N 539757.57 E 3.025 60.85 ~ 1200.00 18.625 341.539 1097.39 1185.39 105.77 N 84.51 W 599 1915 25 N 539746.77 E 3.025 8583 1300.00 21 .307 345.647 1191.38 1279.38 138.53 N 94.07 W 5991947.95 N 539737.03 E 3025 115.87 r- 1400.00 24.066 348.863 1283.64 1371.64 176.14r-J 102.52 W 5991985.52 N 539728.39 E 3.025 150.90 1500.00 26.880 351.447 1373.91 1461 91 218.51 N 109.82 W 5992027.85 N 539720.86 E 3.025 190.81 1600.00 29.732 353572 1461.95 1549,95 265.52 N 115.96W 5992074.83 N 539714.47 E 3.025 235 50 1678.80 32.000 355.000 1529.58 1617.58 305.74 ~J 119.97 W 5992115.03N 539710.25 E 3.025 27401 Increase In Dlr Rate @ 4 000' 11 OOft . 1678.80ft MD. 1617.58ft TVD 1700.00 '32.740 355.773 1547.49 1635.49 317.06 N 120.88 W 5992126.34 N 539709 28 E 4.000 284 88 1734.13 '33.941 356.954 1576.00 1664,00 335.77 N 122.06 W 5992145.05 N 539707.99 E 4000 302.94 Base Permafrost 1800.00 36.288 359.038 1629.88 1ì17.88 373.63 N 123,37 W 5992182.90 N 539706.48 E 4.000 339,70 1900.00 39.911 1.789 1708.57 1796.57 435.31 N 122.86 W 5992244.58 N 539706.66 E 4.000 400.12 2000.00 43.589 4.151 1783 17 1871.17 501 .79 N 119.37 W 5992311 .07 N 539709.80 E 4.000 465.87 2100.00 47.310 6.212 1853.31 1941.31 572.73 N 112.89 W 5992382.05 N 539715,90 E 4.000 5'36.61 2200,00 51,064 8.039 1918.66 2006.66 647.81 t-J 103.47 W 5992457.18 N 539724.92 E 4.000 612 00 2300.00 54.843 9.681 1978.90 2066.90 ì26.65 N 91.15W 5992536.08 N 539736.82 E 4.000 691 67 2400.00 58.643 11.177 2033.73 2121 ì3 80887 "J 76.00 W 5992618.38 N 539751.54 E 4.000 775 24 2500.00 62.458 12.557 2082.89 2170.89 894.06 N 58.07 W 5992703.67 N 539769.00 E 4.000 862.30 2565.94 64.981 13.414 2112.09 2200.09 951.67 N 44.78 W 5992761 .35 N 539781.99 E 4.000 921.41 End Dir. Start Sail @ 64 981' . 2565. 94ftM D .2200. 08ftTV D 2600 00 G..1 981 1341../ 2 1 26 <19 221../.49 981.69 N 37.62 W 5992791.41 N 539788.99 E 0.000 952 27 ----- --- ------ ----- - ----- - ---- - --- -- .- - --- 20 November, 2001 - 19:26 Page 2 of 9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services . .. Proposal Report for 1R-36 WP03 Revised: 20 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (° /1 OOft) 2700.00 64.981 13.414 2168.78 2256.78 1069.84 N 16.60 W 5992879.66 N 539809.54 E 0.000 1042 86 2800.00 G4.981 1 3,4 14 2211.07 2299.07 1157.98N 4.42 E 5992967.92 N 539830.09 E 0.000 113345 2900 00 64.981 1 3.4 14 2253.36 2341.36 1246.12 N 25.44 E 5993056.17 N 539850.64 E 0.000 1224.04 3000.00 64.981 13.414 2295.65 2383.65 1334.27 N 46 46 E 5993144.43 N 539871.20 E 0.000 1314.63 3100.00 64.981 13.414 2337 94 2425.94 1422.41 N 6749 E 5993232.68 N 539891.75 E 0.000 1405.22 3200.00 64 .981 13.414 2380.24 2468.24 1510.56 N 88,51 E 5993320.94 N 539912.30 E 0.000 1495.81 3300.00 64.981 13.414 2422.53 2510 53 1598.70 N 109.53 E 5993409.19 N 539932.85 E 0.000 1586.40 3400.00 64.981 13.414 2464.82 2552.82 1686.85 N 130.55 E 5993497.45 N 539953.41 E 0000 167699 <:::) 3500.00 64.981 13.414 2507.11 2595.11 177499 N 15157E 5993585.71 N 539973.96 E 0.000 1767 58 3600.00 64.981 13.414 2549.40 2637.40 186314 N 172,60 E 5993673.96 N 539994.51 E 0.000 1858.18 ~ 3700.00 64.981 1 3.4 14 2591.69 2679.69 1951.28 N 193.62 E 5993762.22 N 540015.06 E 0.000 1948.77 s:;-:) 3759.84 64,981 13.414 2617.00 2705.00 2004.03 N 206.20 E 5993815.03 N 540027.36 E 0,000 2002.98 Top Ugnu 3800.00 64.981 13.414 2633.98 2721. 98 2039 43 N 21464 E 5993850.47 N 540035.62 E 0.000 2039.36 --- 3900.00 64.981 1 3.414 2676.27 2764.27 2127.57 N 235 66 E 5993938.73 N 540056.17 E 0.000 212995 ;ë::: 4000.00 64,981 13.414 2718.57 2806.57 2215.72 N 256,69 E 5994026,98 N 540076.72 E 0.000 2220.54 ~ 410000 64.981 13.414 2760.86 2848.86 2303.86 N 277.71 E 5994115.24 N 540097.27 E 0.000 2311 .13 r-- 4200,00 64.981 13.414 2803.15 2891.15 2392,01 N 298.73 E 5994203.50 N 540117.82 E 0.000 2401.72 4300.00 64.981 13.414 2845.44 2933.44 2480.15 N 319.75 E 5994291.75 N 540138.38 E 0.000 2492.31 4400.00 64,981 13.414 2887.73 2975.73 2568,30 N 340.77 E 5994380.01 N 540158.93 E 0.000 2582.90 4500.00 64.981 13.414 2930.02 3018.02 2656.44 N 361.80 E 5994468.26 N 540179.48 E 0.000 2673.49 4600,00 64.981 13.414 2972.31 3060.31 2744.59 N 382.82 E 5994556.52 N 540200.03 E 0.000 2764.08 4700 00 64.981 13.414 3014.60 3102.60 2832.73 f\I 403.84 E 5994644.77 N 540220.59 E 0.000 2854.67 4800.00 64.981 13.414 3056.90 3144.90 2920.88 N 424.86 E 5994733.03 N 540241 .14 E 0.000 294526 4900.00 64.981 1 3.4 14 3099.19 3187.19 3009.02 N 445.89 E 5994821 .28 N 540261 69 E 0.000 3035.86 5000.00 64.981 13.414 3141.48 3229.48 3097. 1 7 N 466.91 E 5994909.54 N 540282.24 E 0.000 3126.45 5100 00 64.981 13.414 3183.77 3271.77 3185.31 N 487.93 E 5994997.80 N 540302.80 E 0.000 3217.04 5131.28 64.981 13.414 3197.00 3285.00 3212.89 N 494.51 E 5995025.40 N 540309.23 E 0.000 324538 Base Ugnu 5200 00 64.981 13.414 3226.06 3314.06 3273.46 N 508.95 E 5995086.05 N 540323.35 E 0.000 3307.63 5300 00 64.981 13.414 3268.35 3356.35 3361.60 N 529.97 E 5995174.31 N 540343.90 E 0.000 339822 5384.29 64.981 13414 3304.00 3392,00 3435.90 N 547.69 E 5995248.70 N 540361.22 E 0.000 3474.58 Top West Sak -------------------------------- ----------.--- -------------.------- ---- -- ---- - ------ ----- ------ 20 November, 2001 . 19:26 Page 30f9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for 1R-36 WP03 Revised: 20 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (~/1 OOft) 5400.00 64.981 13.414 3310.64 3398.64 3449.75 I'll 551.00 E 5995262.56 N 540364.45 E 0.000 348881 5500.00 64.981 13.414 3352.93 3440.93 3537.89 N 572.02 E 5995350.82 N 540385.01 E 0.000 357940 5600.00 64.981 13.414 3395.23 3483.23 3626.04 N 593.04 E 5995439.07 N 540405.56 E 0.000 3669.99 5700.00 64.981 13.414 3437.52 3525.52 3714.18N 614.06 E 5995527.33 N 540426.11 E 0.000 3760.58 5800.00 64.981 13.414 3479.81 3567,81 3802.33 N 635.09 E 5995615.58 N 540446.66 E 0.000 3851.17 5900.00 64.981 13.414 3522.10 3610.10 3890.47 N 656.11 E 5995703.84 N 540467.22 E 0.000 3941 76 6000.00 64.981 13.414 3564.39 3652.39 3978.62 N 677.13 E 5995792.10 N 540487,77 E 0.000 4032.35 6100.00 64.981 13.414 3606.68 3694.68 4066,76 N 698.15 E 5995880.35 N 540508.32 E 0.000 4122.95 C 6200.00 64.981 13.414 3648.97 3736.97 4154.90N 719.17E 5995968.61 N 540528.87 E 0.000 4213.54 ~ 6300,00 64 981 13.414 3691.27 3779.27 4243.05 N 740.20 E 5996056.86 N 540549.43 E 0.000 4304 13 -- 6400.00 64.981 13.414 3733.56 3821,56 4331.19 N 761.22 E 5996145.12 N 540569.98 E 0000 4394.72 ~ 6500.00 64.981 13.414 3775.85 3863.85 4419.34 N 782.24 E 5996233.37 N 540590.53 E 0.000 4485.31 6600.00 64.981 13.414 3818.14 3906.14 4507.48 N 803.26 E 5996321.63 N 540611.08 E 0.000 4575.90 -- 6700.00 64,981 13.414 3860.43 3948.43 4595.63 N 824.29 E 5996409.88 N 540631.63 E 0000 4666.49 :æ: 6722.63 64.981 13.414 3870.00 3958.00 4615.58 N 829.04 E 5996429.86 N 540636.29 E 0.000 4686.99 Base West Sak ~ 6800.00 64.981 13.414 3902.72 3990.72 4683.77 N 845.31 E 5996498 14 N 540652.19 E 0.000 475708 r-- 6900.00 64.981 13.414 3945.01 4033.01 4771.92 N 866.33 E 5996586.40 N 540672.74 E 0000 4847.67 7000.00 64.981 13.414 3987.30 4075.30 4860.06 N 887.35 E 5996674.65 N 540693.29 E 0.000 4938.26 7100.00 64,981 13.414 4029.60 4117.60 4948.21 N 908.37 E 5996762.91 N 540713.84 E 0.000 5028.85 7195.54 64 981 13.414 4070.00 4158.00 5032.42 N 928.46 E 5996847.23 N 540733.48 E 0.000 5115.40 9 5/8" Casing 7200.00 64.981 13.414 4071.89 4159.89 5036.35 N 929.40 E 5996851.16 N 540734.40 E 0.000 5119.44 7300.00 64.981 13.414 4114,18 4202.18 5124.50 N 950.42 E 5996939.42 N 540754.95 E 0000 5210.03 7400.00 64.981 13.414 4156.47 4244.4 7 5212.64 N 971.44 E 5997027.67 N 540775.50 E 0000 5300.63 7500.00 64.981 13.414 4198.76 4286.76 5300.79 N 992.46 E 5997115.93 N 540796.05 E 0.000 5391 .22 7600.00 64 981 13.414 4241.05 4329.05 5388.93 N 1013.49 E 5997204.19 N 540816.61 E 0000 5481.81 7700.00 64.981 13.414 4283.34 4371.34 5477.08 N 1034.51 E 5997292.44 N 540837.16 E 0.000 5572 40 7800.00 64.981 13.414 4325.63 4413.63 5565.22 N 1055.53 E 5997380.70 N 540857.71 E 0.000 5662,99 7900.00 64.981 13.414 4367.93 4455.93 5653.37 N 1076.55 E 5997468.95 N 540878.26 E 0.000 5753.58 8000.00 64.981 13.414 4410,22 4498 22 5741.51 N 1097.57 E 5997557.21 N 540898.82 E 0.000 5844.17 8100.00 64 981 13.414 4452.51 4540.51 5829.66 N 1118.60E 5997645.46 N 540919.37 E 0.000 5934.76 -------- ---------- ------ --- -------- - 20 November, 2001 - 19:26 Page 40f9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for 1R-36 WP03 Revised: 20 November, 2001 North Slope. Alaska Kuparuk River Unit Kuparuk 1R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 8200.00 64.981 13.414 4494.80 4582.80 5917.80 N 1139.62 E 5997733.72 N 540939.92 E 0.000 6025.35 8300.00 64.981 13.414 4537.09 4625.09 6005.95 N 1160.64 E 5997821.97 N 540960.47 E 0.000 6115.94 8400.00 64.981 13.414 4579.38 4667.38 6094.09 N 1181.66 E 5997910.23 N 540981.03 E 0.000 6206 53 8500.00 64,981 13.414 4621.67 4709.67 6182.24 N 1202.69 E 5997998.49 N 541001 .58 E 0.000 6297.12 8600.00 64.981 1 3,4 14 4663.96 4751,96 6270 38 N 1223.71 E 5998086.74 N 541022,13 E 0.000 6387.72 8700.00 64.981 13.414 4706.26 4794.26 6358 53 N 1244.73 E 5998175.00 N 541042.68 E 0000 6478 31 8800.00 64.981 13.414 4748.55 4836.55 6446,67 N 1265.75 E 5998263.25 N 541063.24 E 0.000 6568 90 8900.00 64.981 13.414 4790.84 4878.84 6534 82 N 1286.77 E 5998351.51 N 541083.79 E 0.000 665949 9000.00 64.981 13.414 4833.13 4921.13 6622.96 N 1307.80 E 5998439.76 N 541104.34 E 0.000 6750.08 9100.00 64.981 13.414 4875.42 4963.42 6711.11 N 1328,82 E 5998528.02 N 541124.89 E 0.000 6840.67 C 9200.00 64.981 13.414 4917.71 5005.71 6799.25 N 1349.84 E 5998616.27 N 541145.44 E 0.000 6931.26 ::J:J 9300,00 64.981 13.414 4960.00 5048.00 6887,40 N 1370.86 E 5998704.53 t~ 541166.00E 0.000 7021.85 ...... 