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Home My WebLink About201-232 PTD 0 / _ 32 Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday,June 04, 2018 3:03 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: CD2-26 (PTD 201-232) 10-403 Revision Request Attachments: CD2-26 Revised 10-403 Procedure (Sundry 317-484).pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Attached is the revised procedure. Please let me know if you need anything else. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent: Monday,June 4, 2018 1:37 PM To: NSK Well Integrity Supv CPF3 and WNS<n2549@conocophillips.com> Subject: [EXTERNAL]RE: CD2-26 (PTD 201-232) 10-403 Revision Request Rachel, Send me a revised procedure via email. Strike through deletions and add additions in red so we can see where the procedure has been changed or added to. Thanx, Victoria Se�z�ut- State of A.:_ SCANNED JUN 1 $2 n 1 R Oil&Gas Conservation Commissio 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a.aiaska.00,. 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 Victoria Loepp at(907)793-1247 or From: NSK Well Integrity Supv CPF3 and WNS< > Sent: Monday,June 04, 2018 1:27 PM 1 To: Loepp,Victoria T(DOA)< • > • Cc:Senden, R.Tyler< >; Wallace, Chris D (DOA) < > Subject: CD2-26 (PTD 201-232) 10-403 Revision Request Victoria, CRU injector CD2-26 (PTD 201-232) is an injector with known tubing leaks. A 10-403 for a tubing patch repair was submitted and approved (Sundry#317-484) in October 2017. The 10-403 specifies setting a patch across the tubing I,lak found at 650'. However, after the sundry was approved CPAI identified another leak point at''7757'. Does the 10-403 require revision to set an additional tubing patch? If so,what is the easiest way to revise the existing 10-403 to include additional tubing patch(es)? Thanks, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 2 • i CD2-26 SUMMARY OF PROPOSAL CD2-26 demonstrates TxIA communication that was originally reported to the AOGCC in 2014. A leak detect log performed on 7/12/2015 indicated the well has a tubin leak at 650' depth. The well has remained shut-in since the time of this diagnosis. A 64-sand I Grt.k at,. N =a' .' w0.5 109 PirPorwftd Un 3/lb/2dlg. It's been determined that the reservoir would benefit from additional injection support in the vicinity of CD2-26,and CPAI intends to install.aretrievable tubing patch to return the well to service. Repair Plan Outline: 1. Pull existing plug from XN-nipple at 8,012' RKB:y 6e.f A. +U71,19 pet)G1� et.Gre,sS 1 - k .444 2. Set an injection valve in the Cameo DB-Nipple at 1,997' RKB. / 3. Set a retrievable patch across the tubing leak at 650'RKB. 4. Bring well back on injection. After stabilization,perform a State-witnessed MIT1A. 5. Submit 10-404 after passing a witnessed MITIA. N •ro Lf) 11/ v N 111C) s N h T ew r• ❑ P P r P P r r P O x (6 V O j E - Q7 '.) O L C•••1 N 4-'0 A h Y O LS (6 o C ro O E N L u a a c T o `.. Q UN Q ❑ , u c Q 6, Q 0 a9 Lu 0 0 0o 0 0o CO 0 CO CO o N a) O L m J 17 7 4 4 4 4 E E -o o v1 ',. '� O '6 R 16 16 CO CO CO CO e6 L -O .1- L E U). . H N M 7 c0 r C 1a u L 6) v m n o L c in Z Q u 03 o -, 73 2 il,oi *- O C L f6 a) 73 an u ❑ ❑ ❑ ❑ ❑ ❑ coo C L 61 L w J J J J J J J J J C - 0 C" W W W W W W W W W U V L H LL L LL LL LL LL LL L L �., eV a) N "O Q J J J J J J J J J - > at-+ - p.. 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December 20, 2017 Attn.: Makana Bender CEIVED EI rDATA LOGGED 333 West 7th Avenue, Suite 100 ■r \ i►V201C K BENDER Anchorage, Alaska 99501 DEC 2 2 2017 AOGCC RE: Multi Finger Caliper Log: CD2-26 Run Date: 11/8/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 CD2-26 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20397-00 Multi Finger Caliper Log 1 Color Log 50-103-20397-00 CANNED 'N Ax. ' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Signed:f 4L w Ieicet 1 SOF T4 • • � A\ I//,'s THE STATE �� , �, Alaska Oil and Gas gkI !! , ®fI,A.SKA Conservati®n Commissi®n 3-== 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0„0, ;/p• Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Travis Smith Well Integrity Supervisor NOVSOW 2 2 ?.01/ ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine River Oil Pool, CRU CD2-26 Permit to Drill Number: 201-232 Sundry Number: 317-484 Dear Mr. Smith: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, d2X(— Hollis S. French 4.1-) Chair DATED this 2- day of October, 2017. RBDT1S 1/u Ca 1 2017 . • • RECEIVED STATE OF ALASKA OCT 1 1Z 17 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ®G C21/7 20 AAC 25.280 l 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing Patch ❑�' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 201-232 ' 3.Address: Stratigraphic . P.O.Box 100630,Anchorage,Alaska 99510 50-103-20397-00 ' 7. If perforating: N/A 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CRU CD2-26 , Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380075 ' Colville River Field/Alpine Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,238 7,184 . 11,238 7,184 3,000 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 77 16 114 114 Surface 2,351 9-% 2,388 2,384 Intermediate Production 8,583 7 8,619 7,184 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,619-11,238/ 7,184-7,180 4-1/2" L-80 8,025 Packers and SSSV Type: Camco DB-Nipple Packers and SSSV MD(ft)and TVD(ft): 1,997'/1,993' • Baker S-3 Packer 7,912'/7,004' 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑., • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/18/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑., . GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Travis Smith Contact Name: Travis Smith/Rachel Kautz Authorized Title: iI ' rity Su l_ � Contact Email: N2549(c�Conocophillips.com WV Contact Phone: 659-7126 Authorized Signature: Date: lD I� COMMIS ION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' ' LI g Li Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ErNo ❑ RSDrtS c —OCT 1 3 2017 Spacing Exception Required? Yes ❑ No Zr Subsequent Form Required: 1 a— 1 0 APPROVED BY 'U ,Z I 1 Approved by: � COMMISSIONER THE COMMISSION Date: fa to // 0- 0/07 'TZ- '1,°`z ` itit Submit Form and Form 10-403 Revised 4/2017 Approved application is va f approval. Attachments in Duplicate • • RECEIVED y' . . ConocoPh I I I I ps OCT 1 1 2017 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 6, 2017 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-403 from ConocoPhillips Alaska, Inc. well CD2-26 (PTD# 201-232) for a proposed retrievable tubing patch to address a tubing leak. Please contact Travis Smith or Rachel Kautz at 659-7126 if you have any questions. iiiir Sincerely,gTravis Smith Well Integrity Supervisor ConocoPhillips Alaska,Inc. S • CD2-26 SUMMARY OF PROPOSAL CD2-26 demonstrates TxIA communication that was originally reported to the AOGCC in 2014. A leak detect log performed on 7/12/2015 indicated the well has a tubing leak at 650' depth. The well has remained shut-in since the time of this diagnosis. It's been determined that the reservoir would benefit from additional injection support in the vicinity of CD2-26, and CPAI intends to install a retrievable tubing patch to return the well to service. ✓ Repair Plan Outline: 1. Pull existing plug from XN-nipple at 8,012' RKB. 2. Set an injection valve in the Camco DB-Nipple at 1,997' RKB. 3. Set a retrievable patch across the tubing leak at 650' RKB. 4. Bring well back on injection. After stabilization,perform a State-witnessed MITIA. 5. Submit 10-404 after passing a witnessed MITIA. WNS INJ • CD2-26 ConocoPhillips & Well Attributes Max Angle&MD TD A.:1-,:i 117: Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Min(ftKB) conocovwelpc 501032039700 ALPINE INJ 91.54 9,180.87 11,238.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD2-26,10/17/2016 3.05:03 PM SSSV:NIPPLE Last WO: 43.21 1/20/2002 Vertcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PULL PLUG,GLV CIO pproven 10/17/2016 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread _ CONDUCTOR 16 15.062 37.0 114.0 114.0 63.00 H-40 WELDED Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 36.6 2,387.8 2,384.0 36.00 J-55 BTC HANGER;32.5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread f PRODUCTION 7 6.276 35.2 8,618.6 7,184.4 26.00 L 80 BTCM L �. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread salt« I OPEN HOLE 61/8 6.125 8,618.6 11,238.0 TubingTubing DescriptionStrings String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection 11 fTUBING 41/2 3.958 32.5 8,024.9 7,053.1 12.60 L-80 IBTM Completion Details II Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 32.5 32.5 0.00 HANGER FMC TUBING HANGER;METAL TO METAL TUBING 4.500 ; , HANGER SEALS CONDUCTOR;37.0-114.0 I. 1,997.1 1,993.3 0.28 NIPPLE CAMCO DB NIPPLE 3.812 7,912.3 7,003.7 62.16 PACKER BAKER S-3 PACKER 3.875 8,012.4 7,048.0 65.80 NIPPLE HES XN NIPPLE 3.725 8,023.5 7,052.5 66.37 WLEG BAKER WIRELINE GUIDE 3.875 NIPPLE;1,997.1 M Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8,012.0 7,047.8 65.78 PLUG 3.81"PXN PLUG BODY(4 x 1/4"EQ PORTS,26" 10/16/2016 OAL)-P PRONG(1.75"FN,OAL=72") Mandrel Inserts St au [ °" Top(TVD) Valve Latch Port Size TRO Run [ N Top(ftKB)3 (ftKModel OD(in) Sery Type Type (in) (psi) Run Date Com 1 7,798.3 6,9B)47.7 CAMCOMake KBG-2 1 GAS LIFT DMY BK 0.000 0.0 6125/20)6 5:00 Notes:General&Safety SURFACE;36.6-2,387.8 End Date Annotation 8/31/2010 -NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 7/12/2015 -NOTE: Possible tubing leak at 650'RKB,EL LDL GAS LIFT;7,798.3 PACKER;7,912 3 ®'r I PLUG;8,012.01 NIPPLE;8,012.4 Wf WLEG;8,023.5 I PRODUCTION,35 2-8 618 6-- OPEN HOLE;8,616.6-11,238.0 1 • • 20\. 2�� X201 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 12, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 �DATA LOGGED i'3 i2o�$ M. .BENDER RE: Leak Detect Log&Multi-Finger Caliper: CD2-26 Run Date: 7/12/2015 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 CD2-26 Digital Data in LAS format, Digital Log Image file RECEIVED 1 CD Rom 50-103-20397-00 SFP 01 2U1:; AOGCC 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: Signed: 1) ,A-17-a-frio‘,1) 6-eoteeet • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED April 01, 2011 l\ J 4 _ '''' APR C 8 2CW, Aissitatai& figs Cons. Commission Commissioner Dan Seamount AnCtnoragt Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 ) I -3 G9g Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor # 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD2 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD2 -14 50103203900000 2011770 4" n/a 16" n/a 5.4 3/14/2011 CD2 -16 50103204260000 2021440 4" n/a 14" n/a 3.6 3/14/2011 CD2 -17A 50103204060100 2051700 4" n/a 14" n/a 3.6 3/14/2011 CD2 -24 50103203770000 2010950 6" n/a 14" n/a 3.4 3/15/2011 CD2 -25 50103204180000 2020740 4" n/a 14" n/a 3.9 3/28/2011 CO2 -26 50103203970000 2012320. 4" n/a 16" n/a 2.7 3/27/2011 CD2 -33B 50103203810200 2011250 4" n/a 15" n/a 2.7 3/27/2011 CD2 -41 50103204240000 2021260 4" n/a 14" n/a 4.3 3/28/2011 CD2 -50 50103204150000 2020490 8" n/a 16" n/a 3.5 3/27/2011 CD2 -51 50103204410000 2022490 510" 0.80 15" 3/21/2007 3.9 3/27/2011 CD2 -56 50103204980000 2041500 SF n/a 15" n/a 3.8 3/27/2011 CD2 -58 50103204570000 2030850 6" n/a 6" n/a 3.5 3/28/2011 CD2 -59 50103205050000 2042480 6" n/a 6" n/a 5 3/27/2011 CD2 -60A 50103205110100 2091150 6" n/a 6" n/a 5.25 3/27/2011 CD2 -74 50103205910000 2081970 10'9" 1.20 9" 3/26/2011 1.7 3/27/2011 CD2 -76 50103206030000 2090980 32" n/a 32" n/a 9.7 3/27/2011 CD2 -78 50103206010000 2090660 6" n/a 6" n/a 1.7 3/27/2011 CD2 -466 50103205760000 2080950 8" n/a 17" n/a 3.4 3/27/2011 • MEMORANDUM To: Jim Regg ~ ~q ~~Z~~~a P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-26 COLVILLE RIV UNIT CD2-26 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv --~j~<-- Comm Well Name: COLVILLE RIV UNIT CD2-26 API Well Number: 50-103-20397-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ100719122831 Permit Number: 201-232-0 Inspection Date: 6/11/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-26' Type Inj G 'j'~ID 7003 ~ IA~ 2200 -t - ~ 3000 2900 2890 ~ 2012320 i SPT ~75p ' QA 800 P.T.D TypeTest Test psi 850 860 860 Interval 4YRTST p~ P ~ TUhing 3670 3670 3670 3670 ~ Notes: 0.6 BBLS diesel pumped. 1 well inspected; no exceptions noted. , ~~ req., i:- ,rt(~r ~_ Monday, July 26, 2010 Page 1 of 1 ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED APR 2 7 Z007 áÞ~' :J..3d- Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~.Z:~~. ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft !:I a I C02-1 205-118 4" na 4" na 2 , 2/18/2007 C02-2 205-109 6" na 6" na 2.5 2/18/2007 C02-404 206-054 6" na 6" na 1.8 3/22/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 ,om-26 201-232 10'5" na 4" 4/16/2003 1 3/812007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 vVest 7th Avenue, Suite 100 Anchorage, AK 99501 ~:?J~ dfJ \/ J- .""....'tt\¡;n ~?tl C () 20(}7 S\j'V'U"- Dear Mr. Maunder: ' D B" Enclosed please find a spreadsheet with a li~t of wells from:11ìe-.Aipi~e field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water ITom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, £~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft gal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-109 6" na 6" na 2.5 2/18/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 MEMORANDUM . State of Alaska .. Alaska Oil and Gas Conservation CommisJP TO: Jim Regg P.I. Supervisor ~~lf fl3DIC~ DATE: Wednesday, August 30,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHll..LIPS ALASKA INC CD2-26 COL Vll..LE RIV UNIT CD2-26 J.O\~a-~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,)gjZ- Comm NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT CD2-26 API Well Number 50-103-20397-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060828141753 Permit Number: 201-232-0 Inspection Date: 8/27/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-26 Type Inj. G TVD 7003 IA 2400 3250 3220 3220 P.T. 2012320 TypeTest SPT Test psi 1750.75 OA 820 920 920 920 Interval 4YRTST P/F P v Tubing 3520 3520 3520 3520 Notes Pretest pressure observed and found stable SCANNED SEP {) 82005 Wednesday, August 30,2006 Page I of I . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _lnserts\Microfilm _ Marker. doc ). CJ ç,i À~~'1 DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 Permit to Drill 2012320 Well Name/No. COLVILLE RIV UNIT CD2-26 Operator CONOCOPHILLIPS ALASKA INC SV74_¿ )j~ ~~ API No. 50-103-20397-00-00 MD 11238 ,--- Completion Date 1 120/2002 ~ Completion Status TVD 7180 / --- ------------------------------ -- --- - --- - - ---- ---- ---------- REQUIRED INFORMATION Mud Log No Samples No _____......oir~io~al surv."y ~---_._- - --------------------- --- ---.-------------------------- ------ ------ ---------------- -------------- --------------- --- -------------- -- - - n____- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Electr D!gital Dataset ed/Frmt Number Name - ~~rifiCf1ti9ri.\. Log Log Run Scale Media No -----------------._-- 1 1 D u 1156US\ìØ~¡f¡ê~t¡ÞI"1: -----,----- ~46Šê~NØt~~~ --." -._--- 1 ------------------------ Well Cores/Samples Information: Name Interval Start Stop Sent ADDITIONAL INFORMATION Well Cored? Y I ~ Daily History Received? Chips Received? Y IN - Formation Tops Analysis Received? ~ --- ----.- ---- ----- ------ -------------------------- ----------- - -- -------------------------------------------------- -----.------------------------------------ -----------------_0------- ---------------. ------- -- _.._--------- -------- Comm;nt~~ OJl>r~ -1\vrcs-~r~-- C ß v \. ~ Fo\.<{¿¡ ~ "- .f"7 r - 8)... ~- ù '-a-& Jl-á.- rll\.' \I.¡~~ ) ~ Mc.lv<,VL~}., t')ëJù.... \ [ I \-0 ~cI!/d- ) V3J~. ~ J ~ f' V) \.... o-r.-J.- ~- ~ WAGIN Current Status WAGIN ~ ------ ---------------------- - --- ---_on--- ----------- --- (data taken from Logs Portion of Master Well Data Maint) ( Interval OH / Start Stop CH Received Comments ---- -----------------------------------] 2361 11195 Open 10/3/2002 -~:~-; ; ::: -- ~:::- ; ~;: - Di9iu.~~,:og~- Received Sample Set Number Comments Ò/N GIN ( " ~:::=~:-:Re~;:~~~~=-'~-~"- =-~-- ---;;:t~:~=- :Tj a iQ~---~- . >11-'" I~ \J~III~lll I UI-' I III ( Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry.C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> ( Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cement. I believe 34 wells were treated. Chuck Scheve > and John Crisp were notified but declined to witness when we told them what > we were doing. Some time past we had agreed to submit a 10-404 for this > kind of work. Due to the number of these, is a 10-404 needed on each well? > I don't want to commit the time to doing this if it is not necessary; > 10-404's are time consuming to prepare. Would a list of the jobs suffice, > or something similar? We have the well numbers, depth to cement top, and > sacks used to fill the void. My proposal would not affect future > submissions of 10-404's for this work. What do you think? Thanks! > > Jerry Dethlefs (See attached file: tom_maunder.vcf) 1 of 2 4/24/2003 7:55 AM j "¡JIII ~ lJ ~11I....11l I U¡J I III , t.' . ~--- ( ,--.----- -~ Name: AOGCC ALPINE cement top outs 04-16-03.xls ~AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 ,-." ,,- - .".." -..... -....."...." - "..... -.- "" -" "" .." ". -..-" - - - - ,,- ......-...."" - ".". -... -.. ..-., ". ... ._"..... -."..-. ...-...".- _.. ".. .... .... ".. - """"'.. -.. """ -. -".... ".. -" - ......- - . - .. "... -..".... "".." ".... .".... -. ....--. -..... - _.-.-" - -..... ..".. .......""" ."" -, -'" - - ...... - -" ......." ...." ."....""""" ..."" "."." ..."""", -..." .." - "..... -" . ... "......".. "-....".,,. ----...- --...- ~ .. Name: Cement Top Fill AOGCC Letter 04-23-03.doc DCement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder@admin.state.ak.us> I Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of2 4/24/2003 7:55 AM ( Co nocÓPh ill i pS Alaska f P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD 1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment Annular Disposal during the first quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-18 31501 100 0 31601 306 0 31907 January March 35-15,35-16,35-22,35-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Oec 2002 Jan 2003 35-10,35-15,35-09,35-14 CD2-48 20144 100 0 20244 375 11381 32000 Oec 2002 Feb 2003 CO2-45, CO2-35, CO2-08, CO2-28 CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CO2-08, CO2-48, CO2-46 CD2- 22 30773 100 0 30873 380 0 31253 Feb 2003 March CO2-08, CO2-36, CO2-51 2003 3S-10 21104 100 0 21204 388 0 21592 March March 35-21,35-08 2003 2003 lC-22 26944 100 0 27044 0 0 27044 March March lC-190, lC-174 2003 2003 Puviaq #1 4616 100 0 4716 15 0 4731 March March Puviaq 1 2003 2003 ( I( Total Volumes into Annulifor which Disposal Authorization Expired during the first quarter 2003: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Inj ected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 2P-427, Heavenly CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Oec 2002 CO2-13, CO2-37, CO2- 2002 35 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2- 26 29146 100 0 380 29626 Open, Freeze Protected 5eptember October CO2-38, CO2-44, CO2- 2002 2002 29, CO2-13 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 CO2-50, CO2-46, CO2- 22 :) , t ~ C) APR 1 6 2003 ~ Alaska Oil & Gas Cons. Commission & Anchorage ÇL; ECEIVED ,- i ¡ \ <;. ~.- ()"-:\ (q_.~ >~tD- \~ ) \<;~.-\~O, ¡dOO~-~\. '( \~<:,- \';)<6: C- : :;;;:::JJ- a ~ \ C;c;-o~L\ d 0\- où(.o \C1, "t-)S , \~~-{)~w~ -' : .)OD... \ \ \~\'-b) ;;cþ--t:§:)'6 ,f¡ - dO&f;f::, d C)C)- \"- ~ \ C\~-\O Jo.Q"~,þ' '-\.3 \ ~ t;- \ \ ,J(:f:)~ DD~~_", , \~~-\~ - ,;) C)d .,,- ':ì'=':\., j~"d-\ ~ d i ;)ú)""b , J~-~~ död~'") ,-\1 JQ-(JJ~ )t)\-ò J-()\ -\) ðO\-\~\' 1 :-\ '6ð d-G ct.:-\~ J-O~~() ðO".d-\Q ')0 \ - d '1t1 : )-D "d..(j dOD-- \ 4 .( f ConocoPhillips Alaska, Inc. Suñace Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WEllS DEPTH VOLUME TYPE SACKS -.--------- 1---------- - ------ -------- .-'-------- -----.---.---- BBlS Cement -. ------ --------..---- CD1-1 2.25' 0.3 WI 1.8 --- -------. .---------.-.---,----- ----.._-- --'-- -------------- - CD1-2 4' 0.6 WI 3.6 -- CD1-3 10' 1.4 MI 8.5 -.- -_.-- CD1-4 7.33' 1 P 6.0 CD1-5 4' 0.6 MI 3.6 ?:> CD1-6 10.42' 1.4 GI 8.5 ------ ---.. -- CD1-16 14.33' 2 WI 12.1 -.- --.---- -- ç CD1-17 8.75' 1.2 P 7.2 ------ --..---- ---- -' CD1-21 13' 1.8 MI 10.9 .-.----- ----.-------.- -------------- '-----.- ---.----...----.------- J CD1-22 1.83' 0.3 P 1 .8 ----.---.----. - - --------- --'--- 0 CD1-23 15.42' 2.1 MI 12.7 -- -------- (.. CD1-24 2' 0.3 P 1.8 - --.- -.--- --------- -------...----..-- CD1-25 5.66' 0.8 P 4.8 ---- ---------- ------- f.o CD1-27 18.83' 2.6 P 15.7 --------- -.--..-------,-.------ ------ ------- f------ CD1-28 6.75' 1 P 6.0 ---------- ----,_._--.---- 1--.----- ---,------.-- -"----- L{ CD1-32 8.33' 1.2 P 7.2 ---- ---. ..----------------. --------.------- -'-'---"------'---- -.-.------..-----.- CD1-34 41 .83' 5.7 P 34.4 ------,---_. r-----------.--- -----...-------- ----.-.-.----.. -------.--- ) CD1-36 16.75' 2.3 WI 13.9 -.-----.---- --.--.--.-.--.--..-.--.---- ----------. ---."-,.-,,.,----------,. ------------ CD1-38 3.5' 0.5 P 3.0 ------'---- ------.--..------- ---------------'- -------------- --------".---'.-- <; CD1-42 5.83' 0.8 MI 4.8 -----.----..----.-- .-----.-.- -- ----------- :.-._--- CD2-16 1 1.66' 1 .6 INJ 9.7 \'6 -------.--- '------.----------------- --.-------..---.--- -------.---.--.----.- 1-------.----. CD2-17 18' 2.5 INJ 15.1 -----_. .------ .------..--. ------.'-'--.- ------------..--- CD2-19 1 1 .66' 1.6 P 9.7 -------- --------------.--- --------..----- 1----.----------- ----------_._---- :;) CD2-22 13.5' 1 .8 INJ 10.9 --.--,----.---..- ---.---,,-..--------------.-- ------------...-.---- ---.--..--...---------- -----.---.----------.. CD2-25 27.25' 3.7 P 22.3 -----_.,-----,._- ,----.-.--,..--.---...-- -.. ------ -------.------ ~? CD2-26 1 0.42' 1.4 INJ ,8.5 --.-.----------- 1---..--.--------------.-- -----.--- ------"-'--- .-.-------- ------.-_._--.- CD2-32 8.5' 1.2 INJ 7.2 ------.----.----, .-----.--'---"'--------'--- -..-.---.------ ..---.--,-.---.---- ----------'-- ,~ CD2-33 - 7' 1 P 6.0 ------ ,----------_._,-- ----------- ,-------------- --------- CD2-34 4' 0.6 P 3.6 to --.----.------- -----..-----------.---., -----.-------"" -- ---- ------,---....---. _._----,---------- CD2-41 11.83' 1.6 P 9.7 ,-,-"','",,'" ,-----'--'----- ---.-----.- -.-----_._- .-.. ,--.---...------. --.--------..------ CD2-46 7.42' 1 INJ 6.0 ,Î) --.---..----..------.-,------.. ---.--,----.--.--.,------,,-'----'-.-"--. -.-.---.----.--...---.-----.---.- .-----.----.-. -,-_._------------ .-.-----.- --.-_.- .__n______--- CD2-48 10.33' 1.4 INJ 8.5 ---.--'---"-----"- ..-._-- ------,-.-..---...-.-.-.------..-.. -.-.-----.--..-.-------,-..----. ----.---.-....---...'-----------'-- .-- -------------..--.----- CD2-49 9.33' 1.3 INJ 7.8 ~ --.-.------------.---- ---------..-..-..--.--..-.--,- -.-------------.------------- .--------,.--.----.-. ----.- -.---.---------------- ---- CD2-50 1.66' 0.25 P 1 .5 'o!~ d-O \... \ d- \.-\ db\-\ð5 Iff \.., ~f) ~ ~, ~ (""' 13 ( 'f " " A I D' ld . hfi 12003 nnu ar lsposa unng t e lrst quarter 0 . . h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-18 31501 100 0 31601 306 0 31907 January March 35-15,35-16,35-22,35-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Dec 2002 Jan 2003 35-10,35-15,35-09,35-14 CD2-48 20 144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CD2-08, CD2-28 CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 CD2-22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2.;08, CD2-36, CD2-51 2003 3S-10 21104 100 0 21204 388 0 21592 March March 35-21, 35-08 2003 2003 lC-22 26944 100 0 27044 0 0 27044 March March lC-190,IC-174 2003 2003 " Total Volumes into Annulifor which Disposal Authorization Expired during the_first quarter 2003: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 2P-427, Heavenly CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 CD2-13, CD2-37, CD2- 2002 35 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-26 -29146 100 0 380 29626 Open, Freeze Protected September October CD2-38, CD2-44, CD2- 2002 2002 29, CD2-13 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 CD2-50, CD2-46, CD2- 22 1 ( ~I Randy Thomas a OJ - d j; Greater Kuparuk Team Leader Drilling & Wells - ConocÓPh ¡IIi ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RL Thomas @ ppco.com January 10,2003 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal, Fourth Quarter, 2002 Dear Commissioner: Please find attached the fourth quarter 2002 annular disposal for the Kuparuk, Alpine and Cook Inlet Fields. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2002, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2002. Please call me at 265-6830 should you have any questions. Sincerely, -\-.~ .. \~ R. Thomas Greater Kuparuk Team Leader RT/skad cc: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental B. Morrison / R. Overstreet Sharon Allsup-Drake Well Files RECEiVED \ ^.N 1 ¡::; I)O()-~I" . ..{--"'.. ! ,) L- \. \., A.\aska Oil & Gas C.~~~~ Commission An.chc~1 ëì~!1(; Annular Disposal during the fourth quarter of 2002: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-26 15244 100 0 15344 380 13902 29626 September October CD2-38, CD2-44, CD2-29, 2002 2002 CD2-13 CD2-34 22895 100 0 22995 372 0 23367 Oct 2002 Dee 2002 CD2-13, CD2-37, CD2-35 CD2-48 11281 100 0 11381 375 0 11756 Dee 2002 Dee 2002 CD2-28, CD2-45 3S-07 18155 100 0 18255 216 0 18471 Dec 2002 Dec 2002 3S-09,3S-14,3S~10 3S-18 206 100 0 306 0 0 306 Dec 2002 Dec 2002 3S-18 (" ]'¡ l Vt l A l'fi h' hD' lA h . E . dd . h fi h 2002 { ota 0 urnes Into nnu I or W IC lsposa ut orzzatlon Xfnre urzng t e ourt l uarter . Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-39 29466 100 0 379 29945 Open, Freeze Protected October Sept 2002 CD2-15, CD2-47, CO2- 2001 44 CD2-14 30597 100 0 376 31073 Open, Freeze Protected November March CD2-45, CD2-47, CD2- 2001 2002 32, lC-14 32115 100 0 0 32215 Open, Freeze Protected October January 1C-109, 1R-36, 1C-24 2001 . 2002 2P-438 30331 100 0 212 30643 Open, Freeze Protected October December 2P-420, 2P-415, 2P-429 2001 2001 CD2-15 31181 100 0 371 31652 Open, Freeze Protected March 2002 September - CD2-50, CD2-25, CD2- 2002 44 CD2-47 26874 100 0 375 27349 Open, Freeze Protected December January CD2-34, CD2-26 2001 2002 CD2-45 22514 100 0 377 22991 Open, Freeze Protected January February CD2-49, CD2-17 2002 2002 C kIl A l D' ld . h fi h 2002 00 net nnu ar lsposa urmg t e ourt quarter . h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 472 100 0 572 0 67224 67796 January October Hansen # 1 2002 2002 113'Y'1 / J5LJC(; 1311 I 3£.-) lo 13LJ5 113c.J~ ( ( ~oa-IO'ö ' ao~--o~~ dDd- oaCJ ;{o (- ò3d- ~Dd-II~ ¿;¡ O¿)~o ( "3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 November 4,2002 RE: MWD Formation Evaluation Logs - CD2-17, CD2-19, CD2-26, CD2-32+PB1, CD2-46 & CD2-48, AK-MM-11207 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: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AI< 99518 6 LDWG formatted CD Roms for previously delivered Final LDWG data. Note: This data does not replace the previously delivered data. RECEIVED NOV °6 2002 Alaska o~ & Gas Cons. Commilfaion Anchorage ro ~ ........ CJ () ( ( K h h"d if 2002 k dAl' A ld . 1 D' uparu an lplne nnu ar lsposa unng t e t l~ quarter 0 . . h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-32 12701 100 0 12801 379 18636 31816 June 2002 July 2002 CD2-19, CD2- 23, CD2-41 CD2-50 31530 100 0 31630 370 0 32000 July 2002 Sept 2002 CD2-41, CD2-19, CD2-16, CD2-38 lC-18 27969 100 0 28069 379 4276 32724 June 2002 July 2002 1C-104 CD2-39 1966 100 0 2066 379 27500 29945 Oct. 2001 Sept2002 CD2-15, CD2-47, CD2-44 CD2-15 10459 100 0 10559 371 20722 31652 March Sept 2002 CD2-50, CD2-25, CD2-44 2002 CD2-26 13802 100 0 13902 380 0 14282 Sept 2002 Sept 2002 CD2-38, CD2-44, CD2-29 C kil A h h'd if 2002 1 D" ld . 00 n et nnu ar lsposa unng t e t l~ ,uarter 0 " " h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 52255 100 0 52355 0 14869 67224 January Sept 2002 Hansen # 1 2002 ¡'¡tl~l lA h . ( E . dd . 2002 th th' d A l'fi h' hD' oa 0 urnes lnto nnu l or W lC lsposa ut onza lon xplre unng e IT< quarter " " Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-24 33524 100 0 375 33999 Open, Freeze Protected July 2001 Oct 2001 CD2-33, CD2-39, CD2- 14, CD2-15 lC-26 34160 100 0 0 34260 Open, Freeze Protected August - September lC-123, lC-119, lC-102 2001 2001 2N -332 31453 100 0 325 31878 Open, Freeze Protected August 2001 Sept 2001 2N-348, 2N-350 lC-16 32017 100 0 0 32117 Open, Freeze Protected Sept 2001 Oct 2001 lC-102, lC-131, lC-125 R ECEIVED OCT 2 4 2002 A1aska Oil& Gas Goos. Commission Anchorage It It cQO/-~& //J5lp WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs - CD2-26, October 2, 2002 AK-MM-11220 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: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20397-00. RECEIVED OCT 0 9 2002 AJalka Oft & Gas Cons. Cormniliøn Anct1orIge . A L D' Ld . th fi t if 2002 ~ J -~¿);1 nnu ar lsposa urzng e lrs quarter 0 . . h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volome Volome Quarter Protect Total Total Date Date Volumes 2P-417 25534 100 a 25634 887 5431 31952 October March 2P-448, 2P-422A, Grizzly #1, 2001 2002 2P-451, 2P-441, 2P-420 CD2-14 16138 100 a 16238 376 14459 31073 November March CD2-32, CD2-47, CD2-45 2001 2002 1 C-14 9626 100 0 9726 0 22489 32215 October January 1R-36, 1C-24, 1C-109 2001 2002 CD2-1S 10346 100 0 10446 371 0 10817 March March CD2-50 2002 2002 CD2-47 16459 100 0 16559 375 10415 27349 December January CD2-34, CD2-26, 2001 2002 CD2-4S 22514 100 0 22614 377 a 22991 January February CD2-49, CD2-17 2002 2002 2P-41SA 4843 100 a 4943 52 0 4995 March March Grizzly #1, 2P-431, 2P-441 -< 2002 2002 CD2-26 a a 0 a 380 0 380 -- -- Freeze protect only for CD2-26 CD2-49 a a a 0 386 0 386 Feb 2002 Feb 2002 Freeze protect only (' ]'¡ L\f¡L A l'fi h' hD" LA h . E . dd . h fi' 2002 ota 0 urnes lnto nnu l or W lC lsposa ut orlzatlon xplre urzng t e lrst quarter . . Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volome Volume Volume Volume Status of Annulos 1D-32 23162 100 a 337 23599 Open, Freeze Protected January February ID-39 2001 2001 IJ -03 30024 100 a 0 30124 Open, Freeze Protected March 2001 May 2001 11-09, 11-14, 11-10 ( 04/10/02 Sc_lunIbellger NO. 1977 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine f Well Job # Log Description Date BL Sepia Color Prints CD ( CD1-37 j Gq ...dJ- INJECTION PROFILE 03/17/02 1 1 CD2-26 dD J-';)3 d. INJECTION PROFILE 03/14/02 1 1 WD-02 IY9. - ~55? TEMP BASELlNEIWARMBACKS 03/16/02 1 1 WD-02 RST WATERFLOW LOG 03/17/02 1 1 WD-02 ",II INJECTION PROFILE 03/02/02 1 1 - -~ JJw r' SIGNEn~" L .. \ ~) RECEIVED DATE: " r") D 1. '? 2002 hr r \ L Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-831Ã1åiï'ðltI3asCons.com.,. Anchorage 03/25/02 Sc_lumbepger NO. 1921 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine ( Well Job# Log Description Date BL Sepia Color Prints CD .( CD2-26 22108 SCMT 02/10/02 1 ~Ol'" d_-:<';:} III .. .1 ....... '8 ..... fPII" .. II ,-. fIR- _8 V SIGN~ (I. Ch~ t.t~R 2 9 2002 Alaska Oil & Gas Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank -,horage DATE: ( ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 March 22, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-26 and CD2-26PB1 (201-232) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-26 and the plugback operations on CD2-26PB 1. \ If you have any questions regarding this matter, please contact me at 265-6120 or Vern Johnson at 265-6081. Sincerely, ~. ~ Qt( G. C. Alvord Alpine Drilling Team Leader P AI Drilling --- ',I ,I :' '-, '"II , ,: -, c_' GCA/skad f.:",.' In:", I ','~i, ! ,,- , :r:';'Jrt':",..:I! ,::',,:: ,':; I, ' ( STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1- Status of well Classification of Service Well Oil D Gas 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface D Suspended D Abandoned D Service [2] . - , ",:':' WAG Injector ffRlfU'~ 7. Permit Number , .. Y., Q~ 201-232 I . ~~ 8. API Number ~ .13. :-\ 50-1 03-20397-00 --, -"~"" 1825'FNL,153ZFEL,Sec.2,T11N,R4E,UM At Top Producing Interval 1721' FNL, 822' FWL, Sec. 1, T11N, R4E, UM At Total Depth 1066' FSL, 2206' FWL, Sec. 1, T11 N, R4E, UM (ASP: 375406, 5972081) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 33' feet ADL 380075 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. January 3, 2002 January 18, 2002 January 20, 2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 11238' MD I 7180' TVD 11238' MD I 7180' TVD YES [2] No D 22. Type Electric or Other Logs Run GR/Res 23. (ASP: 371708,5974532) --,- -. -,_.--, -, - - -'. -. .-- . " "-' ' - ~ - . 9. Unit or Lease Name Colville River Unit 10. Well Number CD2-26 & CD2-26PB1 (ASP: 374064, 5974596) ¡ -f!:-..~-:"~;\' : ( l"-ð~Ç: f " I[.r,. '.-~- -" -.:..~I.I-'-I'--¡'-"rl,.. ' , _I,......, " ~ 0, r ., 'J/..¡ ;; , -Þ~~- ~ ""---"\-""'~-....,..r,..n"~.,,,,,,,...,.> 11. Field and Pool Colville River Field Alpine Oil Pool 15. Water Depth, if offshore N/A feet MSL 20. Depth where SSSV set 1997' Landing Nipple 16. No. of Completions 1 21. Thickness of Permafrost 1556' MD CASING SIZE 16" WT. PER FT. 62.5# 36# 26# GRADE H-40 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2388' Surface 8619' HOLE SIZE 42" CEMENTING RECORD 305 sx AS 1 455 sx AS III Lite, 235 sx Class G 162 sx Class G AMOUNT PULLED 9.625" 12.25" 7" 8.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25, SIZE CD2-26 PB1 cement plug dressed off to 271' to start CD2-26 sidetrack TUBING RECORD DEPTH SET (MD) 8025' PACKER SET (MD) 7912' 4.5" open hole completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Plug #1: 719' - 175' Plug #1: 81 bbls Class G Plug #2: 478' - 84' Plug #2: 329 sx Class G Plug #3: 344' - 95' Plug #3: 260 sx Class G 27. Date First Production Not applicable Date of Test Hours Tested N/A Flow Tubing Casing Pressure PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) WAG Injector Production for OIL-BBL GAS-MCF Test Period> Calculated 24-Hour Rate> WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 28. psi CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. '.' ..-, -, " ,- N/A ,'- - ".,-' ,- . -~ , " " I: [ i ~ II Ii !, Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~(- Submit in duplicate RBDMS 8Ft MAR ? 7 2002 f- ,I 29. \ GEOLOGIC MARKERS 30. \ FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested. pressure data, all fluids recovered and gravity. GOR, and time of each phase. CD2-26 Top Alpine D Top Alpine C Base Alpine 8292' 8380' 11 093' 7136' 7155' 7183' CD2-26 PB1 TD 719' 719' CD2-26 PB2 TD 490' 490' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Vern Johnson 265-6081 S;gned ßi L O~ Chip Alvord Title Alpine Drillina Team leader Date ?/.2.¿ I 9 L 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 (OF, 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 1, I. \,, ,. \: I, \: \, Ii Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/2/2002 00:00 - 07:00 07:00 - 14:30 14:30 - 15:00 (' PHILLIPS ALASKA INC. OperationsSu mmary . Report CD2-26 CD2-26 ROT - DRILLING doyon1 @ ppco.com Doyon 19 Spud Date: 1/3/2002 End: 1/20/2002 Group: Start: 1/2/2002 Rig Release: 1/20/2002 Rig Number: 19 - Description of Ope rations 7.00 MOVE DMOB MOVE 7.50 DRILL RIRD SURFAC 0.50 DRILL OTHR SURFAC 15:00 - 15:30 0.50 DRILL SFTY SURFAC 15:30 - 18:00 2.50 DRILL PULD SURFAC 18:00 - 18:30 0.50 DRILL OTHR SURFAC 18:30 - 19:00 0.50 DRILL OTHR SURFAC 19:00 - 00:00 5.00 RIGMNT RGRP SURFAC 1/3/2002 00:00 - 01 :00 1.00 RIGMNT RGRP SURFAC 01 :00 - 13:00 12.00 DRILL DRLG SURFAC 13:00 - 14:30 1.50 DRILL TRIP SURFAC 14:30 - 16:30 2.00 DRILL PULD SURFAC 16:30 - 20:30 4.00 DRILL OTHR SURFAC 20:30 - 21 :30 1.00 CEMEN PCLR SURFAC 21 :30 - 22:30 1.00 CEMEN CIRC SURFAC 22:30 - 23:30 1.00 CEMEN PLUG SURFAC 1/4/2002 23:30 - 00:00 00:00 - 01 :00 01 :00 - 08:00 08:00 - 10:00 10:00 - 12:00 12:00 - 13:00 13:00 - 16:00 0.50 CEMEN TRIP SURFAC 1.00 DRILL OTHR SURFAC 7.00 DRILL OTHR SURFAC 2.00 DRILL OTHR SURFAC 2.00 DRILL 1.00 DRILL CIRC SURFAC TRIP SURFAC 3.00 DRILL PULD SURFAC PJSM - Move pits,motor complex, skid floor, move rig & spot over well, mate up pit/moto r complex, pipe shed, & ball mill - hook up water, air, & steam PJSM - NU diverter system - flow line, turn buckles - drain lines - mud line - take on sp ud mud - prep for spud Function test diverter - perform accumulator recovery test - AOGCC waived wittnessing of test Held pre spud meeting with drilling team MU BHA # 1 - bit, motor, MWD, UBHO sub - Orient Fill hole wI water - check for leaks - test su rface equip to 3500 psi RIH & tag up @ 75' - C/O ice plug in conduc tor f/ 75' to 88' Repair electrical line on top drive ( electric al connection on top drive caught fire while cleaning out conductor) Repair electrical cable for top drive - PU 3 j ts. HWDP & test top drive CIO ice plug f/ 88' to 114' - Spud -in @ 011 5 hrs. - Drill 121/4" hole f/ 114' to 719' - R un Gyro surveys - well path crossed propose d path of future well - Confer with Drilling E ngineer ADT - 4 ART -.6 AST - 3.4 POOH f/ 719' - Stand back HWDP, jars, 1 st d DC's LD bit, motor, MWD, Stab, & XO's Prep to set plug - Dowell blending cmt - ser vice rig MU mule shoe & RIH wI 5" DP to 713' Circ & condo mud for plug job PJSM - Set cmt plug fl 719' to 175' (calc. to p) wI 81 bbls 17.0 ppg class G wI .2% D-46, 2% CaCI, 0.09 Gal/sk D-185 - Displace to e qualize- CIP @ 23:20 hrs - break out cmt lin e POOH to 95' PU stack washer & flush f/ 90' to flowline - function annular & flush diverter stack - bl ow down lines WOC - MU 12 1/4" bit, bls, xo for cmt clean out RIH wI bit on HWDP - wash down f/ 97' to 33 8' - circulate cement contamiated mud & cmt - Tag plug @ 341' Circulate & condition mud Blow down TD - POOH - LD bit, bs, ox - clea r floor PU BHA #2 - Adjus motor AKO to 1.6 - MU M WD, UBHO, 1 std DC's Printed: 3/5/2002 2:02:45 PM ( ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PHILLIPS ALASKA INC. Operations Summary Report CD2-26 CD2-26 ROT - DRILLING doyon1 @ppco.com Doyon 19 Page 20f7 Start: 1/2/2002 Rig Release: 1/20/2002 Rig Number: 19 Spud Date: 1/3/2002 End: 1/20/2002 Group: 1/4/2002 16:00 - 20:00 20:00 - 23:30 1/5/2002 23:30 - 00:00 00:00 - 02:00 02:00 - 03:00 03:00 - 07:00 07:00 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 - 11 :00 11 :00 - 22:00 22:00 - 23:30 23:30 - 00:00 1/6/2002 00:00 - 01 :00 01 :00 - 04:00 04:00 - 04:30 04:30 - 05:00 05:00 - 05:30 05:30 - 06:00 06:00 - 23:00 23:00 - 23:30 1nl2002 23:30 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 03:00 03:00 - 04:00 04:00 - 05:30 05:30 - 07:30 4.00 DRILL 3.50 DRILL 0.50 DRILL 2.00 DRILL REAM SURFAC DRLG SURFAC SURV SURFAC TRIP SURFAC 1.00 DRILL PULD SURFAC 4.00 CEMEN OTHR SURFAC 2.00 CEMEN TRIP SURFAC 0.50 CEMEN CIRC SURFAC 0.50 CEMEN PLUG SURFAC 1.00 CEMEN TRIP 11.00 CEMEN OTHR SURFAC SURFAC 1.50 CEMEN TRIP SURFAC 0.50 CEMEN CIRC SURFAC 1.00 DRILL TRIP SURFAC 3.00 CEMEN OTHR SURFAC 0.50 CEMEN TRIP SURFAC 0.50 CEMEN CIRC SURFAC 0.50 CEMEN PLUG SURFAC 0.50 CEMEN TRIP SURFAC 17.00 CEMEN OTHR SURFAC SURFAC 0.50 CEMEN TRIP 0.50 CEMEN CIRC SURFAC 0.50 CEMEN TRIP SURFAC 1.00 DRILL PULD SURFAC 1.50 DRILL TRIP SURFAC 1.00 RIGMNT RSRV SURFAC 1.50 DRILL DRLG SURFAC 2.00 DRILL TRIP SURFAC Wash f/ 114' to 341' wI motor @ 71 Azi. Gyr 0 @ 330' Drill 12 1/4" hole f/ 341' to 490' ADT.8 AS T.8 - hole direction not responding to moto r setting of 71Azi. POOH to 390' - resurvey every 30' POOH - check orientation on UBHO, MWD, & motor all OK LD BHA - confer wI Drilling Team Leader Blend cmt. & prep to set plug # 2 TIH wI mule shoe & 5" DP to 419' - tagged u p - Wash through & RIH to 478' Circ @ 478' - 5 bbl/min @ 230 psi Set kick off plug # 2 wI 329 sx. G wi .2% D- 46,2% CaCI2, .09 galslsk D-185 @ 17.0 ppg - displace to equalize CIP@ 0950hrs. Calc. top @ 84' POOH to 95' - Flush conductor & 20" divert er wi teaated water - blow down lines WOC - change save sub, chnage, change dis c brake pad on drawworks - service & clean rig MU 12 1/'4" bit, B/S, XO - RIH on 5" HWDP - tag top of plug @ 344' Plug to low for kick off Circulate & condition mud - Confer wI Drillin g team Leader POOH wi bit & HWDP Blend cement for plug # 3 f/ 344' RIH wi mule shoe & 5" DP to 336' RU & circulate @ 336' - PJSM - Test lines t 0 2000 psi Set plug # 3 FI 344' wI 260 sxs (47 bbls) G wi 0.2% D-46, 3% CaCI2, 0.09 galsl sk D-18 5, @ 17.0 ppg - Displaced to equalized - Gal c. top @ 23' - CIP @ 0515 hrs - break out Ii nes POOH to 95' - circulate treated water & flus h condo & 20" Diverter Blow down top drive WOC - Clean & service rig - go through mud pumps RIH wi 12 1/4" bit & HWDP - tag top cmt plu g @ 271' Circ & condition mud POOH wi 5" HWDP - LD bit, bls, & XO MU BHA bit, motor wi 2.0 AKO, MWD - TIH t 0 253' - run gyro POOH check UBHO alignment - RIH to 253' & rerun gyro Check valves in pumps Orient & slide f/ 271' to 342' POOH & adjust AKO to 1.5 - PU stab & lead collar, orient motor, MWD & UBHO Printed: 3/5/2002 2:02:45 PM ~l l. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/7/2002 (' PHilLIPS~ALASKA INC. Operations - Summary Report CD2-26 CD2-26 ROT - DRILLING doyon1 @ppco.com Doyon 19 Hours Code Spud Date: 1/3/2002 End: 1/20/2002 Group: Start: 1 /2/2002 Rig Release: 1/20/2002 Rig Number: 19 Description of. ()perations 07:30 - 08:00 0.50 DRILL TRIP SURFAC 08:00 - 00:00 16.00 DRILL DRLG SURFAC 00:00 - 04:30 4.50 DRILL DRLG SURFAC 04:30 - 06:00 1.50 DRILL CIRC SURFAC 06:00 - 07:30 1.50 DRILL WIPR SURFAC 07:30 - 08:00 0.50 DRILL CIRC SURFAC 08:00 - 12:30 4.50 DRILL TRIP SURFAC 1/8/2002 12:30 - 14:00 14:00 - 14:30 14:30 - 19:30 19:30 - 21:00 21 :00 - 23:30 1.50 CASE 0.50 CASE 5.00 CASE RURD SURFAC SFTY SURFAC RUNC SURFAC 1.50 CASE CIRC SURFAC 2.50 CEMEN PUMP SURFAC 23:30 - 00:00 0.50 CEMEN PULD SURFAC 1/9/2002 00:00 - 01 :00 1.00 CEMEN PULD SURFAC 01 :00 - 02:00 1.00 CEMEN NFL T SURFAC 02:00 - 08:30 6.50 DRILL RIRD INTRM1 08:30 - 13:00 4.50 WELCT BOPE INTRM1 13:00 - 14:00 14:00 - 17:00 17:00 - 17:30 17:30 - 18:30 1.00 DRILL OTHR INTRM1 3.00 DRILL PULD INTRM1 0.50 DRILL 1.00 DRILL OTHR INTRM1 TRIP INTRM1 RIH to 342' Drill 12 1/4" hole fl 342' to 2020' - 2016' TV D ADT 10.4 AST - 1.8 ART - 8.6 Drill 12 1/4" hole fl 2020' to 2398' TVD 239 4' ADT 3.8 ART 3.8 Circulate hole clean for wiper trip Wiper trip fl 2398' to 1556' - ok - RIH to 23 98' Circulate hole - Flow check - blow down top drive POOH - change out jars, LD UBHO sub, MWD ,Stab, Pony DC, motor, & bit - clean up rig f 100 r Rig up to run 9 5/8" csg Held PJSM PU & run casing - Ran 55 jts. 9 5/8" 36# J-5 5 BTC csg wI FS @ 2388' FC @ 2297' - Land casing on mandrel hanger in wellhead - RD fill up tool & RU cmt head Circulate & condition mud for cement job PJSM - Cement casing - Pump 40 bbls vis fr esh water wI nut plug marker - Pump 5 bbls water - test lines to 2600 psi - drop btm plu g - pump 50 bbls Arco spacer @ 10.5 ppg - f ollowed by 360 bbls AS 3 Lite @ 10.7 ppg (0 bserved nut plug spacer @ shakers wI 345 b bls pumped) switch to tail slurry 48 bbls (cl ass G) @ 15.8 ppg - drop top plug wI 20 bbl s water f/ Dowell - switch to rig pumps & dis place wI 157 bbls mud - bumped plug wI 100 0 psi - floats held CIP @ 23:05 hrs. - AD c mt lines RD cement head - Back out landing joint Back out & LD landing jt. - clear floor of ca sing tools - remove long bails PU stack washer & wash 20" diverter stack RD 20" diverter system - Install wellhead - NU BOPE Set test plug - Test BOPE - pipe rams, blind rams, choke manifold valves, kill & choke I ine valves, floor dart & TIW valves, top driv e IBOP valves to 250 psi & 5000 psi - Hydril to 250 psi & 3500 psi - perform accumlator recovery test - test witnessed & approved b y John Spalding AOGCC Pull test plug - set wear bushing - PU short bails & 5" elevators MU BHA # 5 - 81/2" bit, motor(1.45 AKa) st ab, MWD - orient motor & MWD - Up load M WD, PU flex collars - RIH wI 5" HWP to 989' Change handling equipment f/ 5" to 4" RIH to 1080' - shallow test MWD - RIH & tag up @ 2271' Printed: 3/5/2002 2:02:45 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( PHILLIPS ALASKA INC. Operations Summary Report CD2-26 CD2-26 ROT - DRILLING doyon1 @ppco.com Doyon 19 Page 4 of 7 Start: 1/2/2002 Rig Release: 1/20/2002 Rig Number: 19 Spud Date: 1/3/2002 End: 1/20/2002 Group: 1/9/2002 18:30 - 19:00 19:00 - 20:00 20:00 - 21 :00 21:00 - 21:30 21 :30 - 22:30 22:30 - 00:00 1/10/2002 00:00 - 19:00 19:00 - 20:00 20:00 - 00:00 1/11/2002 00:00 - 00:00 1/12/2002 00:00 - 10:00 10:00 - 11 :00 11 :00 - 15:30 15:30 - 16:30 16:30 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 23:00 23:00 - 00:00 1/13/2002 00:00 - 00:00 1/14/2002 00:00 - 08:00 08:00 - 09:30 09:30 - 11 :30 11 :30 - 13:00 13:00 - 18:00 18:00 - 19:00 0.50 DRILL 1.00 DRILL CIRC INTRM1 OTHR INTRM1 1.00 CEMEN DSHO INTRM1 0.50 DRILL 1.00 DRILL 1.50 DRILL 19.00 DRILL 1.00 DRILL 4.00 DRILL 24.00 DRILL 10.00 DRILL 1.00 DRILL 4.50 DRILL 1.00 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL CIRC INTRM1 FIT INTRM1 DRLG INTRM1 DRLG INTRM1 CIRC INTRM1 WIPR INTRM1 DRLG INTRM1 DRLG INTRM1 CIRC INTRM1 TRIP INTRM1 TRIP INTRM1 PULD INTRM1 PULD INTRM1 TRIP INTRM1 0.50 RIGMNT RSRV INTRM1 3.50 DRILL TRIP INTRM1 1.00 DRILL 24.00 DRILL 8.00 DRILL 1.50 DRILL 2.00 DRILL 1.50 DRILL 5.00 DRILL 1.00 DRILL DRLG INTRM1 DRLG INTRM1 DRLG INTRM1 CIRC INTRM1 WIPR INTRM1 CIRC INTRM1 TRIP INTRM1 OTHR INTRM1 Circulate for casing test RU test equip pressure test 9 5/8" casing t 0 2500 psi for 30 mins - RD test equip C/O shoe track - cmt fl 2271' to FC @ 2297' - Cmt to FS @ 2386' - drill shoe - c/o rat h ole to 2398' - Drill new hole to 2417' Circ fro FIT RU - perform F.I.T. to 16.0 ppg EMW w/ 9.5 ppg mud @ 810 psi - RD Drill 8 1/2" hole fl 2417' to 2513' TVD 2508 ADT.7 ART.7 Drill 8 1/2" hole fl 2513' to 4613' - TVD 46 09' ADT - 13.4 ART 13.3 AST.1 Pump hi vis sweep & circulate hole clean for wiper trip - monitor well (static) blow down top drive Wiper trip 11 4613' to 2388' ( 23 stds) - mon itor well - static - RIH to 4518' - Prep to saf ety wash & ream to 4613' Dril18 1/2" hole 11 4613' to 6396' TVD 6065 ADT 16.5 ART 7.5 AST 9.0 Dril18 1/2" hole 11 6396' to 7250' TVD 6623 ADT 6.2 ART 4.7 AST 1.5 Pump sweep & circulate hole clean for trip - Monitor well (static) POOH 11 7250' to 990' (top of BHA) Flow che ck @ 9 5/8" shoe Change to 5" handling equip - std back HWD P & NMDC Down load MWD - LD motor & bit PU Motor & bit & orient motor & MWD RIH w/ bit, motor, MDW, NMDC, HWDP - swit ch to 4" handling equip & continue RIH to 1 900' - Test MWD Service TD & Dwks Continue RIH to 7235' - Establish circulatio n - Wash 11 7235' to 7250' Drill 8 1/2" hole 11 7250' to 7277' TVD 6626 ADT .8 ART .8 Drill 8 1/2" hole fl 7277' to 8305' TVD 7128 ADT 18.9 ART 7.5 AST 11.4 Dril18 1/2" hole f/ 8305' to 8629' TVD 7186 ADT 6.3 ART 2.6 AST 3.7 Pump hi vis sweep & circulate hole clean - r otate & recip. pipe wiper trip 11 8629' to 7190' - Monitor well @ 7190' static - RIH to 8519' - safety wash & ream to 8629' Pump hi vis sweep & circulate & condition m ud for casing Flow check - Blow down TD - POOH to HWDP Change to 5" handling tools - POOH & Std b Printed: 3/5/2002 2:02:45 PM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PHilliPS ALASKA INC. Operations~ Summary Report CD2-26 CD2-26 ROT - DRILLING doyon1 @ ppco.com Doyon 19 1.00 DRILL 1.00 DRILL 0.50 DRILL 2.00 CASE Sub Code OTHR INTRM1 PULD INTRM1 OTHR INTRM1 RURD INTRM1 1/14/2002 18:00 - 19:00 19:00 - 20:00 20:00 - 20:30 20:30 - 22:30 Spud Date: 1/3/2002 End: 1/20/2002 Group: Start: 1/2/2002 Rig Release: 1/20/2002 Rig Number: 19 Description of Operations 22:30 - 00:00 1.50 CASE RURD INTRM1 1/15/2002 00:00 - 00:30 0.50 CASE SFTY INTRM1 00:30 - 03:30 3.00 CASE RUNC INTRM1 03:30 - 04:00 0.50 CASE CIRC INTRM1 04:00-10:15 6.25 CASE RUNC INTRM1 10:15 -11:45 1.50 CASE CIRC INTRM1 11 :45 - 13:30 13:30 - 14:00 14:00 - 15:30 15:30 - 16:00 16:00 - 17:00 17:00 - 19:30 19:30 - 23:30 1.75 CASE RUNC INTRM1 0.50 CEMEN PULD INTRM1 1.50 CEMEN CIRC INTRM1 0.50 CEMEN PUMP INTRM1 1.00 CEMEN DISP INTRM1 2.50 CASE PTCH INTRM1 4.00 WELCT BOPE INTRM1 23:30 - 00:00 0.50 CASE RURD INTRM1 1/16/2002 00:00 - 03:00 3.00 DRILL PULD INTRM1 03:00 - 05:00 2.00 DRILL TRIP INTRM1 05:00 - 06:00 1.00 RIGMNT RSRV INTRM1 06:00 - 09:00 3.00 DRILL TRIP INTRM1 09:00 - 10:00 1.00 CEMEN GOUT INTRM1 10:00 - 11 :00 1.00 CASE DEOT INTRM1 11 :00 - 13:00 2.00 CEMEN DSHO INTRM1 13:00 - 14:00 1.00 CEMEN FIT INTRM1 ack HWDP & Flex collars LD MWD, motor, & bit MU stack washer & flush stack Pull wear bushing - change top rams to 7" & test rams to 3500 psi - pull test jt. & plug - set thin wall wear bushing RU to run 7" casing Held prejob safety and opts meeting with cr ew. Run 7", 26#, L-80 casing to 2350'. Circ and cond mud. Run casing to 7520', no problems. Stage pumps up to 4 bpm and condition mud , initial mud wt. 9.6 in, 10.3 out, final 9.6 i n 9.7 out at 360 psi. Run casing, mu hanger and landing joint, la nded casing with shoe @ 8619', FC @ 8533'. LD fill up tool and install cement head. Staged pumps up to 6 bpm and condition mu d, final pressure 560 psi. PJSM. RU and test cement lines to 3500 psi, pump ed 20 bbls of Arco wash, 50 bbls of 12.5 pp g spacer and 33 bbls of 15.8 ppg cement. Displaced cement with 20 bbls of FW, and 3 04 bbls of 9.6 ppg mud. Bumped plugs to 10 00 psi, floats held, CIP at 1650 hours. Reci procated pipe until I last 15 bbls of displace ment, full returns throughout. RD cement head, LD landing joint, pull wear bushing, install and test packoff to 5000 ps i. Install test plug, test pipe and blind rams, c hoke, kill, manifold and surface safety valve s to 250/5000 psi. Tested annular preventor to 250/3500 psi. Pull test plug and install w ear bushing. AOGCC (Jeff Jones) waived wit nessing tests. Hang short bails on top drive, PU running to ols for 4" drill pipe. Mu BHA #7, initalize MWDI LWD. PU 60 joints of 4" drill pipe, shallow test to ols @ 2269'. Slip and cut drilling line, service Top Drive. RIH to 8400', fill pipe every 2000'. Wash down from 8400', cleaned out cement f rom 8455' to 8505'. RU and test casing to 3500 psi for 30 min., blow down surface lines. Drill out cement, float equipment and 20' of new hole to 8649'. Circ and cond mud for FIT. Printed: 3/5/2002 2:02:45 PM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/16/2002 14:00 - 14:45 14:45 - 16:00 1/17/2002 16:00 - 00:00 00:00 - 00:00 1/18/2002 00:00 - 07:30 07:30 - 10:00 10:00 - 12:30 12:30 - 13:45 13:45 - 16:00 16:00 - 21 :30 21 :30 - 23:00 23:00 - 23:30 23:30 - 00:00 1/19/2002 00:00 - 11 :30 11:30-12:15 12:15 - 12:30 12:30 - 19:00 19:00 - 19:45 19:45 - 21 :00 21 :00 - 00:00 1/20/2002 00:00 - 01:15 01:15-04:00 PHILLIPS ALASKA INC.