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Home My WebLink About202-108MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-48 COLVILLE RIV UNIT CD2-48 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/20/2022 CD2-48 50-103-20422-00-00 202-108-0 G SPT 7063 2021080 1766 4100 4100 4100 4100 550 560 560 560 4YRTST P Bob Noble 6/8/2022 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD2-48 Inspection Date: Tubing OA Packer Depth 1590 2510 2475 2470IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220612150610 BBL Pumped:0.9 BBL Returned:0.9 Wednesday, July 20, 2022 Page 1 of 1         • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 11,2018 TO: Jim Regg P.I.Supervisor 1\ C ç4,3C l SUBJECT: Mechanical Integrity Tests lL CONOCOPHILLIPS ALASKA,INC. CD2-48 FROM: Brian Bixby COLVILLE RIV UNIT CD2-48 Petroleum Inspector Src: Inspector Reviewed Bye P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE Riv UNIT CD2-48 API Well Number 50-103-20422-00-00 Inspector Name: Brian Bixby Permit Number: 202-108-0 Inspection Date: 6/6/2018 Insp Num: mitBDB180611052116 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD2-48 -Type Inj G "!TVD 6962 - Tubing 3950 - 3950 ' 3950 -T 3950 — - es SPT — — 'i ,, 410 - 410 e PTD � 2021080 Type Test Test STest psi 1740 IA 1080 2200 2170 2170 BBL Pumped:d: t.z - BBL Returned: 1 OA 310 410 Interval ; 4YRTST P/F P I/ Notes: scowl) JUN 2 '2 LU16 Monday,June 11,2018 Page 1 of 1 Imag 'Project Well History File Cover I 1ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. dOcl -10<6 Well History File Identifier Organizing (dom~) REJCAN .~ Color items: 0 Two-Sided DIGITAL DATA ~ Diskettes, No,1 0 Other, Norrype 0 Grayscale items: 0 Poor Quality Originals: Other: 0 NOTES: BY: BEVERLY ROBIN VINCENT SHERY~WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHER~ WINDY Scanning Preparation ~-~ rn x 30 = BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY ~escan Needed OVERSIZED (Scannable) 0 Maps: 0 Other items scannable by large scanner OVERSIZED (Non-Scannable) V' Logs ofvarious kinds I I [1 Other r 111~ IJ\'f DATE: 'dJIIU /s/ ,I " + ~p DATEr ;)-7of/S' V11 0 ~ = TOTAL PAGES I rx ~ ~ i DATE7 ð7 ðtþs' ~::2 0 . 1,-1 Production Scanning IlL j"\ ~ . }..a.n ~ . j) n \ Stage 1 PAGE COUNTFROM SCANNED FILE: °7' ~ ;/~~cte..c( PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: tL... YES - NO DATErD ~ DtfS' I11P Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ' - YES - NO BY: BEVERLY ROBIN VINCENT SHERYL~~INDY BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECiAl ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (inr.fi\'idu;)/ ¡uq', [!".{)ccial ¡'fT0/ltÎOnj $(:,)nnil1g !;ompll';cd) RESCANNED BY': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /Sl DATE: IS/ Quality Checked (dnllcl 12/10/02Rev3NOTScanned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: 2-t:>¿ !ð r¿ FILE # L - /fC,L,~ i - ¿¡ß Œ. To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ¡ 333 W. 7th Ave., Ste. 100 ; Anchorage, Alaska 99501 Voice (907) 279-1433 ~Fax (907) 276-7542 MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, August 02, 2010 To: Jim Regg i~ 1~~~,/c ~I~ ~ ~ v SUBJECT: Mechanical Integrity Tests P.I. Supervisor CONOCOPHILLIPS ALASKA INC CD2-48 FROM: Jeff Jones COLVILLE RIV UNIT CD2-48 Petroleum Inspector Src: Inspector Nl)N_C~(1NFinF.NTiAL Reviewed By: P.I. Suprv ~_ Comm Well Name: COLVILLE RIV UNIT CD2-48 mitJJ100802072224 Insp Num: Rel Insp Num: API Well Number: 50-103-20422-00-00 Permit Number: 202-108-0 Inspector Name: Jeff Jones Inspection Date: 6/11/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CDZ-as ~ Type Inj. W TVD 6962 IA 400 1980 ~ 1950 1930 ' P.T.D ZozloBO ' TypeTest SPT Test psi 1740 - OA ~s too loo loo Interval 4~TST p/F P 'Tubing 2szo 2s2o 2s2o 2s2o NOtes: 1.3 BBLS diesel pumped; no exceptions noted. ' V~" Monday, August 02, 2010 Page 1 of 1 MEMORANDUM ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, February 11, 2010 Toy Jim Regg Z, P.I. Supervisor ( ~ ~ ~ ~~ ` +~ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-48 FROM: LOU GI'Imai(il COLVILLE RIV iJNIT CD2-48 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J' /~ Comm Well Name: COLVILLE RIV i1NIT CD2-48 API Well Number: 50-103-20422-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG100109201218 Permit Number: 202-108-0 Inspection Date: 1/8/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- CD2-48 ~ ~- Well ~ Type InI. , TVD 6962 ~ ~ IA 1200 - --- 1900 1s6o -- 1860 ~-- - 2021080 SPT P.T~ _ iTypeTest ~ Test psi Interval INITAL ~ p~F P 1741 ~ OA soo ~ Tubing ~ 203s sso 2035 sso 2038 sso 2038 Notes' •3 Bbl's pumped. Good solid test Thursday, February 11, 2010 Page 1 of 1 • • Page 1 of 3 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, January 12, 2010 2:43 PM To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Reed, Scott; Schneider, Tim S.; Barreda, Brian B; Tonello, John V; Pysz, Nick P; NSK Problem Well Supv Subject: ConocoPhillips Cancellation of A1018B.003 Guy/Tom/Jim, >1 Alpine injecto D2-48 PTD#202-108 passed its post workover MITIA as witnessed by Lou Grimaldi on l~ 01/08/10. CPA hereby requests that dministrative Approval A1018B.003 be cancelled and allow the well to be returned to WAG injection service. The well will also be removed from the monthly report. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. ~ ~~~~ ~ ~; ~~~~ Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, October 20, 2009 1:37 PM To: Schneider, Tim S.; Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Regg, James B (DOA); NSK Problem Well Supv; Reed, Scott; Packer, Brett B; ALP DS Lead and Simops Coord Subject: RE: Cancellation of AI018B.003 And AI018B.005 Tim/Martin, I haven't seen the 10-404 for CD2-56 but assume it will be in hand shortly. I have just received the 404 for CD2- 48late last week. Don't remember all the issues with these two wells but hopefully the stacker packer and new tubing will solve issues with elevated IA pressures associated with the MI injection. Keep me in the loop on the witnessed MIT testing and I will try to expedite the cancellations. Are you planning on going to MI as soon as possible?? Guy Schwartz Petroleum Engineer AOGCC " 793-1226 (office) 444-3433 (cell) From: Schneider, Tim S. [mailto:Tim.S.Schneider@conocophillips.com] Sent: Tuesday, October 20, 2009 12:48 PM To: Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Regg, James B (DOA); NSK Problem Well Supv; Schwartz, Guy L (DOA); Reed, Scott; Packer, Brett B; ALP DS Lead and Simops Coord Subject: RE: Cancellation of AI018B.003 And AI018B.005 Tom, 1/21/2010 • ~ Page 2 of 3 We have not yet brought the wells online due to rig interference while sidetracking CD2-60A (completed on 10- 18). We will be performing the post rig slickline work this week and should get the two wells on water injection by early next week. Our operations personnel will then be communicating with the AOGCC to perform a witnessed MITIA once the wells stabilize. Let me know if any additional information is required for these two wells. Thanks Tim S. Schneider Subsurface Development Staff Production Engineer WNS- Alpine ~ Phone: 907-265-6859 ~ Fax: 907-265-1515 ~~ Mobile: 907-632-8136 'I Email: _tims.schneider@conoco~hillips,com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, October 20, 2009 10:50 AM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Schneider, Tim S.; Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: Cancellation of AI018B.003 And AI018B.005 Martin, et al, Has the witnessed MIT been accomplished for either of these wells? The most recent information in our files is the sundries which were only issued - 4 weeks ago. I understand that Guy has just reviewed one of the 404s. While the work has been accomplished and the pressure tests performed while running the new completions likely demonstrated that primary integrity has been restored, your request to cancel the approvals seems premature. If the pressure tests accomplished by the rig indicate integrity, it is acceptable to resume water injection. As soon as we have all the documentation, it will time to move on the cancellations. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, October 19, 2009 1:57 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; ALP DS Lead and Simops Coord; Schneider, Tim S. Subject: Cancellation of AI018B.003 And AI018B.005 Jim/Tom/Guy, Alpine injectors CD2-48 (PTD#202-108) and CD2-56 (PTD#204-150 recently underwent workovers to repair TxIA communications rya iTve pprovals A1018B.003 and A1018B.005 are hereby cancelled. Both wells will also be removed from the monthly report. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 1/21/2010 • ~ Page 3 of 3 Pager 907-659-7000 #909 1/21/2010 Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD /UNIT /PAD: Alpine /CRU /CD2 DATE: 01 /08/10 OPERATOR REP: Gary Seltenreich AOGCC REP: Lou Grimaldi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~~ Packer Depth Pretest Initial 15 Min. 30 Min. Well CD2-48 Type Inj. W TVD 6,963' Tubing 2,035 2,035 2,038 2,038 Interval I P.T.D. 2021080 Type test P Test psi 1741 Casing 1,200 1,900 1,860 1,860 P/F P Notes: Initial witnessed MITIA post RWO OA 500 550 550 550 Observed Pretest conditions for 30 minutes- Solid Test .3 bbl Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P~F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 CRU CD2-48 1-09-10 (2).xls • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bridge Plug Setting /Radial Cutting Torch: CD2-48 Run Date: 9/11/2009 November 10, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99~ 18 CD2-48 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20422-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETLTRN~ING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-353 rafael.barreto@.halliburton.com Date: v~ ~ ~ba -~v-~ !~~'~s~ / ,~ Sinned: ~~/ 'i'~/ ~~ / ~~-- ~~~E~VED • STATE OF ALASKA • OCT 1~ zQQ9 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOI~~~a ~~` ~~as Cans. Commission enrhnrattp- 1. Operations Performed: AbBndOn ^ Repai~ Well ^~ Plug Perforations ~ Stimulate ~ Other ~ Alter Casing ^ Pull Tubing ^~ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: . Permit to Drill Number: COnoCOPhlllips Alaska, InC. Development ^ Exploratory ^ 202-108 / 3. Address: Stratigraphic ^ Service ^~ ~6. API Number: ` P. O. Box 100360, Anchorage, Alaska 99510 50-103-20422-00 KB Elevation (ft): `~Well Name and Number. RKB 52' CD2-48 . Property Designation: 0. Field/Pool(s): ADL 380075 Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: ~ Total Depth measured 13622' feet true vertical ~ 7258' feet Plugs (measured) 9700' Effective Depth measured 13622' feet Junk (measured) true vertical 7258' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 2498' 9-5/8" 2550' 2378' PRODUCTION 10022' 7" 10074' 7259' OPEN HOLE 3548' 5-1/2" 13622' 7257' PerForation depth: Measured depth: open hole completion F ~~4`'i true vertical depth: Tubing (size, grade, and measured depth) 4.5", L-80, 9600' MD. PaCkers & SSSV (type & measured depth) Baker premier pkr @ 9313', Baker S-3 premier pkr @ 947T Camco'DB' landing nipple @ 228T 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 4364 -- Subsequent to operation si -- 14. Attachments 5. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X . Well Status after work: il^ Gas ^ WAG ~^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-312 contact Liz Galiunas @ 265-6247 Printed Name L~Galiunas Title Drilling Engineer Signature -~^ `~ _ ~~ ~ Phone: 265-6247 Date /~ ~~ S"/(T ~ Z ~-~2' " ' ' r'' -'~ Pre ared b Sharon Allsu Drake 263-4612 C~/9"~--~ ~,~~~~ / ~~~~~~ /(~"~d'~~ Form 10-404 Revised 04/2006 ~( Submit Original Only . CD2-48 Well Events Summary DATE SUMMARY 9/8/09 PULLED 3.812 A-1 INJ VALVE 50' RKB, DRIFT TBG 3.80 GAUGE & TA ~ a 9587' RKB MEASURED BHP @ 8925' SLM (5161.21 PSI/ TEMP. 103.20), SET 3.725 PXN PLUG. BODY 9587' RKB, CONFIRMED SET. PULLED 1" DMY @ 9362' RKB. SEVERAL ATTEMPTS TO.SET PRONG & BAIT SUB W/ NO SUCCESS, UNABLE TO WORK PAST GLM @ 9362' RKB, PRG ASS'Y @ 9362'. IN PROGRESS 9/9/09 RECOVERED BAIT SUB & PRONG FROM GLM @ 9362' RKB, SET PRONG IN PXN PLUG BODY @ 9587' RKB, SET 4 1/2 BAIT SUB ON TOP OF PRONG FOR CATCHER @ 9580' RKB, JOB COMPLETE MOVE TO CD2-56, LRS WILL CMIT TUBING & IA TO 3000 PSI. 9/9/09 PULLED 4 1/2 BAIT SUB & PRONG @ 9580' RKB, PULLED PXN PLUG BODY FROM XN NIPPLE @ 9587' RKB TO MONITOR WELL PRESSURES. JOB COMPLETE 9/11/09 PICK UP AND HOIST A WEATHERFOR IBP IN HOLE TO DEPTH OF 9700' RKB. BLEED ~ TBG DOWN FROM 2100 PSI TO 0 PSI. RIG OFF WELL FOR SLICKLINE. IN PROGRESS ~~ G 9/12/09 SET IBP (WEATHERFORD) PLtJG. PU RIH WITH TORCH PERFORATOR AND MAKE ~a`~~p~ HOLE FOR RCT @ 9469.5'. PU RIH WITH RCT AND CUT THE TUBING @ 9469' 9/12/09 SET CATCHER @ 9587' RKB. READY FOR TBG CUT. 9/16/09 *'`**RIG JOB, DOYON 19'`**'` PULLED DB LOCK FROM 3.813 DB NIPPLE @ 9373' RKB. RAN 3.80 LIB, SAT DOWN IN DB NIPPLE @ 9374' RKB UNABLE TO WORK PAST. RAN 3.625" LIB, SAT DOWN @ 9453' SLM, LIB SHOWS JAGGED TBG ON LOW SIDE. DRIFTED THROUGH BAKER O/S WITH 3.48" CENT TO 9471' SLM. SET 3.812" DB RHC PLUG BODY @ 9374' RKB. COMPLETE. ~ ~ Conoco~'hitiips Time Log & Summary 4Ye/Iview Web Reporting Re po rt Well Name: CD2-48 Rig Name: DOYON 19 Job Type: RECOMPLETION Rig Accept: 9/14/2009 8:00:00 AM Rig Release: ' Time L' s Date Fr rrt To Dur' E' Phase ubcod T' Comment 9/13/2009 2a hr Summarv Move rig off CD2-78, Remove wind walls, Prep CD2-48 for rig 15:00 00:00 9.00 MIRU MOVE MOB P Prep rig & Move rig f/ CD2-78 to CD2-48, Move pipe shed, Pits & Motors, Jack floor to center of sub, Move sub off CD2-78, Remove Driller & Off driller side cellar wind walis, Prep CD2-48 for rig by placing 4"x12" around cellar to make level, Install well guards, Blade & Pack Pad around CD2-48, Set herculite 9/14/2009 Move rig f/ CD2-78 to CD2-48, Rig up all service lines, Accept rig @ 08:00 hrs„ Rig pump lines, Pull BPV, Circ 320 bbls 9.6 Brine, N/D Tree, N/U BOP, Ri to test BOP, Chan e out OTECO rin in choke 00:00 08:00 8.00 MIRU MOVE MOB P Move rig f/ CD2-78 to CD2-48 WO - center rig over well - Skid rig floor into drilling position - Spot motors & pits - Hook up service lines Acce t ri 0800 hrs. 08:00 09:00 1.00 COMPZ DRILL RURD P Install outter valve on annulus - RU s ueeze manifold onm ri floor 09:00 10:00 1.00 COMPZ DRILL OTHR P RU FMC lubricator & pull BPV - RD lubricator 10:00 12:00 2.00 COMPZ DRILL RURD P RU hard lines to tbg & annulus - take on 9.6 brine 12:00 13:15 1.25 COMPZ DRILL PRTS P PJSM, Fill lines & Test lines to 1500 psi - No good, Change out valve, Retest to 1500 si -OK 13:15 15:30 2.25 COMPZ DRILL CIRC P Circ well with 320 bbls 9.6 ppg Brine, Shut in well & observe we or ressure - well dead 15:30 16:30 1.00 COMPZ DRILL RURD P Rig down pump lines, Rig up lubricator, Set BPV 16:30 17:30 1.00 COMPZ DRILL NUND P Nipple down Tree, Install Blanking lu 17:30 21:00 3.50 COMPZ DRILL NUND P Nipple up BOP, Choke & Kill lines, Drains, Modify Bell nipple, Change out willis choke 21:00 00:00 3.00 COMPZ DRILL BOPE P Ri to test BOP Attempt to Test BOP - No Good - Choke leaking, Change out OTECO Ring in choke line 9/15/2009 Test BOPE w/ 4-1/2" test jt, Test all Rams & valves to 250 psi low & 3500 psi high, Annular to 2500 psi high - Test waived by AOGCC John Crisp, Pull hanger plug & BPV, M/U Landing jt, Pull hanger to rig floor, Circ full cirulation, Monitor well - OK, UD hanger, POOH & UD w/ Completion string, Clear floor, Pick & Run new com letion strin Page 1 of 3 ! ~ Time Lo s Date From To Dur S. be th E: De th Phase Code - Subcode T' Comment 00:00 00:15 0.25 0 0 COMPZ DRILL SFTY P Held prejob safety and opts meeting on testin BOPE. 00:15 05:15 5.00 0 0 COMPZ WHDBO BOPE P gU and test BOPE - Annular Preventor 250/2500 - Rams, choke, kill, manifold , TD, and floor safety valves 250/3500 psi - Perform Accumulator test - Test waived by AOGCC John Cris 05:15 05:30 0.25 0 0 COMPZ WHDBO OTHR P Pull BPV 05:30 06:00 0.50 9,467 9,434 COMPZ RPCOM PULD P MU LJa - XO to TD - Pull hanqer and tubin strin u hole to cofirm ood cut - Broke over @ 170K - PUW 165K 06:00 07:30 1.50 9,434 9,434 COMPZ RPCOM CIRC P Circulate one hole volume @ 6 bpm / 500 si - Brine wt. 9.6 in & out 07:30 08:00 0.50 9,434 9,434 COMPZ RPCOM PULD P Break out TD - LD LJa and tubing han er 08:00 18:30 10.50 9,434 0 COMPZ RPCOM PULD P POOH - LD 215 full joints 4-1(?,~', Tubing, DB nipple, GLM w/2 pups, and cutoff 'oint - no flare to cutoff - No significant scale or corrosion observed on tubin 18:30 19:15 0.75 0 0 COMPZ RPCOM RURD P Clear rig floor, Set wear bushing, Rig to run 4-1/2" Com letion strin 19:15 23:30 4.25 0 2,350 COMPZ RPCOM RCST P PJSM, Pick up jewelry, Pick up & run new 4-1/2" Completion string as er well lan 9/16/2009 RIH w/ 4-1/2" completion, Tag stub @ 7,473', Pull wear bushing, P/U landing jt "A", Space out & Land tbg @ 9,478', Set TWC, P/U landing "B" Test hanger seals to 5000 psi- OK, N/D BOP, N/U Tree & test to 5000 psi- OK, Rig HOWCO slick line, RIH & Pull RHC plug in "DB" @ 9,352' (22' diff in SLM), M/U 3.8" LIB, RIH to 9,352' - unable to get past "DB" Nipple @ 9,352', POOH & M/U 3.625" LIB, RIH & Tag up @ 9,353' SLM (Top of overshot @ 9,350'), POOH w/ LIB showed jagged marks on low side of LIB, M/U 2.79" swedge and 3.485' centralizer, RIH freely to 9,471' (15' past overshot tail), POOH UD swedge, M/U RHC plug, RIH & Set @ 9,352', POOH & R/D HOWCO 00:00 06:30 6.50 2,350 9,473 COMPZ RPCOM RCST P Continue to Run completion string total 217 joints + 2 used to tag with for spacing to 9,473' & Tag 4-1/2" Stub (Note; Did not see full 14K shear from shear screws in over shot - Only saw +/- 3K shear then was able to go another 4' appearing to swallow stub) Found stub 4.97' deep 9,473', U 165K, Dn 135K 06:30 07:00 0.50 9,473 9,384 COMPZ RPCOM PULD P Lay down 3 joints 4-1/2" tbg 07:00 07:30 0.50 9,384 9,384 COMPZ RPCOM OTHR P Make up bushing puller on landing jt "B" & Pull wear bushin 07:30 09:00 1.50 9,384 9,478 COMPZ RPCOM HOSO P Make up 2 space out pups, 1 full joint 4-1/2" tbg, Tubing Hanger & Landing jt "A", Land tubing ~,478.09', 0.79' from fully located, RILDS, La down landin 't 09:00 10:00 1.00 9,478 9,478 COMPZ RPCOM OTHR P Dry rod TWC, Pick up landing jt "B", Rig up & test hanger seals to 5000 si-OK 10:00 11:00 1.00 9,478 9,478 COMPZ RPCOM NUND P PJSM, Nipple down BOP Page 2 of 3 ' ~ Time L s Date From To " Dur' S. De th E'. De th Phase Code " Subc~de T Comment 11:00 13:15 2.25 9,478 9,478 COMPZ RPCOM NUND P Prep & Nipple up Tree, test same to 5000 si - OK 13:15 00:00 10.75 9,478 9,478 COMPZ RPCOM SLKL P PJSM, Rig up Halliburton slick line, RIH & Pull RHC lug in "DB~ 9,352' (22' difference in wire line measurements - they correlated at weil head), Make up 3.8" Lead Impression Block, RIH to 9,352' - unable to get past "DB" Nippie @ 9,352', POOH & Make up 3.625" LIB, RIH & Tag up @ 9,353' wire line measurements (Top of overshot is @ 9,350'), POOH w/ LIB showed jagged marks on low side of LIB showing rouqh cut, Make up 2.79" swedge and 3.485' centralizer, RIH freely to 9,471' (15' past overshot tail), POOH Lay down swedge, Make RHC plug, RIH & Set @ 9,352', POOH & Rig down Halliburton 9/17/2009 Rig up squeeze manifold & hard lines, Displace well over to 250 bbls 9.0 ppg brine & 70 bbis diesel, U-tube diesel in tbg & ann to 2050' MD / 2000 ND, Set pkr & test tbg to 4200 psi f! 30 min, Test ann to 3500 psi f/ 30 min, bleed tbg & shear sov, Cut & slip drlg line, P/U 130 std's 4" DP, tear out & release rig at 2400 hrs 9/17/09 00:00 01:00 1.00 COMPZ RPCOM RURD P PJSM, Rig up squeeze manifold & Hard lines 01:00 03:45 2.75 COMPZ RPCOM CRIH P PJSM, Displace well w/ 250 bbls 9.0 corrosion inhibited brin r of 3 bpm @ 500 psi Followed by 70 bbls freeze protect diesel at rate of 3 bpm @ 500 to 750 psi pumped down t owe 03:45 04:30 0.75 COMPZ RPCOM FRZP P Put tbg & ann in communication and U-Tube diesel to freeze protect weil to 2050' MD / 2000' ND 04:30 06:45 2.25 COMPZ RPCOM PACK P Pressure up to 4200 psi to set~ acker & hold for 30 min - OK, Bleed tbg pressure to 2200 psi, Pressure test casin to 3500 si for 30 min - OK, Bleed tbg to "0" and shear SOV in GLM 06:45 07:15 0.50 COMPZ RPCOM OTHR P Flush & Blow down all pump lines & manifold 07:15 08:30 1.25 COMPZ RPCOM OTHR P Set BPV & Secure well 08:30 08:45 0.25 COMPZ RPCOM RURD P Pick up & install mouse hole, Chan e elevators to 4" Drill i e 08:45 10:15 1.50 COMPZ RPCOM SLPC P PJSM, Slip & Cut drilling line 60', Service to drive 10:15 23:00 12.75 COMPZ RPCOM PULD P PJSM, Pick up and stand back 130 stands 4" drill pipe, Clear floor, Lay down mouse hole 23:00 00:00 1.00 COMPZ RPCOM DMOB P Rig down & prep to move rig Release ri at 2400 hrs 9/17/09 Page 3 of 3 ~ ~ wNs CQ~'1QtQ~1 T~~l1~!$ ~ ~+ Well Attributes %~I:iinii, ir-q:; M~ellboreAPUUWI Field N ~ 501032042200 ~ALPIN ICommant CD2-48 ~Casing Description String 0... 'IString ID _. Top (ftKB) Sat Dap[h (i_. Set Dep[h (ND) ... I, String Wt... String ... iString Top ThN ~CONDUCTOR 16 , 15.062 33.0 114.0 I 114.0 109-00 ~ H-00 ' WELD '~Casing Description 'String 0... String ID ... Top (ftK6) Se[ Depih (f... Set Depih (ND) ...', String Wt... IString ... IString Top Thrd SURFACE ~~ 95/8 8_927 36_8 2,550_0 2,378J 3600 J-55 ' BTC Casing Description String 0... String ID ... Top (ftKB) Sat DeptA (t... Set Dep[h (ND) ... String Wt... String ... IString Top Thrd I PRODUCTION 7 6.151 34.4 10,074.0 7.259.2 26.00 L-80 MBTC Casing Dascription IString O._ String ID ... Top (ftKB) Se[ Depih (f... Set Dep[h (ND) ... String Wt... Shing ... String Top Thrd ~OPEN HOLE 61/8 6.125 10,074.0 13,622.0 7.257.6 Tubing Strings Tub~in Dec~~ tl~~ii Strin< O.. SM1in ID... Top(f~K6 SetDa t~~f... Se[Depih ND ..~~Strin Wt...''Str 'SiringTOpThrd~ 9 ~ P J ~ 9 1 P ( 1. 9 9...'i 1 UEiNi 1 4 I' ~ 3S8 33.3 9,478.1 7.063 4 12 60 ~ l 80 ~ IBTM Complet~on Details _ Top Depth ~ ~ (ND) Top Inel Top (itKB) _(HKB) (°) Item Descripti on Commant . ID (in) 33.3 33~3 -0.16 HANGER FMC TUBING HANGER 4.500~1 2,286.8 ' 2,186 6 40 42 NIPPLE CAMCO'DB' LANDING NIPPLE 3.875''i 9,313.2 6,962J 52.35 PACKER BAKER PREMIER PACKER 3.870, 9,373.9 7,000.0 53J4~NIPPLE CAMCO'DB'NIPPLEw/RHCBALUROD ; 3.813 9,472.1 ~ 7,059J 51 J7 Overshot i POOR BOY OVERSHOT ~ 4.625 Tubing Description String 0... String ID .. . Top (ftK6) Set Deplh (t... Set Depth (ND) ... String Wf... String ... String Top~ThN TUBINGOriginal 4 V2 3.958 9,468.3 9,600.0 7,134J 1260 L-80 IBTM Com le tion De tails '. Top Dep~h (ND~ Top Incl ~ Top (ftKe) ~hKB) (°) ~~ Item DescTipti on I CommeM ~ ID {in) 9,4/7 1 I 7,062.8;~ 51J4 PACKER BAKERS-3PREMIERPACKER 3.875 9,480.8 7,065.1 S1J6 MILLOUT PACKER MILLOUT EXTENS~ON 4.500 9,587.4 7.128A 5803 NIPPLE I ~~.HALLIBURTON'XN'NIPPLE ~ ~~ ~~ 3J25 9,598.7 7,134.OI 58.S1 W~EG ~WIRELINEENiRYGUIDE 3.875 Other I , n Hole ( roP oev~n Wireline retrieva ble plugs, valves, pumps, fish, etc.) _ - - (TVDI ToP Incl Top(ftKe) (hKe~ _ - (°I ~es npiion _ . __ Comment - - _- __- RunDate ID(in) 9,700 7,1822I 64.03 PLUG iINFLATABLE BRIOGE PWG 9/lll2009 0.000 • Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 ~ ~~~~~~ ~ Re: Colville River Field, Alpine Oil Pool, CD2-48 Sundry Number: 309-312 ?'.; ~s,.,~,. ~..j't ~~i~'3 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~ Daniel T. Seamount, Jr. Chair day of September, 2009 Encl. ~~ ~ °t'~ • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 :. ~. ~ _"~, ~T, ; ,~ ~ ~ ~~~` ~ ~..,~ ~ ~ ~ W, ~-~ y , . _ . ~ ~ _ . .. ~ ~ _~ _ .~ 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other ~ Alter casing ^ Repair well ~• Plug Pertorations ^ Stimulate ^ Time Extension ~ Change approved program ^ Puli Tubing Q/ , Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhiliips Alaska, Inc. Deveiopment ^ Exploratory ^ 202-108 • 3. Address: Stratigraphic ~ Service ~/ , 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20422-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S ^ NO ^~ CD2-48 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380075~ RKB 52' • Colville River Field / Alpine Oil Pool . 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective ~epth MD (ft): Effective Depth ND {ft): Plugs (measured): Junk (measured): 13622' ' 7258' • Casing Length Size MD TVD Burst Coliapse CONDUCTOR 114' 16" 114' 114 SURFACE 2498' 9-5/8" 2550' 2378 PRODUCTION 10022' 7" 10074' ~259 OPEN FiOLE 3548' 6-1/8" 13622' ~25~ Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 ssoo' Packers and SSSV Type: Packers and SSSV MD (ft) Baker S-3 Packer Packer at 9477' Camco DB Nipple DB at 2050 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ~ Development ^ Service ~• 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat September 24, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q. GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Liz Galiunas 265-6247 Printed Name Chl Alvord Title: Drilling Manager Signature ~l .•--~„ Phone 265-6120 Date: 9/2/09 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness _~ Plug integrity ~ BOP Test ~ Mechanical Integrity Test ~°e Location Clearance ^ Y 3~~a fr: ~[.'`~ ~~~.... Other : ~rt +,...J~-~=.'l ~~' 1 ~j"" Z ~J ~ C` S ~ ~ , Subsequent Form Required: ~'a a~ F.~. ~ ~ ? ~ ,;'' ~_ ~~ ~~~ ~~P~'F2~'k/~~ BY ~J A IONER CO D ~ v ~ pproved by: MISS THE MMISSION ate: ~~ Form 10-403~evised 06/2~ ~~' ~' ~v ~ L S,ub~ +'t in~'~7p~~~e ., . l~l~ i ~r-Y ,. ConocoPhillips Alaska, Inc. • Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 3, 2009 ~ ~. h"' ~ t. r~,~, 'i~`~ 5 .. ~.. Fi a.~.» ~ ~° '~,.~- ~,:,-i: ,~~'' ~a ~y l~~~.; Alaska Oil and Gas Conservation Commission 333 West 7t~ Avenue, Suite 100 ::,.~ .. ~; ~~ ~ - .,~ ,~~~: ~.~ .~ ., Anchorage, Alaska 99501 Re: Sundry Permit for Workover Operations, CD2-48 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Sundry permit for well workover operations. It is intended that Doyon 19 move to CD2-48 +/- September 24, 2009. The purpose of the workover is to remediate tubing by casing communication so that the well can be put on MI injection. The plan is to cut the tubing above the packer, pull the tubing, and poor boy overshot, a new packer, and new 4-1/2" tubing string. It is expected that we will be isolated from the reservoir during workover operations with the existing packer and a plug in the tailpipe below the packer, so the well will not need to be killed. 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 10-403 APPLICATION for Sundry Approval (20 ACC 25.280) 2. Proposed operational procedure. 3. Proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out 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 Liz Galiunas at 265-6247 or Chip Alvord at 265-6120. Sincerel , Liz Gal nas Drilling Engineer • ConocoPhillips • Attachments cc: CD2-48 Well File / Sharon Alisup Drake ATO 1530 Chip Alvord ATO 1570 Lanston Chin Kuukpik Corporation • ~ Procedure • 1. Obtain SBHP. Set PXN plug in XN nipple at 9587' RKB. Set catcher sub that will pass through 3.812" nipple. 2. Pull DV @ 9363' RKB. CMIT tubing and IA to 2500 psi. Drawdown test plug by bleeding tubing and IA to 0 psi. If drawdown test passes, workover witl be done with seawater. If fails, kill weight mud will be needed. 3. Cut tubing @+/-g469' RKB (~8' above existing packer). Note pup joint above the packer is 10.05' . The cut must be below the collar on this pup joint. 4. Set BPV 5. MIRU Doyon 19 5,.~' rn`y` 6. ND tree. NU BOPE. Test BOPE 250/~ 7. Circulate well full of seawater or kill weight mud. Pull and lay down 4-1/2" tubing. Set used tubing aside until the ice road is open and the pipe can be inspected. 8. Dress off stub if necessary using 4" drill pipe ~ ~ ~.~}c ~~~,~`~ 9. PU poorboy overshot, pert pup, 3.812" D~ nipple, na d premier packer. RIH on tubing. Tubing above SSSV nipple must drift to 3.91", and all other tubing must drift to 3.843". Purpose of the perforated pup is to aid in circulation. 10. Go over stub. Space out and land tubing. 11. ND BOP. NU and pressure test wellhead. ~ ~~:~ ~~/,~,~ 12. Circulate wellbore full of corrosion inhibited seawater. Pump diesel freeze protect in IA. Set packer. 