9400.00 64.981 13.414 5002.29 5090.29 6975.54 N 1391.89 E 5998792.79 N 541186.55 E 0.000 7112.44 ~ 9500.00 64.981 13.414 5044.59 5132.59 7063.69 N 1412.91 E 5998881 .04 N 541207.10 E 0.000 7203.03 9600.00 64.981 13.414 5086.88 5174.88 7151.83 N 1433.93 E 5998969.30 N 54122ì.65 E 0.000 7293.62 ---. ~ 9700.00 64.981 13.414 5129.17 5217.17 7239.97 N 1454.95 E 5999057.55 N 541248.21 E 0.000 7384 21 9800.00 64.981 13.414 5171 .46 5259.46 7328.12 N 1475.97 E 5999145.81 N 541268.76 E 0000 7474.80 9900.00 64.981 13.414 5213.75 5301.75 7416.26N 1497.00 E 5999234.06 N 541289.31 E 0,000 7565.40 ........ 10000.00 64.981 13.414 5256.04 5344.04 7504.41 N 1518.02E 5999322.32 N 541309.86 E 0.000 7655 99 10100.00 64.981 13.414 5298.33 5386.33 7592.55 N 1539.04 E 5999410.57 N 541330.42 E 0.000 774658 10200.00 64.981 13.414 5340.62 5428.62 7680.70 N 1560.06 E 599949883 N 541350.97 E 0.000 7837,17 10300.00 64.981 13.414 5382.92 5470.92 7768.84 N 1581.09 E 5999587.09 N 541371.52 E 0.000 7927.76 10400.00 64.981 13.414 5425.21 5513.21 7856.99 N 1602.11 E 5999675.34 N 541392.07 E 0.000 8018 35 10500.00 64.981 13.414 5467.50 5555.50 7945.13N 1623.13 E 5999763.60 N 541412.63 E 0.000 8108.94 10600.00 64.981 13.414 5509.79 5597.79 8033.28 N 1644.15 E 5999851.85 N 541433.18 E 0.000 8199.53 10700.00 64.981 13414 5552.08 5640.08 8121.42 N 1665.17E 5999940.11 N 541453.73 E 0.000 8290. 12 10800.00 64.981 13.414 5594.37 5682.37 8209.57 N 1686.20 E 6000028.36 N 541474.28 E 0.000 8380.71 10900.00 64.981 13.414 5636.66 5724.66 8297.71 N 1707.22 E 6000116.62 N 541494.84 E 0.000 8471.30 11000.00 64.981 13.414 5678,95 5766.95 8385.86 N 1728.24 E 6000204.87 N 541515.39 E 0.000 8561.89 11100.00 64.981 1 ~l4 14 5721.25 5809.25 8474.00 N 1749.26 E 6000293.13 N 541535.94 E 0.000 865249 -------- ------ ----------- -------- -- --- -- 20 November, 2001 - 19:26 Page 50f9 Dril/Quest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for 1 R-36 WP03 Revised: 20 November, 2001 North Slope. Alaska Kuparuk River Unit Kuparuk 1 R Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth De pth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (° 11 OOft) 11200.00 64,981 13414 5763.54 5851 54 8562.15 N 17ìO.29 E 6000381.39 N 541556.49 E 0000 8743.08 11300.00 64.981 13414 5805.83 5893.83 8650.29 N 1791.31 E 6000469.64 N 541577.05 E 0.000 8833.67 11400.00 64.981 13414 5848.12 5936.12 8738.44 N 1812.33 E 6000557 90 N 541597.60 E 0.000 8924.26 11432.82 64.981 13.414 5862.00 5950.00 8767.37 N 1819.23 E 6000586.86 N 541604.34 E 0.000 8953.99 C 70 -=.- 11500.00 64.981 13.414 5890.41 5978.41 8826.58 ~~ 1833.35 E 6000646.15 N 541618.15 E 0.000 901485 11600.00 64.981 13.414 5932.70 6020,70 8914.73 N 1854.37 E 6000734.41 N 541638.70 E 0.000 9105.44 11700.00 64.981 13.414 5974.99 6062.99 9002.87 N 1875.40 E 6000822.66 N 541659.25 E 0.000 9196,03 11800.00 64.981 13.414 6017.28 6105.28 9091.02 N 1896.42 E 6000910.92 N 541679.81 E 0.000 9286.62 11822.97 64.981 13.414 6027,00 6115,00 9111.27 N 1901.25 E 6000931 .19 N 541684.53 E 0.000 9307.43 Top HRZ <::) 11900.00 64.981 13.414 6059.58 6147.58 9179.16N 191 7.44 E 6000999.18 N 541700.36 E 0.000 9377 21 ::0 12000,00 64.981 1 3.4 14 6101.87 6189.87 9267.31 ~J 1938.46 E 6001087.43 N 541720.91 E 0.000 9467 80 1210000 64.981 1 3.4 14 6144.16 6232.16 9355.45 N 1959.49 E 6001175.69 N 541741.46 E 0000 9558.39 ---- 12139.82 64.981 13.414 6161.00 6249.00 9390.55 N 1967.86 E 6001210.83 N 541749.65 E 0.000 9594 47 Base HRZlTop Kalubrk ~ 12200,00 64.981 13.414 6186.45 6274.45 9443.60 N 1980.51 E 6001263.94 N 541762.02 E 0000 9648.98 ---- 12300.00 64.981 13.414 6228.74 6316.74 9531.74 N 2001.53 E 6001352.20 N 541782.57 E 0.000 9739,57 ==== 12388.10 64 981 13.414 6266.00 6354.00 9609.40 N 2020.05 E 6001429.95 N 541800.68 E 0.000 981939 K I/Lower Kalublk ~ 12400.00 64.981 13.414 6271.03 6359.03 9619.89 N 2022.55 E 6001440.45 N 541803.12 E 0.000 9830.17 ......... 1 2448, 1 0 64.981 13.414 6291.37 6379.37 9662.28 N 2032.66 E 6001482.90 N 541813.01 E 0.000 9873.74 7" Casing 12500 00 64.981 13.414 6313.32 6401.32 9708.03 N 2043.57 E 600152871 N 541823.67 E 0.000 9920.76 12600.00 64.981 13.414 6355.61 6443.61 9796 18 N 2064.60 E 6001616.96 N 541844.23 E 0.000 1001135 12693.13 64.981 13.414 6395.00 6483.00 9878.26 N 2084 17 E 6001699.16 N 541863.37 E 0.000 10095.71 Top Kuparuk 12700 00 64.981 13.414 6397.91 6485.91 9884.32 N 2085.62 E 6001705.22 N 541864.78 E 0.000 1 0 1 0 1 94 12800.00 64.981 13.414 6440.20 6528.20 9972.47 N 2106,64 E 6001793.48 N 541885.33 E 0.000 10192.53 12900.00 64.981 13.414 6482.49 6570.49 10060.61 N 2127.66 E 6001881.73 N 541905.88 E 0000 10283 12 13000.00 64.981 13.414 6524.78 6612,78 10148.76 N 2148.69 E 6001969.99 N 541926.44 E 0.000 10373.71 13012.34 64.981 13.414 6530.00 6618.00 10159.64 N 2151.28 E 6001980.88 N 541928.97 E 0.000 10384.89 Top C 1 Target 13047.81 64.981 13.414 6545.00 6633.00 10190.90 N 215874 E 6002012.18 N 541936.26 E 0.000 10417.02 TopS 13100.00 64.981 13.414 6567.07 6655.07 10236.90 N 2169.71 E 6002058.24 N 541946.99 E 0.000 10464,30 13200.00 64.981 13.414 6609.36 6697.36 10325.04 N 2190.73 E 6002146.50 N 541967,54 E 0.000 10554.89 13241.71 64.981 13.414 6627.00 6715.00 10361.81 N 2199.50 E 6002183.31 N 541976.11 E 0.000 10592.67 Top A4 -~---- ------------ ------------ --- --- --------- ------- - - - - -- --- - 20 November, 2001 - 19:26 Page 60f9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 1R-36 WP03 Revised: 20 November, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Inct. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 13260.62 64.981 13.414 6635.00 6723.00 10378.48 N 2203.47 E 13300.00 64.981 13.414 6651 65 6739.65 1 04 1 3. 1 9 N 2211.75E 13364.66 64.981 13.414 6679.00 6767.00 10470.19 N 2225.35 E 13400.00 64 981 13.414 6693 94 6781.94 10501.33 N 2232.77 E 13473.43 64.981 13.414 6725.00 6813.00 10566.06 N 2248.21 E C :x:J --- C) --- ~ All data is in Feet (US) unless otherwise stated. Directions and coordinates are relatjve to True North. ~ Vertic.al depths are relatìve to Well. Northings and Eastings are relative to Well. r-- The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 12.035': (True). 13500.00 64.981 13600.00 64.981 13673.50 64.981 13.414 13.414 13414 6736.24 6778 53 6809 61 6824.24 6866.53 6897.61 10589.48 N 10677.62 N 10742.41N 2253.80 E 2274.82 E 2290.27 E Based upon Minimum Curvature type calculations. at a Measured Depth of 13673.50ft.. The Bottom Hole Displacement is 10983.8411., in the Direction of 12.0350 (True). ----- -- ------ 20 November. 