- Operations Sum maryReport CD2-26 CD2-26 ROT - DRILLING doyon1 @ ppco.com Doyon 19 0.75 CEMEN FIT 1.25 DRILL CIRC 8.00 DRILL 24.00 DRILL 7.50 DRILL 2.50 DRILL 2.50 DRILL 1.25 DRILL 2.25 DRILL 5.50 DRILL 1.50 DRILL TRIP DRLG PROD DRLH PROD DRLH PROD CIRC PROD 0.50 CMPL TN NUND CMPL TN CIRC PROD 0.50 CMPLTN OTHR CMPLTN 11.50 CMPLTNTRIP PROD TRIP PROD 0.75 CMPL TN RURD CMPL TN 0.25 CMPL TN SFTY CMPL TN TRIP PROD 6.50 CMPL TN PULD CMPL TN PULD PROD CMPL TN 0.75 CMPL TN PULD CMPL TN 1.25 CMPL TN SEaT CMPL TN 3.00 CMPL TN NUND CMPL TN 1.25 CMPL TN NUND CMPL TN 2.75 CMPL TN FRZP CMPL TN Start: 1/2/2002 Rig Release: 1/20/2002 Rig Number: 19 Spud Date: 1/3/2002 End: 1/20/2002 Group: RU and perform FIT to 12.5 ppg. Pump 38 bbls of SafeKleen water, 75 bbls H V spacer and change well over to 8.9 ppg FI o-Pro, flow check well, static. Drill from 8649' to 9100'. ART=3.4 AST=1.8 Drill from 9100' to 10800'. ART=14.3 AST=1 .9 200 bbls whole mud dilutions every 500'. Hole took 10 bbls of mud @ 10365', no furt her losses. Drill from 10800' to 11238', TD. ART=4.5 A ST=1.1 Pumped piggy back 40 bbl HV sweeps and ci rc hole clean 5 bpm, 1640 psi, 110 rpm. PJS M. Pumped 40 bbl push pill and displace hole w ith 9.0 ppg KCL brine until I clean. Monitor w ell, initial losses at 120 bph. Pump out 3 stands while mixing LCM pill, sp at 40 bbls pill (3 ppb Flovis) in pipe pumpin g out stand # 4, losses at 80 bph. Continued to pump out, pill displaced into open hole with 7 stands out, bit @ 10571'. POH to 8566', monitor well, losses reduced to 15 bph. POH to 267', laid down 66 jts excess drill pi pe for move, culled 15 joints of 4" drill pipe with damage to hard band 3/8" to 5/8" piec es missing. Flushed BHA with 25 bbls of treated brine, d own load LWD, lay down BHA. Pulled and inspected wear bushing, appeare d in good condition, install wear bushing. MU 6" flat bottom mill, 2 junk subs and casi ng scraper. Static losses @ 8-10 bph, 564 bbls total brine losses @ midnight. Ran scraper assembly to 8500', no problems POH, lay down tools, pull wear bushing. RU to run 4 1/2" tubing. Held safety and operations meeting with cre w. MU Completion assembly per program, RIH p icking up 4 1/2" tubing (182 jts total). MU hanger and LJ a, land hanger and RILDS LD LJ a, install TWC, MU LJ b and test hang er seals to 5000 psi, LD LJ b. ND BOPE, NU and test adapter flange and tr ee to 5000 psi. RU lubricator and pull TWC. RU circ manifol d and hard lines to wellhead. Test surface lines to 3800 psi, pumped 15 b bls of 9.6 ppg brine followed by 112 bbls of 9.6 ppg treated kcl brine @ 3 bpm with rig p Printed: 3/5/2002 2:02:45 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/20/2002 01 :15 - 04:00 04:00 - 06:00 06:00 - 08:00 ( (' \ PHILLIPS ALASKA INC. Operations Summary Report CD2-26 CD2-26 ROT - DRILLING doyon1 @ppco.com Doyon 19 - ...-...' Sub Hours. Code Code Phase 2.75 CMPL TN FRZP CMPL TN 2.00 CMPL TN DEOT CMPL TN 2.00 CMPL TN NUND CMPL TN Start: 1/2/2002 Rig Release: 1/20/2002 Rig Number: 19 Spud Date: 1/3/2002 End: 1/20/2002 Group: umps. Dowell pumped 160 bbls of diesel at 2 .5 bpm, final static tubing pressure 700 psi. RU lubricator and drop setting ball and rod. Set packer and test tubing to 3500 psi for 3 0 min, initial pressure 3533 psi, final 3266 psi. Test 7" x 4.5" annulus to 3500 psi for 3 0 min, initial pressure 3533 psi, final 3425 psi. Bleed and blow down lines, rig down manifol d and hard lines. RU lubricator and install B PV, secure wellhead, released rig @ 0800 h ours. Printed: 3/5/2002 2:02:45 PM ".,.'. '. . . . . . . . ",I . . . . . "" '- 'I ~ -, -, ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-001 14 Sidetrack No, Page 1 of 1 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/26PB1 - 26PB2 - 26 Survey Section Name Definitive Survey BHI Rep. BALLOU / MATTESON I NTEQ. WELL DATA Target TVD (Fì) Target Coord. N/S Slot Coord. N/S -1824.78 Grid Correction 0.000 Depths Measured From: RKB g] MSL 0 SSO Target Description Target Coord. E/W Slot Coord. E/W -1530.92 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 3OmD 1OmD Vert. Sec. Azim. 90.48 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (Fì) (DO) (DO) (Fì) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT ( 03-JAN-02 GSS 124.00 0.70 246.00 124.00 124.00 -0.69 -0.31 -0.69 0.56 0.56 \ 03-JAN-02 GSS 147.00 0.90 252.00 23.00 146.99 -0.99 -0.42 -0.99 0.94 0.87 03-JAN-O2 GSS 172.00 0.90 274.00 25.00 171 .99 -1.37 -0.47 -1.37 1.37 0.00 03-JAN-02 GSS 267.00 1.00 228.00 95.00 266.98 -2.73 -0.97 -2.74 0.79 0.11 03-JAN-02 GSS 354.00 2.50 200.00 87.00 353.94 -3.92 -3.26 -3.95 1.94 1.72 03-JAN-02 GSS 447.00 3.40 210.00 93.00 446.81 -5.96 -7.56 -6.02 1.11 0.97 03-JAN-02 MWD 485.15 2.69 218.30 38.15 484.91 -7.06 -9.24 -7.14 2.19 -1.86 03-JAN-02 MWD 576.18 2.23 250.78 91.03 575.86 -10.04 -11.50 -10.14 1.59 -0.51 03-JAN-02 MWD 666.28 1.34 288.63 90.10 665.92 -12.69 -11.74 -12.79 1.59 -0.99 03-JAN-02 MWD 719.00 1.34 288.63 52.72 718.62 -13.86 -11.34 -13.96 0.00 0.00 Projected Data - NO SURVEY l- . . . . . . . . . . . . . . . '1'- -" " " " , ,-" ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00114 Sidetrack No.1 Page 1 of 1 - -- Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/26PB1 - 26PB2 - 26 Survey Section Name Definitive Survey BHI Rep. BALLOU/MATIESON/NEWLON I NT'EQ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1824.78 Grid Correction 0.000 Depths Measured From: RKB g] MSL 0 SSO Target Description Target Coord. E/W Slot Coord. E/W -1530.92 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 30mO 10mO Vert. Sec. Azim. 90.48 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incr. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD -' Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT l 04-JAN-02 MWD 114.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 0.00 ' 04-JAN-02 MWD 213.78 0.43 260.91 99.78 213.78 -0.37 -0.06 -0.37 0.43 0.43 04-JAN-02 MWD 238.00 1.00 232.00 24.22 238.00 -0.62 -0.20 -0.63 2.71 2.35 GYRO SURVEY 04-JAN-02 MWD 276.35 0.76 228.49 38.35 276,34 -1.08 -0.58 -1.08 0.64 -0.63 04-JAN-02 MWD. 307.05 1.10 212.78 30.70 307.04 -1.38 -0.96 -1.39 1.37 1.11 04-JAN-02 MWD 337.87 1.44 213.59 30.82 337.85 -1.75 -1.53 -1.77 1.10 1.10 04-JAN-02 MWD 358.00 2.40 210.00 20.13 357.97 -2.10 -2.11 -2.12 4.80 4.77 GYRO SURVEY 04-JAN-02 MWD 366.56 2.10 213.15 8.56 366.52 -2.27 -2.39 -2.29 3.79 -3.50 04-JAN-02 MWD 395.77 3.38 204.50 29.21 395.70 -2.91 -3.63 -2.94 4.59 4.38 04-JAN-02 MWD 398.00 3.80 208.00 2.23 397.92 -2.97 -3.75 -3.00 21.24 18.83 GYRO SURVEY 04-JAN-02 MWD 430.45 4.05 202.20 32.45 430.30 -3.89 -5.76 -3.94 1.44 0.77 04-JAN-02 MWD 490.00 5.22 199.48 59.55 489.65 -5.55 -10.26 -5.64 2.00 1.96 -4.57 Projected Data - NO SURVEY [ -. . - . - . - . - . - - - - - '. - . - - - - - - - - - ------ - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00114 Sidetrack No.2 Page 1 of 6 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/26PB1 - 26PB2 - 26 Survey Section Name CD2-26 MWD BHI Rep. I NJEQ. WELL DATA Target 1VD (Fl) Target Coord. N/S Slot Coord. N/S -1824.78 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSO Target Description Target Coord. E/W Slot Coord. E/W -1530.92 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 1 OOft~ 30mO 1OmD Vert. Sec. Azim. 90.48 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 1VD Section N(+) (S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (Fl) (DD) (DD) (Fl) (Fl) (Fl) (Fl) (Per 100 Fl) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT { 07 -JAN-01 MWD 114.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 0.00 \ 07 -JAN-01 MWD 174.00 0.70 260.00 60.00 174.00 -0.36 -0.06 -0.36 1.17 1.17 GYRO SINGLE SHOT 07 -JAN-01 MWD 233.36 0.52 274.74 59.36 - 233.36 -0.99 -0.10 -0.99 0.40 -0.30 07 -JAN-01 MWD 303.75 3.31 38.78 70.39 303.71 -0.04 1.51 -0.03 5.15 3.96 07-JAN-01 MWD 351 .57 4.29 46.87 47.82 351.42 2.11 3.81 2.14 2.33 2.05 07-JAN-01 MWD 393.72 4.14 35.97 42.15 393.46 4.13 6.12 4.18 1.93 -0.36 07 -JAN-01 MWD 485.62 3.94 44.43 91.90 485.13 8.25 11.05 8.34 0.68 -0.22 07-JAN-01 MWD 575.48 4.39 55.04 89.86 574.76 13.19 15.23 13.32 0.99 0.50 07 -JAN-01 MWD 665.52 5.27 83.62 90.04 664.49 20.11 17.66 20.26 2.81 0.98 31.74 07 -JAN-01 MWD 755.51 5.40 84.14 89.99 754.09 28.42 18.56 28.58 0.15 0.14 0.58 07-JAN-01 MWD 844.25 5.25 86.08 88.74 842.45 36.62 19.26 36.78 0.26 -0.17 2.19 07 -JAN-01 MWD 934.82 5.48 84.80 90.57 932.62 45.05 19.93 45.22 0.29 0.25 -1.41 l 07 -JAN-01 MWD 1030.11 5.53 82.77 95.29 1027.47 54.13 20.93 54.31 0.21 0.05 -2.13 \. 07 -JAN-01 MWD 1124.75 4.75 85.42 94.64 1121.73 62.55 21.81 62.74 0.86 -0.82 07 -JAN-01 MWD 1220.36 4.37 89.45 95.61 1217.04 70.14 22.16 70.32 0.52 -0.40 07 -JAN-01 MWD 1315.64 4.07 88.30 95.28 1312.06 77.15 22.30 77.33 0.33 -0.31 07-JAN-01 MWD 1409.89 2.40 89.48 94.25 1406.15 82.46 22.42 82.65 1.77 -1.77 07-JAN-01 MWD 1504.85 1.12 99.12 94.96 1501.07 85.37 22.29 85.56 1.38 -1.35 07 -JAN-01 MWD 1600.05 0.69 105.93 95.20 1596.25 86.84 21.98 87.03 0.46 -0.45 07 -JAN-01 MWD 1695.58 0.98 117.14 95.53 1691.77 88.12 21.45 88.31 0.35 0.30 07-JAN-01 MWD 1789.65 0.63 100.43 94.07 1785.84 89.35 20.99 89.53 0.44 -0.37 07-JAN-01 MWD 1884.66 0.43 22.00 95.01 1880.84 90.00 21.23 90.18 0.72 -0.21 07 -JAN-01 MWD 1979.51 0.30 24.25 94.85 1975.69 90.23 21.78 90.41 0.14 -0.14 . . . . . . . . . . . . . . . . . . . ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00114 Sidetrack No.2 Page 2 of 6 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/26PB1 - 26PB2 - 26 Survey Section Name CD2-26 MWD BHI Rep. I NTEQ WELL DATA Target TVD (Fl) Target Coord. N/S Slot Coord. N/S -1824.78 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSO Target Description Target Coord. E/W Slot Coord. E/W -1530.92 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 30mO 10mD Vert. Sec. Azim. 90048 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Inc!. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (Fl) (DO) (DO) (Fl) (Fl) (Fl) (Fl) (Per 100 Fl) Drop (-) Left (-) 07-JAN-01 MWD 2076.18 0.18 353.59 96.67 2072.36 90.31 22.16 90.50 0.18 -0.12 (' , - 07-JAN-01 MWD 2171.74 0.50 11.63 95.56 2167.92 90.37 22.72 90.57 0.35 0.33 07-JAN-01 MWD 2266.1 0 0.26 338.32 94.36 2262.28 90.37 23.32 90.57 0.34 -0.25 07 -JAN-01 MWD 2344.28 0.17 315.58 78.18 2340046 90.22 23.57 90042 0.16 -0.12 09-JAN-01 MWD 2437.75 0049 4.47 93047 2433.92 90.15 24.07 90.36 0043 0.34 1 O-JAN-01 MWD 2535.24 0049 327.23 97049 2531041 89.95 24.84 90.17 0.32 0.00 1 O-JAN-01 MWD 2634047 0.29 348.04 99.23 2630.64 89.67 25044 89.88 0.24 -0.20 1 O-JAN-01 MWD 2729.30 0.51 351.79 94.83 2725047 89.55 26.09 89.77 0.23 0.23 1 O-JAN-01 MWD 2824.67 0047 348.23 95.37 2820.83 89041 26.89 89.63 0.05 -0.04 1 0-JAN-01 MWD) 2920.19 0.53 1.84 95.52 2916.35 89.33 27.72 89.57 0.14 0.06 1 0-JAN-01 MWD 3014.58 0.56 16.94 94.39 3010.73 89047 28.60 89.72 0.15 0.03 1 0-JAN-01 MWD 3111.22 0.59 12.72 96.64 3107.37 89.71 29.53 89.96 0.05 0.03 1 0-JAN-01 MWD 3207.19 0.62 357.65 95.97 3203.33 89.79 30.53 90.05 0.17 0.03 I' - 10-JAN-01 MWD 3301 .90 0.76 7.38 94.71 3298.04 89.84 31.67 90.11 0.19 0.15 ' 1 0-JAN-01 MWD 3397.92 0.83 2.32 96.02 3394.05 89.94 33.00 90.22 0.10 0.07 1 O-JAN-O1 MWD 3492.97 0.79 356.62 95.05 3489.09 89.92 34.34 90.21 0.09 -0.04 1 0-JAN-01 MWD 3587.83 0.26 150.58 94.86 3583.95 89.98 34.80 90.28 1.09 -0.56 1 0-JAN~01 MWD 3683.88 0040 154.19 96.05 3679.99 90.24 34.31 90.53 0.15 0.15 1 0-JAN-01 MWD 3779.37 0.30 186.21 95049 3775048 90.36 33.76 90.65 0.23 -0.10 1 0-JAN-01 MWD 3874047 0.23 185.27 95.10 3870.58 90.32 33.32 90.60 0.07 -0.07 1 0-JAN-01 MWD 3969.73 0.30 174.98 95.26 3965.84 90.33 32.89 90.61 0.09 0.07 1 0-JAN-01 MWD 4064.97 0.35 167.93 95.24 4061.08 90042 32.35 90.69 0.07 0.05 1 0-JAN-01 MWD 4160.01 0.14 194.31 95.04 4156.12 90045 31.96 90.72 0.25 -0.22 1 0-JAN-01 MWD 4256.67 0.17 219.17 96.66 4252.78 90.33 31.73 90.60 0.08 0.03 . . . . . . . . . . . . . . . . ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00114 Sidetrack No.2 Page 3 of 6 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/26PB1 - 26PB2 - 26 Survey Section Name CD2-26 MWD BHI Rep. I NTEQ WELL DATA Target 1VD (FT) Target Coord. N/S Slot Coord. N/S -1824.78 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSD Target Description Target Coord. E/W Slot Coord. E/W -1530.92 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 1 OOft~ 30mD 1OmD Vert. Sec. Azim. 90.48 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 1VD Section N{+) / S{-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 1 0-JAN-01 MWD 4350.48 0.23 169.17 93.81 4346.59 90.28 31.44 90.55 0.19 0.06 ( 1 0-JAN-01 MWD 4447.10 0.18 264.09 96.62 4443.21 90.17 31.23 90.44 0.31 -0.05 1 0-JAN-01 MWD 4539.60 0.17 124.90 92.50 4535.71 90.14 31.14 90.40 0.35 -0.01 11-JAN-01 MWD 4638.90 0.36 251.50 99.30 4635.01 89.97 30.96 90.23 0.48 0.19 11-JAN-01 MWD 4733.48 2.03 59.66 94.58 4729.57 91.12 31.71 91.39 2.52 1.77 11-JAN-01 MWD 4828.96 3.61 62.48 95.48 4824.93 95.23 33.95 95.52 1.66 1.65 11 -JAN-01 MWD 4924.72 5.04 68.72 95.76 4920.42 101 .80 36.87 102.11 1.57 1.49 6.52 11-JAN-01 MWD 5018.30 8.48 68.78 93.58 5013.33 112.03 40.86 112.38 3.68 3.68 0.06 11 -JAN-01 MWD 5117.52 10.54 70.03 99.22 5111.18 127.33 46.61 127.73 2.09 2.08 1.26 11-JAN-01 MWD 521,2.24 15.91 70.76 94.72 5203.36 147.69 53.85 148.14 5.67 5.67 0.77 11-JAN-01 MWD 5308.76 22.43 74.08 96.52 5294.48 177.84 63.27 178.37 6.85 6.76 3.44 11-JAN-01 MWD 5403.09 29.68 75.89 94.33 5379.17 217.76 73.92 218.38 7.73 7.69 1.92 11-JAN-01 MWD 5498.47 38.06 75.61 95.38 5458.29 269.12 87.00 269.85 8.79 8.79 -0.29 ( - 11-JAN-01 MWD 5592.90 44.73 74.38 94.43 5529.09 329.24 103.20 330.12 7.12 7.06 -1.30 11-JAN-01 MWD 5688.23 49.80 70.61 95.33 5593.77 395.77 124.34 396.82 6.06 5.32 -3.95 11-JAN-01 MWD 5781.08 49.20 70.59 92.85 5654.07 462.16 147.79 463.42 0.65 -0.65 -0.02 11-JAN-01 MWD 5878.87 48.65 70.12 97.79 5718.33 531.38 172.57 532.85 0.67 -0.56 -0.48 11-JAN-01 MWD 5974.36 48.05 70.07 95.49 5781.79 598.26 196.86 599.93 0.63 -0.63 -0.05 11-JAN-01 MWD 6069.09 48.36 69.51 94.73 5844.92 664.33 221.26 666.21 0.55 0.33 -0.59 11-JAN-01 MWD 6165.69 47.81 70.37 96.60 5909.45 731 .64 245.92 733.73 0.87 -0.57 0.89 11-JAN-01 MWD 6261.43 47.07 70.51 95.74 5974.21 797.89 269.53 800.18 0.78 -0.77 0.15 11-JAN-01 MWD 6357.03 48.00 70.20 95.60 6038.75 864.11 293.24 866.60 1.00 0.97 -0.32 12-JAN-01 MWD 6452.86 50.18 71.63 95.83 6101 .50 932.35 316.90 935.04 2.54 2.27 1.49 12-JAN-01 MWD 6549.08 49.72 71.58 96.22 6163.42 1002.04 340.15 1004.93 0.48 -0.48 -0.05 . . . . . .' . . - - - - - - - .~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00114 Sidetrack No.2 Page 4 of 6 - - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/26PB1 - 26PB2 - 26 Survey Section Name CD2-26 MWD BHI Rep. I NTEQ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1824.78 Grid Correction 0.000 Depths Measured From: RKB g¡ MSL 0 SSO Target Description Target Coord. E/W Slot Coord. E/W -1530.92 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 90.48 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Inc!. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 12-JAN-01 MWD 6642.29 49.36 71.93 93.21 6223.90 1069.21 362.35 1072.28 0.48 -0.39 0.38 I' 12-JAN-01 MWD 6739.17 48.50 71.95 96.88 6287.55 1138.45 384.99 1141.72 0.89 -0.89 0.02 12-JAN-01 MWD 6832.41 48.86 72.16 93.24 6349.11 1204.89 406.57 1208.34 0.42 0.39 0.23 12-JAN-01 MWD 6930.46 48.93 73.48 98.05 6413.58 1275.29 428.39 1278.92 1.02 0.07 1.35 12-JAN-01 MWD 7026.28 48.76 72.96 95.82 6476.64 1344.18 449.22 1347.99 0.45 -0.18 -0.54 12-JAN-01 MWD 7121.23 48.67 73.45 94.95 6539.28 1412.31 469.83 1416.30 0.40 -0.09 0.52 12-JAN-01 MWD 7215.57 48.39 73.96 94.34 6601.76 1479.99 489.67 1484.15 0.50 -0.30 0.54 13-JAN-01 MWD 7311.63 50.35 77.53 96.06 6664.32 1550.48 507.58 1554.79 3.48 2.04 3.72 13-JAN-01 MWD 7406.78 52.32 86.98 95.15 6723.84 1623.87 517.49 1628.27 8.02 2.07 9.93 - 13-JAN-01 MWD 7502.69 53.68 97.12 95.91 6781.66 1700.27 514.70 1704.64 8.56 1.42 10.57 13-JAN-01 MWD 7598.50 54.75 104.18 95.81 6837.73 1776.68 500.32 1780.93 6.08 1.12 7.37 13-JAN-01 MWD 7694.27 ) 56.22 110.44 95.77 6892.03 1852.14 476.82 1856.20 5.60 1.53 6.54 13-JAN-01 MWD 7789.98 58.88 115.76 95.71 6943.41 1926.62 445.10 1930.42 5.45 2.78 5.56 - 13-JAN-01 MWD 7885.27 61.36 121.41 95.29 6990.90 1999.43 405.55 2002.89 5.76 2.60 5.93 13-JAN-01 MWD 7981.18 64.21 125.69 95.91 7034.78 2070.85 358.40 2073.92 4.96 2.97 4.46 13-JAN-01 MWD 8076.69 69.07 129.29 95.51 7072.65 2140.80 305.02 2143.43 6.15 5.09 3.77 13-JAN-01 MWD 8171.92 72.60 131.27 95.23 7103.91 2209.88 246.87 2212.03 4.19 3.71 2.08 13-JAN-01 MWD 8267.41 75.68 135.39 95.49 7130.01 2277.18 183.84 2278.80 5.26 3.23 4.31 13-JAN-01 MWD 8364.08 78.29 137.21 96.67 7151.78 2342.81 115.75 2343.86 3.26 2.70 1.88 13-JAN-01 MWD 8458.08 81.93 140.98 94.00 7167.93 2403.99 45.78 2404.46 5.53 3.87 4.01 13-JAN-01 MWD 8494.48 82.94 141.42 36.40 7172.72 2426.84 17.66 2427.07 3.02 2.77 1.21 13-JAN-01 MWD 8553.95 84.63 143.65 59.47 7179.16 2463.19 -29.27 2463.03 4.69 2.84 3.75 16-JAN-01 MWD 8701.99 88.16 146.48 148.04 7188.47 2548.78 -150.36 2547.61 3.05 2.38 1.91 - 16-JAN-01 MWD 8797.33 88.40 147.18 95.34 7191 .33 2601 .58 -230.13 2599.75 0.78 0.25 0.73 .. . "! " . . :8 . ". ~. . . . . . . I' " I, ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00114 Sidetrack No.2 Page 5 of 6 - -- Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/26PB1 - 26PB2 - 26 SuNey Section Name CD2-26 MWD BHI Rep. 'NTEQ WELL DATA Target 1VD (Fì) Target Coord. N/S Slot Coord. N/S -1824.78 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSO Target Description Target Coord. E/W Slot Coord. E/W -1530.92 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 90.48 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA SuNey SuNey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length lVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (Fì) (DO) (DO) (Fì) (Fì) (Fì) (Fì) (Per 100 Fì) Drop (-) Left (-) 16-JAN-01 MWD 8893.36 89.02 149.75 96.03 7193.50 2652.47 -311.95 2649.95 2.75 0.65 2.68 ( MWD 150.46 95.55 7195.29 2700.78 -394.77 2697.57 0.77 -0.20 0.74 ' 16-JAN-01 8988.91 88.83 16-JAN-01 MWD 9083.59 89.63 151.05 94.68 7196.56 2747.72 -477.37 2743.82 1.05 0.84 0.62 17-JAN-01 MWD 9180.87 91.54 152.01 97.28 7195.57 2794.81 -562.88 2790.19 2.20 1.96 0.99 17 -JAN-01 MWD 9274.76 90.92 151.48 93.89 7193.55 2839.93 -645.56 2834.62 0.87 -0.66 -0.56 17-JAN-01 MWD 9371 .50 90.62 151.29 96.74 7192.25 2886.97 -730.48 2880.95 0.37 -0.31 -0.20 17-JAN-01 MWD 9466.99 90.49 152.66 95.49 7191 .33 2932.54 -814.77 2925.81 1.44 -0.14 1.43 17-JAN-01 MWD 9562.62 90.37 152.94 95.63 7190.61 2976.96 -899.82 2969.53 0.32 -0.13 0.29 17-JAN-01 MWD 9658.05 90.37 152.75 95.43 7189.99 3021 .22 -984.73 3013.08 0.20 0.00 -0.20 17 -JAN-01 MWD 9753.44 90.86 152.35 95.39 7188.97 3065.90 -1069.37 3057.05 0.66 0.51 -0.42 ) 17-JAN-01 MWD 9848.70 90.92 153.36 95.26 7187.49 3110.06 -1154.13 3100.50 1.06 0.06 1.06 17-JAN-01 MWD 9944.21 90.12 153.19 95.51 7186.62 3153.73 -1239.43 3143.45 0.86 -0.84 -0.18 17 -JAN-01 MWD 10039.55 90.00 153.32 95.34 7186.52 3197.34 -1324.57 3186.36 0.19 -0.13 0.14 - 17 -JAN-01 MWD 10134.43 89.82 153.01 94.88 7186.67 3240.88 -1409.24 3229.19 0.38 -0.19 -0.33 17-JAN-01 MWD 10229.93 90.00 152.68 95.50 7186.82 3285.18 -1494.21 3272.78 0.39 0.19 -0.35 17-JAN-01 MWD 10324.98 90.12 152.82 95.05 7186.72 3329.41 -1578.71 3316.30 0.19 0.13 0.15 17 -JAN-01 MWD 10417.33 90.12 153.19 92.35 7186.53 3372.01 -1661.00 3358.22 0.40 0.00 0.40 17-JAN-01 MWD 10515.89 91.23 152.36 98.56 7185.37 3417.83 -1748.63 3403.30 1.41 1.13 -0.84 17-JAN-01 MWD 10611.94 91.17 153.39 96.05 7183.36 3462.33 -1834.10 3447.08 1.07 -0.06 1.07 17-JAN-01 MWD 10707.28 90.00 152.15 95.34 7182.38 3506.66 -1918.86 3490.70 1.79 -1.23 -1.30 17-JAN-01 MWD 10802.35 89.63 152.23 95.07 7182.69 3551.71 -2002.95 3535.06 0.40 -0.39 0.08 18-JAN-01 MWD 10898.16 89.69 153.23 95.81 7183.26 3596.32 -2088.11 3578.95 1.05 0.06 1.04 18-JAN-01 MWD 10994.34 89.57 151.87 96.18 7183.88 3641.37 -2173.46 3623.29 1.42 -0.12 -1.41 18-JAN-01 MWD 11090.28 91.11 151.46 95.94 7183.31 3687.61 -2257.90 3668.82 1.66 1.61 -0.43 . .'.'" .. . '. . . . . . . . . '. . . . . ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00114 Sidetrack No.2 Page 6 of 6 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/26PB1 - 26PB2 - 26 Survey Section Name CD2-26 MWD BHI Rep. , NTEQ. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1824.78 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E/W Slot Coord. E/W -1530.92 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 3OmD 10mD Vert. Sec. Azim. 90.48 Magn. to Map COHo 0.000 Map North to: OTHER SURVEY DATA Survey Survey Inc!. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (Fì) (DO) (DO) (Fl) (Fl) (Fl) (Fl) (Per 100 Fl) Drop (-) Left (-) 18-JAN-01 MWD 11181.21 91.23 151.19 90.93 7181.45 3731.90 -2337.66 3712.44 0.32 0.13 -0.30 18-JAN-01 MWD 11238.00 91.23 151.19 56.79 7180.23 3759.68 -2387.41 3739.81 0.00 0.00 0.00 f - I( ,c"- i' \ "~r ~'_'Z'} - - .' <':Ä~,~;i"-¡,Œ~"~;l'~~~< ,'- ' 31-Jan-O2 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well CD2-26 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 0.00' MD Window / Kickoff Survey , MD Projected Survey: 11 ,238.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED F-r-p 0' 7' "002 ....u I L.., Attachment(s) Alaska Oil & Gas Cons. Commission Anchorage ~, ~ 1 ~ '. DEFINITIVE (' Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-26 CD2-26 Job No. AKMM11220, Surveyed: 18 January, 2002 SURVEY REPORT 30 January, 2002 Your Ref: API 501032039700 Surface Coordinates: 5974532.34 N, 371707.80 E (70° 20' 19.1519" N, 151002' 27.6907" W) Kelly Bushing: 51. 90ft above Mean Sea Level ( spe.-.r"'J-sur-, D~Ii....L'NG Jiif:5~v.c:el; A Halliburton Company Survey Ref: svy9830 Sperry-Sun Drilling Services . Survey Report for CD2-26 Your Ref: API 501032039700 Job No. AKMM11220, Surveyed: 18 January, 2002 \ North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical ~ Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section CommeAt (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0_000 0.000 -51.90 0.00 O.OON 0.00 E 5974532.34 N 371707.80 E 0.00 Tolerable Gyro ( 114.00 0.000 0.000 62.10 114.00 O.OON O.OOE 5974532.34 N 371707.80 E 0.000 0.00 174.00 0.700 260.000 122.10 174.00 0.065 0.36W 5974532.28 N 371707.44 E 1.167 -0.11 MWD Magnetic 233.36 0.520 274.740 181.46 233.36 0.105 0.99W 5974532.25 N 371706.81 E 0.400 -0.37 303.75 3.310 38.780 251 .81 303.71 1.51 N 0.03W 5974533.85 N 371707.79 E 5.152 -1.34 351.57 4.290 46.870 299.52 351.42 3.81 N 2.14 E 5974536.11 N 371710.00 E 2.331 -2.35 393.72 4.140 35.970 341.56 393.46 6.11 N 4.18 E 5974538.38 N 371712.09 E 1.931 -3.42 485.62 3.940 44.430 433.23 485.13 11.05 N 8.34 E 5974543.25 N 371716.33 E 0.683 -5.82 575.48 4.390 55.040 522.86 574.76 15.23 N 13.32 E 5974547.34 N 371721.38 E 0.991 -7.15 665.52 5.270 83.620 612.59 664.49 17.66 N 20.26 E 5974549.66 N 371728.36 E 2.810 -6.03 755.51 5.400 84.140 702.19 754.09 18.56 N 28.58 E 5974550.40 N 371736.69 E 0_154 -2.89 844.25 5.240 86.080 790.55 842.45 19.26 N 36.77 E 5974550.97 N 371744.90 E 0.271 0.35 934.82 5.480 84.800 880.72 932.62 19.93 N 45.20 E 5974551.50 N 371753.34 E 0.296 3.73 1030.11 5.530 82.770 975.57 1027.47 20.92 N 54.29 E 5974552.33 N 371762.44 E 0.211 7.14 1124.75 4.750 85.420 1069.83 1121.73 21.81 N 62.72 E 5974553.07 N 371770.88 E 0.861 10.34 1220.36 4.370 89.450 1165.14 1217.04 22.16 N 70.31 E 5974553.30 N 371778.48 E 0.520 13.60 1315_64 4.070 88.300 1260_16 1312.06 22.30 N 77.32 E 5974553.31 N 371785.49 E 0.327 16.79 1409.89 2.400 89.480 1354.26 1406.16 22.41 N 82.64 E 5974553.34 N 371790.81 E 1.773 19.19 ( 1504.85 1.120 99.120 1449.17 1501.07 22.29 N 85.54 E 5974553.16 N 371793.71 E 1.379 20.68 1600.05 0.690 105.930 1544.36 1596.26 21.98 N 87.01 E 5974552.83 N 371795.17E 0.465 21.64 1695.58 0.980 117.140 1639.88 1691.78 21.45 N 88.29 E 5974552.28 N 371796.44 E 0.347 22.71 1789.65 0.630 100.430 1733.94 1785.84 20.99 N 89.52 E 5974551.79 N 371797.66 E 0.444 23.69 1884.66 0.430 22.000 1828.94 1880.84 21.23 N 90.16 E 5974552.02 N 371798.31 E 0.724 23.79 1979.51 0.300 24.250 1923.79 1975.69 21.78 N 90.40 E 5974552.57 N 371798.56 E 0.138 23.41 2076.18 0.180 353.590 2020.46 2072.36 22.16 N 90.48 E 5974552.95 N 371798.65 E 0.178 23.12 2171_74 0.500 11.630 2116.02 2167.92 22.72 N 90.55 E 5974553.51' N 371798.73 E 0.349 22.66 2266.10 0.260 338.320 2210.38 2262.28 23.32 N 90.56 E 5974554.11 N 371798.74 E 0.336 22.13 2344.28 0.170 315.580 2288.56 2340.46 23.57 N 90.41 E 5974554.36 N 371798.60 E 0.157 21.84 2437.75 0.490 4.470 2382.03 2433.93 24.07 N 90.34 E 5974554.86 N 371798.54 E 0.427 21.37 2535.24 0.490 327.230 2479.51 2531.41 24.83 N 90.15 E 5974555.63 N 371798.36 E 0.321 20.60 .. ... . -.. .....'..'.. ". .... --... ......_--......... ......""'.'..-.'..."...---" ,--..----,-."-"..-...",,,-"" ".... 30 January, 2002 - 11:08 Page 2 of 7 Dril/Quest 2.00.08.005 <~r' . Sperry-Sun Drilling Services Survey Report for CD2-26 Your Ref: API 501032039700 Job No. AKMM11220, Surveyed: 18 January, 2002 " North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comm4nt "; (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) ,.'J, .~ ;. 