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201-249
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-49 COLVILLE RIV UNIT CD2-49 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 CD2-49 50-103-20401-00-00 201-249-0 W SPT 7094 2012490 1774 1789 1791 1791 1789 790 860 860 870 4YRTST P Guy Cook 7/29/2022 Testing completed with a Little Red Services pump truck and calibrated gauges. 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 CD2-49 Inspection Date: Tubing OA Packer Depth 1800 2600 2530 2530IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220728135930 BBL Pumped:0.8 BBL Returned:0.8 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 14:25:38 -08'00' 5HJJ-DPHV% 2*& )URP 6PLWK7UDYLV7 7UDYLV76PLWK#FRQRFRSKLOOLSVFRP! 6HQW 7XHVGD\-XQH 30 7R 5HJJ-DPHV% 2*& :DOODFH&KULV' 2*& %URRNV3KRHEH/ 2*& '2$$2*&&3UXGKRH%D\ 6XEMHFW &58)RUPV $WWDFKPHQWV 0,7&58&' 6,7(676[OV[ 0,7&58&'3$'6,7(676SDJH[OV[ 0,7&58&'3$'6,7(676SDJH[OV[ ƚƚĂĐŚĞĚ͕ƉůĞĂƐĞĨŝŶĚϭϬͲϰϮϲĨŽƌŵƐĨŽƌD/dƐĐŽŵƉůĞƚĞĚĂƚZh͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨLJŽƵŚĂǀĞĂŶLJƋƵĞƐƚŝŽŶƐŽƌŶĞĞĚ ŵŽƌĞŝŶĨŽƌŵĂƚŝŽŶ͘ dƌĂǀŝƐ^ŵŝƚŚ tE^/ŶƚĞƌǀĞŶƚŝŽŶΘ/ŶƚĞŐƌŝƚLJ ŶŐŝŶĞĞƌ ϵϬϳͲϲϳϬͲϰϬϭϰ dƌĂǀŝƐ͘d͘^ŵŝƚŚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2020290 Type Inj N Tubing 2425 2425 2425 2425 Type Test P Packer TVD 7088 BBL Pump 1.7 IA 60 1900 1850 1850 Interval 4 Test psi 1772 BBL Return 1.5 OA 480 630 630 630 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2022440 Type Inj N Tubing 1940 1940 1940 1940 Type Test P Packer TVD 7064 BBL Pump 2.5 IA 50 2800 2740 2740 Interval 4 Test psi 1766 BBL Return 2.6 OA 740 740 740 740 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2012490 Type Inj N Tubing 3050 3050 3050 3050 Type Test P Packer TVD 7094 BBL Pump 1.9 IA 80 2000 1960 1960 Interval 4 Test psi 1774 BBL Return 1.7 OA 645 705 705 705 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2022490 Type Inj N Tubing 1740 1740 1740 1740 Type Test P Packer TVD 6948 BBL Pump 4.2 IA 60 3300 3280 3280 Interval V Test psi 3000 BBL Return 3.4 OA 780 800 800 800 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine / CRU / CD2 PAD Miller / Weimer 06/13/22 Notes: Notes: CD2-32 CD2-35A CD2-51 Notes: CD2-49 Notes: Notes:MITIA to MAIP per AIO 18C.010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0613_MIT_CRU_CD2-pad_4wells 9 9 9 9 9 9 9 - 5HJJ CD2-49 • 11110 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,June 11,2018 Jim Regg P.I.Supervisor I,)3116 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD2-49 FROM: Brian Bixby COLVILLE RIV UNIT CD2-49 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD2-49API Well Number 50-103-20401-00-00 Inspector Name: Brian Bixby Permit Number: 201-249-0 Inspection Date: 6/6/2018 - Insp Num: mitBDB180611052313 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD2-49 'Type Inj G `1TVD 7094 " ;Tubing 4000 - 4000 . 4000 _ 4000 - PTD 2012490 -Type Test SPT Test psi 1774 • IA 860 2200 • 2150 - 2140 BBL Pumped: 1.5 - BBL Returned: 1.3 - OA 300 445 445 . 445 - Interval 4YRTST P/F P Notes: SCANNED JUN 2 l cu II) Monday,June 11,2018 Page 1 of 1 STATE OF ALASKA ALP OIL AND GAS CONSERVATION COMOION . REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon fl Repair w ell r Plug Pbrforations r Stimulate Other Alter Casing r Pull Tubing r Perforate New Pool fl Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory a 201 - 249 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service p 50 - 103 - 20401 - 00"00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075 • 4 CD2 - 9. Field /Pool(s): .. Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 11874 feet Plugs (measured) None true vertical 7263 feet Junk (measured) None Effective Depth measured 11874 feet Packer (measured) 8213 true vertical 7263 feet (true vertucal) 7094 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2457 9.625" 2494 2378 PRODUCTION 8856 7" 8891 7258 4,4 2 2 2011 RECEIVED Perforation depth: Measured depth: open hole 8891' - 11874' AR+ 201 True Vertical Depth: 7258' Alaske 011 at Gas Cons. G061t n ss Anchorage Tubing (size, grade, MD, and TVD) 4.5, L - 80, 8330 MD, 7160 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER W /MILLOUT EXTENSION 821 D and 7094 TVD NIPPLE - CAMCO DB NIPPLE @ 2039 MD and 1994 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8891'- 11874' Treatment descriptions including volumes used and final pressure: 3230 bbls seawater 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 2433 2465 Subsequent to operation 3600 2250 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development Servic r47 Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL i Daily Report of Well Operations XXXX , GSTOR r WIND r WAG GINJ r SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -031 Contact Tim Schneider (a 265 -6859 Printed Name Tim Sc eider Title WNS Staff Production Engineer Signature ----77— Phone: 265 -6859 Date p 3 ,z r. rr RBDMS MAR 2 1 20f �' " �Z, ` Form 10 -404 Revised 10/2010 y S mit Original Only • v WNS CD2 -49 C��oPhilli Well Attributes Max Angle & MD TD r 1 Wellborn API /UWI Field Name Well Status Inc! (°) IMD MKS) Act Btu, (ftKB) Alaska. 1 5010 32040100 ALPINE IINJ ! 91.84 9,55965 11,8740 Continent H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date SSSV- WRDP Last WO 44 20 2/4/2002 We. Ci8180a,.. '48.. (30112. 641 PM _____ 8 A A I Annotation �IDepth(ftKB) End D t Annotation (Last Mod ._I End Date !Lasl lag: L Rev Reason: FORMAT UPDATE Imosbor I 2/5/2011 Casing Strings Casing Description String O._ String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 37.0 114.0 114.0 _ 63.00 H - 40 WELDED Casing Desorption String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd _.-- _,_..... _. SURFACE 95/8 8.921 36.6 2,493.8 2,378.2 36.00 J - 55 BTC ' .. � :. - S Casirg Description Str ng 0... String ID ... Top (ftlC6) Set Depth (f... Set Depth (TVD) .. String Wt... String String Top Thrd HANGER, 33 PRODUCTION 7 6.151 35.2 8 7,258 3 26.00 L-80 BTCM i v Casing Descnption ' String 0... String ID ... Top (ftKB) Set Depth (i. Set Depth (ND) ... String Wt... String .. String Top Thrd lir OPEN HOLE 61/8 6.125 8,891.0 11,874.0 7,2626 Tubing Strings g g p I p ( I ) g !String... String Top Thrd Tubing Description g S String 0... String ID ... To (ftKB) Set Depth i... Sat Depth (TVD) ... String Wt... G ' I UBING 4 1/2 3.958 32.5 8,330.9 7,1594 12.60 L -80 IBTM Completion Details Top Depth - (TVD) Top Intl Nomi... Top (MKS) (MB) (°) item Description Comment ID (in) 32.5 32.5 -0.49 HANGER FMC TUBING HANGER 4.500 ?i 2,039.0 1,994.5 32.38 NIPPLE CAMCO DB NIPPLE 3.812 InalainalinORNAMINAt ., , , 8,212.5 7,093.9 53.30 PACKER BAKER S-3 PACKER w /Millar extension 3.875 8,318.5 7,153.7 58.23 NIPPLE HES XN NIPPLE 3.725 CONDUCTOR, 8.329. 7,158.6 57.78 WLEG BAKER WIRELINE GUIDE 3.875 37 -111 - Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth, -'i I (ND) Top Intl VALVE, 2,039 op (NCB) (ft KB) C) Description Comment Run Date ID (in) NIPPLE, 2,039 - r . 5 . 3 — — 2,039.0 1,994.5, 32.38 VALVE - - 3.812 A -1 INJECI ION VAL (HWS -121) 11(7/2009 1 3111F1 Notes: General & Safety End Date Annotation 9/3/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 !I tt i . 1I SURFACE, 37 -2,494 , F. it , , ..:, ., _ _._ GAS LIFT. 8,09E tl: tl> y,: PACKER, 8,213 -- NIPPLE, 8,319— - i i WLEG, 8,330 �' • Mandrel Details Top Depth Top Port Il / (TVD) Intl OD Valve Latch Sian TRO Run lik Stn Top (fIKB) (MB) ( Make Model (in) Sore Type Type (in) (psi) Run Date Com... 1 8,0981 7,021.4 48.30 CAMCO KBG - 2 1 GAS LIFT DMY BK 0.000 0.0 2/18/2002 PRODUCTION, _ -. . i 35 -8,891 TD, 8,891 a, OPEN HOLE, 8,891 - 11,874 CD2 -49 Well Work Summary DATE SUMMARY 2/10/11 UNABLE TO PROCEED DUE OF ROZEN SWAB. IN PROGRESS. • 2/11/11 PULLED A -1 INJ VLV (HSS -121) © 2039' RKB. COMPLETE. 2/12/11 PERFORMED TEMP SURVEY FROM TAG AT 11293 CTMD TO 8750 CTMD. WELL IS SHUT IN AND FREEZE PROTECTED FOR WARM BACK. 2/22/11 PUMPED HIGH plESSURE BREAK DOWN. SEAWATER WITH FRICTION RFMI1CFR INITAL PRESSURE AND PUMP RATE WAS 5600 PSI @ 41 BPM, FINAL PRESSURE AND PUMP RATE WAS 4900 PSI @ 41 BPM. FINAL STAGE WAS CUT SHORT DUE TO A LEAK AT THE HIGH PRESS MANIFOLD. PUMPED A TOTAL OF 3230 BBL OF SLICK WATER AND 35 BBL OF DIESEL FREEZE PROTECT. 3/9/11 GAUGED TBG TO 3.85" TO 2039' RKB. SET 3.81" A -1 INJECTION VALVE ( S/N HWS- 211) © SAME. GOOD CLOSURE TEST. COMPLETE. • • su\ITE AillsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tim Schneider Api a 5. 2. 11 WNS Staff Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2 -49 Sundry Number: 311 -031 Dear Mr. Schneider: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holida .. or weekend. Sincere . ► orman ■ • missioner DATED this /', day of February, 2011. Encl. • • STATE OF ALASKA ` ALASKA" AND GAS CONSERVATION COMMISSIll ' 4'' I , APPLICATION FOR SUNDRY APPROVALS ' 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r! Re -enter Susp. Well r Stimulate , Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 201 -249 • 3. Address: 6. API Number: Stratigraphic r Service 17 d P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20401 -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 Required? Yes r No CD2 -49 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 380075 • Colville River Field / Alpine Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11874, 7263 • 11874' • 7263' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 2457 9.625" 2494' 2378' PRODUCTION 8856 7" 8891' 7258' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole 8891'- 11874' 7258' -7263' 4.5 L - 8330 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER S -3 PACKER W /MILLOUT EXTENSION MD= 8213 TVD= 7094 NIPPLE - CAMCO DB NIPPLE MD= 2039 TVD= 1994 12. Attachments: Description Summary of Proposal p' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service P • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/19/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG Abandoned r Commission Representative: GSTOR f SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider © 265 -6859 Printed Name Ti Schneider Title: WNS Staff Production Engineer Signature ( c �,� Phone: 265 -6859 Date 2 - // Commission Use Only Sundry Number: ? I l -031 Conditions of approval: Notify Commission so that a representative may witness * ' Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r r ER 0 9 ?O11 Other: y ;1 GO `, c7 Otis• C"' °` ' 'i$Slan Subsequent Form Required: / Q — 4/0 t{ giirrir-mge // r 0APPROVED BY ,/(� ��/� /..- Approved by: COMMISSIONER THE COMMISSION Date: p' /t // Form 10-403 R 10FE' ' ; ` Submit irf Dup ' ate O RIGIN �, /r • WNS • CD2-49 c Phil tips asokov, Well Attribute* ,Max Angle & MD TD ♦t a*a. ` Wellbore APUU WI Field Name Well Status Inc! (°) MD (COB) Act Btrn (HKB) +`warm" t4arar':Q}1•ttMVS 501032040100 ALPINE INJ I 91.84 I 9,55965 11,8740 °' Com ent HES (ppm) Date [Annotation End Date I KB -Grd (H) Rig Release Date ..• SSSV WRDP Last WO 44.20 2/4/2002 • W ' z 1La "PM ShcamilNc lxaaall _ Annotation I _ Depth(ftKB) End Date Annotation Last Mod... End Date -- Last Tao Rev Reason: FORMAT UPDATE J Imosbor 2/5/2011 1 Casing Strings Casing Description String 0... String ID ... Top (HOB) Set Depth (t... 'Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 37.0 114.0 114.0 63.00 H - 40 WELDED Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 36.6 2,493.8 2,378 2 36.00 J - 55 BTC - Casing Desch pt ion String 0... String ID ... Top MKS) Set Depth (f... Set Depth (TVD) ... Siring Wt... String ... String Top Thrd HANGER, 33 II. it), PRODUCTION 7 6.151 35.2 8,890.8 7,258.3 26 00 L - 80 BTCM ..,,...e,„ Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt... String ._ String Top Thrd ` OPEN HOLE 61/8 6.125 8,891.0 11,874.0 7,262.6 I I Tubing Strings II Tubing Description String 0 String ID... Top OMB) Set Depth (f.. Set Depth (ND) ... IString Wt... !String ... String Top Thrd TUBING 41/2 3958 325 83309 7,1594 I 1260 i L80 IBTM r ' Completion Details Top Depth (TVD) Top Inc! Norm_. Top (figs) (flKB) ( °) Item Description Comment ID (in) 32.5 32.5 -0.49 HANGER FMC TUBING HANGER 4.500 2,039.0 1,994.5 32.38 NIPPLE — CAMCO DB NIPPLE 3.812 — 8,212.5 7,093.9 53.30 PACKER BAKER S-3 PACKER w /Millout extension 3.875 8,318.5 7,153.7 58.23 NIPPLE HESXN NIPPLE 3.725 R, 7 I 8,329.5 7,158.6 57 781 WLEG BAKER WIRELINE GUIDE 3.875 CONDUCTO 37 -114 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inol VALVE, 2,039 T• • HjKB) (5OB) () Description 51 "A - INJECTION VALVE Run Date ID (in) NIPPLE, 2,039 2,039.0 1,994.5 3238 VALVE 3. ALVE (HWS 121) 11/7/2009 1.250 Notgs- General & Safety A. - t 1, . _ • End Date Annotation 9/3/2010 NOTE: VIEW SCHEMATIC wiAAiaska Schematic9.0 SURFACE, II l 37 -2,494 i', i t GAS LIFT, 8,098 L PACKER, 8,213 _ NIPPLE, 8,319— I ( 7 F WLEG, 8,330 - Mandret Details : I Top Depth Top I Port I f (TVD) Inc! OD Valve Latch Si.. TRO Run i I I Stn Top (HKB (HKB) CI Make _ (in) Sere Type TIFF.. 0^) (Psi) Run Date Corn... 1 8,098.1 7,021.4 48.30 CAMCO KBG - 2 1 GAS LIFT DMY BK 0.000 0.0 2/18/2002 PRODUCTION, _ - 35 -8,891 TD,8,891 OPEN HOLE, , m 8,891.11,874 • Overview: A high pressure breakdown is proposed for the CD2 -49 Alpine horizontal injector to improve • injectivity to support the offset oil production. Procedure: 1. MIRU nine clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10 %. Load tanks with seawater from the injection system (approximately 5000 bbls are required for the treatment) 2. Rig up Schlumberger equipment. 