2001 - 19:26 Page 7 of 9 Global Coordinates Northings Eastings (ft) (ft) 6002200.00 N 6002234.75 N 6002291.82 N 6002323,01 N 6002387.82 N 6002411 .26 N 6002499.52 N 6002564.39 N ------------- 541980.00 E 541988.09 E 542001.38 E 542008.65 E 542023.74 E 542029.20 E 542049 75 E 542064.86 E 8:. fíI North Slope, Alaska Kuparuk 1 R Dogleg Rate (° 11 OOft) Vertical Section Comment 0,000 1060981 TopA3 Target - A3 Sand. 15000 Radius. Current Target 0.000 10645.48 0.000 10704 06 Top A2 0.000 10736.07 0.000 10802.60 Base Kuparuk 0.000 10826.66 0,000 1091726 0.000 10983.84 Total Depth 13673 50ttMD,6897 61ftTVD 3 1/2" Liner ------------ ------ DrillQuest 2.00.09.006 - - -- -- - ------ --- - Sperry-Sun Drilling Services Proposal Report for 1 R-36 WP03 Revised: 20 November, 2001 Kuparuk River Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 300.00 300.00 0.00 N 0.00 E Begin Dir @ 2.000~/100ft: 300.00ft MD. 300.00ft TVD 800.00 797.47 24.96 N 35,65 W Increase in Dir Rate @ 3.025'/100ft: 800.00ft MD. 797.47ft TVD 1678.80 1617.58 305.74 N 119.97 W Increase in Dir Rate @ 4,OOoo/100ft: 1678.80ft MD, 1617 58ft TVD 2565.94 2200.08 951.67 N 44,79 W End Dir, Start Sail @ 64.981' : 2565.94ftMD.2200.08ftTVD C 13673.50 6897.61 10742,41 N 2290.27 E Total Depth: 13673.50ftMD,6897.61ftTVD :::x:J Formation Tops -- c-) Formati on Plane Profile Penetration Poi n t -- (Below Well Origin) Measured Vertical Sub-Sea ::æ: Sub-Sea Dip Dip Dir. Depth Depth Depth Northings Eastings Formation Name ~ (ft) Deg. Deg. (ft) (ft) (ft) (ft) (ft) r- 1576.00 0.000 0305 1734.13 1664.00 1576,00 335.77 N 122.06 W Base Permafrost 2617.00 0.000 0.305 3759.84 2705.00 2617,00 2004.03 N 206.20 E Top Ugnu 3197.00 0.000 0.305 5131 28 3285.00 3197.00 3212.89N 494.51 E Base Ugnu 3304.00 0.000 0.305 5384.29 3392.00 3304.00 3435.90 N 547,69 E Top West Sa" 3870.00 0.000 0.305 6722.63 3958.00 3870.00 4615.58 N 829.04 E Base West Sak 5862.00 0.000 0.305 11432.82 5950.00 5862.00 8767.37 N 1819.23 E C 70 6027.00 0.000 0.305 11822.97 6115.00 6027 00 9111 .27 N 1901.25 E Top HRZ 6161.00 0.000 0.305 12139.82 6249.00 6161.00 9390.55 N 1967.86 E Base HRZlTop Kalubik 6266.00 0.000 0305 12388.10 6354.00 6266,00 9609.40 N 2020.05 E K 1/Lower Kalubik 6395.00 0.000 0.305 12693.13 6483.00 6395.00 9878.26 N 2084.17 E Top Kuparuk 6530.00 0.000 0.305 1301 2.34 6618.00 6530.00 10159.64 N 2151.28 E Top C 1 Target 6545.00 0.000 0.305 13047.81 663.3.00 6545.00 10190.90 N 2158.74 E TopB 6627.00 0.000 0.305 13241 .71 6715.00 6627.00 10361.81 N 2199.50 E Top A4 6635.00 0.000 0.305 13260.62 6723.00 6635 00 10378.48 ~~ 2203.47 E Top A3 6679.00 0.000 0.305 13364.66 6767.00 6679.00 10470.19 N 2225.35 E Top A2 -- --- -------- 20 November, 2001 . 19:26 Page 8 of9 -- ----- -- . North Slope. Alaska Kuparuk 1 R DrillQuest 2.00.09.006 Kuparuk River Unit Sperry-Sun Drilling Services Proposal Report for 1R-36 WP03 Revised: 20 November, 2001 Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) Northings (ft) Eastings (ft) Formation Name Formation Tops (Continued) 6725 00 0.000 0.305 13473.43 681'3.00 Casing details C ::0 ---- ~ ---- :æ: ::t:=.. r-- Targets associated with this wellpath Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Suriace> <Suriace> < Suriace> <Surface> <Surface> <Surface> 7195.54 12448.10 13673.50 4158.00 6379.37 6897.61 Target Name A3 Sand C 1 Revised C 1 Sand ----------- 20 November, 2001 - 19:26 6725.00 10566.06 N 2248.21 E Base Kuparuk Casing Detail 9 5/8" Casing 7" Casing 3 1l2" Liner Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 6723.00 10378.48 N 220347 E Mean Sea Level/Global Coordinates: 6635.00 6002200.00 N 54 1980 00 E Geographical Coordinates: 70e 25'00.9213" N 149~ 39' 290165" W 6618,00 10162.24 N 2152.17 E Mean Sea Level/Global Coordinates: 6530.00 6001983.49 N 541929.85 E Geographical Coordinates: 70" 24' 58.7946" N 149" 39' 30.5227" W 6618.00 10258.61 N 2177 84 E Mean Sea Level/Global Coordinates: 6530.00 6002080.00 N 54195500 E Geographical Coordinates: 70" 24' 59.7424" N 149" 39' 29,7694" W -- - --- -- -------- ----- Page 90f9 8-:.' ~ North Slope, Alaska Kuparuk 1 R Target Target Shape Type Circle Current Target POint Circle Current Target ---- - - ----- DrillQuest 2.00.09.006 Sperry-Sun A.nticollision Report Compan)': field: Reference Site: Reference Well: Reference Wellpalh: Phillips Alaska Inc. Kuparuk River Unit Kuparuk 1 R Pad 1 R-36 1 R-36 Date: 11/21/2001 Time: 14:54:30 Page: Co-ordinatel'NE¡ Reference: Vertical InTI I Reference: Well: 1R-36, True North 1 R-36 @ 88' ASL 88.0 GLOBAL SCAN APPLIED: A.II wellpaths \\ilhin 200'+ 100/1000 of reference Interpolation I\lethod: MD Intenal: 50.0 ft Deplh Range: 43.9 to 13672.9 ft l\1aximum Radius: 1562.9 ft Reference: Error 1\10del: Scan 1\1 ethod: Error Surface: Db: Oracle Plan: 1 R-36 WP03 & NOT PLANNED PROORAI ISCW SA Ellipse Trav Cytinder North Ellipse T Casing Casing Points 1\10 nTI Diameter Hole Size Name ft ft in in 7216.1 4166.8 9.625 12.250 95/8" 12416.8 6366.4 7.000 8.500 7" 13629.3 6879.2 3.500 6.125 3' " ,2 Plan: 1 R-36 WP03 Date Composed: 11/19/2001 \"crsion: 1 Principal: Yes Tied-to: From Well Ref. Point Swnmar)' <---------------------- Orrset \\'ellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allo\\able Site Well Wellpath 1\10 1\10 Distance ,.\ rea De,'iation Warning ft ft ft ft ft East Ugnu #1 East Ugnu # 1 Ugnu #1 V2 Plan: Plan 5911.5 3600.0 74.6 0.0 74.6 Pass: Minor 1/100 Kuparuk 1 R Pad 1R-12 1R-12V1 1157.9 1150.0 305.7 19.2 286.6 Pass: Major Risk Kuparuk 1 R Pad 1R-13 1R-13V1 399.4 400.0 30.8 7.8 22.9 Pass: Major Risk Kuparuk 1 R Pad 1R-14 1R-14V1 447.5 450.0 91.3 8.5 82.8 Pass: Major Risk Kuparuk 1 R Pad 1R-15 1R-15 V1 397.2 400.0 149.8 8.6 141.1 Pass: Major Risk Kuparuk 1 R Pad 1R-16 1R-16V1 396.1 400.0 210.5 7.9 202.6 Pass: Major Risk Kuparuk 1 R Pad 1R-17 1 R-17 V1 950.4 900.0 343.8 20.2 324.1 Pass: Major Risk Kuparuk 1 R Pad 1R-18 1R-18VO 1935.9 1850.0 226.2 54.1 176.1 Pass: Major Risk Kuparuk 1 R Pad 1 R-19 1 R-19 VO 250.0 250.0 92.7 6.3 86.4 Pass: Major Risk Kuparuk 1 R Pad 1R-19 1R-19A V2 250.0 250.0 92.7 6.3 86.4 Pass: Major Risk Kuparuk 1 R Pad 1 R-20 1 R-20 V1 502.6 500.0 65.5 12.4 53.2 Pass: Major Risk Kuparuk 1 R Pad 1 R-21 1 R-21 V1 650.7 650.0 19.1 13.4 5.6 Pass: Major Risk Kuparuk 1 R Pad 1 R-22 1 R-22 V1 589.8 600.0 120.0 13.9 106.2 Pass: Major Risk Kuparuk 1 R Pad 1 R-22 1 R-22A VO 589.8 600.0 120.0 10.9 109.2 Pass: Major Risk Kuparuk 1 R Pad 1 R-23 1 R-23 V1 730.1 750.0 187.9 15.7 172.3 Pass: Major Risk Kuparuk 1 R Pad 1 R-32 1 R-32 VO 250.0 250.0 76.7 4.8 71.9 Pass: Major Risk Kuparuk 1 R Pad 1 R-33 1 R-33 VO 1824.3 1800.0 75.9 45.8 33.4 Pass: Major Risk Kuparuk 1 R Pad 1 R-34 1 R-34 V1 550.4 550.0 16.0 9.6 6.4 Pass: Major Risk Kuparuk 1 R Pad 1 R-35 Rig - 1 R-35 V23 398.3 400.0 59.8 7.5 52.2 Pass: Major Risk O~ G NA- =~=~ -)0 --"38 - 0 270 W -3R -50 9J -II' III.""" """',,, ,.... ',1_.1 ., ~ ~1 ,- - ". .,. . . ,", ¡.,.,", "II. 'II ,.. , ,", lR-~O(lR-20, Fn)!TI 0 ~(JO 6CH) 70n ~oo 1000 \500 ~500 3500 4500 :'500 1, 1, ~ 6~00 0 \\\\t-... 7,00 - ~-~'.... - \\t-:" <)~OO , &F " '.1"'-:,. 11,00 ~ ~ 'II -, -. I ~ .. ( 0 SJ~~'O ->J . .. \' _1'1 ¡ /. /' ' 1-- ..' " / / , 1/ i .,:,,-, , " " '" ........ "ì. - '. ''', "'" C~)h\ur T"I\ID 500 600 700 son 1000 1:'01.1 ~50(Ì 350n 4501.1 5500 6500 7:)00 9500 1\500 I 351.1n I-WOO 25 " , , ~ \ '. \ , ""... ,fJO , , , , I) 13 25 . "" I 20 1:; ~ ~:. ~.11 , ",.", 1111"' 11"'''' J I . 'I " ': I ~ I I ' 'i I. I . '\¡,. J r, I ,~~ I' I 1"0111:' ,J 'J> r: J I Ii. ,'~ If, .J ../\ I I J I 1-".'." ...1 I. ¡"II Tra\"elling C~hndor MinlUlh 'Tf'O+AZ"ldërìfe~ t~NÄ :parallon [25ft/inl ~ . "! '.. "" ~ . I J''II "oj I - ~ "..' 11- .. 11- "I,H - II I II. I' 1.1..~..toC.,~ - Illr'.«lh \!,~,,o',,~ -- II< 1',11- I", '.I.~. 10(,.", I'" I" I I" I' \1." r ~. ~ '" I', I'" I " \I.. . ~.,Ir. - l.:.c I',IJ., I~\' "I'r''''"'~ - H "'.',IR=",'I'PIJ.1r. - IH.I I'" ~II '.I_rlk.~ - I~ ":IIf< ~"'I '.1 rrl',,~ II' .: Ilk ::', ,t'r r toI.,,, - 1¡;':;,It.:~il\l~d'L'~ I ~ '.' L .o, i:, "I,., , tI '. .. 1 ~ ,i. 1 ~ ; \, ",I 'r .. ... L ~ It- ....., I R i L' ".t " . ~ , .. - II ,. R."L d. "'I,,,t'.,~ -I".. - II\~'\I'I" - '? ',,", .¡:... "\'1" '""1''''1 ','I" " I I. n. ,,\, I ',I I .11 ,~ T .1' rl .." 1.1,., " :' ~'I. I" I ~I I" I" I"'," 1:'11' '" ~ I ' ~ J I I ., '" 1 "'I \ '" ,. 1- : 1"1 I I'" 11I""d : jll\-M 'I" ... I'"I: " .. ." I I"':> ', : 1 R-36 DrillinQ Hazards Summary 12-1/411 Hole / 9-5/8" Casina Interval Event Conductor Broach Well Collision Hydrate gas G ravel and sand sloughing Shoe Fracture/Lost Returns during cement job Risk Level Low Moderate Moderate Low Moderate 8-1/2" Hole /7" Casina Interval Event Shale stability in HRZ and K-1 intervals High ECD and swabbing if higher MW is required Hole cleaning in long, high angle tangent Drilling too deep into possibly elevated pressure of Kuparuk sands. Risk Level Moderate Low Moderate Moderate 6-1/8" Hole /3 1/2" Liner Interval Event Drill into higher than anticipated reservoir pressure. Hole cleaning in long, high angle tangent Barite sag if higher mud weight are required. Risk Level Low Low Low I M iti~ation Strate~y Set 120' of conductor (instead of 80') and monitor cellar continuously during interval. Careful well planning and surveying, adherence to anti-collision policy. Use coldest water available to mix in mud to keep it cool. Elevated mud viscosity from spud; Hi dens sweeps. Reduced pump rates, and lightweight tail cement I M iti~ation Strate~y Control with higher MW and proper drilling practices. Control mud rheology closely, and monitor surge/swab pressures with PWD tool. Pump out on trips as necessary. Good drilling practices. Monitor GR/Res logs closely and work closely with geologist to ensure 7" casing point is placed as planned. After open-hole LOT, risk of drilling ahead may be deemed acceptable. I Miti~ation Strate~y 1 R-35 may re-define the maximum reservoir pressure in the fault block. Set 7" casing shoe in good shale to provide adequate kick tolerance. Good drilling practices. Use Baroid hole cleaning program as a double-check to prevent problems. Watch mud properties closely. Control mud chemical additions (lubes) to prevent barite settling. Follow guidelines provided. 