2634.47 0.290 348.040 2578.74 2630.64 25.44 N 89.87 E 5974556.24 N 371798.09 E 0.244 19.94 i ( 2729.30 0.510 351.790 2673.57 2725.47 26.09 N 89.76 E 5974556.89 N 371797.99 E 0.234 19.31 2824.67 0.470 348.230 2768.93 2820.83 26.89 N 89.62 E 5974557.70 N 371797.87 E 0.053 18.54 2920.19 0.530 1.840 2864.45 2916.35 27.72 N 89.55 E 5974558.52 N 371797.81 E 0.139 17.78 3014.58 0.560 16.940 2958.84 3010.74 28.60 N 89.70 E 5974559.40 N 371797.98 E 0.155 17.07 3111.22 0.590 12.720 3055.47 3107.37 29.53 N 89.95 E 5974560.33 N 371798.24 E 0.054 16.36 3207.19 0.620 357.650 3151.44 3203.34 30.53 N 90.04 E 5974561.33 N 371798.34 E 0.168 15.52 3301.90 0.760 7.380 3246.14 3298.04 31.67 N 90.10 E 5974562.46 N 371798.42 E 0.192 14.55 3397.92 0.830 2.320 3342.15 3394.05 32.99 N 90.21 E 5974563.79 N 371798.56 E 0.103 13.43 3492.97 0.790 356.620 3437.19 3489.09 34.34 N 90.19 E 5974565.13 N 371798.57 E 0.095 12.24 3587.83 0.260 150.580 3532.05 3583.95 34.80 N 90.26 E 5974565.59 N 371798.64 E 1.086 11.86 3683.88 0.400 154.190 3628.10 3680.00 34.31 N 90.51 E 5974565.10 N 371798.89 E 0.147 12.42 3779.37 0.300 186.210 3723.58 3775.48 33.76 N 90.63 E 5974564.55 N 371799.00 E 0.226 12.96 3874.47 0.230 185.270 3818.68 3870.58 33.32 N 90.59 E 5974564.11 N 371798.94 E 0.074 13.32 3969.73 0.300 174.980 3913.94 3965.84 32.89 N 90.59 E 5974563.67 N 371798.94 E 0.089 13.71 4064.97 0.350 167.930 4009.18 4061.08 32.35 N 90.67 E 5974563.14 N 371799.02 E 0.067 14.22 4160.01 0.140 194.310 4104.22 4156.12 31.96 N 90.71 E 5974562.74 N 371799.04 E 0.245 14.58 4256.67 0.170 219.170 4200.88 4252.78 31.73 N 90.59 E 5974562.52 N 371798.92 E 0.075 14.73 ( .' 4350.48 0.230 169.170 4294.69 4346.59 31.44 N 90.53 E 5974562.22 N 371798.86 E 0.189 14.96 4447.10 0.180 264.090 4391.31 4443.21 31.23 N 90.42 E 5974562.02 N 371798.74 E 0.315 15.09 4539.60 0.170 124.900 4483.81 4535.71 31.14N 90.39 E 5974561.93 N 371798.71 E 0.355 15.16 4638.90 0.360 251.500 4583.11 4635.01 30.95 N 90.21 E 5974561.75 N 371798.53 E 0.485 15.23 4733.48 2.030 59.660 4677.67 4729.57 31.71 N 91.38 E 5974562.48 N 371799.71 E 2.520 15.12 4828.96 3.610 62.480 4773.03 4824.93 33.95 N 95.50 E 5974564.65 N 371803.87 E 1.661 15.09 4924.72 5.040 68.720 4868.52 4920.42 36.87 N 102.10 E 5974567.46 N 371810.51 E 1.570 15.62 5018.30 8.480 68.780 4961.43 5013.33 40.86 N 112.36 E 5974571.27 N 371820.84 E 3.676 16.94 5117.52 10.540 70.030 5059.28 5111.18 46.61 N 127.71 E 5974576.76 N 371836.29 E 2.086 19.11 5212.24 15.910 70.760 5151.46 5203.36 53.85 N 148.13 E 5974583.65 N 371856.83 E 5.672 22.35 5308.76 22.430 74.080 5242.58 5294.48 63.27 N 178.36 E 5974592.55 N 371887.21 E 6.846 28.29 5403.09 29.680 75.890 5327.27 5379.17 73.91 N 218.37 E 5974602.51 N 371927.40 E 7.731 37.77 . ...,....-.--.-...-.-....-.--,.-..-..-.....-- '--.---. -... 30 January, 2002 - 11:08 Page 3 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-26 Your Ref: AP/501032039700 Job No. AKMM11220, Surveyed: 18 January, 2002 \ North Slope, Alaska Kuparuk River Unit Alpine CD-2 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) (°/1 OOft) ( 5498.47 38.060 75.610 5406.39 5458.29 87.00 N 269.84 E 5974614.71 N 371979.09 E 8.787 50.50 5592.90 44.730 74.380 5477.19 5529.09 103.20 N 330.10 E 5974629.88 N 372039.62 E 7.115 64.62 5688.23 49.800 70.610 5541.87 5593.77 124.34 N 396.81 E 5974649.87 N 372106.68 E 6.058 77.43 5781.08 49.200 70.590 5602.18 5654.08 147.79 N 463.40 E 5974672.18 N 372173.66 E 0.646 88.15 5878.87 48.650 70.120 5666.43 5718.33 172.57 N 532.83 E 5974695.77 N 372243.50 E 0.669 99.03 5974.36 48.040 70.070 5729.89 5781.79 196.86 N 599.91 E 5974718.91 N 372310.99 E 0.640 109.24 6069.09 48.360 69.510 5793.04 5844.94 221.26 N 666.18 E 5974742.17 N 372377.67 E 0.555 118.96 6165.69 47.810 70.370 5857.57 5909.47 245.92 N 733.70 E 5974765.67 N 372445.60 E 0.874 129.05 6261.42 47.070 70.510 5922.32 5974.22 269.52 N 800.15 E 5974788.13 N 372512.44 E 0.780 139.56 6357.03 48.000 70.200 5986.86 6038.76 293.24 N 866.57 E 5974810.71 N 372579.26 E 1.002 149.97 6452.86 50.180 71.630 6049.62 6101.52 316.90 N 935.01 E 5974833.20 N 372648.09 E 2.539 161.36 6549.08 49.720 71.580 6111.53 6163.43 340.14 N 1004.90 E 5974855.24 N 372718.37 E 0.480 173.82 6642.29 49.360 71.930 6172.02 6223.92 362.35 N 1072.25 E 5974876.29 N 372786.10 E 0.480 185.99 6739.17 48.500 71.950 6235.67 6287.57 384.99 N 1141.69E 5974897.74 N 372855.91 E 0.888 198.76 6832.41 48.860 72.160 6297.23 6349.13 406.56 N 1208.31 E 5974918.17 N 372922.89 E 0.422 211.15 6930.46 48.930 73.480 6361.69 6413.59 428.39 N 1278.90 E 5974938.78 N 372993.84 E 1.017 225.18 7026.28 48.760 72.960 6424.75 6476.65 449.21 N 1347.97 E 5974958.42 N 373063.26 E 0.445 239.38 7121.23 48.670 73.450 6487.40 6539.30 469.83 N 1416.27 E 5974977.87 N 373131.91 E 0.399 253.40 ( 7215.57 48.390 73.960 6549.87 6601.77 489.66 N 1484.12 E 5974996.54 N 373200.08 E 0.502 267.90 7311.63 50.350 77.530 6612.44 6664.34 507.58 N 1554.77 E 5975013.24 N 373271.02 E 3.481 285.41 7406.78 52.320 86.980 6671.96 6723.86 517.49 N 1628.24 E 5975021.89 N 373344.66 E 8.022 311.31 7502.69 53.680 97.120 6729.78 6781.68 514.69 N 1704.61 E 5975017.79 N 373420.97 E 8.557 349.78 7598.50 54.750 104.180 6785.85 6837.75 500.31 N 1780.91 E 5975002.11 N 373497.01 E 6.080 398.44 7694.27 56.220 110.440 6840.15 6892.05 476.81 N 1856.17 E 5974977.33 N 373571.86 E 5.599 454.64 7789.98 58.880 115.760 6891.52 6943.42 445.10 N 1930.39 E 5974944.34 N 373645.52 E 5.451 517.61 7885.27 61.360 121.410 6939.02 6990.92 405.55 N 2002.87 E 5974903.56 N 373717.31 E 5.761 586.66 7981.18 64.210 125.690 6982.89 7034.79 358.40 N 2073.90 E 5974855.20 N 373787.53 E 4.957 661.73 8076.69 69.070 129.290 7020.76 7072.66 305.02 N 2143.40 E 5974800.64 N 373856.11 E 6.153 741.57 8171.92 72.600 131.270 7052.02 7103.92 246.86 N 2212.00 E 5974741.32 N 373923.70 E 4.195 825.20 8267.41 75.680 135.390 7078.13 7130.03 183.84 N 2278.78 E 5974677.16 N 373989.39 E 5.256 912.26 .....'."......".'.-.. -.-..'. -.....-.--.--.--- ..--------...--...".....-.. '.-"".-'..'.'.-. 30 January, 2002 - 11 :08 Page 4 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-26 Your Ref: API 501032039700 Job No. AKMM11220, Surveyed: 18 January, 2002 '. North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Esstlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8364.08 78.290 137.210 7099.90 7151.80 115.75 N 2343.83 E 5974607.97 N 374053.27 E 3.264 1002.98 ( 8458.08 81.930 140.980 7116.05 7167.95 45.77 N 2404.44 E 5974536.97 N 374112.67 E 5.532 1093.26 8494.48 82.940 141.420 7120.84 7172.74 17.65 N 2427.05 E 5974508.46 N 374134.79 E 3.022 1128.72 8553.95 84.630 143.650 7127.28 7179.18 29.27 S 2463.00 E 5974460.93 N 374169.94 E 4.687 1187.05 8701.99 88.160 146.480 7136.59 7188.49 150.37 5 2547.58 E 5974338.41 N 374252.44 E 3.054 1333.72 8797.33 88.400 147.180 7139.45 7191.35 230.135 2599.72 E 5974257.76 N 374303.20 E 0.776 1428.65 8893.36 89.020 149.750 7141.61 7193.51 311.965 2649.93 E 5974175.09 N 374352.00 E 2.752 1524.48 8988.91 88.830 150.460 7143.40 7195.30 394.78 5 2697.54 E 5974091.4 7 N 374398.19 E 0.769 1619.97 9083.59 89.630 151.050 7144.68 7196.58 477.38 5 2743.79 E 5974008.09 N 374443.02 E 1.050 1714.62 9180.87 91.540 152.010 7143.68 7195.58 562.89 5 2790.16 E 5973921.80 N 374487.92 E 2.197 1811.89 9274.76 90.920 151.480 7141.67 7193.57 645.57 S 2834.60 E 5973838.37 N 374530.94 E 0.869 1905.75 9371.50 90.620 151.290 7140.37 7192.27 730.49 S 2880.93 E 5973752.67 N 374575.81 E 0.367 2002.48 9466.99 90.490 152.660 7139.44 7191.34 814.775 2925.79 E 5973667.63 N 374619.22 E 1.441 2097.96 9562.62 90.370 152.940 7138.72 7190.62 899.82 5 2969.50 E 5973581.84 N 374661.47 E 0.319 2193.58 9658.05 90.370 152.750 7138.11 7190.01 984.735 3013.05 E 5973496.20 N 374703.56 E 0.199 2288.99 9753.44 90.860 152.350 7137.08 7188.98 1069.38 5 3057.02 E 5973410.81 N 374746.08 E 0.663 2384.37 9848.70 90.920 153.360 7135.60 7187.50 1154.14 S 3100.48 E 5973325.33 N 374788.08 E 1.062 2479.60 9944.21 90.120 153.190 7134.74 7186.64 1239.44 S 3143.43 E 5973239.30 N 374829.56 E 0.856 2575.08 (' 10039.55 90.000 153.320 7134.64 7186.54 1324.58 S 3186.33 E 5973153.44 N 374871.00 E 0.186 2670.39 10134.43 89.820 153.010 7134.79 7186.69 1409.24 S 3229.16 E 5973068.06 N 374912.38 E 0.378 2765.25 10229.93 90.000 152.680 7134.94 7186.84 1494.21 S 3272.75 E 5972982.35 N 374954.51 E 0.394 2860.73 10324.98 90.120 152.820 7134.84 7186.74 1578.72 S 3316.27 E 5972897.12 N 374996.57 E 0.194 2955.77 10417.73 90.120 153.190 7134.64 7186.54 1661.36 S 3358.37 E 5972813.76 N 375037.25 E 0.399 3048.50 10515.89 91.230 152.360 7133.49 7185.39 1748.64 S 3403.27 E 5972725.73 N 375080.66 E 1.412 3146.64 10611.94 91.170 153.390 7131.47 7183.37 1834.105 3447.06 E 5972639.53 N 375122.97 E 1.074 3242.65 10707.28 90.000 152.150 7130.50 7182.40 1918.87 S 3490.68 E 5972554.03 N 375165.13 E 1.788 3337.97 10802.35 89.630 152.230 7130.81 7182.71 2002.96 S 3535.03 E 5972469.19 N 375208.04 E 0.398 3433.04 10898.16 89.690 153.230 7131.38 7183.28 2088.12 S 3578.93 E 5972383.30 N 375250.48 E 1.046 3528.84 10994.34 89.570 151.870 7132.00 7183.90 2173.46 5 3623.26 E 5972297.20 N 375293.34 E 1.419 3625.01 11090.28 91.110 151.460 7131.43 7183.33 2257.91 S 3668.80 E 5972211.99 N 375337.43 E 1.661 3720.94 . .......- .-.-.. .-'-..-...'-"--' .------------.- '---'----"'.'--.'."-"...' .'....,.,...... 30 January, 2002 - 11 :08 Page 5 of 7 DrillQ(Jest 2.00.08.005 Kuparuk River Unit Measured Depth (ft) ( 11181.21 11238.00 91.230 91.230 .~~~i'.. Sperry-Sun Drilling Services Survey Report for CD2.26 Your Ref: API 501032039700 Job No. AKMM11220, Surveyed: 18 January, 2002 '. Inct. Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Depth Northlngs Eastlngs Northlngs Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7129.57 7181.47 2337.67 S 3712.42 E 5972131.50 N 375379.68 E 0.325 7128.35 7180.25 2387.42 S 3739.78 E 5972081.29 N 375406.18 E 0.000 Azim. 151.190 151.190 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 25.139° (29-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 151.870° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11238.00ft., The Bottom Hole Displacement is 4436.86ft., in the Direction of 122.554° (True). Comments ( Measured Depth (ft) 11238.00 .-.......- .-....-...--...-....,......-..-..---... . 30 January, 2002 . 11:08 Station Coordinates TVD Northings Eastings ~ ~ ~) Comment 7180.25 2387.42 S 3739.78 E Projected Survey ............._.-.. - ,-.-,---,,-..---'-.---.-'---.'-"---- ----'--'.-'.'.'--.-.'-.----------'-."- _._Om Page 6 of 7 Vertical Section 3811.85 3868.62 ...:,' . North Slope, Alaska Alpine CD-2 Comment Projected Survey DrillQuest 2.00.08.005 "I. .', . Kuparuk River Unit Survey tool program for CD2-26 ( From Measured Vertical Depth Depth (ft) (ft) 0.00 174.00 0.00 174.00 ( ....-...........---.. . 30 January, 2002 - 11:08 To Measured Vertical Depth Depth (ft) (ft) 174.00 11238.00 Sperry-Sun Drilling Services Survey Report for CD2-26 Your Ref: API 501032039700 Job No. AKMM11220, Surveyed: 18 January, 2002 . " North Slope, Alaska Alpine CD-2 Survey Tool Description 174.00 Tolerable Gyro 7180.25 MWD Magnetic ,_._..-. .......-.-...--.-..-...-,--------.. ----------."'.."-.'.- . .... Page 7 of 7 DrillQuest 2.00.08.005 .----~. AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 -~. 31-Jan-02 Definative Surveys Re: Distribution of Survey Data for Well CD2-26PB2 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 172.00' MD 'MD 490.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECE'" ED FEB 0 7 2002 Alaska Oil & Gas Coos. CommiasJon Anchorage ", ' :... '~" - . , .. DEFINITIVE ( Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-26 CD2-26PB2 Job No. AKMM11220, Surveyed: 4 January, 2002 SURVEY REPORT 30 January, 2002 Your Ref: API 501032039771 Surface Coordinates: 5974532.34 N, 371707.80 E (700 20' 19.1519" N, 151002' 27.6907" W) Kelly Bushing: 51.90ft above Mean Sea Level ( \, speI'I'Y-su" Survey Ref: svy9829 A Halliburton Company '..... Sperry-Sun Drilling Services Survey Report for CD2.26PB2 Your Ref: API 501032039771 Job No. AKMM11220, Surveyed: 4 January, 2002 . North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) ( 172.00 0.900 274.000 120.09 171.99 0.47 5 1.37W 5974531.90 N 371706.42 E -0.24 Tie On Point 238.00 1.000 232.000 186.08 237.98 0.795 2.35W 5974531.59 N 371705.44 E 1.041 -0.41 MWD Magnetic 276.35 0.760 228.490 224.43 276.33 1.165 2.80W 5974531.23 N 371704.98 E 0.641 -0.30 307.05 1.130 212.780 255.12 307.02 1.555 3.12W 5974530.84 N 371704.66 E 1.461 -0.10 358.00 2.400 210.000 306.05 357.95 2.905 3.92W 5974529.51 N 371703.83 E 2.498 0.71 395.77 3.380 204.500 343.77 395.67 4.595 4.78W 5974527.83 N 371702.94 E 2.694 1.80 430.45 4.050 202.200 378.38 430.28 6.665 5.67W 5974525.78 N 371702.02 E 1.979 3.20 490.00 4.050 202.200 437.78 489.68 10.55 5 7.25W 5974521.91 N 371700.37 E 0.000 5.89 Projected Survey 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 25.139° (29-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 151.870° (True). ( \- Based upon Minimum Curvature type calculations, at a Measured Depth of 490.00ft., The Bottom Hole Displacement is 12.81ft., in the Direction of 214.506° (True). " \ _. .. .....-...-.-- --.-.-"-....,-.-..---------.----.----...,,.----....-...-----....... _... .--- '.--'---'----.. 30 January, 2002 .. 11 :09 Page 2 of 3 '4. DrillQuest 2.00.08.005 Kuparuk River Unit Comments ( Measured Depth (ft) 172.00 490.00 Sperry-Sun Drilling Services Survey Report for CD2-26PB2 Your Ref: API 501032039771 Job No. AKMM11220, Surveyed: 4 January, 2002 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 171.99 489.68 0.47 S 10.55 S Survey tool program for CD2-26PB2 From Measured Vertical Depth Depth (ft) (ft) 0.00 238.00 ( \ 30 January, 2002 - 11 :09 0.00 237.98 To Measured Vertical Depth Depth (ft) (ft) 238.00 490.00 237.98 489.68 . -'- ..,.,-...,-,-_. Comment 1.37W 7.25W Tie On Point Projected Survey Survey Tool Description Tolerable Gyro (CD2-26PB1) MWD Magnetic (CD2-26PB2) " --'--.,-----------.---."-.-,."-----...,.".-.,,......,,'."._".".'.....-.-..... . Page 3 of 3 ,~. . North Slope, Alaska Alpine CD-2 -,..,..-.",--.--,--,.",-....-.-.."". ..-.. DrillQuest 2.00.08.005 :( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well CD2-26PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Su rvey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 719.00' MD (if applicable) ( .~,.,:.,."t;;:.';'.l..~~.":"."-,,~,,, ~ ' . W~',,!k'II""'" """""""-'.', ':;,.,11.""",\1. ",~"':.:dJ:}I:.,:,:,,,,"'~:.'I.::,I:-. \, '."""'. ".' ": - '."'..""""...,..':",,'.,...L',.' , 31-Jan-02 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Su rvey Manager Attachment(s) RECE\VED FEB 0 7 2002 A\- Oil & Gas Cons. CommiSSion Anchorage DEFINITIVE ( Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-26 CD 2- 26PB 1 Job No. AKMM11220, Surveyed: 3 January, 2002 SURVEY REPORT 30 January, 2002 Your Ref: API 501032039770 Surface Coordinates: 5974532.34 H, 371707.80 E (700 20' 19.1519" N, 151002' 27.6907" W) Kelly Bushing: 51.90ft above Mean Sea Level ( \ Spfl!I'I'Y-SUr-, Survey Ref: svy9828 A Halliburton Company ,,-, Sperry-Sun Drilling Services Survey Report for CD2-26PB1 Your Ref: API 501032039770 Job No. AKMM11220, Surveyed: 3 January, 2002 . North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth locI. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) ( 0.00 0.000 0.000 -51.90 0.00 0.00 N O.OOE 5974532.34 N 371707.80 E 0.00 Tolerable Gyro 124_00 0.700 246.000 72.10 124.00 0.318 0.69W 5974532.04 N 371707.10 E 0.565 -0.05 147.00 0.900 252.000 95.09 146.99 0.42 8 0.99W 5974531.94 N 371706.80 E 0.942 -0.10 172.00 0.900 274.000 120.09 171.99 0.47 8 1.37W 5974531.90 N 371706.42 E 1.374 -0.24 267.00 1.000 228.000 215.08 266.98 0.978 2.74W 5974531.42 N 371705.05 E 0.787 -0.43 354.00 2.500 200.000 302.04 353.94 3.268 3.95W 5974529.15 N 371703.80 E 1.935 1.02 395.24 3.520 205.200 343.22 395.12 5.25S 4.79W 5974527.17 N 371702.92 E 2.558 2.37 447.00 3.400 210.000 394.89 446.79 8.028 6.24W 5974524.43 N 371701.42 E 0.606 4.13 MWD Magnetic 485.15 2.690 218.300 432.98 484.88 9.708 7.36W 5974522.77 N 371700.28 E 2.186 5.09 576.18 2.230 250.780 523.93 575.83 11.968 10.36 W 5974520.56 N 371697.24 E 1.587 5.67 666.28 1.340 288.630 613.99 665.89 12.20 8 13.01 W 5974520.36 N 371694.58 E 1.589 4.63 719.00 1.340 288.630 666.70 718.60 11.81 8 14.18 W 5974520.78 N 371693.42 E 0.000 3.73 Projected Survey 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 25.139° (29-Jan-02) ( The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 151.870° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 719.00ft., The Bottom Hole Displacement is 18.45ft., in the Direction of 230.2110 (True). \. ..-'.......,.-......-...--...--.--------. '--.."'..-.,......--......--.....-.....-...-.....,..-.--.".."'.'."'._.-....' ..'.- ..... .-....-..-.-,__._._n.,.........- 30 January, 2002 - 11:08 Page 2 of 3 L.- DrillQuest 2.00.08.005 .. Kuparuk River Unit Comments ( Measured Depth (ft) 719.00 Sperry-Sun Drilling Services Survey Report for CD2-26PB1 Your Ref: API 501032039770 Job No. AKMM11220, Surveyed: 3 January, 2002 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 718.60 11.81 S Survey tool program for CD2-26PB1 From Measured Vertical Depth Depth (ft) (ft) 0.00 447.00 ( 30 January, 2002 - 11 :08 0.00 446.79 To Measured Vertical Depth Depth (ft) (ft) 447.00 719.00 446.79 718.60 . .-..--... ...-..__.--- Comment 14.18 W Projected Survey Survey Tool Description Tolerable Gyro MWD Magnetic " Page 3 of 3 -,- . North Slope, Alaska Alpine CD-2 --_. -... .-. -". .-.- ..--.-----... ------...-...-.---- - - ----.-. - -----.---- DrillQuest 2.00.08.005 ( (' Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 .. . February 14, 2002 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of DrillinQ Waste on well CD2-26 Dear Sir or Madam: Phillips Alaska, Inc. hereby requests that CD2-26 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular injection on CD2-26 approximately March 25, 2002. Please find attached form 10-403 and other pertinent information as follows: 1. Form 10-403 2. Annular Disposal Transmittal Form 3. Pressure Calculations for Annular Disposal 4. Surface Casing Description 5. Surface Casing Cementing Report & Daily Drilling Report during cement job 6. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 7. Intermediate Casing Description 8. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 9. Formation LOT on 9-5/8" x 7" casing annulus 10. Plan View of Adjacent Wells 11. Details regarding wells within % mile radius of surface casing shoe. If you have any questions or require further information, please contact Vern Johnson at 265- 6081, or Chip Alvord at 265-6120. ~relY, Z ~-- - ~ Vern Johnson Drilling Engineer cc: CD2-26 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake A TO-868 Anadarko A TO-1530 R£:Cl: 111£:0 FEe 1920 Alaskaa~ . ,. Oz ~ & GasQ Anc,h- Dns. COfTllh' . tVTage "1/88/011 C. ).. -~J ¡ C' 1 ~. ~ p L . . t'\ ! ~J t l \\l ¡-\ (' ( ~~ll °sz , ... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1825' FNL, 1532' FEL, Sec. 2, T11 N, R4E, UM At top of productive interval 1846' FNL, 975' FWL, Sec. 1, T11 N, R4E, UM At effective depth At total depth 1080' FSL, 2231' FWL, Sec. 1, T11 N, R4E, UM 12. Present well condition summary Total depth: measured true vertical RECEIVED FEa l . - ~9 í,: I~ i I AlaSkaOi/&G ,,'. as Cons Gì . Anchorage; ommlssion 7" Baker S3 Permanent Packer @ 7912' MD Effective depth: measured true vertical Casing Length Conductor 77' Surface 2351' Production 7582' Perforation depth: measured true vertical Tubing (size, grade, and measured depth 11238 7180 11238 7180 Size 16" 9-5/8" 7" None None Operational shutdown - Plugging - Pull tubing 5. Type of Well: Development - Exploratory - Stratigraphic - Service X ----- Per APD ----- Per APD feet feet feet feet Plugs (measured) Junk (measured) Cemented 305 Sx AS1 455 SxAS III L & 235 Sx 15.8 class G 162 Sx 15.8 class G Packers & SSSV (type & measured depth) 4.5" 12.6#, L-80 @ 8025' MD Description summary of proposal- Detailed operations program - BOP sketch - Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic 14. Estimated date for commencing operation 15. Status of well classification as: March 25, 2002 16. If proposal was verbally approved 13. Attachments Oil_X Name of approver Date approved Service - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Alpine Drilling Team Leader Re-enter suspended well - Time extension - Stimulate - Variance Perforate 6. Datum elevation (DF or KB feet) R KB 52 feet 7. Unit or Property name Other _X Annular Disposal Colville River Unit 8. Well number CD2-26 9. Permit number I approval number 201-232 10. API number 50-103-20397 -00 11. Field / Pool Colville River Field I Alpine Oil Pool Measured Depth 114' 2388' True vertical Depth 114' 2384' 7619' 7185' x Gas- Suspended - Questions? Call Vern Johnson 265-6081 Date l.( ( fJ / '.) L FOR COMMISSION USE ONL Y Conditions of approval: Notify Commission so representative may witness Approv~1 no. OJ - (? Plug integrity - BOP Test - Location clearance - , ~ 0 - (Q D Mechanical Integrity lies,t~~.,., Subsequent form required 1 o-~ . a . 0 \"\ \"--...~ \<:).. ~- ~ \ ~~ A d b d f th C .. {)daina', Signed B.y Comml'ssl'oner Date "J pprove y or er 0 e ommlsslon CA Form 10-403 Rev 06/15/88 . "\:.... '~ ~.~').i r.':~\"~ \ (.:~.~.:I t.: [\\,1 tß L ~.,^'l\ ,t)ij¡I~\~~ '"..'" i, "NO ~ SUBMIT IN TRIPLICATE ( ( Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-26 b. The depth to the base of freshwater aquifers There are no USDW aquifers in the Colville and permafrost, if present. River Unit. Base of Permafrost = 1556' TVD (RKB) c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. d. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slu rry. The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. Types of fluids can be mud, diesel, cement, and water. Maximum volume to be pumped is 35,000 bbls. f. An estimate of maximum anticipated Maximum anticipated pressure at casing shoe pressure at the outer casing shoe during during disposal operations is 1908 psi. See annular disposal operation and calculations attached calculation page. showing how this value was determined. g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. See attached cementing reports, LOT/FIT reports, and casing reports. h. Details that show the inner and outer casing See attached casing summary sheet and strings have sufficient strength in collapse calculation page. and burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission to confirm containment of drilling wastes. NA ( ( CD2-26 Pressure Calculations for Annular Disposal L- L- Q) Q) "0 ro "0 Q) ro Q) ..c: ..c: ëi5 ëi5 c.. c.. 0 0 0 0) 0 0 c: N 0 CJ) N ro + + U ~ ~ = ~ CJ) CJ) l() c.. c.. I ...- ...- (j) 0 0 CJ) CJ) ro ro <.9 <.9 <=9-5/8" 36 Ib/ft, J-55 BTC casing @ 2388 ft MD (2384 ft TVD) Pburst = 3520 psi, @ 85%: Pburst85% = 2992 psi "....n 0.....0.0... °TÖCo Estimated Top of Cement @ 7672 ft MD (6879 ft TVD) (7" csg x 8-1/2" Open hole annulus) 0) c: :.ö ::J l- N 0) ;:: c: I ëi5 """ ro U <=4-1/2" 12.6 Ib/ft L-80 tubing to 8025 ft MD (planned) ¡;... <=7" 26 Ib/ft, L-80, BTC casing @ 8619 ft MD (7185 ft TVD) Pcollapse = 5410 psi, @ 85%: Pcollapse85% = 4598 psi ASSUMPTIONS: . Maximum injection pressure, PApplied = 1500 psi . Maximum density of injection fluid is 12.0 ppg. . Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft . Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULA TIONS: Maximum pressure at 9-5/8" shoe: Pmax = PHydrostatic + P Applied - PFormation Pmax = 12.0 (0.052) (2384)+1500 - 0.4525 (2384) Pmax = 1908 psi Maximum fluid density to burst 9-5/8" casin~ Pburst85% = PHydrostatic + P Applied - PFormation 2992 = MWmax (0.052) (2384) + 1500 - 0.4525 (2384) MWmax = 20.7 ppg Maximum Fluid Density to Collapse 7" Casinq: P collapse85% = PHydrostatic + P Applied - PGasGradient - PHeader 4598 = MWmax (0.052) (6879) + 1500 - (0.1) (6879) - 2000 MWmax = 16.2 ppg ( (' flPHILLIPS Alaska, Inc. Casing Detail 9 5/8" Surface Casinq Well: CD2~26 Date: 1/4/2002 A Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LOS 36.60 FMC Gen V Hanger 2.20 36.60 Jts 3 to 55 53 Jts 9~5/8" 36# J~55 BTC Csg 2258.78 38.80 Davis Lynch Float Collar 1.95 2297.58 Jts 1 to 2 2 Jts 9-5/8" 36# J~55 BTC Csg 86.54 2299.53 Davis Lynch Float Shoe 1.75 2386.07 9- 5/8" shoe @ 2387.82 TO 12 1/4" Surface Hole 2399.00 RUN TOTAL 32 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 ~ #12 (On stop rings of Jt #1 & #2) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52 Last 12 joints stay out # 56 thru # 67. Use Best-O-Life 2000 pipe dope Remarks: UpWt-155k On Wt -130 k Block Wt ~ 75 Supervisor: Don Mickey ( ( PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-26 Common Well Name: CD2-26 Event Name: ROT - DRILLING Report #: Start: 1 1/2/2002 Cement Job Type: Primary ---------- Page 1 of 3 Spud Date: 1/3/2002 Report Date: 1/9/2002 End: 1/20/2002 ----------~-----.._-_.__.... ... -~_._~----__..!:!l'II. a !y__._._--------_._..~--- ....._..__.c_..n_~q_~~~~~gl?~tÜto.J.~.._......_-_...c_.. --_._-_..___._§Ry_~~ze _Ç~~Lr:!g_._n-.._.....~--_..._. -_._._-,--_.c____.EJ.~_g._-----_._..._- ...- -_._.. Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 2,388 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 1/8/2002 sa Date: Date Set: BTM set: (ft) Csg Type: Surface Casing sa Type: Csg Type: Plug Date: Csg Size: 9.625 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start: 19:30 Cmtd. Csg: Cementer: Jerry Culpepper ,.PipeMovement Pipe Movement: Reciprocating Time End: : Time End: 21 :00 Avg Torque: (ft-Ibf) Drag Up: 150 (Ibs) RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 15.0 (ft) . .. . . .--'-----...-. ----.- .----.--..- -_._--- ._-_._. . ----- .-.-- .-_._..._. -'-'.-. -....-.-. _._n.- ..--.-.- -..--.-----.--.. ------------ Stage No: 1 of 1 Type: Cement Casing Volume Excess %: 300.00 Meas. From: Time Circ Prior To Cementing: 1.50 Mud Circ Rate: 231 (gpm) Mud Circ Press: 300 (psi) Start Mix Gmt: 21 :00 Start Slurry Displ: 21 :13 Start Displ: 22:20 End Pumping: 23:05 End Pump Date: 1/8/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.00 (bbl/min) 5.50 (bbl/min) y 480 (psi) 1,000 (psi) 5 (min) Y Mud 'Data Type: Spud Mud Density: 9.6 (ppg) Visc: 57 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud Max Torque: (ft-Ibf) Drag Down: 130 (Ibs) '-..."