13. Pressure test tubing and IA. ~~~~ 14. Freeze protect well 15. RDMO Doyon 19 16. Pull ball & rod. Run new GLD. Pull RHC body. Pull plug at 9587' RKB. + c ar~~c.. S~.r3 d,`~ f • V• ~~ `r ~ ~ ~ Completion Schematic: CD2-48 Workover Schematic ~ ~s°Conductorto114~ Updated8/3/09 4-1/2" Camco DB Nipple (3.875") at 2196' ND = 2300' MD I 9-5/8" 36 ppf J-55 BTC SurFace Casing @ 2550' MD / 2379' TVD cemented to surFace U~per Completion: TOP MD ND Tubing Hanger 32' 32' 4-'/2', 12.6#/ft, IBT-Mod Tubing 4-'/z" Camco DB nipple (3.875") 2300' 2196' 4-'/z', 12.6#/ft, IBT-Mod Tubing Camco KBG2- GLM (3.909" ID) 9342' 6980' 4-1/2" 12.6 ppf L-80 IBTM 4-'/2', 12.6#/ft, IBT-Mod Tubing (1) tubing run with Jet Lube Run'n'Seal 8aker Premier Packer 9390' 7009' pipe dope 4-'/2', 12.6#/ft, IBT-Mod Tubing (1) 4-'/2' Camco "DB" nipple (3.812") - 62° 9440' 7040' "poor boy" over shot with perforated pup 9444' 7042' Bottom of "poor boy" over shot w/pup 9450' 7046' Lower Completion: T P MD TVD 4-'/2', 12.6#/ft, IBT-Mod tubing stub 9446' 7044' Baker S3 Packer w/ millout extension 9477' 7063' 4-'/2', 12.6#/ft, IBT-Mod Tubing (1) HES "XN" (3.725") 9587' 7128' 4-Yz', 12.6#/ft, IBT-Mod 10' pup joint WEG 9599' 7134' Camco KBG-2 GLM (3.909" DRIFT ID) w/ dummy ;. Baker Premier Packer 3.813" DB nipple, with RHC plug, Perforated pup, and overshot assembly 0 00 ~ ::::: :::::::::::::ii:i:::i:i:;:;:. °° Baker S3 Packer W/ millout extension @ 9477' MD ~ ConocoPhillips Alaska, inc. TUBING (0-9600, OD:4.500, ID3.958) SURFACE (0-2550, OD:9.625, Wt:36.00) ~RODUCTION ~o-, oo~a, OD:7.000, wt:2s.oo> PACKER (9477-9478, OD:5.970) PLUG (9584-9585, OD:4.500) NIP (9587-9588, OD:5.000) OPEN HOLE ~ ' ;7007413622, OD:6.125) . 1 1 ~ ALPINE CD2-48 Angle ~.3SZ RnNnm ~~ 4.500 0 9600 7135 12.60 L-80 IBTM I Gas Lift Mandrels/Valve s ' St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 --- - 9362 - 6992 CAMCO KBG-2 DMY 1.0 BK 0.000 0 5/5/2007 r Other lugs e ui . etc . - COMPLETION De th ND T e Description -- ID 2050 - 1999 - NIP - CAMCO LANDING'DB' NIPPLE 3.812 9477 7063 PACKER BAKER S-3 PACKER 3.875 9584 7126 PLUG 4.5" XN PLUG set 5/4l2007 0.000 9587 7128 NIP HES'XN' NIPPLE 3.725 9600 7135 WLEG BAKER WIRELINE GUIDE 3.875 General Notes Date Note 5/7/2007 NOTE: LEAK 9479' 7/7/2007 NOTE: WAIVERED WELL - T x IA ANNULAR COMMUNICATION I ! - - - - - -- CD2-48 (PTD 2021080)MIT-T~ IT-IA Test form. Page 1 of 1 e Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com~ Sent: Friday, January 16, 2009 10:57 AM ~~~ 1 ~.~~-~~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert~J ~DO ); DOA AOGCC Prudhoe Bay Subject: CD2-48 (PTD 2021080)MIT-T /MIT-IA Test form. Attachments: MIT CRU CD2-48 01-15-09.x1s Tom, Jim, Bob. Attached is the MIT test results from 01/15/09 for CD2-48 per AIO 186.003 «MIT CRU CD2-4801-15-09.x1s» Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ,.~. ~., fn ik ... 1 /22/2009 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD (UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Alpine /CRU /CD2-48 01 /15/09 ~~ ) ~2,~~'ZC.`~ 1 Peck / HES Waived right to be present by John Crisp. Packer Dep Pretest Initial 15 Min. 30 Min. Well CD2-48 Type Inj. W TVD 7,063' Tubing 2,100 2,100 2,100 2,100 interval V P.T.D. 2021080 Type test P Test psi 1766 Casing 2,100 "3,000 3,000 ,000 P/F P Notes: MIT-IA per A1018B.003 OA 450 450 450 450 Well CD2-48 Type Inj. N TVD 7,063' Tubing 2,150 ,050 3,050 ,050 Interval V P.T.D. 2021080 Type test P Test psi 1766 Casing 2,050 2,125 2,125 2,125 P/F P Notes: MIT-T per AIO 188.003 OA 50 50 50 50 Plug set @ XN Nipple 9587' Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test .- INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT CRU CD2-48 01-15-09.x1s ~~ Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, September 04, 2008 2:14 PM 2~~ To: 'NSK Well Integrity Proj ; 'NSK Problem Well Supv' 4 Subject: CD2-48 (PTD 2021080) MIT Due Date Brent - re: Admin Approval AIO 186.003 Colville River Unit CD2-48 • ~~~,~~~~ Page 1 of 1 per our phone conversation today, the anniversary date for compliance with MIT requirements in AIO 186.003 is 1/15/2007 (next due 1/15/2009). Some of the early admin approvals were not specific about the anniversary date for MITs; unfortunately this is one of them. The Commission tracks the due dates in our database and we entered the date of the MIT performed as support for the approval. This is consistent with the current approach used for setting the MIT anniversary date in admin approvals. will attach a copy of this note to the Commission's admin approval file. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 sL~N~~ ~FP ~ ~ ~~~$ 9/4/2008 ?;;/ 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 $C'ANNED APR 2 7 7ßGl à0;)...- \ 0 8 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, ~.~~~/ ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31,2007 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 Qal 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 1 318/2007 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 CD2-21 204-245 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 CD2-30 203-135 8" na 8" na 3 318/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 318/2007 CD2-33 201-125 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 CD2-44 202-165 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 CD2-48 202-108 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 1.5 318/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 " . . ~ ConocoPhillips Alaska /2\p j:j "7 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 E, March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 sCANNED APR 0 9 2007 Anchorage, AK 99501 {P'lO'Ò dP Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ftom the Alpine 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 ftom 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, ~----f 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 CD2-48 202-108 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 1 318/2007 Alpine Field March 31,2007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commissio TO: Jim Regg P.I. Supervisor '~"" /~. C' ./' ?~'I' /:'1" ~// I '-' ,:::t....; ~~ 7~1 ¡ L L DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-48 COLVILLE RIV UNIT CD2-48 ~ ~....\O ~b~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 5Bi2- Comm Well Name: COLVILLE RIV UNIT CD2-48 API Well Number 50- I 03-20422-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060828 144753 Permit Number: 202-108-0 Inspection Date: 8/26/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-48 Type Inj. G TVD 7063 IA 1450 2450 2440 2440 P.T. 2021080 TypeTest SPT Test psi 1765.75 OA 750 850 850 850 Interval 4YRTST P/F P ./ Tubing 3850 3850 3850 3850 Notes Pretest pressure observed and found stable NON-CONFIDENTIAL SCANNED SEP 0 B 2006 Wednesday, August 30, 2006 Page I of I • - }~ --~ ~~ ITY IZ ORT " M ' ~~ d1 ~ C:3ANICAL INTEGR .~ ~ `_~~' OPER ~ FIELD U D u: T ~ : ~ ~~ ~ ~ ~~ ~ `V ~~~~ \L.\~ ~ ~ : _ , -- .G r ...~~~ ~C . ~ ~ l~ ~ ~~LL NITrffiER ~`~ ~-- ~~~ ~c7S~ TVD ; = n ~ LL DAT_ ~_ TD : ~~~~- 2~ -- BTD : ~~~c~~- PID ~~ ~ S "T'VD .. . Cos i^ g ~ Shoe : ~~~1~{ t•ID TVD ; i~V . ?~ -?'44i3 =f:,e= . 1J~4 Shoe : ~ '?'VT ; .:.Cr . '_•~ ~'iD =ubi~S ~~ P2CKer ~ty~l~ :~ TVD; het et `1~~'l./ =ale S«e ~ o~ and ; Perks 'T +r~„_ to ~~ k ": ~L'r'.t~?~_C~TJ ItITEGR?TY - P?.RT # nnu:zus ?ress Test: IB ? 5 min ~0 min Cor.~ents ;®~~~~ Noy "t~k ~ ~200~ . :-~'* CHpNIC?_I.. INTEGRTT`~ - PART # 2 ~-~ ~~~j~,jtS Cement Volumes :. Amt. Liner ; Csg ~; DV C~,t Jol to cover aer=s C ~~~ Il•~ \`= ~~`~.~ ~~~~ %~ "~ C~^`~;c ~ -^ t ' 7S _:.eoret:~.cal TDC ~ ~~~.'~.. ~~\ ~- ZS 11~ . Cement Band Log (Yes or No) l'Cti ~% ~-~ ~9 ; In AOGCC File C9L Evaluation, zone above perfs 1r,~~~ ,~~~~,L~ ~ ~~sypr,~_ - r ~ Production Z.og: Type Evaluation LOI+IGLJS10taS : ~~~~e :~ ~-.~~~~ r`~r`.y.~,,~P~ ~~i~ ?art #I. ?ar~ l2: • • Maunder, Thomas E (DOA) From: Clifford L Crabtree [ccrabtr@ppco.com] Sent: Thursday, July 11, 2002 9:27 PM To: Tom Maunder Cc: Vemon T Johnson Subject: Re: CD2-48 bond log results Attachments: tom_maunder.vcf tom_maunder.vcf (2 KB) I looked back at 2- 46, it showed cement that appears to have not developed strength as quickly as the rest. I've no reason to call it gas. Well 48 was clearly anomolous. There was a local reservoir oddity that created a gas saturation in the fault system we drilled through. We do not believe this will be problem in other injectors at this time. BTW, What's the status on our request for clarification on the Alpine SSV's? Cliff Crabtree Phillips Alaska Inc.- Alpine Subsurface Development Office: {907) 265-6842; Cell: (907} 240-5357 Email: ccrabtr@ppco.com; Fax:: {907) 265-1515 Tom Maunder <tom maunder@admin.state.ak.us> 07/11/2002 12:38 PM To: Clifford L Crabtree/PPCO@Phillips cc: Vernon T JohnsonfPPCO@Phillips Subject: Re: CD2-48 bond log results Cliff and Vern, I was doing some filing and found the bond log comments for CD2-48 were similar to those for CD2-46. In both cases the good cement was seen from the top of the Alpine up. Have there been any other injectors that have exhibited this?? Tom Clifford L Crabtree wrote: > The CD2-48 cement bond log suggests satisfactory isolation on the injection > interval. > The tools fell to 9,840' MD (7178' SS), which is at 74.9 degrees hole > angle. The top of the Alpine C Sand is at 9,734' MD (7,144' SS) and > 67 degrees hole angle. We logged cement from the tubing tail (9600' > MD/ 7082' > SS) to the top of the Alpine (9734' MD/ 7,144' SS). Due to diesel in > the annulus, the log showed poor cement from the tubing tail (9600' MD/ 7082' > SS) to 9647' MD/ 7106' SS. The SCMT indicates an excellent cement Boa-~~~ 1 • • > bond of > 87' from 9,647' MD/ 7106' SS to the top of the Alpine at 9,734' MD/ 7144' > SS. Given this depth of cement, we have good quality cement from the > top of the Alpine through the confining shale above the hydrocarbon zone. > The packer was set at 9,477' MD/ 7,010' SS, which is 134' TVD above > the hydrocarbon zone. The casing shoe is at i0, 074' MD/ 7,208' SS. > After consulting with Schlumberger, the cement from the 7" shoe to the > top of Alpine portrays gas imbedded in the cement. When drilling this > well, we encountered gas cut mud at 9,844' MD and its presence > continued to casing point at 10,085' MD. With this said, I believe > that we have satisfied the > 50' of quality cement requirement that must be placed above the hydrocarbon > zone to the confining shale. Attached is the electronic copy of the CD2-48 > cement bond log that may be viewed with the Schlumberger PDS viewer. > As to the placement of the cement, pipe was reciprocated during the > job, the wiper plug bumped and floats held OK. There was no lost > circulation noted during the job. > Please give me a call if you have further questions. We would like to > place this well on injection over the coming weekend. > Best Regards, > Cliff Crabtree > Phillips Alaska Inc.- Alpine Subsurface Development > Office: (907) 265-6842; Cell: {907) 240-5357 > Email: ccrabtr@ppco.com; Fax:: (907) 265-1515 > (See attached file: CD2-48~SCMT_Combo.zip) ------------------------------------------------------------------------ > Name: CD2-48 SCMT Combo zip > CD2-48 SCMT Combo.zip Type: Zip Compressed Data (application/x-zip-compressed) > Encoding: base64 (See attached file; tom maunder.vcf) 2 • ~ ~~~ ~ ~ o d a SARAH PAL/N, GOVERNOR ~S~ O~ ~ ~S 333 W. 7thAVENUE, SUIFE 100 C011TSERQ~TI011T COl-II-'IISSIOR ANCHORAGE, ALASKA 99501-3539 i PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Perry Klein Problem Well Supervisor ~ :~~~~eU.a ~ I,.~ ~ `; ConocoPhillips Alaska, Ind' P.O. Box 100360 Anchorage, AK 99510-0360 RE: CRU CD2-48 (PTD 202-108) Request for AIO 18B.003 ~~ `~~~ ~\ l~~ pproval ~ +~ °-' Dear Mr. HIein: Per Rule 11 of Area Injection Order ("AIO") Conservation Commission ("AOGCC" or ConocoPhillips Alaska, Inc. ("CPAI")'s reques continue water injection in the subject well. 018.B, the Alaska Oil and Gas "Commission") hereby grants t for administrative approval to AOGCC finds that CPAI has performed diagnostic testing on CD2-48 and confirmed pressure communication from the tubing to inner annulus. CPAI has determined that a workover is necessary to eliminate the pressure communication. At this time, the workover has not -been scheduled. The Commission further finds that, based upon reported results of CPAI's diagnostic procedures, CD2-48 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in CRU CD2-48 is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. CPAI shall monitor and record wellhead pressures (TjI/O) and injection rate daily; 3. CPAI shall submit to the AOGCC a monthly report of well pressures and injection rates; 4. CPAI shall demonstrate continued tubular integrity by performing an MIT-T and MIT-IA every two years to 3000 psi; Administrative Approval AIO 18B.003 February 12, 2007 Page 2 of 2 5. CPAI shall immediately shut in the well and notify the AOGCC upon any measurable change in well outer annulus pressure; and 6. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown., a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission d~ion to Superior Court unless rehearing has been requested. at ~icypr~(.ge, Alaska and dated February 12, 2007. . Norman Daniel. T. Seamount. Jr. Ch ' Commissioner F ~' ~~.~~ N b. .~, ,:. ~~ ~ ,. .1 Cath P. Foerster Commissioner • • • ~onocoPh i I I' ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 20, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~t -~ ~ ~~~~, Dear Mr. Maunder: Enclosed please find the Administrative Relief Request for ConocoPhillips Alaska, Inc. well CD2-48 (PTD 202-108). Please call Marie McConnell or myself at 659-7224 or MJ Loveland /Jerry Dethlefs at 659-7043 if you have any questions. Sincerely, Perry Klein Problem Well Supervisor Attachments ConocoPhillips Alaska, Inc. Alpine Well CD2-48 (PTD 202108) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc., proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue water only injection with known annular communication for Alpine injection well CD2-48. Well History and Status Colville River Unit well CD2-48 (PTD 202108) was drilled and completed in June 2002 as a WAG injection well. CD2-48 was converted from MI injection to Sea water on 10/29/06. On 11/26/2006 the well was shut in and T x IA communication was reported to the AOGCC. On 11/28/2006, with the well shut in, an MITIA passed @.2500 psi. While shut in, the tubing and inner annulus did not equalize, continually maintaining 500 psi or greater differential pressure. The passing MITIA was submitted to AOGCC on 17/7/2006 along with a verbal request to restart injection to further monitor and test the well. AOGCC approval to restart injection was received on 12/11/2006 and the well was placed on water injection 12/12/2006. While on injection the well began to show signs of T X IA communication. On 1/15!2007 an MITIA to 3500 psi passed. CPAI notified the AOGCC of the wells status on 01/18/2007 and submitted the passing MITIA. The well is currently on injection and is maintaining a 260 psi differential pressure from the tubing to the IA. The well will require a workover to repair. Barrier and Hazard Evaluation Tubing: The 4-1/2" 12.6# L-80 tubing has integrity to the packer at 9477' MD based on a passing MITIA performed on 1/15/2007. Production casing: The 7" 26# L-80 production casing has integrity to the packer @ 9477' MD based on the MITIA described above. The well passed a witnessed, 4 year MITIA on 8/26/2006. Surface casing: The well is completed with 9-5/8" 36# J-55 surface casing with an internal yield pressure rating of 3520 psi. The surface casing is set at 2550' MD (2379' TVD). The well has an open shoe and maintains pressure integrity to 1100 psi. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Third barrier: The surface casing and cement shoe will act as a third barrier should the first two barriers have failures. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing, production casing, or surface casing it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including ashut-in of the well. T/I plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. NSh Problem Well Supervisor l /20/2007 .- Approved Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or NII allowed); 2. Perform a passing MITIA every 2-years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum); 3. Submit monthly reports of daily tubing & IA pressures and injection volumes; 4. Shut-in the well should MIT's or injection rates and pressures indicate further problems; 5. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification. NSK Problem Well Supervisor 1/20/200? . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs_ Inserts\Microfilm _ Marker.doc J~ JÜJ~ Å ~(){ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 Permit to Drill 2021080 Well Name/No. COLVILLE RIV UNIT CD2-48 Operator CONOCOPHILLlPS ALASKA INC MO 13622 ~ ---------------- -- "------------ TVO 7258./ Completion Date 6/13/2002 ~ Completion Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No --- ------ ---- - --------- DATA INFORMATION Types Electric or Other Logs Run: GR/Res/PWO Well Log Information: Log/ Data Digital Type Med/Frmt - -- ---. , Leg..-- : Lð; ¡~ :~-D , ~- ~D : .1.Qg..--- t39~- Uog , 'tõ9 uÆÓ D Rpt ED ca- Pdf (J:-og-- :L~ i_~-- - --------..----- Electr Dataset Number Naß1e - -----c.e-éÍÍ1ent Evaluation t;Jnperature ~ssure Log Log Ru n Scale Media No 5 Col 1 5 5 Col Col J)jféctional$urvey ,Pi!ectionalSÜrvéY 11 000 ~ection Profile c.IfIjéêfion Profile (jPje'étion Profile ~sure 5 BM Blu Blu Blu ~ng collar locator 11189 t!)8'\Íerification LIS Verification 11349 See Notes ~peratu"e ~mma'Ray Blu Blu Well Cores/Samples Information: Name Interval Start Stop Sent Received Current Status 1WINJ >/1 V\ ¿ :2- Co{ M~ .z U () 1.- API No. 50-103-20422-00-00 -7). ~~..' ~/ Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop 0 9834 0 9834 OH/ CH Received Comments Case 8/9/2002 Case 8/9/2002 Case 8/9/2002 0 9834 0 13622 Open 7/10/2002 0 13622 Open 7/1 0/2002 9768 12375 Case 8/16/2002 9768 12375 Case 8/16/2002 9420 13550 Case 8/26/2002 With Warm backs 9420 13550 Case 8/26/2002 9420 13550 Case 8/26/2002 10049 13622 ~ 10/15/2002 1 0049 13622 Case 1 0/15/2002 2530 13622 ~ 11/6/2002 Digital Well Log data 9420 13550 Case 8/26/2002 9420 13550 Case 8/26/2002 Sample Set Number Comments -- Permit to Drill 2021080 MD 13622 TVD 7258 Well Cored? ADDITIONAL INFORMATION yf0 Chips Received? ~ Y I N Analysis Received? ~v-tN--- Comments: . --- --- -- -- -----~-- - -- -------- ---- - ------------ ----- --. ------- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 Well Name/No. COLVILLE RIV UNIT CD2-48 Operator CONOCOPHILLlPS ALASKA INC Completion Date 6/13/2002 Completion Status 1WINJ Daily History Received? Formation Tops ~ API No. 50-103-20422-00-00 Current Status 1WINJ &/N 6JN Date: UIC Y -- 2.G JJS ~1 ~ Alpine Cement Top Fill '') 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 } 4/24/20037:55 AM Alpine Cement Top Fill <- ,,,' . .., ....... ,.,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 ,...,........,.....#.,...................."...........................................................,....................".......,...................................................,..,...................,..".....................,.....,..,.....................'''''0''''''''''''''''''''''''''''''''''''''''''''''''''''''''"""""''''''''''''''''''''''''''''',..............,.."...............,,'''''''''''''''''''''''''''''''''',...........,..,......................................................... ..... .. \ . ".. """"""'"',1,"'''.1 \'" 'W"'" . ,.. ".. L', . ".\ 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 "VI,I,' . ,- AV." "/A_" '-,--,,,,,"', VH_' -,-, N--' "\-,, "W 'V.M . \w- ,,- -w /O'A ,,-, W II'. 1/ _,n _Iw.. . i. \- -,- . A vi. -_'I"A r v. --, rom Maunder <tom maunder@admin.state,ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 4/24/20037:55 AM ',) Conocó'Phillips Alaska ) 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 16t\ 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 ) ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 " i \ \ ~ S.- ().~ (qn__J ;J'CD-\~) DEPTH VOLUME TYPE SACKS "-----"----'-'--'-' ---,-------_._-- 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 -- -.- --- CD1-17 8.75' 1.2 P 7.2 - ------_.- CD1-21 13' 1.8 MI 10.9 -'--'--------"---"--------"""'---- ------_.---------- CD1-22 1.83' 0.3 P 1.8 -.----.--.-- ---- 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 dOf:.r~~ _fD1-27 18.8~:._.__._- 2.6 P _!5.L- CD1-28 6.75' 1 P 6.0 - -'--"'.---'.""-"--- --- --- \ C\ ~-\ Ol{_Ç.!?_1-3~_____~~-~-~:.._--_. ---_._.J.~.~._------~- 7.?_- JaQ'-l)~~ -çQ1::?~-___~J.83' 5.7 P ----~_i.~- .. .. -.... l<;S-\\) CD1-36 16.75' 2.3 WI 13.9 ..--.-.-.----..".----. -----.---- -.--.------.----..-..---- -----~._-----_._.. -------"- ;jC:f:J--OO"3>- -~~-=~-~_._---_..~~-'-___.__m.. ____9~~.___._-_._----_r:_------------~~Q--- , \~~-\\<; _Ç_121-42 .___§~~L__.--___.g~---- MI 4.8 d\:h),.,,-\..~~ . '6 ._- CQ2-16 _.__1.1:§~:___------- 1.6 I~~__- 9.7.._.- ð-\ ~ d ! ;)O')-c:,\ g~~~~ ~ 111.~~- ~:~ --_!.~~-------'--~~:l--. . ;)fJ . JtJd-t3'\) ~ i¿¡)?:??_==I3:~'=~:~.==-~ß':--===Jg[==Jp]l-= död~~ '-\ : CD2-~~___._--_?.?~?§~-- ~J_._...__J:_-__.___n_?2.3 J{9~")~ JD \ - ð'.1/~_~~~;~-==::1_~12'~_~=~~ ;~-~~=-_:~J===.~=l~ \ ;fO \ - \)iJ_c:.~?:~.:: ---~J~---- ~~-_!_~----~~ ~~_-.f'_----~~ dO - -\ ~ \ lo _ÇD2-34 --~-----~~- P_---- 3.6 '6"ð JO:}.\'}- ... CD2~- _-..l1c8L___J:6 ~. -~____~.7 JO"ð ~() t;ù"d-\O <tJ =~~6§;:~~- =-lÓ~3~'=-:~.=J:4 .~_~~_fÑL=::__~~~== :;0\""d"\C1 __gQ2-L!_~ ---~.:.~-~~----------_!~-----_-.!~~----_.__X=-8____- : d D d-tl~ CO2-50 1.66' 0.25 P 1.5 WEllS \~<;,-\~O :'dOO-~\. '( \~c:.,- \à<6 . :;j:.:{)-O~3> \ ~C;-o~L\ : ; dÖO.. \4Ç d 0\- OG(o I \c; ~- ã-S~, ,-;<;,-()(Ow3> JOO... \ \ Ù . \~" .-t» c... d r:Þ.-.f$)~ (i d 00- \'-t " "\7 d-O \ - \ d- \.-\ Jb\-\ð 5 ~J)~-16~ Annular Disposal during the third quarter of2003: 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 CD2-41 19560 100 0 19660 377 4000 24037 June 2003 July 2003 CD2-20, CD2-55 3S-17A 2133 100 0 2233 361 4659 7253 June 2003 July 2003 35-19 Hansen 1 2498 100 0 2598 0 115278 117876 January July 2003 Hansen 1, Hansen 1A 2002 CD2-38 29522 100 0 29622 389 0 30011 July 2003 Sept 2003 CD2-40, CD2-30, CD2-55 IB-20 36655 100 0 36755 0 0 36755 July 2003 Sept 2003 1B-102, 1B-101 l, CD2-23 22140 100 0 22240 377 0 22617 Sept 2003 Sept 2003 CD2-18, CD2-55 Total Volumes into Annulifor which Disposal Authorization Expired during the third quarter 2003: Freeze Protect Total Volume Fluids Injected Volume 371 380 375 Total h(l) Total h(2) Total h(3) Well Name Volume Volume Volume CD2-46 31393 100 0 CD2-22 30773 100 0 Start Date End Date Source Wells 31525 0 31864 31253 32000 Status of Annulus Open, Freeze Protected Open, Freeze Protected CD2-48 100 Open, Freeze Protected April 2003 May 2003 February March 2003 2003 December February 2002 2003 CD2-51, CD2-12 CD2-08, CD2-36, CD2- 51 CD2-45, CD2-35, CD2- 08, CD2-28 ! RECEIVED OCT 2 3 2003 Alaska Oil & Gas Cons. Commission Ancbora,Q£ 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, 3S-16, 35-22, 3S-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Dec 2002 Jan 2003 3S-10,3S-15,35-09,3S-14 CD2-48 20144 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 3S-21, 3S-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 Total Volumes into Annulifor which Disposal Authorization Expired during the first quarter 2003: Freeze Protect Total Volume Start End 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 CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 2002 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October 2002 2002 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 Source Wells 2P-427, Heavenly CD2-13, CD2-37, CD2- 35 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-38, CD2-44, CD2- 29, CD2-13 CD2-50, CD2-46, CD2- 22 ,~ECEIVED APR 1 6 2003 Alaska Oil & Gas Cons. Conmission ~ Anchorage { Qj e ~ 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 nJ () Volumes (C) 3S-18 31501 100 0 31601 306 0 31907 January March 3S-I5, 3S-I6, 3S-22, 3S-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Dec 2002 Jan 2003 3S-I0, 3S-I5, 3S-09, 3S-I4 CD2-48 20144 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, CD2-5I 2003 3S-10 21104 100 0 21204 388 0 21592 March March 3S-2I, 3S-08 2003 2003 1 C-22 26944 100 0 27044 0 0 27044 March March IC-190,IC-174 2003 2003 Total Volumes into Annulifor which Disposal Authorization Expired during thefirst 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 C02-I3, CD2-37, CD2- 2002 35 ) 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P-44I, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October C02-38, CD2-44, CD2- 2002 2002 29, C02-13 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 CO2-50, CD2-46, CD2- 22 .. ') Randy Thomas Greater Kuparuk Team Leader Drilling & Wells é),od-)()<{ ConocóP'hillips 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-L . \~ \,~ 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 RECEtVED 1 "t\1 1 r~ _2003 . ..1-.:, 1.) ÞJaska Oil & Gas Cons. Comm\ssion .!\nchor8fÁ8 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 Dec 2002 CD2-13, CD2-37, CD2-35 CD2-48 11281 100 0 11381 375 0 11756 Dec 2002 Dec 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 ~~ Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2002: 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, CD2- 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 Cook Inlet Annular Disposal during the fourth quarter 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 Hansen #1 472 100 0 572 0 67224 67796 January October Hansen # 1 2002 2002 13L/q 116LJ~ /341 I 3c) lo 13LJ5 II 34 Y \ ) dO a-lOr; . aoa~o~~ dDd- Qô?'1 ~D( -03d c:< D d-I! Ä ¿;¡ Od-O ( S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tlt Avenue, Suite 1. 00 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 06 2002 Alaska 0;1 & Gas Cons. CoI11ßU88im Anchorage ) ') aoa-Jog III '6; WELL LOG T:RANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 October 11, 2002 RE: MWD Formation Evaluation Logs - CD2-48, AK-MW-22085 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#: 50-103-20422-00. ¿frP-~ RECEIVED OCT 1 5 2002 AI- OH & Gas ~ Collllni8llt/n ) \ G. C. Alvord , Alpine Drilling Team Leader Drilling & Wells ConocJ'Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 September 12, 2002 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-48 (202-108) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-48. If you have any questions regarding this matter, please contact me at 265-6120 or Vern Johnson at 265-6081. Sincerely, ./L- L Qt^-- G. C. Alvord Alpine Drilling Team Leader Conoco Phillips Alaska Drilling GCA/skad ,f') r" I''''' ï-ï" ~ '" ¡ ~'--', [;"'10, ~\"', ~ ~ ,~¡ "~ ;;~, ~ \, , " ,.',.. ß .", '.¡. :¡:~) '~,,:,.,,: :. '''. ~. '.. 1IIo.J... r" ,.--," ~ì . ("'¡'Ion') :jt.r ;.. ".." iit. " .:-" :,". .~"' ~;.,': I;:~,~ "',~' ~b.: '~~) t\nehnrHlJ8 «" [-) !,~ ~ ~ ~:1' 1 i 3 ¡'I:" :1:' ",","" II J~' ,'\ / '\ U Q\ ~ t.J ~ ¡ '0 r" r- ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Oil 0 Gas 2. Name of Operator Phillips Alaska, Inc. 3. Address 0 0 Abandoned 0 Service 0 Suspended Classification of Service Well WAG Injector 7. Permit Number 202-108/ 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20422-00 4. Location of well at surface i-:--"-__M'':"''-f 9. Unit or Lease Name 2043' FNL, 1505' FEL, Sec. 2, T11 N, R4E, UM (ASP: 371731, 5974311) GOi'.r~~::~¡OM ~ F~:?ë'7!~?"::"" ;' Colville River Unit At TO~ Producing I~terval . t-€l&~~ } \'i.¡,';i': ~o, Well Number 2558 FNL, 2545 FEL, Sec. 11, T11N, R4E, UM (ASP. 370598,5968 9.) VEFiiB, " æ,,!tj~- JSU¡1j::~i CD2-48 ~~~~~~~~P;:2' FEL, Sec. 14, T11N, R4E, UM (ASP: 372304, 5965058) ~~~t!:£.t~111'~~~~~I:~~:: Field 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Alpine Oil Pool RKB 33' feet ADL 380075 12. Date Spudded 13. Date T.D. Reached 14. Date Comp" Susp. Or Aband, May 29, 2002 June 11, 2002 June 13, 2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 13622' MD /7258' TVD 13622' MD / 7258' TVD YES 0 No 0 22. Type Electric or Other Logs Run G R/Res/PW D 23. 15. Water Depth, if offshore N/ A feet MSL 20. Depth where SSSV set 2050' Landing Nipple CASING SIZE GRADE H-40 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2550' Surface 10074' CEMENTING RECORD 10 cu yds Portland Type 3 364 sx AS III Lite, 237 sx Class G 160 sx Class G HOLE SIZE WT. PER FT. 62.5# 36# 26# 42" 16" 9.625" 12.25" 8.5" 7" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 4.5" TUBING RECORD DEPTH SET (MD) 9600' 16. No. of Completions 21. Thickness of Permafrost 1556' AMOUNT PULLED PACKER SET (MD) 9477' open hole completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. Date First Production not applicable Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL Test Period> Calculated GAS-MCF N/A Flow Tubing Casing Pressure OIL-BBL GAS-MCF press. 28. psi 24-Hour Rate> CORE DATA WATER-BBL CHOKE SIZE W A TER-BBL OIL GRAVITY - API (corr) Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A ~BOMS BFL ./ \.:J \'-'" Form 10-407 Rev, 7-1-80 CONTINUED ON REVERSE SIDE ,-.. ~~~ \' Ii ~ [,.' 