1 R-36 Drilling Hazards Summary 11-19-01. doc Scott L Lowry Page 1 of 2 0. rG NA- Pad and Surroundina Area Event H2S encountered while drilling. Produced levels of H2S in the range of 160 ppm have been noted in well 1 R-20. Risk Level I M itiqation Strateqy Low Approved Hydrogen Sulfide contingency measures will remain in effect during the drilling of 1 R-36. If it becomes necessary to notify the AOGCC of an H2S encounter, drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures, full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49, and approval of the AOGCC. OJ G NA- 1R-36 Drilling Hazards Summary 11-19-01.doc Scott L Lowry Page 2 of 2 KRU 1 R-36 Injeå_Jr Proposed Completion Schematic T opset Base Case 16" 62.6# @ +1- 120' MD TAM 9-5/8" Port Collar Stnd. Grade BTC Threads (+1- 1000' MD 1993' TVD) Depths are based on Nabors 245E RKB Surface csg. 9-5/8" 40.0# L-80 BTC (+1- 7195' MD 1 4158' TVO) Intermediate csg. 7" 26.0# L-80 BTCM (+1- 12.448' MD I 6379' TVO) Future Perforations Production Liner 3-1/2" 9.3# L-80 SLHT (+1- 13,673' MO I 6898' TVD) &ill l I ~ I I J r. I I ~ ~ ~ ~. ¡ ~ ~ i ~ I IiJ::I IE::I ... i l ~ I . I 'j 6 i. Ii ~ ~ I ~ ~ ~ ., > ~ ¡ i i " , .- ~ <'PiiiLùPS\ PHILLIPS Alaska, Inc. T¡1'¡l A Subsidiary of PHILLIPS PETROLEUM COMPANY ~ 3-1/2" FMC Gen V Tubing Hanger. 3-1/2" L-80 EUE8RO pin down 3-1/2" 9.3# L-80 EUE8RO Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RO Tubing to Surface 3-1/2" Cameo 'DS' nipple wI 2.875" No-Go Profile. Set at +1- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple f- i I ¡ , ¡ ~ I ! I ~ I ~ 3-1/2" x 1-1/2" Cameo 'MMG' mandrel wI shear valve and latch (Max. 005.968", 102.92"), pinned for 3000 psi shear (casing to tubing differential). 6' L-80 handling pups installed above and below. 1 jt 3-1/2" 9.3# L-80 EUE8RO tubing 3-1/2" Cameo 'DS' nipple w/2.813" No-Go profile. 1 jt 3-1/2" 9.3# L-80 EUE8RO tubing 5.125" x 3" Baker locator sub 4-1/2" Baker GBH-22 casing seal assembly w/15' stroke. 3-1/2" L-80 EUE8RD box up - Liner Assembly (run on drillpipe), set @ +1- 12,298' MO Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flexlock' Liner Hanger Baker 17' Seal Bore Extension XO Sub. 5" Stub Acme box x 3-1/2" SLHT pin 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" 9.3# L-80 SLHT liner as needed 3-1/2" Cameo 'D' nipple wI 2.75" No-Go. 3-1/2" SLHT box x pin 3-1/2" Baker Landing Collar 1 jt 3-1/2" 9.3# L -80 SLHT tubing 3-1/2" Baker Float Collar 1 it 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Shoe OR 'G NA- SLL,11/19/01.v1 KRU - 1 R-36 1\ "ector Proposed Completion Schematic Selective Single Completion 16" 62.6# @ J +1- 12O' MD TAM 9-5/8" Port Collar Stnd Grade BTC Threads (+1- 1000' MDI 993' TVD) Surface csg. 9-5/8"40# L-80 BTC (+1- 7195' MD 14158' TVD) ~ ~ ~ ~L;:~)l;.J , \ J i , ~ f Î ~ ~ J ~ ¡ij., .J r C1, Sand Perfs I i MD ~ ~ -J 1 A3 Sand Perfs MD Production csg. 7" 26# L -80 BTCM (+1- 13,673' MDI 6898' TVD) I ¡~ J 1 i\if -',¥..." I it~' " II .' 1 t~-S-_': ---.:..,-- ~-""; ! ;. , .'-~.$' ¡ I -, - I. m . .' - , Cement r--- t ~ I ~ ~ .' ... ~~S\ PHilLIPS Alaska, Inc. .m, A Subsld'ary of PHILLIPS PETROLEUM COMPAI,Y 3-1/2" FMC Gen V tubmg hanger, 3-1/2" L-BO EUE8RD pin down. 3-112", L-80, 9.3# EUE8RO Spaceout Pups as Required. 3-112" Cameo DS Landing Nipple with 2.B75" 10 No-Go profile set @ +/- 500' MD. 3-1/2" x 1-1/2" 'MMG' GLM w/ DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-BO, 9.3# EUE Brd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-BO, 9.3# EUE 8rd Mod Tubing. Baker '8O-4O' PBR. Baker 7" x 3-1/2" 'FHL' Retrievable Packer +/- 150' above top planned perf. Minimum ID through the packer 3.00". 3-1/2", L-BO, 9.3# EUE 8rd Mod Tubing to Packer. 3-1/2" x 1-1/2" 'MMG' GLM wI 6' L-BO handling pups installed on lop and bottom of mandrel. 3-1/2", L-BO, 9.3# EUE 8rd Mod Tubing to GLM. 3-1/2", Blast Joints, enough to cover C sand perfs and 5' on each side. 3-1/2", L-80, 9.3# EUE 8rd Mod Pup JOints as required to begin blast joints 5' below bottom C-Sand Perforations. Baker Sliding Sleeve with Cameo 2.81" DS Profile (Lock has 2.856" NO-GO ring). 6' Pup Joint 3-112", L-80, 9.3,* EUE 8rd Mod Tubing. Baker 'GBH-22' Locator Seal Assembly (5' seals wI locator). Baker 'FB-1' Hydraulic Set Permanent Packer wI 5' Seal Bore Extension set between base of C1 and top of A3 sands (4" 10 through SBE - 2.985" min bore through seals). 6' Pup Joint 3-112", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Cameo D Nipple @ 'w/2.75" No-Go 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" Shear Out Sub wI WL Re-entry Guide. TO @ 13,673' OrG,NA. Scoll L Lowry 11/19/01 v1 "I:' ¡:I'lIJIII ~ I..~: I =1J_':1 :.I_...~~ I: I ::I1:.:þ.I. '1.01: 11þ.: '-' :~e~:~.1.,.~ :..e1 :'_'1:1','. "I,' :1111 ~'j::l :1",. :J:r.ft. 1'.':1 t" ~ .;e': 1~ll_':l ~4.J '-':1 ~~:I :¡.} 1 :II:MI,': 1111 :r.}. ¡:.~".. , {J.::;.< j " :: ;:,; ;. ") "/"" :í'f' ~¡E~;~:~~::~~I."'",\ ,\,"i<; ~ Phillips Alaska. Inc. ','" " " ,',' "payabIeThrotl&t,,:' ," ','"," . P 0 B 0""1 ' ' " Republic Bank, Shelby\1l1e, Kelf1!.~330 . , " . . OX 1 ¿.776 ' Anchorage, AK 99510-2776 ::'Pa5' . C:':::: 1.:'::::':;:..::::1 DOLLARS AND 'NO CENTS To the order of: STATE OF ALASKA ALASY~ OIL & GAS CONSERVATION CO~~fISSION ,: ,: '., ., ;::;.~:' -." : ::.,: . DRIVE . ... ~... . " . .... . .. -.....=.....,.".." .' AK 99501 ,::,t.t,~",,,,,.rr.",.,c,¡:r.,:.,~,:r":'1 r~II!I'I'~ I;I':I~J~ I~:"J" J~I,.,'\II, ~Ig'''~~ (I~Jt,.~.. -- _..-.- ------_w_--._o..--.-.--"--'---.--- .--... III aDO a ¡. 0 ¡. ~ ~ 0 III I: a a ~ g a... 2 b 2 I: Dare 11-26 -01 -- - -- . _.- 011 goooalll 0101330 **************100.00* Amount \' Old after 90 days ...}yXL\\ t\\. \JcLGM'c " ',' . :. ..:' '.~ '\" .; ".,' 'f .~.':.~.., : . . 1"1 GI'nH..iI&) u"""¡ :b:':':' ,vl""'.I.I~' . -. -- - - .. -- . 9. TRANSMlT AL LETTER CHECK LIST CIRCLE APPROPRJA TE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITI AL LETTER \VELL NAME \~\ì \J \ \¿ - sCo CHECK 1 ST ANDARD LEITER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORA TION ANNULAR DISPOSAL <--JNO INJECTION "'ELL ./ ANNULAR DISPOSAL <--J YES INJECTION "'ELL REDRILL ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing weD --' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS ,/ ~YES+ SP ACING EXCEPTION Templates are located m drin\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRA TION APPR DATE COMPANY WELL NAME PROGRAM: exp - dev - redrtl - serv - wellbore seg _ann. disposal para req - INIT CLASS GEOL AREA UNIT# ON/OFF SHORE 1. Pennit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellböre plat induded.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Pennit can be issued without conservation order. . . . . . . . Y N 12. Pennit can be issued without administrative approval.. . . . . Y N 13. Can permit be approved before 15-day wait. . . . . . . Y N 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ~ 15. Surface casing protects all known USDWs. . . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . .x \ N 18. CMT will cover all known productive horizons. . . . . . . . . . ~y) N 19. Casing designs adequate for C, T, 8 & permafrost. . . . . . . N. . ... l 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N Q.~~\\~c:... ,,~, \""l",.~~"-'\<L~.~ 21. If a re-drill, has a 10-403 fo.r abandonment been approved. . . ÞI ~~.) L.~' .... .... \\ 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N c \~~c..~~~~~("".~~", ~t, 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ,- \ 26. BOPE press rating appropriate; test to 39:Ù psig. N\{~X> ~~\~ ~\ll~\' ?\>~ \~t" ~ ~,.