-'-'."".-......-...'. Returns: full Total Mud Lost: (bbl) Gmt Vol to Surf: 51.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: PV/yP: 19 (cp)/14 (lb/100ft2) Gels 10 sec: 10 (lb/100ft2) Gels 10 min: 22 (lb/100ft2) Bottom Hole Static Temperature: CF) Density: 9.6 (ppg) Volume: 157.00 (bbl) . . . . . ... ---- --.- ------- -.------ ----..-.-- -- ---... -- ._-.._--- --..------...- -. -------.------ Stage No: 1 Slurry No:1of4 -.----.-------'-----.----.-..----.---...--......-.. -.--.- ... Slurry Data Fluid Type: FLUSH Slurry Interval: 2,388.00 (ft)To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: CF) Description: Vis Water wI nut plug Cmt Vol: (bbl) Density: 8.30 (ppg) Slurry Vol: (sk) Water Vol: 40.0 (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Temperature: CF) Temperature: CF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Purpose: PRe flush Mix Water: (gal) Foam Job: N Temp CF) CF) Pressure (psi) (psi) Printed: 1/30/2002 3:34:44 PM ( Legal Well Name: CD2-26 Common Well Name: CD2-26 Event Name: ROT - DRILLING (" PHILLIPS ALASKA INC. Cementing Report Page 2 of 3 Report #: Start: 1 1/2/2002 Spud Date: 1/3/2002 Report Date: 1/9/2002 End: 1/20/2002 Stage No: 1 Slurry No: 2014 -,...-..-----.-....-.'--.-' -.--..-...---.. ---...--...-.-.......-.-..---.... .... ..--.-...-..--- ..-..'--.-.- -....-- _..._- ..._- --.-..- .._. .-. - -. ---.... -.. --..- -"'---"-'--' -... --- -.-. -. .-- .-.....-.'. -.. -.-. .....-......-.-.-.-.--.-...-.......--. -. _._.. .--......-.--.-.---.-.-..--- ..... - "". --... . .-... _... _.-...- Slurry Data Fluid Type: Spacer Slurry Interval: 2,388.00 (ft)To: (ft) Water Source: Description: ARCO Cmt Vol: (bbl) Slurry Vol: (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: CF) Temperature: CF) Temperature: CF) (OF) Class: Density: 10.50 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry No: 3 of4 Slurry Data Fluid Type: LEAD Slurry Interval: 1,888.00 (ft)To: (ft) Water Source: lake water Description: AS Lite Cmt Vol: 360.0 (bbl) Slurry Vol:455 (sk) . .....--.---..-----.---..-,-..--...----.-..-...-..-.-.--. .... .--------.---... -.,.--.,.,....--.-.,----.-,.---".--,-,.- . Class: Density: 1 0.70 (ppg) Yield: 4.44 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp CF) CF) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Stage No: 1 Slurry No: 40f4 . Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,388.00 (ft)To: 1,888.00 (ft) Cmt Vol: 48.0 (bbl) Water Source: Slurry Vol:235 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: CF) Temperature: (OF) Temperature: CF) CF) ---.-.- --------.-"-.---- -.-.- -.-. ....------. .----..-----. -. --..----.---.. .-------. _0-__.__-- .-- -- --. ------ -.. ...-. '---- -- -- ..-.- .-.. - . ... _... -. Class: G Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) CF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) -~,--_.__..~-----_.__.....__. Purpose: FILLER CEME Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: SHOE INTEG Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Printed: 1/30/2002 3:34:44 PM (' ( PHILLIPS ALASKA INC. Cementing Report Page 3 of 3 Legal Well Name: CD2-26 Common Well Name: CD2-26 Event Name: ROT - DRILLING Report #: Start: 1 1/2/2002 Spud Date: 1/3/2002 Report Date: 1/9/2002 End: 1/20/2002 Casing Test Shoe Test Liner Top Test _.- --'-"'----..-'.-'--'--- ...-.-..---...--.-...., .... -..--.... -..-..-- ...... _.... .-. -,. _..-.... -..-. ....... -.. ..-.....----...-.. .-... -.. ... ..-.-...... ...... ..-.. -..... ....---... ---- ..._. - '.-.......---..-.---..------.-----..-----. .--.-...-..-. -.-.-.--..--.- ---. -., .-..- -.-.-.. ., -..----.... ,. '-'....'-.. -- -... _.. Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Tool: Open Hole: (ft) Hrs Before Test: Log/Survey Evaluation Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: -..---------.-- -.----...-------.---..--.--..-.--..-...... ..---..... Printed: 1/30/2002 3:34:44 PM ( ( Phillips Alaska, Inc. Daily Drilling Report Page 1 of 2 JOB NUMBER EVENT CODE 124 HRS PROG TMD TVD DFS REPT NO. DATE CD2-26 ODR 378.0 2,398.0 2,394.0 6.00 7 1/8/2002 SUPERVISOR RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD DAILY TANG CUM. TANG Don Mickey____- ---_...9~Y_~nl@J~~f..~coæJ_9_-----------~F: A!pine _____...J...1 ,292JL- --_._-_O.QQ-_--.-fJ.OO ------- CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTW/O MUD CUM INTANG WI MUD 2. 4 .H:~OR~~A~T.test E30P~_:'M:8:::r":HA - D~_8:;'Jh~_~--=~~~ :~~E~:J:::.F LA1~; ;;;;~_:::ING _DA. Ie YTO~~~O~54 --=- .. .:~~ C_~. ~f.~..;..--.;._~.-.~.....:_:..- LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE AUTH. 998D13 .-..---.-----.---- ---.._------ ~- --- --'---E- -----..----.-.-- -'-..'---.-.--..'.-----.. -- --.-- LAST SURVEY: DATE TMD INC AZIM LAST CASING NEXT CASING LAST BOP PRES TEST ___Jl8/20Q.~_- 2,344.2~__.- 0.U_9_____315..58..Q_- -~:.§?_~Ü!:!L@_.___b;l~8.0 ŒL 7.000 Ü.QL@.____I1§~.l!2.(f!l ---.-------.----- .. WELL NAME ---.,-.---...- - .. -.----.--.-- ------ _.',------------ - ----- --------,---.--..,-. ---.--.-----..-....--..-.-- DENSITY(ppg) FV PVlYP 57 19/14 9.60 PP GELS WLlHTHP 10/22 8.01 ECD MUD DATA ... DAILY COST FC/T;SOL OIL/WA T %Sand/MBT Ph/pM 21 I 127.5 8.81 0.00 Pf/Mf I CI CUM COST Ca H2S 0.00 LIME ES BHANO. 4 BHA I HOLE CONDITIONS BHA WT. BELOW JARS STRING WT. UP STRINGWT; DN STRINGVVT.ROT 147 143 147 ITEM DESCRIPTION NOJTS LENGTH O.D. Bit 1 1.00 12.250 Navidril Mach 1 C 1 28.82 8.000 --...-----..-----.----.-----.-------------------......--...--...- .-.--..----------- -------.-----..--.--.------.---------- .---.------.-.-. ----..-...-...----- -.-. . XO 1 1.30 8.000 3.000 -----------------------.---.--.-.------.------ -- - ----- Drill Collar-Short NM 1 9.92 8.125 3.000 --------.-.-...-.---------.-...------.---------.-.--.-- .--.------- ---- ---- -----,.. ---------.- --- _S t~ b i~_~e r.:.~ 0 n -~~R______--..---.--------.-..-.--.----------.-----..--.. ._-----~------ --- 5 .75 --~§-~--_. _._._--~~ 7 5 -- -----.-.-.-.---. ------. .------ ..... MWD 1 30.37 8.063 1.920 ----'.---------..--'.-'---------.----.-----'-'-.---- .----'..----.--- -.-------..- -.----. -..----.-.----.-- ----.-----..-------. --.--.----.--..--.....- ..... . UBHO 1 3.27 8.065 3.000 ------..---.--..- -..--..----.---.----------. - ---.-.--..-------- --- --.----- ._--- ------- -------- Drill Collar - NonMag ------_._----~_.__.__._--- 30.6~_- 8.06~____--__~.875 --'--.----------------------- prill Collar -- Non_~JL__.__._--_._---_..._----_._---- ------~---_._.._-_.- 30~__- 8.065 .__.___~.::.875 - ---.------------ _?...tabilizer - Non~~g ----------.----..---.--------------------_...!_---.---- 5.6~__. ._- 8.0~?__-_.~~.??._-_. -------"'---_.._--_._..._...' Drill Collar - Non Mag 1 31.07 8.065 2.875 Crossover 1 3.65 6.500 3.000 Drill Pipe - Heavy Wgt 3 88.34 5.000 3.000 Jars - Up/Down Jars 1 33.40 6.125 2.250 Drill Pipe - Heavy Wgt 23 690.10 5.000 3.000 TORQUE ¡UNITS 7,000 ft-Ibf I.D. ---....------- . BITS BIT / RUN SIZE MANUF. TYPE S.ERIÀL NO. JETS OR TFA R11 3 12.250 HUGHES-CHR MX-C1 P58JF 12/12/10/1811 R11 3 12.250 HUGHES-CHR MX-C1 P58JF 12/12/10/18// DEPTH IN DATE IN I.O.D.L.B.G.Q.R 271.0 1/7/20024-6-WT-A-E-2-EC-TD 271.0 1/7/2002 0-0------ -----.-------.- -- --.-..-- ----.--- .---..---.--- ---- -.'- ----------.--. .. -- .--.-----.--- -- -------'- ------ . . . .. . --._---- . .. -------- ----- ... ..BITOPERATIONS......... ... .----'--.'.--""'--:tl"-----"'-.--'------- .'------..'-.----".¡---"-. --'------J."'--.':.-.'--""--"- _._-_._._""---t-."""""".-~. '-_..__.,_..~'--- "-"'--'--_._-------j'---"'--'-.""-~."""-. -".---"..--..'-.1-'..-----'--. ........ ". -_.;-- BI~!.!!~N . . .._-_...WO~--_._.- -_J.~~-'Y'__._._- _.._~~-~--_.___fR~~~_. ._._-_.~-~!!_.. ._-~.~--_~4~r~_I_~1._..- 24~~ RO':...: .E~M H~~- CU~E,~~r~- -~Y~-~C?.P R1 I 3 I I . --. -----------------.-....-....--.--------,.-..- -- ------- ---.---.-.--.-.-.. .....---- ---------.----. --' --- ...- -----'" .-------- -- -- -"'---.---- _. - -------- ---- - -.------------ - - -'---..---'- .-.,---- -- . . ... . .. . .. . . . . ---.-.-.----.-...---....-----..,..- .- . .... SURVEYDATA.. --. ._--------- ------.-- .-- ------'-'-- .-..'"---.. .---"--.----'--.---.-..,-...----..-.,---..,--........, . .. . . . .. .. ... . . ---~~____IN~,=--__..~~!.~U"!:~-- -,TY:D:~_.~!~-~~~~ .~_~_~UM .:.~~Il9..~- ,-ivl.D.___~~L:..__. .~ZIMUT_~__.---.:!":~~:~- N/~ C':'..~.._5~CU_~ __~~E~~C:>~ 2,076.18 0.180 353.590 2,072.36 22.16 90.48 23.12 2,266.10 0.260 338.320 2,262.28 23.32 90.56 22.13 ------..-- .-------.-.--------.---- -- --- ---- .-..-.----.--.--.-.- 2,171.74 0.500 11.630 2,167.92 22.72 90.55 22.66 2,344.28 0.170 315.580 2,340.46 23.57 90.41 21.84 PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 12.000 6.000 65 273.00 12.000 6.000 65 273.00 NO. 1 2 MAKE OF PUMP Continental Emsco Continetal Emsco PRESS. (psi) TOTAL Q 2,150 546.00 2,150 546.00 KILL SPM / PRESSURE Printed: 1/30/2002 1:15:23 PM ( (' Phillips Alaska, Inc. Daily Drilling Report Page 2 of 2 CD2-26 JOB NUMBER EVENT CODE 24 HRS PROG ODR 378.0 DATE 1/8/2002 WELL NAME OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 04:30 4.50 DRILL P DRLG SURFAC D rill 1 2 1 14" h 0 I e f I 2 0 2 0' to 2398' TV D 2394' ADT 3.8 ART 3.8 --- -...------.-------...-.-------..---------.-....- ------.------------ . ----..-------.---..-. ..Q1:30 06~g.9.__-.:!..50 -. DRI~.~_~..- ---_.___~IRC __SURFAC C i r cui ate h 0 I e c I e a n for wi per t rip -.--------- 06:00 07:30 -_..!.:~-- pR~LLJ:.__.__---_._- WIP_R____._~URF_~C Wi P eLJ..!:i~_~}-~~....!...~~. 55 6 ~~-_o k - R I H!..o__~_~~-'..- 07:30 08:00 0.50 DRILL P CIRC SURFAC C i r cui ate h 0 Ie.. F low c h e c k - b low do w n top d r i V e ---.._- --- --.------- --.-----.--.- ------..----.-. ------ ---- -- ---- -.-------..--. --....--..-----.--.-.-..--..---.-.. 08:00 12:30 4.50 DRILL P TRIP SURFAC POOH .. c h a n g e 0 u t jar s, L DUB H 0 sub. M W D , S t a -- ------------.-.-.---------- b, -~_C?_~_¥._..J?~-,--~~~~-~~__:._£!...e~_~_~..E.._~._~.9_J_.I_~._~__r--.-.-..... 12:30 .._~i:_OO -~-~~~§J:>_-----_.__._-~~~--_.___SUR~A~ Rig up to run 9 5 I ~" c s g.---------.----...---------.-------. . 14:00 14:30 0.50 CASE P SFTY SURFAC He I d P J S M 14:30 19:30 5.00 CASE P RUNC SURFAC P U & run cas i n g - Ran 55 j t s. 9 5 I 8" 3 6 # J - 55 B T C csg wI FS @ 2388' FC @ 2297' - Land casing 0 n mandrel hanger in wellhead .. RD fill up tool & RU Gmt head CIRC SURFAC C i r cui ate & con d it ion mud for c e men t job PUMP SURFAC P J S M - C e men t cas i n g .. P u m p 40 b b I S vis f res h w ater wI nut plug marker - Pump 5 bbls water - tes t lines to 2600 psi - drop btm plug - pump 50 bbl s Arco spacer @ 10.5 ppg .. followed by 360 bbls AS 3 Lite @ 10.7 ppg (observed nut plug spacer @ shakers wI 345 bbls pumped) switch to tail slu rry 48 bbls (class G) @ 15.8 ppg - drop top plug wI 20 bbls water fI Dowell - switch to rig pumps & displace wI 157 bbls mud - bumped plug wI 100 0 psi .. floats held CIP @ 23:05 hrs. - RD cmt lin es --- ---------.------- --.-.-------.----..-.-.-..-.....-....-.. PULD SURFAC R D c e men the ad.. B a c k 0 uti and i n g j 0 i n t 19:30 21 :00 21 :00 23:30 1.50 2.50 CASE P CEMENT --- -- ----- --..--- ---- 23:30 00:00 0.50 CEMENT 24 HR SUMMARY: Drill to 2398' TD - Circ - Short Trip - Circ - POOH .. RU & run casing 55 its Shoe @ 2388' - Cmt wI 360 bbllead & 48 bbls tail Clp @ 1105 hrs. RD Gmt equip COMPANY Phillips Doyon Baker Inteq MI Drilling Flui~___. Dowell . PERSONNEL DATA NO. . HOURS COMPANY 1 Sperry Sun 25 DSR 1 ACI 3 FMC ---------.-..---- ----- ---.---.-- 2 HOURS SERVICE SERVICE. NO. 2 4 5 1 -.--.--. ..--- ----------- ---. -.--.-.-.-..,..--... ..-.. _.. ---.----- --_._--.- -..----...-'"--- -.-----.-.-.-- -.- -.-.- - .-... .. --"--'-'-'--'-.-'-----.----- "'--------'-- .. .. . .... . ... MATERIALS/CONSUMPTION...... .... . . ;¿~:~:~-~=~f~~Ú~-= ~l--~::~~O~~:~~ ------".'-..-'---."'-.'-"- ------------ -----------'.'. ---.--- - -'-.--,-- .. . . -..,.,..-.-.------.--..,.---,-----.- -.----..,.:-----.. ..,.-..-...-..---.----------------...,...-,-.-----.-_J?JJ,e PO.~I..g_BA F:.I.,:_____-. "---'----------- ----.-----.-.-..-----,--------.....--..----,.-,-.......--.,-... ......_. TYPE NO. REMARKS. . TYPE NO: REMARKS CD2-47 850 CD2-26 ----- .--------.----.--- . .. .. .. ..-,----..-.-.----,.....-..- Printed: 1/30/2002 1:15:23 PM Well Name: CASING TEST and FORMATION INTEGRITY TEST Date: MINUTES MINUTES FOR FOR LOT STROKES PRESSURE eSG TEST STROKES PRESSURE !:~~~~~~~~~~~~~~~I~~~~~~Q~~~~~~I~~~~~~Ë~!~~~][~~~~~~~~~~~~~I~I~!E~~~~r~~~~IR~I~~] 1 1 1.0 1 30 psi: 1 1 2 stks : 50 psi: ',______n______------------------t----------------of"_--------------+--------------+-----____-_n_--i Casing Setting Depth: 2,388' TMD Hole Depth: 2,418' TMD! 1 2.0 1 60 psi 1 ! 1 4 stks : 180 psi: ',----_n______---"---------------~-----------_----""---------------....--------------....----------------.. 2,384' TVD 2,414' TVD L--------------L----~:Q------L--~-~-P.~~--~b~-------------L--~-~!~:;---L--~-~QJ?_~~--.l Mud Weight: 9.5 ppg Length of Open Hole Section: 30' I'---------------+-----~~~-----+--~;-~-~~:W~--------------+--1~Õ~r~Š--+---~-~~-~~~---t 1,--------------------------------t-------------.--'>i\\C!s'--------------+--------------+--------------.--i !,--------------_l._---~:Q-----_L_~~_~_p'~_I_~~b-------------_l._~.2._~!~~-_l._!~~Q_~_P.:;Ll EMW = Leak-off Press. + Mud Weight = 809 psi + 9.5 ppg L-------------.l----_!':Q------L-~~-~-P.~-~)l,LC~b--------------L-~-~-~!~~--L-!~.!.~-~_p':;_i--1 0.052 x TVD 0.052 x 2,384' !,----------------~-----~:Q------~---~~-~-p.~L~b-------------L--~-~-~!~-~--L--!!~~.Q_p.:;L¡ EMW for 0 en hole section = 16~ 'fp ~ ~OI~a~s4) ~ IS ~~----------+----190~Õ-__-+--~~-~-~~~-~" ~-------------t-.l~-~~~~--t--~~~~~-~~+-1 p 9 ',-____-----------"---------------~----______n___~ \ ~------------_...._------------_...._--------------_.. NO Pump output = 0.0997 bps Fluid Pumped = 1.2 bb!s ¡'---------------+-----~~~----+--~¡-~-~~:-~~b------------t--~-~~~~--t-~~~~-~-~~-:--i I'----------------r----------------r----------------..,,'---------------""--------------""--------------.--~ # 2 Fluid Bled Back = 0.7 bbls 1 1 1 1 : 1 26 stks I 2,240 pSI: 1'--- - - - -- - - - - - - ------- -- ------ -- - t n____- - - -- - - - - - of :'---- - - -- -- - -- - - + ------ - - - - - -- - +- n----- -- --- -.- - i 1 1 1 1 : 1 28 stks : 2,440 pSI 1 ',----------------"_____n______--~----------------"',-n___---------""--------------""----------------" ! ! ! ¡ ¡ ¡ 29 stks ¡ 2,500 psi ¡ "----------------,,---------------~----------------""---------------+------____n__+___-------------ot 1 I 1 1 1 1 1 1 1 I 1 1 1 1 I 1 I'---------------+---------------~-----------------:I.---------------+--------------+----------------~ I I I I 1 I 1 1 t--- --- - - - - --- -- -~----- - - -- - - -- -- t-------- - - - -- -- - 4 !.---- - -- - - -- - - --+------- - - - -- - - + - ------- - -- - - ---i I 1 I , 1 I 1 1 I 1 I I 1 I 1 1 .----- - - - ---- - - - ....----- - - -- - - -- --~-------- - - - --- - -.. ~---- - - - - - - - - ---....---- --- - - - - - - -.... - -- ----- - - - - ----.. 1 1 1 1 1 I 1 I I 1 1 1 1 I 1 I ~---------------..:.---------------~----------------.; 1 I 1 I ! ! ! ! ! SHUT IN TIME! SHUT IN PRESSURE I'. -- - - - - -- --- - - --r----- - - - -------- r ------- - - - --- - - -.., r----- - - -- ----- -.,.. ------ --- - - - -- ...-- - - ----- - - - - -- - - ~ 1 1 1 I:O.Omìnl 12.500psi: 1'---- - - - -- - -- - - ------- - - ------ -- - t - ------ - ---- - - -- of }---- - - ----~-- - - + ------ - - - - - - -- +-- -------- - ---.- - i 1 1 1 1 : 1.0mln 1 : 2,500pSI: .--- - _n_- - - - -- --... .. ........ ....... ......... ~ ............................... , . ~-- -- - - -- _n - - - -.... ------ - - - - - - -- ....-- _-__-n___- - - -.. ¡ ¡ ¡ ¡¡2.0mìn¡ ¡2,500psi¡ ¡ SHUT IN TIME! SHUT IN PRESSURE r---i(frri¡ri--r-------------r'2~5õ-õJ)ŠTl t--- - -- - - - - - -- -- .,..-------- - - - - - -- r n_____- - - - ---- -.... t---- - - - - - - - - - - -.,.. --- -- -- - -- --- -.,..- ------- - -- - - - --~ : 0.0 mìn : : 810 psi : 1 4.0 mín : 1 2,500 psi 1 ~-- --- - - ----,-- -- -I- ----- - - - - - - -- --t------- - - - ---: - - of 1------- - - - - -, - ---+-------- - - --- - + - - ------ - - - - --:-i ; 1.0 mln 1 : 760 pSI: 1 5.0 n1m : 1 2,500 pSI: ,----- - - ------ - - ....----- - - -- ------~ ------- - - - -- - - --.. ~------ - - - - -- -- -.... - ----- -- - - - - --.... - - - ----- - - - - - ---.. ! 2.0 min ! ¡ 720 psi! ! 6.0 mìn ¡ ¡ 2,500 psi! r--- - - - --- - -- - - -+---- -- - - --- - -- - ~ - ------ --- - - - - --.. .----- - -- -- --- - - + ------ - -- - - - -- + -- - ------- ---- - - ~ ¡ 3.0 mill ¡ ¡ 690 psi ¡ ! 7.0 min ¡ ! 2,500 psi ¡ t--- - ----- - -- -- --,.-- -- -- ---- - -- - - r - ------ --- - - - - --.., t----- -- - - -- -- - -.,.. ------ - - -- - - -- .,..-- --- --- -- ---- - - ~ : 4.0 mill : 1 660 psi 1 1 8.0 min 1 : 2,500 psi: ~--- ---- - - --, ---- ------ --- - - - - - - - -t -------- -- - --:- - of }---- - --- - -~ -- - -+ ------- - ------+- ------- - -----.- - i : 5.0 mln : : 620 pSI: 1 9.0 mm : : 2,500 pSI 1 r--ffõ - nlin -- T---- - - - - - - ----¡--SÕ-Õ - r;šT -1 ¡--1-Õ ~ Õ ¡ñ 1 n-r--- ----- - - --- T - '2 ~5Õ-Õ -r; šT! r--- - - - - -- --- --- +----- - - -- ------ ~------- - - --- - - - -.. ~------- - - - - - ---+--------- - - - - - + - - - ------ - - - ----ot ! 7,0 min ¡ ¡ 590 psi ¡ ! 15.0 rnin ! ¡ 2,500 psi ¡ t--- --------- -- -.,..----- - - ------- - r - ------ -- -- - - - --.., r------ - --------.,.. ------ --- - - --- .,..-- - ------- - - ----~ 1 8.0 mill 1 1 570 psi 1 : 20.0 min 1 : 2,490 psi: ~--- - ----- - -,- -- ----- -- -- -- -- -- - - - t - --------- - - -:- - of }-- -- - -------;- --+ ------ - -------+--------------.-- i : 9.0 mm : : 560 pSI: 1 25.0 nW1 : : 2,490 pSI: r-Tõ~ë)" m in-¡-- -- ----- - - - - - -¡ -- 5!fõ" r; sf" -1 r - 3- Õ ~õ -!ñ 1 ñ - - r----- - - - - --- - r '2~4ffõ -r;šT 1 .-------------------------------.----------------...-----------------------------------------------4 CD2-26 1/9/2002 Supervisor: D. Mickey Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8", 36#, J-55, BTC CSG Used cement unit Ria pump used 4,000 psi 3,900 pSI 3,800 PS! 3,700 pSI 3,600 PS! 3,500 pSI 3,400 psi 3,300 pSI 3,200 pSI 3,100ps! 3,000 PS! 2,900 pSI 2,800 pSI 2,700 PS! 2,600 PS! 2,500 pSI W 2,400 psi "'" 2,300 PS! ~ 2,200 PS! ..... 2,100 pSI rJ) 2,000 psi rJ) 1,900 pSI W 1,800 ps! D:: 1,700 pSI Q. 1,600 psi 1,500 pSI 1,400 pSI 1,300 pSI 1,200 PS! 1,100 pSI 1,000 pSI 900 ps 800 ps 700 ps 600 ps 500 ps 400 ps 300 ps 200 ps 100 ps 0 ps --..-------------- ---------- ---- ______n____-'--------- - .----.-----.- :':====::::'==~=I=':====-:=~~-'= - -----.---.--------------- - .-------------- --.--.---------..------ --------'---- .- ----------- -------_._-.-- -- ------ --.---- -- ----.---- ---.--.-------.----1--------.-.------- 1------'----- ------.------- ___n______--.--- ----------'-------- TIME LINE... . 1--,-------- - ---.-------------- -'----'-'--------- ------------.---- ------.----- -- ONEMINUTE TICKS I - ---- -. . - ---._.---------- -'.----' - --- n -r-- - - ----------- -- -----.--.--.-- --.- 1---------------- ___n__-.__--- ----;/--- ----------.------. ------- ---------- ------- -- -.------------ ---/--.-- n_.._.__----.- ---- --. -- __n ---- _!--LL.J- ..L -...------------- -.-..---------. ------:/---- - --------.-- .---------------.- ---- ----------- ----- ---.------------- ---------.------ ---- ---f------ ------------._-- ---.--..-..---.---.-- ----.--------- ------- -------- ¡------------- -~---- --.-------- .------- ----------- ------_.~ -------- -- -----'--- _.------------ _n__- --_._-- ---.------------ ===-~~ ------ ...-------- ------------ ----..------ --- ---------_._- ----------.---- -..----.----- -._--._.------ -0- LEAK-OFF TEST .L'r .-- -ö-CASING TEST ,....~ ,---- ,.- LOT SHUT IN TIME .I- - ----'. ~ '.. .- CASING TEST SHUT IN TIME L!T -+- TIME LINE --- ~ --- 0 20 so 30 STROKES 10 40 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds .PHlllIPS Alaska, Inc. . ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY LEAK-OFF DATA CASING TEST DATA ) ) 60 NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ( ( Casing Detail 7" Intermediate Casinq Well: CD2~26 Date: 1/15/2002 Phillips Alaska, Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 35.20 FMC 11" X 7" Hanger 1.58 35.20 Jts 3 to 211 209 Jts 7" 26# L-80 BTCM Csg 8496.41 36.78 7" Davis Lynch Float Collar 1.42 8533.19 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 82.23 8534.61 7" Davis Lynch Float Shoe 1.71 8616.84 8618.55 8-1/2" TD 8629.00 1 straight blade centralizer per jt # 1 thru # 32 Jt. 152, 153, 154, then every other jt 156 to 208 62 total centralizers Use Best-a-Life 2000 pipe dope Remarks: Up 111ft =290 On Wt =190 Block Wt= 75K Supervisor: David P. Burley (" ( PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-26 Common Well Name: CD2-26 Event Name: ROT - DRILLING Report #: Start: 2 1/2/2002 Cement Job Type: Primary Page 1 of 2 Spud Date: 1/3/2002 Report Date: 1/17/2002 End: 1/20/2002 ..-----.--._u_----.--------._u.p.rl!Dary._..._u_--_u_---.-.-----. ._-_..__._-_u_--§g!-!~~?~_9._p"~_Q,H_9..I.~_._._--_.._._------..- -_.._---_._____~il~~.~?=~-ç-~-~J.!1..g-_._------_...:.- --------_._.._--_u_...._._-_.__P.l'!'!9...__..__.._------- Hole Size: 8.500 (in) Hole Size: Hole Size: Hole Size: TMD Set: 8,619 (ft) SO TMD: (ft) TMD Set: Top Set: (ft) Date Set: 1/15/2000 SO Date: Date Set: BTM set: (ft) Csg Type: Intermediate Casing/Li SO Type: Csg Type: Plug Date: Csg Size: 7.000 (in.) SO TMD: Plug Type: SO Date: Drilled Out: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start: 13:30 Cmtd. Csg: Cementer: Jim Thompson Pipe Movement -- Pipe Movement: Reciprocating Time End: : Time End: 16:45 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 50 (Ibs) Stage No: 1 of 1 ----..---.---.-----. Max Torque: (ft-Ibf) Drag Down: 50 (Ibs) ---...c.-_--'----'.-------------.---._C_---.--..----- --------.------,-.----.-.----..------..-.-------..- -----.--..------------------------------- -----'--.--'-------.-------.--------'-.-----------.--------.. ---- Type: Cement Casing Volume Excess %: 40.00 Meas. From: Time Circ Prior To Cementing: 3.00 Mud Circ Rate: 252 (gpm) Mud Circ Press: 560 (psi) Start Mix Gmt: 15:35 Start Slurry Displ: 15:36 Start Displ: 15:44 End Pumping: 16:50 End Pump Date: 1/15/2000 Top Plug: Y Bottom Plug: Y Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 38 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 6.50 (bbl/min) Y 440 (psi) 1,000 (psi) 2 (min) Y Returns: Full Total Mud Lost: Gmt Vol to Surf: (bbl) (bbl) Mud Data Ann Flow After: N Mixing Method: Density Meas By: Densometer PVIYP: 6 (cp)/14 (lb/100ft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 5 (lb/100ft2) Bottom Hole Static Temperature: CF) Density: 9.6 (ppg) Volume: 324.00 (bbl) Description: Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: CF) Temperature: CF) Density: 8.60 (ppg) Water Vol: 20.0 (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Stage No: 1 Slurry No: 1 of3 -- - - - - - - - - - - - - - -----------------.._- -----.u_-----. ----.---'---------------------'-'--"----------------------..-----------------------------.--..---.---...--..-----------...-----. --.-.------ - --- .--- Slurry Data Fluid Type: Arco wash Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp CF) CF) Pressure (psi) (psi) Printed: 1/30/2002 1 :08:56 PM ( ( PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-26 Common Well Name: CD2-26 Event Name: ROT - DRILLING Report #: Start: 2 1/2/2002 Stage No: 1 Slurry No: 2 of3 Page 2 of 2 Spud Date: 1/3/2002 Report Date: 1/17/2002 End: 1/20/2002 -- ---- ------ - ---.- - -.-. -- -- - --- -- -- - .--.-- -- --- ---- --. -- --- ---. -. - --.- -- - -- .-- - -- -- - -- --- ---- ------.- - - -- - -_.- - -.---- - --- ------ --- - - -------- ---- ---- -..- -- - ---- -- - . Slurry Data Fluid Type: Spacer Slurry Interval: (ft) Water Source: To: (ft) Description: ARCO Spacer Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: CF) Temperature: CF) Temperature: CF) Time Compressive Strength 1 : Compressive Strength 2: (OF) Stage No: 1< Slurry No: 3 of 3 Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) CF) Pressure (psi) (psi) - - - - - --. --'--'-"----.'----'-'.-.--.--.---------..--.------.-.-.------.------------- ---- -, _0-_-'----'-'------'------'----------,------,--,--,- ----.-.----.---------------.-.----.--------.-,--------- ---._.___0.__._.--------------------- - ----..._- --'-.------- - Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 8,619.00 (ft)To: 7,674.00 (ft) Cmt Vol: 33.0 (bbl) Water Source: lake Slurry Vol:162 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: CF) Temperature: CF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: (OF) Casing Test Shoe Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Log/Su rveyEvaluation Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (ft) Temp CF) CF) Pressure (psi) (psi) Liner-Top Test Tool: Tool: Printed: 1/30/2002 1 :08:56 PM ( ( Page 1 of 2 Phillips Alaska, Inc. Daily Drilling Report JOB NUMBER EVENT CODE 24 HRS PROG TMD TVD DFS REPT NO. DA TE CD2-26 ODR 8,629.0 7,186.0 13.00 14 1/15/2002 SUPERVISOR RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD DAILY TANG CUM. TANG -.-- Dave Burley__- ---. doyon_"L@~p~Q.,fQ~ 1 ~_._------ ._-_.__....6!~---- 11,292.0 _~QL -- ---~_Q..