1\ \.../ ~ .... , l ~~: :~~~' t'~ ~~- ~ ~jt,r~ -~ GAS-OIL RATIO r :'Jf~t(') r' . I,Ll" ~" ,';..'.', \:. I' ~...¡ .' : ), ! ,j ~ .' '\ Il..- SEP 2 3 2002 Submit in duplicate 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME CD2-48 Top Alpine D Top Alpine C 9686' 9734' 7177' 7196' (i ~' !1". ~ ~ "I, ,;~.¡I, f: rlrlW,r:. 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 Signed #4t.- ()(.l Chip Alvord Title Alpine Drilling Team Leader Date .it ''> /ðL- 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 1 0-407 /'~ [ t r . f "-.) \ l t- ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/28/2002 5/29/2002 5/30/2002 5/31 /2002 ) ) PHILLIPS ALASKA INC. OperationsSumrnary .Report CD2-48 CD2-48 ROT - DRILLING doyon1 @ ppco.com Doyon 19 Sub From.. To Hours Code Code Phase 16:00 - 00:00 00:00 - 01 :00 01 :00 - 02:00 02:00 - 04:30 04:30 - 06:00 06:00 - 07:30 07:30 - 08:00 08:00 - 09:30 09:30 - 10:30 10:30 - 12:00 12:00 - 14:00 14:00 - 15:00 15:00 - 16:00 16:00 - 17:00 17:00 - 00:00 00:00 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 15:00 15:00 - 16:30 16:30 - 19:00 19:00 - 21 :30 21 :30 - 22:30 22:30 - 00:00 00:00 - 02:30 8.00 MOVE MOVE MOVE 1.00 MOVE POSN MOVE 1.00 MOVE POSN MOVE 2.50 DRILL RIRD RIGUP 1.50 DRILL PULD SURFAC 1.50 DRILL OTHR SURFAC 0.50 DRILL DRLG SURFAC 1.50 DRILL TRIP SURFAC 1.00 DRILL DRLG SURFAC 1.50 DRILL TRIP SURFAC 2.00 DRILL DRLG SURFAC 1.00 DRILL TRIP SURFAC 1.00 DRILL OTHR SURFAC 1.00 DRILL TRIP SURFAC 7.00 DRILL DRLG SURFAC 12.00 DRILL DRLG SURFAC 1.00 DRILL CIRC SURFAC 1.00 DRILL WIPR SURFAC 1.00 DRILL TRIP SURFAC 1.50 DRILL REAM SURFAC 2.50 DRILL TRIP SURFAC 2.50 DRILL PULD SURFAC 1.00 CASE RURD SURFAC 1.50 CASE RUNC SURFAC 2.50 CASE RUNC SURFAC Page 1 of 8 Spud Date: 5/29/2002 End: 6/13/2002 G rou p: Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: 19 Description of Operations Move rig f/ CD2-22 to CD2-48 - Install 20" H ydrill - Spot & level rig Level sub & skid f I 0 0 r over well Move in & spot pit & motor complexes Accept Rig @ 0200 hrs. - hook up diverter a nd connect mud lines, install riser, test div erter wI 5" HWDP - tag ice plug @ 73' MU bit, motor, NM pony DC, NM stab, NM po ny DC Pre spud wI rig crew - fill hole - check for I eaks - Screw into std HWDP - test mud lines to 3500 psi Spud in C/O ice plug f/ 73' to 114 - Drill 12 1/4" hole f/ 114' to 234' POOH & std back HWDP - MU MWD, ubho, fl oat,1 std 8" DC RIH to 230' - Run gyro surv ey Drill f/ 234' to 368' Plugged jets - POOH - 2 jets plugged wI gra vel - C/O - RIH to 368' Drill f/ 368' to 496' Plugged jets - POOH - 3 jets plugged wI gra vel - Check suction chamber - both screens on M P's - found nothing - dumped possium belly & cleaned under shakers - changed 2 shaker screens RIH to 189' - Wash to 496' Drill f/ 496' to 1440' MD 1438" TVD Past 2 4 hrs. - ADT- 6.4 ART- 3 AST- 3.4 Drill 12 1/4" hole f/ 1440' to 2560' MD 2384 'TVD ADT- 9.2 ART- 4.6 AST- 4.6 Circulate hole clean for wiper trip @ 588 gp m wI 110 RPM - monitor well - static Wiper trip f/ 2560' to 1092' - several spots wI pulls 15 to 50 over through bulid section - Monitor well- static RIH f/ 1092' to 2487' - Break circulation & safety wash & ream f/ 2 487' to 2560' TD - Circulate hole clean for 9 5/8" casing - monitor well - static - blow d own top drive POOH f/ 2560' to 189' - Std back HWDP - C hange out drilling jars Handle BHA - std back 8" DC's - LD UBHO, Float sub, stabs, NM pony DC'c, MWD, moto r, & bit RU to run 9 5/8" casing - PJSM Run 9 5/8" caasing - FS - 2 jts. 9 5/8" 36# J -55 BTC - FC - 13 jts. 9 5/8" 36# J-55 BTC t 0 628' - BakerLoc first 4 connections 15 j ts. of 60 jts. to run in hole @ report time Continue running casing - ran 45 jts. 9 5/8" Printed: 7/15/2002 2:06:04 PM ~~~ ~~r;;~ ~ ) ) PHILLIPS ALASKA INC. Operations Summary Report' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-48 CD2-48 ROT - DRILLING doyon1 @ppco.com Doyon 19 , Date 5/31/2002 6/1/2002 6/2/2002 Sub, From.. To Hours Code Còde Phase 00:00 - 02:30 2.50 CASE RUNC SURFAC 02:30 - 03:00 03:00 - 05:00 05:00 - 08:00 0.50 CASE RURD SURFAC 2.00 CEMENTCIRC SURFAC 3.00 CEMENT PUMP SURFAC 08:00 - 11 :00 3.00 WELCTL EaRP SURFAC 11 :00 - 16:00 5.00 WELCTL BOPE SURFAC 16:00 - 19:30 3.50 DRILL PULD SURFAC 19:30 - 21 :30 2.00 DRILL TRIP SURFAC 21 :30 - 22:00 0.50 DRILL CIRC SURFAC 22:00 - 23:00 1.00 CASE DEaT SURFAC 23:00 - 00:00 1.00 CEMENT DSHO SURFAC 00:00 - 00:30 00:30 - 01 :00 01 :00 - 23:30 0.50 DRILL CIRC SURFAC 0.50 DRILL FIT SURFAC 22.50 DRILL DRLG INTRM1 23:30 - 00:00 0.50 DRILL CIRC INTRM1 00:00 - 00:30 0.50 DRILL CIRC INTRM1 Page 2018 Spud Date: 5/29/2002 End: 6/13/2002 Group: Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: 19 Description of Operations 36# J-55 BTC casing - PU landing jt. & land casing wi fluted mandrel hanger on landing ring wi shoe @ 2550' & FC @ 2465' Total jt s. ran 60 RD casing equip. & RU cement head Circ and condition for cement job PJSM - Cement 9 5/8" casing - Pumped 40 b bl Boizan water wI nut plug - 5 bbls water f/ Dowell - Test lines to 2500 psi - Drop btm plug - Pumped 50 bbl Mud push spacer @ 10 .5 ppg - Mix & pump lead slurry (AS lite III) @ 10.7ppg - observed nut plug @ shakers w I 260 bbls lead pumped - pumped down tub 1 5 bbls - Total lead slurry 285 bbls - Switch to tail slurry ( G wi 0.2% D046, 0.3% D065, & 1% S001) @ 15.8 ppg pumped 48 bbls - d rop top plug wi 20 bbls water f/ Dowell - swi tch to rig pumps & displace cmt wi 169 bbls 9.7 ppg mud - bumped plug wi 1000 psi - flo ats held CIP @ 0636 hrs. - full returns throu gh job wi 120 bbls 10.7 ppg lead cmt to surf ace RD cmt head, long bails, casing elevat ors, & LD landing joint - Flush 20" Hydril PJSM - ND 20" hydril & diverter system - In stall & test FMC 11" - 5K Unihead - NU 13 5/8" 5K BOPE Set test plug - Test BOPE to 5000 psi high & 250 psi low (Hydril to 3500 psi high) as p er Phillips policy - AOGCC John Crisp waive d witnessing of test - Pull test plug - set we ar bushing MU BHA #2 - 8 1/2" - RIH wI flex collars & H WDP fl derrick - RIH wi 8 1/2" bit - PU 36 jts. 4" DP f/ shed -RIH wi DP f/ derrick to 2315' - Wash to 243 5' @ 4.5 BPM 410 psi Circulate btms up RU & test 9 5/8" casing to 2500 psi for 30 m ins. R D RIH & tag @ 2459' drill cmt, rubber plugs, F C @ 2465' - cmt & FS @ 2550' - C/O rat hot e to 2560' - Drill 20' new hole fl 2560' to 25 80' - Circ Circ hole clean for FIT RU - perform FIT to 16.1 ppg EMW - RD Drill 8 1/2" hole f/ 2580' to 5172' MD 4171 TVD ADT- 15 AST-.6 ART- 14.4 * Note - Changed over to 9.4 ppg LSND mud while dri Iling ahead f/ 2580' Pump sweep & circulate hole clean for wiper t rip Circ hole clean for wiper trip - monitor well (static) Printed: 7/15/2002 2:06:04 PM ') I'~~ ~ ) PHILLIPS ALASKA INC. Operations. Summary Report Legal Well Name: CD2-48 Common Well Name: CD2-48 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From.. To Hours Code Sub Phase Code 6/2/2002 00:30 - 02:30 2.00 DRILL WIPR INTRM1 02:30 - 03:30 1.00 DRILL TRIP INTRM1 03:30 - 04:00 0.50 DRILL REAM INTRM1 04:00 - 00:00 20.00 DRILL DRLG INTRM1 6/3/2002 00:00 - 10:30 10.50 DRILL DRLG INTRM1 10:30 - 11 :30 1.00 DRILL CIRC INTRM1 11 :30 - 13:30 2.00 DRILL WIPR INTRM1 13:30 - 15:00 1.50 DRILL TRIP INTRM1 15:00 - 00:00 9,00 DRILL DRLG INTRM1 6/4/2002 00:00 - 08:00 8.00 DRILL DRLG INTRM1 08:00 - 09:30 1.50 DRILL CIRC INTRM1 09:30 - 15:00 5.50 DRILL TRIP INTRM1 15:00 - 17:00 2.00 DRILL PULD INTRM1 17:00 - 17:45 0.75 DRILL TRIP INTRM1 17:45 - 19:00 1.25 RIGMNT RSRV INTRM1 19:00 - 22:15 3.25 DRILL TRIP INTRM1 22: 15 - 23:30 1.25 DRILL CIRC INTRM1 23:30 - 00:00 0.50 DRILL CIRC INTRM1 6/5/2002 00:00 - 00:30 0.50 DRILL CIRC INTRM1 00:30 - 03:30 3.00 DRILL REAM INTRM1 Page 3 of 8 Spud Date: 5/29/2002 End: 6/13/2002 G rou p: Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: 19 Description of Operations Wiper trip f/ 5172' to 2500' - hole in good c ondition - 5 to 10 K drag RIH f/ 2500' to 5081' * Held kick drill Break circ - safety wash & ream f/ 5081' to 5172 ' Drill 8-1/2" hole fl 5172' to 7367' MD 5661' TVD ADT- 12.9 ART- 12.1 AST-.8 Dril18 1/2" hole f/ 7367' to 8226' MD 6242' TVD ADT- 7.4 ART- 5.2 AST- 2.2 Pump hi-vis sweep & circulate hole clean for wiper trip - monitor well (static) Wiper trip f/ 8226' to 5200' - Monitor well (s tatic) service TD, blocks, & dwks RIH to 8140' - Establish circ @ 13BPM - 304 0 psi - Safety wash & ream f/ 8140' to 8226' - 100 RPM Dril18 1/2" hole f/ 8226' to 8989' MD 6745 TVD ADT- 5.9 ART- 4.6 AST- 1.3 Drill from 8989' to 9534' ART=2.3 AST=3.0 Last two surveys at 9437' and 9469' showed D.L.S. increased from 8 to 11.5 degrees and loss of Azimuth controle. Pumped 40 bbls 150 fv sweep and circ hole clean, 13 bpm 1100 rpm. Flow check well, s tat i c . POH, 10-25k over, flow check well at shoe, static. Continue to POH, stand back hwdp an d nmcsdp. Down load LWD, lay down motor (AKO adjust ment sleeve was backed off). MU M1X motor @ 1.5 degree I LWD I MWD, scribe tools. MU remainder of bha from derrick and RIH t 0 2500'. Slip and cut drilling line, service Top Drive and Drawworks. RIH, no problems, fill pipe every 2000'. Stage pumps up to 9 bpm 2400 psi, precauti onary ream from 9275' to 9296', hole began packing off and pulling tight. Reduced rate t 0 2-4 bpm 700-940 psi, packoff and 30-50k 0 verpull continued. Pump out 2-3 bpm, slight packoff from 9296' to 9150', pump out to 89 84', top of HRZ @ 9020'. Staged pumps up to 9 bpm 2290 psi, pipe m oving freely with full returns 260k PUW 160k SOW. Circ and condition mud, mud wt. in 9 .7 ppg, mud wt. out 10.2 - 10.4 ppg. Circ and cond mud until I mud wt. out @ 9.8 ppg, 13 bpm, 3300 psi, 100 rpm. Precautionary ream from 8986' to 9534' one tight spot 9250' to 9270' - back reamed one t ¡me clean. Saw strong show of small slivers of HRZ shale first BU below 9270', cleaned Printed: 7/15/2002 2:06:04 PM ~þ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: '.) ) PHILLIPS ALASKA INC. Operations Summary Report CD2-48 CD2-48 ROT - DRILLING doyon 1 @ ppco.com Doyon 19 Date From"" To Hours Code, Sub Phase Code 6/5/2002 00:30 - 03:30 3.00 DRILL REAM INTRM1 03:30 - 14:00 10.50 DRILL DRLG INTRM1 14:00 - 15:00 1.00 DRILL CIRC INTRM1 6/6/2002 15:00 - 20:00 20:00 - 23:30 23:30 - 00:00 00:00 - 05:30 05:30 - 08:00 08:00 - 11 :00 11 :00 - 13:00 13:00 - 20:00 5.00 DRILL CIRC INTRM1 3.50 DRILL CIRC INTRM1 0.50 DRILL DRLG INTRM1 5,50 DRILL DRLG INTRM1 2.50 DRILL CIRC INTRM1 3.00 DRILL WIPR INTRM1 2.00 DRILL CIRC INTRM1 7.00 DRILL TRIP INTRM1 Page 40f8 Spud Date: 5/29/2002 End: 6/13/2002 Group: Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: 19 Description ofOperatibns up shortly after BU. Drill from 9534' to 9844' ART=1.5 AST=6.4 Flow check well, no flow, circulate out gas c ut mud, 9.65- 9.7 ppg in 9.0 ppg out, 13 bp m 3280 psi. ECD=10.1 ppg no gain I no los s. No improvement, mud wt. out gas cut 9.0 ppg. Flow check well, slight flow. Shut in well initial SIDPP 30 psi, SICP 50 P si no change in 10 min. Circ out gas cut mu d 9.1 ppg through choke 4 bpm increased m ud wt. to 9.8 ppg. Flow check through choke , no flow. Open well, mud dropping in annul us with gas breaking out. Circ well 13 bpm 3 370 psi, mud wt. out gas cut to 9.2 ppg ECD =10.1ppg. Increase in gas volume at bottom s up gas cut to 9.0 ppg no pit gain. Shut in well, SIDPP 30 psi, SICP 50 psi. Circ throu gh choke at 4 bpm, increase mud wt. to 10.0 ppg. pressurized scales, mud wt out 9.5 pp g balance scale. Monitor well through ckoke , no flow. Open well, mud dropping in annul us as gas breaking out. Circ 13 bpm, 3490 psi, after two BU mud wt in and out at 10.0 ppg with pressurized seal e, mud weight out 8.5 ppg on balance scale, no pit gain ECD=10.3 Continue to circ and i ncreased mud wt. to 10.3 ppb, gas cut to 9. 7 ppg out, no gain / no loss. Drill from 9844' to 9863' (TVD 7235') ART=O AST=0.3 Drill from 9863' to 10085'. ART=1.1 AST=1.7 Increased mud wt to 10.5 ppg while drillin g - ECD=10.8 ppg. No background gas cut m ud present with 10.8 ppg ECD, connection g as cut mud wt. to 9.5 - 9.7 ppg. Began weig hting mud up to 10.8 ppg @ 0445 hrs. Circ and cond mud @ 12 bpm / 3550 psi I 10 0 rpm, after 10.8 ppg around, shut down pu mps for 5 min. Continue to circulate hole cl ean, no gas cut mud @ BU, flow check well, static. Pumped out to 9557', pulled up to 8600' - 10 -20k over, flow check well, static. RIH to 10 010', no problems. Staged pumps up to 12.5 bpm 13850 psi, pr ecautionary reamed to 10085'- 80 rpm. Circ hole clean, no gas cut mud observed. Flow c heck well, static. Pump out to 9500' - 5 bpm I 870 psi, flow ch eck well, static. POH to 8320', flow check w ell, static. POH to 2370', 5-15k drag - hole appeared in good condition. Flow check well , static. Continue to POH, change running to Printed: 7/15/2002 2:06:04 PM ') ~~ ~ ') PHILLIPS ALASKA INC. OperationsSumrnaryReport Legal Well Name: CD2-48 Common Well Name: CD2-48 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date, From~To Hours Code, Sub Phase Code 6/6/2002 13:00 - 20:00 7.00 DRILL TRIP INTRM1 20:00 - 21 :00 1.00 DRILL PULD INTRM1 21 :00 - 23:00 2.00 CASE NUND INTRM1 6/7/2002 23:00 - 00:00 00:00 - 00:30 1.00 CASE RURD INTRM1 0.50 CASE RURD INTRM1 00:30 - 15:30 15.00 CASE RUNC INTRM1 15:30 - 18:00 2.50 CASE CIRC INTRM1 18:00 - 20:00 2.00 CEMENT DISP INTRM1 20:00 - 20:30 0.50 CASE NUND INTRM1 20:30 - 00:00 3.50 WELCTL BOPE INTRM1 6/8/2002 00:00 - 00:30 0.50 DRILL PULD INTRM1 00:30 - 02:00 1.50 DRILL PULD INTRM1 02:00 - 05:00 3.00 DRILL DEOT INTRM1 05:00 - 05:30 0.50 DRILL PULD INTRM1 05:30 - 06:00 0.50 DRILL DEOT INTRM1 Page 5öt 8 Spud Date: 5/29/2002 End: 6/13/2002 Group: Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: 19 Description otOperations ols to 5" and stand back hwdp and NMCSDP. Lay down BHA and clear tools from floor. Pull wear bushing and install test plug. Cha nge top pipe rams to 7", test rams 250/5000 psi. Pull test plug and install thin wall we a r bushing. RU to run 7" casing. 10085' md [ 7261' tvd]. Complete ru csg eq uip. Run shoe track & a total of 236 jts 7' x 26 ppf x L-8- x BT&C Mod. Ck float equip. B rk cir @ 4041,6590, & 8700 '. Run to 1004 0, pu Idg jt & hanger - landing out csg @ 10 074'. Stage pump up each cir to 3-4 bpm. Start 15' reciprocation as soon as landing 0 ut, staging up pump to final of 5 bpm I 700 ps i. Make up cmt head. PJSM & ops meeting. C ir cond mud lowering yp to < 20. Final cir r ate 5 bpm I 500 psi. Dowell cmt well as follows: Continued to re ciprocate 15' / 2 minute cycles. Pump 5 bbl fw followed by pump & line test to 3500 psi Pump 20 bbl ARCO pre flush, 50 bbl Mudp ush @ 12.5 ppg, drop bottom plug, follow wi 34 bbl batch mixed slurry [160 sx] 15.8 ppg [yield 1.15 ft3 / sx]. CI G + adds. Pump @ 5.3 bpm I max pressure 580 psi, avg 500 psi. Drop top plug & disp wi 20 bbl fw. H and over to rig for completion of displaceme nt. Rig displace w/ 358 of 362 calculated b bls, avg pressure 480 psi / 5.6 bpm, final d is place pressure I rate 450 psi / 4 bpm. Bu mped plug to 1000 psi, held 2 minutes chec king floats holding. CIP = 1936 hrs. Rd cmt equip & Id Idg jt. Csg landed off wi ma ndrel system in well hd @ 10074' rkb Doyon 1 9. Pull wear bushing, install packoff & test to 5 k psi. Install test plug, x-out rams to 3.5 - 6" vari able. Test bope to 250 I 500 psi high / low, annular to 250 I 3500 psi. Recover test plug & install wear bushing. Pu bails I elevators & prepare floor to rih. Pu bit #4,mwd I Iwd & orient - scrib same. Shallow test, pwd ¡nop, x-out same test & co mplete upload. Complete bha work. Complete testing Iwd / mwd.. Printed: 7/15/2002 2:06:04 PM ) /~ @! ) , PHILLIPS ALASKA INC. Operations Sum maryReport Legal Well Name: CD2-48 Common Well Name: CD2-48 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 6/8/2002 06:00 - 11 :30 5.50 DRILL PULD INTRM1 11 :30 - 13:00 1.50 DRILL CIRC INTRM1 13:00 - 14:00 1.00 CASE DEQT INTRM1 14:00 - 16:00 2.00 DRILL DRLG INTRM1 16:00 - 16:30 0.50 DRILL DRLG INTRM1 16:30 - 18:30 2.00 DRILL CIRC INTRM1 18:30 - 20:00 1.50 DRILL CIRC INTRM1 20:00 - 21 :00 1.00 WELCTL OTHR INTRM1 21 :00 - 00:00 3.00 DRILL DRLG INTRM1 6/9/2002 1.00 DRILL CIRC PROD 00:00 - 01 :00 01 :00 - 06:00 5.00 DRILL DRLH PROD 06:00 - 07:00 07:00 - 00:00 1.00 DRILL CIRC PROD 17.00 DRILL DRLH PROD 6/10/2002 8.00 DRILL DRLH PROD 00:00 - 08:00 08:00 - 08:30 0.50 DRILL CIRC PROD 08:30 - 09:30 1.00 DRILL DRLH PROD 09:30 - 12:00 2.50 DRILL DRLH PROD 12:00 - 13:00 1.00 WELCTL OBSV PROD Page 6 of 8 Spud Date: 5/29/2002 End: 6/13/2002 Group: Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: 19 Description of Operations, Rih picking up 135 jts 4" x S-135 dp, contin ue to run pipe out of derrick to 9902'. Filii ng pipe / 2000'. Brk cir, wash 9902 - 9910, tag cmt @ 9944' ,clean out to 9971' [4.2 bpm /1680 psi]. Ci r - cond for csg test. Test csg [charted] 3500 psi / 30 minutes. Drlg shoe track float equip & 8.5" hole to 10 084' . Drlg new 6.125" hole to 10005'. Cir gas cut mud [cut .6 ppg to +1- 10 ppg.]. Discuss ops wi PPCO engineering - raise mw from 10.5 - 10.8 ppg. Pooh & run FIT to 12.5 ppg. Dir drlg 10005 - 10285' [7258 tvd'], evaluati ng drilling conditions [well control] due to g as cut mud. Total Drlg Time = ART 2.1 h rs + AST .3 . = 2.4 hrs Cir samples for Geo, cir & reduce mw from 1 0.4 to 10.2 ppg. Dir drlg 10284 [7258 tvd] - 10515' X-out I snd mud for Flow Pro, start @ 0100 hrs @ s urface @ 1 0300'. Adt = 6.3 = art 5.5 + ast . 8 hrs Cir samples for geology. Work pipe. Dir drlg 10515 - 11395 [7232' tvd]. Adt = 7. 6 = art 5.3 + ast 2.3 hrs. Parameters: Pul so wts = 230 I 135k Ibs, Delta Press 300 psi I PP - Q = 1950 psi - 4.8 bpm / Torque - r pm = 14000ft-lbs @ 80 rpm / bit wts = slide 10k - rot 5k Ibs. Ecd in the 10.9 +/- .2 rang e. Resistivities in the 11- 12 ohm range. Dir drlg 11395 [ 7232' tvd] - 11744' started to lose 50% mud returns. Losing 50% returns wi 4.7 bbpm pump rate I ecd 11.0 ppg. Reduce p rate to 2.3 bpm [e cd 10.4 ppg] spotting 40 bbl 10 ppb fine - coarse Icm, spotting wi mud mixing 10 ppb I em on the fly. Continue to cir @ 2.3 bpm, working string while mixing pill. Drlg 11788 - 11815'. Displace Icm pill to b it while drlg ahs @ 30fph wi mud treated wi 8 ppb Icm as above. Had 25% returns befor e pill left bit, after pill on formation returns slowly increased to 65 - 75% returnes whil e pumping 4.3 bpm 1700 psi. Mud losses 1 20 bph. Adt = 7.7 = ast 1.1 + art 6.6 hrs. Continue to drlg ahd @ +1- 80 fph while pum ping 8- 10 ppb Icm mud. Returnes 50 - 75 % wi hourly losses 120 to 140 bbl. On conn ection observe well breathing. Conduct breathing I Exhalation Test: Si we I Printed: 7/15/2002 2:06:04 PM ~I J~~ .~:-' ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/10/2002 6/11/2002 6/12/2002 ) ') PHILLIPS ALASKA INC. Operations Summary Report CD2-48 CD2-48 ROT - DRILLING doyon1 @ ppco.com Doyon 19 Page 7 of 8 Spud Date: 5/29/2002 End: 6/13/2002 Group: Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: 19 Description of Operations, Sub From-To Hours ..Code Gode Phase 12:00 - 13:00 13:00 - 00:00 00:00 - 13:30 13:30 - 19:00 19:00 - 19:30 19:30 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 11 :30 11 :30 - 12:00 12:00 - 13:00 1.00 WELCTL OBSV PROD 11.00 DRILL DRLH PROD 13.50 DRILL DRLH PROD 5.50 DRILL CIRC PROD 0.50 DRILL SFTY PROD 3.50 DRILL CIRC PROD 0.50 DRILL OBSV PROD 0.50 DRILL TRIP PROD 11.50 DRILL TRIP PROD 0.50 DRILL CIRC PROD 1.00 DRILL OTHR PROD I & monitor well for 12 minutes. Initial SID DP / SICP 150 I 200 psi. Pressures equaliz ed after 9 minutes @ 200 psi, then SIDDP in creased to 235 & SICP decreased to 190 psi after an additional 3 minutes. Bleed aff an nular & dp press to trip tank via choke & ga s buster. Recovered 4.75 bbl after 15 minut es. Over next 3 minutes gained 1 bpm, con tinued to monitor for additional 12 minutes, flow continued to decrease wi the last 4 mi nute rates being less than .25 bpm or to sm all to measure. Si & monitor SIDDP & SICP for 6 minutes; SIDDP remainted @ 250 psi after a 30 second build up & SICP increased to 30 psi over 4 minutes & remained @ 30 psi for 2 minutes. Bleed off annulas & dp - prepare to drlg. Dir drlg ahd 11995 - 12730' [7250' tvd]. Drl g ahd wi 8 -20 bph mud losses. Losses are erratic, some do correspond to changes in t he Gr info. Adt = 8.2 = art 7.9 + ast .3 hrs. Ecds in the 10.5 range +1- .2 ppg Dir drlg 12730 [7250' tvd] - 13622 [7257'tvd] - total depth. Mud losses in the 8 -20 bph range. Slight breathing on connections & mud wt cut.3 - ,4 ppg on bottoms up. Cir / cond @ 5 bpm I 1700 psi, work pipe ov er one stand rot @ 80 rpm. Pump 35 bbl hi vis poloymer swee, sweep back on time wi m ode rate cuttings. Continue to circulate I co ndition. PJSM - displacement - pooh - treating lost c irculation continue to circulate. Pump 35 bbl high viscus sweep @ 5 bpm / 1 900 psi. followed by 9.3 ppg kcl brine. Stag e pump up from 2 bpm to 5 bpm over 30 min utes. Spot 30 bbl hi vis brine - poloymer p ill during displacement to cover from 12788' [known loss zone] to base of shoe. Continu e wi brine displacement. Monitor well @ 3 bph losses. Pooh to 13048'. Losses @ 3 -5 bph. Continue to pooh 13048 - 450'. Rot through tigh spot @ 12190'. observed well @ shoe t aking 8.5 bph via trip tnk, Spot high vis pol oymer pill @ shoe, continue tooh wi 3 - 4 bp h losses. Continue to pooh to bha, hole ta king 8.5 bph.Filling hole contineously via tri p tank throughout all ops. Flush bha wI 40 bbl brine treated wI 10 gall ons of Conqor 404. Pull to down loading ports & down load Iwd I mwd. Printed: 7/15/2002 2:06:04 PM ~. ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/12/2002 ) ) PHILLIPS ALASKA INC. Operations Summary Report CD2-48 CD2-48 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub From - To Hours Code Code Phase 13:00 - 13:30 13:30 - 14:30 14:30 - 15:00 15:00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 0.50 DRILL PULD PROD 1.00 DRILL OTHR PROD 0.50 CMPL TN SFTY CMPL TN 6.50 CMPL TN RUNT CMPL TN 1.50 CMPL TN SOHO CMPL TN 1.00 CMPL TN NUND CMPL TN 6/13/2002 00:00 - 01 :30 1.50 CMPL TN NUNO CMPL TN 01 :30 - 02:00 0.50 CMPL TN NUND CMPL TN 02:00 - 02:30 0.50 CMPL TN SEQT CMPL TN 02:30 - 03:00 0.50 CMPL TN SFTY CMPL TN 03:00 - 04:30 1.50 CMPL TN FRZP CMPL TN 04:30 - 07:00 2.50 CMPL TN PCKR CMPL TN 07:00 - 07:30 07:30 - 08:00 08:00 - 08:30 0.50 CMPL TN RURO CMPL TN 0.50 CMPL TN OTHR CMPL TN 0.50 MOVE DMOB CMPL TN Page 801 8 Spud Date: 5/29/2002 End: 6/13/2002 Group: Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: 19 Description of Operations Ld bha. Bit in near new condition. Flush stack PJSM Hole taking 9 bph. Pu wleg, 10' 4.5" pup, 4.5" xn nipple, 2 jts 4.5" tbg, 10' pup, 8.8' X 4.5" id millout ext ension, Baker 4.5 x 7" S-3 Packer, 10' x 4. 5" pup jt, 2 jts 4.5" tbg ,10' pup, Cameo 4. 5" KBG-2 GLM & 4.5" x 9' pup. Continue to run a total of 217jts 4.5" x 12.6 ppf x L-80 I BTM tbg to land out in well hd profile W/ wi eg @ 9600' rkb Doyon19. Cameo OB-6 nipp Ie @ 2050'. Refer to tbg detail for details. Thread lock all connections from bottom of packer. Used Jet Lub "Run-N-Seal thread c om pound. Mu tbg hanger to last jt, Use Idg jt A to Ian d out, recover jt & install 2 way ck valve in hanger. Mu Idg jt B to hanger & pt tp to 50 00 psi. Recover jt B. Ru to annulus & gravity feed 9.3 ppg kcl bri ne to annulus keeping annulus full. {rate + / -5 bph}. Nd bope - incomplete rpt time. ND bope, Nu adaptor & tree testing same 5000 psi. Retrieve bpv. Ru aux manifold & test to 4000 psi. PJSM subjects = freeze prot - set pkr - pres s test tbg/pkr & annulus. Dowell freeze protect w/ 180bbl total: 29 bbl to annulus & 146 bbl in tbg. Initial Q-Pres s = 2.3 - 300, final 2.3 bpm - 800 psi. Drop ball-bar assmby. Stage tbg up to 3500 psi & hold for 30 minutes: initial press 350 0 final 3226 psi {7.8 % bleed off}, annular p ressure 0 psi.. Test packer / annulus to 35 00 psi, initial press = 3500, final = 3411 ps i. After hole was displaced to 9.3 brine, 351 bbl of brine was lost to the formation ov er 30 hrs until the packer was set, avg loss es = 11.7 bph. Rd surface pressure test equip. Set bpv wi lubricator. Prepare to move off well. Rig released @ 0 830 hrs. Printed: 7/15/2002 2:06:04 PM ') ) BAKER HUGHES INTEQ ======> ALPINE CD2-48 Alaska State Plane VSect. Plane = 1! Coordinates Measured Angle Azimuth TVD-RKB TVD X Y N / -S E/-W DLS SVY# Depth deg deg ft Subsea ft ft ft ft deg/100 ft 1 0.00 0.00 0.00 0.00 -52.00 371731.20 5974313.74 0.00 0.00 0.00 2 114.00 0.00 0.00 114.00 62.00 371731.20 5974313.74 0.00 0.00 0.00 3 268.00 0.30 82.00 268.00 216.00 371731.60 5974313.79 0.06 0.40 0.19 4 400.84 1.00 78.34 400.83 348.83 371733.09 5974314.04 0.34 1.88 0.53 5 487.82 1.91 101.51 487.78 435.78 371735.25 5974313.87 0.20 4.04 1.23 6 575.51 3.05 120.44 575.39 523.39 371738.66 5974312.34 -1.27 7.49 1.58 7 664.60 3.94 125.34 664.31 612.31 371743.15 5974309.29 -4.24 12.03 1.05 8 755.11 3.95 125.36 754.61 702.61 371748.17 5974305,60 -7.84 17.11 0.01 9 845.77 3.07 121.24 845.10 793.10 371752.74 5974302.46 -10.91 21.73 1.01 10 936.23 1.83 119.91 935.47 883.47 371756.03 5974300.43 -12.89 25.05 1.37 11 ' 1031.74 0.37 228.47 1030.97 978.97 371757.10 5974299.45 -13.85 26.14 2.07 12 1125.38 0.77 249.40 1124.60 1072.60 371756.28 5974299.04 -14.27 25.33 0.47 13 1222.52 3.33 186.83 1221.68 1169.68 371755.28 5974296.02 -17.31 24.38 3.14 14 1316.78 6.14 186.83 1315.61 1263.61 371754.23 5974288.32 -25.03 23.45 2.98 15 1412.22 9.80 186.87 1410.11 1358.11 371752.43 5974275.21 -38.17 21.88 3.83 16 1506.51 12.45 189.11 1502.62 1450.62 371749.55 5974257.25 -56.17 19.31 2.85 17 1602.72 15.32 191.18 1596.01 1544.01 371745.06 5974234.61 -78.89 15.20 3.03 18 1697.59 18.48 186.78 1686.78 1634.78 371740.40 5974207.45 -106.12 10.99 3.59 19 1792.20 23.27 184.10 1775.15 1723.15 371736.72 5974173.96 -139.67 7.88 5.16 20 1887.10 28.23 187.27 1860.61 1808.61 371731.85 5974133.05 -180.66 3.70 5.42 21 1981.93 32.02 190.61 1942.62 1890.62 371723.58 5974086.21 -227.64 -3.77 4.37 22 2077.07 35.47 192.09 2021.72 1969.72 371712.28 5974034.60 -279.44 -14.20 3.73 23 2171.99 38.04 193.13 2097,76 2045.76 371698.93 5973979.40 -334.86 -26.61 2.79 24 2266.97 40.03 193.62 2171.54 2119.54 371684.11 5973921 .46 -393.05 -40,45 2.12 25 2362.11 41.89 194.84 2243.38 2191.38 371667.75 5973861.29 -453.49 -55.80 2.13 26 2456.97 44.37 194.84 2312.60 2260.60 371650.09 5973798.90 -516.18 -72.40 2.61 27 2496.17 44.65 195.45 2340.56 2288.56 371642.46 5973772.50 -542.70 -79.58 1.30 28 2630.32 45.28 195.48 2435.47 2383.47 371615.64 5973681.58 -634.07 -104.86 0.47 29 2726.88 45.56 194.36 2503.25 2451.25 371596.82 5973615.44 -700.53 -122.57 0.88 30 2822.61 47.21 193.82 2569.28 2517.28 371578.82 5973548.52 -767.75 -139.44 1.77 31 2918.73 47.51 194.17 2634.40 2582.40 371560.56 5973480.21 -836.36 -156.54 0.41 32 3013.53 47.44 194.55 2698.47 2646.47 371542.09 5973412.84 -904.04 -173.86 0.30 33 3108.74 47.74 193.57 2762.69 2710.69 371523.87 5973344.95 -972.23 -190.94 0.82 34 3204.05 47.44 191.91 2826.97 2774.97 371507.19 5973276.60 -1040.86 -206.46 1.32 35 3300.27 47.20 190.69 2892.20 2840.20 371492.16 5973207.49 -1110.22 -220.32 0.96 36 3392.76 47.08 191.58 2955.11 2903.11 371477.95 5973141.20 -1176.74 -233.41 0.72 37 3490.75 47.05 191.58 3021.86 2969.86 371462.36 5973071.18 -1247.03 -247.81 0.03 38 3586.01 46.87 190.85 3086.87 3034.87 371447.67 5973003.13 -1315.32 -261.36 0.59 39 3681.17 46.36 191.30 3152.24 3100.24 371433.24 5972935.50 -1383.19 -274.64 0.64 40 3776.06 45.92 191.35 3217.99 3165.99 371418.67 5972868.66 -1450.27 -288.08 0.47 41 3870.80 46.92 191.76 3283.30 3231.30 371403.79 5972801.67 -1517.51 -301.82 1.10 42 3966.33 47.03 191.12 3348.48 3296.48 371388.79 5972733.47 -1585.96 -315.68 0.50 43 4060.75 46.88 191.36 3412.93 3360.93 371374.20 5972666.03 -1653.64 -329.13 0.24 44 4157.26 46.94 190.67 3478.86 3426.86 371359.56 5972597.09 -1722.82 -342.59 0.53 45 4252.24 46.65 191.06 3543.88 3491.88 371345.37 5972529.34 -1790.81 -355.64 0.43 46 4348.05 46.46 190.90 3609.77 3557.77 371330.97 5972461.29 -1859.10 -368.89 0.23 47 4443.63 46.40 190.94 3675.65 3623.65 371316.70 5972393.53 -1927.10 -382.01 0.07 48 4538.96 46.16 191.53 3741.53 3689.53 371302.14 5972326.19 -1994.67 -395.43 0.51 49 4634.63 45.82 191.40 3808.00 3756.00 371287.33 5972259.01 -2062.11 -409.11 0.37 50 4729.20 45.61 191.38 3874.03 3822.03 371272.84 5972192.88 -2128.48 -422.48 0.22 51 4825.78 46.82 191.77 3940.86 3888.86 371257.69 5972124.83 -2196.78 -436.47 1.29 52 4918.24 48.63 190.49 4003.06 3951.06 371243.37 5972057.94 -2263.90 -449.67 2.21 53 5016.03 48.54 191.81 4067.75 4015.75 371227.97 5971986.25 -2335.85 -463.85 1.02 ) ') 54 5111.00 48.36 191.63 4130.74 4078.74 371212.36 5971916.92 -2405.45 -478.28 0.24 55 5207.24 47.87 191.74 4194.99 4142.99 371196.67 5971847.01 -2475.61 -492.79 0.52 56 5303.07 47.41 192.45 4259.56 4207.56 371180.67 5971778.04 -2544.85 -507.63 0.73 57 5398.15 47.24 192.02 4324.01 4272.01 371164.70 5971709.99 -2613.16 -522.44 0.38 58 5494.02 47.04 192.09 4389.22 4337.22 371148.87 5971641.53 -2681.89 -537.12 0.22 59 5589.74 46.85 191.92 4454.57 4402.57 371133.16 5971573.38 -2750.30 -551.67 0.24 60 5684.50 47.57 190.83 4518.94 4466.94 371118.30 5971505.45 -2818.47 -565.38 1.14 61 5780.58 47.55 190.87 4583.78 4531.78 371103.78 5971436.06 -2888.11 -578.73 0.04 62 5876.25 47.33 190.61 4648.49 4596.49 371089.48 5971367.06 -2957.34 -591.86 0.30 63 5970.64 47.32 190.59 4712.47 4660.47 371075.57 5971299.08 -3025.56 -604.62 0.02 64 6065.20 46.92 191.26 4776.81 4724.81 371061.29 5971231.28 -3093.59 -617.76 0.67 65 6160.41 46.73 190.78 4841.96 4789.96 371046.87 5971163.37 -3161.74 -631.03 0.42 66 6256.40 46.48 190.94 4907.91 4855.91 371032.57 5971095.11 -3230.24 -644.17 0.29 67 6351. 