\e->\-~.. ~~-s:, 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N , . 1 28. Work will occur without operation shutdown. . . . . . . . . . . Y N ~. . ~ ~'. ~ . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ \-\~à ~~~ \.u ~~L\.~Œ. \~'"). ~\.-~':3 ~~\~ ~~"'\.~~'--.I' ~<t.~,,-~~'-ú,v-!o.. 30. Pennit can be issued w/o hydrogen sulfide measures. . . . . Y N 31. Data presented on potential overpressure zones. . . . . . . Y N 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y N 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y N 34. Contact name/phone for weekly progress reports [exploratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surfaœ; (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~Þ8 c 0 Z 0 -4 :E ::0 APPR DATE ENGINEERING -4 m . ~/ DATE Ijt'l"L- l ;J I ") Y N Y N \/-"7~CA\ \..~~ ~~~~tè. \ \L~,,-~\~"> ~-c-Ck~c;~\1.. ~\\ V b..~.\-D ~\.:)~\-~~~~\...~r~~ ~\..~ Z -t :I: en » ::0 m » GEOLOGY APPR DATE Com ments/lnstructions: ~m WM TE~J}'VL)LÎ 8~s JMH c:\msoffice\wordian\diana\check.list (rev. 11/01/100) ~i2?¿ ( WELL PERMIT CHECKLIST COMPANy.-4 i / ¿ ¡:S WELL NAME (;Ii? .3(~ PROGRAM: exp - d~v ~ rednl- seN - wellbore seg _ann. disposal para req- FIELD & POOL V?I--,','/C)(~ INIT CLASS ~ ~ER 711.///'0./-1 GEOL AREA ~, 10 UNIT# ()/ I /~(-,; ON/OFF SHORE Î)/l ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ~ 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . ..5'-'r-f .í.':"¿ /,,"¿ 4 ';"0..... ....~~ A-D <.... 0 2~~ 35, ---f':;"..r" rC/d ,-,' {./-, Þ-è- .:A-i 4 v c...! 3. Unique well name and number. .. . . . . . . . . . . . . . N ~ T !::>. l.-1\, I'9D L..- D Z.5~ 28 . / 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . .; N 7. Sufficient acreage available in drilling unit.. . . . . . . . ...:! N 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . . / N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . . N A~F.R DA T.E 12. Permit can.be issued without administrative approval.. . . . . " N ~ Ii. I( D I 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ~ N 15. Surface casing protects all known USDWs. . . . . . . . . .. . N 'r\C \.J~~~~ ~~~C"'\.~ 16. CMT vol adequate to ciraJlate on condudor & surf csg. . . . . N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y ŒD~~~~\~",'-2:...~~~\ ,,;)\-\-'I.~~.\,\ ~\~'="~~ 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N. 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ~\~-\-\.,",~ "",-'::,1 't"'\C ~~~,~~ ~,~ ' 21. If a re-drill, has a 10-403 for abandonment been approved. . . ~ ~ ~ ~ . ~ - 22. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N c \o<:.<è.. C'\.~Q~-~~ "'è }~~$,\~c.) ~~ \~\.ì 23. If diverter required, does it meet regula.tions . . . . . . . . . . N , ......... L "- 24. Drilling fluid program schematic & equip list adequate. . . . . N ~~~~\<.t..\ ~ ~~ ~'\QC"~~ \;~'SS-..I.. ~ "'\C. \t..t"'-..~''\~0 25. BOPEs, do they meet regulation. . . . . . . . ö . . . . . . N \. ~,.,",,^ 26. BOPE press rating appropriate; test to '1~ ~\\, psig. N ~~~ ~~~~. ~\,\, \,S"\, ~a~~-\- \~~ ~ ~~X>~\ 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N . 28. Work will occur without operation shutdown. . . . . . . . . . . Y N ~ . - - )..... 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . Y N ~~~ ~~~\ù\>~..xJ~ \.\~~~,,~~~ ~,~'\.~ ~~~~d~(~~-G'a~~, 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 6' N of{'<.'..f to-( ~I /R.-.3.l¡L ,:x..u;~'L'r<.d ~fi.,.~ ~s &y-t DI-DI.c."/.. 31. Data presented on potential overpressure zones. . . . . . . Y~ (/ (j 32. Seismic analysis of shallow gas zones. . . . . . . . . . . .. A/Ý N AP~ DA T1= 33. Seabed condition survey (if off-shore). . . . . . . . . : : ..~ Y N // ~ 12 ¥' D.I 34. Contad name/phone for weekly progress reports [exp/~ only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. . ,,-'";)~,,~\ \c-....\-Do.~~~~ \~<:.."<'-'('.~\~':,.~~ <:"\u-,>~ ~ ~\ \, (A) will contain waste in a suitable receiving zone; . . . . . . . Y N \ "(- , ~ - , (B) will not contaminate freshwater; or cause drilling waste. .. Y N Ç7 \ 0.. \'.. \. ~ ~ 'D \G::. \¡ " ~ ~ ~ () D ~V"~ \ ~, ,""-' ~ u:£ \ \ . to surface: \S" (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool: and (E) will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N GE~L,~ ¥:. ENGINEERING: UI~Annular COMMISSION: ~~.. ~ ~~ WM"- "' 8~s /°/ TEM.Jft9Y1')\J/') JMH ,}¡1~l{¡1. IzJi'q-k,j >ï~\ ~10 GEOLOGY APPR DATE c 0 Z 0 -I ~ ::a -I m Z -I :I: en » ( ::a m > Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) Well History File APPENDIX Infonnation of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simpltfy 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. -: :'~', '. -.- I r " L L 1 l 1 'L ,', 1 1- I -= _::- ~ i , i_I t ill r:. , .:, I. . . L_~L~t: .: !.. .-' . 1. ~ ~ ~ ..-, : .:. J ~.1~r :I~I ~ ~ : ~,>: j :. ;:.. -:-.-: J. .., --:- ;: J ': L : '::..' _:- ~ í::: r'l -:-.. . . . . . . . . .. . . . L = ~ ! i.= ::. - . . ~';.: --:. --:- . . . . . . . . . . . . . . . . . . . . . 1.1- ,~ '.L.' l ~ 1 r: . .. . .. . . . . . . . . . . . . . . . ~ T ~~ F - :. ~ ! I :::1 '-" -:.. . . . . . . . . . . . . . . . . 1_; I I ¡.. ¡, - iiI, ~' ~ 1-1:-- :.. ,-, IJ ~ r=. "t. ~ I-I JIIJ iI'lt ~ t.. . . . . .. I: 1 ~c-:;' 1 :I...~ ¡:~I:~ r~rlt--=....... .1_lirlJ'~'~t"L - ~ ~' ':. ~ L ¡:: ';j L 1 r. J r':1 i. 1. to. r " l" , . "~III(I'I--=I-,~.:................... .'::.T~ 'ï ;,!:'~ H::1 j"- L .= ~ r. . l ,~ "" r,,, r, ,"- . . . . . . . . . . . . . L 1 :C' 1 l ;: [, ~ t 0.:. . .. .. . . . . .. .. .. .. . . . . . .. . .. . . 1'1 - 1'1-' '1. I.' ,> L 1 ~ 1 r,. . . . . . . . . . . . . . . . . . . :" ï ~- 1 ;, I.:''=' II;' Iî'~ . . . . . . . . . . . . . . . . '.11 It 11'.'I.JlI '~:I-ltl.r!l..J~ti.:r! tII..JÍI'lt~r........ .I:IL Fr,,: 1,:,'.1'; ï:,[::,.:. Ii "r",,:. ...... .liIW¡J,,¡'!I¡ ,',. : r"r".=,. r, T, .: . . . . . . . . . . . . . . . . . .: T.: L L~ ¡ Jr 1 I. L I' '.J L d:, [ " C.., . b!'~':-l~"l L':'F ,'~":.rlll'tlt7 1.1 t I-"~,~ - 1.- j ï ,:, ~ E. r! [ ..:., L [ I: ¡..'.'I..';' 1'-11-: b,1..--= L I-'r', 1 1:. IlliC' II,~,C' L'>3: ¡I i;CLL li.é.!lE: ,: [1 ¡ ii_it IE C ¡. : "FEF,'-,T"':.F : L,>~,'3II i':; ,~'i:'I,I~ '-.II'! : 'j,:,FL ,:Fl,:','fl':'jl ['.,if.: _-¡<IF: [, ~ T ,L ¡,:,,: Iii_II IE [F : 1.'>:;'3Iil'3 lil,:;J¡i~lF: ¡ii,jE, ~,Ui j L. t'-I.li,\-.I. 1 : \ ':' loiL ,:,' .Li. ':'~U,:ï'>': ¡,ï.ïliF:c: C. ',I E:' ï i::. F ~,.Ir ,:-,-':'[ 1'>.:,'.,[ [,',,1 :['~TT'>II: '1 ':'¡, ;1 I': ¡-I 1 ~ : r..::'.i I'~E : [ilL: [:L: [¡: L: [i'iL: ELE','-,TI':'li .. ET t"ï.-:,II 11;'[ r"ELL: Hi.:HJli,~,: [,U 1. ET ,. L'»!: : ,:;F':'¡.'II[' LElL: I", I ¡,eu ':-,~,.:ïW; FE.':-:'F,I" I r - .', ,', ':, .'I~I.- --, ~ ".1 I:, - <II~\ [. '-I ILL ï l ~ '1;, 7 I. OJ , " I' ,~ I r' " 1_11'1 1 ':' -I] ..1' - ':' ~ I 1¡ 1[, ~,I.ii I .:. t. -r,!i,!- 1 ] . j ,., 1.li I"(Fe,.,,11 ('. \, t:' ¡ ': F 1.11 1.':'[ ,':,1.1': 1 .! . . 1>1,1 ,! ':'. :".' ~ ~ . :":' _: ~ 1 -:- í, 1':. J. f I ~ i.' -:- :-1', r- 1. -: ~ 1 .: --= l. " . 1 ' . r ,I.L [" L - 1 '=' -I., r, 1 : ;, 1 .: ~ r . I I-I ::: . i IHE' F,I.il i ,:..,.' -1.1[,\- 1 t'. 1 ':' ,. . Hi.1 i I=.,',I! II. TH':-~!iT'~'I' ':'I:[li H':'L~~',::ì ii'.' l'F! U.EF: HT ~I-F. 'I!i' :L,[ 11:1' L,UTI- ':Ï" l:T ,:TFIII':; ~I![' .~HIII':; ~~ C' ~TF III,~, ~ 1= >Cdj':( I '_'II .: [¡: I! I':, : 1:,1', 4 F [" II ::'J f'': : I~I . I,' I:' I.' 11: : . I -~l~'.I> L. ,LLL C'UTI-i~ ,':'I:E 1\[,:"":-,I.lI=[L, C'Et1H~ ,1iC'1 1.IfILE.~c- '~'TH[¡:i,iL~E. .:'[ ~,T ll'. I r; i c' F i.11 i ~ ] I [';,r I l.iT I!.., 1 = .C ¡ il~' '_õE r '~-,F ~ ':, . I~ ~ I~ '. r £: l.,HC':-TF,¡i:¡ inTII C,i.i,',I. '~,:JilF. ¡::'1 ¡ 11.' i:: L L F"I~ '[ '.' L I L'Í:...TI,','¡ ':'1 ,: ,.,1 I L' U L ','[ ¡. '.,1 ¡, ,'.:lli,'[ 1 ,~. ; ¡:, .~ aOJ-d<3l /0700 I "',: .: 1. =- ':: .: ~~.:=.=T~ :-1 ~ :-J ~ .? .:. , t:.; j F " ; .. . C ::. 1_' 1 I - - - - -. , - ~ 1 1 ~ ~ .~--: i_I.:- '-'-~~' 1 ~ _.: ,_:,;- ~~. i II'~ '-'''- l'~l!"- II.i::'Li...E¡:; TI)~~ ['ETU:.-::'F.:, EL;::':-:F'T.:',~,li¡:::F ~. I. -', .' J:.. -:~.:I:"fT..'I:. I~ i~ :., ,= F ~ '[i;':] " ':-'Y~E:!.>TE[' t:UI1ï- ::: ~-:'ï-':'-,IT 1 ~J,:'E1L.l =E.:L. I..ITrl'.'-C'Erl~~~.i.l L t ?Li.-,.. .=-i J ~ . , :;, [ ,~ =- J U ;.=- ;: ,:' 1 .:'~, F " ;I~', ~1~~' T I"' T" - -1 i ,:,' ! I c." j j '~ -' T '. l'. :: ~ I: ].3 ~:' i.. ' - " ~'::' ': [ E [ 11 Ii, C, - : ,; :¡ I I':; F ¡; .: ,I i - ~ E: I --' T l. I T J ~: L< :;~E[I EE~I'I~. ~ ï- ':-1; -,::, ':' :.1 e" ~ 1 j: ' T 'e" F' - -11 ,:,' ¡Ie" ~ 11= ~ I Le,. 