___n_- CURRENT STATUS ¡ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INTANG WI MUD ----_~_~p'_and cut drillingJi..ne @ 2275'., -------- -_._._-_J).OQ...._._- ___0.00 ---.- m 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Run & Gmt 7" - I~~Lê.9£É_J-Io1JJ..§.1ßJ:. BHA - Rlr---' -. ..___._.1/15/200:?___--. ._-_____?49,036 2, 151 ,.22_4--.__,_-..--- LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE AUTH. 16.04 998D13 ---.-------.--------------- ---- 1------- _1--- ------------- -----.---------- --- --- LAST SURVEY: DATE TMD INC AZIM LAST CASING NEXT CASING LAST BOP PRES TEST __1114/2002 ___.J!ß53. 9L____.§.~.6_~Q.__- ___li~§50 -- -~,-~~(!DL@--___?J.388.:.Qjf!L~:9.QQ.(i!!L@___..§,6 t~. 0 Jf!L- ._--__1L1.§/2..9_9_~- .'-' - WELL NAME "---'-"--------"- - --"'--" -------.-------- -.'."-- -~~-~- --~~- ---------- ------- ---.--..--.---..------.-- 38 6/14 5/5 4.6/9.6 ECD MUD DATA DAILY COST FC/T.SOL OILIWA T %Sand/MBT Ph/pM 11 I 117.5 8.51 0.00 Pf/Mf I CI CUM COST Ca H2S 0.00 LIME ES DENSITY(ppg) FV PV/YP 9.60 PP GELS WLlHTHP BITS BIT ¡RUN R11 3 SIZE MANUF. TYPE 12.250 HUGHES-CHR MX-C1 SERIAL NO. P58JF JETSORTFA 12/12/10/1811 DEPTH IN DATE IN I.O~D.L-B-G.O-R 271.0 1/7/2002 0-0------ ----'-..-----..'- ---..--..--., ---'----".'----."'-----'--'-----'---------'-'----.'-'-._-,,----... --,,-.-----------,.,-------..------,-.-,-,------------,.'--.-------'----- ----."'--'-----.-"-"--'.' -.. --,--,,-_.,------ - - '-' -'--'- - . - - - - - - - - - - - OPERATIONS SUMMARY -- -FROM-~-TÕ'.~'-liouRS-----cõDri-"TRÖ~~~~-"'---.SÙB----~'.-P'HASE'-"ë-~- -- --"'~ - --- - - ---~~--=='._""'DE~'RIP~?N--_"'__'----===~=='~.~.__.-~=~..,~.. 00:00 ,.,gO:~~_._-- 0.50 CAS~-------___~..~TY.____INI!3M.1 ._'i~~j_.E!_~_i~__~aJ_~_Y..._-~~~-~~~~~~~~-~_.~-~-~_..._- 00:30 03:30 3.00 CASE P RUNC INTRM1 Run 7", 2 6 #, L - 8 0 cas i n g to 2350'. ----.--..--..- -,--,--_. ---------- -'-----' ---'------------ ----------.-. .---,----------.-----.-.--.....------------..-..-----.-------.---.--- .---.-- '-'.' -_..,- 03:30 04:00 0.50 CASE P CIRC INTRM1 C i r can d con d mud. ------ ----.--.---,- -------.-.- ----- ----------.. .-----.--'--"-------- --------------.---.----------------...-..-...---......- --.. -- - 04:00 10:15 6.25 CASE P -- RUNC JNTRM1 Run cas i n g to 7520', no pro b I ems. ----- 10:1511:45 1.50 CASEP CIRC INTRM1 Stage pumps up to 4 bpm and condition mud, initi al mud wt. 9.6 in, 10.3 out, final 9.6 in 9.7 out a t 360 psi. RUNC INTRM1 Run cas i n g, m u h a n 9 era n d I and i n 9 j 0 i nt, I and e d casing with shoe @ 8619', FC @ 8533'. PULD INTRM1 LD fill up tool and install cement head. CIRC INTRM1 S tag e d p u m p sup to 6 b P man d con d it ion mud, fin al pressure 560 psi. PJSM. PUMP INTRM1 R U and t est c e men t I i n est 0 3 500 psi, P u m P e d 2 0 bbls of Arco wash, 50 bbls of 12.5 ppg spacer a ---- --.-----. --.-----.---. ---..,.--.-..-.-.-...- .-.-,--------------.----- ----.-----. .~9...._-~-~_.. b b Iso !_~~~ p p g -~-~_'!'_~~.:...._-----_._---_._----_.- 16:00 17:00 1.00 CEMENT DISP INTRM1 0 i S P I ace d C em en t wit h 20 b b Iso f F W, and 304 b b Is of 9.6 ppg mud. Bumped plugs to 1000 psi, flo ats held, CIP at 1650 hours. Reciprocated pipe u ntill last 15 bbls of displacement, full returns thr -------,- -.---- -------------- 0 u g- h 0 u t . ----- ----------,------,----- 17:0019:30 2.50 CASEP PTCH INTRM1 RD cement head, LD landing joint, pull wear bush '----_.------- ---------..-------- i nJL.....~~~- and t est pac k 0 !.!......t...~_5 0 Q...Q_....e.~J..:_,--_..._--~._._-- 19:30 23:30 4.00 WELCTL P BOPE INTRM1 Ins t a II t est p lug, t est pip e and b I i n d ram s, C h 0 k e , kill, manifold and surface safety valves to 2501 5000 psi. Tested annular preventor to 250/3500 p si. Pull test plug and install wear bushing. AOGC C (Jeff Jones) waived witnessing tests. RURD INTRM1 H a n g S h 0 r t b a i Iso n top d r i ve, PUr un n i n 9 too Is f or 4" drill pipe. 11 :45 13:30 1.75 CASE P 13:30 14:00 14:00 15:30 0.50 1.50 CEMENT CEMENT 15:30 16:00 0.50 CEMENT 23:30 00:00 0.50 CASE P Printed: 1/30/2002 1 :14:58 PM ( (' - ..... ,- "- ~ 1HILLlP::Þ l' l" ~tftj) ~ Page 2 of 2 CD2-26 Phillips Alaska, Inc. Daily Drilling Report ¡JOB NUMBER I EVENT CODE 24 HRS PROG I TMD ITVD I ODR I 8,629.0 7,186.0 DFS I REPT NO. 13.00 I 14 DATE 1/15/2002 WELL NAME 24 HR SUMMARY: Run and cement 211 jts of 7" casing, landed at 8619'. Install and test packoff, RU and test BOPE. PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS -------.-.-.----.------------------.--.---.-.----.-- ---,,---.-----,-------------------------u,--"-,,----..--.-.-.- -..--------- --.-------------. ---------..--------------.----......-.-...- ,-",-----------.-.----"-,-"--,--,,,.-,,,,---.--..-"...-"--"------ -..--.---------.-------- ------------.-._----- - Philli~_____._---------- ------------------..------.- --------~--------- Sperry Sun ------ -----_._----_.._------_._~-- -----...-- - Doy~~__.._._---------------_._--_.._-----..._- -----.2"'-.. ------- DSR______------_._--------- --~- ----_u- Baker Inteq .--------...-.-----------------.---.-------- ----.-_!..._- ACI -.------ ----------.--.--.-----.--------------_5..... _'-On_.- MI Drilling Fluids 3 FMC 1 ------------_._-----~--------- --.-------- -----_..------------- -.---------.------.-.--- ---------- -------. -.- Dowell 2 Epoch 2 --------.------ ------------------- - .-. ------------ -- ------- ----- -.. _.~-_.._---- ------"-.""---,- - ---- -. -- --- ---------- -_.._---- ----,- .--..- ----.--'-"-'--'-- --.--- -'~--'~--- --- -- ----- ---.--.----..-. "-...-..-,-_._--,--_._- ...-..----------.- ---- -...-_.- --- ,-- -- - - -.--- - - - - - - MATERIALS I CONSUMPTION -,----- -------,-------,--...,-'--- ----~---------- ------.--'-" --O----~---'~ ---'-'------:- ---------- --"'-----""-"'-'------- ITEM UNITS USAGE ON HAND -- ITEM UNITS USAGE ON HAND -.-----------------.---.,----- ---.-----.-----------. -_..._-------------..----------- .-.-.--.--.-------.-.-.- -_._~---"--_._~----".- --.---.-------.- --------.-------.--.--- ------.--------..----.--.-....-------- Fuel gals 2,340 -31,680 Water, Potable bbls 115 -1,285 Water, Drilling bbls 384 -10,814 - - - SUPPORT CRAFT REMARKS TYPE NO. - REMARKS TYPE CD2-47 - NO; 548 CD2-26 Printed: 1/30/2002 1:14:58 PM CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-26 Date: 1/16/2002 Supervisor: D. Burley Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC X 7" 26# L-80 BTMC Casing Setting Depth: TOC 7,672' TMD 6,879' TVD 2,388' TMD 2,384' TVD Hole Depth: Mud Weight: 9.6 ppg 5,284' Length of Open Hole Section: EMW= Leak-off Press. 0.052 x TVD = 727 psi 0.052 x 2,384' + Mud Weight + 9.6 ppg EMW for open hole section = 15.5 ppg Used cement unit Ri used Pump output = bbls pumped Fluid Pumped = 9J) bbls Fluid Bled Back = 0.0 bbls yes #2 900 psi --------- --- -----______n___n_- ----------. -- --------- ----------~ ---------------'---------'---.----------1----.-----------_____.n__- w ~ 500 psi (/) (/) ~ 400 psi a. 800 psi-------- ---'--'------- ----------------- 700 psi --..-- 600 psi --------- 300 psi ~ LEAK-OFF TEST -D-CASING TEST HW"¡"'M LOT SHUT IN TIME -.-CASING TEST SHUT IN TIME -+-TIME LINE 200 psi ------------ .--- ------ .---.---------..-. ---- -------.----------.---- --..-.-.-----..-- -_._------ ------- ---.-----..--- 100 psi ------.----- .-. ------- ---.--------- ---------'------. ------.---- ------- - ----- a psi. 0 10 BARRELS 12 14 16 18 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds MINUTES MINUTES FOR FOR lOT BBlS PRESSURE CSG TEST STROKES PRESSURE [~~~ ~~ ~ ~ ~ ~~~~~I~~~~~ ~~~ ~ ~~~~~ [~~I Ë ~ ~~~~] C~~~ ~ ~ ~~ ~ ~ ~~~~I~I~! ~~~~~I ~~~~q~p'~( ~ ~~~ I \ : 0.5 : 5 psi: I : : : [---------------+---------------t------------;-----tl---------------+--------------+----------------t : : 1.0: 10psl:: : : I .----------------'----------------.----------------""---------------....--------------....----------------~ I ! 1.5! 30 psi II ! I ! .---------------..,..---------------,.----------------...---------------..,...--------------..,...----------------.. ¡ 12.0! 66 psi Ii ¡ ¡ I r----------------.----------------r-----------------rr---------------T--------------T----------------~ : : 2.5 : 141psi:: : : : [---------------+---------------t-------------.----tl---------------+--------------+----------------t ~__m______m__~___--~:~------~---~~-~_P..~-~-1b--~--------------+_____m______+----------------~ t---------------+-----~~~-----+--~~-¡-~~f-)ji~--_m______---+--------------+----------------1 ¡'----------------r-----4~5------t---52-Õ---šf~'\t---------------t--------------t----------------i I,'---------------t, ------5--.0-------t, ----6-1--1--P..P--s-'I-../iC' -!,'(--------------t, --------------t, ----------------1, ._---------------'---------------_._-------------~ "l) l --------------....--------------....---------- ------~ t---------------+-----~~~-----+--~i-~-~~:--)t~_____m_--t--------------t----------------t !:~~~~~~~~~~~~~~~t~~~~~~~~~~~~t~~~~Ip..~~~~1~?.I~~~~~~~~t~~~~~~~~~~~~~t~~~~~~~~~~~~~~~j L_m - - - -- - --- __L____!..: ~- -- - -- L - ~?_~- P.. ~L =\.. "'L~,_þ"- -- - - - - --1..----- ---- - - - -1.. -- ----- - - - - - - -..l t---------------+-----~~~-----+--~~-~-~~:--j\tf-----------t--------------t-------______mt ¡'----------------r-----8~5------t---6r6-pŠr~'!"O-------------t--------------t----------------i ¡'---------------t-----9~Õ------t---62Tpšr~~--------------t--------------t----------------1 .----------------'----------------.----------------""---------------....--------------....----------------~ , I , , , , I I , , , , , , I , , , , , , , , , .------- -- - ----- -..----- - -- -- -- -- -,. - -------- -- - - - --.. I , , , I , , , ~---------------+---------------~----------------4 , , , , , , , , :'---------------+---------------t-----------------t , , , , , , , ,,---------------.................................~................................. , , , I , , , I , , , , LEAK-OFF DATA 20 ! SHUT IN TIME I SHUT IN PRESSURE r----------------,.---------------r----------------"'\' : 0.0 min : : 621 psi: ,,---------------+---------------t-----------------t I 1.0 mín : : 586 psi: "----------------'----------------.----------------'" I 2.0 mín I I 525 psi! r--3--õ-ñiTñ--r--------------r--¡ffõ--p-šr-l " , , , r----------------"---------------r-----------------r : 4.0 rnin : : 455 psi: }-----------,----+---------------t-------------.----I : 5.0 mln : : 445 pSI: "----------------'----------------~----------------'" I 6.0 mín I ! 435 psi I ,,---------------..,..---------------,.----------------.. I 7.0 rnín ! ! 424 psi I ,'----- - - -- - - - -- - -.- - ------ - - -- - -- -r ------- - - - -- --- --r : 8.0 min : : 414 psi: :'-----------,----+---------------t-------------.----I : 9.0 mill : : 409 pSI: '----------------'----------------.----------------... ! 10.0 mín I I 404 psi I .----------------~---------------þ----------------~ .PHlllIPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY CASING TEST DATA ( I SHUT IN TIME I SHUT IN PRESSURE ,.- ---- ---- ------ T ------ -- - - - -- -..... - - - -- ---- - - - -- - - ~ : 0.0 rnin I : 0 psi I :._---------~----+--------------+----------------t : 1.0 111m : : I ¡'---2-.0rriJri--t--------------t----------------1 , , , , ,'---------------..,...--------------..,..----------------.. I ~3.0 mín I ! ! ,.- - --- -- - - -- - -- - T ------- --- -- - -T - -- ----- -- - - - ---~ : 4.0 min : : : :.- --¡:.- - -- - - ~ ---- + ------ - --- - -- - + - -- ----- -- - - -- - - t : ,).0 rnln : : I .---------------....--------------....----------------~ ! 6.0 rnìn I I ! ,'---------------..,...--------------..,...----------------.. ! 7.0 rnin I I ! "-----------:----T--------------T----------------~ : 8.0 mln : : : :'-----------:----+--------------+----------------t : 9.0 mln : : I .---------------.....--------------....----------------~ I 10.0 min ! I ! ,.---------------..,...--------------..,..----------------.. : 15.0 rnin : : : ~---------------+--------------+----------------4 : 20.0 min : : : :'--;:i'::------~---+------------- -+----------- ___nut : 2,).0 mln : : : ,,---------------....-------------_...._---------------~ I 30.0 min I I ! .'---------------......--------------......----------------~ ( NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ( <: ¡C';'~I~d by--hm:c';.., - . F~;: ïi j~i;;;~~r; - : Do.. .,ollod : IJ-F..-20D2 , p,o. ..t.,..c. i, \Awe cO-" 2J9'>- , Coo,.'.al.. °'° ¡. '.0' ,.10'...0 "a' 126. . ¡Tn.. V."I.o' D..'h, 010 ..1.,.... ... (Dayo. , B).! , ~S . "1ì!.~¿ i........._..._..._.........._~.~.~,~L..._..__..._..__...._.............._.........j ........-.............-....-.-.....-......--........-...............-....--..-...--......................-.........-.........._.............................-.....-....-_............._..............-.. t}~..~..~...~_.~...~..,P.. -~......_.._..~_. !...~...~..~...~...~,.... _..,.._~..~~...~....~..... Structure: CD#2 Well: 26 Field: Alpine Field Location: North Slope. Alaska, ..........-......--.-.-.----....-.....-..-...-......................-.-.---....---......................................................................,-..........-.......-...........................- Scale 1 inch ~ 400 It East (feet) -> 'OliO '000 ,""O OlIO 2'00 'OlIO ..00 , --'--'-- -~-'--'-'--'._' --'- -.'--'--"-.- ,- . -'-.-'- -- '----'- ., - '- '-- '--'--'---'-~--~- ~-'---'---'--' -~ -~-'---'----'-~~-'--'--'-'--'-_."--'--'-- '---'---,-,--'-, --'--'--'--'-- 6'00 6000 "011 "'10 2000 J2DO J6o11 '000 ",," 'ouo 20110 '0'10 1200 aUo 'DO '00 ..110 20110 ""U 4400 ,'ODD I:EI \. \, \ \ \ \ , \ \ \ \ \. \. l~ '\ \[i!J , .. \ .. \\ 1\ ./ \ \ \ \ \ , 02;-21/'::1:1"" 2>-S.,,-01 "~.:'/2'." t~~ .000 "00 hOoo . '000 ~200 'Hon ..DD - 'DOD . J6o0 J20D 2800 . 2400 2000 'UDo ,.00 . 800 ^ I z 0 .., :;: 400 ....... .... I'D I'D .:;. 40<1 800 . 1200 '800 2000 2400 2600 J.oo . JOOO 4000 ..00 VI 0 0 ii <800 5' 0 ~- 6200 '" 0 0 'BOO = <ii' - ""', 728," S, "",," C ~ "~-'e;""J',,~,,. '-,-" '\ .....-......, "-'-'-""~-~ """""""GÐ 000 '- " -. ~ . , , - -- : -.:$;""" '000 "'\ ">4',,:,,1., , ' " "" , \- "", 1100 "\ "~":'~ . 1200 , \ _\ .'\ , , "'\' ~~ 1000 c-- ( ¡ Cr.."'" by "mic".., For: V Johnsoo 1 ! 0.,. pion.. : I 3-r.b" )00) i Plot R,f",.c. II MWD <0-1 '238'), C..,.;n.,c, 0" in f.e' 'cf...nc. .10' '2G. ; iT,uc V,,'lco' D,plhs 0" ,elerence ~Ke (D.yon 19),! j ~ : :-~.J~¡~~}M-g-D~2-_~_I__~_~_~-~I~~2J~-~_:1 Field: Alpine Field Locatian Narth Slope, Alaska¡ {" PHllUP~ , ¡=:;':':,.~"'.......:i:.\ ;~ ""~ " ._, \;:; :~:,' :; ~~_: .;;, ~-; , . ., "" 'NI~'! ,--",. Scale 1 inch ~ loa II East (feet) -> 1200 700 100 000 000 'JOO "00 1000 1100 '200 600 )00 BOO 200 JOO .00 GOO SOD '00 JOO 200 100 liDO 1000 000 BOO "<&;-'--'---'-'-'_1- '-,-~"-_.L- ._'--'--~:.. -, -,. -- '----'--' -7ÈJ -I.-' -'--'--a-L...-.I-L......I_L__' - -'--1.- 'L.."'L.._L_@_L......I , , , ~ CQ , , , \ \\\~ ,- / \\ / \\ / \. ,/~ ;, >/0' '.00", Q!7. \ /' ' ' """"'".,....... ' ). ",:'/ .,...."""~.,' '>/B C...;, "f-.... '0 >1' c..,., .Á>.' ", 'I' C..I'D" '.t, ¡¡::;" ,;;0. .;).' . "I" "n"'D . ",-.....»-,---..."", " '.'..', ~ ,,/::.::~:;C'///' æ..".."t; '~i'~ r....,o ..><', '~;'~/:""""'D ,.'...,.. , """- "'>"~:."""""".,,:.,..,:~..4~~1~"""', ""_'""~""-"_""'--"""-""",---""-"",..:.:",,,,,<,~ ~,,'" "..- 1 3 2 0 f t ~Ïi'~/" c.".o1Ç-'-:-':':- 0 O/R c.. ,t: ," "I", .I.:.~ "-:';'/~';;">;,:},.';,,,:. '., "..",,:"'~,'¿'~":->" """"'" -~-. ,..., ""'.'O/BC.,I., "",- j.¡.",.I'I'~'~~" . . "è"""", ...,."1" ,-" ,',-,,'11' ,.,~., """"'.. . :"'-""'" .' ;"~/o In''.Æ..:<¡ ow..- r'l' 't ~""" ""'" ...""....... " ",-:::.:;;:~::::~"';>/ " ,,:. .1"':' ~\~~;~:~'~'~:.""".."<~"""'B " ;~~;;/B 'eo,I'" / I. \\ " ~",:~~,...".. \'" '. ".~:~.", : , ' . , . , \ ':c~"'b",(~ co"" """ ",.,'", . '\ v'" ... '~"">/O c",~, /, ""'\ ' .,.".,. ,......., ", , ,.~,>/";;;;;~ , . ,/1' ~ "~/. C..I., <.< . """"""":"""""""""" '\\, , " ,..~ß'" --¡ , J..~ 0 'I' ...,., \" """'" .~.....,.".. ,.,,/,,/ ./ " "\"" """"'" ".', ,." . ~,~' . C.,I., ,! .~, 'O/R C.'I., """ ~~:;>' ,,' ' .' './ \~ ',~/' ...In" cf1" "". JJ.¡. "/8 ~.'I'~', "\ , ' v "/B eo.",~ / .' '\ ", (§)' / \ /' i /' ~. ClJ. i'~ 0 01' eo"", - <ID "10 enoln, ~ \ \ \ \ \\ \ \~ ¡J :¡ ,I í I I . I @@ ~---- , v '>10 C"'" ~ ~~ 00 ~ ~ @% @ 'oDD ,GOO '700 , ~@-'-.-: 1600 \\ '500 , , :\\ 1400 ~"'IOO , ,/ ;' / / ncc 1100 .~ 1000 . 900 ROO 100 f;$J 000 ,0 2B . 000 .00 JOO 200 ^ I z 0 4- :T 100 0 ,... ..... () () ~ 100 200 JOD .00 ,co .. oco )00 ROO VI " c ¡;¡ 1JCO ;õ' n :r . "CO 0 0 .- SURFACE CASING SHOE SEPARATION FROM CD2-26 CD2-26 x y Surface Casing Shoe ASP 4 Coordinates: 371798.52 5974554.55 Distance Surface Surface csg. Cement Casing No. of Ann. Vol. from Object csg. Shoe X Shoe Y Wells Permit # Permit Date Report Tally LOT Source well **** Start Date End Date well* Coord. Coord. CD2-35** ---- ---- x x 1 ----- ---- ---- 743 372312.31 5974017.68 CD2-24, CD2-33, CD2-42 301-140 6/1/2001 x x 2 CD2-33A, CD2-15 33992 6/1/2001 10/10/2001 898 371098.46 5973992.48 CD2-33 (+A&8), CD2- CD2-24 301-186 7/13/2001 x x 2 39, CD2-14, CD2-15 33999 7/16/2001 10/9/2001 1180 370630.11 5974721.81 CD2-39 301-281 10/9/2001 x x 2 CD2-15, CD2-47 27879 10/10/2001 11/12/2001 1074 372350.61 5973633.17 CD2-14 301-288 10/9/2001 x x 2 CD2-45, CD2-47 14835 11/13/2001 12/17i2001 573 372202.4 7 5974960.87 CD2-15 301-308 11/6/2001 x x 2 NA 1058 370832.00 5974984.02 CD2-45 301-345 12/13/2001 x x 2 CD249 18721 1/20/2002 2/12/2002 1194 372765.13 5973853.74 CD2-34 x x 2 NA 115 371803.06 5974439.79 CD2-49 x x 2 NA 733 371252.38 5974065.93 ~ * Distance in feet, between surface casing shoes, in the X-Y plane ** CD2-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted for annuluar disposal. ***CD2-33 8 was a delineation well with a window milled out of 9-518" casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. **** As of 12-Feb-02 ,.,-~ Re: CD2-26 cement evaluation ~ . ' ,~ ( ~\-~~I~ Subject: Re: CD2-26 cement evaluation Date: Man, 11 Feb 2002 12:50:35 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Clifford L Crabtree <ccrabtr@ppco.com> Cliff, What you relate in the message is encouraging. Impressive on how far you were able to get the logging tool to fall. Please plan on submitting a copy of the log at your earliest convenience. Based on the depths you noted, it is likely that your good to excellent cement bond is much greater in length given the volume you pumped. Based on your message, I do not see a problem with your forward plans. As noted, please forward a copy of the log as soon as you might be able. Good luck with the water flood initiation on CD-2. Please call with any questions. Tom Maunder, PE Sr. Petrol~um Engineer AOGCC Clifford L Crabtree wrote: > Tom > We obtained the first CD2 cement bond log over the weekend in CD2...26. The > results look good. > > We managed to get the tools to fall to 8265' MD (7077' SS) which is about > 76 degrees hole angle. The top of the hydrocarbon bearing interval or in > other words the top of the Alpine C is at 8380' MD (7103' 88, and about 79 > degrees hole angle). > > We logged up to the tubing tail which is at 8025' MD (7001' 88). The log > indicated 240' of interval had (quoting from the report) "Excellent Bond". > The packer is at 7912' MD or 6952' 58 which makes the packer 151' TVD above > the hydrocarbon. The casing shoe is at 8619' MD (7132' 88). This log > enables us to project there is at least 594' of good cement above the shoe. > > The volume of cement placed into the 7" PC x OH annulus with "full returns > throughout" was 29.8 bbls which, assuming an 8-5/8'1 OH, would fill > approximately 1200' above the casing shoe. > > Given the above, I believe we have met all the goals that were discussed as > we began drilling injectors at CD2: > > 1. Phillips is allowed to determine the placement of injection well packers > such that the angle at their tailpipe nipple ;s about 60°. > 2. The packer depth cannot be more than 200' tvd above the top of the > Alpine. > 3. Phillips shall pump sufficient cement to place cement a minimum of 500' >md > above the top of the Alpine or 1.5 times the distance from the top of the > Alpine to the proposed packer depth which ever is greater. Normal excess > volume factors shall be added to the calculated cement volume. > 4. Phillips may run the Cement Evaluation Log after running the completion, > however nothing in this rule precludes them from running the log prior to > running the completion. 10f2 2/11/02 12:50 PM Re: CD2-26 cement evaluation (' ( > 5. If analysis of the evaluation log does not give confidence that > sufficient > isolation has been achieved, PhHlips will need to demonstrate external > isolation using other methods or perform remedial operations to achieve > satisfactory isolation. > > Out plan is to bring CO2 injection and this well on as soon as we confirm > the bond integrity in injector CO2-49. > > Cliff Crabtree > Phillips Alaska Inc.- Alpine Subsurface Development > Office: (907) 265-6842; Cell: (907) 240-5357 > Emai/: ccrabtr@ppco.com; Fax:: (907) 265-1515 ~Tom Maunder <tom ma~nder@~in.state.ak.US> I Sr. Petroleum Engineer ~~ska Oil and Gas conse~ation Commission -- 2 of2 2/11/02 12:50 PM f ~~~1rŒ ffi)~ !A\~!A\~[K\!A\ ( ALAS KA. 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Vem Johnson Drilling Engineer Phillips Alaska, Inc. . PO Box lO0360 Anchorage AK 99510 Re: Colville River Unit CD2-26 Phillips Alaska, Inc. Pennit No: 201-232 Sur. Loc. 1825' FNL, 1532' FEL, Sec. 2, T11N, R4E, UM Btmhole Loc.1080' FSL, 2231' FWL, Sec. 1, T11N, R4E, UM Dear Mr. Johnson: Enclosed is the approved application for pennit to drill the above referenced well. The pennit 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 pennitting detenninations 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 CD2 must comply with 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 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 NIl test before operation, and of the BOPE test perfonned 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, Cæ~DuJut-. t?r Cammy Ó~chsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 14th day of December, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( RECEIVED 1\). ('3 STATE OF ALASKA NOV 2 7 2001 ALASKA OIL AND GAS CONSERVATION COMMISSION Cons com~ftft PERMIT TO DRILL AlaskaOil&r. IIIIHMA 20 AAC 25.005 nchoIage WGf\- 1'L/lD( D I JMW 'z1'Lf/D( , ~ 1a. Type of Work Drill X Redrill 1b Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry Deepen Service X Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10, Field and Pool Phillips Alaska, Inc. DF 52' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380075 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1825' FNL, 1532' FEL, Sec.2, T11 N, R4E, UM Colville River Unit Statewide At target (=7" casing point) 8. Well number Number 1846' FNL, 975' FWL, Sec. 1, T11 N, R4E, UM CD2-26 #59-52-180 At total depth 9. Approximate spud date Amount 1080' FSL, 2231' FWL, Sec. 1, T11N, R4E, UM 12/28/2001 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line CD2-24 ~ :3'?~ø- 11292' MD 1825' FNL T11N feet 19.7' at 400' MD Feet 7174' TVD feet R4E 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 90.6Q Maximum surface 2535 psig At total depth (TV D) 3230 at psig 7139' TVD.SS 18. Casing program SettinQ Depth size Specifications Top Bottom Quantity of cement Hole CasinQ WeiQht Grade CouplinQ LenQth MD TVD MD TVD (include staoe data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' 305 Sx AS 1 12.25" 9.625" 36# J-55 BTC 2356' 37' 37' 2393' 2389' 475 Sx Arcticsetlll L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 8586' 37' 37' 8623' 7191' 163 Sx Class G N/A 4.5" 12.6# L-80 IBT-M 7983' 32' 32' 8015' 7041' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20, Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed fl ~ ~{ ()[) Title DrillinQ Team Leader Date I tll,e. ( '.), / ,, '- Commission Use Only , Permit Number. 2,. :s 2..,. I API number 2b3q7 .. 6(:) I Approval date I~ 'r~"D ( See cover letter for 2...Þ,~ 50- I b "3 ... Other requirements Conditions of approval Samples required Yes @ Mud log re"q\Jired.. Yes é9 Hydrogen sulfide measures Yes (31 Directional survey required e No 4~?ri\ ." 't-[Ç¡f.' Required working pressure for BOPE 5M 10M 15M -r¿:,,<:,;f È;¡iG) PC 1 'It. S't¡ f~., " 2M 3M . ',.eo;. "'I' ,I . "~ lr~tA ¡'I,.'1.~ ~ 1:1'. , ".," '".' Other: ,,/\ '[ 'T ìÓ? ...t 16~:;'{"~' U' ,t.~~ (~> '°., Wç~' , ,"" J ~,~,~.~,"'II.,...... " \ 'i; Original Signed By by order of J~113l~J Approved by - Commissioner the commission Date Form 10-401 Rev. 7-24-89 I ORIGINAL gubmit'in triplicate . , , . ( ( CD2-26 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/411 Hole /9-5/8" Casin Interval Event Risk Level Conductor Broach Low Well Collision Low GMH~~~ ~w Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVO Lost Circulation Low Low 8-1/2" Hole /7" Casin Event Abnormal Pressure in Surface Formations >2000' TVO Lost circulation Interval Risk Level low Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low M iti ation Strate Monitor cellar continuousl durin interval. Close a roach olicies, ro sin Ie shots. Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Oiverter drills, increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries M iti ation Strate BOPE drills, Keep mud weight above 9.3 ppg. Check for flow during connections and if needed, increase mud wei ht. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheolo , lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted swee s. Well control drills, increased mud weight. No mapped faults occur within 700. of the planned wellbore. H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low M iti ation Strate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo , lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitorin , wei hted swee s. BOPE drills, Keep mud weight above 9.3 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL , , ,r I( ( Alpine: CD2-26 1. 