70 46.19 190.18 4973.70 4921.70 371018.79 5971027.57 -3298.02 -656.80 0.65 68 6445.60 45.81 190.30 5038.93 4986.93 371005.66 5970961.31 -3364.49 -668.81 0.41 69 6543.03 47.42 190.08 5105.86 5053.86 370991.97 5970891.85 -3434.17 -681.34 1.66 70 6638.54 47.71 190.38 5170.30 5118.30 370978.28 5970822.71 -3503.54 -693.86 0.38 71 6731.16 48.33 192.22 5232.25 5180.25 370963.64 5970755.44 -3571.05 -707.35 1.62 72 6829.08 47.93 191.64 5297.61 5245.61 370947.37 5970684.37 -3642.39 -722.43 0.60 73 6924.28 47.24 192.03 5361.82 5309.82 370931 .79 5970615.84 -3711.18 -736.84 0.79 74 7018.73 46.88 191.21 5426.17 5374.17 370916.72 5970548.37 -3778.91 -750.77 0.74 75 7114.76 48.46 191.63 5490.83 5438.83 370901.49 5970479.04 -3848.49 -764.83 1.68 76 7208.88 47.64 190.91 5553.75 5501.75 370886.65 5970410.64 -3917.14 -778.51 1.04 77 7305.76 47.05 191.49 5619.39 5567.39 370871.63 5970340.99 -3987.03 -792.35 0.75 78 7401.18 46.94 192.34 5684.47 5632.47 370856.08 5970272.98 -4055.31 -806.75 0.66 79 7497.51 48.40 190.41 5749.34 5697.34 370840.87 5970203.42 -4125.12 -820.78 2.12 80 7593.11 48.17 189.78 5812.96 5760.96 370827.18 5970133.39 -4195.38 -833.29 0.55 81 7688.09 47.43 191.95 5876.76 5824.76 370812.76 5970064.53 -4264.47 -846.55 1.86 82 7784.00 46.97 190.40 5941.93 5889.93 370797.95 5969995.75 -4333.50 -860.19 1.28 83 7879.13 47.24 190.68 6006.68 5954.68 370784.05 5969927.46 -4402.02 -872.93 0.36 84 7974.95 46.77 190.35 6072.02 6020.02 370770.10 5969858.79 -4470.93 -885.73 0.55 85 8070.24 47.66 190.70 6136.75 6084.75 370756,16 5969790.26 -4539.68 -898.50 0.97 86 8162.79 47.55 191.69 6199.15 6147.15 370741.76 5969723.45 -4606.73 -911.77 0.80 87 8260.09 47.03 191.10 6265.15 6213.15 370726.45 5969653.62 -4676.81 -925.90 0.70 88 8355.54 47.65 191 .46 6329.83 6277.83 370711.56 5969585.04 -4745.65 -939.63 0.71 89 8451.25 47.21 191.67 6394.58 6342.58 370696.27 5969516.24 -4814.71 -953.76 0.49 90 8546.75 48.59 191.66 6458.60 6406.60 370680.77 5969447.10 -4884.10 -968.09 1.45 91 8642.04 48.23 190.83 6521.85 6469.85 370665.69 5969377.45 -4954.00 -981.98 0.75 92 8737.74 47.65 191.25, 6585.96 6533.96 370650.91 5969307.96 -5023.73 -995.59 0.69 93 8833.71 50.03 192.65 6649.13 6597.13 370634.75 5969237.55 -5094.41 -1010.56 2.71 94 8928.57 49.99 192.62 6710.09 6658.09 370617.65 5969166.92 -5165.33 -1026.46 0.05 95 9024.27 49.13 191.65 6772.16 6720.16 370601.14 5969095.99 -5236.53 -1041.78 1.18 96 9119.30 48.29 191.93 6834.87 6782.87 370585.37 5969026.36 -5306.43 -1056.36 0.91 97 9215.00 47.91 191.37 6898.78 6846.78 370569.81 5968956.85 -5376.19 -1070.75 0.59 98 9275.18 49.55 185.92 6938.49 6886.49 370562.29 5968912.29 -5420.88 -1077.52 7.33 99 9309.95 51.45 183.00 6960.61 6908.61 370559.76 5968885.59 -5447.62 -1079.59 8.48 100 9335.16 52.55 181.75 6976.13 6924.13 370558.61 5968865.76 -5467.47 -1080.41 5.86 101 9368.81 52.85 179.57 6996.53 6944.53 370557.85 5968839.01 -5494.23 -1080.72 5.23 102 9405.16 52.77 178.66 7018.50 6966.50 370557.80 5968810.05 -5523.19 -1080.27 2.01 103 9436.83 51.79 173.93 7037.88 6985.88 370558.99 5968785.04 -5548.18 -1078.66 12.21 104 9468.72 51.69 169.44 7057.63 7005.63 370562.19 5968760.22 -5572.94 -1075.04 11.06 105 9501.07 51.88 168.69 7077.65 7025.65 370566.59 5968735.19 -5597.90 -1070.22 1.91 106 9533.95 53.10 169.63 7097.67 7045.67 370571.06 5968709.50 -5623.51 -1065.32 4.35 107 9563.29 55.61 170.66 7114.76 7062.76 370574.74 5968685.94 -5647.00 -1061.24 9.02 108 9596.77 58.43 170.51 7132.99 7080.99 370578.86 5968658.17 -5674.71 -1056.65 8.43 109 9628.50 59.77 170.17 7149.28 7097.28 370582.98 5968631.26 -5701.55 -1052.08 4.32 110 9660.42 61.80 170.14 7164.86 7112.86 370587.28 5968603.74 -5728.99 -1047.31 6.36 111 9691.32 64.08 168.75 7178.92 7126.92 370591.86 5968576.61 -5756.04 -1042.27 8.40 112 9721.97 66.01 168.67 7191.85 7139.85 370596.84 5968549.27 -5783.29 -1036.83 6.30 113 9756.01 69.07 166.60 7204.85 7152.85 370603.06 5968518.44 -5814.01 -1030.09 10.60 ') ) 114 9785.25 71.50 164.38 7214.72 7162.72 370609.51 5968491.69 -5840.65 -1023.19 10.96 115 9815.30 73.35 162.54 7223.79 7171.79 370617.20 5968464.10 -5868. 11 -1015.03 8.48 116 9846.03 75.32 160.82 7232.09 7180.09 370626,02 5968435.86 -5896.20 -1005.73 8.37 117 9881.25 77.72 159.40 7240.30 7188.30 370637.13 5968403.47 -5928.40 -994.08 7.86 118 9916.05 80.72 157.49 7246.81 7194.81 370649.15 5968371.48 -5960.19 -981.52 10.17 119 9939.58 82.52 156.46 7250.24 7198.24 370657.89 5968349.90 -5981.61 -972.41 8.79 120 9973.56 84.38 156.01 7254.11 7202.11 370670.97 5968318.79 -6012.51 -958.81 5.63 121 10007.44 85.92 155.13 7256.98 7204.98 370684.41 5968287.82 -6043.24 -944.85 5.23 122 10022.90 86.47 154.47 7258.00 7206.00 370690.74 5968273.76 -6057.20 -938.28 5.55 123 10129.57 90.92 151.97 7260.43 7208.43 370737.15 5968177.80 -6152.37 -890.24 4.78 124 10226.36 90.92 151.95 7258.88 7206.88 370781.19 5968091.63 -6237.79 -844.75 0.02 125 10322.14 90.98 152.34 7257.29 7205.29 370824.50 5968006.22 -6322.46 -800.01 0.41 126 10418.20 90.86 152.45 7255.75 7203.75 370867.56 5967920.37 -6407.57 -755.50 0.17 127 10513.42 91.91 153.44 7253.45 7201.45 370909.41 5967834.89 -6492.35 -712.20 1.52 128 10609.36 92.95 153.84 7249.38 7197.38 370950.51 5967748.30 -6578.23 -669.64 1.16 129 10704.26 93.08 154.10 7244.39 7192.39 370990.65 5967662.46 -6663.39 -628.05 0.31 130 10799.69 92.15 153.72 7240.03 7188.03 371031.11 5967576.16 -6749.00 -586.13 1.05 131 10895.03 90.92 153.45 7237.48 7185.48 371072.06 5967490.11 -6834.36 -543.73 1.32 132 10990.56 90.92 153.51 7235.94 7183.94 371113.25 5967403.94 -6919.82 -501.08 0.06 133 11085.85 90.74 152.17 7234.56 7182.56 371155.30 5967318.45 -7004.60 -457.59 1.42 134 11182.10 90.18 152.49 7233.79 7181.79 371198.55 5967232.47 -7089.84 -412.90 0.67 135 11277.02 90.49 152.33 7233.24 7181.24 371241.08 5967147.62 -7173.96 -368.94 0.37 136 11372,64 89.69 151.84 7233.09 7181.09 371284.40 5967062.39 -7258.45 -324.17 0.98 137 11468.08 88.83 151.54 7234.32 7182.32 371328.23 5966977.63 -7342.47 -278.91 0.95 138 11563.49 89.26 152.39 7235.91 7183.91 371371.63 5966892.69 -7426.67 -234.08 1.00 139 11656.85 88.83 151.52 7237.47 7185.47 371414.12 5966809.58 -7509.06 -190.19 1.04 140 11754.26 89.20 150.35 7239.14 7187.14 371459.98 5966723.67 -7594.19 -142.87 1.26 141 11849.50 89.02 150.84 7240.62 7188.62 371505.33 5966639.94 -7677.15 -96.12 0.55 142 11945.12 89.26 151 .45 7242.05 7190.05 371550.04 5966555.44 -7760.89 -49.98 0.69 143 12040.86 89.38 151 .42 7243.19 7191.19 371594.38 5966470.61 -7844.97 -4.20 0.13 144 12136.70 89.32 151.56 7244.28 7192.28 371638.69 5966385.64 -7929.18 41.54 0.16 145 12232.38 89.38 152.11 7245.36 7193.36 371682.42 5966300.55 -8013.52 86.70 0.58 146 12327.88 89.39 152.37 7246.39 7194.39 371725.46 5966215.31 -8098.03 131.18 0.27 147 12423.13 89.57 152.31 7247.25 7195.25 371768.24 5966130.22 -8182.39 175.39 0.20 148 12517.47 89.32 152.08 7248.17 7196.17 371810.82 5966046.05 -8265.83 219.40 0.36 149 12613.29 89.38 152.14 7249.25 7197.25 371854.20 5965960.63 -8350.52 264.22 0.09 150 12708.29 89.57 153.04 7250.12 7198.12 371896.49 5965875.58 -8434.85 307.95 0.97 151 12803.21 89.75 153.32 7250.69 7198.69 371937.88 5965790.17 -8519.55 350.77 0.35 152 12898.89 89.88 153.14 7251.00 7199.00 371979.52 5965704.03 -8604.98 393.87 0.23 153 12994.31 89.94 152.72 7251.15 7199.15 372021.50 5965618.35 -8689.94 437.29 0.44 154 13089.45 89.08 152.32 7251.96 7199.96 372063.96 5965533.23 -8774.35 481 .19 1.00 155 13184.62 89.20 151.80 7253.39 7201.39 372107.11 5965448.43 -8858.41 525.78 0.56 156 13280.79 89.26 151.44 7254.68 7202.68 372151.38 5965363.07 -8943.02 571.48 0.38 157 13375.85 89.45 151 .62 7255.75 7203.75 372195.27 5965278.76 -9026.58 616.80 0.28 158 13472.34 89.57 152.00 7256.58 7204.58 372239.40 5965192.97 -9111.62 662.38 0.41 159 13562.13 89.63 152.76 7257.20 7205.20 372279.67 5965112.73 -9191.17 704.00 0.85 PROJECTED TO TD 13622.00 89.63 152.76 7257.59 7205.59 372306.17 5965059.05 -9244.40 731.40 0.00 ), j aoa-IDõ'" 09-Jul-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-48 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD (if applicable) 13,622.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECE\\JED JUL ~~ 0 LQ02 A\asK80\\ & Gas Cons. comm\sS\on Anct\ota9ð l>o Q -..... . ~. ., n'\,,~ 8FL A'i 1(' r> r.. " ,0G I".J JUDO? - L ...1 '- "- C.I";f;~OT:t North S ,CO": Jl;(:188ka Alpine CD~2_" CD2.48 01)'4 Job No. AKMW22085, Surveyed: 11 June, 2002 SURVEY8PORT 9 July, 2"2 Your Ref: 50101842-200 Surface Coordinates: 5974313.77 N, 371731.19E (10.20' 11.0063- N, 151002' 26.8983- W) Kelly Bushing: 52.25ft above Mean Sea Level -, ~"i."_,:'V'~..~. .., DAILLING s_"vlcès A Halßburton Company ) EF .1 1\1'1 llEZl!œ8::, - V r- r~ r . ¡ .~ r-- .. 1 i - Survey Ref: svy9903 Sperry-Sun ÐItI/lltl.SétVices . Survey ReportfdJ;.;C1J2J.48 Your Rèf:(:501:~2f1o Job No. AKMW22085T SU~1-1 June, 2002 North Slope, Alaska Colville River Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) {ft} (ft) (ft) (ft) (ft) (ft) (o/1 OOft) -- 0.00 0.000 0.000 -52.25 0.00 O.OON O.OOE 5974313.77 N 371731.19 E 0.00 Tolerable Gyro 114.00 0.000 0.000 61.75 114.00 O.OON O.OOE 5974313.77 N 371731.19 E 0.000 0.00 268.00 0.300 82.000 215.75 268.00 0.06N 0.40 E 5974313.82 N 371731.59 E 0.195 0.14 MWD Magnetic 400.84 1.000 78.340 348.58 400.83 0.34 N 1.88E 5974314.08 N 371733.07 E 0.528 0.59 487.82 1.910 101.510 435.53 487.78 0.20N 4.04E 5974313.90 N 371735.24 E 1.225 1.73 575.51 3.050 120.440 523.14 575.39 1.275 7.49E 5974312.37 N 371738.65 E 1 .584 4.65 664.60 3.940 125.340 612.06 664.31 4.245 12.03 E 5974309.32 N 371743.14 E 1.053 9.41 755.11 3.950 125.360 702.36 754,61 7.845 17.11E 5974305.63 N 371748.16 E 0.011 14.98 845.77 3.070 121.240 792.85 845.10 10.91 5 21.73 E 5974302.49 N 371752.73 E 1.009 19.87 936.23 1.830 119.910 883.22 935.47 12.895 25.05 E 5974300.46 N 371756.02 E 1.372 23_18 1031.74 0.370 228.470 978.72 1030.97 13.855 26.14 E 5974299.47 N 371757.09 E 2.072 24.54 1125.38 0.770 249.400 1072.35 1124.60 14.27 5 25.33 E 5974299.06 N 371756.27 E 0.475 24.53 1222.52 3.330 186.830 1169.43 1221.68 17.31 5 24.38 E 5974296.05 N 371755.27 E 3.143 26.76 1316.78 6.140 186.830 1263.36 1315.61 25.03 5 23.45 E 5914288.34 N 371754.21 E 2.981 33.13 1412.22 9.800 186.870 1357.86 1410.11 38.17 5 21.88 E 5974275.23 N 371752.41 E 3.835 43.97 1506.51 12.450 189.110 1450.37 1502.62 56.17 5 19.31 E 5974257.27 N 371749.53 E 2.847 58.64 1602.72 15.320 191.180 1543.76 1596.01 78.89 5 15.20 E 5974234.63 N 371745.04 E 3.027 76.73 1697.59 18.480 186.780 1634.53 1686.78 106.125 10.99 E 5974207.48 N 371740.37 E 3.591 98.77 /~.- 1792.20 23.270 184.100 1722.90 1775.15 139.67 5 7.88E 5974173.98 N 371736.68 E 5.161 126.89 1887.10 28.230 187.270 1808.36 1860.61 180.665 3.70E 5974133.07 N 371731.80 E 5.423 161.07 1981.93 32.020 190.610 1890.37 1942.62 227.64 5 3.77W 5974086.23 N 371723.53 E 4.369 198.97 2077.07 35.4 70 192.090 1969.47 2021.72 279.44 5 14.20 W 5974034.62 N 371712.21 E 3.728 239.74 2171.99 38.040 193.130 2045.51 2097.76 334.86 5 26.61 W 5973979.42 N 371698.85 E 2.786 282.76 2266.97 40.030 193.620 2119.29 2171.54 393.05 S 40.45 W 5973921.47 N 371684.02 E 2.120 327.55 2362.11 41.890 194.840 2191.13 2243.38 453.495 55.80 W 5973861.30 N 371667.65 E 2.128 373.62 2456.97 44.370 194.840 2260.35 2312.60 516.185 72.40 W 5973798.91 N 371649.97 E 2.614 421.07 2496.17 44.650 195.450 2288.31 2340.56 542.70 5 79.58 W 5973772.51 N 371642.33 E 1.304 441.08 2630.32 45.280 195.480 2383.22 2435.47 634.07 5 104.86 W 5973681.59 N 371615.50 E 0.470 509.73 2726.88 45.560 194.360 2451.00 2503.25 700.53 5 122.57 W 5973615.44 N 371596.66 E 0.876 559.99 2822.61 47.210 193.820 2517.03 2569.28 767.75 S 139.44 W 5973548.52 N 371578.64 E 1.771 611.32 - ---. -~--- ---- 9 July, 2002 - 15:50 Page 20f8 DrillQllest 2.00.08.005 . North Slope, Alaska Colville River Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eaetlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) _0 2918.73 47.510 194.170 2582.15 2634.40 836.36 S 156.54 W 5973480.21 N 371560.37 E 0.411 663.76 3013.53 47.440 194.550 2646.22 2698.47 904.04 S 173.86 W 5973412.84 N 371541.89 E 0.305 715.28 3108.74 47.740 193.570 2710.44 2762.69 972.23 S 190.94 W 5973344.95 N 371523.65 E 0.823 767.37 3204.05 47.440 191.910 2774.72 2826.97 1040.86 S 206.46 W 5973276.59 N 371506.96 E 1.324 820.58 3300.27 47.200 190.690 2839.95 2892.20 1110.22 S 220.32 W 5973207.48 N 371491.91 E 0.965 875.21 3392.76 47.080 191.580 2902.86 2955.11 1176.74 S 233.41 W 5973141.19 N 371477.68 E 0.717 927.70 3490.75 47.050 191.580 2969.61 3021.86 1247.03 S 247.81 W 5973071.17 N 371462.08 E 0.031 982.89 3586.01 46.870 190.850 3034.62 3086.87 1315.32 S 261.36 W 5973003.12 N 371447.37 E 0.591 1036.73 3681.17 46.360 191.300 3099.99 3152.24 1383.19 S 274.64 W 5972935.48 N 371432.93 E 0.637 1090.32 3776.06 45.920 191.350 3165.74 3217.99 1450.27 S 288.08 W 5972868.64 N 371418.35 E 0.465 1143.15 3870.80 46.920 191.760 3231.05 3283.30 1517.51 S 301.82 W 5912801.64 N 371403.45 E 1.101 1195.96 3966.33 47.030 191.120 3296.23 3348.48 1585.96 S 315.68 W 5972733.44 N 371388.43 E 0.503 1249.80 4060.75 46.880 191.360 3360.68 3412.93 1653.64 S 329.13 W 5972666.00 N 371373.83 E 0.244 1303.14 4157.26 46.940 190.670 3426.61 3478.86 1722.82 S 342.59 W 5972597.06 N 371359.18 E 0.526 1357.80 4252.24 46.650 191.060 3491.63 3543.88 1790.81 S 355.64 W 5972529.30 N 371344.97 E 0.428 1411.61 4348.05 46.460 190.900 3557.52 3609.77 1859.10 S 368.89 W 5972461.25 N 371330.55 E 0.232 1465.58 4443.63 46.400 190.940 3623.40 3675.65 1927.10 S 382.01 W 5972393.49 N 371316.27 E 0.070 1519.36 4538.96 46.160 191.530 3689.28 3741.53 1994.67 S 395.43 W 5972326.15 N 371301.70 E 0.513 1572.63 -- 4634.63 45.820 191.400 3755.75 3808.00 2062.11 S 409.11 W 5972258.96 N 371286.87 E 0.369 1625.65 4729.20 45.610 191.380 3821.78 3874.03 2128.48 S 422.48 W 5972192.83 N 371272.36 E 0.223 1677.87 4825.78 46.820 191.770 3888.61 3940.86 2196.78 S 436.47 W 5972124.78 N 371257.21 E 1.286 1731.51 4918.24 48.630 190.490 3950.81 4003.06 2263.90 S 449.67 W 5972057.89 N 371242.87 E 2.209 1784.49 5016.03 48.540 191.810 4015.50 4067.75 2335.85 S 463.85 W 5971986.19 N 371227.46 E 1.016 1841.25 5111.74 48.360 191.630 4078.98 4131.23 2405.99 S 478.40 W 5971916.32 N 371211.71 E 0.235 1896.24 5207.24 47.870 191.740 4142.74 4194.99 2475.61 S 492.79 W 5971846.95 N 371196.12 E 0.520 1950.85 5303.07 47.410 192.450 4207.31 4259.56 2544.85 S 507.63 W 5971777.97 N 371180.10 E 0.728 2004.92 5398.15 47.240 192.020 4271.76 4324.01 2613.17 S 522.44 W 5971709.92 N 371164.12 E 0.378 2058.18 5494.02 47.040 192.090 4336.97 4389.22 2681.89 S 537.12 W 5971641.46 N 371148.27 E 0.215 2111.87 5589.74 46.850 191.920 4402.32 4454.57 2750.30 S 551.67 W 5971573.30 N 371132.56 E 0.237 2165.34 5684.50 47.570 190.830 4466.69 4518.94 2818.48 S 565.38 W 5971505.38 N 371117.68 E 1.136 2219.00 ---,- -_..-. ---- 9 July, 2002 - 15:50 Page 3 0'8 DrillQuest 2.00.08.005 Sperry-Sun DrilllflgServices . Survey ReportfrJ!~CD2-48 Your RêI:.SlJ1D1_2IIJO Job No. AKMW22085,Sui~r1-1 June, 2002 North Slope, Alaska Colville River Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5780.58 47.550 190.870 4531.53 4583.78 2888.11 S 578.73 W 5971435.98 N 371103.14 E 0.037 2274.12 5876.25 47.330 190.610 4596.23 4648.48 2957.35 S 591.86 W 5971366.98 N 371088.83 E 0.305 2328.98 5970.64 47.320 190.590 4660.21 4712.46 3025.56 S 604.63 W 5971299.00 N 371074.90 E 0.019 2383.12 6065.20 46.920 191.260 4724.56 4776.81 3093.59 S 617.76 W 5971231.20 N 371060.61 E 0.670 2436.92 6160.41 46.730 190.780 4789.70 4841.95 3161.75 S 631.03 W 5971163.28 N 371046.17 E 0.418 2490.77 6256.40 46.480 190.940 4855.65 4907.90 3230.25 S 644.17W 5971095.01 N 371031.86 E 0.287 2544.98 6351.70 46.190 190.180 4921.45 4973.70 3298.02 S 656.81 W 5971027.47 N 371018.07 E 0.652 2598.79 6445.60 45.810 190.300 4986.68 5038.93 3364.49 S 668.81 W 5970961.21 N 371004.92 E 0.415 2651.75 6543.03 47.420 190.080 5053.60 5105.85 3434.18 S 681.34 W 5970891.75 N 370991.21 E 1.661 2707.30 6638.54 47.710 190.380 5118.05 5170.30 3503.55 S 693.86 W 5970822.61 N 370977.50 E 0.382 2762.57 6731.16 48.330 192.220 5180,00 5232.25 3571.06 S 707.35 W 5970755.34 N 370962.86 E 1.621 2815.75 6829.08 47.930 191.640 5245.36 5297.61 3642.40 S 722.43 W 5970684.26 N 370946.56 E 0.601 2871.55 6924.28 47.240 192.030 5309.57 5361.82 3711.19 S 736.84 W 5970615.73 N 370930.98 E 0.785 2925.42 7018.73 46.880 191.210 5373.91 5426.16 3778.91 S 750.77 W 5970548.25 N 370915.89 E 0.741 2978.58 7114.76 48.460 191.630 5438.58 5490.83 3848.50 S 764.83 W 5970478.92 N 370900.64 E 1.677 3033.32 7208.88 47.640 190.910 5501.49 5553.74 3917.14 S 778.51 W 5970410.52 N 370885.79 E 1.041 3087.41 7305.76 47.050 191.490 5567.14 5619.39 3987.04 S 792.35 W 5970340.87 N 370870.76 E 0.751 3142.52 7401.18 46.940 192.340 5632.22 5684.47 4055.31 S 806.75 W 5970272.85 N 370855.19 E 0.662 3195.94 /.-."""" 7497.51 48.400 190.410 5697.09 5749.34 4125.12 S 820.78 W 5970203.29 N 370839.96 E 2.119 3250.89 7593.11 48.170 189.780 5760.71 5812.96 4195.38 S 833.29 W 5970133.26 N 370826.25 E 0.548 3306.95 7688.09 47.430 191.950 5824.51 5876.76 4264.47 S 846.55 W 5970064.40 N 370811.82 E 1.863 3361.63 7784.00 46.970 190.400 5889.68 5941.93 4333.51 S 860.19W 5969995.61 N 370797.00 E 1.279 3416.08 7879.13 47.240 190.680 5954.43 6006.68 4402.02 S 872.94 W 5969927.32 N 370783.08 E 0.356 3470.49 7974.95 46.770 190.350 6019.77 6072.02 4470.93 S 885.73 W 5969858.65 N 370769.11 E 0.551 3525.23 8070.24 47.660 190.700 6084.50 6136.75 4539.69 S 898.50 W 5969790.12 N 370755.16 E 0.972 3579.84 8162.79 47.550 191.690 6146.90 6199.15 4606.73 S 911.77 W 5969723.31 N 370740.75 E 0.799 3632.71 8260.09 47.030 191.100 6212.90 6265.15 4676.82 S 925.90 W 5969653.47 N 370725.43 E 0.696 3687.86 8355.54 47.650 191.460 6277.58 6329.83 4745.65 S 939.63 W 5969584.88 N 370710.52 E 0.706 3742.09 8451.25 47.210 191.670 6342.32 6394.57 4814.71 S 953.76 W 5969516.08 N 370695.21 E 0.487 3796.32 8546.75 48.590 191.660 6406.35 6458.60 4884.10 S 968.09 W 5969446.94 N 370679.70 E 1.445 3850.77 --.------- ----- 9 July, 2002 - 15:50 Page 4 ofB DrillQuest 2.00.08.005 Sperry-Sun DrillltgServices . Survey ReIOrt~248 Your Ref:501t11#tffttlO Job No. AKMW22085, S~:11 June, 2002 North Slope, Alaska Colville River Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8642.04 48.230 190.830 6469.60 6521.85 4954.00 S 981.98 W 5969377.29 N 370664.61 E 0.753 3905.85 8737.74 47.650 191.250 6533.71 6585.96 5023.74 S 995.59 W 5969307.80 N 370649.81 E 0.688 3960.94 8833.71 50.030 192.650 6596.87 6649.12 5094.41 S 1010.56 W 5969237.39 N 370633.63 E 2.712 4016.21 8928.57 49.990 192.620 6657.83 6710.08 5165.33 S 1026.46 W 5969166.75 N 370616.52 E 0.049 4071.25 9024.27 49.130 191.650 6719.91 6772.16 5236.54 S 1041.78 W 5969095.82 N 370599.99 E 1.184 4126.83 9119.30 48.290 191.930 6782.62 6834.87 5306.43 S 1056.36 W 5969026.18 N 370584.21 E 0.911 4181.59 9215.00 47.910 191.370 6846.53 6898.78 5376.20 S 1070.75 W 5968956.68 N 370568.63 E 0.589 4236.33 9275.18 49.550 185.920 6886.24 6938.49 5420.88 S 1077.52 W 5968912.11 N 370561.10 E 7.330 4272.55 9309.95 51.450 183.000 6908.36 6960.61 5447.63 S 1079.59 W 5968885.41 N 370558.57 E 8.4 76 4295.15 9335.16 52.550 181.750 6923.88 6976.13 5467.47 S 1080.41 W 5968865.58 N 370557.41 E 5.857 4312.27 9368.81 52.850 179.570 6944.27 6996.52 5494.24 S 1080.72 W 5968838.82 N 370556.64 E 5.230 4335.73 9405.16 52.770 178.660 6966.25 7018.50 5523.19 S 1080.27 W 5968809.87 N 370556.60 E 2.006 4361.47 9436.83 51.790 173.930 6985.63 7037.88 5548.18 S 1078.66 W 5968784.86 N 370557.78 E 12.211 4384.27 9468.72 51.690 169.440 7005.38 7057.63 5572.94 S 1075.04 W 5968760.03 N 370560.97 E 11.059 4407.81 9501.07 51.880 168.690 7025.39 7077.64 5597.90 S 1070.22 W 5968735.00 N 370565.37 E 1.914 4432.09 9533.95 53.100 169.630 7045.41 7097.66 5623.52 S 1065.32 W 5968709.30 N 370569.83 E 4.349 4457.00 9563.29 55.610 170.660 7062.51 7114.76 5641.00 S 1061.24 W 5968685.75 N 370573.51 E 9.018 4479.63 9596.77 58.430 170.510 7080.73 7132.98 5674.71 S 1056.65 W 5968657.97 N 370577.63 E 8.431 4506.23 - 9628.50 59.770 170.170 7097.03 7149.28 5701.55 S 1052.08 W 5968631.05 N 370581.74 E 4.322 4532.05 9660.42 61.800 170.140 7112.61 7164.86 5729.00 S 1047.32 W 5968603.53 N 370586.03 E 6.360 4558.51 9691.32 64.080 168.750 7126,66 7178.91 5756.04 S 1042.27 W 5968576.40 N 370590.61 E 8.396 4584.74 9721.97 66.010 168.670 7139.59 7191.84 5783.29 S 1036.83 W 5968549.06 N 370595.58 E 6.301 4611.33 9756.01 69.070 166.600 7152.60 7204.85 5814.01 S 1030.09 W 5968518.23 N 370601.80 E 10.601 4641.60 9785.25 71.500 164.380 7162.46 7214.71 5840.66 S 1023.19 W 5968491.47 N 370608.24 E 10.961 4668.35 9815.30 73.350 162.540 7171.54 7223.79 5868.12 S 1015.03 W 5968463.88 N 370615.93 E 8.484 4696.41 9846.03 75.320 160.820 7179.84 7232.09 5896.20 S 1005.73 W 5968435.63 N 370624.75 E 8.375 4725.57 9881.25 77.720 159.400 7188.04 7240.29 5928.40 S 994.08 W 5968403.24 N 370635.85 E 7.862 4759.46 9916.05 80.720 157.490 7194.55 7246.80 5960.19 S 981.52 W 5968371.24 N 370647.86 E 10.168 4793.42 9939.58 82.520 156.460 7197.98 7250.23 5981.62 S 972.41 W 5968349.66 N 370656.60 E 8.790 4816.60 9973.56 84.380 156.010 7201.86 7254.11 6012.51 S 958.81 W 5968318.54 N 370669.67 E 5.630 4850.26 -- - -----~-~-- --------- 9 July, 2002 - 15:50 Page 50'8 DrillQflest 2.00.08.005 Sperry-Sun Ðrill/!fJ8øNices . Survey Report~."" Your Re'fS01~ Job No. AKMfIV22085, SUfVJlIed:11 June, 2002 North Slope, Alaska Colville River . Alpine CD-2 Measured Sub-Sea Vertical Local Coordinate. Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs &88tlng8 Northing. Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10007.44 85.920 155.130 7204.72 7256.97 6043.25 S 944.85 W 5968287.57 N 370683.11 E 5.231 4883.95 -- 10022.90 86.470 6057.20 S 938.28 W 5968273.50 N 370689.43 E 5.550 4899.35 154.470 7205.75 7258.00 10129.57 90.920 151.970 7208.18 7260.43 6152.37 S 890.25 W 5968177.52 N 370735.83 E 4.784 5005.93 10226.36 90.920 151.950 7206.62 7258.87 6237.79 S 844.75 W 5968091.34 N 370779.86 E 0.021 5102.71 10322.14 90.980 152.340 7205.04 7257.29 6322.46 S 800.01 W 5968005.92 N 370823.15 E 0.412 5198.47 10418.20 90.860 152.450 7203.49 7255.74 6407.58 S 755.50 W 5967920.05 N 370866.19 E 0.169 5294.52 10513.42 91.910 153.440 7201.19 7253.44 6492.35 S 712.20W 5967834.55 N 370908.03 E 1.515 5389.69 10609.36 92.950 153.840 7197.12 7249.37 6578.24 S 669.64 W 5967747.95 N 370949.12 E 1.161 5485.50 10704.26 93,080 154.100 7192.13 7244.38 6663.39 S 628.06 W 5967662.10 N 370989.24 E 0.306 5580.20 10799.69 92.150 153.720 7187.78 7240.03 6749.01 S 586.13 W 5967575.78 N 371029.70 E 1.053 5675.47 10895.03 90.920 153.450 7185.23 7237.48 6834.36 S 543.73 W 5967489.71 N 371070.63 E 1.321 5770.73 10990.56 90.920 153.510 7183.69 7235.94 6919.83 S 501.08 W 5967403.53 N 371111.81 E 0.063 5866.21 11085.85 90.740 152.170 7182.31 7234.56 7004.60 S 457.59 W 5967318.02 N 371153.85 E 1.419 5961.47 11182.10 90.180 152.490 7181.54 7233.79 7089.84 S 412.90 W 5967232.03 N 371197.08 E 0.670 6057.72 11277.02 90.490 152.330 7180.98 7233.23 7173.96 S 368.94 W 5967147.17 N 371239.59 E 0.368 6152.63 11372.64 89.690 151.840 7180.83 7233.08 7258.46 S 324.17 W 5967061.92 N 371282.90 E 0.981 6248.25 11468.08 88.830 151.540 7182.07 7234.32 7342.47 S 278.91 W 5966977.14 N 371326.72 E 0.954 6343.68 11563.49 89.260 152.390 7183.66 7235.91 7426.68 S 234.08 W 5966892.19 N 371370.11 E 0.998 6439.08 11656.85 88.830 151.520 7185.21 7237.46 7509.06 S 190.19 W 5966809.06 N 371412.58 E 1.039 6532.42 11754.26 89.200 150.350 7186.89 7239.14 7594.19 S 142.88 W 5966723.14 N 371458.43 E 1.260 6629.80 11849.50 89.020 150.840 7188.37 7240.62 7677.15 S 96.12 W 5966639.39 N 371503.76 E 0.548 6725.01 11945.12 89.260 151.450 7189.80 7242.05 7760.89 S 49.98 W 5966554.87 N 371548.46 E 0.685 6820.61 12040.86 89.380 151.420 7190.94 7243.19 7844.97 S 4.20W 59664 70.02 N 371592.79 E 0.129 6916.34 12136.70 89.320 151.560 7192.02 7244.27 7929.18 S 41.54 E 5966385.04 N 371637.09 E 0.159 7012.17 12232.38 89.380 152.110 7193.11 7245.36 8013.53 S 86.70 E 5966299.93 N 371680.80 E 0.578 7107.84 12327.88 89.390 152.370 7194.14 7246.39 8098.03 S 131.18E 5966214.68 N 371723.82 E 0.272 7203.34 12423.13 89.570 152.310 7195.00 7247.25 8182.39 S 175.39 E 5966129.58 N 371766.59 E 0.199 7298.58 12517.47 89.320 152.080 7195.91 7248.16 8265.83 S 219.40 E 5966045.39 N 371809.16 E 0.360 7392.91 12613.29 89.380 152.140 7197.00 7249.25 8350.52 S 264.21 E 5965959.95 N 371852.52 E 0.089 7488.73 12708.29 89.570 153.040 7197.87 7250.12 8434.85 S 307.95 E 5965874.89 N 371894.81 E 0.968 7583.71 ~-----_._-~ ~--_.- - 9 July, 2002 - 15:50 Page 6 0'8 DrillQuest 2.00.08.005 Sperry-SUfI fJri"', Services Survey Report-f!l:f~"'" Your~ReI:;5D1~ Job No. AKMW220B5ì. 'SurveYed: 11 June, 2002 . North Slope, Alaska Colville River Alpine CD-2 Measured Sub-Sea Vertical Local Coordlnatås Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eaatlng.' Northing. Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12803.21 89.750 153.320 7198.43 7250.68 8519.56 S 350.77 E 5965789.46 N 371936.18 E 0.351 7678.61 12898.89 89.880 153.140 7198.74 7250.99 8604.98 S 393.87 E 5965703.31 N 371977.81 E 0.232 7774.26 12994.31 89.940 152.720 7198.89 7251.14 8689.95 S 437.29 E 5965617.61 N 372019.77 E 0.445 7869.66 13089.45 89.080 152.320 7199.71 7251.96 8774.35 S 481.19E 5965532.47 N 372062.22 E 0.997 7964.79 13184.62 89.200 151.800 7201.14 7253.39 8858.42 S 525.78 E 5965447.66 N 372105.36 E 0.561 8059.95 13280.79 89.260 151.440 7202.43 7254.68 8943.02 S 571.48 E 5965362.28 N 372149.61 E 0.379 8156.11 13375.85 89.450 151.620 7203.50 7255.75 902ð.58 S 616.80 E 5965277.96 N 372193.49 E 0.275 8251.16 13472.34 89.570 152.000 7204.32 7256.57 9111.62 S 662.31 E 5965192.15 N 312231.61 E 0.413 8347.65 13562.13 89.630 152.760 7204.95 7257.20 9191.18 S 704.00 E 5965111.90 N 372217.87 E 0.849 8437.43 13622.00 89.630 152.760 7205.34 7257.59 9244.40 S 131.40 E 5965058.21 N 372304.35 E 0.000 8497.29 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. 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 13622.00ft., - The Bottom Hole Displacement is 9273.29ft., in the Direction of 175.476° (True). ---- 9 July, 2002 - 15:50 Page 70f8 DrillQuest 2.00.08.005 Sperry-Su-nØdtl1iglervices Survey flfI1IortC' c~>, ..- - .._-~ YOîlffltê1i1~- - - - IfIt Job No. AKMW22iJ85,SuMþd: 11 June, 2002 . Colville River North Slope, Alaska Alpine CD-2 Comments \'-~ Measured Depth (ft) Station Coordinates TVD Northlngs Eastings (ft) (ft) (ft) Comment 13622.00 7257.59 9244.40 S 731.40 E Projected Survey Survey tool program for CD2-48 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 268.00 0.00 268.00 268.00 13622.00 268.00 Tolerable Gyro 7257.59 MWD Magnetic - ----~----- --~ 9 July, 2002 - 15:50 Page 8 of8 DrillQuest 2.00.08.005 08/26/02 Schluß1~epger NO. 2353 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine ,.-. Well Job# log Description Color Date Bl Sepia Prints CD 08/09/02 1 08/04/02 1 08/02102 1 CD2-32 CD2-46 CD2-48 ~..œ9 INJECTION SURVEY-WARMBACKS ~oÀ.-oi ~ INJECTION SURVEY-WARMBACKS ~lJd ..¡09/ INJECTION SURVEY-WARMBACKS ,.---, SIGNED~ ú-j}¡~o ~ DATE: RECEIVED AUG B ()) 2002 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank ~&.I, '''''~ & G... . . 