11\,'[', :=',:'T,: Iê ,-,',il,èj C't¡:r.l~' ~C":- ,-,~ : "TI'I-:'F [-rl~' t', 11. L'>'I,=,e'EI' ':'t r H I L LI ¡: è ,=- L =- " ',:, [ I 1,:-. F U 1 H E. ~ -I 1.: T L l ¡: ':'11 C,. .:,J-I\'U",;::T:: 'Æ H-¡:¡LLlf<' ,:',L.:":j-',:" 11":. ¡',=-,jt:L, ':'i :,] -- . ,:',L.L. IILJL' L'_"_; 1--II,...:.e.'l¡'; e.',~,L:' ¡-'!:..!.-lil:.'" ¡'-It.., '.+,l,"'III.~L C,ULLEF,'':: e,UTH F[E"E¡::'Eli,::-U. III i [, ,: l.ill.? 1 - ::, F U H: ê [II ï i j t. L L 1 F - > l j IT H :,,¡:1 II '~<'-':'_:'-...;':":~'-"" Ï'!n~' ',iELL f.E",':'!-¡E.C, .'-, 'l':'T,ë,!... LfJT H ':OF 1 ~ - <,,:,' II L " ',', :,' - ~ ' I,. êi':'i; ":ll'>:,Tiir[, !:"It, '.'L' L[li!:'jI;:rc':'li ,:",::,j-,:", = .=¡Y":.THE.[' ,:;.é..l-lil.c. F,r',i ',::':'I,IEc:¡IIE.i:' ::E:',F = .:!¡':":,Tt-IEL' ~H,'-,'::l '::HH'l L,t::F,.I"t::[, FE.'::l.::TI"IT,' 1 e '[ ,: i., .:: t-I ,:', L L .: ,[j :ë F .e. ':- [ II,:; I ,èt: .=: b = :!I':":'TH E!' ,: i'I,=-, ~ï: .::-f-i I E"T LÆ I: I 'H, H:: T ~TI' ':¡ T': ?H,'-,L.L':,¡; ::-Í::",~'jll',,; 1 .?E.IIF = 711'»lj-IFi:' FI-I,<'F. ;!-IHi iHl'[C' FE.:J:?T1TT,' 11 U'II,III -' b =- 'I II':; I ê[C'b ~- .èW""JfIU, Fii,' :l?l-ilr,~ ï..F,F1 [e, FE.:'ETIIL L'C[F-:~,:',':lll,j I ?E:':C = .::II'»THLD r'AI'I,~TI':11 E.::l~':''::I_'FE rHIL .:tk, =- .èW,",THJ::r:, [=:I,IIY iÆii.?TT\' I L,:'¡¡-,:-,:d,ili1 E 1111 -, ,- = êl['>:,ïl-Itr" '::'U-.II["':'ll '-:':'¡'i'F':'TI':'11 1 L.':'¡;-,::-':'¡JIIT LIil' ,:IIF':' êll,:":'THll:' li[~F CE'j'l,::'j':'F ':,Iij, FH'::ï':.EL¡:'~'nL ,'-,E.?'>F FTJ-:,¡ i E",ë":'T':'ï 1 l.,:,¡;-,:":diiiï LI,II' ,:ï<I' ,- ,II',":¡"!iLl' ,:',.,lil.Lli_',','l'LL' Ili,l-"l¡~"i: ~'A':'.='l1, '-=,LJi[".èT':'lil I'I.~.TI' I' 1-1.-1':[, H':.Lf': '::1=F I -=W,,:'THC[, ,~:'Eí-,,!.,',r.. ':'l [-,LJ C'En"~T:'F' ,: ,::-:,I)IIT ,::-T r,=-, ¡::TE '':'111.'-, F =-,:- F: ::-II':'-:'1HE"ï' "'C.f:'!F. "'l liF':,:¡' [ÆH:,::-r'J'.: '::-':d,IIIT E!I"lI-':'IIII'-.III,=-~ 1'-,1',-111 11:1, ~ II'U, 111 li:,''',i:.:~'lll'~ I'lL 'lfIIT¡:":,11 i.'-",; L',- !.-: H':,L[ .: I '::,E : liiJ [, : j[ 1 ,,è,j'I'\ : 1 ':. . ':' b ¡: ,~, I ì U L' r 1 L l' ~ ,:', l i:.. ,':'H L.':,F ICE':: t':,¡:II.=-,il'.,IIII,-lei lLl.ll L' !,EII.:1'I'L: :'. j - :',:,i. C 11,1- T ,': __'.1 -1:1:11:1 t~11 -- ,-, L 111 L f ,': 1,.,',",<' I: E!: _II L.'A I L'[.' 1 . :; : :' =-,¡ I ¡ ': '1' ,II [ r:d~ H'~:.,J,:-,: :'=L L >" 1':'111""............ ..:"!,:'Llt .',":'1. :: ,= L" . . i -:.-:- .::',It L.:::' '':' 1 Ii :.rr..::: . . . ',,,: L" = 1: r, I I'jl;,l"" t'. . . . . . . . . . .1. ':'. ':' j' T. '" :3 ,~ 'J [ II I j J :3 T r I I':' " ~I 'JI !I I ':'H j J - T 1- r I i::' c 'J111 I :V'H j ï T !' : ~, i, 'J I ~I : ,11 1 :'1 I l :' , " L' 'J! Ii j ,II 1 :'j : '. - 1 l-j I J ~ ~ ~ I Ii-I :3 II :Ii-I 'Jl \! I l..Jj I' - I Ii 11,1' 'J 11I ! I ~ j .- I II jJ-l':' 'J: \! I I I j j :, T ,. :, I iliH<' 'Jt 'II I :3 :J - T i UIH':, oj! 1i i j :! .. ~ j j : 'Jl Ii I j ~, : " Ii ! ;, u I J',' :I r , : ,IJ ..L :3 ~I'J T II.: I~ ,j :¡~ I, ¡ :1 'J III, .'1 I ' I c' I I ,I >~ .1, " ../ :" - ~I'II~ I 1 I I ~ .. . , I.' .~ -' P'I - .1 - l j IJ.> i .f I.,: - -I. j 1: .~ -:" J..:- 1.'Jr-, -...I-:IJ " . " " " . . . . . . " . " . " . " . " . . " =-:, ~ 'J I" ,~:¡:I :"''-1 ':. I: .~, - .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. :;.. r" T ~ .. ~ I) =- :: ':1 -: ¡:,:..;ji:j:'~;hl"'.....'""'. "¡:.i:.."",i ,i:,:i ,:""u'c:::'~ ':':11 ll~ i." '-I:'."""""""""""""""""'" "t:"jT'=r::::i,:" :-"II~.Tj r'~",¡TT:;.r:;.ii'I'.'.".'..'..' :",,~: - J :,< r.Tõ;Ï:' j I~:¡':'J l-:---:--J......."" 'o'lT',II' ',I:'.j:,¡:., I...: I. [r::~'T-~:i.:, Ij I , : IJ .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. ij : l :¡...: ==- ."I T,] ll.l T [[ : -i J < '."::' i Ij:' I. :¡":. ':.i.} T. ~ :1.:" :¡.r-:'li.ï :'J ¡:: ~ ~Ij . '- - j I I [ -: I! ,Jj', 'I j I I : : ,I :I: II] j u ':J I: I' ~ I - :"1 . 1.1 ~ I 'J, ,I i 1.1 . 1_1,.- r ' '- . . ~ I ~; J I_I .' ~ . '::J ,:,. .:' '.' r 1 ]':'1 J~'nll -:11 Iii I] 111 'J! )11 '}J':'::" -1':--:'1 I-!j-j .L:1I'I':':' ,l~,,'J J]~":lJ'1 3:':'3 J~'jJli H,Li}j J:ll'¡J::::! --------- 1-\ I:i j'j '1 ~ lJ ï 1,,'111'1 .l.11-n ,hl<'l --------- '1-IL,j)'J 'jJjll:":"Jli' ~,:',-! IJili: J :,,',: ::,UIi-i: :1':'.1 J..:lI'I.:' JIIIlJ.::ÕJ II I ' 11.1 , ï - T " . ~: T. I ,', . ',~ 'I r " ,:, . "- [r , _1 j -i II ..11'1 ':' . ',":':' -: T :. . ':' ':' :.' ~' T I> . I~' l - <I . : '; 1 I! I":' j I "I ~ I ':' . ': ':. j ~ '~, . .:' ,:,:, '~ 1 'I . '; r ';' -: T " . ~ r T 'I . ~ r T : I' ï :¡.:, " IJJ I I . ~, \- ~ - ï J :i ' ~ J j -: <I. I; f" .:,1 ~ T '.1 . ~I t :, - T <I . : l T. ':' . : r- T c- i J j j 1- I . ..~ : - " :1 . ~ ~, -' ~ ~ I' . ': ~~ T :i L~I IiI j '1 ï 2 ' : ,1 :' ! 1. j "111 1 'J -: .L ;.' ~ " , , l' ~ ~.~ \'1 ~ i ; j :'¡:I jl'l." J --: I..i I ~ I I . II - I ':'I . :lIIJ~':jj,:.'!.I '-1i.:J::i:: ¡: I J ~ ~~. J j ï: I_~:; I ~ j :: -~, i .(7l-~-:-':J ~:1.J;1.1 'j -) I T I:. ~ :; :',', .i ~-I :.. ( :, :1 :1 T T ~ J~,.J J~~':~:! 1~-=-I~~ : :!::ij~!I"I: Jli~ j~lj:~rl ~-i~j , , , - : j -L I ~ I. . :: = -::.: ,';' c' . . . . . . . :"." i : -:- - ~ .: ::-' r- - ï .:. :'1. . . . . . . . . . . . . . . . ~ ':. ,i. ~ .: ~l ~ ~, . . ~ -~ =:.. 70 -: ~ ~.: i: :-, - IJ ~ 111-1 'J "';'" , , .1:1":-: . ~ ~ - ' . . . . . . . I , , .: ':' ';' ~ 1 ': ':";' ~ 1 .: ':';' ~ 1 . : ~ 1 , , , - ï . ~ ï , - T - T ; t .:. - I. ';. r ;' ~ ~ 'j r :' ~ ~ : ~ ~'~ :, - ì. . ~::::: :~ :- .. - j . - -: T r :- ~ 1. r - : H- I: :1 r' - .:'.1 \" I~' I_I r- - : r ~ : r T : 1- l : .- l r::. i I> . :' '- . '=, . t, :r ': l.Jj 7: ¡ j '.:' 1 . ':";.' :, . :,,:, . I. =' -I -, 0 'j L 1,:, <. ]'J - -, 1. Hln,] :V F . . ,'ï ..- J c. ~ ': J 'c :, .:' :. 1.1 T I I r"1 J .~ .-: .:.: I> I : 1-' :,1 - , ':' :: ':' T t ~ 1 T ':' 1 . , , >.>'1 >,1.,': : .: ,., 1 1. ~ . : :" : ." ~ ". <I I . ~I I I ,- ,.: : : I , 1 - '~I '~, I . r 1- ; I: I: r ~ ,: '; r ~ T - l '~I '. ~ - ~ ":J '-" þ ~ ¡- -: - . ': r ~ ~ I~' ~- ~' . ~, l : ~ ~ '~ '- '. ~ - - ':1 ': -: . - - '.1 - '"I .' .: I i. r . 1"" ~ - - , - .1' -1':, - -.. "I ,- . '..1:;: -:::-:! Ii I:": .:~ I I '.J i-: -:. ~ : - ~ .' ....:& I ~ I . '~, - ~ .' ,> . ~ ç ~ I; I I '~J I_I . ~ ': -~ ; 1.1" - ll'~':l : I ,[J' 1:, .i] 111 I '::<"-1 :]0:' 1 : Li' :! 311 I j'J ']1 :]I'iIl-T~']~ ~V' ,Õ.:J':'I'I]li' ],:3.;1 '~l:'J : 11'_o1~' j J.., :n :111...3 ':'': 3'1 ':. H 1 iI :,>J : 11'- 1_' J j, J.I:l l.U'-',,- J -'.:J :]11':' .j J,I :1..1':'': : '-I j ':':::<,'1 ] ,.L:'] :',.L.:'"I n'J~]:-I ':":'1 1:1 .. .:" '; 1 I~' . ':: ~ T j ,=, j ,llJ '.ï ':1" ::-- 1- ~ :i j ..::3 j ~-:3 :J I i:3.:i , , :n ':' . :: I 1. '~I . . r L I., .. I: ..- T 111n'J l:i~L.=- j ':' j'J':':' l'».l 'J'>JIIJ,. ,':J:ïiiil-I.: ,] -11 .1 1/ :lliJij]L'iiI Hi.:JJ.J : :J ..H I ! !III: II! j ,1 ~ :! .~ '.1 I:' :'1: [;".11: 07. ..11"".' 'J: I! I I::] : :1 =nl i'-II i ]'1 U ':iJ'J:']I-! ~J1::j I.II.II.I'=:¡ -I. .'. -I '.1 ~ '::' .1:.1 "~~ " r: '.:,r; " r-} = :'.:--:i ~ij ;1.11111 - - T ':":' . ,] i 1': 1.': . . . . . . . ;'Li 10 II ::, T 1 j 21-,:, 1, . =- J :i ': ï' . . . . . . . . . . . . . . . ',..:i' 1 ::, T.' J ~ - ~ :.-;, . . r::' : - .:,- j T'~:";:,;~ j 'Jlr'llj T .. ~ l : 1:11 ~=I'.I, ~I:I"""""" .ij,=,ì.~~~-:1ij~~~1 J: .::,~r:.IJ I~I .. I~I .. T .. .. .. .. .. .. .. .. .. .. "3::, :~IIrq i j: ¡: =-.ï~.. . . . =-'" '0 I i ï =-,. =-1 :1'-' c' =-: T,..1 '=.=- ~ I:' I ~ I .. :3 I "1.: 1': .. .. .. .. .. .. .. .. .. .. .. .. .. ::-. I.U ~ 1.1 ~'~'l...j :I,~' .I::'~'~ ::'1.1 : L T j .1':'3 l',:'T.?".I:l -.,.",'311,:1:-""'..'" ':"I~:I! ::11j :¡'.=II ,> ï . . . . . . . . . . . . . . . . ::' :i:: ,1 =- T T J ~,~~,,~,;,' '¡::.T:~::'j T'O:T=:."'i:i ,.ur-"""".."II I>T. ~<I -=-I~I.""""" .'j~r-I~.T:;'.i:.~=' .J: ~ :¡ ,,,'J I: I .. I: I .. T .. .. .. .. .. .. .. .. .. .. .. .1 -=.':~ I! I rl I i 1.1 ~. ¡: :: .1 =:- , . . . =-'.'I'õ [! 1 ::'..::-1 ':1r,.: ::,:' T.oJ::'c 1 ':":' . ,3 11': 1: . . . . . . . . . . . . . ::"JJ ~ 'J "'. 1...1 =0': T::-'lTt::.1¡ '::'Ti:j :' :. [ .. . .. . . - . . . " I: " .1 ~.i T ~'j j .1 ': j I:' j .- ¡:: " =- 'J ~: 'c 1 ':' ',: t . . . . . . . - . . :. í '.1 c,.j ï i; '3 .ï: j L.I q:,'; ::, j :¡ ~ .ï T j - '.' . " 1 ] oj : i:' ::.' ~ I:::' :' 'J ['J i .~ -I j 'J! U I = h :"] 'Jr \1: j':'rl ~ ,~¡ ~I! .i ' 1- 1 : J~.~l! .lll:::j 'J:.~I! IH3!, Jl ~: ~-:J..J r '.' .1:1 . - '"1.1- T ~ ~ ~ .: l . ¡' ~, T i . , , . '.' :' 1 T -': I"L 1'1' 1'1:-. '- '- . T : r . T '.': L' ~.. -, I j ~. ~, . ,.' <I ¡: to I . ': :JH , . ! ~ 11-'-: l""i ~ ..J I~ [.H ~ I <II ,- '. , l . T,: . T: - - T H- T111 i.j ~ - . . . - l , , T: I , " l..:~~ ~ -;- 1.1 i'! -=-: -:-' J ': I' 'r.:\ J ; ,:,~' 1:1'.'!1 ,:"'::'~'~: . . . - <,'~II .: ~ r ! I I, =:, I ï :. r J .: IE> T T I . 'i' 1 , - . :'.'L ï.~l ~ 1.1.:" i~ I~~ :"'l.H :..~ I.,",. ~ LE>~:- F '=';"1.:,1). ¡: r:.? = ~ . I I, I, ,- ~ - ::: ' I : -: ~ - . -- 1_' -=- ~ [- t I.' -- - .: _!