2. 3. 4. 5. 6. 7. 8. 9. Procedure Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 inch surface casing. /" Install and test BOPE to 5000 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. øt IUD /Þ6!) .r "'. Drill 8 W' ho Ie to the interm ed late casing point in the Alpine Rese rvoi r. t1 ¡:: Iii": i!:5 /A l/ r 7}' Run and cement 7 inch casing as per program. Top of cement +/-700 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" x r casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze pr9tect casing annulus and casing. ../' BOPE test to 5000 psi. 10. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. mAJD ht$~.' Drill 6-1/8" horizontal section to well TD. ~..e/æEb/~'{i°/r~ Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). 11. 12. 16. Displace well to brine and pull out of hole. Run 4-1/2" 12.6 #, L-80 tubing with lower gas lift mandrel, DB nipple, and production packer. Land hanger. 17. 18. 19. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 min. Set BPV and secure well. Move rig off. 22. ORIGINAL , . {. ( Well Proximity Risks: Directional drilling / collision avoidance information as required by 2~CC 25.050 (b) is provided in following attachments. CD2-24 will be the closest well to CD2-26, 19.7' at 400' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 17.7' at 400' MD. Drillina Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpina Operations: Incidental fluids developed from drilling operations on well CD2-26 will be injected into a permitted annulus on CD2 pad. The CD2-26 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill a~e the top of the Alpine as per regulations. We request that CD2-26 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones q,pntaining significant hydrocarbons will be isolated prior to initiating annular pumping. There will be ncY'USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other form.Çltion 'Y.. Gir.. rkers in thts well.. A f II -J~ ../" . 11.J¡I?!O(. ðc. 00 ve.. rt....e- o¡/ v--JC¡. e-'f' \l' ¿At\ ¡t""(:q,,,,-- I ~(j " Surface casing will be set,..oclow the ba3c of-- tfle-.Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. v The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi ./ = 1 ,086 psi Pore Pressure Therefore Differential = 2998 - 1086 = 1912 psi. / The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1 ,717 psi 3,520 psi 2.992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi ./ 7,240 psi 6,154 psi /' ORIGINAL ¡( ( CD2-26 DRilLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 Y2" Section - 6 1 18" point - 12 %" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 1 0 - 25 10-15 YP 20 - 60 1 5 - 25 25 - 30 Funnel Viscosity 1 00 - 200 Initial Gels 4-8 10-15 10 minute gels <18 12 - 20 API Filtrate NC -10 cc I 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 -9.0 9.0 -10.0 9.0-9.5 KCL 6 % Surface Hole: A standard high vi~sity fresh water I gel spud mud is recommended for the surface interval. Keep flowline viscosity at :t 200 sec/qt while drilling and running ~ing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel I polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is pote~for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: /"",' The horizontal production interval will be drilled with aM-I Flo-Pro drill-in fluid. The base fluid ~l consist of 6% KCI, witlJ730PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. OR""'" ", 1 ""'A L n/l1iN i ,( ( Colville River Field CD2-26 Injection Well Completion Plan ¡¡m ;: ¡:~ ::::: ~¡H H~¡¡¡ mm ::;::; ¡¡1m .:.:.; ¡¡n : ¡: ¡: ~ HH 11,111 ;:::; ¡U¡ .;.:. ¡¡ j1 ~ ~¡W ::::: :;::; ::::: 4-1/2" Cameo DB Nipple (3.812" ID) :z: Surface Casing @ 2393' MD 1 2389' TVD cemented to surface 16" Conductor to 114' Updated 11/20/01 A 1 Injection Valve (2.125"ID) - to be installed later Packer Fluid mix: 9.6 PPg KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet lube pipe dope Tubing Supended with diesel TOG @ +/- 7670' MD (+689' MD above top z,. Alpine C) "~¡Dltjj¡i¡¡l¡i~j¡¡¡¡jj;lli:j!ili¡m¡mm:H¡¡m:Hb' Top Alpine Cat 8359' MD 1 7154' TVD Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Cameo DB Nipple 2004' 2000' 4-1/2", 12.6#/ft, IBT-Mod Tubing Cameo KBG-2 GLM (3.909" ID) 7785' 6930' 4-1/2" tubing joint (2) R3 S3 Packer (c/w handling pups) 7900' 6989' 4-1/2" tubing joint (2) R3 HES "XN" (3.725" ID) - 64.4° 8002' 7035' 4-1/2" 1 0' pup joint WEG - 64.9° 8015' 7041' GameD KBG-2 GLM (3.909" ID) & 1" dummy valve ':[1111>;", Baker 83 Packer at +1- 7900' (<200' TVD above top Alpine) ":::¡ff¡nDTn¡¡1WmmFFFmw" ---- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- -----, Well TD at ! 11292' MD I ! I 7174' TVD ¡ I I -----------------------------------------------------------------------_! 7" 26 ppf L-80 BTC Mod Production Casing @ 8623' MD 1 7191' TVD @ 87° ORIGINAL (' ( Colville River Field CD2-26 Injection Well Completion Plan Formation Isolation Contingency Options mm iiliii mm ~ ~ ¡ n ~ , ' ',' IIIIII 111111 :-:'::o~::~:r:: ~~:~Ie (3.812" 10) mm @ 2000' TVO = 2004' MO ,illi 9-5/8' 36 ppf J-55 BTG "::j Surface Casing @ 2393' MO / 2389' TVO cemented to surface Updated 11/20/01 : U!S 4-1/2" 12.6 ppf L-80 IBT Mod. tubing run with Jet Lube Run'n'Seal pipe dope (A) BonzaLECP Assem~ - Baker ZXP Packer (4.75" 10) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBO) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBO) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-1 0 ECP (anchor) - Muleshoe / Entry Guide (C) Open ~dQe PluQ Assem~ - Baker Payzone ECP (cement inflated) -XC -Float Collar - 4-1/2" Float Shoe Gamco KBG-2 GLM (3.909" ID) & 1" dummy installed, set 2 joints above Packer ,~...... :::~m:::,:>.. Baker 83 Packer set at +1- 7900' "::::¡¡nn11'~;~"., Well TO at 11292' MD I 7174' TVD TOG @ +1- 7670' MD (+689' MD above top Alpine D) ----~-------~--------:' ------ - ~ ,¡jjjj.Hmllllk:.. @ @ : ~q~[¡jQQ¡, 'ŒB::::::!:;~i~;;;~~~o 6 R ï G j fiAt (. ( CD2-26 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (Ibs. I (psi) (psi) MDfTVD(ft) gal} 16 114/114 10.9 52 53 9518 2393 I 2389 14.5 1081 1562 7" 8731 /7191 16.0 3254 2535 N/A 11292 I 7174 16.0 3254 N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point 1. ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1081 - (0.1 x 2389') = 842 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D = [(14.5 x 0.052) - 0.1] x 2389 = 1562 psi OR ASP = FPP - (0.1 x D) = 3254 - (0.1 x 7191') = 2535 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3254 - (0.1 x 7191') = 2535 psi ORIGINAL (' { M¡>ine. CD2-26 Well Cementing Requirements 95/8" Surface Casing run to 2393 MD /2389' TVD. Cement from 2393' MD to 18931 (500' of fill) with Class G + Adds @ 15.8 PPG, and from 18931 to surface with Arctic Set Lite 3. Assume 3000/0 excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: System: Tail slurry: System: (1893'-1556') X 0.3132 fe/ft X 1.5 (50% excess) = 158.3 fe below permafrost 1556' X 0.3132 felft X 4 (300% excess) = 1949.4 fe above permafrost Total volume = 158.3 + 1949.4 = 2107.7 ft3 => 475 Sx @ 4.44 fe/sk 475 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 fe/sk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% SO01 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 felft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 ft31ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 fe/sk 230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % SO01 accelerator @ 15.8 PPG yielding 1.17 fe/sk 7" Intermediate Casing run to 8623 MD /7191' TVD Cement from 8623' MO to +/- 7670' MO (cement 688' above packer depth) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (8623' - 7670') X 0.1268 fe/ft X 1.4 (40% excess) = 169.2 fe annular volume 80' X 0.2148 felft = 17.2 fe shoe joint volume Total volume = 169.2 + 17.2 = 186.4 fe => 163 Sx @ 1.15 fe/sk 163 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk 1 By Weight Of mix Water, all other additives are BWOCement ORIGINAL ,'" ........... ...........-.--...................-....-.-.-..---..--.-.--.-..-., ¡ CreatBd by bm¡chos' FOR: V Johnson ¡ ¡ Dale p!otloni : 2,-1\:--2001 1 1 Põot Rel"",nce is C2-26 Ven¡onl7. ~ ~ Coordinates are ;n ~e"'" reñorence s!at 126. ¡ ;True Ve"'¡col Deptils are reference j;I;(B (Daya.. 19).¡ ~---_.._-_._--_.._._.__._..._--_. .-...... ."""""" .. .-.......----..-...--.--..----. i ~ I..~..~..~l.~.~.~~..'-~..~.~-~..~..~..,...._...!.~.? o.i I Structure: CD#2 Well: 26 : ¡ FIeld: Alpine FIeld Location: North Slope. Alaska: .--.- ...._m...._.._........"""--'" .-....--- ...-....-..----.. -- -- - INJ EO ,.__.._-----_._----------~ .-.....-.--..-.-.....-.-..-...-.-.-.---.---.-.----.--.--....-.--...-...-..-----.-... .--..------.----------------..-...-...............-.. .--.-.------.-.-----...-...-.-.....-.... ..........-....-...-.-..--....-....-...... -.......... . ..... . ... . .. ... , ---- PROFILE COViMFNT DATA ---- ! ¡----- Point ----- MD inc OJ,. TV] North East !KOP 500.00 0.00 77.70 500.00 0.00 0.00 ~EOC 850.00 7.00 77.70 849.13 4.55 20.86 ¡Begin Drop 1200.00 7.00 77. 70 ~ '196.52 13.64 62.54 !EOC 1550.00 0.00 77.70 1545.65 18.18 83.40 !Base Permafrost 1556.35 0.00 71.78 í 552.00 18.18 83.40 ; iC-40 2226.35 0.00 71.78 2222.00 18.18 83.40 '.eR "eý~Ç(~ ¡9 5/8 Casing 2393.~5 0.00 71.78 2389.00* 18.18 83.40 ., -.-----fJ'II> iC-30 2403.3'5 0.00 71.78 2399.00" 18.18 83.40 ~A.l'U1o fCt(~t !C-20 2756.35 0.00 71.78 2752.00 18.18 83.40 ttf~t ¡K-3 3852.35 0.00 71.78 3848.00 18. í 8 83.40 !K-2 4072.35 0.00 71.78 4068.00 18.18 83.40 D<OP 4650.00 0.00 71.78 4645.65 18.18 83.40 !Begin 6/100 Bid 5050.00 8.00 71.78 5044.35 26.90 ; 09.88 ;Albio!".-97 5661.46 44.69 71.78 5583.00 1 Î 0.32 363.24 I ¡EOC 5749.19 49.95 71.78 5642.45 í 30.48 424.47 ¡A¡bian-96 6409.00 49.95 71.78 6067.00 288.43 904.22 ¡Begin Fnl Bld/Trn 7281.82 49.95 7î.78 6628.61 497.38 í 538.85 !HRZ 7535.36 52.66 91.00 6788.00 526.14 ¡ 732.94 !K-í 7847.96 59.80 111.93 6963.00 473.05 1984.75 ¡LCU 8042.02 65.73 123.21 7052.00 393.01 2137.07 ;Mi!L:veach A 8224.87 72.02 132.86 7118.00 287.90 2270.96 ¡A!pine D 8286.92 74.26 135.96 7136.00 246.3Lt 2313.37 ¡A!pine C 8359.28 76.93 139.50 7í 54.00 ¡ 94.49 2360.48 ¡Target - Casing pt 8623.35 87.00 Î 51.87 7; 91.00 -20.96 2507. ¡ 2 ~t:OC 8984.26 90.61 -¡51.87 7198.53 -339.13 2677.2í ¡IQ.......~.....ç.s.g. ..P.t. .... .... ...... l1Z9..2"Jl5_...._........_............~.o...6j._......._._-_.._...1.5...1.. .87 ... ..........71...7..1.!Q.O.. .~..2.~..7..1-..!2.2 ~.765.18 C ::J:J - - c-) - ~ ........ V. Sect 0.00 20.82 62.42 83.25 83.25 83.25 83.25 83.25 83.25 83.25 83.25 83.25 109.65 362.30 L23.36 90í.78 153(-.64- 1 728.48 1980.72 2133.71 2268.47 2311.22 2358.77 2507.21 2679.96 3784.91 .-. , Jeg/1 00 0.00 2.00 0.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 6.00 6.00 0.00 0.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 ~ .00 0.00 ..-., C.aalad Dr ami.haa. For: V Johnson Dal. .,aU.d : 2:-av-200~ Pal Ralare... ;. C~2-2S Vare;a."'. CaD,a;"al.. are ;" '...1 ..r...." sial ,'S. -;,.. Vorl;..1 :Iopt"" a.. ..!...nca ~(9 (~"'D' '9). !.!:J;:"U 1lA1I:i1! _1115 !"'I'I:'.' 0 250 L--._-L..--..J-_.--L..__I___.J.,__l,_.- ,1.- _.J- -. J- ...J...__J_-._.J. _.L.._..J.,.....L..._,.L.... ..,I--_..I_..L., __I-__I--__..L u- J__.L...._..J..._-L.- --..I..___L- _..L--.J... --I-, - ,1-- ..L .. I-SURF^èE-LoëAi:¡õ~"1 ' 825' FNL., , 532' FEL SE.C.2,f"N,R4E" ------------ -- 70 À.~ ,oc 77 . Alblon'.-97 ;...q & ~~~,..p1!.~~' -tof't-"g~~"'(1 ~ó' ~ ~ ð. (I". C! "00 I'o~ -'110~' & ~ci~ ~ ( ( ,., " . 1'. " . ," f" ìI I I "'1 ',,", S ,;", ... ~ ... .Jl ~..... 'v ... ..1. A" ~ , ~ " ~~as~;{a, ,.. :; "'1"" I'~ .... .....:.. "-' a Structure: CDg2 Field: Alpine Field Well: 26 Location: North Slope, Alaska East (feet) -> !:IOO 'I!l0 '250 1000 1!:100 1'150 '"000 ""!l0 2500 2'150 I..CU MX~~~~cß A Klpine C JOOO J250 "-,,,,-~ r~I-"'I! "I"""'" ::. .. ,. .' """, r 'il """'-' '" ~ ¡ \ \. - i -..-..,,:---- J500 .3;'50 G----'-------~- lARGcr LOCATION: , 846' FNL, 975' FWI. SEC. " T' , N, R4f. ',Torget - Casing Pi ~~ ", 90.48 AZIMUTH 2507' (TO TARGET) naPlono or Proposal... ',F.OC ~ .~~ l,,;! TRUE '~ 'ú' ',~ ....~ ~ "7 ',~ '. TO _n Csg Pi ... " :zIJ 11) LOCATION: ~ '080' FSL, 2,,3" FWL SEC. " r" N, R4E ---------.----- <1000 - 'i'50 . 500 - 250 0 .250 500 (J) 0 - 'i'50 C - :J'" ,-.... - 1000 -h CD CD - '-"" . 1250 I V 1500 - 1 "50 . 2000 2250 2500 - 2"50 ORIGINAL ( ( 'r' ... ." '1 . ;..JI:",,""',I;.,,"Y'S .i.. ~..~'.......~..;¡'..;L V ~.. A~~as~~a.. , ,. ,: I, 1'"). ~.. ~'-'. Crea'... II' D"'¡C~QD: For: V Johnson ~c:. .'an... : ~:-~av..~co~ PIal Ra!...n.. :. CJ~..2S Ve"'¡Dnl7. Structure: CDH2 Field: Alpine Field Well: 26 Location: North Slope. Alaska CDard;.atc. arc ;" !ae. '.'.r.".. .ID. "S. rr... Vort;..: ~.D:~. Doe rc!.ra"c. RICa (Dor.. '.). .......... 2400 - Q) Q) ~ :'.BOO ...t: - 0- Q) 3:'.00 0 c u - 10... Q) > Q) :J 10... I- I V '100 - 800 . 1200 1600 :1000 3600 4000 4400, 2.00 4800 4.00 6.00 12.00 5200 18.00 24.00 30.00 .. 36.00 48.00 5600 6000 6'100 - 6800 - 7200 - nMFIJI ~!'I.'J.i~ :~.;.::<,¡ 0 . RKll LlevaUon: :>2' KOP 2.00 4.00 6.00 ~.OC DLS: ~.OO deg per 100 ft 90.4.0 AZIMUTH 2507' (TO TARGET) ...Plone of Proposal.... l3e.Qin Drop 6.0'0 4.00 2.00 DL S: 2.00 deg per 100 rt I-".OC ßasc Permafrost C-40 ~ L 9 5/8 Casing C..JO C...20 K -":S K.-~ TANGENT ANGLE VEHTICAL KOP DLS: 2.00 dog per 100 ft Bogin 6/100 Bid TANGENT ANGLE 49.95 DEG DLS: 6.00 dog por 100 ft Albian-97 E.OC TARGET ANGLE 07 DEG B . F I Bld/T DLS: 6.00 deg per 100 ft 50.04 egm n rn f?"- 52.10 I-"~Z t- \(\~ "- 55.98 ,.' f'~ c.°r;; ^ f? 61 30 of.: -.) e°'Vc." c.r;;... . - "G .j.~..g.~e e ~ ,. 67'~~.46 ,..~ç'f.o<~Oc. '\~ .. ..--~---_._--_._.-.... ~ ---r- I 0 400 BOO 1200 1600 2000 2400 2800 3200 3600 '1000 Vertical Section (feet) -> Azimuth 90.48 with reference 0.00 N, 0.00 E from slot 1126 ~'"""'---"". ," "'I "\ rmU..Ir-3 t j ~ !1 . \i Ii . & \. .1 "--... -.F ...... ORIGINAL C ::J:J - - ~ - ~ r- -:; 66001 ~ J .......... I I 6800 -f I I 7000 ] 0 i 0 1 7200 ~ ~ 74001 i ; I 7600 i V ..r: -+- 0- m 0 0- -+- L. m > m :J L. I- ----------------------------.- .---.-.-.... -..._..-.-_.- ; C.....:ed by b:nicilae! FOR: V J ohnøon !)Cte p:Dtted : 2~-i\:av-2001 P:a: ;œ~erer.ce is c!)2-26 Vers!anl7. Caa."¡¡nales are in fee'. refere~c. slat 126. - ~True Vertical "ept.'!. are ...re....cc RKa (!Jayan i9).! ! - ..... - , ; IN"J'EO ; -.-.-----..........-.......-------.-..-----------..-J 50.04- 50.82 52.10 53.83 55.98 58.48 61.30 64.37 ,. 7,.13 78.46 !iRZ DLS: 6.00 deg per 100 ft .-.-------------.---.-..- ..-..... .------------------.--.... _.-. ,- .. ..- ....----______n___"" ¡Phillips Alaska, ¡n__...n...... .,... n_n'_____--____"'n"_" __n.._n__________n__'___"-""'--""---------~ , Structure: CDI2 Well: 26 ! Inc.! ; ! FIeld: Alpine Field Location: North Slope, Alaska! '--__n........ ..-------.-......- nn.. n n______-.............--..-------' 151.87 AZIMUTH 1201' (TO TARGET) ...Plene of Proposel... TARGET ANGLE 87 DEG TANGENT ANGLE 90.61 DEG <t- r:.'~~ úO 1\." ~-:-.o(o¡e """"II ~~ "!":J .- Csg I't -.-..... ...-... I I II "I'; 'III 1111"': II IIII "'l I II,---"""--r--~---I ,.. ~ cP f\) ú ..J.6 e LCU ~~~~~~,~e 0 800 1000 200 400 600 ~200 1800 2000 2400 2600 3000 2800 2200 1400 1600 Vertical Section (feet) -> Azimuth 151.87 with reference 0.00 N, 0.00 E from slot #26 3200 3400 3600 3800 '-000 ~200 ~I,OO 4600 (-- C'.o:ea '" ....¡cnee' For: V Johnson Oo.e Olol:eo : 2".--'001 I'lal Relo",nea ÕO CO'-2& Vor.la~'I. Caardi...:a. a'. :. !cc. r"'c'c,cc sial 12&. õru. V."'ic:al Oaal." ara 'ola...noa ~Kj CO..,..n ~!I). ;:r.¡.õiI )~~ 1:-'-1'):0 "PO" "' .,..... '!JI"~":11~"'"""'S .....J........ ....... J... Structure: CDff2 Field: Alpine Field ( A"' ... ,'... ... r fr- . ..ìaS..Ka, ¡r 'I"" , 'to .J~........~ . ,r-~ "" DUI: : IP~ ~" , ~ 1 S L;L. . .... B ij ;J !) :! '\ S s "'- .....- --.,.-- East (feet) -> 40 60 80 100 120 11\0 160 180 200 220 21\0 260 280 .l..-.I._I..._--!..--L__.J- .L-..,.J---!_I._..J._....J.....--1____1---!_L_-L.._-L--....L-1.-._.L-...J.__I-__, - 11\0 1\0 20 0 20 L......!...-._..J...__l~ I , , jOO@ GD ~ ",'1ð6'" 9..306 1'ì5'... 700 ~ """""'-""8300 @300 @) 300 8300 8~mo .' '00 Q'§J , 8300 ~ c.. , "00 . ~ UOQ . "00 '700 .' 5~0 m;'300 @' ..9 CiIJ. ......~OO 700 8 300 ~... """"'.-....-.e 300 (i}300 900.. . 500 ... . 83ÐCT . "lOO . '8300 ..'. 500 @ 30b .. 900 8300 8300 8300 @);SOO ... '30~JOO .tiI ,., 5°<ao ......1'608300 68i-'-~"" . 0'"' . ~300 -WOO t 700 . UOO' . ,. . .1100 (-:00 '300 . em .9~0/OO ~ 700 QID . , '00 6D . ,. . 700 . ø\5SJ . '900 . .900 1500 , , ;SOO .." "4900 -' ~9 .. ". -: ëóo ..., '00 900 , '00 .' . Well: 26 Location: North Slope. Alaska 1700 .. , ,~OO .. .. 5300 .. , 100 .. ,~OO . " 5100 ., ~ 300 . ~JOO . ~SOO IJD ~ . ,;/,O 100 '900 19 . "r$) 80 (jP 60 . 40 ^ I 20 Z 0 ..., - ::J" 0 ~ ...... CD CD - 20 ......... - 40 60 . 80 . 100 120 ORIGINAL ( (- ,~~ .,.,.. , .I 11"'\" ~ .1 " '"",, S ~~ .tI. .l .~ .. .... ,V ... ... A,. .... 'r. ""'I i "" ...aS~Ka , ,r I: 'V"\ C . I , ... .. ... .." , C...a:.a III a",'chae, For: V Johnson Well: 26 Structure: CDN2 Field: Alpine Field Location: North Slope. Alaska Ja:e alalled: 71.,Nav ,70C1 P,al Relerenee ÕI :02..2& va'.:"""7. C....ru:na:al are Õ. leal rel.,e"e Iial 12&. 'r... V.":cal Je.I." .... ,.'.,."e. A~9 (Joyo" ~a. ~";<;;¡ Ð..~ltn¡o 11U8t~ ::I:'I':'::) East ( feet) - > 1;/0 160 :!OO 2110 :!BO J:!O 360 400 11110 IIBO 520 560 600 6110 1.___1.. ._J_Ifj--,J.__!.-.,_J ._-,J__..1_...J._-,._1..@_.1__--l..,_.__I__J__,_..1.-.......I._,....I._- - L-_. L_'~&-"1.__L.'--.L__L._--1_- I . "699.99 ........ 2500 ....¥300 ,.....',., "",,~'íõ'~ "",..".,...,.."... .....1900 .~ / '/'// ""1700 ,/,,/""""'" ","'r5~0 1& .. 1J~:",.,..../ ,," .,.,., / .£)...1'300 & s ," '900 <II "500 " 4300 '.7,'00 II> 1"100 .. "1100 .. 3900 .. '900 . 3700 , ..' , ~oo .. '700 2'00 . ~.. ~ Ii 2500 , , .. 3500 .. '300 " , , " tl700 , ' ' " ' ~ .~ .. 2300 , "'900 330~", ffi2 i"'o~' (§7 .. 1500 2'00, ' , ' ~... ' .. '700 '300, ..' , '900 . , -S500 . .'700 ŒD "00 ~~'.', \$)' , . -sjoo " '500 @'300 ../",r~, ',~ PH I U..I P$ ¡ !ì ì .' v. ,; , ~ I \~ .. ""'-- ----" ,+- 6BO 120 760 "IBO 240 ^ I z 0 ..., -+ ::J'" & ~ 440 r¡,'P .. 4~00 .' 2300 "100 360 3:10 .2BO @ '1.& 'tl9QD'" ,13 , ~ ~.. 270 200 ,-..., -h CD CD -+ ......... - 160 120 BO "10 0 - '10 ORIGINAL "--' ( <.' 'D ì(l~ : 1 ~ "'"' S J. J.. ~. .... ....... ,...I .. ... A'" '1 :¡ a. S !'T 8'!' , ....^..~~....., ,. 'I ", r"!i ':".....:.~ 0 ~I. ~ I~... "\.. 10 n Lõ.. õ""f LJ C..a.c., .-.chac! For: V JohnRon Ja,c ...:,... : 2:-N....2OD' a:.. RoIcranco Õ. CJ2..2& Vafo:""I. Structure: CD#2 Field: Alpine Field Well: 26 Location: North Slope, Alaska Ca...;"a:.. ara In !aat rel_"ca olot ",. Ir.a Vorlloal Dca,no are ra'.aranoa R4B (Ja,a. :0). Zir.'õ! ~ - I~rt...' East (feet) - > 800 900 1000 1100 1'-00 1300 1400 1~00 1600 1700 1800 1900 '-000 ;,0100 noo 2300 '-400 '-~OO I. ...._L. ...L_l___.L._.L--.-L...l......1 . ... L...... 1 - , ,..... 1..- _1- ._.J..__I._..I._. 1-_L.....__I.._, ~_.._I. __I.... _I.. ..1.. .._I_....J,_...1 ---L..._,J, ,-, .1.- ...Lm .....L...,_.,L ,-... . <§) JJ..oo~ ~- 5700 .. 1000 6300.. .' " 1 00 \ (jf) .. \ .3100 \ 900 6100..' ,'3900 \ ,..4100 , ~\9 5900.. .. 2900':f1O0 \ , 3900 F \ 5500 . 530 800 5700.' .' '3500 , 3'/0~ ' 5100 5500, . 2700 ' \ , . 4900 "3300 . 3500 , 47~, , \ \ \ \ ~300 , \ \ \. \. . ,,5100 '1100 ' . . \ . \ . "00 5300 . , ,1IQ5~a.'3100 ~ 51.00' 230~" .' 2900 ~ ,'4900 ,... ' , ,'I, 2700 'l.fj 3300. . 4500 .. 4300 '. 600 ^ I z 0 .., -+- ::r 3100. 390Q 2900..' 370,0; ~ ~., , "'6500 2700 '3500 , " . ..' , ," , "..' 6300 2500.. ' .."," 3300 , "'3100 ~9 ...." ,., 61 00 \9 ....900 ~6 4100 .. ",---'" 6700 6900 . .. fiOO 'loa .-... ....... CD CD ..... --- . 300 '. \ . \. .200 . . \,900 . .:~ 100 ,~ 0 100 ORIGINAL (- (' ~....,. ~1 . ~1 "I . ::.11:("'11' ìl";~S .... ..~ ..~ ..I.. ........ '1-1 ... Alaska, ~r v'\ n ~.:...;.,'-'. c.-loa ... om,o.aa' For: V Johnson a.t. plalloa : ':..N..,.'OO1 alai Ra!.",... :. CJ'.'. Ve,.ia."', Well: 26 Structure: CDfl2 Field: Alpine Field Location: North Slope. Alaska eaa,di.o,n a.. i. f.., "'.'0". ."'. '26, T,~. Verl,.a: OoDl.. ara "".",.oa !tKB (Doyon 1 II, lLuRi"'" WWW:S ;¡.,n,~ East (feet) -> 1950 2100 2'-50 '-400 '550 '700 2850 3000 3150 3300 3450 3600 3150 3900 4050 ~ ~-~:'- ,- L,~-~~__L- ~-'-,-'--~-L..~- --,~~,~ .~~~-, - '50 , ,\, .\ , "1191"\ '.\ .\ . , . , ". \ ',~500 \ . , ", . . \ ~300 . \, \ " \ " \ " \~100 \' \ , \ \, \, '\ 3900 . i\9~0 \ ' ~.~.. 3500 " \ '~....... ".. 3'700 3500' ~::....:...,.,.. 3700 "\ 37~"""~"""""" 3900 '. ,\ """" ' \ 390~ "".~"~,....,....~t~~~O ""'\ J500 4 1 00. """""~..,.4300 " \ 4300" """""...,..,~50Ò', ", \ , ""'....', " \ 450"0- ":""':'>~4700. ", ,,30300 .' ....~....... ' 4100" ""':'..",." 490'ò ' ~ "'~..:. \ 4~~0 '~:""""'i"m.~~ "', \;~'ò~.~ , """> " 5gget, ~ ", ,\2700 . fS \. 2500 \ ~ 2300 8...~0 "', WfJ.~go \ 2500 . .. '. 2700 \, \, 290 " ~ 4700 f1Ð . * 3100 . 3300 " .' 3500 '.. 3l0e- , . , . 4100 .. 4300 .. 4,5~0 ~..,. 4900 '>:'~,.~900 ~"... 5100 ..,.....,., """'.. 5300 ""'" 3100 "" .""" 5500 "':~~Ò'.....: . 3300 "" ' "'....." , 5900 ....... " ' """'" ' , 3500 6100 ". " 'III. ......,..~ 6300"'",.. ' ,.,."...... . 3'700 ' 650Ò~"" . IlL. , ..,...~, " 670Ò"""".. "," 'ffiJ ""'" " -3900 "Qb ~ Qà .. 30300 ".. 3500 t . 3700 ~ Qà .",..-"""""~ j P=~~lUPS ( ~~ , 44 0 - 150 . 300 - 450 - BOO 750 - 900 (J) 0 c: -1050 -I- :J'" ~ - -1200 CD CD -I- ........... 1350 I V 1500 1650 1800 ..1950 - 2100 2250 2400 2550 ORIGINAL (- ( ..." ,. ....... ¡;."'I'"'\""i~.":"""S ..~ .1. ... ..:. .¡.JL..;.. 1.'-..1 .. .. A'" ,. 'c' .., ,: c' .- ~l2.S.:~a, ,. ;, 'Y'" "'\ .. ..;".... \.." . .~~ ~;. Þ!j..1IJ : I;!~ ",' -. L... . .;; r: J ¡ ~ . ""- ---..,.....--- CroaLD. III' ""¡C"aD' For: V Johnson Oalc p'a:Loa : ,: .."""v-,oo: Pia' ~CION""O :0 C:l2 -2& Vo'.:""I7. Structure: CD#2 Field: Alpine Field Well: 26 Location: North Slope. Alaska CoD'.:.D'O' are In !ool ..!..o.oo I"" "S. 1r.... Va"';OD' :I..:no aro N!O'D.CD RK!I (OaJon :ø). ~.... !'I:I!!I'o'.. !fO~ ::.11.0} ~ ClJ, 340 35~ 'n~u[ NOI~TH ~ r.:-:-.:J 0 1 0 '~002 0.,"'."& 2 1 0 ............ 30 ...,., .. 1000 ..3100 330 OJ. .;3 2 0 .. 1000 40 ~ \1 50 60 <§J -/0 ŒD 80 260 310 <l.~J 280 270 90 100 $' 250~,. aD 110 120 230 130 220 .'5500 ..100., .,'" .,""- 2 1..0.1'3'00 ~// 2~,j¡,~1g0 1 600 ........ 220 ~ 0 .,.'..,.,. ~ 1000 (000 ~-'13~0 ..".,....,. 1000' '\" 1 50 œ ' ..........., 16~' , . 18°% 170'~ ~ Normal FJlane Travelling Cylinder -.. Feet All depths shown are Measured depths on Reference Well 140 CiD ORIGINAL ( Phillips Alaska, Inc. CD#2 26 slot #26 Alpine Field North Slope, Alaska PRO P 0 S A L LIS TIN G by Baker Hughes INTEQ Your ref: CD2-26 Version#7 Our ref: prop4097 License: Date printed: 21-Nov-2001 Date created: 28-Sep-2000 Last revised: 21-Nov-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 19.152,w151 2 27.691 Slot Grid coordinates are N 5974532.354, E 371707.789 Slot local coordinates are 1824.78 S 1530.92 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ( ORIGINAL ( .( Phillips Alaska, Inc. PROPOSAL LISTING Page 1 CD#2, 26 Your ref : CD2-26 Version#1 Alpine Field,North Slope, Alaska Last revised : 21-Nov-2001 Measured Inclin Azimuth True Vert R £ C T A N G U L A R G R I D COO R D S G £ 0 G RAP H I C Depth Degrees Degrees Depth COO R D I N A T £ S £asting Northing COO R D I N A T £ S 0.00 0.00 0.00 0.00 O.OON 0.00£ 311'10"1.19 59"14532.35 n"lO 20 19.15 w151 2 27.69 100.00 0.00 71.10 100.00 O.OON 0.00£ 3'/1"107.79 5914532.35 n70 20 19.15 w151 2 27.69 200.00 0.00 11.10 200.00 O.OON 0.00£ 3'/1"107.19 5914532.35 n"lO 20 19.15 w151 2 21.69 300.00 0.00 71.70 300.00 O.OON 0.00£ 371707.19 5974532.35 n70 20 19.15 w151 2 27.69 400.00 0.00 11."10 400.00 O.OON 0.00£ 311'101.79 5974532.35 n'IO 20 19.15 w151 2 27.69 500.00 0.00 rI.70 500.00 O.OON 0.00£ 3"1170"1."19 5974532.35 n70 20 19.15 w151 2 27.69 600.00 2.00 '17.'10 599.98 0.37N 1.71£ 3"11'109.50 59"14532.70 n10 20 19.16 w151 2 27.64 "100.00 4.00 11."10 699.84 1.49N 6.82£ 371"114.63 59'14533.72 n70 20 19.1'/ w151 2 27.49 800.00 6.00 77.10 '/99.45 3.34N 15.33£ 3'/1'/23.18 59"14535.44 n10 20 19.18 w151 2 27.24 850.00 1.00 77. '70 849.13 4.55N 20.86£ 311'/28.'/2 5974536.55 n70 20 19.20 w151 2 27.08 1000.00 1.00 ï'l.70 998.01 8.44N 38.72£ 3"11'146.65 5974540.14 n70 20 19.24 w151 2 26.56 1200.00 7.00 71.'/0 1196.52 13.64N 62.54£ 3'/1770.54 5974544.93 n10 20 19.29 w151 2 25.86 1250.00 6.00 77.70 1246.20 14.84N 68.07£ 371776.09 5974546.04 n10 20 19.30 w151 2 25.10 1350.00 4.00 '/7.'/0 1345.81 16.'/ON '76.58£ 3ïl 784.64 5974547.'/5 n10 20 19.32 w151 2 25.45 1450.00 2.00 11.10 1445.6'/ l"1.81N 81.70E 3ïl"l89.'7'7 59"14548.78 n10 20 19.33 w151 2 25.30 1550.00 0.00 77.70 1545.65 18.18N 83.40£ 3ïl791.48 5974549.12 n'/O 20 19.33 w151 2 25.26 1556.35 0.00 71.ï8 1552.00 18.18N 83.40£ 3"11791.48 5974549.12 n"lO 20 19.33 w151 2 25.26 1600.00 0.00 71.78 1595.65 18.18N 83.40£ 311'/91.48 5974549.12 n'lO 20 19.33 w151 2 25.26 1'/00.00 0.00 '71.'