1\8 Uh as Cons. Cvmmi!9ion . ' Anchorage ) ) Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 21, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drillinp' Waste on well CD2-48 Dear Sir or M,adam: Phillips Alaska, Inc. hereby requests that CD2-48 be pennitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD2-48 approximately October 5,2002. Please find attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. lntennediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9, Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. Details regarding wells on CD2 pad within ~ mile radius should be 011 file at the AOGCC. If you have any questions or require further information, please contact Vem, Johnson at 265-6081, or Chip Alvord at 265-6120. . ~y,~ /{/L (- . V ern Johnson Drilling Engineer cc: CD2-48 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake A TO-868 Anadarko ATO-1530 , ,. 0 '-'\, '. .f''''.. 3' '\ 1 ;', L ' j':r '. '\\ i\ ' l" J J c.'".') ,1 1 \.l \ ., : ~ \ i t,,;1 I',' f~\ ' ) ') 1¡JG-,A ~ ~)j 11 /C¡¡! 0 L. 11 r7f~ } !¿O/OC 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 2043' FNL, 1505' FEL, Sec. 2, T11 N, R4E, UM At top of productive interval 2356' FSL, 2423' FEL, Sec. 11, T11 N, R4E, UM At effective depth At total depth 731' FNL, 784' FEL, Sec. 14, T11N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13622 7258 13622 7258 Casing Conductor Surface Length 78' 2513' 9-5/8" Size 16" Production 10038' 7" Perforation depth: measured None true vertical None Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service - ----- Per APD ----- Per APD feet feet feet feet Plugs (measured) Junk (measured) Cemented Pre installed 364 Sx AS III L & 237 Sx 15.8 class G 160 Sx 15.8 class G Tubing (size, grade, and measured depth 4.5" 12.6#, l-80 ibtm @9600' MD Re-enter suspended well - Time extension - Stimulate- Variance - Perforate - 6. Datum elevation (DF or KB feet) r:,KB S2 feet 7. Unit or Property name Other _X Annular Disposal Colville River Unit 8. Well number CD2-48 9. Permit number I approval number 202-108 10. API number 50-1 03-20422-00 11. Field I Pool Colville River Field / Alpine Oil Pool Measu red Depth 114' 2550' True vertical Depth 114' 2375' 10075' 7259' ., Packers & SSSV (type & measured depth) 7" Baker S3 Permanent Packer @ 9477' MD, Cameo DB nipple @ 2050' 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 _X 14. Estimated date for commencing operation 15. Status of well classification as: October 5, 2002 16. If proposal was verbally approved 13. Attachments Oil- Name of approver Date approved Service _x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed ~ ¿ / f1/0 Chip Alvord ~~- \.JG/\...... Title: Alpine Drilling Team leader Gas- Suspended - Questions? Call Vern Johnson 265-6081 Date 8 (t'l ðL FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test - Subsequent form required 10- Approved by order of the Commission Ongmal Signed By c~msrIY ~JIi T 9Ylor Fonn 10-403 Rev 06115/88. 1 1 'I , I , " I Approval no. 2. 'c: 30 -Z7~ ft(U It- ~~ Å-tlAv..( f1;V )¿ sjZ<J~ ( Commissioner Date q MoÞ ;2 it I I SUBMIT IN TRIPLICATE ') ) Note to File Well C02-48 PTO 202-108 Sundry 302-275 Phillips Alaska, Inc. (PAl) requests approval for annular disposal in the subject well. This note analyzes information submitted by PAl, affirms mechanical integ- rity of all wells within CO2-48's area of review (AOR), and recommends approv- ing PAl's request for annular disposal. C02-48 9-5/8" surface casing was cemented with 285 bbls lead cement followed by 48 bbls tail cement, totaling about 140% excess cement relative to gauge wellbore. 120 bbls of lead cement circulated to surface during initial placement. Successful placement of such volumes of cement indicates that CO2-48's sur- face casing is adequately cemented. The formation below the 9-5/8" shoe supported a 16.1 ppg EMW leak off test. Applied pressure dropped 130 psi (from 810 psi) during a 10 minute observation. An annular (9-5/8" x 7") injectivity test showed a pressure gradient of 15.4 ppg EMW referenced to the 9-5/8" casing shoe. During this test, pressure reached a maximum of 570 psi. The pressure then stabilized and shut in pressure varied between 450 psi and 360 psi over 10 minutes. Cementing records indicate mechanical integrity of all wells within CD2- 48's AOR. Refer to well C02-46 (PTO 202-082) for additional information on wells within this AOR. Based upon information submitted, AOGCC recommends approval of Phillips' request for annular disposal in Well C02-48 (PTO 202-092). Winton Aubert ~ 6 Â- q I Ie¡ /0 L Petroleum Engineer ) ) Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-48 b. The depth to the base of freshwater aquifers and There are no USDW aquifers in the Colville River permafrost, if present. Unit. Base of Permafrost = 1552' 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. 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) d. A list of all publicly recorded wells within one- See attached map indicating wells within 1/4 mile. quarter mile and all publicly recorded water There are no water wells within 1 mile. wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of Types of fluids can be mud, diesel, cement, and waste to be disposed of and the estimated density water. Maximum volume to be pumped is 35,000 of the waste slurry. bbls. f. An estimate of maximUlll anticipated pressure at Maximum anticipated pressure at casing shoe the outer casing shoe during annular disposaJ during disposal operations is 1907 psi. See operation and calculations showing how this attached calculation page. value was determined. g. Details that show the shoe of the outer casing is See attached cementing reports, LOT/FIT reports, set below the base of any freshwater aquifer and and casing reports. permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing See attached casing summary sheet and calculation strings have sufficient strength in collapse and page. burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission NA to confirm containment of drilling wastes. ) CD2-48 Pressure Calculations for Annular Disposal DETAILS: ~ '- '- Q) "C Q) (U "C Q) (U .t::. Q) .t::. lñ Ii> Co Co o 0 0 0> 0 0 c N 0 1« N + + c..> t: t: ~ ïi) '(i) LO Co Co ~ ~ ...... 0 0 ~ (J) (J) (U (U C> C> <=9-5/8" 36lb/ft, J-55 BTC casing @ 2550 ft MD (2375 ft TVD) Pburst == 3520 psi, (@ 85%: Pburst85% == 2992 psi """"" .... "" .,.. "fö'ë Z Z Estimated Top ofCeluent @ 9234 ft MD (6911 ft TVD) (7" csg x 8-112" Open hole annulus) 0) c: :.ë ~ I- 0) ~ c: "7 ïi> ..;t (U () <=4-1/2" 12.6lb/ft L-80 tubing to 9600 ft MD (planned) L ~ <=7" 26 tb/ft, L-80, BTC casing ({9 10074 ft MD (7259 ft TVD) Pcollapse == 5410 psi, (?g 85%: Pcollapse85% == 4598 psi F-- ~ ASSUM:PTIONS: . M,axiluUlu injection pressure, P Applied == 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: P max == PHydrostatic + P Applied - PFonnation Pmax == 12.0 (0.052) (2375)+ 1500 - 0.4525 (2375) P max == 1907 psi Maximum fluid density to burst 9-5/8" casing: Pburst85% == PHydrostatic + P Applied - PFormation 2992 == MWmax (0.052) (2375) + 1500 - 0.4525 (2375) MW max == 20.8 ppg Maximum Fluid Density to Collapse 7" Casing: P collapse85% == PHydrostatic + PApplied - PGasGradient - PHeader 4598 == MWmax (0.052) (6911) + 1500 - (0.1) (6911) - 2000 MWmax == 16.1 ppg " ) Casing Detail 95/8" ~urface Casing ~PHILLIPS Alaska, Inc. ~' A Subsidiary of PHilLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 60 Doyon 19 RKB to LOS FMC Gen V Hanger 9-518" 36# J-55 BTC Csg Davis Lynch Float Collar 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Shoe 58 Jts Jts 1 to 2 2 Jts 9- 5/8" shoe @ TO 12 1/4" Surface Hole RUN TOTAL 34 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, 40,42,44.46,48,50,52,54,56 68 joints total in shed - 60 joints total to run Last 8 joints stay out # 61 thru # 68. Use Best-Q-Life 2000 pipe dope Remarks: Up Wt -165 k On Wt -140 k Block Wt - 75 Well: CD2-48 Date: 5/31/2002 LENGTH 36.82 2.19 2425.66 1.51 82.11 1.71 2560.00 Supervisor: Don Mickey DEPTH TOPS 36.82 39.01 2464.67 2466.18 2548.29 2550.00 <)HI:~~p$': ' r;r;¡ ~ ~~ ) ') PHI1IJPS'ALASt<A I NO. ' '.1 . 'C,èJ)1eQti:ng,R~p~rt Legal Well Name: CD2-48 Common Well Name: CD2-48 Event Name: ROT - DRILLING Report #: Start: Spud Date: 5/29/2002 1 Report Date: 5/31/2002 5/28/2002 End: 6/13/2002 , "Ce~ntJobJypé~',PrimaJY ' , , , , '" ,~==~-~~~~~=~--Bfu~~~_7.~="~___~~7,=_-~:=:~~~:§¡~;~~S;i~~.~~;L=-~_~~~'-'-'~~S,~'7~~~i~~Qi¡L~i:~?_~===::~~~C~~Sé~~~~:=~:-~_:T~,~.=- Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 2,550 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 5/31/2002 sa Date: Date Set: BTM set: (ft) Csg Type: Suñace Casing sa Type: Csg Type: Plug Date: CSg Size: 9,625 (in.) sa TMD: Plug Type: sa Date: Drilled Out: ~~.C~: C~.C~: Cmtd. Csg: Suñace Casing Cement Co: Dowell Schlumberger Cmtd. Csg: Cementer: Jim Thompson Pipe Movement: Reciprocating ---;-'--;o:-n"I,"" ',---"-;---r"".,""',---;--'~-;"""'''':-''~--'-',,""",:'''''''''''.''''''--'ï'''''''''''''''-' ~ -'--;--'''',.''','''' --- -:-: .............,.-:--- -.~"'.-',:"'-"'" ~~--''''.,-''''':--.''''''~-''''''.'''''':----:--'-.-;-"''''''''',,:,"---:--'--:---''-ï:'"''-~- --:;---O"'''':'''''':--'-,--;-''''''''''''--~.---'''''17"' ----.,.. --:---''''°:-'"'-' .' : '" I '. . '" I ',: ' ", ,I " .j .' 'I,',' I " , PJp,~'lVIoven.nt' '''' Rot Time Start:: Time End:: RPM: Rec Time Start:03:00 Time End: 05:30 SPM: 2 Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 155,000 (Ibs) Drag Down: 145,000 (Ibs) ~"~:~-.I"1r-~"T1"T';' ~¡~"~~'~.,~":"~"'~~7'--::~:'."-~~~~-:1"~'~.':'~'.~,~'1"'T"~'Ï~,:"M""",..",~r-~~.,~'"""-~r-~~';,~:~~~r\"-'-~::M',~,"f;T\~';'"f'"'.~.:"f~'-~'~~-7~~'~'~'rr'~~"p,~...~,"f~\~':~"""""~':--:-~:'~ "~"~rrr-~:.,~ '-~..~~:,"": " ,', " ,$tag~NØ:'1o'1'"",' ",' , .-_....",--.~_""":'_.- ..~.......~--:~.._..;....~..:"'_' ....,..--..... .~_:.._..........._..._-~_..._..:......:- -~~--~.~_.l....._.....-:. --~_..._.~....~_._..;....:....:...~~;~~~......:.'L.;":'~;~ ~~~:~.~-_.......:;~--,~.- _.~_...--.~--~..._...;...:..._.~--_.- ..-..--: ~-_:....._.;..- ....-.:~~--_..._-----,~;~ _......:....-...._-_.~_..:.-_...- Type: Cement Casing Volume Excess %: 300.00 Meas. From: 120 Time Circ Prior To Cementing: 1.50 Mud Circ Rate: 273 (gpm) Mud Circ Press: 300 (psi) Start Mix Cmt: 05:10 Start Slurry Displ: 05:12 Start Displ: 06:05 End Pumping: 06:36 End Pump Date: 5/31/2002 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) 7,00 (bbl/min) Y 520 (psi) 1,000 (psi) 5 (min) Y Retums: 100 Total Mud Lost: (bbl) Cmt Vol to Suñ: 120.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: Densometer , " ' , ' ' , , ' " , MU4Data, ' , , '" "",' , ' , ' , ....; -' -_....:..- -_. - -.- ..:....~ ...........---.:.-..-. _.....":'_'.""":.:.-...,-_.._.:.....": ._'.-.... "*-- -.-......,.:..-: .-..---' _:'..'-_.~. ...._-~~ ..:- ........:..~. """,-.:0-- -.-.......:..-.,.-.."";'" ~...;. :.......~_. ._~ -:-......:..-. """,,,-""':"""..:._...........: .-...:---.,;_._........ '- .-..-- -'--"'_._'._"~'" - ..,,--......-. _M"'~"'__"""::..."""""~-";_'_-_"".' ........~-..: . Type: Spud Mud Density: 9.7 (ppg) Visc: 95 (s/qt) Bottom Hole Circulating Temperature: eF) Displacement Fluid Type: Mud PVNP: 25 (cp)/17 (lb/100ft2) Gels 10 sec: 3 (lb/10Qft2) Gels 10 min: 17 (lb/10Qft2) Bottom Hole Static Temperature: (OF) Density: 9.7 (ppg) Volume: 190.00 (bbl) Stage No: '1 Slurry No: 1 Qf4 . ," " ...L.--~_L,.._."'_--~~"-'~---"'-~'''-'I.I---..-..--.---....-...-~..--- _.101..--__- _...__.."'-~ .._.1.1__'-8_.10--__-. - _._-"-'-~_'''_8---------_._'-''_._--'-'-''--~'''-'''.~-'''1..---__..... _.w- S lu rry Data Auid Type: PRe-wash Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Auid Loss: (cc) Auid Loss Pressure: eF) Description: Biozan water w/nut plug Class: Cmt Vol: 40.0 (bbl) Density: 8,30 (ppg) Yield: (ff'/sk) Slurry Vol: (sk) Water Vol: 40.0 (bbl) Other Vol: 0 Temperature: CF) Temperature: (OF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Purpose: PRe wash & Mix Water: (gal) Foam Job: N Temp (oF) (oF) Pressure (psi) (psi) Printed: 8/2112002 9:44:23 AM ~~, œ ~ ) ) ,. PHILLIPS. ALASKA INC; , . '. I . " " . '. . C'èroenti~g,","RepØrt Legal Well Name: CD2-48 Common Well Name: CD2-48 Event Name: ROT - DRILLING P~ge 2.of~' Report #: Start: Spud Date: 5/29/2002 1 Report Date: 5/31/2002 5/28/2002 End: 6/13/2002 "~~""7"""-7:'-:""''''''-"71~7~~--''''''-'''''''''''~~,~:~~-r""TT~.''-'7:~-'''''-'-rrr-"':"~--'''''''''''~---r-'T-~~---''''''''''''''~-'''''~~~~"''''''~-"':"~'-~--'~-~''-'~''''''''''''''''''-''''7~-'''~''''-~-"':"7'-~''-'-'-:r-r-''''7~--''-~~~~~~'--:''''-~~'-~~~7'--'"'''''''~7''''''7~~'- . .' , .' ,$tag~ Nor.1Slur,y'NQ: 2~f4' .. " ..J.'..I.--.......,..... -~-- ~""""-'-.'--~'- :"~"'~""""''-''--~._~'...I._---,-,.....L..-':'...I....-....._-_........~.J..J'-''''''''''-' ------,.-........---.' ~--'...I._~."":'",-,,,,- ..1-,.-..:....::',..0.-.........."':":'''''-------'''- --~""'-~-'~- -,-,.'-~-",....J..._..,.J,_-,--__:""",__'''''._....o..- ---~. ..-,---."-----..1'-""""'-'.--- Slurry Data Fluid Type: Spacer Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: To: (ft) Description: MUDPUSH XL Class: Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) " :1. I. I I I 1 , , , , . " . "',stage No=,1Slurry. NQ: 3 ôf4 " ," , ~'_~L-"':"~,.¡.,::....:.... ....~-'.~ o(-,~ -"~-'~-'. _~'l ~~..._'_.,""~L- -~ '~~~, ~_.- '.__.,o(~-~ ~~- -~'._-"... ._."--~:-.,.,,:~,¡~,,:,,_'~, ..'.~~"~~~"'~-~. _.L_~__), :_~'_,_L_.--I..o! --_.:_-",,,,:,~,,~--,-... ...~ ~o!~--~- -.l'. ~"...:~---~._~,,-_. ~..~-~'-~o!:..::":'.~~__L_~o! ,~-~ Temperature: (OF) Temperature: eF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp eF) (OF) eF) Slurry Data Fluid Type: LEAD Slurry Interval: 2,050.00 (ft)To: (ft) Water Source: lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Description: ASLite Class: Cmt Vol: 285,0 (bbl) Density: 10.70 (ppg) Yield: 4.44 (ff'/sk) Slurry Vol:364 (sk) Water Vol: (bbl) Other Vol: () Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp eF) eF) Purpose: FILLER CEME Mix Water: (gal) Foam Job: N Pressure (psi) (psi) ........---....,--,.......,., ------'-'----"""""""---f''''''----''''''' ---"'----',-,,,,,,"""-..-,-.----.............--.,,.....,- ---.....,--..--.¡.....,...---..... ......,.---.!..... ---.-..,......,-.---., .....---,,..~--,----.................-.,,_....._--...., ....."......--,.....----",,,,,,,---,,,,------,,,, """""",.",,-'---"""'''''''''''''''-''''''----....---..,.....,-- --....,. . I' " '. 'I . .' '. . '.' '., ' '.' . ' .' I . I I '.,' 'I .' ,'." ' eF) , . ' .. , .' . " Stagé.No:1SJurryNø: 401.4, " "'" , ' .' -----....J,.-' ..J..._"""':'_--~--- '.oJ- _._......---'--'...:.....__......~'...... --.-.................: ,";--_........---1..--, ..I-....--.......--L-- '...0.._-.. ..--t-r'.¡...-~.~.............--,'''''''__. .-'--...o.i.-.,.......,-",-.....-.....I.............------..J..o.... ,:.....--............ !..--"...I-__......--...J-J ':"""--..---'-- ,.:.....--_...__...J.~ ......:- Slurry Data Fluid Type: TAIL Description: G + additives Class: G Slurry Interval: 2,550.00 (ft)To: 2,050,00 (ft) Cmt Vol: 48.0 (bbl) Density: 15.80 (ppg) Yield: 1.15 (ff'/sk) Water Source: lake Slurry Vol:237 (sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: eF) Temperature: (OF) Temperature: eF) Time Compressive Strength 1: Compressive Strength 2: Temp eF) (oF) Purpose: SHOE INTEG Mix Water: (gal) Foam Job: N Pressure (psi) (psi) D-46 D-65 S1 eF) DEFOAMER DISPERSANT I~CEL~_~~OR 0.2C % 0.3C% 1.OC % ----,---_.._---- Printe<l: 812112002 9:44:23 AM ) ') ~'~, ~ PHI~LIPS' ,ALAS,K,Ä INC. ' , ' '. '.', C:erne~ti,ng,~epo'rt ,~~ge'30f 3 Legal Well Name: CD2-48 Common Well Name: CD2-48 Event Name: ROT - DRILLING Report #: Start: Spud Date: 5/29/2002 1 Report Date: 5/31/2002 5/28/2002 End: 6/13/2002 . , --'-!""'IT-""''''~-''''''''-'-'-r'''''--'--'''----r'''I'T-~'''''--''''---r'''r-''''''' " I '" I ,. . " . . """""~""~"'''--'''''''~-:r-r-''''''''--'''''''''''''''''''-'--''''''--''''''''''''''''' I I , " cia~lngte~t, " ',Shoe Tèst, 'L..~-,-..,~.,~~~_...~;~-,-~..,~~~:.J' "'...oI-~.~,~~...._"",::,__..~~~'.u............ -':_-~--~"'.~~_.' _"'~~"'.~.""~_.:"""~'~..J.':'~_.~"":~.J._""'-'-"'~~".J''''->---~~'~-'''_.-I...."""-----_""':'~-':----',",._--- ~-- ~'.J'" ~~_"";;"-~."'-'---~~"":":_J:~---- ~~:.-.~ Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: 16.10 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N "t~/~ùrV~YI:V~tuÆ8tion, ',I," ," ' .:......_..........'~.....':'...w...~... --- '-- ...J...,"':'_..._..........'..._J.. ~...:.-... .-:...-- 1.I.o.I....:......--...,'--,.o..L.o.._..- -".'-_...........:.-..._-'-_.~...__:"'-.....,~_..._.........~- 1.I.oI__....._..~_':" ....1-,':"'-... -'-_.,.&.J..._..._"';-' ~_..""'"'----- '-- ""'"'---- _............_-----~_........_~-..:.....-- ....J.."':- CBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N _._--_._._._--_.*..._._._.,_..~-_..,._,,_._._--_...._-_.-.---..'.--"-.---...--.-.---*..--.-..----.."..--'-.---...._-_._....__..._._.-.._-~.. -.---..----.-..-.--.*..--,-.---...--.-.-.---.*..--.- Printed: 8/2112002 9:44:23 AM ) ') Phillip$, 'Alas~a', Inç~ " , Dét,Uy QriUingFte"ott ' , " , , ," , , I JOB NUMBER r EVENT CODE [24 HRS PROG TMD I TVD ' I DFS 'I REPT NO. ' I DATE' C02-48 OOR 1,120.0 2,560.0 2,384.0 2.00 3 5/30/2002 ,:.~.~~:~~~ ~!ckey ..__J:~.:.~~¡~~;@£~~~.~Jg I FIELD ~~~~~;;;:~.. ~-~;~~:.9._J::~~_:_~:QQ_.._,-_.J:~-~~~-~;'QQ-=~ CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTWIO MUD CUM INTANG WI MUD _..,...__.._..__.._,....,--.._,_........_-,.....,ç~æ~Q,!jD.9_~_91~~:_~!~!D.fL..,._..._..._...__..._..,._...._.__..._..._.......__..._...,_..,--.--.,.....- ._..,........__......._,.....J~:QQ.._..._m.._._._,..__..._..__._--, 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD ..---- Finis~ cmt ÍQÞ._:..NJL~1~~têQ.EE_:!1_Y-,~Jl.?':",ê~.ð- ~ Q!:!!L.-....----,...-..----, §tl:.?!!l!l£___. -__..J_~..L1~§__.._.._---_..,-,---_!Q~P~~----_....._- ;:=~ÄTË-~TMD---t:::~;~1;:~~':J:"-=-lNEX~ÑG~~~--;~~!1~~T--- __?@Q{2002 -,.._,1,A:~:17 ,.~&?'Q._..__,_1..~-:.4§.9_.._.lJ~,Ooo (in) ~ 114,0 (ft) I 9.625 (in) ~ ,.._~2~:2.1ID- -,--..---. .:'~~~T.!~!P~IU.,..-- ,..~~~ .....- Jl!~L_.,-~--..... .~...:.l~~.L... ~.lM~~..g~IAl-,!'~~~!c:t~!J.._~~... ~..~:~....,_..,....,_.,.L~~~~C.~Ij"r'-'--~"E.::~~..~.. '~"'..- 'FV, '~~IYP,:G-=L~, '''VUlfrHP, FCn\$~t., ,ØU..~AT' %~~~/lVIar "P~/pM ,', f't(1\1t ',<::1" ',Ca.. 'H2$" ~11\IIe:' "fQS , 108 19/43 32/44 13.6/ 21 I 122.5 8.5/ 1 -..-- -----...--- ~-~-"-_._-~-'_.'._--~--_._--~-' _._--~-_..- ~¡f~t~~IT§~~~~:?~~~~~~~:~~~1I~¡~~-=;I~~;s.:"= 21 150 140 140 8,000 ft-Ibf 1,000.23 ~.- _..,_.."-~-.~..--~._-,,c-. .'-lfiß~pi~~írTiøÑ~'- ....-.... --'-'"''''-'-'''~''''''~-'-''~~,jT$~---'''~''~~GT~''~'- "-'---~'ð.p:c-'~":~'-'-~~i:O::'~ 'cc-'-ëë)NÑJ,ië~:~ÇQNti~fip~~, SIT MXCI 1 1.00 12.250 ..__..._..._~._-~.__.....-...__._-_...~_..._._---~.__._...__._~._-_._.._---...._-_._.__._-~.__.__..__._-~.._-...-.--,..-...--- '-'~'_..''''''----'-'-'--'''--'-''--'--~'-''-'-'--'''-'''--.-.--,-....-----.--,--...---.- ._._-_...__.~_.__...__...~ NAVIDRILL M1C 1 27.80 12.125 SNMOC 1 9.92 8.125 2.875 ._._-_._..--_......_._--~._. -....--.-.---.-.---.......--.--.-.---....--.-.--..-........--.-.-.--....---.-.---..-.-....-.---.....---.-.--- .'.-"-'-'---."'---'---.-'.--'-'---..---'-.---.-"---... NMSTAS 1 5.63 12.125 2.875 SNMDC 1 9.40 8.125 2.875 .-..----.".-.......----..-.....--..--.,,--..-.....--.,..-'---'--"-"-'-----"-"""-'----"'-"."-.'----'-".------_...._....._.._---_.._......_._--_..__...._._....._~_._._.--_._..~.._._--_.._... -....,--.--..- MWD W/FLOAT 1 30.87 8.000 1.920 UBHO 1 3.27 8,000 2.813 ---.-..."-..-..--.-.-.."..--..."..-----....-,,..-...---.-...-.. -,-".--.-.---. .-..---.----..-.-...---,. ._-_.- ---.----.-...--.----.--...-..-,--.-...-..---.-.-.,.--.-..-- NMDC 2 61.71 8.062 2.875 NMSTAS 1 5.54 12.250 2.875 "---"--'-'---'''."----.--'-'-- ----.----.----.-.------.--.----.-----..----.-.-- .---------..----..-.--'.-. NMDC 1 30.83 8.063 2.875 CROSSOVER 1 3.65 8.062 3.000 -.---.----.--....----- ~--,-_...._---_.__...._------~'._-_.._--_.__.- ----------------- HWDP 3 90.47 5.000 3,000 JARS 1 32.37 6.250 2.250 .-""'---'-'''------'--..-------'--''.' ---.-.....----.-.------.-.----,-..-.-.------.--..--- .-.----... HWDP 23 687.77 5.000 3.000 ,Page ,1' öf, 2 WELL NAME .-....-.----..-.-..-.. -..------..-.------. -.-.w..-----...-----.-...... _'--'n___,_,-''''--'-'.--'-'-'--'-----'-'-_''___'n_''_'--'-'--_._-'-'-'---'--'-'-'-'---'''--'--'--_.-~--'-'-'---- -.-.------.- '-'---..--.-'---_W_-.--.- '-- ---, ---,~-~"-'~,-'-,"," -'~'~,-~-----"--"--' -- -"-'--"-~-'_.'~"-:-'-~--':-'~----'--'-'---~~its-'-,-"~~-'-'~,----'-:----' --,~- --~ -,-""-'c' ~-----~ _._,-,-,......,-~.._,~:-.~----~,~-.. -~,. , ,81,T iRUN, ':' ':' sl,Ze, ,'MANUf,,' ::' "tYPE 1, SERIAL. NO','." ',,&TSOR TFÂ," ,," 'QISP1}Ù,. OA'TE'fN'" 'ï~C)"J..L~S~..o..R.' -,--_.........~- -"'---'''''''''''''~_.ML--....._""""--~_.._-'':'__"",,,,--I___¡'':'-------~--_.L..:....-....__''''''''':',--_..-...-.--,--_.-,-...._-_.___I_........._,_._._¡~~"':-_~--_J_-_.---""",,--,-_.L_-",,--,,--_J.':'-""_-- -,~_........_~I___....__.'- ..-.....:.... 11 1 12.250 HUGHES-CHR MX-C1 X690N 18/12/12/10// 114.0 5/29/2oo23-4-WT~A-E-2~RG-TO ===._,:~:~"'-~-=:~~~~-=-=':~=--~'~~=--=~~---=i!IT-'öi~RÄ1J$fM¡-~-='=-~==~~=-~.""":==-~~==-~~==~,~.~~~==-:_..~.~~ -- BI~L~..':'~~~_,-- WO,~~.,-~-,!t!~--~,._-~!~-,,--~~SS._~,-..!. ,slt_.,_~~~~~1~F~~,~.~4Hr RO,~-,-~U~~~~~~~,!?~..!~_c.:~~~~~~ ._--~_._---~..__!~~Q.----"sq-~.._~~~-_.~!.~O --- 1,025 9.20 1,120.0 121.74 15.60 2,446.0 156.79 , .. SU~VEY DAT.A T.V.D. NJS CUM E1W CUM seCTION, M.p. 1,410.11 -38.17 21.88 43j)2-2,077.07- 1,502.62 -56.17 19.31 58.64 2,171.99 1,596.01 -78.89 15.20 76.73 2,266.97 1,686.78 -106.12 10.99 98.77 2,362.11 1,775.15 -139.67 7.88 126.89 2,456.97 1,860.61 -180.66 3.70 161.07 2,496.17 1,942.62 -227.641 -3.77 198.97 . PUMPLHYDAAÛLlCDATA' I STROKE (in) I LINER (In) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM I PRESSURE 12,000 6.000 70 293.02 2,450 586.04 12.000 6.000 70 293.02 2,450 586.04 INCL. 35.470 38.040 40.030 41.890 44.370 44.650 AZIMUTH. T.V.D. 'N/SCUM EmCUM SECTION 192.090 2,021,72 ~279.44 -14.20 239.74 193.130 2,097.76 -334.86 -26.61 282.76 193.620 2,171.54 -393.05 -40.45 327.55 194,840 2,243.38 -453.49 -55.80 373.62 194.840 2,312,60 -516.18 -72.40 421.07 195.450 2,340.56 -542.70 -79.58 441.08 ...-----L ","p. 1 ,412.22 1 ,506.51 1,602.72 1,697.59 ~~~.20 1,887.10 1 ,981.93 INCL. 9.800 12.450 15.320 18.480 23.270 28.230 32.020 AZIMUTH 186.870 189.110 191.180 186.780 184.100 187,270 190.610 NO. MAKE OF PUMP 1 Continental Emsco 2 Continetal Emsco Printed: 8/2112002 9:47:51 AM ) ') ~lä',~,"""~'~ ", , ~ ~ CD2-48 " I '. , PhUI~p','AI~sl<aflnc. , ' Dahy Qrl'Uing~eþorf' , IJOB NUMBER [EVENT CODE 24HRS PROG ' , TMD ' ODR 1,120.0 2,560.0 Page,~tof ,~' , WELL NAME [rVD' 'rDFS 'IREPTN30. fDATE 2,384.0 2.00 5/39/2002. ~ö~~~=~;~~~~~-!E:~~~~~3:.==~~~~~ 00:00 12:00 12.00 DRILL P DRLG SURFAC Dr ill 1 2 1 14" h 0 Ie f I 1 440 I to 2560' M D 2384' TV D ADT- 9.2 ART- 4.6 AST- 4.6 CIRC SURFAC C i r cui ate h 0 I e c I e an for wi per t rip @ 588 g P m w / 110 RPM - monitor well - static WIPR SURFAC Wi per t rip f I 2560' to 1092' - s eve r a I s p 0 is w / P u lis 15 to 50 over through bulid section - Monitor well- static --,-----"~.,.._...._-_.~._~... ---'~"'-'-_'____R_"'__'-'-'---_."'---'-"~----' 14:00 15:00 1.00 DRILLP TRIP SURFAC R I H fl 1092' to 2487' - 15:00 16:30 1.50 DRILL P REAM SURFAC B rea k c i r cui a t ion & sa f e t y was h & rea m f I 2 487' t 0 2560' TD - Circulate hole clean for 9 5/8" casi n - monitor well - static - blow down to drive 16:30 19:00 2.50 DRILL P TRIP SURFAC POOH f / 2560' to 1 89' - S t d b a c k H W D P - C h an g ----,----_.,-,-_.._._. _.__._'--_._._-~_._'--_._--_.._'-_._.----_._'---._----..-,---- e 0 u t _.~_! i II i n 9 j a L~.- ,.--------..-.--,-.-- 19:00 21 :30 2.50 DRILL P PULD SURFAC H and I e B H A - s t d b a c k 8" DC's - L DUB H 0 I F loa t -----..-.-,-.--.--.-,----..- ----,---_._-,_._~_~_Ê2_.~_!_~._~-~'. N M P 0 n y__Qg_~~L__~_~_9-2._-~_C:_!,~!_l- & bit 21:30 22:30 1,00 CASEP RURD SURFACRU to run 9 5/8" casing - PJSM 22:30 00:00 1.50 CASEP RUNC SURFACRun 9 5/8" caasing - FS - 2 jts, 95/8" 36# J-55 BTC - FC - 13 jts. 9 5/8" 36# J-55 BTC to 628' - BakerLoc first 4 connections 15 jts. of 60 jts, -----_!..~~ n i n h 0 I e @.._!:...E!..E_~!..!-.!_!..~_!:.- ------.----..----- 12:00 13:00 1.00 DRILL P 13:00 14:00 1.00 DRILL P ---"-'-~'---"--''''- ---...--..-"..---------- ~_.,....-----.- "''''---''---''''------'---''''''----''--''~---------''''..___."M___.'-W___M__-....____M__.'ø_---.--.'.' .'M_____.--.'.'.--."..---. 24 HR SUMMARY: Drill fl 1440' to 2560' TD of 121/4" hole - Clrc hole clean - wiper trip to 1092'- RIH to TD - Circulate clean for casing - POOH _....,.._..__.__...__._-------_..:.~Q-~t!~~J~-~.~--~_C:~!"--~.!:!,~!~_!!,~~Q....,---...._----_..._-----_....,-_....__..__._--_.._.__.._---".-,---",----'----'----"'----"---"----'-"---"-'''--'''---,-,--'---'--'- ~~~L~~~~iI:¿=I~~È=S;i~~~~~~~~~~~I~~2;:~E~~ -~~!)!!P.~_._--_.._-_._--- -.-..--.----------..-, ._----_._.._..~._--_..,_._--,---~.!3_._--- 4 - Doy._o_~,_.._-_.._-_.,.., 24 -------_..,._-Q<!~~!!..__.__._-_..._--_.._-_....,.._-----,..,---._--,..,...__._--_..._-_.._._~...__._..__........_- BHI 2 MI 3 -.ø..-.----_ø__ø.---.-------'-'-'-'-'-----.'.'--'---.'-----,-.--.---,----,...-.....--.-.-. .--...,...--..---,----.,..--.------'w.--.--------.-.w.____M___'_'--'-----.---'-'--'---'-----'--'---'---'-'--'---'--'-'w'-'ø.----.. -'-'--'---'---- -~_13..~~.._-----,...__.._,,--_.__..__.._,,_....__...._--,..._---,...__.._---_._,.._--_..__._.__..._-_?._--_._...__.._..,_.._~.E.~!!Y~~~.._-,-,,--_._, ----..---.-...----,--------- ---,.._-~-,---,_.._--_.._-- ~-,~-~~~.,-,,'.' . ~~~r~RIA~trLÇQ~SU,MP~I()N," , , " 116M ,UNITS USAGe' ON HANDttEM ' ' \IN'~~~ÀG~''~';,ON HAÑ~ . .. . . . -~~~)--,..._,--,...__.._.._,-_..__. -,._--,-~~~~"---_....._----"----)~~~._--_..._--_.---~.'.,!~-~..._,-~~~~~~~!..~~c:_,--,_.__._,..__..,..~~~~._--_._---------,_.___~9_,__,.. ----_..._-_.._~.!~~_.__. -~!~I-~.._Q~~.!~"-~-_..,._-----_...__..._-_.~-~!....,._--_.._...._-_..._..___~1.?r~..___- .__._-_..._':'~1.~~.Q._.....- --"--'--'''---''--'---'''----''----''----''--'---'''''---''--.---'''----'-----'''-----'---'''---------''''-- ==~~.=~~=~~:-":~~-=".=~:~';~~C~PP~~TC~;;~.=-=~~::-=-==~:;;::== CD2-17 960 CD2-48 Printed: 8/2112002 9:47:51 AM ) ) Zm'~> I" " ~' PhUUp15 "AI~sf(a~: ~nç~, , D¡¡Uy DtIUing~ep9~: ,," 'IJOBNUMBERrEVEN~CODE 124HRSPROG 'TMD' [TVD rDFS REPTNO, I DATE CD2-48 ODR 2,580.0 2,400,0 3.00 4 5/31/2002 ,~UPERV;;~ ~!~~~Y._.__.__.l:.~~:';:'9.~@P-2ç_~:~om 19 J:I.:LD NAME~~~~:~.._.__. AU;~,~~9:.9__t:.~_~_,TA~~00 __.J:~M TAN;.~~=~-=~ CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTW/O MUD CUM INTANG WI MUD --,--,._-,._..__._,..,_.__.,_.._._-_.._._...__..--'~.rJtHD[.'@.11.~~..,_._._--,-,._.,-,_..,.._.,_._._--_.__...__._-,-.-. "--"'''-'--'.''-'''----'--'-'--''-''--'---'--'--'''--'--,.,---.--..,Q...QQ..--.--..--.--,-.--,.-....-.--.----.Q.00 24 HR FORECAST DATE OF LAST SAFElY MEETING DAILY TOTAL CUM COST WI MUD Drill 81/2" hole 5/27/2002 ,199,693 602127 =:~oA~=-~~:;;í;;:::J:==I:~~~~~QL-==.o;:;:1!T= ---§@.Q{~Q9.~,-_._..__._~4~: 17 44&?_(L, 195.4§.Q_.__,L~.625 (in) ~ ?t?..?.9..f>Jftl. _L.QQ,Q..Q!:1) ~ 10,128.0 (ft) --.. 5/31/2002_.__--__. :'~-~!m:~!~tlr..-...~~~ .,-,_.,:..L~~~L. ¡.,---..,,~,-,..,._¡_.L~?~j..- ..-_.J.M!J.gJ~~I~~l~t~~-!J.R~_!J.- -'..'- -,g:~--...- ._~_,:_L~~~r-~~~tj., -.." -_-__E:2~----,~,. roo 'F¥" ~Y1Y,P: ~L.$, :~/~'ni,:.",Fc:l1\.<>,. ,Ø'L~~1> ,\I~"~~tMa~, ~~/pM' ,F't(~,(JI""Ca:,',H~, LllVlfE" t!$'" 48 1 2/8 13.61 21 I 115.0 10.71 / _._._-~-------- ~~it~~i;:~ci~~g~i::2~W~~~Ç~f~~~~i~-~~~lit~~=~i~~~=' 15 142 125 135 7,OOOft-lbf 1,074.71 "''-:_''~~'''''--'',:,''..r~.''___._' ,f",pi~~í~f¡6~~é", ,~-_..- ~~-','~-~'c'.~~'~'~~--""Né)Jr~"':-"~~~,~~iÑG~k~~, ~ --'c' ~ö.a':,--- .;-7"~.--~i;D;~~~ "~_.~ë~Ñij'$,ie~~~'_§()N~N"TYP( BIT DP-0912 PDC 1 1.00 8.500 .,__"M_'__'_._-~,-,-_._._._,-,..,-- ,"._-_.__._.._--~._--_._._-~._~._~-_._.__..._-_.__._._- '--""-'-'--"._'_'M.'__._.-.-.-,---,---.-.-,--..,---.-.-----'--'--'--"'--'--' NAVIDRILL M1XP 1 23.04 8.375 NMSTAB 1 4.45 8.125 2,875 .-.-- -."---'."---'""-'-.,.".---....-.--.-.-..---....---.-.---....-.--.-..---.....-....---...--.-.----..---. ---...---. GAMMA SUB 1 27.72 6.750 1.920 MWDW/FLOAT 1 22.35 6,750 1.920 "._.__M"_,,,',",-'-""'-_'_"'MM_'____-"-"--'_'_'_M'"-"''''-''---''--''_'"''M_'.___---'-''---''----'-''---'--"--"-"---'----"-"---'----'-'-"-'---"-"--------.--..---.----..-.. --.-----.,...-. DPCSNM 3 88.87 4.500 2.875 CROSSOVER 1 1.67 6.250 2.875 -. '-"'--'---"-".'_."-----'-"'-"~'---'-"'-~'--'''--._,.."--_._--_....~....~_.._-._.._...__._-,--. _..",._~.__.- --~.__.- ..-.. HWDP 3 90.47 5.000 3.000 JARS 1 32.69 6.250 2.250 ".._--_._--_...._.._.__._--_."_._--_._.__..,,.__..._~-_.".._--_.---_._.._~-_._--_.._._~-_._--,_.._._--_._~---.-.--.----.. "~'-~---~--"~'_._-'-~-~-""----'-~--'-'-~---'-'-"'-"-'_.~--'----""--'--'-'-'''-''.' HWDP 23 689.09 5.000 3.000 CROSSOVER 1 1.37 6.500 2.500 -,--- ----.