3. Pressure test surface lines to 5000 psi 4. Pump the following schedule at 30-40 BPM with a maximum pressure of 4500 psi, Maintain 3000 psi on the IA during the treatment. Do not exceed 4500 psi treating pressure. • 5000 bbls slick seawater • Flush with linear fluid and freeze protect Total Sand: 0 lbs. 5. Monitor the surface pressure fall -off at the end of the job for 30 min (or until closure is verified). 6. Rig down equipment, move off location. MEMORANDUM TO: Jim Regg P.I. Supervisor ~C) ~'7°'1I(` FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA 1NC CD2-49 COLVILLE RIV UNIT CD2-49 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~~- Comm Wetl Name: COLVILLE RIV UNIT CD2-49 API Well Number: 50-103-20401-00-00 Insp Num: mitJJ100719113614 Permit Number: 201-249-0 Rel Insp Num: Inspector Name: Jeff Jones Inspection Date: 6/11/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - Welly cDZ-a y P.T.D 2012490 pe Inj. TypeTest W sPT TVD ~zo9a Test psi "" IA ~A sso 1980 ~ 60 ~ 65 lsso 6s is6o ~ 60 ~ Interval aYRTST p~ P Tubing 2soo 2soo zsoo 2aso Notes: 2,1 BBLS diesel pumped. 1 well inspected; one exception noted: the tree cap o-ring seal appears to be leaking. Mr. Colee to initiate repair. A ;~, X5.11_ '; ;~SaSiC` Monday, July 26, 2010 Page 1 of 1 ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED APR 2 7 zmJj ~O ,- ~tfi 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 thatthe 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:~~. ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft 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 1 318/2007 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 1.5 318/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-48 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . Conoc;Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 E! March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 <"}-4q :1Ö \ ~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from 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 from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, sCANNED APR 0 9 2007 ~~C - Jerry Dethlefs ConocoPhillips Well Irttegrity 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 PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-1 09 6" na 6" na 2.5 2/18/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 CD2-14 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 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 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 3/8/2007 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 3/8/2007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 CD2-37 202-211 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 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 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 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 MEMORANDUM . State of Alaska _ Alaska Oil and Gas Conservation Commis. TO: Jim Regg P.I. Supervisor í//¿fl'y. é12.} ~:/·¿7(P h'-'1~' v. , \ l I DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHlLLIPS ALASKA INC CD2-49 COLVILLE RIV UNIT CD2-49 \/g..Ltq ~O FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,'íBf2- Comm NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT CD2-49 API Well Number 50-103-20401-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060828 144938 Permit Number: 201-249-0 Inspection Date: 8/26/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-49 Type Inj. G TVD 7094 IA 1425 2470 2440 I 2440 i P.T. 2012490 TypeTest SPT Test psi 1773.5 OA 600 720 720 I 720 Interval 4YRTST P/F P ¿/' Tubing 3850 3850 3850 ! 3850 Notes Pretest pressure observed and found stable SCANNED SE? 082006 Wednesday, August 30,2006 Page I of I . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marlœr.doc ids CÆJ II- ) fiLL LOG TRANSMITTAL ') tAo ( - 2, <{ c:r ProActive Diagnostic Services, Inc. To: AOGCC 333 West 7th Ave. Ste. 100 Anchorage, AK 99501-3539 RE: Distribution - Final 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 1389 Stafford, TX 77497 LOG DIGITAL BLUE LINE REPORT WELL DATE TYPE OR PRINT(S) OR CD-ROM BLUE LINE C.Þ2 - '/9 ~fiðjor/ Open Hole 1 1 c,J) 2. .. '11 ~f$t>(C> cf Res. Eva!. CH 1 1 Sígned:~/'~ Ife,/e,u ~T{Ahr/HcuV Date: IP-f/o c? Print Name: cr I, \¡\,~~u:;~"""' v \¿,1"'\.tl '\1 ~ \'! !\....."L-<' ~I', iV PRoACTivE DiAGNOSTic SERVicES, INC., PO Box 1 ~69 STAffoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ids ~ I'- wJLL LOG TRANS ) ó(tJl-;<ff ProActive Diagnostic Services, Inc. To: AOGCC 333 West 7th Ave. Ste. 1 00 Anchorage, AK 99501-3539 RE: Distribution - Final 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 ! BLUE LINE REPORT WEll DATE TYPE OR PRINT(S) OR CD-ROM BLUE LINE Open Hole 1 1 CD 2-49 9-01-04 Res. Eva!. CH 1 1 Signed: Date: /;þ/Ód Print Name: ~/(;aJT !d-~ ., ", ,.. -r'o C;"ì fl/e(¡ SCANNEC UE" z 20DI) PRoAcTivE DÎAGNOSTic SERvicES, INC., PO Box 1 ~69 STAttORd TX 77477 Phone:(281) 565-9085 Fa-x:(281) 565-1369 E-mail: pds@memorylog.comWebsite:\vww.memorylog.com Cp 'MNL ð¿~ '-\ DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Permit to Drill 2012490 Well Name/No. COLVILLE RIV UNIT CD2-49 Operator CONOCOPHILLIPS ALASKA INC s~ ,;Z I ~ ~eO z..- API No. 50-103-20401-00-00 MD 11874 /' TVD 7263 ,;' Completion Date 2/4/2002 r-- Completion Status WAG IN ./ _:~e~~~_tatus WAG~.~__--_._--~~~-- ----- ------ ---- - ------- -----.------------.------ REQUIRED INFORMATION ----- --- -------- ------ -----.----- - Direction",-:~€ ~:þ.c== Mud Log No Samples No ------------------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset Type MedlFrmt Number Name -------------------------- tbg )njection Profile - -- - ---- - - ---- -------- ---- - --- ~:§s,~re_..--. --._-------- ---------- -- --- -- - -,- --- - - -- -----.. -- --..- - ...,.eh'1P~ratur:--._-.-. ~~h1m,a.~åY_-.' /p~~inøRPII~r-lq-~~t?t--,... 11190 tï$\i~hfiêlåtiòh" --, (data taken from Logs Portion of Master Well Data Maint) --'---'--~-------------- ,,/ , Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments .----------------- 1 Blu 1 8100 11500 Case 7/26/2002 1 Blu 1 8100 11500 Case 7/26/2002 1 Blu 1 8100 11500 Case 7/26/2002 1 Blu 1 8100 11500 Case 7/26/2002 1 Blu 1 8100 11500 Case 7/26/2002 1 2459 11831 a.ut 1 0/15/2002 1 2459 11831 ~ 10/15/2002 2460 11874 0 ~ 1 12/3/2002 Digital Well Log data ---------'-------'----------- Sample Set Sent Received Number Comments ( D ------,--,--," C Pdf -- - - - - - -- --- .~ï~Y~~ifiq~~i9~... - - - - .. - - - -.... 11366SêéNdtes' Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y I@) Chips Received? ...... Y J þJ----- Daily History Received? ~ ?!JI N Formation Tops Analysis Received? ~l f) - ----.- --- ---.----- -------------- ------------- ---- --------- -- ------- - ------ -- -. .---.- - ---- -------- -- .- ---- ---------.------------- -------._------- .----- '----- --------'--'-------'---- --------- Comments: N'<o't--'~ 1t~~t'\.c. $ C"fW\, c t1 ~ \ F.t. (, .:a..OQ ~ It\L \...~ l ~r - B 't:r <0 r.t~~~ ---- - - - -------. ----------- --- --.------------------------- ------------- ---------.-----------.------- ----..------ -------- DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Permit to Drill 2012490 Well Name/No. COLVILLE RIV UNIT CD2-49 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20401-00-00 MD 11874 TVD 72~63____- CffPleU__Pletio_n _D_ate 2/4/2002 Compliance Reviewed By: ~- - -~ Completion Status WAGIN Current Status WAGIN UIC Y Date: -15~ {}!j~.~iJNL~{ - ( ( ,.II-'"luvuIIIÇ/llIUfJlllI ( 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> it 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? > 1 don't want to commit the time to doing this if it is not necessary; > 10-404's are time consuming to prepare. Would a list of the jobs suffice, > or something similar? We have the well numbers, depth to cement top, and > sacks used to fill the void. My proposal would not affect future > submissions of 10-404's for this work. What do you think? Thanks! > > Jerry Dethlefs (See attached file: tom_maunder.vcf) 1 of 2 4/24/2003 7:55 AM .1¡JIII~v~III...JIlIUI-'IIII ~ ( ( 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'..' ...... '.'-"........""-" .._. -- .--.-...-..........,.,.. ..-...-----... ¡c;-- - Name: Cement Top Fill AOGCC Letter 04-23-03.doc DCement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 4/24/20037:55 AM ,-I" ~, C onoc;Ph i iii pS Alaska 'I' ( 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 April16t\ 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, JetTY Dethlefs ConocoPhillips Problem Well Supervisor Attachment ( ( ConocoPhillips Alaska, Inc. Suñace Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 DEPTH VOLUME TYPE SACKS - -- --------- BBlS Cement - - ---------- CD1-1 2.25' 0.3 WI 1.8 ------ j------.--.-- .------ CD1-2 4' 0.6 WI 3.6 ---- \G.~'-\~O ¡ __CD1-3 ~Q~___1.4 _MI 8.5 ;~O--~\ 'ì CD1-4 7.33' 1 P 6.0 \~<:,- \a ~ : CD1-5 -- 41 0.6 ~~- __~.6 : :;y::f:)-O~3> CD1-6 10.42' 1.4 GI 8.5 \ c;C;-()~L\ ; CD1-16 14.3_~___~----~-----_'!J1-_----_!~..:.~-- : ;)ÙD.- \ 4 ç CD 1-1 7 8 :?"~-'- -~-.:~-----~----- --- 7.2- d 0\- ()Ù(o : CD1-21 __13' - 1.8 --"" MI -------_1.<!:_~- \~ "\- à-S ~__g~1-2?_______1:~_~:_-,---, _____,Ql__- -------~--,-",_.._------_..J..:,~--- \~~-()<O-~ : JOO- \ \0 g~~~;~ 1~2~~~ ~:~ ~L___,__---~~: --- \ ~ ~- ~ ',) (.. --------------- ------ ------- dcþ~-\f:)'6 i ..-fD1-?.5 --~,:,?.~~--'-- 0.8 P 4.8 d CD- \~ ~ 'dLf:r~~ -~~ ~*- __{I\~' - ~1~ ~~~ò?:.......... ----..---------1--"'-----"'---'---"---- ------- --...--..---- \ ~ ~ - \ oL{ -ç 0 .!~~~_. ----~..:~-~'---- f--_--..1~--- -..---..-P..------ ______l:_~- J-DQ.~:.Ç>~3 l ~ C;-\\) -{.g~~;: ------~}~~~----;:~--~- ;,---"'-i~~~ ------------- -------..-..--..-......------.. ------------- -------...-------..----------- dC:iJ.- DO ~ - -- _.fP 1-~~__.. ----~_:.?:_------ --------Q~~----- ._-----_..._~------ -------~:Q------ \t\ ~- \ \ <; _90 ~ -42 -------§..:_~~~---- ----------Qß -~---- ______4.~__- dXJ~;..~'::\:\~ ! CD2-16 11.661 1.6 INJ 9.7 : d())1:::>\~ --CD"2--17f----;rS,---"--------"'----2":-S--- ---INY---- ------fs-:-f-- . JtJð-\ ~ d . -----Ç_!?~:,1~--~~=~~_1f-~~'~=-- ~==_'=f~_--___-=~=~~-~~-~=---~---"':~--~--~_?_------ J~ - ~f\) -- C ~?-=.?_?_- -_...J~~..~~------- ---______L~____-e------_!~~---------_.....1_q..:~--- död~~ '-\ i _C£2..?~?~--e-----~Z_:?"§~--------------~:!_- ---~------- -_..____--J..2.~- ;)Q -t) ")c, )D \ -09 -~~ ~~~- 1 ~ ~- --- ~ :~--~~~----H-- :fa \ - \") ~-----C-62~I3-::: ---"'----"----7'----------"------------1-------- ------"P"'-----------------6~O----- dO ,,\ -\ ~ \ . ') ~--"CÖ2:34--- ---_--___:¿F--____- -------0":6---- --------p----- ------3:6--- '6d' if () d~ I.d: _to... CD,2 -{1"",,= =Ii.:,_~ ~~ ~=..iJ....- =-y== =-~ d-O d- ~O dO 4 - \D ~ ::J~t~~ ~=~fò ~~ ~--~ -:~ _:::::1\=:: -~=~~=::-:: :=:::~~:~ --= ';)0 \.,- 'd'1C1 CD2-49 9.33' 1.3 INJ 7.8 : dO "d-tl-f' ----CO2-50 -- ---f661---'-------'-"O~"'25--------'-----P-"----------------rs---- WEllS '¡ \ \ <;. ~.. ()-'-\.. Cq_J ,dID-\~) 'O!þ d-O \ - \ d- \....\ ~\-\ð5 Annular Disposal during the first quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New 8 tart End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 38-18 31501 100 0 31601 306 0 31907 January March 3S-15,3S-16,3S-22,3S-08 2003 2003 38-07 13415 100 0 13515 216 18255 31986 Dec 2002 J an 2003 3S-10, 3S-15, 3S-09, 3S-14 CD2-48 20 144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CD2-08, CD2-28 CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 CD2- 22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2-08, CD2-36, CD2-51 2003 38-10 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 1C-190, 1C-174 2003 2003 Puviaq #1 4616 100 0 4716 15 0 4731 March March Puviaq 1 2003 2003 .f '\ ~ I ~ I A tfi h. hD. fA h . E . dd . h ft 2003 ota 0 urnes Into nnu lor W IC lsposa ut orzzatlon xplre urzng t e lrst quarter . Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 2P-427, Heavenly CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 CD2-13, CD2-37, CD2- 2002 35 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October CD2-38, CD2-44, CD2- 2002 2002 29, CD2-13 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 CD2-50, CD2-46, CD2- 22 0 , II' \ ~ APR 1 6 ZO03 Q , Alaska Oil & Gas Cons. Conmission ~ ","--. Anchorage -1J ECEIVED ( ( ¿x 0 / -ê) c¡ 9 1/3foÚJ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 November 22, 2002 RE: MWD Formation Evaluation Logs - CD2-49, AK-MW-22 0 14 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 1 LIS formatted CD Rom. API#: 50-103-20401-00. ~-" RECEIVED DEC 06 2002 AJalk8 o¡~ & Gas Cons. Commission Anchorage ~ {' aD/~tJ 9 I II C¡o \VELL LOG TRANSl\'IITT AL 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 - CD2-49, AK-MW-22014 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#: 50-103-20401-00. RECEIVED OCT 1 5 2002 Alaska Oil & Gas Cons. Commi88ion Ancb0r8ge 07/17102 Schlumbepger NO. 2241 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 I ." . Well Job # Log Description Date BL Sepia Color Prints CD CD1-01 CD2-49 1<1 q - 04 ~ INJECTION SURVEY -WARMBACKS ~f)J- avq INJECTION SURVEY-WARMBACKS 06/03/02 OS/24/02 1 1 J " SIGN~_~~~ .- --'-' fa\ e~-'In 1""< 1:: L~ r.:, V tI i'--IV JUL 2 6 2002 Aiaska Ot & Gas Cons. OJmmia~n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Ancbomse DATE: dDJ- dLf~ A 1 D. ld . th d t if 2002 ( nnu ar lsposa urzng e secon quar er 0 . . h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CO2-15 10176 100 0 10276 371 10446 21093 March Apri I CD2- 25, CD2- 50 2002 2002 2P-420 9479 100 0 9579 150 0 9729 April May 2002 2P-427, Heavenly 2002 2P-415A 26238 100 0 26338 52 4943 31333 March April 2P-431, 2P-422A, 2P-427, 2002 2002 Heavenly, Grizzly, 2P-441 CD2-49 27474 100 0 27574 386 0 27960 April May 2002 CD2-46, CD2-22, CD2-50 2002 CD2-17 14962 100 0 15062 372 0 15434 May 2002 June 2002 CD2-48, CD2-46 ID-II 32102 100 0 32202 235 0 32437 May 2002 June 2002 ID-I03 CO2-32 18536 100 0 18636 379 0 19015 June 2002 June 2002 CD2-19, CD2-41 IC-IS 4176 100 0 4276 379 0 4655 June 2002 June 2002 lC-104 ~ 1 ~ 1 A l"fi h. hD. lA h . E . dd . h d 2002 ( ora 0 urnes into nnu l or W lC lsposa ut orzzatlon xplre urzng t e secon quarter . . Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus IJ -09 24202 100 0 330 24632 Open, Freeze Protected May 2001 May 2001 11-10 IC-17 33139 100 0 160 33399 Open, Freeze Protected May 2001 June 2001 lC-133, lC-121, lC- 123, lC-127 CD2-42 33507 100 0 385 33992 Open, Freeze Protected June 2001 October CD2-24, CD2-33, CD2- 2001 15 2P-417 30965 100 0 887 31952 Open, Freeze Protected October March 2P-422, Grizzly, 2P-451, 2001 2002 2P-441, 2P-448, 2P- 422A,2P-420 I C-27 31766 100 0 153 32019 Open, Freeze Protected June 2001 July 2001 IC-127, IC-117, IC- 111, IC-123 ( , ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 March 22, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-49 (201-249) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-49. If you have any questions regarding this matter, please contact me at 265-6120 or Vern Johnson at 265-6081. AvL {. c»- Sincerely, G. C. Alvord Alpine Drilling Team Leader PAl Drilling GCA/skad '-..' '-',' -'.," ;,.,,_.,11_1,:,..,/-' ,: ,_-'-,e ,- ¡:. ". r"~. .", , --..h.'":""'" - ,.. '-,,-- .." r'."-IT".,,-,,:'-"""'r-'~ :.':-J. ',...<!J.ju~;",>...;,:.Ji'! \, (J f. ,'" ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well 'i.oCAltQNS t Oil D Gas D Suspended D Abandoned D Service 0 WAG Injector 2. Name of Operator V~~ 7. Permit Number Phillips Alaska, Inc. - ..- ~ 201-249 / ~".... "',I' \ 3. Address c:::,;¡ ':.- 8. API Number B. f-t. .. I "l "" P. O. Box 100360, Anchorage, AK 99510-0360 ..""""",",~.;:" ,,-~ 50-103-20401-00 .,.~ ,...-.. ' 4. location of well at surface J ... 9. Unit or lease Name , I . Colville River Unit 2053' FNL, 1504' FEL, Sec. 2, T11 N, R4E, UM (ASP: 371732,5974304) t _-?--/%'G..,; At Top Producing Interval 10. Well Number 1020' FSL, 761' FWL, Sec. 2, T11 N, R4E, UM (ASP: 368682, 5972150)'~ ~-<:j " ~ CD2-49 . ~ ,,\ At Total Depth I .- ...-... .."" ~-,-. i. 11. Field and Pool ~...,....,.".;,;.,~,.~~~...\!!,\.' 2009' FNL, 2328' FWL, Sec. 11, T11 N, R4E, UM (ASP: 370200, 5969094) Colville River Field 5. Elevation in feet (indicate KB, DF, 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. 15. Water Depth, if offshore 16. No. of Completions January 21 , 2002 February 2, 2002 February 4, 2002 N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11874' MD 17263' TVD 11874' MD / 7263' TVD YES 0 No D 2039' Landing Nipple 1558' 22. Type Electric or Other logs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PUllED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2494' 12.25" 390 sx AS III Lite, 236 sx Class G 7" 26# L-80 Surface 8891' 8.5" 198 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 8331' 8213' open hole completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable Injector Date of Test Hours Tested Production for Oll-BBl GAS-MCF WATER-BBl CHOKE SIZE GAS-Oil RATIO N/A Test Period> Flow Tubing Casing Pressure Calculated Oll-BBl GAS-MCF WATER-BBl Oil GRAVITY - API (corr) press. psi 24-Hour Rate> 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core Chip~; .-" , i, N/A ".0. (. ". ,.. ..'.." , i ... '... .' Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ I;.".", Submit in duplicate RBDMS BFl M~R ? 7 2m? (,~ 29. \ GEOLOGIC MARKERS 30. ( FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. CD2-49 Top Alpine D Top Alpine C Base Alpine 8400' 8448' 11874' 7193' 7211' 7263' .- 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 /).£ ¿ {}t/( Chip Alvord Title Alpine Drillina Team Leader Date 3/ ¿2-{ 0 L Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~ ...... ,- -~ ~. ,PHILLIPS t I[Ð 'V' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/20/2002 1/21/2002 1 /22/2002 1/23/2002 ( (" PHilliPS ALASKA INC. Operations Summary Report CD2-49 CD2-49 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub From - To Hours Code Code Phase 08:00 - 14:00 14:00 - 18:00 18:00 - 21 :00 21 :00 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 02:00 02:00 - 00:00 00:00 - 06:00 06:00 - 07:00 07:00 - 09:00 09:00 - 10:00 10:00 - 12:30 12:30 - 13:30 13:30 - 14:45 14:45 - 15:00 15:00 - 19:00 19:00 - 19:30 19:30 - 20:45 20:45 - 22:15 22:15 - 23:00 23:00 - 00:00 00:00 - 01 :00 6.00 MOVE MOVE MOVE 4.00 MOVE MOVE MOVE 3.00 MOVE MOVE MOVE 3.00 MOVE MOVE MOVE 0.50 MOVE SFTY MOVE 0.50 WELCTL BOPE SURFAC 1.00 DRILL PULD SURFAC 22.00 DRILL DRLG SURFAC 6.00 DRILL 1.00 DRILL DRLG SURFAC CIRC SURFAC 2.00 DRILL WIPR SURFAC 1.00 DRILL CIRC SURFAC 2.50 DRILL TRIP SURFAC 1.00 DRILL PULD SURFAC 1.25 CASE RURD SURFAC 0.25 CASE SFTY SURFAC 4.00 CASE RUNC SURFAC 0.50 CEMENl RURD SURFAC 1.25 CEMENl CIRC SURFAC 1.50 CEMENl PUMP SURFAC 0.75 CEMENl DISP SURFAC 1.00 CEMENl RURD SURFAC 1.00 CASE OTHR SURFAC Page 1 of 6 Spud Date: 1/21/2002 End: 2/4/2002 Group: Start: 1/17/2002 Rig Release: 2/4/2002 Rig Number: 19 Description of Operations PJSM. Move out Pits/Motor Complex skid flo or, Move rig to CD2-49, center rig over hole Split Pit and Motor Complexes to change out wheel and tire on Motor Complex. Spot Pits , changed out wheel and spot Motor Complex and Ball mill. NU riser, divertor and flowlin e, turn buckles, drains and mud line. RU, high line power on @ 2100 hrs. Accepted rig @ 1900 hours. Take on mud in pits, prep to spud, MU bit, motor and MWD. Held Pre-Spud meeting with Rig Team. Perform Divertor and Accumulator test, AOG CC (Chuck Sheve) waived witnessing test. fill Conductor with mud, pressure test mud I ines to 3000 psi, MU 8" drill collars. Spud well @ 0200, drill 12 1/4" hole from 11 4' to 2290'. ART=9.3 AST=5.7 Drill from 2290' to 2500'. ART=4.9 Pumped 40 bbl 300 FV sweep and circ hole c lean, 550 gpm 110 rpm, 1690 psi. Flow check well, static. Wiped hole to 1462' 10-25k over, max 50k over. RIH, no proble ms, no fill. Pumped 40 bbl 300 FV sweep and circ hole c lean with 650 gpm, 110 rpm 1850 psi. Flow check well, static. POH, no problems, max over 25k. Flowcheck well at BHA, static Stand back hwdp and 8" DC's. Lay down ubho sub, MWD, stab, pony collar and motor. RU long bails, elevators, slips and casing t 0 n g s. Held pre-job safety and operations meeting with rig crew. Ran 57 joints of 9-5/8", 36#, J-55 casing. M U hanger and landing joint and land casing with shoe @ 2494', FC @ 2405'. Lay down fill up tool and MU cement head. Staged pumps up to 8.0 bpm and condition mud for cementing. PJSM. Pump 40 bbls of Biozan wI nut plug preflush , test cement lines to 2500 psi. Pump 50 bbl s of 10.5 ppg spacer, 390 sxs of 10.7 ppg I ead and 236 sxs of 15.8 ppg tail cement. Displaced with 20 bbls of FW and 167 bbls 0 f mud, bumped plugs to 1000 psi, floats hel d, CIP @ 2255 hrs. Monitor annulus, static, flush conductor and blow down lines. RD cement head, lay down landing joint and long bails. PU wash tool and flush surface stack. Printed: 3/5/2002 4:41:31 PM ( (' PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-49 Common Well Name: CD2-49 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 1/23/2002 01 :00 - 04:00 3.00 CASE NUND SURFAC 04:00 - 05:00 05:00 - 06:30 06:30 - 12:30 1.00 CASE NUND SURFAC 1.50 WELCT NUND SURFAC 6.00 WELCT BOPE SURFAC 12:30 - 15:30 3.00 DRILL PULD SURFAC 15:30 - 17:00 1.50 DRILL TRIP SURFAC 17:00 - 18:30 1.50 RIGMNT RSRV SURFAC 18:30 - 19:30 1.00 DRILL TRIP SURFAC 19:30 - 19:45 0.25 DRILL REAM SURFAC 19:45 - 21 :00 1.25 CASE DEOT SURFAC 21 :00 - 22:30 1.50 CEMEN DSHO SURFAC 22:30 - 23:00 0.50 CEMEN LOT SURFAC 23:00 - 00:00 1.00 CEMEN LOT SURFAC 1/24/2002 00:00 - 20:30 20.50 DRILL DRLG INTRM1 1/25/2002 1/26/2002 20:30 - 21 :30 21 :30 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 00:00 00:00 - 13:30 13:30 - 14:30 14:30 - 19:30 19:30 - 21:30 1.00 DRILL CIRC INTRM1 2.50 DRILL WIPR INTRM1 0.50 DRILL 1.00 DRILL WIPR INTRM1 CIRC INTRM1 22.50 DRILL DRLG INTRM1 13.50 DRILL DRLG INTRM1 1.00 DRILL CIRC 5.00 DRILL TRIP 2.00 DRILL INTRM1 INTRM1 PULD INTRM1 Page 2 of 6 Spud Date: 1/21/2002 End: 2/4/2002 Group: Start: 1/17/2002 Rig Release: 2/4/2002 Rig Number: 19 Description of Operations ND Divertor system, installed Unihead, clea ned grease out of ring groove and found rin g groove damaged. Changed out Unihead, tested M/M seal to 10 00 psi, 10 min. NU BOPE. Test BOPE, pipe and blind rams, choke, kill, manifold and surface safety valves to 250/5 000 psi, annular preventer 250/3500 psi. Pul I test plug and set wear bushing. AOGCC (L ou Grimaldi) waived witnessing test. MU BHA #2, initialize LWD. RIH to 1750'. Slip and cut drilling line, service top drive and Drawworks. Shallow test tools, RIH to 2327'. wash down from 2327' to 2397'. RU and test casing to 2500 psi for 30 min., blow down lines. Drill out cement and float equipment from 2 397', 20' of new hole to 2520'. Circ hole clean for LOT. Perform LOT, established EMW=14.4 ppg. Drill from 2520' to 4898',4408' TVD ART= 14 AST=0.3 Pumped high vis sweeps 200'-4 00' intervals, very productives. Pumped 40 bbls 150 FV sweep and circ hole clean 640 gpm, 120 rpm, large increase in c uttings with sweep returns. Flow check well, static. Wiped hole to shoe, max overpull 10K. Flow check well, static. RIH, 3659' at midnight. RIH to 4800', no problems. Precautionary ream from to 4898', pumped 4 0 bbls 250 FV sweep, 640 gpm, 120 rpm. Ha d very heavy cuttings returns through last 6 0% of first BU, hole clean after sweep back. Initial ECD 11.2 ppg, final 10.3 ppg. Drill from 4898' to 7050' (6220 tvd) ART=12 .9 AST=2.3 Pumped high vis sweeps every 300'-400', moderate increse in cuttings retu rns with sweeps. Drill from 7050' to 7696'. ART=2.8 AST=6 Assembly difficult to slide, ROP averaged 3 0 f ph. Pump 40 bbls 300 FV sweep and circ hole cl ean, 640 gpm, 120 rpm, moderate increase i n cuttings returns with sweep back. Flow check well, static. POH to shoe, max 0 verpull 10k, flow check, static. POH to hwdp , flow check, static. stand back hwdp. Change out motor to M1X @ 1.5 degrees, Mu bit and initialize MWD. Printed: 3/5/2002 4:41 :31 PM ( ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-49 Common Well Name: CD2-49 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 1/26/2002 21 :30 - 00:00 2.50 DRILL TRIP INTRM1 1/27/2002 00:00 - 01 :45 01 :45 - 02:45 1.75 DRILL 1.00 DRILL TRIP INTRM1 CIRC INTRM1 02:45 - 00:00 21.25 DRILL DRLG INTRM1 1/28/2002 00:00 - 13:00 13.00 DRILL DRLG INTRM1 13:00 - 14:00 1.00 DRILL CIRC INTRM1 14:00 - 17:30 3.50 DRILL WIPR INTRM1 17:30 - 17:45 17:45 - 19:30 0.25 DRILL CIRC INTRM1 1.75 DRILL CIRC INTRM1 19:30 - 00:00 4.50 DRILL TRIP INTRM1 1/29/2002 00:00 - 02:00 2.00 DRILL TRIP INTRM1 02:00 - 04:00 2.00 DRILL TRIP INTRM1 04:00 - 06:30 2.50 DRILL OTHR INTRM1 1/30/2002 06:30 - 08:00 08:00 - 20:30 1.50 CASE 12.50 CASE RURD INTRM1 RUNC INTRM1 20:30 - 21 :00 0.50 CEMEN RURD INTRM1 21 :00 - 22:30 1.50 CEMEN CI RC INTRM1 22:30 - 00:00 1.50 CEMEN PUMP INTRM1 00:00 - 00:30 0.50 CEMEN DISP INTRM1 Page 3 of 6 Spud Date: 1/21/2002 End: 2/4/2002 Group: Start: 1/17/2002 Rig Release: 2/4/2002 Rig Number: 19 Description of Operations RIH to 2019', fill pipe and shallow test tools . Continue to RIH, fill pipe every 2000',459 7' @ midnight. RIH to 7561', no problems.. Precautionary ream last stand, pump 40 bbls 250 FV sweep, condition heavy (11.0 ppg) t hick mud until I clean, @ 640 gpm, 110 rpm. Initial ECD 11.2 ppg, final 10.3 ppg. Drill from 7669' to 8416' (7200' tvd) ART=2. 