~ r- I.:, : ¡: !: ':' ~ ~ ::' - ~-i I~ ,:; : :: :'J~ J ".:'~ !::r'~':-L [ ,:¡, L ':- :,..: I 11'_: [',:' ï ,', '>F:.i' f-1':,L¿ Elï ..'1=E ,TII,: C>FILL¡:~'_: ':-:..'111':; [,UTH 'FT,: 1. ~ . - ': I,' ~':'~,EI-i':-LE '':,:,II[,IT1':II..: ¡.I',' [, T I b [ : :li.IL' [,Eil.:1T,' 'LE ':.:': I ii.'L' ,1":':-'>:1 ¡,' '..:': ii'IL' H-I: 1~I.i [, ,:-1'1 L':'~ T L,F.: ,[ L II, : tLI.1 IL' L':,,:-,: ,,":-,: ~E.:l'=-TT"!T" ,,"I-iill1, ',T 'TfllbUYTIIFf" ,j'¡:':;I:-, ¡.II_IL ,:¡ IIE.:_:I.I~E"I-, TEIHFJ:'TI_IFE ,Inl: ill.IL.' ,~,i 11.:"... '_'1!~'''I.'L..-,¡lll'-, llr,I.au.: ['.lr-,i:.: ! 11,1 L' l I L TF.: 'H: .L.T lIT: i 11,1 [, ,:-.é.,!'T ,i:.,T I.n: l~r:.-:;[ E;,¿--:-J '~. . ~,< I', II :, . ~ I: 1.11:1 '~, . '.1':11.1 . . : . ~ ,; ~ " . 1 <, <, -.t ,", I~' I. I . I ~I ~. . I ~ II ~ II ~ I I:, I~I . . 'L IF,H I": I j,'--,TF ï' ['Ï: I i ~ IT, : rl':.u:. ':-':.¡ F [':-T1':'11 , 11 I , : T':"Æ .:T.'",II[":'i:¡- '1111: E.i.;~ F¡:' [';,'.1[/ ¡,:-'. ,W, I : F [II :,F 1-'': : I~I~ t. ~ t - Crï,;¡ t: ~I=":".L [l'~ ~II~ 1_'>1-[ ~::- ~': t':! L ' ~ t ~ I~ ~ ~ : r j '¡', ~ "c . . . . . . . . . . . . . . . . . . I~':" ~:"[:,= ~t [l. :~r:l. :,r, E'l :..~I: T:J'-=".,. <, L:';IJH'J L'j r..;;,-:tl,'rl................. L':'-..T, '>f:r:l. ::~1 L..~ ,j'~i:r:r, '.¡r,ll::........... ¡-':'õr: L,:,I::, F,::: [':.L ': I',,:,: ~ :'¡ r,r:.. -.......... .Ur":I'~Ll.r,,.>j ,- L" ;J i'-"; .: r: ;, ~ J í",I. . . . . . . . . . . . . . . . . . . . . ',', '.' . 1111 [i;I:.", [1_':'111=': I: ~'l .r."~ >. L'j....................... ..1.l1"lj7L~LI'l'-:" : I: = '= r, t . ~ J '.J :. . . . . . . . , . . . . . . . . . . . . . . - :' ':, :- L": ¡: t I', I ',', l. r:: . . . . . . . . . . . . . . . . . . . . . . . L':1 t:: U !I', ~: [- ,~ ~ i t j ..: ~ t 1 '- ,- L L 1. - ~ I . .: ,J!..: -i~J'~- =-...... '.1 , I :1111':- -,:' L " '1 ,- ':'L",j ': r 1 .1 r, 1 f, - 1 - ,; L'[ ~ T t T I~ 'F I !'; ;[ L C 1 i.j '::'~, I 1~~L'<ll .- l ( I: ¡::. I 1\ iU'l ':'1'11 11 I ~ F.? I :L i [,,', 1 ' ':'111,\1 I I: F/ I I Ii i I '1>.1 I ,"Iil II I I~ F l' Iii 1C":'l ,:'Hr \I I r-U I lí jL":'l ' !-i I~ Ii: :It" F -:: ¡:' ,:',:, -J,: r:,[ f = -::. r: '~I'I ',1'11",-::,1 . . ., - .1.': , . I'~, \", f' I r " i.. ~J t I I ~ 111-= - r:' 1 ,0 1.11-1 1 I: I 11 ' I I ;..:. ~ I I" , I I ~ !II " =1 :1 l r, ~ ¡; :1'",; 1 1" :1 [ 'E bT [T 1 '~ " " - I. - ,: '1 ", ,: - - F':' F ! Ii:; [":'1 ' f'j' H 1 1 ) 1 .- ,: ,: 1 ' - "I ,; '::,1' I Il J L"> 1 ' ,-,!:- 1 1 1 1 i ,', ., : -1 ;.-1 L -. - 1 J ~I '; '- '~ ~ ¡: I ¡¡W<, 1 ':,HI \1,1 1. ' - : 1 1 " ~., ' " l ' 1 :. 1 ..¡ t:: - - - - I: b':- I 1; j L":'1 " ':'HI U 1 ' '~, ,:, L ~ 1 ,: - ~ ..¡ l ' ' 1 ,'. l "¡ ,: ,J -' - '- ', - -'- F F¡ I I nIL"'.' 1 ' ':'HI tr.t L ,I:, " I' ,: ,':1 ';1 l l ' I. ", ,~. 1 i I- L L' I 'Ii i [ " 1 ':'I.il Ii I " ,. - " " ', ,, I. ' I ". ~ -'- ,'- ¡-E T I 1'L i L"> 1 " HF ' 1 I ,: : ,, - 1. ':'1 L "¡ l11.:. 1':. j.. ,-- ;,¡,j.L' !'~1 L. L L I'll- 1. L.:. [1.1'~....................L.:: ':' L~: r: F ,'= ~,j H, ~ ¡-:' LEI", t 1. r '''. i: 11 r: . . . . . . . . . . . ': . ~ .: ~ ~ 1 ' ! ~. ~ 1 1 '-7 ~ ~~ .:: r' . 1 ::---= ¡- :::;ìIO::-...................... .::-.:'LIE.'. . - -....:.," -''':' : I_~ t L ,~ '..:.'~ I I ~~ f' I -= .. .. .. I J ,_:1 r -=: L" .. .. .. .. .. .. .. .. .. .. .. l .. -=- L" ::. i ~ r"1 ~ 1 -~ -:- . - 1~1=:-'-I':"_.~7' - ~,'.............. I :- . 1. r I ..1 :~I ~~. . ~ l. : ~ ~ F -:- ~ = ~. :: .. .. .: - - .: . r 1. l'~ 1 'I: '-: .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. L .' : I,,; [i~: II~II~.............:~":I...!~. '. - I',. :: 1. -: ~ L 1:'1=1 b l ~ .L ': " ": ;, ,j 'Õ t. " '~ L. ... L ': 'Õ r"1 ~ jl'll-:: .. .. .. .. .. .. .. .. .. .. .. .. .. ~ T ~ LIt: .. 1,1'.1": ~_. -=:. 1 . l -:- 0.:: ,:.- IJ L L'~. :-1 II;, rw' . . . '..:: L" : i. : fl Ii Urll[':: r .. .. .. .. .. .. .. .. .. .. .. 1 .. I>.. '.1 [,,, r. ':- :' r '3,-::-,',--:.t"~'~1 ~I'I........... .':'~ I I:, ill II~J I (, b I-I - '.: 'f. .' ~ 1 F 7 :: : L j.. .. ~- '~, '~ =. ~ F L 1. == T 1'~: '-: .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. L ~ ¡:. L ,~ . , ]. : IJ.: ¡:-]. 1 'õ II" ir, '= . . . . . . . .; '1." L If:. ,_"'- . : '''I''', r, r. ¡; '"'. :': r j l I L C. H E .:,l' ¡: F LILE 111.111c:.[i-: F :',¡; ill; [, '. '-' L" - - 1,-,:J l:} 1-, -'- 1 :J" '.. j~, 1:., t - t ',:: ~ I., I-:L r E l T I~ I_III 111.11 IE F: ï : l:ÆHi-I Ili,::-r:,[il[¡II: ;¡ t 1: t C .: ur IlL'- ¡; ! '[II[<'F 1'>-.'1" ,::-,:,[,t .. ~" 1"11"' I", .="'l,':'.F [ ('U 1 H :I'A [UII-t l L 1 I .' I - 1:-, . I> F F [, HII I~ ¡: :: F ¡:.: ~ - , I I I: - - I -.. -.: ,~, . 1.1 - . . .~ ~.. .. 1-, , - I ~ . I:' 1- '. - , I', 'c. F F,--t I: ~ ~ <, .. ::.. -; ..: ~, :. .. ~I Ij ~ -.. 1-,' .. . ~ .:. I.' .. :; I-i¿.:. C,U l'iT.:, L:- 'l E. L.' :'':-,,=, [ l.': -= ':. t T \ i,':' f r ~1.1r. r.:,'~ I~ ~-:'I-Ti i.' I: C . '-I- ,- ¡, ,II: C"='i. illi-i':,U:' .:':,FTi i.["i- f. '-[f'e I,:,I I: [,:I,=', L¡::C r!IUI':'F,,' ':'F FE:L-III.itl: 'T' [, [',F IL L EF I F.T I : ,'0[: L'>:, IrITE.F,,.: I. ,f-r I: t:'II'-'I. L.'>-, llljt,~ ,I.. 'l[': tI'T F,>L.-rII',:] .:~u:- 'HII': H,:'LC Ili'-"LIII,'-TI'_di 'i."-.'", I II II Illi il I ,: I j,:]i...IC_: 'i.~,:.i¡ I'_iil .,lj".U_: T'>.'L .:Hlli':] ''l':'[= I':, [=':"ìT"-'II' . T.il [<'I~ I'.<'L '::-' ,[..l I"'_'L ! 1 i- t I~":;F L.'¡.i.~,L ':'~>J 111.', F 1 , 1: \ i I~ ~ i:: L [ :- r ~ '. ,I "':'~'. F (:.' T ,:' . ': ' :' F t H':- L F : I i 1-' ':- -c T I I'.. 1- ,- T : ':'[=[11 H':'LE. f-lT '::L[ ,Tli J: ['FILLE-F'..: ':',:'?l!i':'; [,UlH ,[II: C'<'F E.W,L.E. ':-':'11 [,IT I '~'I i.: i 1'_1 [, 1 J. i: L: lil_I[, [[li.:11', ,[¡: ,:],: I ii_ie, 1':-',:.':':'1 [, ,-~',: I II_i [, ¡: I.¡ : 11i_'[, '_ï-iL'A,}L'L.: ,,[[II,': c-tin [, L,?.: "_:~": F E: I .: 1 I . "1 L I':' i-i f 11.1 , ,'- 'Ï l'E I It [ ¡:; ,'- T'i i i: [ ,l 'E.' -~ F- I iIUC, i-,-1 I1E..~',.:I.'FU' TEî.IH:F.':"TI_IF',E ,In r: 1'1 1'1 1 I ! .: ,.. f: .1 L" ~ r. ': ~ I. 1 ': . . . .l ~ - [E': - ':'1 T 1'1.:' I r ,=- -! . ,.,,- . ,: ':' ;:, . 1,:, 1.1': r(,:, r.; - 4 ~ I> .. 1.1 1 ~ -1 . -' r-:":'L li'.IIIE[: bE':":.':' ~ .:. H F '::' ': f t: '.'':' ~ -. .:. 1-1 F :': 1 ~. ~I~. : .:1. I> ~ I. -! ~,I> I> -' . ~ . ~ I:II~I I:, I:, . I_I 'I_~' ,~, T ¡ 1:'. ". I. r: ""I I ~,:,:- T' j,~: T~=~r!r~F:'T'_¡:F: ÎI,'~ ~-=Ll!-:,TE. :-, ilT: ",,[, >,. E :",T ',IT: : 1'- _I ~ I: >i. ;- I. '_,i. : ~ ... -:- ;: 1 ' . . : ~ :, T F - . ,~: L:::: l,~~II..:ïï,: "">F::E..-TI II : ! :..:'!... ,; T:".I I'=":-¡- ~ I : f' I : '~,ij~ ~1:'~I~.I;.IE~j,~! M = , : " ~r I,:-,¡:;,r' :- : C, :1 1: ~ ~ ~ r rll ~ t- ..:!' ~ ~ 'l f '1. ~ :, 1: i : 1", ¡-. ':: : ~ 1" :: [, ~.. ~ ¡:::. - :. ,',j T.'I" ,. . , , . . . . . . . . . . . . . . . L':,;::, ::f::":lf1 ::,I:.:l :1-' fL,:I.. l"'r:.,,:.... .':' L:'~'j1.rl~ ['1.L"~:r:.::':1-1................ .[,:"f, ,"r:'l:.l.,:-~l 1 :'~ j'::.r: r:.r', ur,',. 1:..:'........... t.::-::.I:. i~'~ r:: ~ F '::- [-: co-:: I-I::: b:"l rl ~ . . . . . . . . . . . . . . I_'rl.j,= f 1. r,,~ j l~. ~ III~ ":~l=:J~' i:1 ~1 . . . . . . . . . . . . . . . . . . . . . I: <I . 111 I:;" fl~í,,~= ¡:-:-L r"':: r:I............ .I.II,j",fi ',,',:1 :',1= ~ ": rl t ';, I I.' ~ . . . . . . . . . . . . . . . . . . . . . . - .:, '.:' _:1 L ':- ,: I:. I', 1,1 r, 1 I:. , . . . . . . . . . . . . . . . . . . . . . . . ~'=,I:.I.lr"1 ':I:'=':lfl.,=-~r:l.:,r, El :,:1.'. '''.It-t..,,¡:,,,:.. .'.' - . -',! ':' - . - . ~ . '.".' .' II ',i',": :"= r" i. ,""= ':'L:1: r CO[ C T I', . I.ir,jt.: ,'1:'" 11.:~r" \:,:[:' ':-:..:j,' ':'[f.:"1:. '~I-,,,r,rl,,,l I ~ I 1":'[ ,:; F FE: F F. ? !' b I : I. r c., ~ ~'; ;['<1: <I [T CT II .: E- 1 'Alllli ,.,tlll! , '.'!lllIl 'AI!.l!.\ HF ,-=,.: III i [d:'':' ':. I 1 ~ ~ [, I: I ... I ~ I . . 1'- ¡-~ Iii i[,':,- ':' III i[,'.,,:, ,', II'¡ ¡[II' : ':' I~' ~ ¡-u i Ii'i[":' ~ ':' Ii:, III'::: ?.-: r '1 - ~ , 11 ! ' 11,,;-. ',1,-,"' " ':" .' ~ J ~, 1 . l ':' L.1 c .¡ :.. :: ':, I 1 .1 I I [.: " ,', ",:',[ .. i .~ ,= . ~ . l - . . c, -, ,',.j ',' . 1 ':.¡ - . "', . ,I '.'" ~ "J ~ " . ,", ,'.", ,') ,1 1 1 1 I" ~L r- ['E F T r [ I; ,'.'b Ii; " ['.:..: t'!, 1.1 ,:, F 1.11 1 Ld.l~ ~ b 1 F b I Ii ¡['II:' ~ 1:1 '~'rll U I ¡:: b I I; ì[iI: ~ '~'i'll II \ Ft.!' i Ii i[ - ' H!: ,,,,: " I. . ,~,' ,~ J . ~ "t 1 . :' l . ~ ':, ~ . - ""', ." . I'I_! II.' 1'1 . .:, ':, I-I I ~ 1.1 ~j 1. " I I . 1, , 1 l . .. l:.. L' .:. I:. I;:" ,j l I .. '~I l - L L i , I. J L' L 1 L , . . .. . ':..- " - . - 1- ~.: I:. F "= ~ j i r"~1 E": r [r, t: 'l L' ':: ¡-:LÌ 'c: - . . . . . . . . . . - ~ ::'.:' 1:- '. T ~.