---....----.-.--.--- ------.-----.....-..---.--- --....--------...-.- --.-----.---.-.--- HWDP 3 91.99 4.000 2.562 WELL NAME .--.--.--.- .----... .__........._,--"...._---~. -.-.-.--.-....--.- ..---.-_._-.-_...- '-"-'-"'---''''-''--'----'-'--'-'-- ........,.~ '-"T"''''''I'r:''''''''''- --"""-,.,. ,r-,...' ""-'--""""'-,"'~I'",.....,.,~! "-r-r-;-r- """""7"'--:" "-!'"T"',.r-'-"""-~'''-n'''I'''''''''-''"i----''''''--¡o~r-I''''''''---'''''',-''''TI.',.......,--....,.,....-M''''r .""""'1,",;,-'--"" "-n-r~ 1-"",,---'r'''-i"T".,.r-I'''''"'''''''~ "-''''',''''''''''''-''--'''''''''-"",,'rr-ï- """T------r "-r"i"";r:i'""""-': ,.~: 'r"',T""--r---;r "-r-,' :r-,"'. ~__~~~T!~~~:=Z~~-~~~~~~--~~~.~~~~~~~=-~'-~!(!¡~~_~~~~~L'~§;~~~:~~~$ ~~~!~._~-:~~"_:~O~¿f~jÑ,,'~~~iÑ~~~~=~l~~~~~4=Õ~~=~~-~ 2 I 1 8.500 HUGHES-CHR DP0912 7000566 12/12/12/12/12/ 2,560.0 5/31/20020..Q-NO-A-D-I-NO-DMF -.-~-c:-'r--'-~--:-':"""-~-7:-'~~:-~-~:-'~~'-~""""7-7:-::,"~--_'-7-'''''''~--'~'BIT opeRATIðNS----'--~~-c:-~-c-:"""-~-'""-T-'-"-'~-'--'~~---~'.-"---~,-:~---,~.-. ~:'=~f!.~~=~.~~_._~Qe.=~==~~~=,_...~~!£~.!~!š$~...! SIT ~:~~~!..~-~=~~~~~. -L~H;-~~i~~----Ë~~~~~~~~!~=-~~~~I 21 1 5/8 /20 419 1,600 503 0.10 20.0 200.00 0.10 20.0 200.00 -,._-~~..__._~~~_.._-~_..._,._~-~-_._-~,._.._c~_~_P.JLM~LtI-YDMJ!y'Ç...gA T/t,._~.~,"_.._~._,"~,~-~-_._--_.._.._~~_.._-~-,-- NO. MAKE OF PUMP STROKE (In) LUltER (in) SPM Q (gpt'n) PREiSS. (psI) 'TOTAL Q' KILLSPM I PRESSURE 1 Continental Emsco 12.000 6.000 50 209.30 1,600 418.60 40 280 -----.---- -.--------..- -.-..- - ------..- 2 Continetal Emsco 12.000 6.000 50 209.30 1,600 418,60 ,,' '.:, ,',':,:" ',OPEAAnøNSstJMMARY" ' ",", ' .' ",' ' " " --_..._-----....-.~...""...~------~..._-_._~-- -. I "f""":'"o'~'" I . '. \,~_tt:-~~I' :"l"~"""":;"::'\' ~"'':''''''':':'~~''''~.-::~,~'''''~~~ --~QM,'to:',"O~RS ',>cøoe"'rRcn!ë~~',$Uâ;'~"'PHA$~ ~~_v";":""', . .~, ", " ""QESc;Rìf$,11Ó~', , '~..i..:c..:...:.~~~~~~ 00:00 02:30 2.50 CASE P RUNC SURFAC Con tin u e run n i n g cas i n g - ran 45 j t s. 9 5/8" 3 6 # J-55 BTC casing - PU landing jt. & land casing W / fluted mandrel hanger on landing ring wi shoe @ 2550' & FC @ 2465' Total jts. ran 60 SURFAC R Dca sin g e qui p. & RUe em en the a d SURFAC C ire and con d i ti 0 n for c e men t job SURFAC P J S M - C e men t 9 5/8" cas i n g - P u m p e d 40 b bIB 0 izan water wI nut plug - 5 bbls water fLDowel1 - 02:30 03:00 0.50 CASE P 03:00 05:00 2.00 CEMENT P 05:00 08:00 3.00 CEMENT P IRURD ICIRC PUMP ! ------- Printed: 8121/2002 9:48:21 AM ) ) ~m'.'~,,~,"~ , ,,' , \~¡" CD2-48 Phillip$, "Alas~¡¡f Inc'~ , Da,iIYDI'IIUnQ~epo~"', ',' I JOB NUM~ER' r EVENT CODE 124 HRS PROG '¡ TMD ' ODR 2,580.0 Page'~öf'~' , WELL NAME 1~400.0 DFS3.00 IREPT~O. 1~;;~12002 ~~~~~J~~~~t~:~~~~~~~1:~õ~~-~~~~=-~~~~ 05:00 08:00 3.00 CEMENT P PUMP SURFAC T est I I n est 0 2500 psi - Dr 0 p b t m pi u g - P u m p e d 50 bbl Mud push spacer @ 10.5 ppg - Mix & pump lead slurry (AS lite III) @ 10.7ppg - observed n ut plug @ shakers wi 260 bbls lead pumped - pu mped down tub 15 bbls - Total lead slurry 285 bb Is - Switch to tail slurry ( G wi 0.2% D046, 0.3% D065, & 1 % S001) @ 15.8 ppg pumped 48 bbls - drop top plug wi 20 bbls water fl Dowell - switch to rig pumps & displace cmt wi 169 bbls 9.7 ppg mud - bumped plug wi 1000 psi - floats held CIP @ 0636 hrs. - full returns through job wi 120 bbl s 10,7 ppg lead cmt to surface RD cmt head, Ion 9 bails, casing elevators, & LD landing joint - FI ush 20" Hydril EQRP SURFACPJSM - ND 20" hydril & diverter system - Install & test FMC 11" - 5K Unihead - NU 13 5/8" 5K BO PE ----_ø'--"'--'-_'___'M'._' _...._-,_.._-_....."'..~- ""---"'--'-_"'''M''_'''.''''''--'''.''''''''-'''''--'--'-.''''-''.--.--.---........-..,--...."--.-..-...-.,,.--.--.-- ...---...-...--.--.-.--...-...--.--.----...-..--..--.----.-- '--'--'---"'-"'-- 11:00 16:00 5.00 WELCTL P BOPE SURFAC Set t est p lug - T est BOP E to 5000 psi h i 9 h & 2 50 psi low (Hydril to 3500 psi high) as per Phillips policy - AOGCC John Crisp waived witnessing of t est - Pull t est _...!?L~~-_._=-_!.~!..,-_.~~_!!..___b u s h i n g "--""-'--"--""--' PULD SURFAC M U B H A # 2 - 8 1/2" - R I H wi fie x coil a r s & H W D P fl derrick - --_._"_'_M~'~'~'--'~'W'---~'._'-~-'---~--'---'-''''_.'-,._--_....._..._.,_._---_.._.._--_.__._...._--~--_._~-._.._~----_...._..- .._._.._~.._-'----""-'._._____M"'''_''_._--'.''''-''._'.--. 19:30 21 :30 2.00 DRILL P TRIP SURFAC R I H wi 8 1/2" bit - P U 36 j t s. 4" D P f Ish e d - R I H wi DP fl derrick to 2315' - Wash to 2435' @ 4.5 ----..--,..---..,...-..-...-----,-.---------,-....--.------..--.--,---- .._-_._----,_..~-~-~-- 4 1 0 psi ----,-..--.----.--.-----,-..--.----,-...----.-----.---,--.---,-..-,-.-.--. -~_:~-,._.?2:~.Q--"".__q:~9_._.."Q.~1 ~!:~._--_._-------_<?l~,~.__._-,~~_~,~AC _C?.i.,E_~.~,~,.t__7-.!.!_~..~--~P-__..,_._.._._-,_..,-------,-".------.....,...---.----..,.-,.-.--..,..-- 22:00 23:00 1.00 CASEP DEQT SURFACRU & test 9 5/8" casing to 2500 psi for 30 mins. RD .-. ,-,,---,-"w,---- "-----"'''---'---'-'''----''-----'..----''-----''''---''---.-.... -_._.._---_...-_._-_.._~.-.._.._--_..._-_._.._--_.._-_.-...--- -..--.-......-..-...---,,-...-.---...---..-,,"----.--- 23:00 00:00 1,00 CEMENT P DSHO SURFAC R I H & tag @ 2 4 59' d rill c m t I rub be r p lug s, F C @ 2465' - cmt & FS @ 2550' - CIO rat hole to 2560' - Drill 20' new hole fl 2560' to 2580' - Circ 08:00 11:00 3.00 WELCTL P --"---....-.-.--. .~-~.._----_.._.- 16:00 19:30 3.50 DRILL P ------"------"'-__.___0._'___.---------.----- ------------ ---_.------..- --~._---_....__.,-_..._---_..._--~..'_._----.._-_._-_._----"--'--'~'-----"_._'--'~'-----"-'--~'---"~--'--'-'---_.._-_.__.~._.._,---,-_..._--_.._._,--_._---_._. '-----"_._'--'~---"~._'--'~'----"~._'--'-'-----"-~-.--. 24 HR SUMMARY: Finish csg run FS@2550' FC@ 2465 - Cmt casing - CIP @ 0630 hr - NU & test wellhead & BOPE - MU BHA - RIH - Test -------------~-~..:.. C/O -~.!'1t ~ Dri~_!? 2580' - Circ for F~_____- , PERSONNEL DATA, ' -_.._- CÒMÞiÑY-~--'--'-'SËRvièË-"----- NO. --.-. HOuRš--;------' 'COMPAÑY--c ---.-- seRVlcÊ-'----~--HOUR$- £,~illips ,--------------------------- 1 ----- DSB...____---------- --_.._---------~-- Doyon 26 Dowell 2 BHI 1 MI 3 ARCA 5 Sperry-Sun 2 .. ", ,...-~~~~. '.'.' 'MATERIA.LS/::.CONSUM.P:TIÖ.N : ' . . '.' ':..' ".':. '. ' C-==---ïTeM_-'=-=~-ÜNITS---:-=~':-ÜŠAG_~- --l=~N HAN~__~_- ITEM --~-UN~ ~-'ÜS_~GE--~__~t.iHA~~= . Fuel gals 1,405 -4,518 Water, Potable bbls 90 -270 Water, Drilling bbls 945 -3,965 Printed: 8/21/2002 9:48:21 AM ) ) ~fã':, H,ILLI~, -. " ' ~- ~ , " ' Pagø ',3öf 3' .. .. ' , P~ill~p$~laS~~f ~nç~' " ,Qany pt~lIing~ep()tt ' JOB NUMBËR '[EVENT CODE I24HRSPROG" ']TMD ' ODR 2,580.0 CD2-48 r " , 'r " ' 'I' , 'r .. TVD DFS REPT NO. DATE 2,400.0 3,00 4 5/3112002 WELL NAME =~=~:.~"s~~~~~~çj;~~~~~~¿~~~== g-~~~1-.,,------_..__.,.._---_.._--1.~~~_?,--"~g~_~8 -----,-.---------.,.--..,----. ----------..---------_.",--- -----..-"'--,----.,.--------.,.----.,----..--------.-.'.. Printed: 8/21/2002 9:48:21 AM CASING AND PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 5/3112002 I Volume Input Volume/Stroke Pump Rate: Ipump used: I #1 Mud Pump i... I ~ i , I I Strokes I ... ,0.10001 BblsjStrk.'" 5.01 Strk/min ... f Pumping down drillpipe. ¡ ... . I C . T t I ¡. asmq es Pressure Integrity Tesi Hole Depth Pumping Shut-in Pumping Shut-in 2,580 Ft-MD 2,400 Ft-TVD Strks psi Min psi Strks psi Min psi I. rOO 0 2500 0 0 0 810 2 150 1 2500 1 50 0.25 790 4 400 2 2500 2 130 0.5 780 6 600 3 2500 3 240 1 770, 8 775 4 2500 4 330 1.5 750 10 925 5 2500 5 440 2 750'---- 12 1075 6 2500 6 530 2.5 740 14 1250 7 2495 7 590 3 735 16 1475 8 2495 8 660 3.5 725 18 1675 9 2490 9 720 4 720 20 1925 10 2460 10 770 4.5 715 22 2150 15 2450 11 810 5 710 24 2400 20 2440 5.5 705 25 2500 25 2435 6 700 --- 6.5 700 7 695 7.5 690 8 690 8.5 690 9 685 9.5 680 10 680~ Well Name: CD2-48 I Rig: Don Mickey Drilling Supervisor: Type of Test: I Casing Shoe Leak Off Test Hole Size: 18-1/2" I. Casing Shoe Depth RKB-CHF: 36.6 Ft 2,550 Ft-MD 2,375 Ft-TVD CasinQ Size and Description: 19-5/8" 36#{Ft J-55 BTC CasinQ Test Mud Weight: 9.5 ppg Mud 10 min Gel: 15.0 Lb/100 Ft2 Test Pressure 2,500 psi Rotating Weight (Pumps off 140,000 Lbs BlocksfTop Drive Weight: 75,000 Lbs Estimates for Test: 1.6 bbls Pressure InteQritvTes1 Mud Weight: 9.5 ppg Mud 10 min Gel: 15.0 Lb/100 Ft2 Rotating Weight (Pumps off): 140,000 Lbs BlocksITop Drive Weight: 75,000 Lbs Desired PIT EMW: 16.0 ppg Estimates for Test: 803 psi 0.5 bbls , I ¡., PIT 15 Second Shut-in Pressure, psi 790 I I. EMW = Leak-Off Pressure+ Mud Weight = 810 95 0.052 x TVD 0.052 x 2375 + . EMW at 2550 Ft-MD (2375 Ft-TVD) = 16.1 ppa 3000 - i Lost 65 psi during test, I 97.4% oftest pressure. ! I I ¡ ! *~"~:~~.i~~ ,~---..i 1- ¡ I I I t J i i I 2500 . / /f I ! I I ¡ i i I I , 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point 2000 . I i ¡ ! ! í i ¡ I i i I I I i i I 1 I 3 0 w a:: ::J en 1500. en W a:: Q. 1000. 500 . 0 0 2 Barrels ~CASING TEST -4Þ-LEAK~FFTEST Comments: 30 Volume Volume Pumped Bled Back 2.5 1:sbls . 2.5 ~bls Volume Pumped 1.1 ~bls ! !.. ~ Volume Bled Back 0.8 ~bls Phillips Alaska, Inc. ) Casing Detail 1" Intermødíate Casína Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 236 Jts 1 to 2 Remarks: 234 Jts 2Jts Up Wt=335 Doyon 19 R KB to LDS FMC 11\1 X 7" Hanger 7" 26# L.80 STCM Csg 7" Davis Lynch Float Collar 7" 26# L.80 STCM Csg 7" Davis Lynch Float Shoe 1 straight blade centralizer per jt # 1 thru # 17 #'s 176 177 178 then every other jt f/ #180 to # 234. Total Centralizers: 48 260 joints in pipe shed. last 24 joints stay out Use Best-o-Life 2000 pipe dope On V\if = 170 Block V\if= 75K ) 7" shoe @ 8.112" TD Supervisor: David Burley Well: CD248 Date: 6/6/2002 LENGTH 34.66 2.37 9949.61 1.44 84.46 1.70 DEPTH TOPS 34.66 37.03 9986,64 9988.08 10072.54 10074.24 10085,00 ~þ' ~. ) ) Legal Well Name: CD2-48 Common Well Name: CD2-48 Event Name: ROT - DRILLING Report #: Start: Spud Date: 5/29/2002 2 Report Date: 6/912002 5/28/2002 End: 6/13/2002 , ,.".",.". "Cement Job.. Typ'e:: .prima,y. ,,'.' .,." ,. '. :~-~'~!:~,'.~.~~~~~~m~!Y~~_~~::~~~~~~~.=:~~~_7:~A~~~S;i~Ð~~~!~:~~~~_7.~.1_~~:~S~.~~;;~;i~:ç~~i~i~"'~=~.~-;=-~~~=~~=:==~-~~.~~~~_?,~.~~~~~?~~ Hole Size: 8.500 (in) Hole Size: Hole Size: Hole Size: TMD Set: 10,074 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 6/8/2002 sa Date: Date Set: BTM set: (ft) Csg Type: Intermediate Casing/Li sa Type: Csg Type: Plug Date: Csg Size: (in,) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Cmtd. Csg: Cementer: Steve Doughten Pipe Movement: Reciprocating ~-~"-~.-~~.~r:~'-~~~~''''-~'.'~~.'''':'";''''..~-'-'I-'''''~:''~'":'r¥--",,,,,,-,w-"~~~,T:~,,:,,,,w--'~~7~.~-~.~,-'-:'~'~.".~-~-~'~i:--'~r~'''~~--;''':',7""-'~''..~-'':-'--'-:~-~~.~-"'~-~'-"~"":7'"-.~-.~-'~~'-:~"-:-:';~:-~~"'~'~~-~-~~"':'"~:--'_....:~-~...~...--:-'~'~......-~'-_.~~~~~.,-~'~, , .."'f'~p~fMo,,e~n1 Rot Time start:: Time End:: RPM: RecTime Start: 15:45 Time End: 19:30 SPM: 1 'I I' Init Torque: (ft-Ibf) Stroke Length: 15,0 (ft) Avg Torque: (ft-Ibf) Drag Up: 335 (Ibs) ""'~"'rr':"~''i'':,-'''r.'~''''''''T,:,~:'r'''''''''''''''7;~''''''''''~r:~'~''':-"'''"':~-1''''''I''M~"'''':~-~':"~::'~:''~'''~I''''''''''''''''''::'~:--~~I''''''''''''''-:''''''':''''"':~''''''';-~':''"¡'''''-~"'''':''~r::~'~"'''''''''''''''''''''''--','.' Max Torque: (ft-Ibf) Drag Down: 170 (Ibs) . '. ,,',. " " .,Stag~N():.1. ~f 1 ., ' I ' . , --.¡,......:..._..:,~_.- -~.__.~.......---,~-~~._~~.._.._..~~_.. ~.,I..._~...~-~~. ._--_.........; ----_.._.L..._---:__.._..~._-~.......'':'''''';~-~~;.._--''';",:,~,~ ~'~~._L.~'~;~ -~~._.;... .....-....... _..:....~._-~.._--._--~....:.~_....--...._..:....~.. 'O.. ....~........~ -_...._..J.~..."':-..:;.._..;--_......_.~---;--~-_.--:~..-.:...:.~._- Type: Cement Casing Volume Excess %: 40,00 Meas. From: 0 Time Circ Prior To Cementing: 4.00 Mud Circ Rate: 218 (gpm) Mud Circ Press: 520 (psi) Start Mix Cmt: 18: 17 Start Slurry Displ: 18:19 Start Displ: 18:27 End Pumping: 19:38 End Pump Date: Top Plug: Bottom Plug: Dlsp Avg Rate: 5.50 (bbl/min) Disp Max Rate: 5.90 (bbl/min) Bump Plug: Press Prior: (psi) Press Bumped: (psi) Press Held: (min) Float Held: Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbJ) Ann Flow After: Mixing Method: Density Meas By: Densometer , M.u~Data'" . ' ' , , _...~-_........._......... ......~- -.--........,-: .~---- ... _...~.....- .---'.........-----.......... ~----'-'--~"'-' ....J'~"-'-"--~-~"~""'--'-'" -..~ ""'- .:...-.....- - ..._-~- '... ''''''''''''''''-'--' _......_......~ ,--,,--~..._. .----. "- .........- ----- -.--......:. _: .......:- -.-.......:..-. .~_--:....._-_....... -------- _._-~_._. .~-.,;_.~....~_._. .------ ,- Type: Density: (ppg) Visc: (s/qt) Bottom Hole Circulating Temperature: eF) Displacement Fluid Type: PVNP: (cp)1 (lb/1ooft2) Gels 10 sec: (lb/100ft2) Gels 10 min: (lb/10Qft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) Stag~No: 1'Slurry'No: 1 of,3 . ' Io..._._~.- _.......-.------....._.._-~----,.._..._-~--~._-----_._----~-_. .._.~--~-~- -'''-~-'.__.~-_.~-'-_.'''-_._.'._'''--'--''''''._'~---''._-''-~-''''''--'--"""'-"'-_."--~--"--"'---~_. ..-.... Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Auid Loss: (cc) Auid Loss Pressure: eF) To: (ft) Description: ARCO WASH Class: Cmt Vol: (bbl) Density: 8.30 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRE FLUSH Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (oF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Temp eF) eF) Pressure (psi) (psi) Printed: 8121/2002 9:44:55 AM ) ) ~, ~ ~. ~' .' " PHll~LJRS,'.ALAS.KA, 'INC',. 'C,èmenting,'",Rep()ft Legal Well Name: CD2-48 Common Well Name: CD2-48 Event Name: ROT - DRILLING " 'r , ,P~ge ~'"of.3 Report #: Start: Spud Date: 5/29/2002 2 Report Date: 6/9/2002 5/28/2002 End: 6/13/2002 ',' " ~::~~""~-"~"'!T-~~~-'~:~''''''''''-''-;'~~-~¡''-~:"':':-~--:''-,~-"':"~~-:-~"':'""7.'~-:r-r-"7' -~~...,...:..,-rr-'~,~~-:--,-.r-",:",-~-~-",:"..-:---,.-rr-"':"~'-''':'''''''''~-7'''-'''' """',~~7; ~~:~-r--..:~.'~~~""-~"':"..--'~ " ','. " ,', " . " ,$tågø,No:1,SIU"rY~O: 2of"~"" ',,', , ' '. " -""'¡''''--'-'-''--,~.,-""-",,,,'''''':'-~-_........~........:.....----.'':..._. ......._-,.~. .....--'...,.---'------L.-.,'""-"""","-'-------,,¡,-,,,,,,,,,, ---- .....I._.......~- -'-........_...I....I._"""-~--_.J._.........--':" ---'...J..o....o.-o_-'---- .....I_."""",----_":'..J._"""","---------,._""",,,--':_- -...I..J._..........._-......._'-:.....J._.........-...:-~....:._.:. Slurry Data Fluid Type: SPACER Slurry Interval: (ft) Water Source: To: (ft) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (fP/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Time Compressive Strength 1: Compressive Strength 2: Temp eF) eF) Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) " I I I I" I I "I I --.--.: --- ,~._, :__:_.~~.~.,_._._-,_.~-~, :,:~~. '~:~~~~.~:~~~~..:_-- ~,.:~_._-~~,-~~~~~~~"~~~~~__1,~~~~~, ~~~'~-~.~~~:!.~ .~~~,~~---,-_.:_-~,--~:,~-, ~-, ::,-----~ ~~, ~-__.,~.l_.:.,,:_~.~.:-_,:,~,'L'~ Slurry Data Fluid Type: LEAD Description: Slurry Interval: 10,074.00 (fIJo: 9,234.00 (ft) Cmt Vol: 32.5 (bbl) Water Source: Slurry Vol:160 (sk) Class: G NEAT Density: 15,80 (ppg) Yield: 1.15 (fP/sk) Water Vol: 19.4 (bbl) Other Vol: () Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Time Compressive Strength 1: Compressive Strength 2: Temp (OF) eF) Temperature: eF) Temperature: (OF) Temperature: (OF) eF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) """-"--:''''''''''-~-:""'''.''-'I--:-r-~~---:"'''''''''''--~'---~'''':"''''''-;-':''''~-;'7''"'----:"''''''''''"-""-"""';:-"'-"""'-"-'-~;:-'-----"'" --:--;><f;_.-:',-...,.r-"'7'"-"',"""--",:-........r,-.--.;' --~.-"'" --~,'-~.'-:-;"""'_r...........-~,::-,-~-.....~-.,..:-_. ~',..... :~..~.......-_~_~a...,-.--:,-.~"'.-. --:--:-""",--,--:-"-.,.......--,,,;.....,--~ ~.... , , ",'$t4gé No:'f'$'~~,¥N():'3 Øf 3..AdditiV$$ . " ",' " . " ',' " ,- . " .. . . . " I'. "," ,~.=~=.~~:==-~:=!~~~~~~;¿:~~=~-=.=~=:=,::~::i~P;:=~=._~~~tZ~t1_=~~~:~='-=~~~~.':~~=~~~~~ê~;~==~~_:~=~~!'~.:== 0-46 DEFOAMER 0.02 % 0-65 DISPERSANT 0.25 % 0-800 RETARDR MID-T 0.25 % 0-167 Fluid loss 0.18 % --'.'-----'."_'__'R'__'__"RR_'__'R'__.'_'."---'---'----"---'--'-'-----".----'-'-----"---'--'-'---"---'-------..---.--.-.-----..---.--.-.-----..-.--.-.---..-._.__.__._-----_._._------_._------..__.__.._--_..~._.--,..----.,.--.-. Printed: 8/2112002 9:44:55 AM ) ') ~, ~ ,'PHILLIP$"Al.~$KAINÇ. ' , , ' I' , I . ',.' .1 , , C,ème.,ti'o9,Fteport, Legal Well Name: CD2-48 Common Well Name: CD2-48 Event Name: ROT - DRILLING Report #: Start: Spud Date: 5/29/2002 2 Report Date: 6/9/2002 5/28/2002 End: 6/13/2002 "'''''--~~"':"'"''-'-~1'''''-T""'r"~~~'''''--r'''-"':":"-''''''''''''~~:'"'7"7"""~~~~-''''.'""-'~'' ......,-:r-"t~~:--:'-'I7"'"~~"~""'~-'-'~"7~._--"-7""""~~'''''~'''''-'"7""f-"'""";~-~--.~'"",-r""'r'''':~~--"--r-r-:''7""''''''''''''''-:r'' ~.,..:........--.........-,-r~~""-'~--r"'1"-:"---~r""TT""":"--:. ",åa$it1g"Te~t" ,', "Sh()e:Test, ", '" ,', Li~erTQP'Test, " ',', ~..J._'-"""'::"'_~~.L...:-'_..J'_~'--'~~-'~..J._..¡,.~~,.~'.I__'-J~._---,-~~~~,..J'_~'-~~_':".'.~""""'---~-'" ~~..J"--'-~-~~~':"...I'~~~----..J.~~---,~~~.~.........--.:.~_'L..~........,~- -'---~..J.~"":"'_.,._..._~:.:~...._,-__.~_'L._...L__.~-_.:.'~._._~~'-'::""",-...I.J.~...~----,-.oJ Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: 12.50 (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N -, ~ '"7~:~..~~ "~""'..:"~~;'":'..r:'.~'.~.~:"-;~,""7".. ~'.-'.-::-':~: ,'-:~, ':'~'.7'.'-"~ :~~., ~~'-'-~~:"~~~'.'-'_.~'~"-:~: ' :-'''''''''~'~,~-;~'~' ~~.........~, ~:~-, :7";"', ~~,...~ ~"-:~.. -:-.~,.,......:.._~.....: -7'.,": ""~~~7. ~""""""""'::"~~' -:- ....... :-:~~..~.:-:-~.,..... -:.. ~~. -:-~ -"'-':"-7r~'.'I- ~._~~:~c,~,5~{~_~~l,:~~~1~~r~~.,~:_,.~-~.,~~~,~_.._~c.~~,~~-,~,~~'"~~--~,~~:"~~~~~~~~~~~~--~~~~-~_:~~~-~,--~-'~'.,:_,~~,~~--,-~-~~ CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N I I ~:-.~"í7',~~~~'~.-~:.~'~'~"--,r;,~'7--,~.,M:"-,~~7~ " , ,~em$rIç$" " ~~._....,~,...:.~~~-~........,.l'-',':':'Ji',-~:..'......,.:._.~J'~~~'''''''''.J .......:..~i~.: -;~..l_, ""';~;"-'_..J.....':'_,~~~~~~.'~..l""~":'~':~'~.l- ~Ji~...~._..l.. ~~~~':~~~_':"'~'~--~:........~ ~~~~-~'--~- ~~~~~~,~~-,~.:~~~- ~..I.-'~~~_- '_~..1~':"'J__.._, J....~'" -"J~~~ ''''',--~''''''-'-''''''''''''''--'",,":'''''-:-'''-'''' . 'I 1'1 , , ...,-.....-.....-...--'... Dowell cmt well as follows: Continued to reciprocate 15' I 2 minute cycles. Pump 5 bbl fw followed by pump & line test to 3500 psi. Pump 20 bbl ARCO pre flush, 50 bbl Mudpush @ 12.5 ppg, drop bottom plug, follow wi 34 bbl batch mixed slurry [160 sx] 15.8 ppg [yield 1.15 ft3 I sx]. CI G + adds. Pump @ 5.3 bpm I max pressure 580 p si, avg 500 psi. Drop top plug & disp wI 20 bbl fw. Hand over to rig for completion of displacement. Rig displace wi 358 of 362 calculated bbls, avg pressure 480 psi I 5.6 bpm, final displace pressure I rate 450 psi 14 bpm. Bumped plug to 1000 psi, h eld 2 minutes checking floats holding. CIP = 1936 hrs, Rd cmt equip & Id Idg jt. Csg landed off wi mandrel system in well hd @ 10074' rkb Doyon 19. Printed: 8/2112002 9:44:55 AM ') ) Zm...~,~' ; " . ~--vo--I ' . . . , PhiUiP':'~la$~'af ~nc~ . . '. Dái'ly[)t~ning~epørt ' , ,', " , .., .. JOBNUMBERI'EVENTCODE I'~'HRSPROG ' 'TMC' 1M 'rDFS IREPTNO. .fDATE CD2-48 --.-,. ODR L -_..1.Q~.:9 7,261.0 10.00 11 6/?(2002- ,:.UP::~~;~~~rley I R~.::_~;:'9.;@~~~,~.~.,.1~.___._J:~:~:.::~~~~::~.__._-.__:~~J;~~:.9._t:.~~ TA~~ .__._.__J~~~.~_~_N~.OO ---.-.-. CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTWIO MUD CUM INTANG WI MUD ._,--_..__..._.._,-,.__.,-_......._--,.._...E.!Ç.~l!1JLYP.-..1:::i!_r1!Lplp-~.___,.__.. -..------,.--..--.--.---..-...-.,.-,------.-..,--...--,.--. .--..Q:.Q9.--.-.-..--..---,..-..-,...,.-.--,.--..Q.:,Q9--..--.--.".."-- 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD ._--_..__._.._B.tH.tJ~~t~_sJL..£!~~D._~Y_U~PLl?!l!!J!_-j.!.~:.h~J~: ----,--- ,.. Ê!l(l:Q9J._,.._._._----_.,_..____-Æ§M.L~3 1,Z~1,.r~§--,._._-- ~DÄ~--t=~=-;;j:;:;;:l:~IÑEXT:"G 998~-~H~~~- ___ß.l~~g~___.._-_tQ"Q£?'~Q..-,_.._.,J~§'~?.Q-,. 154.419_...l.1.:.QQQ-(~..@'--_.1Q!.QZ4.01ID. ---jt~) @ . (ft) __917/2002 -'~!'t~1!!(Pi.~t L-.1.!9:~.,.".- .L!!_L.., ._~.,-.~ "'é".': .J.!~P.J._, .__.J.M_Y,QJ~)~frM_~~,~V,-~g-~r.J ,-_.._-,-,p.:,~-- -. - .'.-. .L~~~J?~Il~_. ._'7C"--_O.:~,~ .__._~ ",-- , FV ' ' P"tV,P~L$~. .YVl1l-!'rMP : F~J1:~O,L Ø1yW~T ~4~FI"/IV'$T '., PhfPV' , Pt(~., CI' '" ca. 'H~S.. L'~,~$" 44 1 5/7 4.4/10.0 11 I 117.5 9.01 I ,Page'.fôf 2, WELL NAME -_ø_-.----ø----. ~~~~i~Z~~Æ':~~-E~¡i~:~i~I~:~!~~~~~~~j?f~~~~=~2?=7E3==2S~ 00:00 00:30 0.50 CASE P RURD INTRM1 1 0085' m d [ 726 l' tv d ] . Com pie t e r u c s 9 e qui p . 00:30 15:30 15.00 CASE P RUNC INTRM1 Run s hoe t r a C k & a tot a I 0 f 23 6 j t s 7' x 2 6 P P f x L-8- x BT&C Mod, Ck float equip, Brk clr @ 4 041,6590, & 8700' Run to 10040, pu Idg jt & hanger - landing out csg @ 10074', Stage pump up each cir to 3-4 bpm. Start 15' reciprocation a s soon as landing out, staging up pump to final ...-. ,----,-.---.---.-,-.--..,-----,.-.---.---,-...,------,_?J._-~~-,P-..~,_!"",!..Q,Q....E..~.L..___, -.,--..-.--,-., --..--,-.-,...-..---- 15:30 18:00 2,50 CASEP CIRC INTRM1 Make up cmt head. PJSM & ops meeting. Cir co nd mud lowering yp to < 20, Final clr rate 5 bpm 1500 psi. INTRM1 Do well c m t well a s follow s : Con tin u e d tor e c i pro cate 15' I 2 minute cycles. Pump 5 bbl fw follow ed by pump & line test to 3500 psi. Pump 20 bbl ARCO pre flush, 50 bbl Mudpush @ 12.5 ppg, dr op bottom plug, follow wi 34 bbl batch mixed slur r y [1 60s x] 1 5.8 P P g [y i e I d 1. 15ft 3 I s x]. C I G + adds. Pump @ 5.3 bpm I max pressure 580 ps i, avg 500 psi. Drop top plug & disp wi 20 bbl fw Hand over to rig for completion of displace men t. Rig displace wi 358 of 362 calculated bbls, av g pressure 480 psi 15.6 bpm, final displace pre ssure I rate 450 psi 14 bpm. Bumped plug to 10 00 psi, held 2 minutes checking floats holding. CIP = 1936 hrs. Rd cmt equip & Id Idg jt. Cs g landed off wi mandrel system in well hd @ 100 .____--7 4' r k b D 0 yon 1 9 . NUND INTRM1 Pull we arb us h i n g, ins t a II pac k 0 f f & t est to 5 k P s i, 18:00 20:00 2.00 CEMENT P DISP -----~-- 20:00 20:30 0.50 CASE P 20:30 00:00 3.50 WELCTL P BOPE INTRM1 Ins t a II t est p lug, x - 0 u t ram s to 3. 5 - 6" v a ria b Ie. Test bope to 250 I 500 psi high I low, annular t 0 250 I 3500 psi. Recover test plug & install wear bushing. Printed: 8/21/2002 10:27: 12 AM ) ') Zœ'.'~,".~ , I " , '--v--' C02-48 Phinip,"AI~8~a,~nc~ " , P¡¡lly, Dr~IUng~epo~" ¡JOB NUMBER [EVENT CODE I24HRS PROG ' ITMD" [rYe OOR 10,085,0 7,261,0 P,age'~,of 2 WELL NAME 'I DFS I REPT NO. I DATE 10,00 11 6/7/2002 -------.----.-- _._~_._-----_._-----_._- ---.------- -'--'---"'-'---~'- ~~_~.~~UMMARY: ComPl!~~!_l:'!!~~-~,~~~~~.,!~~~asing with s~~.~-~~g2?~. FC @ 9~!:.. ----"----'-- ~~~.~~.~""~~+-=::~=~-=~=::~~~~:~=¡~.=-~~:~:::=-=.=:~=--'-_egBïQNt!~£Q~~!A~=:~=~-'~-~~~=~==~~~~~=:~,-=--=~~~~~-~~~~:7-~~-==~,~: -,_:.~~~~~~~.:~N~.___~-~.~;.~~,---~~~.~!C?~.._...:.~~._~~"'~'_~-"~~~!_~"'~'~~~~C?~~~~!:!..Y~--~~--~-'"-~~~-'-':'~~~~~~-"~~~_:":"~-~~i~~_~~~UR!.~ .f>~.illips -~- ML_.____---.---- -_._---_._.._--------,~---,--_..._.._- -~~~~_._""--_.._,_.__._---,--_._--_._-_._,--- ---,--_._,~_._----,-_..._,--~!~~~,--_._,---,---_.- ..--,-- ---,-~ BHI 2 FMC 1 '---.'--__H_'__'_"----'-"'.'-'-------'--'--.-----,-..---.----.-- ..------..-.-..-..- ".'--.---------..____n_'_"_.,----.-,,-""----,-.,,-,-,.,,-._--- ".'-'-------.".'- ARCA 5 Quadco 1 ..---.....-..--..----....--..-.-.----........--..-.-. .----'..""_..'_._._---~'.'.'_.._._.__.__.....__.n__.--.........-..-.-.---..,......-..-.---.---.......-..-.--.---,.-....-..- -.--"'..""--.-'-"-- --......".-....-......---,......- ..~.~._---_..,'_.__..._--,---_.,_._-----_._._.,_._---------"-'----,------,,-,------------- 4 _.._-----,--_.,~.e.<?~-~_.__.._._-_._----_.._._--------,_.----------_._...._._----_.._._-_.__..._-_.._._-_.~-_.._._.._-----_.. Dowell 2 .-.....----.--.-,....-...----.--.-.-...-----.-- -.....-------..-.--..---------.--...--.---.--.---.-----.--.-,.....----..-..-....-...--------.--...-----.--.--.------.--.--..--------.-.-...--,-.----- ~~"7:~:'-~-"'~'I~-:~"'~¿'.~"_I"":~~-"~;:~:"_~'''~':~~-~-~..~,:~'IVIAIL~A~.~.1P;gN§U~P~t~L,;.~~,-~_:~~.i".~,,:~';.r-.'~"~¿''-7~7'''"~--''F~..~~2 " ":, I;rEM ",'.," ',' "'UNI'TS'" 'USAß,E" ':.ONHA~~ ' ,<'11eM, 'I,' ":, , , UNITS" ',"U$AO,r: '()N~Af)lO' .~~~!.,-_......._,_._......__.._.._._._.._,----,-,-~~~~-_..,.._-,_._.._,-_....._-,..._.~~......_-,_._.._._:.!_!L~.?~__.._._~~~-~.!.~g~~~).~._.....,-_.._-_.._..__.._._-,-~~!!_.._.,._,-_._.._.__.....--_._!_~...._..,'-_.._"-,_......~-~~_!_~_..._._- Water, Drilling bbls 25 -8,715 gE~2Ë2j~E3~==2~:=~~~1=~d::~=;~~:S:?iE~i~~¿;= CD2-17 437 C02-48 -"-''''-'''--'"-----'--'' .,-----..-.......-----.-. .,---.--..-..,--.-. .-...---..--.-..-.- '.'----."'''.-.''''''----'.'-.-'''-- Printed: 8/2112002 10:27:12 AM Welf Name: Drilling Supervisor: CD2-48 I Rig: Burley / Bowie PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Doyon 19 I Date: 08-06-02 I Volume Input Pump used: I Cement Unit [... Barrels ... .. Pumping down annulus. Hole Depth 9,232 Ft-MD 6,910 Ft-TVD /,., Pressure InteqritvTest Mud Weight: 10.8 ppg Inner casing 00: 7.0 In. Desired PIT EMW: Estimates for Test: 15.0 ppg 519 psi 0.4 bbls 1.1 Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: 18-1/2" I. Casing Shoe Depth RKB-CHF: 34.7 Ft 2,550 Ft-MD 2,375 Ft-TVD Casing Size and Descriotion: 19-5/8" 36#/Ft J.55 BTC Chanaes for Annular Adeauacy Test Enter outer casing shoe test results in comments Casing Description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOe for Hole Depth, Enter inner casing 00 at right. I. EMW = Leak-off Pressure + Mud Weight = 570 + 108 0.052 x TVD 0.052 x 2375 . EMW at 2550 Ft-MD (2375 Ft-TVD) = 15.4 1000 - UJ 0::: :J ~ 500 - UJ 0::: 0.. 0 0 5 2 3 6 4 Barrels """CASING TEST ---LEAK.OFF TEST Comments: 9-5/8" casing shoe test 16.0 ppg FIT. Did not bleed off test to cement unit. PIT 15 Second Shut-in Pressure, psi 434 8 9 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point .. CasinQ Test Pumping Shut-in Bbls si Min si 30 Volume Volume Pumped Bled Back 0.0 Bbls _Bbls ... Pump Rate: 0.5 8bl/min ... Pressure Integrity Test Pumping Shut-in Bbls psi Min psi 0 20 0 450 0.5 80 0.25 434 1 141 0.5 419 1.5 217 1 409 2 283 1.5 404 2.5 348 2 399-- 3 414 2.5 394 3.5 470 3 389 4 525 3.5 384 4.5 570 4 379 5 545 4.5 374 5.5 449 5 374 6 449 5.5 374 6.5 444 6 369 7 459 6.5 369 7.5 470 ; 7 369 8 465 7.5 364 8 359 8.5 359 9 359 9.5 359 10 359 "~/ Volume Volume Pumped Bled Back 8.0 i:sbls _i:sbls \ \ \ OOIiL- -'\ OOJ.L- OQOL' ~ ~llOn l. 0«1- oOla- 0011- 001:, / ~ 1 ~: / /~ 1: 00' ,: ~-........", .~"" W.' / /;::.///. .....-~_/-.-W) ~ ::~ ~ =~ ~=-=--=---=;Z¡¡O~-F ~ ,m: .... >-.~,,~ i / ¿//'< //"" //... ~/A$J '--........ ",- -;:7 ..---/ -----~ """"""'......... ", a..~ ta/'D II :%': /.......- ,......- "",:;;'i1o.6 ~ -:?'" - .--- .----- -, - ""--'":::..'0.. " ø/. 0 ~ /' /~-_/'"" "'~ --:? /' /---::;:~- 8 " '" v /~ ///"':/ -..---,::--~ '- 0",,,,. 6 .?-// ¿:::::¿;:::/'""- ~~--~~~ 0""" 'W.,ì-;;¿:_,_--?/;-/ ..--,""'- '"'-., IiI.ijIoo iIIu 8..J'(: ......./ "'0 0;. ~»;7ò~;::::::=--/'""' -------:;;::-~--'\~:.:-;;~~::._" ----...----..-..'-...'.....,..---.----.--....--- ..~'" ,-~,:::......'.- .....-..---- /y "'."', --.... ;::....-"..../' --./.... "'''''''''', ¿::."-;'... /..- / .... /,:.-;-'''' ....... /' ....................~........ :¡: ~// ./ // /: 0 00II- ."-----/" /' / ........ ~ ., r..~~---"':/ / - ".. ' ------ .--- "'I... ;;.....~........... ~ OOl :($Y-_/ \ '---.---.------------ ::;:-, :; 00II- / ~ ~ 001 """"".",'.'""""""" , , , , , , , , , , , , , , . , , , , , , OOt - 001 ,- 001 ,. OO~ - om - 00;0- OO'P~ CXK:~ OO~L OOLI OOOL OOQ 005 ooo~ DOLI. Qœl. tlnt~ no,~ oo,~ OCtH It 001 ,= 4~ul ~ QIQ~S (~99~) ~S9M -> D)SDI\f '9dolS 4.J°N : UOJJDOOl 1:117 : 119M Pie!.:! 9u!dl\f : PI9J.:! 'Z#C'J : ÐJn~onJIS ~ :!fL .(ti ~ u~ao) U>4t1 IOUIU.~'J 11.10 841d'Cllnp~.^ In,! 'viii tOl" IKHUa...."w ~'I "I aiD '~Ul.llp.tOO;) '<.~DtL-'O> CWMI'IOO\lO"'OIIlOlo ZDOZ-unl"'~"'Z : p~,otd ~r.o ¡IDI.IDlwq J..q pI~~~~--"-,.."._-_...,_. ifd:-¡ ,#u,-~~ I ~~ -""__'__"'W""---"-,"",--_._,,~,--,-,,",.,..~_._._-,..",-----..". .----. "" . -_'_'._-.,_._.......--,....,--_..-..,.~,,_...._-,~- ...--... . . 0lI1 'BY(SH[V sd 1[1111IcI -"--""--".'''''._''''--'''--'~-''-'--'''''-''''-'"''''''''''''-''~''-''''''--'''-'''''-''-.~w-'-'"-''''''-'~-'-'-'---'-""-"-"'_...n."._..,..-..--...-".-.,-,-.-.-...-.",.....