3 AST=12.5 Drill from 8416' to 8901', casing point (7260 , tvd). ART=2.1 AST=6.5 Circ and condition mud for wiper trip, monit or well, static. Pump out to 8256', 4 bpm 510 psi, 10-20k ov er. Wiped hole to 7493' 10-20k over, flow ch eck well, static. RIH, wiped tight hole from 8290' to 8310' untill free, RIH to 8830'. Establish circ and precautionary ream from 8830' to 8901'. Pumped 40 bbls 250 FV sweep, circ and con d mud 14.4 bpm, 100 rpm, 3220 psi. Moderat e amount of sand back at BU, sweep return ed nearly clean, Flow check well, static. Pump out to 8225', max overpull 15k. POH, no problems, 3706' @ midnight. POOH FI 3706' TO 1068' (BHA) - monitor we I I @ 2493' POOH wI BHA - LD MWD, motor, & bit - moni tor well - static Pull wear bushing - set test plug - change t op pipe rams to 7" & test to 5000 psi - pull test plug - set thin wall wear bushing Rig up to run 7" casing - Held PJSM Run 7" 26# L-80 MBTC csg 217 jts. - landed wI shoe @ 8891' FC @ 8806' - Circulate bott oms up @ 2486', 5088', & 7337' - worked thr ough tight spots fl 8238' to 8470' RD tongs & fill up tool - install cement head - rig up cement line Circulate and condition for cement job - hel d PJSM Cement 7" casing: Pumped 5 bbls Arco was h - test lines to 3500 psi - pumped 15 bbls Arco wash - pumped 50 bbls Arco spacer @ 12.5 ppg - drop btm plug - mix & pump 40 bb Is cmt slurry @ 15.8 ppg (198 sks) - drop to p plug - pumped 20 bbls water - switch to ri g pumps & displace wI 9.6 ppg mud @ 5 bbls I m i n Finish displacing cement pupming 5 bbls/mi n @ 800 psi - bumped plug wI 1600 psi - flo ats held - CIP @ 0025 hrs. Printed: 3/5/2002 4:41:31 PM ( ( PHilliPS ALASKA INC. Operations Summary Report legal Well Name: CD2-49 Common Well Name: CD2-49 Event Name: ROT - DRilLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 1/30/2002 00:30 - 01 :00 0.50 CEMEN PULD INTRM1 01 :00 - 03:00 2.00 DRILL OTHR INTRM1 03:00 - 04:00 1.00 WELCT BOPE INTRM1 04:00 - 09:00 5.00 WELCT BOPE INTRM1 09:00 - 13:00 4.00 DRILL PULD PROD 13:00 - 16:00 3.00 DRILL PULD PROD 16:00 - 18:00 2.00 DRILL TRIP PROD 18:00 - 20:30 2.50 DRILL TRIP PROD 20:30 - 21 :00 0.50 DRILL OTHR PROD 21 :00 - 22:00 1.00 DRILL CIRC PROD 22:00 - 23:00 1.00 DRILL OTHR PROD 23:00 - 00:00 1.00 DRILL OTHR PROD 1/31/2002 00:00 - 01 :30 1.50 DRILL OTHR PROD 01 :30 - 02:00 02:00 - 03:00 03:00 - 04:00 0.50 DRILL 1.00 DRILL 1.00 DRILL DRLG PROD CIRC PROD FIT PROD 04:00 - 05:30 1.50 DRILL OTHR PROD 05:30 - 06:00 0.50 DRILL OTHR PROD 06:00 - 00:00 18.00 DRILL DRLH PROD 2/1/2002 00:00 - 00:00 24.00 DRILL DRLH PROD 2/2/2002 00:00 - 07:30 7.50 DRILL DRLH PROD 07:30 - 08:00 0.50 WELCT OTHR PROD Page 4 of 6 Spud Date: 1/21/2002 End: 2/4/2002 Group: Start: 1/17/2002 Rig Release: 2/4/2002 Rig Number: 19 Description of Operations Rig down cmt head - LD landing joint Flush stack - pull thin wall wear bushing - S et & test pack off to 5000 psi Set test plug - change top pipe rams back to 3 1/2" x 6" VRB PJSM Test BOPE - Pipe rams, choke manifold valv es, kill & choke line valves, floor & top driv e valves, blind rams to 250 psi low & 5000 P si high - test Hydril to 250 psi low & 3500 P si high - Witnessing of test waived by AOGC C - pull test plug - set wear bushing - blow down kill & choke lines PU bails & elevators - PJSM - PU 6 1/8" BH A - MU MWD - orient motor & MWD - RIH to 361' - shallow test MWD RIH w/ 6 1/8" bit to 3509' - PU 99 jts. 4" dr ill pipe f/ pipe shed Slip & cut drill line - service top drive Continue RIH f/ 3509' to 8694' Tag up @ 8694 - C/O cmt stringers to 8757' Circulate bottoms up for csg test Rig up & test 7" casing to 3500 psi for 30 m ins. C/O cmt f/ 8757' to 8804 ' - drill wiper plug s f/ 8804' Drill up wiper plugs - drill FC @ 8806' - dril I cmt to FS - Drill out shoe @ 8891' - C/O r at hole to 8901 Drill 20' new hole f/ 8901' to 8921' Circulate for FIT RU & perform F.I.T. to 12.5 ppg EMW wI 110 0 psi w/ 9.6 ppg mud - RD - blow down kill & choke lines Monitor well - static - PJSM - Change well 0 ver to 9.0 ppg Flo-Pro - monitor well - stati c Perform base line ECD Dril16 1/8" hole f/ 8921' to 9879' TVD 7241 ADT 12.6 ART 11 AST 1.6 Dril16 1/8" hole f/ 9879' to 11,122' 7261' T VD ADT 16.5 AST 1.1 ART 15.4 Drill 6 1/8" hole f/ 11,122' to 11,514' - hole started taking fluid Continue to drill @ reduced pump ratef/ 11, 514' to 11,527' - kelly down - flow chec k wel I - well flowing - shut in well SIDPP - 230 psi SICP- 0 - monitor pressure for 15 min. - DPP - 90 psi CP - 0 - open well through choke & bleed for 5 min. DPP & CP both 0 - Shut in choke monitor pressure for 10 mins. DPP 0 & CP 0 - open well flow check - no f low - fluid level dropping very slowly. Exha Ie Test - well appears to be breathing Printed: 3/5/2002 4:41:31 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/2/2002 ( (' PHilliPS ALASKA INC. Operations Summary Report CD2-49 CD2-49 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub From - To Hours Code Code Phase 08:00 - 10:15 10:15 - 13:00 13:00 - 19:30 19:30 - 22:30 22:30 - 00:00 2.25 DRILL DRLH PROD 2.75 WELCT KILL PROD 6.50 DRILL DRLH PROD 3.00 DRILL DRLH PROD 1.50 DRILL DRLH PROD 2/3/2002 00:00 - 01 :00 1.00 CMPL TN OTHR CMPL TN 01 :00 - 11 :30 10.50 CMPL TN TRI P CMPL TN 11 :30 - 12:30 1.00 CMPL TN PULD CMPL TN 12:30 - 13:00 0.50 CMPL TN OTHR CMPL TN 13:00 - 13:30 0.50 CMPL TN OTHR CMPL TN 13:30 - 21 :00 7.50 CMPL TN RUNT CMPL TN 21 :00 - 22:00 1.00 CMPL TN OTHR CMPL TN 22:00 - 23:30 1.50 CMPL TN NUND CMPL TN 23:30 - 00:00 0.50 CMPL TN NUND CMPL TN 2/4/2002 00:00 - 01 :00 1.00 CMPL TN NUND CMPL TN 01 :00 - 02:00 1.00 CMPL TN OTHR CMPL TN 02:00 - 02:30 0.50 CMPL TN OTHR CMPL TN 02:30 - 05:30 3.00 CMPL TN OTHR CMPL TN Page 5 of 6 Spud Date: 1/21/2002 End: 2/4/2002 Group: Start: 1/17/2002 Rig Release: 2/4/2002 Rig Number: 19 Description of Operations Make connection & drill fl 11,527' to 11,621' - Observed increase in flow rate - shut dow n pump - well flowing - shut in well SIDPP - 450 psi SICP - 340 psi - monitor pr essure for 15 mins. SIDPP- 410 psi SICP- 330 psi - Circulate out kick wI Drillers Met hod - 30 spm @ 1070 psi - shut down pump - DDP - 0 CP- 0 - monitor pressure for 10 m ins. - DPP- 0 CP- 0 - open Hydril monitor w ell - well static Continue drilling 6 1/8" hole fI 11,621' to 11 ,874' TD WI reduced pump rate 176 gpm - hole still taking fluid & breathing on connec t ion s pump hi vis pill & circulate hole clean @ 4 BPM @ 100 RPM - while cleaning pits & tak e on 9.1 ppg KCL brine PJSM - change well over to KCL brine - pum p 40 bbls vis spacer - & 9.1 ppg brine @ 4.5 BPM Drilling time last 24 hrs. ADT 13 .2 ART 12.6 AST.6 Total losses to form ation 522 bbls Flo-Pro & 60 bbls brine while displacing Finish changing well over to 9.1 ppg KCL bri ne - monitor well fluid level 4" below flow Ii ne & dropping very slowly POOH wI bit # 4 to run completion - LD 25 jt s. 4" drill pipe wI bad hard banding LD BHA - MWD, motor, stab, & bit Pull wear bushing RU to run 4 1/2" completion - held PJSM Run 4 1/2" completion - MU - WLEG, pup jt. - XN nippple wI RHC plug installed - 2 jts. 4 1/2" 12.6# L-80 IBT-M tbg - Baker 8-3 pack erwl mill out extension - 2 jts. 4 1/2" 12.6# L-80 IBT-M tbg - GLM wI dummy valve - 139 jts.4 1/2" 12.6# L-80 IBT-M tbg - Camco D B nipple - 46 jts. 4 1/2" 12.6# L-80 IBT-M tb g - FMC tbg hanger & landing jt. - Land tbg in well head on tbg hanger W tail @ 8330' - LD landing jt A Run in lock down screws on hanger - install TWC - PU and install landing jt. B - rig up & test hanger seals to 5000 psi for 10 mins. - RD test equip & LD landing jt. B ND BOP, flow line, turnbuckles, all lines - r emove BOP & set back in rack NU tree NU & test tree to 5000 psi RU FMC lubicator & pull TWC - RD lubicator RU for change over - PJSM Test lines to 1500 psi - Displace well wI 11 0 bbls 9.6 Inhib KCL brine & pump tbg volum Printed: 3/5/2002 4:41:31 PM ~ ..... ~ ~~PHILLlPS) IW> 'V" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/4/2002 From - To 02:30 - 05:30 05:30 - 06:30 06:30 - 09:00 09:00 - 10:30 10:30 - 15:00 (' ( PHilliPS ALASKA INC. Operations Summary Report CD2-49 CD2-49 ROT - DRILLING doyon1 @ppco.com Doyon 19 C Sub Hours ode Code 3.00 CMPL TN OTHR CMPL TN Phase 1.00 CMPL TN PCKR CMPL TN 2.50 CMPL TN PCKR CMPL TN 1.50 CMPL TN OTHR CMPL TN 4.50 CMPL TN OTHR CMPL TN Page 6 of 6 Spud Date: 1/21/2002 End: 2/4/2002 Group: Start: 1/17/2002 Rig Release: 2/4/2002 Rig Number: 19 Description of Operations e plus 2000' diesel for freeze protection 155 bbls total RU lubicator & drop packer setting ball & ro d - RD lubicator Pressure test lines to 4000 psi - pressure u p on tbg to 3500 psi to set packer & test tbg for 30 mins.- Bleed off pressure to 800 psi - pressure up on annulus to 3500 psi & test for 30 mins. - bleed off pressure - vaccume out lines - RD lines & squeeze maniflod RU FMC lubicator & set BPV - RD lubicator & secure well LD excess DP f/ derrick in mouse hole - cha nge TD junk sub f/ XT-39 to 4 1/2" IF REL EASE RIG @ 1500 hrs. - 2/4/2002 Printed: 3/5/2002 4:41:31 PM - - - - - - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00119 Sidetrack No. Page 1 of 7 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD . Well Name & No. PAD CD#2/49 Survey Section Name CD2-49 MWD BHIRep. NEWLON/FUHRER I r.rrEQ. WELL DATA TargetTVD (FT) Target Coord. N/S Slot Coord. N/S -2053.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD ssD Target Description Target Coord. E/W Slot Coord. E/W -1502.79 Magn. Declination 25.160 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 3OmD 1OmD Vert. Sec. Azim. 226.98 Magn. to Map Corr. 25.160 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical Build (+) Right (+) Comment Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (Fì) (DO) (DO) (Fì) (FT) (Fl) (Fl) (Per 100 Fl) Drop (-) Left (-) TIE IN POINT ~ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - 21-JAN-02 MWD 114.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 0.00 21-JAN-02 MWD 172.00 0.35 204.00 58.00 172.00 0.16 -0.16 -0.07 0.60 0.60 Gyro Single Shot 21-JAN-02 MWD 210.99 0.48 191.74 38.99 210.99 0.41 -0.43 -0.15 0.40 0.33 21-JAN-02 MWD 303.87 2.09 221.79 92.88 303.84 2.41 -2.07 -1.36 1.82 1.73 21-JAN-O2 MWD 394.47 2.85 226.81 90.60 394.36 6.31 -4.85 -4.10 0.87 0.84 21-JAN-02 MWD 485.40 4.19 233.32 90.93 485.11 11.87 -8.38 -8.42 1.54 1.47 21-JAN-O2 MWD 574.83 5.24 237.37 89.43 574.24 19.14 -12.53 -14.48 1.23 1.17 4.53 21-JAN-O2 MWD 664.79 5.55 233.46 89.96 663.80 27.50 -17.34 -21.43 0.53 0.34 -4.35 21-JAN-02 MWD 754.12 4.64 235.97 89.33 752.78 35.36 -21.93 -27.90 1.05 -1.02 . 21-JAN-02 MWD 842.84 4.30 245.06 88.72 841.23 42.07 -25.34 -33.89 0.88 -0.38 21-JAN-O2 MWD 933.20 3.39 251.12 90.36 931.39 47.72 -27.64 -39.49 1.10 -1.01 21-JAN-O2 MWD 1 028.11 1.94 265.14 94.91 1026.19 51.55 -28.68 -43.74 1.66 -1.53 ---. - 21-JAN-02 MWD 1123.28 1.96 257.43 95.17 1121.31 54.22 -29.17 -46.94 0.28 0.02 21-JAN-02 MWD 1218.32 3.47 250.69 95.04 1216.24 58.25 -30.48 -51.24 1.62 1.59 21-JAN-O2 MWD 1313.10 5.44 247.16 94.78 1310.73 65.10 -33.17 -58.09 2.10 2.08 -3.72 21-JAN-02 MWD 1408.94 8.72 243.64 95.84 1405.82 76.32 -38.16 -68.78 3.45 3.42 -3.67 21-JAN-O2 MWD 1503.56 12.48 243.65 94.62 1498.81 92.99 -45.88 -84.38 3.97 3.97 0.01 21-JAN-O2 . MWD 1598.99 14.86 244.57 95.43 1591 .53 114.54 -55.72 -104.67 2.50 2.49 0.96 21-JAN-O2 MWD 1692.92 18.21 244.95 93.93 1681 .57 139.99 -67.11 -128.85 3.57 3.57 0.40 21-JAN-02 MWD 1788.67 22.04 243.58 95.75 1771 .45 171.45 -81.44 -158.51 4.03 4.00 -1.43 21-JAN-O2 MWD 1883.63 25.96 243.04 94.96 1858.19 208.51 -98.80 -193.00 4.13 4.13 -0.57 21-JAN-02 MWD 1979.07 29.44 244.53 95.44 1942.68 250.96 -118.36 -232.81 3.72 3.65 1.56 21-JAN-O2 MWD 2074.46 32.49 245.29 95.39 2024.46 297.65 -139.16 -277.26 3.22 3.20 0.80 . .. ,. , : " I' 'I . - ." ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00119 Sidetrack No. Page 2 of 7 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/49 Survey Section Name CD2-49 MWD BHI Rep. NEWLON I FUHRER I NTEQ WELL DATA Target 1VD (n) Target Coord. N/S Slot Coord. N/S -2053.00 Grid Correction 0.000 Depths Measured From: AKB g¡ MSL 0 SSD Target Description Target Coord. E/W Slot Coord. E/W -1502.79 Magn. Declination 25.160 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 3OmD 10mO Vert. Sec. Azim. 226.98 Magn. to Map Corr. 25.160 Map North to: OTHER SURVEY DATA Survey Total Coordinate Build Rate Walk Rate I Survey Incl. Hole Course Vertical Date Tool Depth Angle Direction Length 1VD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 21-JAN-02 MWD 2170.27 32.79 241.46 95.81 2105.15 347.20 -162.31 -323.43 2.18 0.31 -4.00 (" - 21-JAN-02 MWD 2265.03 32.63 240.98 94.76 2184.88 396.83 -186.96 -368.31 0.32 -0.17 -0.51 22-JAN-02 MWD 2360.47 32.41 241.07 95.44 2265.36 446.61 -211.82 -413.20 0.24 -0.23 0.09 22-JAN-02 MWD 2444.84 32.14 241 .63 84.37 2336.69 490.25 -233.42 -452.73 0.48 -0.32 0.66 24-JAN-02 MWD 2536.45 31.67 240.98 91.61 2414.46 537.16 -256.67 -495.20 0.64 -0.51 -0.71 24-JAN-02 MWD 2631.89 31.62 240.87 95.44 2495.71 585.76 -281.00 -538.97 0.08 -0.05 -0.12 24-JAN-02 MWD 2727.52 31 .40 239.43 95.63 2577.24 634.42 -305.87 -582.31 0.82 -0.23 -1.51 24-JAN-02 MWD 2823.40 31.35 239.52 95.88 2659.10 683.16 -331.23 -625.31 0.07 -0.05 0.09 24-JAN-O2 MWD 2919.36 31.36 238.55 95.96 2741.05 731.99 -356.92 -668.13 0.53 0.01 -1.01 24-JAN-02 MWD 3012.81 31.41 237.55 93.45 2820.83 779.75 -382.67 -709.42 0.56 0.05 -1.07 24-JAN-02 MWD 3111.54 31.50 238.11 98.73 2905.05 830.35 -410.10 -753.03 0.31 0.09 0.57 24-JAN-02 MWD 3207.41 32.11 240.14 95.87 2986.53 879.73 -436.02 -796.40 1.28 0.64 2.12 24-JAN-02 MWD 3302.35 32.00 240.48 94.94 3066.99 928.76 -460.98 -840.17 0.22 -0.12 0.36 I" - 24-JAN-02 MWD 3398.02 31.84 240.82 95.67 3148.19 977.91 -485.77 -884.26 0.25 -0.17 0.36 24-JAN-02 MWD 3493.48 31.77 240.45 95.46 3229.32 1026.80 -510.44 -928.11 0.22 -0.07 -0.39 24-JAN-02 MWD 3589.07 31.81 239.96 95.59 3310.57 1075.82 -535.46 -971.81 0.27 0.04 -0.51 24-JAN-02 MWD 3684.60 32.80 241.48 95.53 3391.31 1125.41 -560.42 -1016.34 1.34 1.04 1.59 24-JAN-02 MWD 3779.85 32.76 242.01 95.25 3471.40 1175.28 -584.84 -1061.76 0.30 -0.04 0.56 24-JAN-02 MWD 3875.38 32.82 240.91 95.53 3551.71 1225.37 -609.55 -1107.21 0.63 0.06 -1.15 24-JAN-02 MWD 3970.77 32.80 242.08 95.39 3631.88 1275.40 -634.22 -1152.63 0.66 -0.02 1.23 24-JAN-02 MWD 4066.27 32.82 241 .18 95.50 3712.14 1325.47 -658.81 -1198.16 0.51 0.02 -0.94 24-JAN-02 MWD 4161.54 32.96 241.55 95.27 3792.14 1375.58 -683.60 -1243.57 0.26 0.15 0.39 . 24-JAN-02 MWD 4256.82 33.00 240.85 95.28 3872.07 1425.85 -708.58 -1289.02 0.40 0.04 -0.73 24-JAN-02 MWD 4351.28 33.26 240.06 94.46 3951.18 1476.06 -734.04 - 1333.93 0.'53 0.28 .-0.84 " , ., .', " r '1, (' " I ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00119 Sidetrack No. Page 3 of 7 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2J49 Survey Section Name CD2-49 MWD BHI Rep. NEWLON I FUHRER I NTIEQ WELL DATA Target TVD (Fì) Target Coord. N/S Slot Coord. N/S -2053.00 Grid Correction 0.000 Depths Measured From: RKB g¡ MSLO SSO Target Description Target Coord. E/VÝ Slot Coord. E/VÝ -1502.79 Magn. Declination 25.160 Calculation Method MINIMUM CURVATURE Target Direction (CD) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 226.98 Magn. to Map Corr. 25.160 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment Type (Fì) (DD) (DD) (Fì) (Fì) (Fì) (Fì) (Per 100 Fì) Drop (-) Left (-) 24-JAN-02 MWD 4447.16 33.36 240.33 95.88 4031 .30 1527.32 -760.21 -1379.62 0.19 0.10 0.28 { - 24-JAN-02 MWD 4542.40 33.35 240.00 95.24 4110.86 1578.30 -786.27 -1425.04 0.19 -0.01 -0.35 24-JAN-02 MWD 4637.63 33.36 239.52 95.23 4190.40 1629.36 -812.64 -1470.28 0.28 0.01 -0.50 24-JAN-02 MWD 4732.83 33.38 237.95 95.20 4269.91 1680.63 -839.81 -1515.03 0.91 0.02 -1.65 24-JAN-02 MWD 4826.98 33.57 238.03 94.15 4348.44 1731.60 -867.34 -1559.07 0.21 0.20 0.08 25-JAN-02 MWD 4925.15 33.58 237.40 98.17 4430.23 1784.94 -896.33 -1604.96 0.36 0.01 -0.64 25-JAN-02 MWD 5019.90 33.66 240.03 94.75 4509.14 1836.29 -923.57 -1649.79 1.54 0.08 2.78 25-JAN-02 MWD 5115.16 33.37 240.14 95.26 4588.56 1887.52 -949.80 -1695.38 0.31 -0.30 0.12 25-JAN-02 MWD 5210.17 33.61 241 .61 95.01 4667.80 1938.41 -975.32 -1741.17 0.89 0.25 1.55 25-JAN-02 MWD 5305.15 33.79 241.36 94.98 4746.82 1989.43 -1000.47 -1787.48 0.24 0.19 -0.26 25-JAN-02 MWD 5402.26 33.66 241.46 97.11 4827.58 2041.65 -1026.27 -1834.82 0.15 -0.13 0.10 25-JAN-02 MWD 5496.93 33.90 240.82 94.67 4906.27 2092.68 -1051.68 -1880.92 0.45 0.25 -0.68 25-JAN-02 MWD 5592.03 34.02 239.91 95.10 4985.15 2144.36 -1077.95 -1927.09 0.55 0.13 -0.96 ( - 25-JAN-02 MWD 5687.23 33.08 241.73 95.20 5064.49 2195.45 -1103.61 -1973.02 1.45 -0.99 1.91 25-JAN-02 MWD 5782.16 33.07 241.82 94.93 5144.04 2245.54 -1128.11 -2018.67 0.05 -0.01 0.09 25-JAN-02 MWD 5878.90 33.19 245.60 96.74 5225.06 2296.15 -1151.51 -2066.05 2.14 0.12 3.91 25-JAN-02 MWD 5974.87 32.90 245.04 95.97 5305.51 2345.82 -1173.37 -2113.60 0.44 -0.30 -0.58 25-JAN-02 MWD 6070.05 32.73 245.14 95.18 5385.50 2394.84 -1195.09 -2160.38 0.19 -0.18 0.11 25-JAN-02 MWD 6166.18 32.43 243.65 96.13 5466.50 2444.23 -1217.46 -2207.06 0.89 -0.31 -1.55 25-JAN-02 MWD 6261.72 31.72 244.57 95.54 5547.46 2492.72 -1239.61 -2252.70 0.90 -0.74 0.96 25-JAN-02 MWD 6357.26 31.74 243.55 95.54 5628.72 2540.74 -1261.59 -2297.88 0.56 0.02 -1.07 25-JAN-02 MWD 6452.81 32.20 243.48 95.55 5709.78 2589.24 -1284.15 -2343.17 0.48 0.48 -0.07 25-JAN-02 MWD 6547.70 32.19 242.40 94.89 5790.08 2637.85 -1307.15 -2388.19 0.61 -0.01 -1.14 25-JAN-02 MWD 6643.39 32.10 242.61 95.69 5871.10 2686.91 -1330.66 -2433.35 0.15 -0.09 0.22 .'c" . . . . . . - - - - - - - - - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00119 Sidetrack No. Page 4 of 7 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/49 Survey Section Name CD2-49 MWD BHI Rep. NEWLON I FUHRER , NTEQ WELL DATA Target 1VD (FT) Target Coord. N/S Slot Coord. N/S -2053.00 Grid Correction 0.000 Depths Measured From: RKB g¡ MSL 0 SSO Target Description Target Coord. E/W Slot Coord. E/W -1502.79 Magn. Declination 25.160 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 226.98 Magn. to Map Corr. 25.160 Map North to: OTHER SURVEY DATA Survey Survey Inc!. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 1VD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 25-JAN-02 MWD 6738.74 31.86 242.68 95.35 5951.98 2735.53 -1353.86 -2478.20 0.25 -0.25 0.07 ( - 25-JAN-02 MWD 6834.38 31.50 242.68 95.64 6033.37 2783.88 -1376.91 -2522.83 0.38 -0.38 0.00 25-JAN-02 MWD 6929.73 31.16 242.09 95.35 6114.81 2831.68 -1399.89 -2566.76 0.48 -0.36 -0.62 26-JAN-02 MWD 7024.72 32.42 241 .34 94.99 6195.55 2880.08 -1423.61 -2610.82 1.39 1.33 -0.79 26-JAN-02 MWD 7120.71 35.75 236.08 95.99 6275.06 2932.72 -1451.61 -2656.69 4.63 3.47 -5.48 26-JAN-02 MWD 7215.91 37.21 232.14 95.20 6351.61 2988.86 -1484.81 -2702.50 2.90 1.53 -4.14 26-JAN-02 MWD 7312.88 38.01 230.83 96.97 6428.43 3047.85 -1521.66 -2748.80 1.17 0.82 -1.35 26-JAN-02 MWD 7408.10 37.99 229.99 95.22 6503.47 3106.37 -1559.02 -2793.98 0.54 -0.02 -0.88 , 26-JAN-02 MWD 7504.03 38.15 229.98 95.93 6578.99 3165.44 -1597.05 -2839.28 0.17 0.17 -0.01 26-JAN-02 MWD 7595.12 38.77 229.82 91.09 6650.31 3222.02 -1633.55 -2882.62 0.69 0.68 -0.18 27 -JAN-02 MWD 7695.55 39.77 226.12 100.43 6728.07 3285.55 -1676.11 -2929.80 2.54 1.00 -3.68 27 -JAN-02 MWD 7721.12 40.40 223.43 25.57 6747.64 3302.00 -1687.80 -2941.40 7.21 2.46 -10.52 27 -JAN-02 MWD 7753.37 40.89 219.66 32.25 6772.11 3322.91 -1703.51 -2955.32 7.76 1.52 -11 .69 l " - 27 -JAN-02 MWD 7785.77 41.73 215.25 32.40 6796.46 3343.99 -1720.49 -2968.31 9.35 2.59 -13.61 27 -JAN-02 MWD 7819.02 41.99 212.99 33.25 6821.22 3365.62 -1738.86 -2980.76 4.60 0.78 -6.80 27 -JAN-02 MWD 7850.60 42.13 210.60 31.58 6844.67 3386.03 -1756.83 -2991.90 5.09 0.44 -7.57 27-JAN-02 MWD 7881.31 42.49 208.36 30.71 6867.38 3405.74 -1774.83 -3002.07 5.05 1.17 -7.29 27 -JAN-02 MWD 7914.00 43.13 205.85 32.69 6891.36 3426.63 -1794.60 -3012.19. 5.57 1.96 -7.68 27 -JAN-02 MWD 7945.47 43.52 203.37 31.47 6914.26 3446.60 -1814.23 -3021.18 5.55 1.24 -7.88 27-JAN-02 MWD 7976.56 43.99 199.94 31.09 6936.72 3466.02 -1834.21 -3029.11 7.78 1.51 -11.03 27-JAN-02 MWD 8010.28 44.52 196.80 33.72 6960.87 3486.67 -1856.54 -3036.52 6.69 1.57 -9.31 27-JAN-02 MWD 8042.33 46.13 194.63 32.05 6983.41 3506.15 -1878.47 -3042.69 6.96 5.02 -6.77 27 -JAN-02 MWD 8073.15 47.07 191 .19 30.82 7004.59 3524.69 -1900.29 -3047.68 8.66 3.05 -11.16 27-JAN-02 MWD 8105.76 48.65 187.29 32.61 7026.47 3543.80 -1924.15 -3051.55 10.10 4.85 -11 .96 .., " ,. ..' ,. .., - - - - - - - - - i ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00119 Sidetrack No. Page ~ of 7 - Company PHILLIPS ALASKA. INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/49 Survey Section Name CD2-49 MWD BHIRep. NEWLON/FUHRER 'NTEQ. WELL DATA Depths Measured From: RKB g] MSLD SSD ' Target TVD (Fì) Target Coord. N/S Slot Coord. N/S -2053.00 Grid Correction 0.000 Target Description Target Coord. E/W Slot Coord. E/W -1502.79 Magn. Declination 25.160 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 1000[3 30mD 10mD Vert. Sec. Azim. 226.98 Magn. to Map Corr. 25.160 Map North to: OTHER SURVEY DATA Survey Survey Inc!. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (Fì) (DO) (DO) (Fì) (Fì) (Fì) (Fì) (Per 100 Fì) Drop (-) Left (-) MWD 8137.48 3561 .99 -7.53 ," 27-JAN-02 50.08 184.90 31.72 7047.13 -1948.09 -3054.10 7.28 4.51 ( - 27-JAN-02 MWD 8168.40 51.12 180.52 30.92 7066.76 3579.09 -1971.94 -3055.22 11.45 3.36 -14.17 27 -JAN-02 MWD 8201.12 52.33 175.57 32.72 7087.04 3595.94 -1997.60 -3054.34 12.44 3.70 -15.13 27-JAN-02 MWD 8233.26 54.24 172.85 32.14 7106.25 3611 .52 -2023.22 -3051.73 9.02 5.94 -8.46 27-JAN-02 MWD 8263.07 55.72 170.31 29.81 7123.36 3625.38 -2047.37 -3048.15 8.56 4.96 -8.52 27-JAN-02 MWD 8296.52 56.75 167.66 33.45 7141.95 3640.11 -2074.66 -3042.84 7.27 3.08 -7.92 27 -JAN-02 MWD 8328.39 58.89 166.33 31.87 7158.93 3653.60 -2100.94 -3036.77 7.59 6.71 -4.17 27-JAN-02 MWD 8358.07 60.77 165.89 29.68 7173.84 3666.09 -2125.85 -3030.60 6.46 6.33 -1.48 27-JAN-02 MWD 8391.74 64.29 167.24 33.67 7189.37 3680.84 -2154.90 -3023.67 11.04 10.45 4.01 28-JAN-02 MWD 8423.62 67.09 168.26 31.88 7202.49 3695.70 -2183.29 -3017.51 9.25 8.78 3.20 28-JAN-02 MWD 8454.65 70.56 168.25 31.03 7213.70 3710.72 -2211.61 -3011.62 11.18 11.18 -0.03 28-JAN-02 MWD 8486.32 73.86 168.04 31.67 7223.38 3726.33 -2241.12 -3005.43 10.44 10.42 -0.66 28-JAN-02 MWD 8518.83 77.25 168.28 32.51 7231.48 3742.62 -2271 .93 -2998.97 10.45 10.43 0.74 - 28-JAN-02 MWD 8550.44 79.82 167.41 31.61 7237.77 3758.51 -2302.21 -2992.44 8.57 8.13 -2.75 28-JAN-02 MWD 8582.32 81.98 167.47 31.88 7242.81 3774.47 -2332.93 -2985.60 6.78 6.78 0.19 28-JAN-02 MWD 8614.53 84.07 165.12 32.21 7246.72 3790.12 -2363.99 -2978.02 9.72 6.49 -7.30 28-JAN-02 MWD 8644.88 85.64 164.33 30.35 7249.44 3804.19 -2393.15 -2970.06 5.79 5.17 -2.60 28-JAN-02 MWD 8678.19 87.09 162.35 33.31 7251.55 3818.95 -2425.00 -2960.53 7.36 4.35 -5.94 28-JAN-02 MWD 8709.98 88.01 162.06 31.79 7252.91 3832.49 -2455.24 -2950.82 3.03 2.89 -0.91 28-JAN-02 MWD 8741.23 88.59 159.65 31.25 7253.84 3845.13 -2484.74 -2940.58 7.93 1.86 -7.71 28-JAN-02 MWD 8773.02 88.55 157.88 31.79 7254.63 3856.92 -2514.36 -2929.07 5.57 -0.13 -5.57 28-JAN-02 MWD 8804.71 88.55 156.38 31.69 7255.44 3867.83 -2543.55 -2916.76 4.73 0.00 -4.73 28-JAN-02 MWD 8836.80 87.83 153.94 32.09 7256.45 3877.84 -2572.66 -2903.29 7.92 -2.24 -7.60 31-JAN-02 MWD 8927.37 89.63 150.73 90.57 7258.46 3901 .81 -2652.84 -2861 .25 4.06 1.99 -3.54 ----- - ---- ~ SURVEY CALC U LA TIO N AN D FIE LD W 0 R KS H E ET Job No. 045().00119 Sidetrack No. Page ~ of..J.... .... ...... .... Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/49 Survey Section Name CD2-49 MWD BHI Rep. NEWLON I FUHRER INTEQ. WELL DATA Target TVD (F1) Target Coord. N/S Slot Coord. N/S -2053.00 Grid Correction 0.000 Depths Measured From: RKB g¡ MSLD SSD Target Description Target Coord. E/W Slot Coord. ENl -1502.79 Magn. Declination 25.160 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 30mD 10mD Vert. Sec. Azim.. 226.98 Magn. to Map Corr. 25.160 Map North to: OTHER SURVEY DATA . Survey Survey Incl. Hole Course Vertical Total Coordinate Bui~d Rate W~lk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (F1) (F1) (FT) (FT) (Per 100 F1) Drop (-) Left (-) .