- ~I :L j ,= I : ':: L . ':l : '': t"I;lrll:............. :T.:~L -It .I_">~ ,. "= C . i : ~ ~' IJ l' ;., ':' . ':: 1 I 1 :, I,,:. . . . ,= 1.. : 1 ': rl 1 i I.Jrllt:. =.. I"" . . . . . . . . . . . 1 . 1:1. 1'1 L =, T:. ':' :' t" I ~,,-: , I'.w L' ;1 t 1. :. I' ~. . . . . . . ': I ~ I: I ~ .L I_I ! 1:1:-: t !rIUn'l ~ ¡", 'J'¿- 1 ::.1 I:.~ :.= r j. . I:,I~,I:, j I:, I:-d,,: '"!'_f--=:......"""'" .L.'~' 11,,:..1:. tll-=: II :,r,',.;:. . . . . . . . . . .':-1 ":L.It. ':":'.1 rl"J.::"'~=ll [I='t E" ). .1.:. 1-1':- ~,j '" ~. .: ':' 1"' .. i ,>:. t~I:IIII:::............. ~'T::LIE.. I.I':'~ c'::C ~,~:. :",d.:, L,:.-",,'l [I "Irl';: ... . ":' t :. 1': I', ! 1 urr,t:.o:. ( . . . . . . . . . . . 1 . ':' . ':' C':'~'~ ': f 1:..-:-rlo-::L";,i::L :rl...... .1:1~ I:I-~, jt~1 i i :, :.: iro"'.J iT, H',.." 1 .: ,,1 F'"= =- , r j . . ,", ': ':., :, ':, [11,,= T ..'f: :' . . . . . . . . . . . . . . . . i. :' L I" ~ 1'1 -- .[ 11,- 'JI" .1 '. "".', ~ .:, I I ~ ». ~ :. ,', : .j . ".1 ~ 1 >:,". . ., - -. . . - . - 1-.1 1" :. t: F : ",:111', ~I -.. I: '::, - -I '.' . ,~, ,: - -.. ,: .Jw J- . ...' -~. - . I:, r~ ~ ~~I ~ . I~, I .-,0:' . ~~ ::... . I~ i ~~ I ~ I : ~:I.: I' I~ :. :, j i", ~: .1:' " '. . " ;1 ~. . '~ ~ -: ':' , .,/- '-, -~ ':' 1'-' oJ : ,~ 'I ", I ,",,:, t . T '~I . '; ~, I> I~II: 8 T I:. r '- 8 ,> . .:' ~ T (I .. -; ':' ,>,> r . [ ï . T ,:]j ,~,~,':JI.!H -: T ç: > j:J '~'~':JI \ii ~ T ': ~ ':,j:J '~n 3111":1 '1->:',[. - '-'" '.18 -f ,-: 81." I. ,," -I ~ I.U :.l 1 - " " . :,,:' . ~ ::: ~ ( ~ I.J "I. U'-:'3'J--:- . ~ .I~ T f ~ -:.;. ,::- .: :: "-:--: : .: . ,¡ :: i ¡:J j : i '~H ! I .~, ! J \-\,'~,] :L.i :H ~ 3 : '111' Jy,']!j,l,:- 1':":'1 : I ¡I,' I I':' I ,L']:j ::1':,'=, :n,:'J-i :r.1EI13'J ::I:j.l:il : ,", 1 ~,l:! I "['.":,1 II'> ~J.i"1311 : 1,¡ I l';' j ~,' ,:' 'J ,'! I i :.lll 1": :-!I~'jL1IJ 'J,"III : ,LI!I.t7'n,Jl'fi,H '"'III L'l!"!':"~I.:' :'>{II 1-;' 'JI"III :(111' 3::i11J.';':J,jj¡'i3.l. ',lJ':J,".:;,]il 1.: 'J!'!I! 'j:-<.:J'], J:lI"¡,l;,":j]j¡j]ll..: Ilii'iii<" .;..ll:.l.l:-E:J:I : . ~..-" ~... ~-, = ' "1 'J I l.t -1 j : , [I j :!' :- ]'J I j':'IH:' 'JI'III : I, j ,] I-i~ i : <. "1]: .=":',:'': 1. ,J 1"11 : ":' c¡ ¡ " J T ,: II ::i'l 'J I"'¡ j :J:J'..l 'J'"II! 'C! I'> l,lJ ,j I I,:,.:' :3'1,:,i'l J :J,:<J : I LJ' iH:i'l'J .:'II"L::":,' =', ::iJTrI:J'J : 'Iil' J, L" .LLJ J ¡','II Ilj:i",' "~J,,'J ,,-'IlL,", 'II!; ]-¡"I'lli'>=' I!J'J '"I UTI 'IJ',T113;,1: 11':,HI!:i11 'Jll.'¡';:ìljjIF.::' r . ~- J '.:' J.j . .,' ;''I':dL<:J 1 J ;,;':-1 '/i'ii U.:' 1':',",'J 11' ,I i,' ,,"j , 11':,'J,l/' J :. :.. " . ': ': :' ~ T I.'.I~>~'~T I I . I~ 1:1 ~,' ~ T. 'I , 'I.' I> 8 1"'1:1 '~, ~ T I~I 8 <II> ':' ~ T. > . ':"> :,' ~ T '~, . T '>..-. T ':' . " r " "1 8 :' t > ~ ~ . ~, r :' - T . ~, r :: ~ T .1 . .:J r :' - T H':' LEi ,:¡':,E J I. '.I. I .1 'J ¡ ': ,:J Ii,:' ~ ':I ~ j ,] :j~"J 1,,'1", 1-':1 ':1':'llll, '.'.1, Lj I ~'lll:1 1: '1,>:,1 : :n~'1 i~' IIIIIII'.:;"¡ I : l'1:'1 I.' II,'III)'I! I! i :~'J'j,' IJ':'U:'lii1~'liI l1':'1-I : 11!:i:l I ,:¡jJ.j.: ~'liLl:.l':':j IH :'.lJ: -I,:',,:l31,li1 -::"~'1 il':'l..E,j : i í.i I T::.ilJ!iT ~":'l j,-".l' : , ,LJ' ~ j "I 'I 1 ::i'J 'J,j, : , ,III I 1. - "J i l:1 ~': ,'-,,: ,I I] ~ I' J j ',I : ,1 : J :;/"I..:Jl.. ]J;'lilY,,: JT'¡illLi,>J : 11"')':- -JJ, ,] j -:'l1..L"F',: J~J:'j :iI'I.: ]'oj ; l ~l,j'.,::- :'J]~'-::":'1 lI.'J :',L:"J ':iJ'J-;lH ,:,,:-, '. ï '~ . " ~ L - ',' . : T 1 - ':' . ~ T [. - ,', . ; T ~ ' :J - :i ':'H :i'J ::i<'¡-I j 1< ~ : 1 :'>JI,J , :i:! II J!"I~- J ': 1"' H.li3J l:J;'.i: : 1 ~ ~ ~ I J l '~.-, ~ ~ 1-1:.~ ~ ~: ~.¡ - -¡ '.1.. ~ - "- .- ~,; I"; -:- '.: : j:J j 1 .1 ¡:: ,I !"¡j 1..':' j : ¡ F, 'J " ,::: , - J. '-: ~ '-: t- _..I , : :i:J ~, "',,, .,. ... :; \ T ~, :'':J:.:¡'"'' . ..n ~ .j ~ :. .;:! ~... ~ "I' . 1- '.' . j = 1 :" .:. : . - 8 .. 8 8 8 7' 'IJ r: r! -:- ~ 1. .:1 ~. 1-' : ï" ,-:-' - C ;: r- =:: ::-,: C ~-:. ..:..~ -~ - ~ : ~ - : I --:. ' C' :-: '.;: .: ': ,-= ,~ ~ ~ . :- ? "':: :.. = ~ I = L : -: ~ . j '.,'f: --:- . . . . . '.' :. ..:. I~': - - , . " - - , ." . - ... : -, r.- "" ' . " . " a a . . . a a " " . . . " . .- ~ ;1 ~ - r' ~ [~!" =.; - '- :l : r: . . " a . . . . . . . a . . . . . C :- .'" i : 1: -. 1 ~ ~ 1 .~ = J ::':- r- r- \-1 .' rl! -: ~: . . a - . . . . . . " r Þ='~-: ! I;,. : ~. ~ III":':~ != -:- 1. ',:-:~:: ~":'':'':''_'::I-I."':'. F. ~rL""... a a..."..".1 I-I;'-::-:':"'I~ ~J [ 1" .:.:! '::' .: ~ .:: :- 1 !': ;ì. " . " " . . . . . " " a . . . . . . . " '. 1,1 . 1 - I I :. ~ .: -= '-, ~ -' ~ "... " C J a . . . . . . . " . . . . I. (, ~--: I 1,' -: :~ ~ l 'J :- . a " . " " " . a . . . . . . . . . . " . . - ':'.' c ,-= ¡~ ~ r I I I I ~"':..~ . a . . . . . . . . " . . . . " " . . . " . . 1:1 (11'= : '-:' r' 1. :-: I~IC j '-:' r : ~~ ':, ':.L : 1 -... ~ '- ... ~ I, [~. -' \ . : 1 - ':; ! : .: .1111 C';J 1~ U II' [,t:. t T , , - ~. 1 1'; ; [11.1.: ::, <, IIEHI Ilii[,':'~", t,:ï'T 11;, i[",' ~ ':' II .ï I ! ¡ilL j [II> -" I'.' I:I+Æ ¡niC,,», [,Hi':' illiC":':'" F [ t I ,~ : C rll'lll '-'1-111/1 Iii ¡ [II:' ~ ,> I., ~ 1 '~ I [II> -: I I F [ , ¡: F ..: F f I I III i[ ,>:; '.' III'i F":' -. ,', ! 1;, ; C,,> ~:,':' '-'111 III I' l L' 'Ii iE,'> >., '_'I'1í III tt:.T !ll¡C":':;,':' H~ II¡:i-II ¡li:i[,,:,:;J, ¡:II-~- [:'111 Il'ii[">:;':' ,,'f:;,> , :"1:'1 ¡ I'; I ï.':':;:' :' i : ':' ~I.,'>E 11';:[":'':':' '-; '_11 U H': III :[">,'" '., :'11 ¡: [ t I Ii iE,,:':" I:' 1- ., ,., : ' ,', '. .- :, -' 1 ' : ~ '1 i : ~ ~ i - -1 J '. I . ..J L - -- J l~ == . . a '- I.: rl i. ~ .: :"-Õ f: =-- ~ j :: :'U~..:: ~- t 1 l'!' 11 ,-H :'1'11111 '.'i-lI 11 I '.'¡'IIIII ',' I-nit I HF F 11-': ,~t~ ~ t I . b -' I I ,:; ,'r! " ,ï I E Î- flu, 1.1 ~ ;': ¡'I:: :, r, 1 '.11" .! ~ ~r:jl-cl':;! r 1_- :, ÍI' 1.:1 t~, - -; 1 ,', 1 . ~ ':' .~, I::' ': ~: ',' 1 J - . ':, - - 1,';, I " 1 ,< 1''- 1 '.' ': 1 : -' . I~ - - I~, - . . . . ~ ~, : : . 1 ' . ,:' 1 <, ':' 1 '. J ,'1.' 1. ',' '-' L ': 1 . i, 1 :; ~, . 1':'~, 1 :: 1 <I ~ ~ :. I . ':1 I_ I -, ~ I " '~I I , . I.., I -- '.' . 1 ' '1. .l - j . I. "I 11.-' ~ 1 L ,0 r: ¡:;..:::, j 1 r';1 E', t. F. I', r " l ~ 1:- 'l t c- - . . . - - . . . - -, .; ~ ;., . ':' :.. ;, ò r: F..::;,:J 1 t, ~ f:, L £' r,1. 1 t., t i 1 ': . . . . . . . . . . . i.: .: .:, :' . :, L- J _L ~ 1 r " 1 .L :. L -; .:., -: I~, . c.J I ~ ': '~'~I . ':, ,',. -..¡ " . ,II ~ 1 ':, . ,:', ':' ,I '.':'. i I '. :.- ..1.11.111 1-' . I. 1 - 1.11> 1"1 ',' . -- ~ "III' II ,.' I111I ':' . 1 '= ", ~.. '~,I L <I '~1 . I:, ¡'- "~ 1,1 - 1"1 I . i . ,,- 1 , .. I , . ' I .- I 11_, 1 . ) ", ._11 ;,.', .' 1 . :'.1 ". ' - I I. ~ " '.'.' ,.1 ] I I . I ~, - ? ': r' '1 ~ '': r, '" ".= . . . . . . . . . . . . . :-T _c: i. ~ t . ':' ':'.1 ~.=, C'l'~"= ,:"Jl- j.,o--,o l II :-11,,-':. . . . -= r = i : ï I I i U Ii d=, : J..." . . . . ~ " . . . . . .1 . I ~ I . I.' [':1 ~ ,-= ~ l '';''::11: (::I;~ J _'I I. . . . . . . '~I, ,>:.. 1 ':' 1¡;'"l!'.I'-'ÏI' ¡;~,'/-=l:"lt F',~:rj...:,':,~:.:,':, [1 i '" T J ¡: dO . . . . . . . . . . . . . . . . L':, 1I',.,r: ['d,-:, !i:'¡l"o...........:-T.:LIE'.<":":, F ¡-'.', 1 : :, 1 E. '-.. L T "¡::- T L " 1 1 -:- t- ..... . - - - - - : '7 L"" . 1. ,:,: ,-= !-¡;, 111'-: . " . . . . . . " . . . . L 1.= l' ~-l:. [, ~ t -::-. . . . . . . " . . . . . . . . . - . - . <. ~ r>~. 11.1 , "t 1 ~ 1 r, . . . . . . . . . . . . . . . . . . . :: 1 -~ T ;, i:'-': ! i "r",,: . . . . . . . . . . . . . . . . '.i\ WII, :'~, ¡¡ : ,... - r'l r:. i r, Ij ~ t 1. ~,rl II u ml~,,~ L . . . " . . I~I 1 ,1-':..1: -;-~l."-: '!::"":.......... .'lliiîl',ilil I: :tiljïl-:-rlt:................. :T~ L.I.:' l;I~'.I_~"tí';l t.it'" L:J1",". 'I" .' . ': 1 11_': - ~ . 1 ,'- 11 I "', 1,', 1 I I ~ '.1 . .I I ~ I -' "I . ¡'l r.= r F,,:' 'I :J 1 !"~ ~ ..- - ~ ~,'~I.. I:, . . - - . - . -.'. I.,. -' -- ~,'~1 ':' . ':, - ~! ,:":'.':, J --,;".L. ", 1 - ': -1 " L,: !'= L,:,~ : , I: . ,- 1- ~ -1 '~ L":.j'~ 1 :.. ,~, ,> '~I 1. - I.~ I.' : L,:';' .1. -': II I ',~ '1. -:-f'lt t f 1 - 'r=:- -1',1'1'1. ~ ~ 1 ,~ =- I ' " . - . l' ~~ 1 ~ ~. [" -.:... I' .....:- . . . . - . . . . . . i... 1 .: T , E. "'1 ~ ~i 1-:' .. . - :" -. =- . . - . . . . . . . . . . . . . . . . . . '"' ~ ,",; 1,:' .:..' - 1 ~ 1"1.. .. .. .. .. .. .. .. .. .. .. .. .. . . . .. . .. .: ~ .: - ..; -:-... ! r "1 '11':' .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. I_II r I J<'I JI ' ,~~ ;-,1:: 1 rll..J ~ i- 1. ~ II I i IJil'~~ :. L-" .. .. .. .. .. I>'~ :--::.,.... ~":--'71 ;1:'d'I'~...........1_11H'I,',Url ~ : 1- n 1'-: r I 1":. ;: .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. :~ T:.' !..-!: ~ ~ 1-, , ., I. E.: ï I, I"" I". . 1- -' ~ ! ;.' J '.' t: L 1 - L .L .l-: ."i :.' 1. 7. L ~ I ~ L.':" -- - .'.L. . .. : .=- - -: I I - -: -:: -' I 1. - ., - . -