/8 1695.65 18.18N 83.40£ 3'71'191.48 59'/4549.12 n'lO 20 19.33 w151 2 25.26 1800.00 0.00 ïl.78 1795.65 18.18N 83.40£ 371"191.48 59'74549.12 n"lO 20 19.33 w151 2 25.26 1900.00 0.00 71."18 1895.65 18.18N 83.40E 3'/1791.48 59'/4549.12 n70 20 19.33 w151 2 25.26 2000.00 0.00 71.78 1995.65 18.18N 83.40£ 371791.48 5974549.12 n70 20 19.33 w151 2 25.26 2100.00 0.00 71.78 2095.65 18.18N 83.40£ 371791.48 59"/4549.12 n70 20 19.33 w151 2 25.26 2200.00 0.00 "11.78 2195.65 18.18N 83.40£ 3'71791.48 5974549.12 n"lO 20 19.33 w151 2 25.26 2226.35 0.00 '/1.78 2222.00 18.18N 83.40£ 3'/1'/91.48 59'/4549.12 n'IO 20 19.33 w151 2 25.26 2300.00 0.00 ïl. '/8 2295.65 18.18N 83.40£ 311'/91.48 5914549.12 n70 20 19.33 w151 2 25.26 2393.35 0.00 71.78 2389.00 18.18N 83.40E 3'/1'191.48 5974549.12 n70 20 19.33 w151 2 25.26 2400.00 0.00 ïl.78 2395.65 18.18N 83.40E 311'/91.48 59'/4549.12 n'/O 20 19.33 w151 2 25.26 2403.35 0.00 '/1.78 2399.00 18.18N 83.40£ 3'/1791.48 5914549.12 n70 20 19.33 w151 2 25.26 2500.00 0.00 '/1."18 2495.65 18.18N 83.40£ 311791.48 5974549.12 n70 20 19.33 w151 2 25.26 2600.00 0.00 '71.78 2595.65 18.18N 83.40£ 3'/1'191.48 59"14549.12 n70 20 19.33 w151 2 25.26 2700.00 0.00 '71.78 2695.65 18.18N 83.40£ 3ïl'/91.48 5974549.12 n70 20 19.33 w151 2 25.26 2'/56.35 0.00 ïl.78 2"152.00 18.18N 83.40£ 3ïl'l91.48 5974549.12 n'IO 20 19.33 w151 2 25.26 2800.00 0.00 '/1.78 2795.65 18.18N 83.40E 3'71'191.48 5974549.12 n70 20 19.33 w151 2 25.26 2900.00 0.00 ïl.78 2895.65 18.18N 83.40£ 3"11'191.48 59'/4549.12 n70 20 19.33 w151 2 25.26 3000.00 0.00 71.78 2995.65 18.18N 83.40E 3'/1'/91.48 59'14549.12 n"lO 20 19.33 w151 2 25.26 3100.00 0.00 '/1.78 3095.65 18.18N 83.40E 3ïl'l91.48 59'14549.12 n'IO 20 19.33 w151 2 25.26 3200.00 0.00 '71."18 3195.65 18.18N 83.40£ 371'191.48 59'/4549.12 n'lO 20 19.33 w151 2 25.26 3300.00 0.00 11.78 3295.65 18.18N 83.40£ 3'/1'191.48 5974549.12 n"lO 20 19.33 w151 2 25.26 3400.00 0.00 '/1.78 3395.65 18.18N 83.40E 3 '71'/91. 48 59'/4549.12 n"lO 20 19.33 w151 2 25.26 3500.00 0.00 71.78 3495.65 18.18N 83.40£ 371791.48 59'14549.12 n70 20 19.33 w151 2 25.26 3600.00 0.00 11."18 3595.65 18.18N 83.40£ 311191.48 59'14549.12 n70 20 19.33 w151 2 25.26 3'100.00 0.00 ïl.78 3695.65 18.18N 83.40E 371791.48 5974549.12 n'70 20 19.33 w151 2 25.26 3800.00 0.00 ïl.78 3'195.65 18.18N 83.40E 3'/1'191.48 59'/4549.12 n'lO 20 19.33 w151 2 25.26 3852.35 0.00 '11.78 3848.00 18.18N 83.40£ 3ïl791.48 5974549.12 n'/O 20 19.33 w151 2 25.26 3900.00 0.00 '/1.18 3895.65 18.18N 83.40E 3'/1791.48 5974549.12 n70 20 19.33 w151 2 25.26 4000.00 0.00 '/1.78 3995.65 18.18N 83.40E 371'191.48 59'14549.12 n'lO 20 19.33 w151 2 25.26 4072.35 0.00 71.78 4068.00 18.18N 83.40£ 371791.48 5974549.12 n'lO 20 19.33 w151 2 25.26 4100.00 0.00 '71.'18 4095.65 18.18N 83.40£ 3'71791.48 5974549.12 n70 20 19.33 w151 2 25.26 4200.00 0.00 71.78 4195.65 18.18N 83.40£ 3'/1'191.48 5974549.12 n'lO 20 19.33 w151 2 25.26 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #26 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 4451.26 on azimuth 122.23 degrees from wellhead. Total Dogleg for wellpath is 148.05 degrees. Vertical section is from wellhead on azimuth 90.48 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INT£Q ORIGINAL (' ( Phillips Alaska, Inc. PROPOSAL LISTING Page 2 CD#2,26 Your ref : CD2-26 Version#1 Alpine Field,North Slope, Alaska Last revised : 21-Nov-2001 Measured Inclin Azimuth True Vert R E C T AN G U LA R G R I D COO R D S G E 0 G R A P H I C Depth Degrees Degrees Depth COO R D I N ATE S Easting Northing COO R D I N ATE S 4300.00 0.00 11.78 4295.65 18.18N 83.40E 371791.48 5914549.12 n10 20 19.33 w151 2 25.26 4400.00 0.00 11.78 4395.65 18.18N 83.40E 311'191.48 5914549.12 n10 20 19.33 w151 2 25.26 4500.00 0.00 71.78 4495.65 18.18N 83.40E 371791.48 5914549.12 n10 20 19.33 w151 2 25.26 4600.00 0.00 71.18 4595.65 18.18N 83.40E 311191.48 5914549.12 n10 20 19,,33 w151 2 25,,26 4650.00 0.00 '11.78 4645.65 18.18N 83.40E 311'191.48 5974549.12 n'lO 20 19.33 w151 2 25.26 4750.00 2.00 11.78 4145.63 18.73N 85.06E 311193.15 5914549.64 n10 20 19.34 w151 2 25.21 4850.00 4.00 11.78 4845.49 20.37N 90.03E 311798.14 5914551.19 n10 20 19.35 w151 2 25.06 4950.00 6.00 11.18 4945.10 23.09N 98.31E 311806.41 5914553.78 n10 20 19.38 w151 2 24.82 5050.00 8.00 11. '/8 5044.35 26.90N 109.88E 311818.10 5974557.39 n70 20 19.42 w151 2 24.48 5116.6"/ 12.00 11."/8 5109.99 30.52N 120.88E 371829.15 59'/4560.83 n70 20 19.45 w151 2 24.16 5216.6"/ 18.00 11."18 5206.54 38.61N 145.45E 311853.86 59'/4568.50 n70 20 19.53 w151 2 23.44 5316.67 24.00 71.78 5299.86 49.82N 179.47E 371888.06 5974579.12 n'/O 20 19.64 w151 2 22.45 5416.6'/ 30.00 11.78 5388.92 64.01N 222.58E 3'11931.40 5974592.58 n70 20 19.78 w151 2 21.19 5516.6'/ 36.00 '11."/8 5472.'/5 81.03N 2'/4.2 8E 371983.38 59'/4608.73 n'/O 20 19.95 w151 2 19.68 5616.67 42.00 '/1."/8 5550.42 100.70N 334.03E 312043.45 597462'/.39 n70 20 20.14 w151 2 17.94 5661.46 44.69 71."/8 5583,,00 110.32N 363.24E 3'/20'/2.81 59'/4636.51 n10 20 20.24 w151 2 1'1.08 5'116.67 48.00 '11."/8 5621.10 122.81N 401.1'7E 312110.94 5914648.35 n70 20 20.36 w151 2 15.97 5'149.19 49.95 '/1. '/8 5642.45 130.48N 424.41E 372134.37 5974655.63 n70 20 20.44 w151 2 15.29 6000.00 49.95 n.n 5803.83 190.52N 606.84E 372317.71 5974112.51 n10 20 21.03 w151 2 09.97 6409.00 49,,95 '/1. '18 6061,,00 288.43N 904.22E 3'/2616.69 59'/4805.44 n'/O 20 21.99 w151 2 01.28 6500.00 49.95 '11 . '/8 6125.55 310.22N 970.39E 312683.20 5974826.10 n70 20 22.20 w151 1 59.35 1000.00 49.95 71. '/8 6441.27 429.91N 1333. 94E 373048.'10 59'/4939.62 n'lO 20 23.38 w151 1 48.'13 '/281.82 49.95 n.'18 6628.61 49'1.38N 1538.85E 3'/3254.'11 59'/5003.61 n'/O 20 24.05 w151 1 42. '/4 '/300.00 50.04 13.20 6640.29 501.57N 1552.13E 373268.05 59'1500'1.57 n'/O 20 24.09 w151 1 42.36 '/400.00 50.82 80.92 6704.05 518.78N 1627.16E 373343.35 5975023.51 n70 20 24.26 w151 1 40.16 7500.00 52.10 88.41 6'/66.41 526.00N 1704. 94E 3"/3421.24 59'/5029.41 n'/O 20 24.33 w151 1 37.89 7535.36 52.66 91.00 6"/88.00 526.14N 1'I32.94E 3'13449.23 5975029.08 n70 20 24.33 w151 1 3'/.01 7600.00 53.83 95.61 6826.69 523.14N 1784.62E 3'13500.85 59'/5025.21 n70 20 24.30 w151 1 35.5'/ '/'JOO.OO 55.98 102.46 6884.23 510.24N 1865.33E 373581.32 59'/5010.95 n70 20 24.1'1 w151 1 33.21 1800.00 58.48 108.95 6938.39 48'1.44N 1946.18E 313661.'1'l 5974986.78 n'/O 20 23.95 w151 1 30.85 7847.96 59.80 111.93 6963.00 4'13.05N 1984.'/5E 373'/00.09 59'149'71.'/5 n70 20 23.81 w151 1 29.72 7900.00 61.30 115.08 6988.59 454.98N 2026.29E 373'/41.31 59'/4952.98 n'/O 20 23.63 w151 1 28.51 8000.00 64.3'/ 120.87 7034.27 413.23N 2104.'/8E 373819.08 5974909.91 n70 20 23.22 w151 1 26.21 8042.02 65. '13 123.21 '1052.00 393.01N 213"1. O'/E 373851.03 59'/4889.15 n70 20 23.02 w151 1 25.27 8100.00 6'/.66 126.36 70'14.94 362.63N 2180.'I9E 3'/3894.22 59'/4858.04 n70 20 22. '12 w151 1 23.99 8200.00 '/1.13 131.59 "/11 0 . 14 303.75N 2253.49E 3-/3965.90 597419'1.94 n70 20 22.14 w151 1 21. 8'/ 8224.87 '12.02 132.86 '1118.00 287.90N 2270.96E 373983.10 5974781.80 n70 20 21.98 w151 1 21.36 8286.92 14.26 135.96 7136.00 246.34N 2313.37E 374024.80 5974739.53 n'/O 20 21.58 w151 1 20.12 8300.00 '/4. '14 136.61 '/139 . 49 237.23N 2322.07E 3'}4033.35 5974'130.28 n70 20 21.49 w151 1 19.8"/ 8359.28 '/6.93 139.50 '/154.00 194.49N 2360.48E 374071.03 59"/4686.90 n70 20 21.07 w151 1 18. '/5 8400.00 '/8.46 141.45 1162.68 163.80N 2385.80E 3'/4095.82 5914655.'/9 n70 20 20.76 w151 1 18.01 8500.00 82.25 146.17 '11'79.44 84.26N 2443.97E 3'/4152.63 59'14575.28 n70 20 19.98 w151 1 16.31 8600.00 86.10 150.80 "/189.59 0.51S 2495.94E 374203.16 59'14489.65 n'/O 20 19.15 w151 1 14.79 8623.35 87.00 151.87 7191.00 20. 96S 2507.12E 374213.99 5974469.01 n'/O 20 18.95 w151 1 14.46 8623.37 87.00 151.8'/ 7191.00 20.98S 2507.13E 374214.00 5974469.00 n70 20 18.95 w151 1 14.46 8723.37 88.00 151.87 1195.36 109.08S 2554.23E 374259.60 5974380.12 n70 20 18.08 w151 1 13.09 8823.37 89.00 151.87 7197.98 197.24S 2601.36E 374305.23 5974291.19 n'/O 20 1'1.21 w151 1 11.71 8923.3'1 90.00 151. 8 -/ 7198.85 285.42S 2648.50E 374350.87 59'/4202.22 n'/O 20 16.35 w151 1 10.33 8984.26 90.61 151.87 1198.53 339.13S 26'f'1.21E 374378.67 5974148.05 n70 20 15.82 w151 1 09.50 9000.00 90.61 151.8'/ '1198.36 353.00S 2684.63E 374385.85 5974134.05 n70 20 15.68 w151 1 09.28 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #26 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 4451.26 on azimuth 122.23 degrees from wellhead. Total Dogleg for wellpath is 148.05 degrees. Vertical section is from wellhead on azimuth 90.48 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL (' ( Phillips Alaska, Inc. PROPO5AL LI5TING Page 3 CD#2,26 Your ref : CD2-26 Version#'/ Alpine Field,North 51ope, Alaska Last revised : 21-Nov-2001 Measured Inclin Azimuth True Vert R E C T AN G U LA R G R I D COO R D 5 G E 0 G R A P H I C Depth Degrees Degrees Depth COO R D I N A T E 5 Easting Northing COO R D I N AT E 5 9500.00 90.61 151.8'/ 'J193.05 '193.925 2920.35E 3'/4614.06 59'/3689.24 n'IO 20 11.34 w151 1 02.40 10000.00 90.61 151.8'/ '/18'/.73 1234.845 3156.0'IE 3'/4842.2'1 59'13244.44 n70 20 07.01 w151 0 55.52 10500.00 90.61 151.8'1 '/182.42 16'/5.'/65 3391.'/8E 3'/50'/0.48 59'12'799.63 n70 20 02.6'/ w151 0 48.64 11000.00 90.61 151.8'1 71n .10 2116.685 362'1.50E 3'/5298.69 59'12354.83 n70 19 58.33 w151 0 41.76 11292.05 90.61 151.8'/ '/174.00 23'/4.225 3'/65.18E 3'/5431.99 5912095.02 n'/O 19 55.80 w151 0 3'1. '14 11292.0'1 90.61 151.8'1 7174.00 2374.245 3'/65.19E 3'/5432.00 5912095.00 n70 19 55.80 w151 0 37.74 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #26 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 4451.26 on azimuth 122.23 degrees from wellhead. Total Dogleg for wellpath is 148.05 degrees. Vertical section is from wellhead on azimuth 90.48 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL (' ( Phillips Alaska, Inc. CD#2,26 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 4 Your ref: CD2-26 Version#1 Last revised: 21-Nov-2001 Comments in wellpath -------------------- -------------------- MD Rectangular Coords. Comment TVD ----------------------------------------------------------------------------------------------------------- 500.00 500.00 O.OON O.OOE KOP 850.00 849.13 4.55N 20.8 6E EOC 1200.00 1196.52 13. 64N 62.54E Begin Drop 1550.00 1545.65 18.18N 83.40E EOC 1556.35 1552.00 18.18N 83.40E Base Permafrost 2226.35 2222.00 18.18N 83.40E C-40 2393.35 2389.00 18.18N 83.40E 9 5/8" Casing 2403.35 2399.00 18.18N 83.40E C-30 2156.35 2152.00 18.18N 83.40E C-20 3852.35 3848.00 18.18N 83.40E K-3 4072.35 4068.00 18.18N 83.40E K-2 4650.00 4645.65 18.18N 83.40E KOP 5050.00 5044.35 26. 90N 109.88E Begin 6/100 Bld 5661.46 5583.00 11 0 .32N 363.24E Albian- 9'1 5149.19 5642.45 130.48N 424.41E EOC 6409.00 6067.00 288.43N 904.22E Albian-96 7281. 82 6628.61 491.38N 1538.85E Begin Fnl Bld/Trn 1535.36 6788.00 526.14N 1132.94E HRZ 1847.96 6963.00 413.05N 1984.75E K-1 8042.02 1052.00 393.01N 2131.01E LCU 8224.87 7118.00 287.90N 2270.96E Miluveach A 8286.92 '1136.00 246.34N 2313. 31E Alpine D 8359.28 '1154.00 194.49N 2360.48E Alpine C 8623.35 '1191.00 20.96S 2507.12E Target - Casing pt 8623.3'1 7191.00 20.98S 2501.13E CD2-26 Heel Rvsd 25-Sept-01 8984.26 '1198.53 339.13S 26'l"/.21E EOC 11292.05 1114.00 2314.22S 3165.18E TD - Csg pt 11292.07 1114.00 2314.24S 3165.19E CD2-26 Toe Rvsd 5-Nov-01 Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE O.OOE 2393.35 8131.29 2389.00 1195.63 83.40E 2557.96E 9 5/8" Casing 'I" Casing 18.18N 116.0'/S Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- CD2-26 Heel Rvsd 25- 374214.000,59'14469.000,2.0000 CD2-26 Toe Rvsd 5-No 315432.000,5912095.000,-2.000 '1191.00 1174.00 20.98S 23"/4.24S 250'l.13E 3765.19E 19-Jun-1998 8-Nov-2001 OID/~j'ßIAl ,4!!",,':'r;"I,¥n'f~ '\':" )", ,.." ,', ". .,A., i.1 II.. ,; ,4'.J,..~ I.'. . \.,' '" ,,' oJ \"," I,' i. rJ Ii Ii] .cia . ;> <' ( Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 26,2001 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED NOV 2 7 2001 Re: Application for Permit to Drill CD2-26 Alaska Oil & Gas Cons. Commission Anchorage Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Water Alternating Gas (WAG) injection well from the Alpine CO2 drilling pad. The intended spud date for this well is December 28, 2001. It is intended that Doyon Rig 19 be used to drill the well. The CD2-26 will be drilled to penetrate the Alpine reservoir horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well will be completed as an open hole injector. At the end of the work program, the well will be shut in awaiting connection to surface facilities. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. IY,Z .--- ?/ 0/0, ern Johnson Drilling Engineer ORIGINAL , . ( Attachments cc: CD2-26 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin e-mail: (' ATO 1530 A TO 868 A TO 848 A TO 844 Anadarko - Houston Kuukpik Corporation Tommy- Thompson@anadarko.com ORIG1NAL RECEIVED NOV 2 7 2001 Alaska Oil & Gas Cons. Commission Anchorage ~. ( THIS MULTI-TONE AREA OF THE DOCUMFNT CHANGES COLOR GRADUALLY AND EVENLY FROM DARK TO LIGHT WITH DARKER AREAS BOTH TOP AND BOTTOM. -- - ~;. -------- ~ .'. Phillips Alaska, Inc. P. O. Box 102776 Anchorage, AK 99510-2776 \ n <';-i:~::r~ji; r5t~::5'(rTçr:~,\,"~: .:~:, " , ~ . :-';>;""'. ;, ~~,a", nct,»:' ;!">:.i;t"'~~--;'-;: '/;::-~;)¡ .::'~,~~¡;""t~ , : ::;~.;:.; " '"~~i:l\~t~~~~~~~~~'9~tB7~~~;,t~:-);5'¡'\"~¡',::{~;: :';, , :,",~\'I.~~~, ,!J,~ ,~~~:: :,:",,;.';:- ':""~: "",', fa.11'able'Tbrou&IJ. ,:,' ,,>", ',' ,: ,: " RepØbJic B~k; Shel~YVi~1~;,.~t~31 ' ' ,: i:'.,: :,: ',:,:: :,' ~,:, 0,: ',','. ~,.,' .,'. ~,: 1 W,.",1 ~,.,' ~,' .,~ - ~:' {,M,':. ,":, ,',' ,:"," ,::::':,' : """'::"", "",,'" " ,', :::;:: ",,", ,", "", """ ',' ,:::, ':'" :::", " ,',,' ,:, :':, ::: ,:', ="',:,T:6":,>th"è,",:p",,,£,.:dê,"':::,,r,' O,":':f,';,', 'lii27}6.i:: """ ~:*::'II::~:;i.~,~,,~~:~:~:*+~i9.d:,O'O+: " ' ,p~ìe:, :Anj~urit '.'. . ".:',~~~;~~~~~~::V¡;.~I~: Ç9~SS[9~i.. ,.....r~¡{~:9q.:!~ ,". .' ::":,,,."'" .: :,":':-: :","'" " :;:\ i-üiCHOAAGE ,::1¥<, 9ß~q-1::: ,',' ", ",'" "'"t,:::" "" ,," ':::::' ',' ", lj£)Cj, " " i III 0 a 0 a ~ a .~ a:l ~ III ' I:O,8:} qO ~ 2,(; 21: Ol1 gOO 0.0 III \, . ( {" 'I~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETfERIP ARAGRAPHS TO BE INCLUDED IN TRANSNUTTALLETTER WELL NAME {!;f? U CHECK 1 ST ANDARD LETTER DEVELOPMENT CHECK WHAT APPLIFS ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) ø DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORA TION ANNULAR DISPOSAL L-JNO INJECTION WELL ~' ANNULAR DISPOSAL L-J YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL eD L - Z- ?::> "CLUE" The permit is for a new 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 2.0 AAC 25.005(f), aU records, data and logs acquired for the pilot bole 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 / wi> 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 . 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 ~ame) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY FIELD & POOL /ZL) / DO INIT CLASS . ADMINISTRA TION 1.Permitfeeattached....................... 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . '("'- . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can.be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided . . . . . . . . .. . . . . . . . . . N 15. Surface casing protects all known USDWs. . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Ji... ' 17. GMT vol adequate to ,tie-in long string to surf csg. . . . . . . . QV b.......~\) \.o..~~""\"">\>(:)"i:..~ \ ~ \-\~ t'-"-~~" ~ \o...,,~~ , 18. CMT will cover all known productive horizons. . . . .'. . . . . N 19. Casing designs adequate for C, T, 8 & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . !y:.~'N 21. If a re-drill, has a 10-403 for abandonment been approved. . . N ~lA 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23.' If diverter required, does it meet regulations. . . . . . . . . . N f)o~"'- \ q, 24. Drilling .fluid program schematic & equip list adequate. . ~ . . N 25. 80PEs, do they meet regulation. . . . . . . . . . . . . . . . ¡ N 26. BOPE press rating appropriate; test to 5 0 cJ (/ psig. , N . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N D I ~ ~~: ~~:::~~~;rH~h:: ~:~:~~; ~~u~d~~n: : : : : : : : : : : y ~ 30. Permit can be issued w/o hydrogen sulfide measures. . . . .. 'élJ N, 31. Data presented on potential overpressure zones. . . . . . . ~ 32. Seismic analysis of shallow gas zones. . . . . . . . . Ä. . . Y N AFff~ PATE 33. Seabed condition survey flf off-shore). . . . . . . . . . . . Y N ~ 12 ,ip,D r 34. Contact name/phone for weekly progress reports [explo ory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface; ," ' (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING:,' UIC/Annular COMMISSION: RP~ W414- WM '-- . S F ~-ifb- - - ~rgp DA ~E ( IZ-'{¡;.D ENGINEERING DtT~ Il. 10 01 l Øfc ,.0 ~ GEOLOGY APPR DATE . PROGRAM: exp - dev - redrll GEOLAREA N N serv wellbore seg _ann. disposal para req- UNIT# áÇTJ36[] ON/OFF SHORE D/l c 0 Z 0 ~ ~ :xJ ( - ~ m - z ~ .J: - en :Þ :xJ m » ( Y N Y N 'I),; 'ë." ~ ~ ';~;"t:J~ O¡",,- C 1) 2. ' (Å.. d ~ "'J Q \ \. ~ "- 'fV'..c'>' ~ \ '- Jþ(t~\ ~\':.~ C'C þ.,. ~ 'ore Com me ntsllnstructions: l').-I \4' Ò \ 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 Permitting Process' but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically , . organize this category of information. ( ~i , Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Sep 30 12:41:26 2002 Reel Header Service name.... ........ .LISTPE Date.....................02/09/30 Origin...................STS Reel Name. .............. . UNKNOWN Continuation Number.... ..01 Previous Reel Name...... . UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name........... ..LISTPE Date.....................02/09/30 Origin...................STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Physical EOF Writing Library. Scientific Technical Services Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: CD2-26 501032039700 PHILLIPS Alaska, Inc. Sperry Sun 30-SEP-02 MWD RUN 4 MWD RUN 5 MWD RUN 6 AK-MM-1l220 AK-MM-1l220 AK-MM-1l220 A. WEAVER M. HANIK M. HANIK D. MICKEY D. MICKEY D. BURLEY 2 llN 4E 1825 1532 MSL 0) .00 51. 90 15.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 2387.0 8.500 7.000 8618.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 -3 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 4 - 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY a DJ - ål3d /lJ5(p (i' ( (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. GAMMA RAY LOGGED BEHIND CASING FROM 2361' MD, 2357' TVD, TO 2387', 2383' TVD. 5. GAMMA RAY LOGGED BEHIND CASING FROM 8596' MD, 7183' TVD, TO 8618', 7184' TVD. RESISTIVITY DATA LOGGED BEHIND CASING FROM 8589' MD, 7182' TVD TO 8618', 7184' TVD. 6. GAMMA RAY DATA HAS BEEN CORRECTED FOR 6% KCL MUD AND BOREHOLE SIZE ON MWD RUN 6. 7. MWD CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 09/26/01. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 6 REPRESENT WELL CD2-26 WITH API # 50-103-20397-00. THIS WEL REACHED A TOTAL DEPTH OF 11238' MD, 7180' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/09/30 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2361.0 2377.0 2377.0 2377.0 2377 . 0 2377.0 2398.0 STOP DEPTH 11195.0 11202.0 11202.0 11202.0 11202.0 11202.0 11237.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # ( ( MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 4 2361.0 7250.0 MWD 5 7250.5 8629.0 MWD 6 8629.5 11237.5 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type............. .....0 Data Specification Block Type.....O Logging Direction.... ..... ...... ..Down Optical log depth units......... ..Feet Data Reference Point.... .... ..... .Undefined Frame Spacing......... ..... ...... .60 .1IN Max frames per record.......... ...Undefined Absent value................. .... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2361 11237.5 6799.25 17754 2361 11237.5 ROP MWD FT/H 0.08 429.14 130.227 17680 2398 11237.5 GR MWD API 27.7 429.81 96.7293 17669 2361 11195 RPX MWD OHMM 0.27 2000 9.97115 17651 2377 11202 RPS MWD OHMM 0.26 2000 11. 2958 17651 2377 11202 RPM MWD OHMM 0.27 2000 16.103 17651 2377 11202 RPD MWD OHMM 0.16 2000 17.3298 17651 2377 11202 FET MWD HR 0.21 56.26 1. 09503 17651 2377 11202 First Reading For Entire File......... .2361 Last Reading For Entire File.......... .11237.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation.. .... .02/09/30 Maximum Physical Record. .65535 File Type........... .... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation... ... .02/09/30 Maximum Physical Record. .65535 File Type............... .LO Previous File Name... ....STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD 2 ( ( header data for each bit run in separate files. 4 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ START DEPTH 2361.0 2377.0 2377.0 2377 .0 2377.0 2377.0 2398.0 STOP DEPTH 7208.0 7200.5 7200.5 7200.5 7200.5 7200.5 7250.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units..... .,... .Feet Data Reference Point............. .Undefined Frame spacing.....................60 .1IN Max frames per record........... ..Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type. ..0 12-JAN-02 Insite 4.05.5 66.16 Memory 7250.0 .1 50.2 TOOL NUMBER PB2236HWRGV6 PB2236HWRGV6 8.500 LSND 9.60 40.0 8.8 500 5.0 2.300 1.099 2.100 1. 800 60.0 133.0 60.0 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel ( ( DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2361 7250 4805.5 9779 2361 7250 ROP MWD040 FT/H 0.08 429.14 158.25 9705 2398 7250 GR MWD040 API 44.97 200.25 109.215 9695 2361 7208 RPX MWD040 OHMM 0.29 2000 5.17761 9648 2377 7200.5 RPS MWD040 OHMM 0.26 2000 5.22463 9648 2377 7200.5 RPM MWD040 OHMM 0.27 2000 6.01216 9648 2377 7200.5 RPD MWD040 OHMM 0.16 2000 6.86986 9648 2377 7200.5 FET MWD040 HR 0.22 42.41 0.809313 9648 2377 7200.5 First Reading For Entire File......... .2361 Last Reading For Entire File.......... .7250 File Trailer Service name... ......... .STSLIB.002 Service Sub Level Name... Version Number.... .... ...1.0.0 Date of Generation... ... .02/09/30 Maximum Physical Record. .65535 File Type............... .LO Next File Name... .... ....STSLIB.003 Physical EOF File Header Service name..... .... ....STSLIB.003 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation... ....02/09/30 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 3 header data for each bit run in separate files. 5 .5000 START DEPTH 7201.0 7201.0 7201.0 7201.0 7201.0 7208.5 7250.5 STOP DEPTH 8588.5 8588.5 8588.5 8588.5 8588.5 8596.0 8629.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): 14-JAN-02 Insite 4.05.5 66.16 Memory 8629.0 f BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ........ ..0 Data Specification Block Type.. ...0 Logging Direction.... ........... ..Down Optical log depth units. ...,.. ... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.................... ..-999 Depth Units....................... Datum Specification Block sub-type...O .,. ( 50.4 84.6 TOOL NUMBER PB2236HWRGV6 PB22 3 6HWRGV 6 8.500 8618.0 LSND 9.60 41.0 8.9 400 4.6 1. 600 .732 1.100 1. 800 62.0 143.6 62.0 62.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7201 8629 7915 2857 7201 8629 ROP MWD050 FT/H 6.02 239.38 65.7206 2758 7250.5 8629 GR MWD050 API 48.87 429.81 135.349 2776 7208.5 8596 RPX MWD050 OHMM 1. 64 29.69 6.53831 2776 7201 8588.5 RPS MWD050 OHMM 1. 64 31.88 6.95467 2776 7201 8588.5 RPM MWD050 OHMM 1. 67 31.26 7.37389 2776 7201 8588.5 RPD MWD050 OHMM 1. 59 28.79 7.50187 2776 7201 8588.5 FET MWD050 HR 0.43 14.87 1.45676 2776 7201 8588.5 ( { First Reading For Entire File. ....... ..7201 Last Reading For Entire File.......... .8629 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation.. .... .02/09/30 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/09/30 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 header data for each bit run in separate files. 6 .5000 START DEPTH 8589.0 8589.0 8589.0 8589.0 8589.0 8596.5 8629.5 STOP DEPTH 11202.0 11202.0 11202.0 11202.0 11202.0 11195.0 11237.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 18-JAN-02 Insite 4.05.5 66.37 Memory 11238.0 88.2 91. 5 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PBO2355HAGR4 PBO2355HAGR4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): Flo Pro 8.90 47.0 9.0 26000 4.2 ( ,4 \ RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .100 .051 .120 .080 79.0 159.8 79.0 79.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction............ .... . Down Optical log depth units..... ..... .Feet Data Reference Point............. .Undefined Frame Spacing.................. ...60 .1IN Max frames per record........ .... . Undefined Absent value........... ..... ..... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8589 11237.5 9913.25 5298 8589 11237.5 ROP MWD060 FT/H 0.27 231. 69 112.198 5217 8629.5 11237.5 GR MWD060 API 27.7 81. 6 52.8174 5198 8596.5 11195 RPX MWD060 OHMM 0.27 1458.73 20.6422 5227 8589 11202 RPS MWD060 OHMM 1. 28 1458.79 24.8074 5227 8589 11202 RPM MWD060 OHMM 5.86 2000 39.3646 5227 8589 11202 RPD MWD060 OHMM 7.82 2000 41. 8562 5227 8589 11202 FET MWD060 HR 0.21 56.26 1.4303 5227 8589 11202 First Reading For Entire File........ ..8589 Last Reading For Entire File... ....... .11237.5 File Trailer Service name... ......... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/09/30 Maximum Physical Record..65535 File Type.............. ..LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................02/09/30 Origin...................STS Tape Name............... . UNKNOWN Continuation Number.... ..01 ~: Next Tape Name.......... . UNKNOWN Comments............. ... .STS LIS Writing Library. Reel Trailer Service name....... ..... .LISTPE Date.....................02/09/30 Origin...................STS Reel Name... ..... ....... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments.................STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. ( Scientific Technical Services Scientific Technical Services