-. 31-JAN-O2 MWD 8988.11 89.45150.32 60.74 7258.94 3916.04 -2705.71 -2831.36 0.74 -0.30 -0.68. - 31-JAN-O2 MWD .9083.75 89.45 151.00 95.64 7259.86 3938.66 -2789.08 -2784.50 0.71 0.00 0.71 31-JAN-O2 MWD 9179.43 91 .54 152.28 95.68 7259.04 3962.87 -2873.27 -2739.06 2.56 2.18 1.34 . 31-JAN-O2 MWD. 9275.25 91.66 152.35 95.82 7256.36 3988.20 -2958.09 -2694.56 0.14 0.13 0.07 31-JAN-02 MWD 9370.79 91.66 152.27 95.54 7253.59 4013.45 -3042.65 -2650.18 0.08 0.00 -0.08 31-JAN-02 MWD 9465.96 91.60 151.77 95.17 7250.89 4038.13 -3126.66 -2605.55 0.53 -0.06 -0.53 31-JAN-O2 MWD 9559.65 91.84 151.40 93.69 7248.07 4061.75 -3209.03 -2560.99 0.47 0.26 ~.39 31-JAN-O2 MWD 9657.15 90.80 151.04 97.50 7245.83 4085.72 -3294.46 -2514.06 1.13 -1.07 -0.37 31-JAN-02 MWD 9752.06 91.11 151.38 94.91 7244.25 4109.05 -3377.62 -2468.36 0.48 0.33 0.36 31-JAN-02 MWD 9847.01 89.51 150.17 94.95 7243.73 4131.69 -3460.48 -2422.00 2.11 -1.69 -1.27 01-FEB-O2 MWD 9941.80 88.03 149.82 94.79 7245.77 4153.03 -3542.55 -2374.61 1.60 -1.56 -0.37 01-FEB-02 MWD 10038.39 88.28 151.16 96.59 7248.88 4175.58 -3626.56 -2327.06 1.41 0.26 1.39 01-FEB-O2 MWD 10133.16 88.34 151.10 94.77 7251.67 4198.74 -3709.52 -2281.32 0.09 0.06 -0.06 ~, - 01-FEB-O2 MWD 10230.21 88.95 151.82 97.05 7253.97 4223.00 -3794.75 -2234.97 0.97 0.63 0.74 01-FEB-02 MWD 10325.96 90.68 151.00 95.75 7254.28 4246.86 -3878.82 -2189.15 2.00 1.81 -0.86 01-FEB-02 MWD 10421.55 91.11 150.79 95.59 7252.78 4269.85 -3962.33 -2142.66 0.50 0.45 -0.22 01-FEB-O2 MWD 10517.44 90.12 151.92 95.89 7251.75 4293.65 -4046.48 -2096.70 1.57 -1.03 1.18 01-FEB-02 MWD 10613.24 90.06 151.42 95.80 7251.60 4317.94 -4130.80 -2051.23 0.53 -0.06 -0.52 01-FEB-02 MWD 10706.34 89.08 151.32 93.10 7252.30 4341.08 -4212.51 -2006.63 1.06 -1.05 -0.11 01-FEB-O2 MWD 10803.62 88.83 151.34 97.28 7254.08 4365.19 -4297.85 -1959.96 0.26 -0.26 0.02 01-FEB-02 MWD 10898.84 88.77 151.45 95.22 7256.07 4388.89 -4381.43 -1914.38 0.13 -0.06 0.12 01-FEB-02 MWD 10994.22 88.64 151.05 95.38 7258.23 4412.39 -4465.03 -1868.52 0.44 -0.14 -0.42 01-FEB-O2 MWD 11090.01 88.71 151.32 95.79 7260.44 4435.89 -4548.94 -1822.36 0.29 0.07 0.28 02-FEB-O2 MWD 11185.83 88.71 150.97 95.82 7262.60 4459.33 -4632.84 -1776.13 0.37 0.00 -0.37 ~ , NTEQ. Target TVD Target Description Target Direction 8' - ~--~ SURY-EY CALCULATION AND FIELD WORKSHEET Job No. 0450-00119 Company PHILLIPS ALASKA, INC. Well Name & No. PAD CD#2/49 Survey Survey Date I Tool Depth Type (FT) 02-FEB-O2 1 MWD 11281.23 02-FEB-02 02-FEB-O2 02-FEB-02 02-FEB-02 02-FEB-02 02-FEB-02 02-FEB-02 MWD MWD MWD MWD 11376.85 11471.32 11567.~5 11662.23 MWD 11758.13 MWD 11817.60 MWD I 11874.00 (FT) (DO) Incl. Angle (DO) 90.25 90.31 90.18 90.06 89.88 90.00 89.94 89.94 Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Survey Section Name CD2-49 MWD WELL DATA Target Coord. N/S Slot Coord. N/S Target Coord. E/W Slot Coord. E/W Build\Walk\DL per: 1 OOft~ 3OmD 1OmD Vert. Sec. Azim. Hole Direction ~ 151.21 151.35 150.27 150.66 151.49 151.34 150.92 150.92 Course Length ~ 95.40 95.62 94.47 96.03 94.88 95.90 59.47 56.40 TVD (FT) 7263.46 7263.00 7262.59 7262.39 7262.44 7262.54 7262.57 7262.63 SURVEY DATA Vertical Section 4482.59 4506.21 4528.79 4551.18 4574.29 4598.19 4612.73 4626.32 -2053.00 -1502.79 226.98 Total Coordinate N(+) I S(-) (FT) -4716.35 -4800 . 20 -4882.67 -4966.23 -5049.27 -5133.48 -5185.56 -5234.85, E(+) I W(-) (FT) -1730.02 -1684.07 -1638.00 -1590.66 -1544.77 -1498.88 -1470.17 -1442.76 - Grid Correction Magn. Declination Magn. to Map Corr. Build Rate DL Build (+) (per 100 FT) Drop (-) 1.63 1.61 0.16 1.15 0.42 0.90 0.20 0.71 0.00 - 0.06 -0.14 -0.12 -0.19 0.13 -0.10 0.00 0.000 25.160 25.160 Walk Rate Right(+) Left (-) 0.25 0.15 - Sidetrack No. Field ALPINE FIELD BHI Rep. NEWLON I FUHRER .' - Page ~ of 7 Depths Measured From: RKB ~ MSLD SSD Calculation Method MINIMUM CURVATURE Map North to: OTHER Comment -1.14 0.41 0.87 -0.16 -0.71 0.001 Projected Data - NO SURVEY ~ -1 --"'- :(' Ie :( -~/'!"'\'-t.}:';;~..':."..C,¥':".'.q'...". . ~.,.".~...,.,.....',..,...,.I,....''.',<.. "..,..,.r".'. , .. .... ,.1... "... . .., " '".. 12-Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-49 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD 'MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED FEB 2 0 2002 Attachment(s) Alaska Oil & Gas Cons. eommissiort Anchorage . . - .. -- çr- ~ ~ ........ Ç}. 'Ð '. D EFI N ITIVE -- Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-49 CD2-49 Gyro Job No. AKFO22014, Surveyed: 18 January, 2002 SUR V E Y R EPO R T 12 February, 2002 ------- Your Ref: 501032040100 Surface Coordinates: 5974303.80 N, 371732.05 E (70020' 16.9084" N, 151002'26.8682" W) Surface Coordinates relative to Project H Reference: 974303.80 N, 128267.95 W (Grid) Surface Coordinates relative to Structure: 138.84 S, 16.94 E (True) Kelly Bushing: 52. 70ft above Mean Sea Level 5pE!""~Y-SU" DRILLING SERVICES A Halliburton Company Survey Ref: svy9838 G ..~ Kuparuk River Unit Measured Depth Incl. Azlm. (ft) 0.00 0.000 0.000 114.00 0.000 0.000 172.00 0.350 204.000 Sub-Sea Depth (ft) Vertical Depth (ft) Sperry-Sun Drilling Services Survey Report for CD2-49 Gyro Your Ref: 501032040100 Job No. AKFO22014, Surveyed: 18 January, 2002 Local Coordinates Northlngs Eastlngs (ft) (ft) O.OON O.OON 0.16S 0.00 E O.OOE 0.07W -52.70 61.30 119.30 0.00 114.00 172.00 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. c~- Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.149° (18-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 151.860° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 172.000., The Bottom Hole Displacement is 0.18ft, in the Direction of 204.000° (True). Survey toof program for CD2-49 Gyro From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 ~~~ 12 February, 2002 - 14:02 172.00 172.00 Survey Tool Description Tolerable Gyro Global Coordinates Northlngs Eastlngs (ft) (ft) 5974303.80 N 5974303.80 N 5974303.64 N 371732.05 E 371732.05 E 371731.98 E Page 2 of 2 Dogleg Rate (0/100ft) 0.000 0.603 Vertical Section 0.00 0.00 0.11 . North Slope, Alaska Alpine CD-2 Comment Tolerable Gyro Dril/Quest 2.00.09.008 f AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ( 12-Feb-02 DEFINITIVE Re: Distribution of Survey Data for Well CD2-49 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 172.00' MD Window / Kickoff Survey , MD Projected Survey: 11,874.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED FEB 2 0 2002 AI8Ika Oil & Gas Cons. Commi88i0n Anchorage d , ..,.',O,.",.,)~..."~~).~i\~'" ;:. , ,l, -, t::::JI-" ~ " ~ -~ .~ \ .~ Q '1} DEFINITIVE y~ Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-49 CD2-49 Job No. AKMW22014, Surveyed: 18 January, 2002 SURVEY REPORT 12 February, 2002 '.~ Your Ref: 501032040100 Surface Coordinates: 5974303.80 N, 371732.05 E (70020' 16.9084" N, 151002'26.8682" W) Surface Coordinates relative to Project H Reference: 974303.80 N, 128267.95 W (Grid) Surface Coordinates relative to Structure: 138.84 S, 16.94 E (True) Kelly Bushing: 52.700 above Mean Sea Level spe ...... ...... y - 5 U., DRILLING SERVices A Halliburton Company Survey Ref: svy9839 Sperry-Sun Drilling Services . Survey Report for CD2-49 Your Ref: 501032040100 Job No. AKMW22014, Surveyed: 18 January, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 172.00 0.350 204.000 119.30 172.00 0.165 0.07W 5974303.64 N 371731.98 E 0.11 Tie On Point MWD Magnetic 210.99 0.480 191.740 158.29 210.99 0.43 5 0.15W 5974303.37 N 371731.89 E 0.402 0.31 303.87 2.090 221.790 251.14 303.84 2.075 1.36W 5974301.75 N 371730.65 E 1.821 1.19 394.47 2.850 226.810 341.66 394.36 4.855 4.10W 5974299.02 N 371727.86 E 0.871 2.34 - 485.40 4.190 233.320 432.41 485.11 8.385 8.42W 5974295.57 N 371723.49 E 1.535 3.42 574.83 5.240 237.370 521.54 574.24 12.53 S 14.48 W 5974291.52 N 371717.36 E 1.231 4.22 664.79 5.550 233.460 611.10 663.80 17.34 S 21.43 W 5974286.83 N 371710.33 E 0.534 5.18 754.12 4.640 235.970 700.08 752.78 21.93 S 27.90 W 5974282.35 N 371703.78 E 1.049 6.18 842.84 4.300 245.060 788.53 841.23 25.34 5 33.89 W 5974279.04 N 371697.73 E 0.884 6.37 933.20 3.390 251 . 120 878.69 931.39 27.64 S 39.49 W 5974276.84 N 371692.10 E 1.102 5.75 1028.11 1.940 265.140 973.49 1026.19 28.68 5 43.74 W 5974275.87 N 371687.82 E 1.664 4.66 1123.28 1.960 257.430 1068.61 1121.31 29.175 46.94 W 5974275.44 N 371684.62 E 0.276 3.59 1218.32 3.470 250.690 1163.54 1216.24 30.48 S 51.24 W 5974274.21 N 371680.30 E 1.621 2.71 1313.10 5.440 247.160 1258.03 1310.73 33.17 5 58.09 W 5974271.63 N 371673.41 E 2.098 1.85 1408.94 8.720 243.640 1353.12 1405.82 38.16 5 68.78 W 5974266.82 N 371662.62 E 3.451 1.21 1503.56 12.480 243.650 1446.11 1498.81 45.88 5 84.38 W 5974259.37 N 371646.90 E 3.974 0.67 1598.99 14.860 244.570 1538.83 1591.53 55.725 104.67 W 5974249.88 N 371626.44 E 2.504 -0.24 1692.92 18.210 244.950 1628.87 1681.57 67.11 5 128.85 W 5974238.91 N 371602.07 E 3.568 -1.60 1788.66 22.040 243.580 1718.74 1771.44 81.44 5 158.50 W 5974225.08 N 371572.18 E 4.030 -2.94 1883.63 25.960 243.040 1805.49 1858.19 98.80 S 193.00 W 5974208.32 N 371537.39 E 4.134 -3.91 '-- 1979.07 29.440 244.530 1889.98 1942.68 118.365 232.81 W 5974189.44 N 371497.25 E 3.718 -5.43 2074.46 32.490 245.290 1971.76 2024.46 139.165 277.26 W 5974169.41 N 371452.45 E 3.224 -8.05 2170.27 32.790 241 .460 2052.45 2105.15 162.31 5 323.43 W 5974147.05 N 371405.89 E 2.178 -9.41 2265.03 32.630 240.980 2132.18 2184.88 186.96 5 368.31 W 5974123.16 N 371360.59 E 0.322 -8.84 2360.47 32.410 241.070 2212.66 2265.36 211.825 413.20 W 5974099.08 N 371315.29 E 0.236 -8.09 2444.84 32.140 241.630 2283.99 2336.69 233.42 S 452.73 W 5974078.16 N 371275.39 E 0.478 -7.69 2536.45 31.670 240.980 2361.76 2414.46 256.67 5 495.20 W 5974055.64 N 371232.53 E 0.635 -7.22 2631 .89 31 .620 24å.870 2443.01 2495.71 281.00 S 538.97 W 5974032.06 N 371188.36 E 0.080 -6.41 2727.52 31.400 239.430 2524.54 2577.24 305.87 S 582.31 W 5974007.93 N 371144.59 E 0.820 -4.92 2823.40 31.350 239.520 2606.40 2659.10 331.23 S 625.31 W 5973983.32 N 371101.16 E 0.071 -2.84 -_c- 12 February, 2002 - 14:05 Page 2 of 7 DrillQuest 2.00.09.008 Sperry-Sun Drilling Services . Survey Report for CD2-49 Your Ref: 501032040100 Job No. AKMW22014 Surveyed: 18 January, 2002 ", North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 2919.36 31 .360 238.550 2688.35 2741.05 356.928 668.13 W 5973958.36 N 371057.91 E 0.526 -0.38 3012.81 31.410 237.550 2768.13 2820.83 382.67 8 709.42 W 5973933.32 N 371016.19 E 0.560 2.85 3111.54 31.500 238.110 2852.35 2905.05 410.10 S 753.03 W 5973906.64 N 370972.11 E 0.310 6.47 3207.41 32. 11 0 240.140 2933.83 2986.53 436.02 S 796.40 W 5973881.47 N 370928.31 E 1.285 8.88 3302.35 32.000 240.480 3014.29 3066.99 460.98 S 840.17 W 5973857.26 N 370884.12 E 0.223 10.24 ~ 3398.02 31.840 240.820 3095.49 3148.19 485.778 884.26 W 5973833.23 N 370839.61 E 0.252 11.31 3493.48 31 .770 240.450 3176.62 3229.32 510.448 928.11 W 5973809.31 N 370795.35 E 0.217 12.38 3589.07 31.810 239.960 3257.87 3310.57 535.46 8 971.81 W 5973785.04 N 370751 .23 E 0.273 13.84 3684.60 32.800 241.480 3338.61 3391.31 560.42 S 1016.34 W 5973760.85 N 370706.27 E 1.340 14.85 3779.85 32.760 242.010 3418.70 3471.40 584.83 8 1061.76 W 5973737.21 N 370660.44 E 0.304 14.95 3875.38 32.820 240.910 3499.01 3551.71 609.55 S 1107.21 W 5973713.28 N 370614.58 E 0.627 15.31 3970.77 32.800 242.080 3579.18 3631.88 634.22 S 1152.63 W 5973689.39 N 370568.74 E 0.665 15.64 4066.27 32.820 241 .180 3659.45 3712.15 658.81 S 1198.16 W 5973665.59 N 370522.80 E 0.511 15.85 4161.54 32.960 241.550 3739.44 3792.14 683.60 8 1243.57 W 5973641 .57 N 370476.97 E 0.257 16.29 4256.82 33.000 240.850 3819.37 3872.07 708.58 8 1289.02 W 5973617.37 N 370431.10 E 0.402 16.89 4351.28 33.260 240.060 3898.48 3951.18 734.04 S 1333.93 W 5973592.68 N 370385.76 E 0.534 18.16 4447.16 33.360 240.330 3978.60 4031.30 760.21 S 1379.62 W 5973567.30 N 370339.63 E 0.187 19.69 4542.40 33.350 240.000 4058.16 4110.86 786.27 S 1425.04 W 5973542.03 N 370293.77 E 0.191 21.24 4637.63 33.360 239.520 4137.70 4190.40 812.63 S 1470.28 W 5973516.43 N 370248.09 E 0.277 23.16 4732.83 33.380 237.950 4217.21 4269.91 839.81 S 1515.03 W 5973490.03 N 370202.87 E 0.907 26.01 4826.98 33.570 238.030 4295.74 4348.44 867.348 1559.07 W 5973463.26 N 370158.37 E 0.207 29.52 4925.15 33.580 237.400 4377.53 4430.23 896.33 S 1604.97 W 5973435.05 N 370111.99 E 0.355 33.44 -- 5019.90 33.660 240.030 4456.44 4509.14 923.57 8 1649.79 W 5973408.58 N 370066.70 E 1.539 36.32 5115.16 33.370 240.140 4535.86 4588.56 949.80 8 1695.38 W 5973383.14 N 370020.67 E 0.311 37.95 5210.17 33.610 241.610 4615.10 4667.80 975.32 8 1741.17W 5973358.41 N 369974.45 E 0.890 38.84 5305.15 33.790 241.360 4694.12 4746.82 1000.478 1787.48 W 5973334.05 N 369927.72 E 0.239 39.19 5402.26 33.660 241 .460 4774.88 4827.58 1026.27 8 1834.82 W 5973309.06 N 369879.94 E 0.146 39.61 5496.93 33.900 240.820 4853.57 4906.27 1051.688 1880.92 W 5973284.45 N 369833.41 E 0.453 40.28 5592.03 34.020 239.910 4932.45 4985.15 1077.95 8 1927.10 W 5973258.97 N 369786.80 E 0.549 41.66 5687.23 33.080 241.730 5011.79 5064.49 1103.618 1973.02 W 5973234.10 N 369740.44 E 1 .446 42.63 12 February, 2002 - 14:05 Page 3 of 7 DrillQuest 2.00.09. 