~ ( ( SURFACE CASING SHOE SEPARATION FROM CD2-48 CD2-48 X Y Surface Casing Shoe ASP 4 Coordinates: 371631.74 5973736.14 Distance Suñace Suñace 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. Coorct. CD2-35"'* --- x x 1 ----- ---- ---- 737 372312.31 5974017.68 CD2-24, CD2-33, CD2-33A, CD2-42 301-140 6/1/2001 x x 2 CD2-15 33992 6/112001 1 0/1 0/2001 592 371098.46 5973992.48 CD2-33 (+A&B), CD2-39, CD2-24 301-186 7/13/2001 x x 2 CD2-14, CD2-15 33999 7/16/2001 10/9/2001 1405 370630.11 5974721 .81 CD2-33 B*** --- x x 4 ---- -----' ----- 1484 370155.64 5973886.23 ~ CD2-39 301-281 10/9/200 1 x x 2 CD2-15, CD2-47 27879 10/10/2001 11/12/2001 726 372350.61 5973633.17 CD2-14 301-288 10/9/2001 x x 2 CD2-45, CD2-47, CD2-32 31073 11/1312001 3/512002 1351 372202.47 5974960.87 CD2-15 301-308 11/6/2001 x x 2 CD2-50, CD2-25 21093 3/6/2002 4/2212002 1482 370832.00 5974984.02 CD2-47 301-322 12/3/2001 x x 2 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 596 371231.72 5973294.19 CD2-45 301-345 12/13/2001 x x 2 CD2-49, CD2-17 22991 1/20/2002 2/19/2002 1139 372765.13 5973853.74 CD2-34 302-069 3/4/2002 x x 2 NA 0 724 371803.06 5974439.79 CD2-26 302-068 3/4/2002 x x 2 NA 0 835 371798.52 5974554.55 CD2-49 302-070 3/4/2002 x x 2 CD2-50, CD2-46, CD2-22 27960 4/2212002 5/28/2002 503 371252.38 5974065.93 CD2-17 302-122 4/1 0/2002 x x 2 CD-48 15434 5/29/2002 6/13/2002 920 371774.00 5974645.00 CD2-32 302-119 4/30/2002 x x 2 CD2-19, CD2-41, CD2-23 31113 6/1412002 7/23/2002 658 371295.61 5974302.38 CD2-50 302-121 4/30/2002 x x 2 CD2-41, CD2-19, CD2-16 17900 7/24/2002 8/18/2002 493 371665.21 5974227.65 CD2-46 x x 2 NA 0 578 371694.80 5974310.85 CD2-22 x x 2 NA 0 827 371678.61 5974562.30 CD2-48 x x 2 NA 0 0 371631.74 5973736.14 CD2-19 x x 2 NA 0 1149 372284.88 5974681.33 CD2-41 x x 2 NA 0 365 371990.58 5973802.52 CD2-23 x x 2 NA 0 1488 370996.57 5975081.46 CD2-16 x x 2 NA 0 1356 372471.24 5974801.40 CD2-29 x x 2 NA 0 1580 372680.00 5974918.00 CD2-38 2 NA 0 473 372057.13 5973528.38 .~ x x CD2-44 x x 2 NA 0 724 372041 .40 5974333.45 '" Distance in feet, between surface casing shoes, in the X-V plane - CD2-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted for annular disposal. "'-CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. - As of 18-Aug-02 ~s OCJ II. ) WE'LL LOG TRANSMITTA:L ) Ò03-J6t' ProActive Diagnostic Services, Inc. To: AOGCC 333 West 7th Ave. Boo. 100 Anchorage. AK 99501-3539 RE : Distribution - Rnal Print( s] 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 : Joey Burton / Jeni Thompson ProActive Diagnostic Services. Inc. P. O. Box 1369 Stafford. TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BLUE LINE Open Hole 1 1 1 CD 2-48 8/3/02 Res. Eva!. CH 0:7 () @ ~, Mech. CH Caliper Survey 1 Rpt or 1 Color Signed: d~ G- Ooep-.J Date : i;lil:.~;;i~ "-", , --"':',,- ~'",';~ t ~,~- l , t J.u,. , .J' Print Name: . t' ','. J (, 1-,.../ .I "'!i~) t ~- "<~:~~~':'~.i~{~~i,:r~;l~ Î.~ -.';~',I.,'l, ""I.' ,. .1 A!-- - - ., . ",)lnr;,Jj:+ft~,~:.; PROAcTiVE DiAGNOSTic SERVicES, INC., ~ 10 K STREET SUiTE 200, ANChoRAGE, Ak"' 9'9~Ôl~ Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memorylog.com Website: wW\Y.memorvl0,g.coll1 08/06/02 Schlumbergel' NO. 2298 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth 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 CD2-48 ~d"lo1 22324 SCMT 06/20/02 1 '----- SIG~ (..ß-Þ-p.--.......... RECEIVED DATE: AUG 0 9 2002 Please sign and return one copy of this transmittal to Sherrie atthe above address or fax to (907) 561-8317. Thank YCJ.tIaskaOil&GasCons.Comn1iaõion Anchorage ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor ltf\ Chair WM SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~- PAl P.I. Supervisor ' (\~ CD2 22,46,48 FROM: John H. Spaulding Colville R. Unit Petroleum Inspector Alpine Field NON- CONFIDENTIAL DATE: August 9, 2002 Packer Depth Pretest Initial 15 Min. 30 Min. Well CD2-46 Type Inj. S T.V.D. 7017 Tubing pas pos pas pas Interval I P.T.D. 202-082 Type test P Test psi 1754 Casing 550 1950 1900 1890 P/F f Notes: Well CD2-48 Type Inj. S TV.D. 7063 Tubing 747 747 747 747 Interval I P.T.D. 202-108 Type test P Test psi 1766 Casing 1050 1850 1840 1850 P/F f Notes: Well CD2-22 Type Inj. S TV.D. 6997 Tubing 1000 1000 1000 1000 Interval I P.T.D. 202-092 Type test P Test psi 1749 Casing 450 1950 1875 1875 P/F f Notes: Well Type Inj. T.V,D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year CYCle s = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details I witnessed the MIT's on the above wells located in P AI's Colville R. Unit. As noted in the above report all wells stabilized in their respective pressure tests. M.I.T.ls performed: ~ Attachments: none Number of Failures: Q Total Time during tests: 3 hrs. cc: none M IT report form 5/12/00 L.G. mit cru cd2 8-9-02 js.xls 8/14/2002 ) @ IT ~CIT, ~ rñì. (] fþ ~u~ul uvû !r:l¡.' n (i:\ (éù n f7 r¡;\ ; ß\ lL'~ 11\,' fJ\ ~,\, ¡ ~\,f IÜ\, WLlñ.\Q2JLfuU-U AT,ASIiA. OIL AND GAS CONSERVATION COMMISSION Chip Alvord Drilling Team Leader Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit CD2-47 Phillips Alaska, Inc. Permit No: 202-108 Sur. Loc. 2043' FNL, 1505' FEL, Sec. 2, TI1N, R4E, UM Btmhole Loc. 731' FNL, 784' FEL, Sec 14, TI1N, R4E, UM Dear Mr. Alvord: , , \ Enclosed is the approved application for permit to drill the above referenced well. TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. . 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 pad must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 baITe1s through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (/J1ttA M.. ^/~.1~.t/ ~~~~~chsli Taylor 0 Chair BY ORDER OF THE COMMISSION DATED this 23rd day of May, 2002 jjc/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ) 1a. Type of Work 2. Drill X Re-Entry Name of Operator Phillips Alaska, Inc. Address P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface Redrill Deepen 3. 4. 2043' FNL, 1505' FEL, Sec. 2, T11 N, R4E, UM At target (=7" casing point) 2356' FSL, 2432' FEL, Sec. 11, T11 N, R4E, UM At total depth 731' FNL, 784' FEL, Sec. 14, T11 N, R4E, UM 12. Distance to nearest 13. Distance to nearest well Property line CD2-47 / 784' FEL Sec. 14 feet 9.9' at 300' MD T11 N R4E 16. To be completed for deviated wells Kickoff depth Maximum hole angle 1750 feet loP 5:.Y¡Vi,flÚ74 r~ jr-> ¿~d u/e!(:j5 . C/)¿,-~ L)¿f~ I D}.J~,r tVq,uer o¡t vff:f- 51 t2/0L ~ S(l..l.--- Stratigraphic Test Development Oil Single Zone X Multiple Zone 10. Field and Pool Colville River Field Alpine Oil Pool ADL 380075 7. Unit or property Name Colville River Unit 8. Well number / CD2-48 9. Approximate J'Ud date 5/30/2002 14. Number of acres in property Feet 2560 ') feet 18. Casing program Setting Depth size Specifications Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' 12.25" 9.625" 36# J-55 BTC 2526' 37' 37' 2563' 2394' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b Type of Well Exploratory Service X Development Gas 5. Datum Elevation (DF or KB) DF 52' 6. Property Designation 11. Type Bond (see 20 MC 25.025) Statewide Number #59-52-180 Amount $200,000 15. Proposed depth (MD and TVD) 13629' MD 7272' TVD feet 89.96° Maximum surface 2563 17. Anticipated pressure (see 20 MC 25.035(e)(2)) psig At total depth (TVD) 3267 at psig 7220' TVD.SS 8.5" N/A 26# L-80 12.6# L-80 BTC-M 10091' 37' IBT mod 9581' 32' 37' 32' 10128' 9613' 7" 4.5" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20, Attachments Filing fee X Property plat Drilling fluid program X Time vs depth plot feet feet Plugs (measured) feet feet Junk (measured) Cemented 7262' 7127' Ð""!o ,... ~,'" ¡¡:..., ~ , ' Ii [<) Ð'\. t (.~ t ~ \f [:' .~7 'j/W) \ ! ~1J¡J... Quantity of cement (include stage data) Pre-installed 475 Sx Arcticset III L & 230 Sx Class G 141 Sx Class G Tubing Measured depth True Vertical depth .(\lo/'k:1 em & ¡.J¡:¡'~ .cCPS ClllYln1iSsiorl . . BOP Skefèf1 ~ .An8\~&ketch Drilling program X Refraction analysis Seabed report 20 AAC 25.050 requirements X Signed 21 . I hereby certify that the foregoing is true and correct to the best of my knowledge Drilling Team Leader ~[ O£Z Permit Numb~r I API nUlJlber :z.c <...- /ð? 50- Æ7..." - 2.0 $I .2.... :L Conditions of approval Samples required Yes Hydrogen sulfide measures Yes GJ Required working pressure for BOPE 2M 3M Other: Tt's t ß~ P E fo 5000 f i ~. M1:T I r¿y W AA f... 'LS. 0-;5 (~) {z. \ ct \/e-{ tel" On'gmal SÎgnãd By Approved by Cammy Oochsli Tayk>1 Form 10-401 Rev. 7-24-89 Date 5(11 (~L. Title Commission Use Only I Approval date c.:;~ 0- ~~ I See cover ~etter for I j~" ) \J Otë;Jer re Ulrements /Ño~ Mud log required s 0 L./'Directional survey required G No 5M 110M J5M ¿, I d tMAT, qtL~ n¡ c] ~ ,.0 N? . '( '( ~:~ !4. ~wt ¡ s \1\.' t<..{ ".e d . ik1~~ U by order of Commissioner the commission Ii I" I ¡,I I,: '.. / I Date VJ s~~r Q~ ) ) CD2-48 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 19-518" CasinQ Interval Event Risk Level Conductor Broach Low Well Collision medium Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVD Lost Circulation Low Low 8-1/2" Hole 17" CasinQ Interval Event Risk Level Abnormal Pressure in low Surface Formations >2000' TVD Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low M itiqation Strateqy Monitor cellar continuously during interval. Gyro single shots, traveling cylinder diagrams Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Increased mud weight / Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries M itiqation Strateqy BOPE drills, Keep mud weight above 10.4 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 7001 of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers / .6-1/8" Hole I Horizontal Production Hole Event Risk Level Lost circulation moderate Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low Mitigation Strateqy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, 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 (ECD) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 9.0 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers / ') ') Alpine: CD2-48 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 16. 17. 18. 19. 20. 21. 22. Procedure / Move on Doyon 19. Drill 12- %" hole to the surface casing point as per the directional plan. I Run and cement 9-5/8" surface casing. Install and test BOPE to 5000 psi. I Pressure test casing to 2500 psi. ¿/ Drill out 20' of new hole. Perform leak off test. Drill 8-%" hole to intermediate casing point in the Alpine Sands. (LWD Program: GR/RES/PWD) Run and cement 7" casing as per program. Top of cement> 500 feet MD above Alpine reservoir. Carry out ~' a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 5000 psi. / ( 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. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. / Run 4-%, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrel and packer. Land hanger. 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. Circulate tubing to diesel and install freeze protection in the annulus. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 ~i 1 30 mins. Set BPV and secure well. Move rig off. ') ') Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-47 will be the closest well to CD2-48, 9.9' at 300' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 7.7' at 300' MD. DrillinQ Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered 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 PumpinQ Operations: / Incidental fluids developed from drilling operations on well CD2-48 will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. The CD2-48 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 above the top of the Alpine as per regulations. We request that CD2-48 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 containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no 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 formation markers in this well. Surface casing will be set near the below the base of the Schrader Bluff Formation (C-40). These 300-400' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. 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) * (2394') + 1,500 psi = 2,994 psi = 1 ,083 psi Pore Pressure / Therefore Differential = 2994 - 1083 = 1910 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 850/0 of 850/0 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 ) ) CD2-48 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 / 9.0-9.3 ppg /' PV 1 0 - 25 10-15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 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 m in PH 8.5-9.0 9.0 -10.0 9.0-9.5 KCL 6% Surface Hole: A standard high viscosity fresh water I gel spud mud is recommended for the surface interval. Keep flowline viscosity at :t 200 sec/qt while drilling and running casing. 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 potential 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 well bore stability. Production Hole Section: The horizontal production interval will be drilled with aM-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with :t 30PPB 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. ') ) Colville River Field CD2-48 Injection Well Completion Plan 16" Conductor to 114' Updated 05/16/02 . 4-1/2" Camco DB Nipple (3.812') at 2000' TVD = 2044' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2562' MD / 2394' TVD cemented to surface Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope Tubing suspended with diesel Toe @ +/- 9313' MO I (>500' MO above top Alpine) Camco KBG-2 GLM (3.909" DRIFT 10) wi dummy Baker 53 Packer at +1- 9500' <200' TVO from top of Alpine :;¡jjI Well TO at 136281 MO I 72721 TVO Top Alpine at 9813' MD / 7204' TVD ~ 7" 26 ppf L-80 BTC Mod Production Casing @ 10128' MD / 7262' TVD @+/- 87Q .) ) Colville River Field CD2-48 Injection Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' Updated 05/16/02 . 4-1/2" Camco DB Nipple (3.812') at 2000' TVD = 2044' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2563' MD / 2394' TVD cemented to surface Packer Fluid mix: 9.6 PPQ KCI Brine with 2000' TVD diesel cap Tubing suspended with diesel 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope (A) Banzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe TOC @ +1- 9813' MD (>500' MD above top Alpine) (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Cameo KBG-2 GLM (3.909" DRIFT ID) wi dummy ~ÞØ Well TD at 136281 MD I !72721 Tf\VP .: I . .., @ i): Yi . Baker 83 Packer at +1- 9500' <200' TVD from top of Alpine / ~.. @ 0<]... ~~ " Top Alpine at 9813' MD / 7204' TVD 7" 26 ppf L -80 BTC Mod Production Casing @ 10128/7262' TVD @+/-872 ') ) CD2-48 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 : Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (Ibs. I gal) (psi) (psi) 16 114/114 10.9 52 53 9 5/8 2563 I 2394 14.5 1083 1566 7" 10128 I 7262 16.0 3286 2563 ./ N/A 13628 I 7272 16.0 3290 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) = 1083 - (0.1 x 2394') = 844 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 2394 = 1566 psi OR ASP = FPP - (0.1 x D) = 3286 - (0.1 x 7262') = 2560 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) / = 3290 - (0.1 x 7272') = 2563 psi ') ') Alpine. CD2-48 Well CementinQ ReQuirements 95/8" Surfáce Casin2 run to 2562' MD 12394' TVD. Cement from 2562' MD to 2062' (500' offill) with Class G + Adds @ 15.8 PPG, and from 2062' to surface with Arctic Set Lite 3. Assume 300 % excess annular volume in permafrost and 50 % excess below the permafrost (1557' MD). Lead slurry: System: Tail slurry: System: (1890'-1557') X 0.3132 ft3/ft X 1.5 (50% excess) = 156.4 ft3 below permafrost 1557' X 0.3132 ft3/ft X 4 (300% excess) = 1950.6 ft3 above permafrost Total volume = 156.4 + 1950.6 = 2107.0 ft3 => 475 Sx @ 4.44 ft3/sk 475 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% SOOI accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % SOOI accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casin2 run to 10128' MD 17162' TVD Cement from 10128' MD to +1- 9313' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (10128' - 9313') X 0.1268 ft3/ft X 1.4 (40% excess) = 144.7 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 144.7 + 17.2 = 161.9 ft3 => 141 Sx @ 1.15 ft3/sk System: 141 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk 1 By Weight Of mix Water, all other additives are BWOCement ~._---_._--- ----~_._-- )A-~ ') t I ""- + ). 0 I 0 I . I ""- + ~ 0 I 0 N ~ ) 12" FLOWLINE NIPPLE 18" 150#, SLOTTED FLANGE FOR NIPPLE ALIGNMENT 1 8" 20"x 18" CONCENTRIC ~ REDUCER I . 21 ~", 2M, RTJ / --cj þ- rh= =DI<J .-..~--- -----.---------- --..--..------------- -. -. --- -cv JWN, AJf..1:;:, \0. HY :iY - --.-.---.-.-- ".- --._-- - CESe~I~TIO~ ~~CJEeT 1111: ~,\lL . 03-2' -02 Se¡\ I \TS FMC ADAPTER 16" CONDUCTOR ~'iS IS ^ P~OPRI,TORY ~,SIGN 00 DOVO~ CR¡:J\C, ~o::>RC~JC~'ON OR LSo 00 DCSICt\S PCRWSSBLê O\~Y, AL71'0'<IZED IN WR-'NC 3Y DOYC~ DRU:NC -.,o,on -/ RIG 19 PROPOSED DIVERTERLESS RISER CONFIGURATION el ¡;:C~L() jy-.'.^'I;:~6VL.ÌJ-:3Y . _EA. .)I¡fi~¡N-':Jv- ~)WG, - t\-o~- DWG R"V C _EA ?J~::: SI . Phillips Alaska, Inc.: ~PHILLIPS~ , Created by bmichce: For: V Johnson Structure: CD#2 Well: 48 ¡.'¡f~"~ Date platted: 1 ~-May-2002 .....~"..~~ ~ Plat Reference Õ. CD2-48 Versionl5. Field: Alpine Field Location: North Slope, Alaska, Coordinat:C3 ore in feet reference slot 148. 'Tru> Vertica: Depth!! cr. rolerencø RKB (Cayo~ . -- .... INTEq ---- PROFILE COMMENT DATA ~-'=""''''''''''''''''~ ----- Point ----- MD inc Dir TVD North East V. Sect Oeg/l 001 Nudge 1/100 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.001 EOC 550.00 3.00 125.00 549.86 -4.50 6.43 3.50 1.00! Drop 1/100 800.00 3.00 125.00 799.52 -12.01 17.15 9.34 O.OO! EOC 1100.00 0.00 125.00 1099.38 -16.51 23.58 12.84 1.00! KOP 1150.00 0.00 í 91.55 1149.38 -16.51 23.58 12.84 o.ooi West Sak 1212.63 2.19 191.55 1212.00 -17.69 23.34 14.04 3.501 I Base Permafrost í 556.79 14.24 191 .55 1552.00 -65.78 13.51 63.05 3.501 C --40 2298.56 40.20 191 .55 2206.00 -395.34 -53.86 398.96 3.50! EOC 2504.92 47.42 191 .55 2354.82 -535.21 -82.45 541 .52 3.501 9 5/8 Casing pt 2562.83 47.42 191 .55 2394.00 -576.99 -90.99 584.10 O.OO! C-30 2577.61 47.42 191.55 2404.00 -587.65 -93. 1 7 594.97 0.001 C-20 3124.47 47.42 191.55 2774.00 -982.18 -1 73.82 997.09 0.001 K-3 4695.58 47.42 191 .55 3837.00 -2115.64 -405.52 2152.37 0.001 Basal K-,3 4988.22 47.42 191 .55 4035.00 -2326.77 -448.68 2367.55 0.001 K--2 5032,56 47.42 191 .55 4065.00 -2358.76 -455.22 2400.16 O.OO! Albian-97 7248.08 47.42 191 .55 5564.00 -3957.12 -781.96 4029.28 0.001 ~ Albian-96 7926.49 47.42 191 .55 6023.00 -4446.55 -882.00 4528.13 0.001 HRZ 9023.16 47.42 191.55 6765.00 -5237.73 -1043.74 5334.54 O.OO¡ Begin Final Bld/Trn 9244.37 47.42 191 .55 6914.67 -5397.33 -1076.36 5497.20 o.oo¡ K --1 9336.60 50.90 185.86 6975.00 -5466.25 -1 086.83 5566.91 6.00! l_CU 9489.83 57.21 177.59 7065.00 -5590.01 -1090.19 5689.81 6.00! Miluveach A 9694.83 66.35 168.23 7162.00 -5768.71 -1067.32 5863. 16 6.00! A!pine D 9741.75 68.52 166.29 7180.00 -5810.96 -1057.76 5903.53 c ¡ 0.001 Alpine C 9812.54 71.84 1 63.47 7204.00 -5875.23 -1040.38 5964.52 6aOOl I Target -- Csg PL 10128.30 87.00 151.87 7262.00 -6160.69 -922.28 6229.34 S.OOr EOC 10424.48 89.96 151 .87 7269.85 -6421.76 -782.68 6466.86 1.00! JO -- CS9 pt 13628.81 89.96 151.87 7272.00 -9247.48 728.28 9037.75 O.OO! ,....---. '1 Phillips Alaska, Inc. 4HIWPS\ .Jt';~4. ~ ,~ ' I C"",t.o by bmich..1 For: V lohnson 01>1. pl.tlod : 14-MDy-,nD2 Plot r~.",.nc. I. CD2-4e V...1o",ð. Coardlnclca Dr. In foel, rlll.,on,", .IDI 148. Try. V.ttõcel Depth. era ref"GnGO RKB (D"I"'" 1 g). 450 0 - Structure: CD#2 Well: 48 Location: North Slope, Alaska I- Field: Alpine Field - _111 - j;¡:¡~'--- A. RKB Elévation: 52' - 0,50 C NIJdgc 1/100 1.50.. 450" 2.50 t: EOC Drop '/100 900 - 2.00: 1,00: t<8~ 3.50;¡ West Sok 1350' 1'~~~' 14.00 1"7.50 21,00 28.00 35.00 ' 42.00 1800- ........ 2,250 - (D Q.) ~ 2700' ..c: -+- 0.. 3150- Q.) a ã 3600 - 0 :¡:: L () > 4050... Q.) :J L 4500 - l- ' V 4950 - 5400 - 5850 - 6300-' 6750 - 7200 - 7650 450 DLS: 1.00 deg per 100 ft DL.S: ~t50 deg per 100 H Bose Permafrost lBB.51 AZIMUTH 6229' (TO TARGET) .uPlane of Proposal"''''''' C'..40 EOC 9 ð¿~o Casing pt TANGENT ANGLE 47.42 DEG DLS: 6.00 deg per 10Q It 'r\~'L. Begin Final Bld¡rrn 'i-" '\ CÙ oc~~ C c,~~ ~\, 49.~9 \,.; ,(~\!~,e.\(le \(le " 5 ~f!g ",,\ p"ç þo.W ~op"" . ......., 0 85.63 ~ 48 0 900 1350 2250 2700 3600 4050 5400 6300 4500 4950 5850 3150 1800 450 Vertical Section (feet) -> AzImuth 188.51 with reference 0,00 S, 0.00 E from slot #48 ') """_.",..._.._,,'~'~- . --.." ..- -""-""_._-.."-'~'-.""''''~''-''-''- . Structure: CD#2 Well: 48 I;HI~ip~ rllli '-¡;;~~ï,;dbÿ¡';;;I~h';;'¡-:è~~;-.v.i~-b~~~~1 Dat. plotted: 14-May"'2002 Plot R.,...... 10 CD2.,.48 Vwolon'3. Coordinate. .r. In Io.t ,.Iorono. .Iot 148. TN' V.,lio.' Do.tI\. or. ",r.,on.. RI<9 (00\'0" 19), Phillips Alaska" Inc. Field: Alpine Field Location: North Slope, Alaska .£ ~ <- West (feet) 3000 2500 2000 1500 1000 500 0 500 1000 1500 500 E'bugge 1/100 fó8P 1/100 - 0 KOP Base Permafrost ,0 500 Casing Pt -, 1000 ..1500 - 2000 - 2500 - ::5000 - 3500 (/) - 4000 0 C -+- :r - 4500 "....., -+. () () -+- - SOOO .......... I V ..,5500 - 6000 - 6500 - 7000 - 7500 - 8000 - 8S00 [--;~~~F~ï~.~-L~~t~Õ~~O~-'-1 SEC. 2, T11 N, R4E .. 9000 188.51 AZIMUTH 6229' (TO TARGET) .."Piano of Propo¡mlu* I"-~~~Gg~~~~~~~~-~-l SEC. 11, T11N, R4E l TO LOCATION: I 731' FNL, 784' FEL TO - Csg Pt SEC. 14, T11 N, R4f: -.--------.----,.------ - 9500 ) Phillips Alaska, Inc. Well: 48 LocatIon: North Slope, Alaska ~~HI.iìp~ .{!ltJJ ò Croot';:" bý -¡,~,id;.;o'''-F~;:-v-.i~.h~;~~- 1"'10 ploll,od : H-Moy-2OD2 ÞIO! Ref.",nco 10 CC2--48 Vo",lonlS. COOn:llMloo ore In f..l ,.(oron"" ...t #48. '111.. Vortico, Doplh. ntO ...r.,..,.. R~Ø (Cayon 19), Structure: CD#2 Field: Alpine Field . .. -. ......- -...,_. ,--.. ..," uP - ~ 70 60 I 40 I 10 I East (feet) -> 0 10 20 30 40 50 I I I I I I ~~ü' I % I Qb"" - 30 ~- ...20 eGJ)----....... 500 '-----._" '~.~ \ ~~ 1:300 ~o ~,'-¡OO , "'''~ \'~ . '~''-- ~qOO '--...,,~ 20 ~- 1II"~7 ,. .1800 700 . 2.1OÓ. 900 ' 900 .. 900" J'~ "p. 18 . . & ,. .,. "r 2500 ~._-~..~t):-' 1300 5300 ".- "" Jfo/"-/ I.....-'~'.~? Q.3OC .. /' '.500 /.." ~ ' 5500 ./' " ./ l!>oo ",700 ~ ~ /' ./ F500. ','00 ¥ / ./19300 . 11 00 w ///: /°0 ;/ " 1 :500 / 700 8300 : ----.......1-.1-00~0 / " I ~ ..500< ./ . "",/" ,~30 I l!Þ ",oo~. 0 . / .700! / ~~O' /{,oo ¡ 1500 300 500 I / .. . , ~oo . 500 300/ / .,. ;,1,:500 : ~ 1700 . 500/300< &.uO .700' ~ I I /8300 " '. 50D I " (i 300 I I 1l00~ I I I I I I I I I I , I I , I I f 1800 I 30 I 20 50 I ~ ///~ & c§> .'700 " 700 .900 &> .900 @ r!J 60 I 80 I 90 100 70 I .,900 [iD- -. 10 - 0 - 10 oj; 900 ..1800 30 .,700 .. 40 .1500 V) -50 0 C - - ::r- 111.900 ,., 60 ......... - .1900 (1) (') -+ -- '10 ......... I oj; 1100 ~ V - 80 11\ 700 - 90 ~: 700 .500 -~ 50l'} 700 ,,900 ~ ~100 11\ 900 ~~110 - 120 - .. 1700 -130 -140 -- 150 ~m - 160 f?- . " 700 ~ 900 'ð \è) "'ë;;;¡;'d'þ;ï;;~¡;;i;;;ï-F~~;'V'.T~~~~n-' Oat. platl4d : 1 +.-Moy-2002 Plat ~o1'ro.a. Is CD:!--4I! V""¡""fð, Coordlnot.. aro in foot rof......,. .101 *~e. T,... V.rllaol 0..1". a'" ,.r...n.. R~a (Ooyon 19). - -=- ïÑ-ï:;¡¡""""" 420 <- West (feet) 360 .300 240 180 120 60 at!! 60 ,120 180 240 300 ;560 420 1~0~'&/ø...' ~~I~ri>,.'(§;',~\0A<fh.'æfm~~,~,;'" I \3..~;.~~~ ' , " ./ ~r~ I /. 100Q I ,~~)', 1000 ,',,'?), 400' \ íØ. ~ ...... 2800 ~.~~~o /í 200"..'.. '.°00 1~00'",;,H.;ÓO",. , '~.' ".12.00,., '."':.. ~.., ~,V600~. ~~ /' // ' / // ~4001200' I .1800 '. '" " ..'. ~'8B'" 180 /~¥.!.200 .,,' // JiI<'..J40 i" "/ 1 000 ~ \~ 1 ~OO .'~,16QO .. " <1-$ . .. 180Ç!./" // "I,160¡}'6400 / " I \',".., ' ..~'~ 1400 " J'$ - .di,,~/, / / ~, 1200 j "\I 2200 ' . \., '" 1600 - 240 (§>. /-;......~o "pGOO 'r2OOO ~/ / 12100, ~' ~ / 11,,1400.,14.00 ."àoo 800. 1400 / ;, 2000 " I I 000(.800 A600 /2200 ////1800 ,/ ~~~o ",1600 i [.:;7 I I \ ! 1 i I I ¡,2400 I I I 1 I I 1 I I I I I I I ~ 2600 I I I I I I I I I I I I I I ; 2800 I I \,/ \ I ~ /\ ri 300o'~ ð ~ 540 480 &> , 2000 (f; 12{0~OO I / I )2400 .. 2700 I / / @/ / / ~ ." 1800 ) PllilliI)S Alaska, In.c. (~i~~ ~ Structure: CD#2 Well: 48 fIeld: Field Location: North Slope, 480 - 120 .1;(10 Qõ.. 300 ~ 1600 1,\ 240p , <it: 1600 I 11,2000 'i@b - 360 " ~ 420 * 2,400 "~ 2200\ . 1600, - 480 .. 1800 '" 2600 - 540 '.1800 - 600 (/) 0 C -+ :::r ¥ 2600 ,- 660 ....-. - CD CD -+ "'-" ~ 1800 ~ 2400 . 2600 :,¡,2000' I V ~:;\ - 720 ~ - 780 ",28OÖ, - 840 . 3000 -, 900 <I> 2000 .. 960 . noo - 1020 . 3000 .. 2600 . 3200 - .- 1080 ~ -1140 i- .. 1200 œ § ~200 -1260 "- '".'''''-.'''.-'-'-.''''''''''..''-'.''-..'''.'-''".....''''''..,...,...".-.._-....,...... ... .......".,,~.~._.._.._.... '''''.''-....."......,.'''.-.''. ... .. W.." .... .. ~ ow - ..... .. .- . .-. . n..'. ..- C",at.d by bmloh""l For: V Johnson !Jet. plotted: 14-t.Ioy-2002 Plot IMoronc. I. CD2'''49 Vo",lon'O. Coordinatml Cr1! 1" teet rallemnce "lot '48. Phillil)S Alaska, Irlc. Structure: CD#2 Field: Alpine Field Well: 48 Location: North Slope. Alaska (PHII:':¡P~. m , ." ~ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ .. 5700 \ \ \ \ \ \ \ 6000" \ \ \ \ \ \ \ \ \ \ \ r~8.J T"," V.rl1oal Deplh. ore ",roronaD RKB (DO)'On 19), .£ ¡ïif.i;¡(~:¡'-"-"-' @ ¿Z700 600 49 6300 /6600 16900 I \ ~~~~~ I Neve # 1 'I \ I ~300Q, \ \ \ % East (feet) - > 450 2250 I .. 5100 '" 3600 : 1,,5400 .~ 5700 ,~, 3900 , ~ 6000 - 3600 , ¡. 6~500 .' 39 0 ".+It 4200 ~!L 6600 ,:1:~] , ~,4200 ;¡ 690~ 4500 !I<; 4500 - - 4050 ~- :. 6300 .. 4~qf600 .. 7200 ~,4500 '''',4800 " 4500 U) 0 !: - 4950 :F ... 6900 '; ~9200 +It 5100 ~ 4800 ~ 5100 lit 5400 ...-- --+. - 5400 ~ -+- '-'" ~ 4800 ~ 5400 io 5700 - 5850 I V '" 5100 'Ð - 6300 % - 6750 ~ 5700 115400 III 6000 - 7200 .. 6300 - 7650 .. 6600 GÐ.. 6900 - 8100 - 8550 . 7200 6300. - 9000 00 ~ - 9450 ') ) -,.,~, --.,.., ""-~"~"-'."""-"-'-'.".-.-- .. '-"'''.M--_'' N-'~_""."'''--'V- ...".".....-..-.-,.-.-...".,...... ."" "....._",-".'- - Phil. s Alaska, Ine. . Cr-';":l~d'.ÿþ';"it¡'';;1 'For:" J~~~~ 'I Do"," plctted : 1 ~-MO)'-2002 Plot RoI.",nto Ia CD2-oI!I V.llIijon*~, Coordlnot.. ora I. 1001 """.... .Iot ,om. Truo Vert....1 Doplh. ora ",'...na. RK~ (Doyon 19). ~~ ';4;"" ~, Structure: CD#2 Well: 48 1__...., ,F~~',~.:..~'p_~ø..~~~I.d. - ..'", ",--~~:~!I~~_:..~.~r.!~..~'.~.~~ .~!~-~~~¡ .. - -- ~ 260 C0 20 , , 330 lit 1500 ~'~3, 2.",..0 .JIC,1000 150u 310 ,. " (j§J. '''''-._~ '......,. 30 40 50 300 s£ 70 L1D 80 2.70 90 100 240 / ~og .@) Qù 110 . 2500 Œ~ @D1 20 130 220 140 ~ 210 150 & 200 @ 160 ~ 1~ ~ Normal FJlane Travelling Cylinder - Feet shown ar'e Measured depths on Reference We!1 190 180 All depths ) phi 11 ips Alaska, Inç. CD#2 48 F.!lot #48 ;l\lp:Lne Field North Slope, Alask<1 PRO P 0 S ALL 1ST I N G bx' B.lke:r Bughes INTr;Q Your: ref: CD2-48 version#5 Our ref: prop4142 Lir:::ense : Dat,.~ printed: 14'-May.-2002 Dat.'? cre"It.,"d : 12,..Oct-,2000 La¡,t revii~ed : 14'-May.,.:W02 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 17.006,w151 2 26,898 slot Grid coordinates are N 5974313.737, P; 371.731.201 slot 10c<11 coordinates ar\;J 2042.98 s 1503,81 W Projection type: ¡:Üaska - Zone 4. Spheroid: Clark\;J - 1866 Reference North is True North ') Phillip8 Alaska, Inc. PROPOSAL. LIS'J.'ING Pè;lQ'e 1 CDil2, 48 Yc?ur ref : cD:2-48 Versionil5 Alpine P'ield, North Slope, Alask,' [,<1st revi sed : 14'-May-2002 ME,asured Inc1 in Azimuth True Vert R E C T A N G U [, A R G R I D C 0 0 R D S G E 0 G R A P H I C Depth Degrees D",grees Depth C 0 0 R D I N A 'J:' E S Eê\sting Northing C 0 0 R D I N A T E 5 0.00 0.00 0.00 (1.00 O.OOS O. OOE 371731.20 5974313.74 n70 20 17.01 ,~151 2 26.90 250.00 0.0(1 0.00 2liO. 00 O. OON O. OOE 371731.20 5974313.74 n70 20 17.01 w151 2 26.90 300.00 0.50 125.00 300.00 O.13s 0.18E 371731. 38 5974313.61 n70 20 17.00 ,~151 2 26.89 400.00 1. 50 125.00 399.98 1. US 1. 61E 371732.79 5974312.58 n70 20 16.99 w151 2 26.85 SOO.OO :2.50 125.00 499.92 3.13s 4,47E 3717.35.61 5974310.53 n70 20 16.98 w151 2 26.77 550.00 3.00 125.00 5~19. 86 '1. !50s 6,43E 371737.56 5974309.13 n70 20 16.96 w151 2 26. '71 800.00 3.00 125.00 799.S2 12. 01s 1.7 . 15E 371748.14 5974301.44 n70 20 16.89 w151 2 26.40 900.00 2.00 125.00 899.42 14. !j1s 20.72E 371751.67 !;974298.88 n70 20 16.86 ,~151 2 26.29 1000.00 1. 00 125.00 999.39 16.01s 22. 87B 371753.79 5974297.34 n70 20 16.85 w151 2 26.23 1100.00 0,00 125.00 1099.38 16. 51¡; 23.58B 371754.50 5974296.83 n70 20 16.84 w151 2 26.21 1150.00 0,00 191. 55 1149.38 16. !515 23. 5BE~ 371754.50 5974296.83 n,70 20 16.84 w151 2 26.21 1212.63 2.19 191.5[; 1212.00 17.69,; 23. 34E: 371754.24 S974295. 66 n70 20 16.83 ,~151 2 26.22 1250.00 .3.50 191. 55 1249.3:~ 19, 50s 2:¡. 97r~ 371753.84 5974293.85 n70 20 16.81 w151 2 26.23 1.350.00 '7,00 191. 5!5 13413.89 28.47s 21.14E 371751.8!5 5974284.92 n70 20 16.73 w151 2 26.28 1450.00 10. f;O 191. 55 1447.71 43.37S 18. 09E: 371748.56 5974270.07 n70 20 16. S8 w151 2 26.:37 1550.00 14.00 191. 55 15~15.41 64.15S 13, 84E: 371743.96 5974249.36 n70 20 16.38 w151 2 26.49 E;55.79 H.24 191. 55 1552.00 6£;.788 13.lin: 3'/1743.50 5974247.75 n70 20 1.6.36 w1.51 2 26.50 :l650. ao 17,50 191..55 1641.65 90.748 8,41E 371738.07 5974222.87 n70 20 16.11 w151 2 26.65 1750.00 21. 00 191. SS 1736.04 123. 04S 1.8n: 371730.93 5974190.69 n70 20 15.80 w151 2 26.84 18~;O.OO 24.50 191. S5 11328.2£; 160.928 5,94w 371722.54 5974152.95 n70 20 15.42 w1S1 2 27.07 19~;0. 00 28.00 191. 5S 1917.92 204, 25s 14, 79W 371712.96 5974109.79 n70 20 15,.00 w151 2 27.33 2050.00 31. !50 191. S!3 2004.73 252.865 24, '73W 371702.20 5974061. 36 n70 20 14,52 w151 2 27.62 2150.00 3~;, 00 191.S5 2088.34 306. S75 35, 71W 371690.3:? 5974007.84 n70 20 1.3.99 w151 2 27.94 22S0.00 38.50 191.55 2168.45 365.188 '17.69w 371677.35 5973949.45 n70 20 13.41 w151 ;; 28,29 2298.56 40.20 191.5~; 2206.00 395.345 53. 86w 371670.67 5973919.40 n70 20 1.3.12 w151 2 28.47 2350.00 42,00 191. 55 2244.76 428,475 60. 63\'J 371663.34 ~5973886. 39 n,70 20 12.79 w151 2 28,67 2450.00 45. !30 191. 5!5 :1316.99 4%.215 7 4,. 4 8I~ 371648.35 5973818.90 n70 20 12,1.3 wlS1 :2 29.07 2S04.92 47,42 193..55 2354.82 535.218 82. 4S~~ 371639.72 5973780.04 n70 20 11. 74 w1S1 2 29.30 2562.83 47,42 191.55 2394.00 576.998 90. 99w 371630.48 5973738.41 n70 20 11.33 w151 2 29.55 2577.61 47.42 191. 55 2404.00 587.658 93.1.7W 371628.12 5973727.79 n70 20 11. 23 w1S1 2 29,62 3000.00 47,42 191.55 2689.79 892.388 155.46W 371560.69 5973424.18 n70 :ao 08.23 w151 2 31.43 3124.17 47.42 191.55 2774.00 982,18S 173.82~~ 371540.82 5973334.72 n.70 20 07.35 w151, 2 31.97 3S00.00 47.42 191. 55 3028.08 1253.105 229.20w 371480. f.rI 5973064.79 n.70 20 04.68 w151 2 33.58 4000.00 47.42 193.. 55 3366.38 1613. 82s 302.94W 371401.. 05 5972705.40 n70 20 0 1. 1.3 w151 '1 35. '73 4500.00 47,42 191. 55 3704.67 1974.545 376, 68W 371321,23 5972346.00 n70 19 57..59 w151 2 37.89 4695.58 47,42 191. 55 3837.00 2115.648 40[),52w 371290.01 S972205. 42 n70 19 56.20 w151 2 38.73 4988.22 47.42 191. 55 4035,00 2326. 77s 448,68W 371243.29 5971995.08 n70 19 54.12 w151 2 39.99 5000.00 47,42 191. 55 4042.97 2335.26s 450. 42w 371241.41 S971986. 61 n70 19 54.04 w15I 2 40.04 5()32,56 47.42 191.55 4065.00 2358.76s 45~;. 22w 371236.:n 5971963.20 n70 19 53.81 w151 2 40.18 5500.00 47.42 191..55 4381.26 269.5.988 524.15W 37116l..59 5971627.22 n70 19 50,49 w151 2 42.19 6()OO.OO 47, .12 191..55 4719.56 3056. 70S ~;97.89W 371081. 77 5971267.83 n70 19 46,94 w15I 2 44.34 6500.00 47.42 191.55 5057.85 3417,423 671.63W 371001. 95 5970908..u n70 19 43.39 w151 2 46.49 7()()O.00 47.42 191. 55 5396 .15 3778.145 745,37w 370922.13 5970549.04 n70 19 39.85 w151 2 48.64 7248.08 47.42 191.55 5564.00 3957. 12s 781.96w 370882.53 5970370.72 n70 19 38.09 w151 2 49.70 7500.00 47.42 191. 55 5734.44 4138.87s 819.11W 370842.31 5970189.65 n70 19 36.]0 w151 2 50.78 7926.49 47.42 191.55 6023.00 4446. 55S 882. OO~~ 370774.23 5969883.10 n70 19 33.27 wI51 2 52.62 8000.00 47.42 191. 55 6072.74 4499,598 892. 85W 370762.49 5969830. ~i6 n70 19 32.75 w151 2 52.93 8500.00 47.42 191.55 6411..03 4860.315 966. 58~~ 370682.67 5969470.86 n70 19 29.20 w151 2 55.08 9000.00 47.42 191. 55 6749.33 5221.03s 1040, 32w 370602. 8S 5969111.47 n70 19 25.65 w151 2 57.23 9023.16 47.42 191.55 6765.00 5237.735 1043. 74W 370599.16 5969094.82 n70 19 25.49 w151 2 57.33 ...11 data in. feet unless otherwise stated. calculation uses minimum curvature methc,d. coordinates from slot #48 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 9276.14 on azimuth 175.50 degrees from wellhead. Total Dogleg for wellpath is 109.42 degrees. Vertio::al section is from \~ellhead on azimuth 188.51 degrees. Grid is alaska -, Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 s¡:-heroid Presented by Baker H1.1ghes INTEQ ) Ph:i.llip8 Alaska, lnG. PROPOSAL. LISTING P~~ge 2 <::D#2, 48 Your ref : <::D2.-48 Version#5 Alpine F'i~:ld, North Slope, Alaska [,ast. revised : 14-May..2002 Me..'¡¡1l1n"d Inclin Azimuth rl'rue Vert R E C '1' A N G U L A R G R I D C 0 0 R D S G E 0 G R A P H I C Depth D.?gree!¡ Degre<,s Depth C 0 0 R D I N A ~l' E S Basting Northing C 0 0 R D I N A 'r E S 9244.37 47.42 191..55 6914.67 5397, 33s 1076,36W 370563.84 5968935.82 n70 19 23.92 w151 2 58,28 9300.00 49.49 188.05 6951.57 5438.34s 1083,43W 370556.09 5968894.93 n70 19 23.52 w1.51 2 58,49 9336.60 50.90 185.86 6975.00 5466.258 1086, 83w 370S52.22 5968867.09 n70 19 23.24 w151 2 58.59 9400.00 53.44 182.28 7013.89 5516 ,18s 1090.35\'1 370547.85 5968817.23 n70 19 22.75 w151 2 58.69 9489.83 57,21 1'77.59 706S.00 5590.018 1090.19\'1 370546.76 5968743.42 n70 19 22.03 w151 2 58.68 9500.00 57.65 177.08 7070.48 5fj98.578 1089,79W 370S4,7. 01 596873.~. 85 n70 19 21. 94 w151 2 58,67 9600.00 62.04 172.36 7120.72 %84.618 1081,76W 370S!33.58 5968648.69 n70 19 21.10 w151 2 58.44 9694.83 66.35 168.23 7162.00 5768.71S 1067,32w 370566.60 5968564.36 n70 19 20.27 w151 2 58.01 9700.00 66,59 168.01 '7164.06 5773,358 1066,35\'1) 370567.50 5968559.71. n70 19 20.22 wI51 2 57.99 9741.75 68,52 166.29 ?l80. 00 5810,968 1057.76W 370S75.44 5968521. 96 n70 19 19.85 w151 2 57.73 9800.00 71,25 1,,63.96 7200.03 5863.828 1043,'72W 370588.60 5968468.88 n70 19 19.33 w151 2 57,32 9812.54 71,84 163.47 '7204.00 5875. 23s 10.10,38W 370591. 74 5968457.41 n70 19 19.22 w151 2 57.23 9875.28 74.81 161. 06 7222.00 5932.468 1022.06\'1) 370609.08 5968399.89 n70 19 18.66 w151 2 56.69 9900.00 75.99 160.:L.3 7228.23 5955,03S 1014,11W 370616.65 5968377.19 n70 19 18.44 w151 2 56.46 10000.00 GO. 79 156.45 7248.3!; 6045,988 977, 87W 370651..35 S9 68285. 6~; n70 19 17.54 w1Ei1 2 5~i. 40 10100.00 85.63 152.87 7260.18 6135, 67~; 935.37\'1 370692.32 5968195.25 n,70 19 16.66 w1.51 :2 54.16 10128.30 87,00 151. 87 7262.00 61()O.6%: 922. 28W 370704.99 5968170.02 n70 19 16.41 w151 2 53.78 10128.32 87.00 151. 87 7262.00 6160,71S 922. 27W 370705.00 5968170.00 n70 19 16.41 w151 2 53.78 10200.00 87.72 151.87 7265.30 6223. 85s 888.50W 370737.69 5968106.30 n70 19 IS.79 w151 2 52.79 10300,00 88.72 151. 87 7268.42 6311.99¡; 841.. 37W 370783.32 5968017.38 n.70 19 14.93 w151 2 51.41 10400.00 89.72 151.87 7269.78 6400.178 794.23\'1 370828.96 5967928.43 n70 19 14.06 ,v151 2 50.04 10424.48 89.96 151. 87 7269.85 6421.76s 782.68\'1 370840.14 5967906.6!3 n'70 19 13.85 wlS1 2 49.70 10500.00 89.96 151.87 7269.90 6488. 3Ss 747.07\'1 370874.61 5967839.47 n70 19 13.19 wlS1 2 48.66 11.()OO.OO 89.96 151.. 87 7270.:24 6929.288 ~,11. 30w 371102,88 5967394..66 n70 19 08.86 w151 :2 4.1. '78 11500.00 89.96 151.. 87 7270.57 7370. 2 Or,; 275,54w 371331.14 5966949.85 n70 19 04.52 w151. .2 34,09 12000. DO 89.96 151.8'7 7270.91. 7811.12s 39. T7W 37155~L .~O 5966505.04 n'70 19 00.18 w151 2 28.01 12500.00 89.96 151..8'7 7271.24 8252. 05S 196.00E: 371787.66 5966060.23 n70 18 55.85 w151 2 21.13 13000.00 89.96 151. 8'7 '7271.58 8692. 97s 431,77g 372015.9;J 5965615.42 n70 18 51.51 w151 2 14.25 13500.00 89.96 151. 87 7271. 91 9133.898 667 . 54]~: 372244.19 5965170.61. n70 18 47.18 wI51 2 07.37 13628.81 89.96 151. 8'7 7272.00 924.'7,488 728,28g 372302.99 5965056.02 n70 18 46: 06 wlGl 2 05.60 13628.83 89.96 151. 87 7272.00 924.7,508 '728. 29E: 372303.00 596,5056.00 n70 18 46.06 wlG1 :2 05.60 All data in feet unless otherwise stated. Calculatic,n uses minimum curvature method. Coordinates from slot #48 and TVD fr')m RKE (Doyon 19) (52.00 Ft above mean sea level). Bottom hol'2 distance is 92"16.14 on azimuth 175.50 degr"es from wellhead. Total Dogleg for \~e llpath is 109.42 degrees. Vertical s'2ction is from wellhead on azimuth 188.51 degr'2es. Grid is alaska - Zone 4. Grid coordinates in FEET and c,)mp\lted using the Clarke ." 1866 spheroid Presented by Baker Hughes INTEQ ) Phill ips Alask¡,.¡ Inc:. CD#2 ¡ 48 Alpine Field, North Slope, Alaska PROPOSAL LIS'l'ING P"1ge 3 Your ref: CD2-48 Version#5 c.ast revised: 14-May-.2002 Comments in wellp;:~th ::::: ::::;:'.:;::=::::::~::: ::::::: ~:~::::: =:::;;:::::::= 1:=::::::=::: = MD TVD p".êctangul"lr Coords. Comment -.- ,- - ~~ - _.~ -.... ....~ ,- - - - -~" - - ~¥~.. - .'" -, -. -"¥ -,~. - - - - - _.- ¥" -.- - --.-.- -" -. - -' ,-..- ". -... -". - -.-.... - ,.. -.-.-". '-' - - - - - -- - - - - - ... _.. - - - -. -..- - -- - -- ,- ..' - -".... -.- - -.- -.- -. - - -- 250.00 250.00 O.OON O.OOE NUd[.)'e 1/100 550.00 549.86 4, !jOs 6.43E EOC 800.00 799.52 12.01S 17.15E Dr()p 1/100 1100.00 1099.38 16,518 23. 58E EOC: 1150.00 1149,38 16.:,lS 23. 58E KOP 121,2.63 1212,00 17, 69s 23.34E West. s~lk 1556.79 1552,00 65. 7BS D.SIE B"lse Permlil:f:rost 2298.56 2206.00 395.348 53. 86w c-'10 2504.9:2 2354.82 535, :ns 82.4¡;w E:OC 2562.83 2394.00 576,9% 90. 99w 9 SlB" Ca¡¡ing pt 2577.61 2404.00 507.65::; 93.1.7W c-30 3124.47 2774.00 982,188 173. 82w c-20 4695.58 3837.00 2115,648 405.52w K--3 4988.22 4035.00 2326. 77S 448. 68W l3a,8c;~,1 ¡;.-3 5032.56 4065.00 2358.?68 455.22w K.";¡ 7248.08 5564.00 3957,1.28 781, 9M'! Albi;;Ln-' 97 7926.49 6023.00 4446,558 882. OOW Albian,' 96 9023.16 6765.00 5237.738 1043.74w 1'¡¡:~.7.. 9244.37 6914,67 5397.335 1076.36w Fin<tl Bld/'J~rn 9336.60 6975,00 5466,258 1086. 83W 9M39. 83 7065,00 5S90.01S 1090.19W LCU 9694.83 71.62.00 576H.71.5 1067. 32W Miluveach A 9741.7!5 7180. ° 0 5810.965 1057. 76W Alpine D 9812.54 720¡~. 00 5875.235 1040. 38w Alpine C 9875.28 7222,00 5932.465 1022.06w Alpine C 10128.30 7262.00 6160.695 922. 28W 'l'''lrøet -. Csø Pt. 10128.32 7262.00 6160.715 922. 27W CD2..48 Heel R'ItSd 10-i'\:¡:>r.-02 10424.48 7269.85 6421.76S 782. 68W EOC 13628.81 7272.00 9247,48::; 728. 28E TD - Csg pt 13628.83 7272.00 9247. [i05 728.29E CD2..48 Toe Rv¡¡d 10.-Apr-02 Casing posi thms in st.:d.ng ¡ A' '::::::: :~':;:::: ~':::::= = ::: ::::=:: =~:= ::::::;; =:= :::::: ::::~~: ~~:::::~::::;:: ::::::::: J:'~::::::::r.: =: 'rop MD Top 'rVD Rectlimg\lla.r Coords. BQt MD Bot TVD R€!ctangular C"ords. Casing 0.00 O.O() O. ()O 0.00 0.005 O.OOS OOE 2S62.83 2394.00 O.OOE 10128.30 7262,00 576.99s 61.60.698 90.99w 9 5/8' c"ising 922.28w' 7' C.~sing 'l'argets ,,,u!sociated with t.his wellpath ,1::;:::: I=: ::~ c:::~ ::::: :::: :c: :::;: t::~ ~o;:: :::: :::::::::::: =: :-~: r. :::::::::::: :::::~::: ~~: ::::::: ::::::.:: ;::.~ :::,,:::: =: :::::::.:: ==::::: :::: 'l'arg'~t nam..~ GeQgraphic j,ocation T.V.D. Rectangular Coordinates Revi sed - ... -. -. *~ - - ... - ,- - ......- ~,. -. -, - - - ..,~. -.- .-, ,- - -. - ,_.- -- - - -.-... -,... -"- ,-.-.-... - - ,- -...... -. ..,~...." _. - _.- -. .., - - _.~ - ,- ~,."~ .,.'~. - -, -, - - .'. ,- ,-.- -, - ,- _.~~.~. - ,- -... - ,- - -, .,~ - ,.- - ~,. ,- ",- ,- -.- ~~ -- CD2-48 HE!el Rvsd 10- 370705.000,5968170.000,0,0000 7262.00 CD2-48 Toe Rvsc1 10--]\ 372303,OOO,59650S6.000,O.0000 7272.00 6160.71S 9247.50s 922.27W 15,-Oct.-1997 728.29E 15--oc:t-1997 ) ) Phillips Alaska, Inc. CD#2 48 slot #48 Alpine Field North Slope, Alaska SUM MAR Y C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: CD2-48 Version#5 Our ref: prop4142 License: Date printed: l4-May-2002 Date created: 12-0ct-2000 Last revised: 14-May-2002 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 17.006,w151 2 26,898 Slot Grid coordinates are N 5974313.737, E 371731. 201 Slot local coordinates are 2042.98 S 1503.81 W proj ection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object we11path MWD <0-11056'>,,14,CD#2 MWD <0-11238'>, ,26,CD#2 Composite Survey <0-490'>,,26PB2,CD#2 MWD <485 - 719'>, ,26PB1,CD#2 MWD <0-9507'>,,42PH,CD#2 MWD <8480 - 13138'>, ,42,CD#2 MWD <0-11874'>, ,49,CD#2 MWD w/IFR <3794 - 13078'>, ,33B,CD#2 MWD w/IFR <0 - 21464'>, ,33,CD#2 MWD W/IFR <6007 - 15355'>, ,33A,CD#2 MWD <7712 - 11720'>, ,32,CD#2 MWD <0-8595'>, ,32PB1,CD#2 MWD <0-12278'>, ,15 PB1,CD#2 MWD <11806 - 13776'>,,15 PB2,CD#2 MWD <13450 - 14161'>, ,15,CD#2 MWD <0-10054' >, ,24PH, CD#2 MWD <8715 - 14301'>, ,24,CD#2 MWD w/IFR <0-???'>,,45,CD#2 MWD <0 - 9113'>,,39PB1,CD#2 MWD <8371 - 12651'>,,39,CD#2 PMSS <0-11984'>,,35,CD#2 MWD w/IFR <0 - 14580'>, ,47,CD#2 MWD <0-7562'>, ,34PB1,CD#2 MWD <6701 - 8755'>, ,34,CD#2 MWD <752-7927'>,,50PB1,CD#2 MWD <6756 - 11624'>,,50,CD#2 MWD <0-8757'>,,17,CD#2 MWD <0-11994'>,,25,CD#2 MWD <0-11000'>, ,46,CD#2 PMSS <1876-9940'>, ,A1p1A,A1pine #1 PMSS <0-3161'>, ,Alp1,Alpine #1 PMSS <1868-8850' >, ,Alp1B, Alpine #1 PMSS <0-7170'>, ,Neve #l,Neve #1 Reference North is True North Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 2-0ct-2001 340.2 283.3 9679.0 6-Feb-2002 219.9 180.0 180.0 8-Jan-2002 213.9 483.3 483.3 7-Jan-2002 215.1 483.3 483.3 27-May-2001 60.0 283.3 283.3 2-Jul-2001 60.0 283.3 9916.7 20-Feb-2002 10.1 100.0 9360.4 18-Sep-2001 150.2 300,0 300.0 18-Sep-2001 150,2 300.0 300.0 19-Aug-2001 150.2 300.0 300.0 15-Mar-2002 159.7 100.0 1160.4 15-Mar-2002 159.7 100.0 1160.4 30-0ct-2001 329.8 100.0 100.0 30-0ct-2001 329.8 100.0 100.0 30-0ct-2001 329.8 100,0 100.0 18-Jun-2001 239.8 266.7 266.7 26-Jun-2001 239.8 266.7 266.7 26-Nov-2001 30.5 100.0 466.7 12-Sep-2001 77.6 680.0 680.0 1-0ct-2001 77.6 680.0 13480.0 30-Nov-2001 128.9 300.0 1170.9 8-Feb-2002 9.8 100.0 13560.0 26-Dec-2001 139.9 100.0 1191.8 15-Jan-2002 139.9 100.0 1191.8 3-May-2002 18.2 433.3 1670.0 13-May-2002 18.2 433.3 8720.0 20-Mar-2002 310.1 100.0 100.0 26-Apr-2002 229.9 100.0 6900.0 14-May-2002 19.7 266.7 7620.0 21-Sep-1999 3411.9 3180.0 3180.0 21-Sep-1999 4034.6 3060.0 3060.0 21-Sep-1999 4073.9 2600.0 12360.0 16-Dec-1999 1703.412360.0 12360.0 SURFACE CASING SHOE SEPARATION FROM CD2-22 CD2-48 X Y Surface Casing Shoe ASP 4 Coordinates: 371630.00 5973738.00 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 --- ---- ---- 737 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 589 371098.46 5973992.48 CD2-33 (+A&B), CD2- CD2-24 301-186 7/13/2001 x x 2 39, CD2-14, C02-15 33999 7/16/2001 1 0/9/2001 1403 370630.11 5974721.81 -' CD2-33 B*** ----- ----- x x 4 ----- ---- ---- 1482 370155.64 5973886.23 CD2-39 301-281 10/9/2001 x x 2 CD2-15, C02-47 27879 10/10/2001 11/12/2001 728 372350.61 5973633.17 CD2-45, CD2-47, C02-14 301-288 10/9/2001 x x 2 CD2-32 31073 11/13/2001 3/5/2002 1350 372202.47 5974960.87 CD2-15 301-308 11/6/2001 x x 2 CD2-50, CD2-25 21093 3/6/2002 3/22/2002 1480 370832.00 5974984.02 CD2-4 7 301-322 12/3/2001 x x 2 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 596 371231.72 5973294.19 CD2-45 301-345 12/13/2001 x x 2 C02-49, CD2-17 22991 1/20/2002 2/19/2002 1141 372765.13 5973853.74 CD2-34 302-069 3/4/2002 x x 2 NA 0 723 371803.06 5974439.79 C02-26 302-068 3/4/2002 x x 2 NA 0 834 371798.52 5974554.55 CD2-49 302-070 3/4/2002 x x 2 CO2-50, C02-46 7535 3/22/2002 500 371252.38 5974065.93 CD2-17 302-122 4/10/2002 x x 2 NA 0 918 371774.00 5974645.00 C02-32 302-119 4/30/2002 x x 2 NA 0 656 371295.61 5974302.38 CD2-50 302-121 4/30/2002 x x 2 NA 0 491 371664.50 5974228.10 CD2-46 x x 2 NA 0 588 371696.07 5974322.16 CD2-22 x x 2 NA 0 826 371677.32 5974563.10 CD2-48 x x 3 NA 0 0 371630.00 5973738.00 -......~/ * Distance in feet, between surface casing shoes, in the X- Y plane ** C02-35 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 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MO (3062' TVO), shoe depth shown indicates window depth. It has not been permitted for annular disposal. **** As of 22-Apr-02 ) ) Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 16,2002 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-48 Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore WAG (water alternating gas) injection well from the Alpine CD2 drilling pad. The intended spud date for this well is May 30, 2002. It is intended that Doyon Rig 19 be used to drill the well. CD2-48 will be drilled to penetrate the Alpine reservoir at horizontal. After setting 711 intermediate casing, the horizontal section will be drilled and the well completed as an open hole injector. At the end of the work program, the well will be closed in awaiting completion of well work and facilities work that will allow the well to begin injection. -', Note that it is planned to drill the surface 20le without a diverter< There have been 38 .. ,: wells drilled on CD1 pad and 16 surface holes drilled on CD2 pad with no significant .. indication of gas or shallow gas hydrates. All of the wells on CD2 have surface casing shoes within ä 1500' radius of the planned surface casing shoe of CD2-48. 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: . Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed pilot hole schematic. Proposed completion diagram. Proposed completion diagram with open hole isolation options. Pressure information as required by 20 ACC 25.035 (d)(2). CD2-48 Cementing Requirements. Diverterless riser configuration drawing. . . . . . . . . . 1. 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 ~r'liV~éf1) out as required by 20 ACC 25.035 (a) and (b). ~" t t.. t ~ ê} t~ Ï,.þ 2. A description of the drilling fluids handling system. , . \". I .' f r; r. " .) :'.;', ,',;: I I !! 'I J ¡ ¡;."'-.~ . ,-.U....(....., . " '1 ') 1 '\ : "\\1 ,\ "' , 1 ...- Alaska Oil & Gas Cons. GomffiíSSlon Anchorage ) ') If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~IY¿" / V¿,--... - Vern Joh son Drilling Engineer Attachments cc: CD2-48 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin e-mail: ATO 1530 ATO 868 ATO 848 ATO 844 Anadarko - Houston Kuukpik Corporation Tommy_Thompson @ anadarko.com r~ E"- ~,,"" t"'" g , ' - D ~t.. "" L ,'-, ~ ," L Q\, ~ ~ 'f r lb.a,¡~ ~ ,1 ~"'1Q IWIot' ;,/ ,,\ \/ .'] -(- 'l n 0 t) ¡ 11--,,; .:..U I¿ ^ 'as'''a n~¡ ¡: '"'"" .-, t1J ~\ wh ~~ baS LOr:;;: ¡ -O¡"'¡I"r-'i~~¡or' 6V. """ h 'u....n.... Anchorage ./ PHILLIPS ALASKA, INC. PAl PAYABLES P.O. Box 102776 Anchorage, AK 99510-2776 73-426/839 CHECK NUMBER 205114251 0997579 PAY TO THE ORDER OF: ST A TE OF ALASKA AOGCC 333 W. 7TH AVENUE, SUITE 100 APRIL 23, 2002 H* VOID AFTER 90 DAYS H* .... ..... BANK = ONE. -- BANK ONE, NA - 0710 Chicago. IL Payable through Republ ic Bank & Trust Company EXACTLY ********** 100 DOLLARS AND 00 CENTS $******** 100.00 - c~d~ TRACE NUMBER: 205114251 1/1205..L. 25./11 ':08 jgOL. 2b 2.: 0 g g 7 5 7 g 1/1 --' ) , v ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~D 'r¿~4'f CHECK 1 ST ANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORATION INJECTION WELL -/ INJECTION WELL RED RILL "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 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD ( /) SP ACING EXCEPTION Rev: 5/6/02 C\j ody\temp lates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANYA:'~.; WELL NAMEl"'"-Rú CD 2. -7'<{ PROGRAM: Exp - Dev - Redrll - Se;" ~ Wellbore seg - Ann. disposal para re~ FIELD & POOL / ..2.,Ø¡ od INIT CLASS /-~~r~T ~GEOL AREA C(7n UNIT# (.)<1,=? h~ ON/OFF SHORE aM ADMINISTRATION 1. Permit fee attached. """""""" ...... Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y \I 5. Well located proper distance from drilling unit boundary. . . . Y \J 6. Well located proper distance from other wells.. . . . . . . . . Y\J 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y \J 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y\J 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y \J 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N ~ g~ TE 12. Permit can be issued without administrative approval.. . . . . Y N /} P- -y;~ 13. Can permit be approved before 15-day wait.. . . . . . . . .. \.It N . ' ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ~N i & f( qp ; ill . 15. Surface casing protects all known USDWs. . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ~ 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y ~VLw..[ç.vF d1 ~ po C;~ r;"'i L<.t2!;Þd. 18. CMT will cover all known productive horizons. . . . . . . . . . ~ 0 f2RA/\. L,o Ie. rA.~~/ø'W",- ... 19. Casing designs adequate for C, T, B & permafrost. . . . . . . ,N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N 0 D-i'f........... {c¡ 21. If a re-drill, has a 10-403 fo.r abandonment been approved. . . '*"* tLi/Pr- 22. Adequate wellbore separation proposed.. . . . . . . . . .-. . ~ N ;-\,,', t I 23. If diverter required, does it meet regulations. . . . . . . . .. .)(- Y N D'i \J 4 ~ý iN 4\A ""-;I Y'¿ Õ £.tR ~ e.-<t . 24, Drilling fluid program schematic & equip list adequate. . . . . f N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N A R () 1-. APef1 DA TEl 26. BOPE press rating appropriate; test to S 000 psig. ..'.. N 1\ J 6 = '2. S G, '5 to s /. (l1 a-K (Ç,lCo .,:Þ s t -: J ç 0 c:J p~ ¡' , ~/t S (12/0 L 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ~~: ~~~~~~~~~~~~~~~ ~~~~:gf; ~~u~d~~n.. .' .. .. .. .. .. .. .. .. .. Y .~ Çu Ix (OiAJ ' GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . . . âJ N ~ 31. Data presented on potential overpressure zones. . . . . .. XN A ) /J 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y ,/ £/,..1"'1 . ~j;R 'p~E / 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N ~ -9'~L:?¿" 34. Contact name/phone for weekly progress reports [exploratory 0 1 Y N ANNULAR DISPOSAL 35. Wi.th proper cementing records, this plan ~ (A) will contain waste in a suitable receiving zone; . . . . . .. LÞN (B) will not contaminate freshwater; or cause drilling waste. .. Õ) N to surface; (C) will not impair mechanical integrity of the well used for disposaŒ N (D) will not damage producing formation or impair recovery from a ?::f) N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. G N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: R~ ( APPR DATE §~ <~~~~ Comments/I nstructions: JDH WGA \t-t6k <Jí+ ~vv COT. DTS ~~) I ? J frt~ G:\geology\permits\checklist.doc ) ') Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting 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 infonnation. ) ) d~/08 lit OJ Sperry-Sun Drilling Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Oct 08 06:53:23 2002 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/08 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. . . . . . . . . . . . . . . . . . . . .02/10/08 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name..... ..UNKNOWN Comments................ .STS LIS Writing Lib~ary. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-48 501032042200 PHILLIPS Alaska, Inc. Sperry Sun 08-0CT-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22085 R. KRELL D. MICKEY MWD RUN 3 AK-MW-22085 R. KRELL D. BURLEY MWD RUN 4 AK-MW-22085 M. HANIK D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 UN 4E 2043 1505 MSL 0) .00 52.25 15.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 2550.0 8.500 7.000 10074.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 2 - 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY ) ) (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. GAMMA RAY LOGGED BEHIND CASING FROM 2530' MD, 2365' TVD, TO 2550', 2379' TVD. 5. GAMMA RAY LOGGED BEHIND CASING FROM 10057' MD, 7260' TVD, TO 10074' MD, 7260' TVD. RESISTIVITY DATA LOGGED BEHIND CASING FROM 10049' MD, 7259' TVD TO 10074' MD, 7260' TVD. 6. GAMMA RAY DATA HAS BEEN CORRECTED FOR 6% KCL MUD AND BOREHOLE SIZE ON MWD RUN 4. 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 - 4 REPRESENT WELL CD2-48 WITH API # 50-103-20422-00. THIS WELL REACHED A TOTAL DEPTH OF 13622' MD, 7258' 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...... .02/10/08 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 2530.0 2540.0 2540.0 2540.0 2540.0 2540.0 2560.5 STOP DEPTH 13577.5 13584.5 13584.5 13584.5 13584.5 13584.5 13622.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ ) ) # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 2 2530.0 3 9534.5 4 10084.5 MERGE BASE 9534.0 10084.0 13622.0 # 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 2530 13622 8076 22185 2530 13 622 ROP MWD FT/H 0.49 335.13 139.964 22124 2560.5 13622 GR MWD API 28.07 384.11 95.3181 22096 2530 13577.5 RPX MWD OHMM 0.2 1336.23 7.51903 22090 2540 13584.5 RPS MWD OHMM 0.17 1864.09 8.44861 22090 2540 13584.5 RPM MWD OHMM 0.13 2000 11.954 22090 2540 13584.5 RPD MWD OHMM 0.11 2000 13.23 22090 2540 13584.5 FET MWD HR 0.18 84.93 1.03491 22090 2540 13584.5 First Reading For Entire File........ ..2530 Last Reading For Entire File.......... .13622 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/08 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...... .02/10/08 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 ) RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ ) header data for each bit run in separate files. 2 .5000 START DEPTH 2530.0 2540.0 2540.0 2540.0 2540.0 2540.0 2560.5 STOP DEPTH 9502.5 9494.5 9494.5 9494.5 9494.5 9494.5 9534.0 # 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. RES IS. 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..................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 04-JUN-02 Insite 4.05.5 66.37 Memory 9534.0 45.3 52.9 TOOL NUMBER PBOO173HWRGV6 PBOO173HWRGV6 8.500 LSND 9.70 41. 0 9.0 700 5.2 2.600 1. 646 1.700 2.400 85.0 138.2 70.0 70.0 ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2530 9534 6032 14009 2530 9534 ROP MWD020 FT/H 0.49 335.13 170.907 13948 2560.5 9534 GR MWD020 API 53.25 384.11 119.096 13946 2530 9502.5 RPX MWD020 OHMM 0.2 18.47 5.18502 13910 2540 9494.5 RPS MWD020 OHMM 0.17 1864.09 5.39253 13910 2540 9494.5 RPM MWD020 OHMM 0.13 2000 5.95348 13910 2540 9494.5 RPD MWD020 OHMM 0.11 2000 7.52548 13910 2540 9494.5 FET MWD020 HR 0.18 84.93 0.721612 13910 2540 9494.5 First Reading For Entire File......... .2530 Last Reading For Entire File.......... .9534 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/08 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...... .02/10/08 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. 3 .5000 START DEPTH 9495.0 9495.0 9495.0 9495.0 9495.0 9503.0 9534.5 STOP DEPTH 10048.5 10048.5 10048.5 10048.5 10048.5 10056.5 10084.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): 06-JUN-02 Insite 4.05.5 66.37 Memory 10084.0 ) 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...O ) 55.6 86.5 TOOL NUMBER PBOO173HWRGV6 PBOO173HWRGV6 8.500 10074.0 LSND 9.70 42.0 9.2 800 4.6 1. 300 .655 1. 300 1.600 70.0 145.5 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9495 10084 9789.5 1179 9495 10084 ROP MWD030 FT/H 4.31 191.52 68.9598 1100 9534.5 10084 GR MWD030 API 44.04 154.21 84.0825 1108 9503 10056.5 RPX MWD030 OHMM 1. 71 24.62 11.1246 1108 9495 10048.5 RPS MWD030 OHMM 1.8 22.37 11.0935 1108 9495 10048.5 RPM MWD030 OHMM 1.78 22.13 11. 3484 1108 9495 10048.5 RPD MWD030 OHMM 1.78 21.64 11.4972 1108 9495 10048.5 FET MWD030 HR 0.45 21.44 3.07497 1108 9495 10048.5 ) First Reading For Entire File......... .9495 Last Reading For Entire File.......... .10084 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/08 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...... .02/10/08 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. 4 .5000 START DEPTH 10049.0 10049.0 10049.0 10049.0 10049.0 10057.0 10084.5 # 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: # STOP DEPTH 13584.5 13584.5 13584.5 13584.5 13584.5 13577.5 13622.0 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): 11-JUN-02 Insite 4.05.5 66.37 Memory 13622.0 88.8 93.1 TOOL NUMBER PB00210HAGR4 PB00210HAGR4 6.125 FloPro 9.70 44.0 8.5 80000 '.) ) 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: 4.0 .060 .028 .040 .060 74.0 163.4 68.0 72 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # Data Format Specification Record Da ta 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 Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 10049 13622 11835.5 7147 10049 13 622 ROP MWD040 FT/H 0.75 254.78 90.0086 7076 10084.5 13 622 GR MWD040 API 28.07 68.18 49.9969 7042 10057 13577.5 RPX MWD040 OHMM 1. 77 1336.23 11.5449 7072 10049 13584.5 RPS MWD040 OHMM 2.37 1390.12 14.0453 7072 10049 13584.5 RPM MWD040 OHMM 2.87 2000 23.8514 7072 10049 13584.5 RPD MWD040 OHMM 3.31 2000 24.7217 7072 10049 13584.5 FET MWD040 HR 0.33 64.23 1. 33151 7072 10049 13584.5 First Reading For Entire File......... .10049 Last Reading For Entire File.......... .13622 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation..... ..02/10/08 Maximum Physical Record..65535 File Type............... .LO Next File Name. ......... .STSLIB.005 Physical EOF Tape Trailer Service name........... ..LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02/10/08 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name......... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name... ... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/08 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number.... ..01 Next Reel Name........ ...UNKNOWN Comments.............. ...STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File