008 Sperry-Sun Drilling Services . Survey Report for CD2-49 Your Ref: 501032040100 Job No. AKMW22014, Surveyed: 18 January, 2002 '- North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C/100ft) 5782.16 33.070 241 .820 5091.34 5144.04 1128.11 5 2018.67 W 5973210.39 N 369694.38 E 0.053 42.70 5878.90 33.190 245.600 5172.36 5225.06 1151.515 2066.05 W 5973187.79 N 369646.60 E 2.139 41.00 5974.87 32.900 245.040 5252.81 5305.51 1173.365 2113.60 W 5973166.76 N 369598.68 E 0.439 37.84 6070.05 32.730 245.140 5332.80 5385.50 1195.09 5 2160.39 W 5973145.84 N 369551.54 E 0.187 34.93 6166.18 32.430 243.650 5413.80 5466.50 1217.465 2207.06 W 5973124.27 N 369504.48 E 0.891 32.64 ~"- 6261.72 31 .720 244.570 5494.76 5547.46 1239.61 S 2252.70 W 5973102.90 N 369458.47 E 0.902 30.65 6357.26 31 .740 243.550 5576.02 5628.72 1261.59 S 2297.89 W 5973081.70 N 369412.92 E 0.562 28.72 6452.81 32.200 243.480 5657.08 5709.78 1284.155 2343.17 W 5973059.92 N 369367.26 E 0.483 27.26 6547.72 32.190 242.400 5737.39 5790.09 1307.16 S 2388.20 W 5973037.69 N 369321.84 E 0.606 26.31 6643.39 32.100 242.610 5818.40 5871.10 1330.66 S 2433.35 W 5973014.96 N 369276.29 E 0.150 25.73 6738.74 31.860 242.680 5899.28 5951.98 1353.865 2478.20 W 5972992.53 N 369231.05 E 0.255 25.04 6834.38 31.500 242.660 5980.67 6033.37 1376.92 5 2522.83 W 5972970.23 N 369186.04 E 0.377 24.33 6929.73 31 . 160 242.090 6062.11 6114.81 1399.91 5 2566.75 W 5972948.00 N 369141.73 E 0.473 23.89 7024.72 32.420 241.340 6142.85 6195.55 1423.635 2610.81 W 5972925.04 N 369097.27 E 1.390 24.02 7120.71 35.750 236.080 6222.36 6275.06 1451.635 2656.68 W 5972897.83 N 369050.92 E 4.630 27.08 7215.91 37.210 232.140 6298.91 6351.61 1484.82 5 2702.50 W 5972865.42 N 369004.55 E 2.899 34.74 7312.88 38.010 230.830 6375.73 6428.43 1521.685 2748.80 W 5972829.37 N 368957.63 E 1.166 45.40 7408.10 37.990 229.990 6450.77 6503.4 7 1559.045 2793.97 W 5972792.79 N 368911.82 E 0.544 57.04 7504.03 38.150 229.980 6526.29 6578.99 1597.07 5 2839.28 W 5972755.53 N 368865.87 E 0.167 69.21 7595.12 38.770 229.820 6597.62 6650.32 1633.56 5 2882.61 W 5972719.78 N 368821.92 E 0.689 80.95 7695.55 39.770 226.120 6675.38 6728.08 1676.125 2929.80 W 5972678.04 N 368774.01 E 2.535 96.23 -.~ 7721.12 40.400 223.430 6694.94 6747.64 1687.81 5 2941.39 W 5972666.55 N 368762.22 E 7.208 101.07 7755.37 40.890 219.660 6720.93 6773.63 1704.50 5 2956.18 W 5972650.11 N 368747.15 E 7.310 108.81 7785.77 41 .730 215.250 6743.77 6796.47 1720.43 5 2968.37 W 5972634.40 N 368734.69 E 9.965 117.11 7819.02 41.990 212.690 6768.54 6821.24 1738.83 5 2980.76 W 5972616.21 N 368721.98 E 5.197 127.48 7850.60 42.130 210.600 6791.98 6844.68 1756.845 2991.86 W 5972598.40 N 368710.57 E 4.455 138.13 7881.31 42.490 208.360 6814.70 6867.40 1774.83 S 3002.03 W 5972580.58 N 368700.10 E 5.048 149.20 7914.00 43.130 205.850 6838.68 6891.38 1794.60 S 3012.15 W 5972560.98 N 368689.64 E 5.573 161.87 7945.47 43.520 203.370 6861.57 6914.27 1814.235 3021.14 W 5972541.51 N 368680.32 E 5.547 174.93 7976.56 43.990 199.940 6884.03 6936.73 1834.21 5 3029.07 W 5972521.67 N 368672.05 E 7.777 188.81 12 February, 2002 - 14:05 Page 4 of 7 DrillQuest 2.00.09.008 "'-;':¡" <~¥.~', .. .' Sperry-Sun Drilling Serviceš~"'" Survey Report for CD2-49 Your Ref: 501032040100 Job No. AKMW22014, Surveyed: 18 January, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/10Oft) 8010.28 44.520 196.800 6908.19 6960.89 1856.54 S 3036.48 W 5972499.47 N 368664.26 E 6.685 205.01 8042.33 46.130 194.630 6930.72 6983.42 1878.48 S 3042.65 W 5972477.64 N 368657.72 E 6.958 221.44 8073.15 47.070 191.190 6951.90 7004.60 1900.30 S 3047.64 W 5972455.91 N 368652.35 E 8.663 238.33 8105.76 48.650 187.290 6973.79 7026.49 1924.16 S 3051.51 W 5972432.12 N 368648.07 E 10.104 257.54 8137.48 50.080 184.900 6994.44 7047.14 1948.09 S 3054.06 W 5972408.24 N 368645.11 E 7.281 277.44 "- 8168.40 51 .1 20 180.520 7014.08 7066.78 -1971.95 S 3055.19 W 5972384.40 N 368643.58 E 11.450 297.95 8201.12 52.330 175.570 7034.35 7087.05 1997.60 S 3054.30 W 5972358.74 N 368644.03 E 12.437 320.99 8233.26 54.290 172.850 7053.56 7106.26 2023.24 S 3051.69 W 5972333.06 N 368646.19 E 9.123 344.82 8263.07 55.720 170.310 7070.65 7123.35 2047.39 S 3048.11 W 5972308.85 N 368649.36 E 8.469 367.81 8296.52 56.750 167.660 7089.25 7141.95 2074.68 S 3042.80 W 5972281.47 N 368654.21 E 7.270 394.38 8328.39 58.890 166.330 7106.22 7158.92 2100.96 S 3036.72 W 5972255.09 N 368659.83 E 7.587 420.42 8358.07 60.770 165.890 7121.13 7173.83 2125.87 S 3030.56 W 5972230.08 N 368665.57 E 6.463 445.29 8391.74 64.290 167.240 7136.66 7189.36 2154.92 S 3023.63 W 5972200.92 N 368672.00 E 11.043 474.18 8423.62 67.090 168.260 7149.79 7202.49 2183.31 S 3017.47 W 5972172.43 N 368677.68 E 9.254 502.11 8454.65 70.560 168.250 7160.99 7213.69 2211.63 S 3011.58 W 5972144.01 N 368683.08 E 11.183 529.87 8486.32 73.860 168.040 7170.67 7223.37 2241.14 S 3005.38 W 5972114.40 N 368688. 77 E 10.439 558.81 8518.83 77.250 168.280 7178.78 7231.48 2271.95 S 2998.93 W 5972083.48 N 368694.70 E 10.452 589.02 8550.44 79.820 167.410 7185.06 7237.76 2302.23 S 2992.40 W 5972053.09 N 368700.70 E 8.566 618.80 8582.32 81.980 167.470 7190.10 7242.80 2332.95 S 2985.56 W 5972022.26 N 368707.02 E 6.778 649.12 8614.53 84.070 165.120 7194.01 7246.71 2364.01 S 2977.98 W 5971991.07 N 368714.06 E 9.723 680.08 8644.88 85.640 164.330 7196.74 7249.44 2393.17 S 2970.02 W 5971961.78 N 368721.53 E 5.786 709.55 8678.19 87.090 162.350 7198.85 7251.55 2425.01 S 2960.49 W 5971929.78 N 368730.51 E 7.358 742.12 '-- 2455.26 S 2950.78 W 5971899.38 N 8709.98 88.010 162.060 7200.21 7252.91 368739.70 E 3.034 773.37 8741.23 88.590 159.650 7201.13 7253.83 2484.76 S 2940.54 W 5971869.70 N 368749.44 E 7.929 804.22 8773.02 88.550 157.880 7201.93 7254.63 2514.38 S 2929.03 W 5971839.89 N 368760.44 E 5.567 835.77 8804.71 88.550 156.380 7202.73 7255.43 2543.57 S 2916.72 W 5971810.49 N 368772.25 E 4.732 867.31 8836.80 87.830 153.940 7203.74 7256.44 2572.68 S 2903.25 W 5971781.16 N 368785.22 E 7.924 899.33 8927.37 89.630 150.730 7205.75 7258.45 2652.86 S 2861.21 W 5971700.27 N 368825.88 E 4.063 989.86 8988.12 89.450 150.320 7206.24 7258.94 2705.74 S 2831.32 W 5971646.88 N 368854.86 E 0.737 1050.59 9083.75 89.450 151.000 7207.16 7259.86 2789.10 S 2784.46 W 5971562.74 N 368900.28 E 0.711 1146.19 12 February, 2002 - 14:05 Page 5 of 7 Dril/Ouest 2.00.09.008 Sperry-Sun Drilling Services . Survey Report for CD2-49 Your Ref: 501032040100 Job No. AKMW22014, Surveyed: 18 January, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9179.43 91.540 152.280 7206.33 7259.03 2873.29 S 2739.02 W 5971477.78 N 368944.28 E 2.561 1241.86 9275.25 91.660 152.350 7203.65 7256.35 2958.11 S 2694.52 W 5971392.22 N 368987.33 E 0.145 1337.64 9370.79 91.660 152.270 7200.89 7253.59 3042.67 S 2650.14 W . 5971306.91 N 369030.25 E 0.084 1433.14 9465.96 91.600 151.770 7198.18 7250.88 3126.68 S 2605.51 W 5971222.15 N 369073.44 E 0.529 1528.27 9559.65 91.840 151 .400 7195.37 7248.07 3209.05 S 2560.95 W 5971139.03 N 369116.59 E 0.471 1621.92 '-- 9657.15 90.800 151.040 7193.12 7245.82 3294.48 S 2514.02 W 5971052.81 N 369162.05 E 1.129 1719.38 9752.06 91.110 151.380 7191.54 7244.24 3377.64 S 2468.32 W 5970968.87 N 369206.32 E 0.485 1814.27 9847.01 89.510 150.170 7191.03 7243.73 3460.50 S 2421.96 W 5970885.23 N 369251.25 E 2.113 1909.20 9941.80 88.030 149.820 7193.06 7245.76 3542.57 S 2374.57 W 5970802.37 N 369297.23 E 1.604 2003.92 10038.39 88.280 151.160 7196.17 7248.87 3626.58 S 2327.02 W 5970717.55 N 369343.34 E 1.411 2100.43 10133.16 88.340 151.100 7198.97 7251.67 3709.54 S 2281.28 W 5970633.83 N 369387.65 E 0.090 2195.15 10230.21 88.950 151.820 7201.26 7253.96 3794.77 S 2234.93 W 5970547.82 N 369432.54 E 0.972 2292.17 10325.96 90. 6AG 151.000 7201.57 7254.27 3878.84 S 2189.11 W 5970462.97 N 369476.91 E 1.999 2387.91 10421.55 91.110 150.790 7200.08 7252.78 3962.35 S 2142.62 W 5970378.68 N 369521.97 E 0.501 2483.47 10517.44 90.120 151.920 7199.05 7251.75 4046.50 S 2096.66 W 5970293.76 N 369566.48 E 1.567 2579.35 10613.24 90.060 151 .420 7198.90 7251.60 4130.82 S 2051.19 W 5970208.67 N 369610.50 E 0.526 2675.15 10706.34 89.080 151.320 7199.60 7252.30 4212.53 S 2006.59 W 5970126.21 N 369653.70 E 1.058 2768.24 10803.62 88.830 151.340 7201.37 7254.07 4297.87 S 1959.92 W 5970040.08 N 369698.90 E 0.258 2865.50 10898.84 88.770 151.450 7203.36 7256.06 4381.45 S 1914.34 W 5969955.73 N 369743.04 E 0.132 2960.70 10994.22 88.640 151.050 7205.52 7258.22 4465.05 S 1868.48 W 5969871.36 N 369787.47 E 0.441 3056.05 11090.01 88.710 151.320 7207.73 7260.43 4548.96 S 1822.32 W 5969786.68 N 369832.18 E 0.291 3151.81 "~.~ 11185.83 88.710 150.970 7209.89 7262.59 4632.86 S 1776.09 W 5969702.00 N 369876.97 E 0.365 3247.59 11281.23 90.250 151.210 7210.76 7263.46 4716.37 S 1729.98 W 5969617.71 N 369921.65 E 1.634 3342.98 11376.85 90.310 151.350 7210.29 7262.99 4800.22 S 1684.03 W 5969533.09 N 369966.16 E 0.159 3438.59 11471.32 90.180 150.270 7209.89 7262.59 4882.69 S 1637.96 W 5969449.84 N 370010.81 E 1.151 3533.04 11567.35 90.060 150.660 7209.68 7262.38 4966.25 S 1590.62 W 5969365.49 N 370056.71 E 0.425 3629.04 11662.23 89.880 151 .490 7209.73 7262.43 5049.29 S 1544.73 W 5969281.67 N 370101.18 E 0.895 3723.92 11758.13 90.000 151.340 7209.83 7262.53 5133.50 S 1498.84 W 5969196.69 N 370145.61 E 0.200 3819.81 11817.60 89.940 150.920 7209.87 7262.57 5185.58 S 1470.13 W 5969144.13 N 370173.43 E 0.713 3879.28 11874.00 89.940 150.920 7209.92 7262.62 5234.87 S 1442.72 W 5969094.38 N 370200.00 E 0.000 3935.67 Projected Survey 12 February, 2002 - 14:05 Page 6 of 7 DrillQuest 2.00.09.008 . ;;Sperry-Sun Drilling ServiceF Survey Report for CD2-49 Your Ref: 501032040100 Job No. AKMW22014, Surveyed: 18 January, 2002 I) Kuparuk River Unit North Slope, Alaska Alpine CD-2 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.127° (12-Feb-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 151.860° (True). "'- Based upon Minimum Curvature type calculations, at a Measured Depth of 11874.000., The Bottom Hole Displacement is 5430.03ft, in the Direction of 195.408° (True). Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) Comment 172.00 172.00 11874.00 172.00 172.00 7262.62 0.16 S 0.16 S 5234.87 S 0.07W 0.07W 1442.72 W MWD Magnetic Tie On Point Projected Survey Survey tool program for CD2-49 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description - 0.00 172.00 0.00 172.00 172.00 11874.00 172.00 7262.62 Tolerable Gyro (CD2-49 Gyro) MWD Magnetic (CD2-49) -----"'--- - 12 February, 2002 - 14:05 Page 7 of 7 DrillQuest 2.00.09.008 03/07/02 ScblUmbll'ger NO. 1885 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine ~~- Well Job# Log Description Date BL Sepia Color Prints CD '- CD2-15 ~Oj-J5q 22094 SCMT 02/23/02 1 CD2-17 aD;) -OIS 22096 SCMT 02/23/02 1 CD2-49 ~nJ-.-::JLI CJ 22095 SCMT 02/11/02 1 SIGNED~ c.!ÞfffJÅ..A- ) RECEIVED DATE: t?;!P "' 5 'Jt10? 'of';, I Lv- Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. MøeilaÐU& Gas Cons. Commission Anchorage ( MEMORANDUM ( State of Alaska Alaska Oil and Gas Conservation Commission ~ TO: Cammy O. Taylor CO' DATE: Chair t~- ç( ~~BJECT: Mechanical Integrity Tests THRU: Tom Maunder ~ dûÒ~ Operator \-~";' (..;::: Petroleum Engineer\^-CA..'\\' Pad or platform '\ \ \>;, \"\.Z- Well Name C \)- ~ FROM: Lou Grimaldi Unit Petroleum Inspector Field c..c\ ~--'~ \\.~ '\"<.i.',-..>"C' NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well CD2-15 Type Inj. S TV.D. 7008 Tubing 1228 1220 1220 1220 Interval I P.T.D. 2011590 Type test P Test psi 1752 Casing 1300 2000 1975 1950 P/F P Notes: Well CD2-17 Type Inj. S TV.D. 6968 Tubing 750 755 755 755 Interval I P.T.D. 2020150 Type test P Test psi 1742 Casing 1300 1875 1850 1825 P/F P Notes: Well CD2-26 Type Inj. S TV.D. 7003 Tubing 1620 1620 1620 1620 Interval I P.T.D. 2012490 Type test P Test psi 1751 Casing 850 1875 1875 1875 P/F P Notes: Observed. pretest condo for thirty minutes (500 psi D.P.) Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details The wells were on injection and ready to be tested when I arrived this morning. A]] wells pressured up quickly with no gas cap evident. Rick A lexander (lead operator) conducted the tests and had all peninent info on hand The three injectors all passed their initial MIT's. M.LT's performed: Three Attachments: None Number of Failures: None Total Time during tests: 3 hours cc: Dethlefs/Nezaticky œAll M IT report form 5/12/00 LG. MIT Alpine CD2-15,17,26 3-9-02 LG.xls 3/11/02 . A I D. Id . th fi t t if 2002 7\0 j -a L/G¡ nnu ar lsposa unng e lrs quar er 0 . . h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 2P-417 25534 100 0 25634 887 5431 31952 October March 2P-448, 2P-422A, Grizzly #1, 2001 2002 2P-451, 2P-441, 2P-420 CD2-14 16138 100 0 16238 376 14459 31073 November March CD2-32, CD2-47, CD2-45 2001 2002 lC-14 9626 100 0 9726 0 22489 32215 October January lR-36, lC-24, lC-109 2001 2002 CD2-15 10346 100 0 10446 371 0 10817 March March CD2-50 2002 2002 CD2-47 16459 100 0 16559 375 10415 27349 December January CD2-34, CD2-26, 2001 2002 CD2-45 22514 100 0 22614 377 0 22991 January February CD2-49, CD2-17 2002 2002 2P-415A 4843 100 0 4943 52 0 4995 March March Grizzly #1, 2P-431, 2P-441 2002 2002 CD2- 26 0 0 0 0 380 0 380 -- -- Freeze protect only for CD2- 26 CD2-49 0 0 0 0 386 0 386 Feb 2002 Feb 2002 Freeze protect only ( ]'¡tl\f¡l . t A ["fi h. hD. I A th . t. E . dd . th fi. t 2002 oa 0 urnes In 0 nnu lor W lC lsposa u orzza lon xplre urznf? e lrst quar er . . 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 ID-32 23162 100 0 337 23599 Open, Freeze Protected January February ID-39 2001 2001 IJ -03 30024 100 0 0 30124 Open, Freeze Protected March 2001 May 2001 11-09, 11-14, 11-10 ( ( 11 '\ PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage,AJaska 99510~60 G. L. (Chip) Alvord Alpine Drilling Team Leader Phone (907) 265-6120 Fax: (907) 265-1515 Tom Maunder Petroleum Engineer State of Alaska Alaska Oil and Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, Alaska 99501 Subject: Annular Disposal Permit for Alpine CD2-49 Tom, I've enclosed several documents to help with the permitting process for annular disposal on Alpine well CD2-49. Both the mud report and the cementing report dated January 22, 2002 for CD2-49 document the amount of cement returns (95 to 100bbls) observed on the surface casing cement job for this well. The lack of this detail on the PAl drilling and cement report was an oversight. This omission and it's importance has been discussed with the PAl drilling supervisor that prepared the documents. We also re-ran the 7" x 9-5/8" annular injection test on CD2-49 and have attached the resulting LOT form and graph for your review. Please call if you have additional questions or concerns. / ., ~ / A, (J /'~"L- ~ Regards, Chip Alvord Attachments: CD2-49 M&IDF Mud Report 1/22/2002 CD2-49 Dowell Schlumberger Cementing Service Report 1/22/2002 CD2-49 Leak-off Test Form for Formation Adequacy Test 2/22/2002 RECEIVE FEe 2 8 .- 4l .' \' 2 D 1].:; ) askaOil&G . '" as Cons C . AnChorage ommlSSion CD2-49 2/22/2002 Date: for test: Size and Hole EMW Mud Weight: Pump output = OJ)997 bps 1,300 pSI 1,200 pSI 1,100 psi 1,000 psi p";--, 000 psi W II: ::::> 700 psi (f æ 600 psi II: Q. 400 pSI 100 pSI Op" () STROKES TO MINUTES DURING "SHUT BTMC Length of Hole 6.9 ppg """'LEAK-OFF TEST ~CASING TEST SHUT IN TIME ~CASING TEST SHUT IN TIME LINE 12 time line above p MINUTES FOR LOT MiNUTES FOR eSG TEST 18 NOTE: TO CLEAR HIGHLIGHT AND PRESS PRESSURE SHUT IN PRESSURE DELETE KEY Feb-25-02 12:40 From-DOYON 19 HALL ( 907-670-430' f T-543 P.02/05 F-589 .FE ~I_.-.g WATER..BASED MUD REPORT No.3 - 25õõft I 2363 ft Operator: Phillips AI;u¡ka. Ine. FJeldlArva : Alpine/Colville Rìver DopthlTVD : Repon For: Dave Burtey Do5cr1ptlon: Sec. 2, T11N, R4E UM Date : 1/22/2002 wen N¡ame: CD2-49 Location: North Slope Spud Date : 1/21/2002 Contractor. Doyon Rig 19 Mud Type: Spud Rø It Far: Jim paul M-I Well: CO2-49 Activity : W.O.C. .. BOP test. WN"'- A-=O:EM .Y C G -MUD VOL E fbþl\ (:IRCUL :nON DAT-' ft, -in DP 1&.in @114 ft (114 TVD) Hole Puma Make EMSCO FQ-1 SOD eM$CO ¡:s., IlOO ft. -In 9.625-in @2494 ft (23771VO) 189.6 Pumø Uner )C sue 6x12in 6x12 In It. -In ACtIve Pit5 Pu ß1D stk 4.186 4.186 ft,"¡n 290.4 PtJmD 6Iklmln 0@95% D/m95% ft. -in Totat Circulating Volume Flow Rate aaumln ft.-In 290.4 Pumo PteSSLII'e MI NœzIes 32x1 1/32" In Storage Weight Bottoms Uø Bit 8.921-in Float ShoB Total Circulation MUD PROPSJ TIES PRODUGT8 uSED Last Z4 hf SamDie Fmm Pit 21 :00 PIt 15;00 Pit 6:30 PIt 3:10 Producta Size Amount FlowUne Tem.:. "F 57 N/A 73 71 BielAN 50LBBG 2 D&øtttITVP ft 250012383 250012383 2500/2383 239312293 DecWT 55GADM 3 Mud WeiClht /T'erne Ibloal 9.6@57 9.6Cð:169 9.6a71 9.81i'j)71 CEFOAM X 5GACN 7 Funn~ Vi8CO9Ïtv slat 59 150 145 210 DJ:SCO CF 25 la BG 30 RhEiClIMV Temø DF 120 120 120 120 ~NGINEERING SERVICI= 1 J;.A 2 R8001R300 42/29 70152 69/50 87/68 GELEX 8~r EXTI:NPER 2 La BG 2 R200IR1 00 21/14 43/34 41/32 55145 M~I Ga EXPORT 100 LB 8G 20 Ra/AS 5/4 25122 24/21 34/33 PECAN NUT PLUG MED 50LBBG 4 PV çp 13 18 19 19 SAPP 50 LB BG 30 VP Ibl100fP 16 34 31 49 SODIUM BICARBONA11= 50 La ßG 30 1 OS/1 Om/30m Gel Ib/100ft1' 7120/31 28155178 27/60166 43/52155 API Fluitt Loss cCl30min 10.2 12.0 12.4 12.8 HTHP Fluid '-OtiS CCl30min N/CaN/A N/CtBIN/A N/C7i'1iNlA N/CIBfNlA cake APT/HT 1/32" 2/N/A 3/N/A 3IN/A SIN/A Solids O/OVol 7.5 7.5 7.6 7.5 OiJJWater %Vol /93 193 193 193 SOliDS CONTROL eQUIPMeNT 8Gt 24 hr Sand %Vol 0.25 .25 .25 0.25 Type 'ModallSlze HrfIi UMd MBT Ib/aal 25 SO 27.5 27.15 Derrick Shaker 1 2101210/175/1 18 oH I Terno 8.8@57 8.6~70 8.6@70 9.f,W)71 P&l'l'lek Shaleel' 2 175/175/17511 16 Alkal M~ (Pm\ 0.05 .05 .05 0.11 DerricK Stlaker 3 175/175/175/1 18 PfJMf .021.32 .01/.40 .01/.30 .041.25 Mud Cleaner 2501250/250 7 ChloridBti Moll 1200 1800 1600 1800 Centl'ifuae Hardn&&s ICa++) 0 40 40 40 C-Sander \ IUD PROPJ:RTY SP~CS Actual welaht 8.S-9.8 9.6 ViSCOSitY 140-300 59 Filtl'ate N/C 10.2 141:1 KK Allin TR T R .5 00 CWT ana Nut Plug to counter bit balling. Desco ClF and drill water to lower YP to 20 Drill from 2290' to 2500', 2383 TVO. Clrc Hv sweep ¡¡I "Id clean hole. sr Ibel10Oft^2 for CQment job. Build 220 bbl treated water for cement jOD wI SAPP, DeSCD C/F to 1560'. RIH to 2600', Pump HV $weep and clean nole. POOH. Run and Biçl;lrþ. 9111 out ~me for drillol,Jl Blozan for wash ~c:er. Send ßi(l2:an wash, ARCO and cement 9 5/8 csg per pr( gram. 9.t~~<~~..:I:\!",,'c'\;:;~;~~I"~~I:S i, ~pacer,lnterfl;lcQ and -100 þbl cement to GI~ for dj~posal. Retain 290 bbl Spud mud for drlllolJt and intermediate. ~E DISTRIBUTION L.a.t~hr* MUD ~C :':TG Ibbn' :Em ¡rANAL S 1%/IÞ RH~Y 111 n l' .n~AULICS Ria UoiServlce 2 Oil Aclded NBCI .1.6 nolna Orllllna 6 Water Added 406 KCI .I. KDlKa TrloDlnA S Mud ReceivEtd low Gl1IvitV 5.6/50.8 Bit Pressute Loss % a.c.p. NU Mud Returned Bentonite 2.41 21.8 Bit HHP/HSI Runnina casino 5 Send to GIS 787 Drill Solids 3.2/29.1 Jet Velocltv OutS C&mentlna 2 Shakers Weloht Material 1.9127.4 Va Pice Oyl6 Condition Hole 2 Evsooration ChemIcal Cone .. I . Va C( lIal's OutT Condltloo Mud 2 CentrlfucB InertJReøct 1.0331 C\la Pice Corina Formarlon Averäõe SG 3 Cva Collars Dev. SUn/BY 19ft In Hole ECO at Shoe ðther Y-I EJtlGR I PHONE WAREHOUSE PHONE DAIt.. Y COST OUMULATIVE COST Jim Cooullu 670-4318 -4308 Rob Reinhardt 670-4314 $6.049.90 $22 1'01.04 J;} ':' Feb-25-02 12 :40 F rom-DOYON It ~~LL . 90T-6TO-43~ ......... ~menting Service Repor:t ._-_~~=PS-AU>INE . ~ (1eg8I) 5ec.2. T11 N.R4E UM ~ 33 .~ ... T-543 P.O3/05 F-5a9 , I - , CØItII:¡ Alpine FonPaII an ~ C-40 . Job NmiI8r 2201036804 DcMeII LacaDon Job SWt PrudhOe Bay, AI( 2002..Jan-22 Bit SIze w.n 18) w.. lVD 12.1 in 2,500 ft 2,389 _ft ÐIt&T BHCT Pore P'rGM. GrdMt 60 DF 60 DF psUft Ca5 i I'Ig/U net' SI:Ja, In ~ IÞIft 9.83 36 Gtado ~ YieJe CO2 49 FIeld .- ~ Alaska ~VIa Land o.pat, n WoCI TJPe 2493 Devetopment II8X. 0018llly -- !PI.. VlacO8l&y . 9.6 ~ 50 ~ DiIpth, )$I ~ie Point .-~ For Injection WMI CIUIo New RIG NIme DOYON 19 OIN.... ZanG '-, J55 BTC -- ,-- DI1IIIng Auld l'yrM Spud Mud Sorke LIno Jäb Typo Cementing Cern Surface Cas(ng --. AIIOWINI Tdblng ..--,.- "1II8L AI~ Ann. PteauIv I w.Utlød CcMInoc:1ion 1000 psi psi Double cement -, ", SeINlI:9InrdNcaonB PROVIDE EQUIPMENT,MATERIALS AND PERSONEL TO CEMENT SURFACE CASING AS INSTRUCTED BY MR DA~ BURLf;V. TREATMENT #2011-0436 ALLOCATION COST $22981.00 MATERIAL COST $ 26597.88 FIELD ~STIMA TE $48558.88 '-----YUbingJDrln PIpe -~ . ~~~E PerforationslOpon Hole 'IbNDd --- .. hea Tap. I'/; QoItom, ft wpf NIII. of 9h* 1_1 _rval , ".... ft -, - " . Dlanlflter - - " .- in - - ,.. Tr8at OCMII f,II.pIacomclßt P~cketTyPO p,¡¡çJmt Depth Casing 195.7 bbl It " " .., Tubing VoL CUing VttI. ~nl.ll.. Vol. 0"11"010 Vo .- bbl 193.25 bbl 154.5 bbl bb -.' . -, ... ... C881nBl'tablnO gewrwi 0 11to1o,VOIU1118 CIID4II1ted pno~1D C6~ng~ Casing Tools Squtem Job Lift..r...1n:" --Psi . ,., - Sh08 TYPo; Float sqlMlNO Type .-- ,. ...1-.'1.- I ~ Shoe Oopttl; . PlIM ftotared :l 2494 ft Toot Typ&: " ~ ~ "TõPf:-.UF: .I~mPlu!,:' l' Støgo,1~I"I)pe " -,. No. ClntnlUZi'lta: 1 Toot PðpÖl: ft Cement H- Type: Double SÙlgo TQQI 08plh: ft 1aliPipe 51zo; in - .. Call.. Tyl'ð= .. -, JoÞ :liSctleddIM For- AMvacI an Lacldlvn: Leave !.QI¡dM: Float l'ai' Pil'ð Copth: ft -, 2002..Jan-22 18:30 2002..Jan-22 23;00 Collar Dapth: 2407 ft Sq:¡; Tðtal Vat: bbl Date Time Danel., PtM8UIV U1 SllGk$ STAGatOL T otFltnNIIIte MØG8agð 24hr ~0Ck pp" ~I NONE bbl bpm .. ~OO2-Jan..:Q 20:51 0 0 0 0 0 0 0 START ACQUlSmON 2002-Jan--22 20:51 -0.015 32,~2 o. O. o. 0 0 2002-Jan-22 20:51 -0.015 32.32 O. O. O. 0 0 Rig pumping wasta 2002.. Jan-22 20:51 ..0-015 32.32 O. O. O. 0 0 PAUSE ACQUXSmON 2002- Jan..22 ~O:56 .0.015 32.32 O. O. O. 0 0 RESTART AF"Tl;:R PAUSE 2002- Jan-22 20:56 -O.OlS 151.4 O. O. O. 0 0 --, , ~ 2002-3an-22 20:56 .0.015 151.4 Q. o. 0, 0 0 Start Pumping Water 2002-]éln-22 20:57 -0.015 275. o. 2.49 3.55 0 0 2002-300-22 20:58 .0.015 275. O. 2.49 3.55 0 0 Pressure Test Unes 2002.. Jan-22 20:58 "0.015 87.26 O. 4.34 O. 0 0 2OO2.Jan-22 20:59 ..0.015 2459 o. 4.35 O. 0 0 2002- Jan"22 21:00 "0.015 993.9 o. 4.37 o. 0 0 .. 2002- Jan-22 21:01 ,-0.015 82.68 O. 4.38 O. 0 0 . 2002-Jan"22 21:02 -0.015 82.68 O. 4.38 O. 0 0 Drop Bottom Plug ...... 2002-3an-22 21:02 8.47 320.8 o. 4.38 O. 0 a 2002.. Jan-22 21:03 10.92 320.8 O. 438 O. 0 0 .. " -... ~-. r ..",.--..,' ---," ;, 1"~n?-:1i~~ri-'" ?J~~~ 11...,~9 971, Q. 4.4 O. 0 0 , - - -.-.....,-, .. ".... ."" , ...--".""--,-,.",-""",,"-,,,-,-.,,---~----,--,,-"'.~ -..- _.'.-'-"~r~--.---- '1 Feb-25-02 12:40 - -- .-..... ---..r- -..r"'" ~ c.õiiiiiñii; -~ =r:?- wen cO2 #49 AIpitI& D222...1a1't..22 PH IU.IPS-ALP IN E . . Date TIme CenIky ......... U1 SJtCka STAGE1/Ol TotF1cNtaI8 IhuGage 24hr NOtœ IIÞt Þpm , cIoc:k ppQ P8I - 2002-Jan-22 21:09 10.52 641.3 O. 17.76 5.72 0 0 2002-Jan-22 21:10 10.59 627.6 O. 23.5 5.72 0 0 2002- Jan-22 21:11 10.65 618.4 0- :¿9.23 S.72 0 0 2002- Jan-- 22 21:12 10.63 623. O. 34.96 5.72 0 0 2002-Jan-22 21:13 10.65 641.3 O. -to.7 5.72 0 0 2.0~-Jan-22 21:14 10.?4 600_1 O. 46.43 5.72 0 0 2002-]00- U 21:15 10.53 641.3 O. 52.17 5.72 0 0 ¡--.. r-- , , 2002-Jan-22 21:16 10.53 &11.3 O. 52.17 5.12 0 0 2002-Jan-22 21:16 10.53 611.3 o. 52.11 5:72 0 0 Reset Volume 2002-Jan-22 21:16 10.53 6413 o. 52.17 5.72 0 0 2002-Jan-22 21:16 10.53 641.3 O. 52.17 s.n 0 0 Start Mixing Lead Slurry 2002- Jan-- 22 21:16 10.51 7%.6 251 2.04 6.1 0 0 2002-Jan-22 21:17 10.98 842.8 10.2. 8.21 6.34 0 0 2002-.Jan..22 21:18 UJ.81 778.7 18.17 11.53 6.3 0 0 2002-Jan-22 21:19 1().81 719.1 26.09 20.85 6.34 0 0 2002-J~n-22 21:20 1().84 916. 34.17 27.27 6.89 0 0 2002- Jan-22 21:21 10.77 1003 43.42 34,6 7.27 0 0 2002-Jan-22 21:22 10.86 948.1 52.61 41.88 7.27 0 0 2002-Jan-22 21:23 10.83 952.6 61.82 49.18 7.27 0 0 ZOO2-Jan-Z2 21:24 1.0.84 957.2 71.01 56.46 7.27 0 0 2002..J.22 21:25 10.86 925.2 80.23 63.75 7.27 0 0 .. 200;2.- Jan-22 21:26 10.84 943.5 89.44 71.04 7.27 0 0 2002- Jan-22 21:27 10.83 916. 98.63 7832 7.27 0 0 2002- Jan-22 21:28 10.84 893.1 107.8 85.62 7.Z7 0 0 2002-Jan-22 21:29 10.83 897.7 117.1 92.92 7.3 0 0 -- . 2002-3an-22 21:30 10.84 916. 126.3 100.2 7.21 0 0 2002-Jan-22 . 21:31 10.83 957.2 135.4 107.5 7.27 0 0 - 2002-Jan-22 21:32 1.0.85 810.7 144.7 114.8 7.2'1 0 0 __0- ,- -"" .~ -,.. - . " .--.. 2002..Ji¡ln-22 21:33 10.86 801.5 153.9 122.1 7.3 0 0 2002- Jara..22 ~1:34 3.0.84 810.7 163.1 129.4 7.27 0 0 2OQ2-Jan-22 21:35 J.D.84 902.3 172.3 136.7 7.2.7 0 0 2002-Jan-n 21:36 10.84 819.9 181.5 144. 7.27 0 0 2002-Jan-~2 21:37 10.84 861.1 190.7 1S1.3 7.27 0 0 2002-Jan-22 21:38 :LO.83 870.2 199.9 158.6 7.3 0 0 2002-J~n-22 21:39 :LO.81 819.9 209.1 165.9 7.32 0 0 2002-Jan-22 21:40 10.84 888.5 218.4 113.1 7.27 0 0 2002- Jan-2J. 21:41 10.86 819.9 227.6 180.5 7.3 0 0 2002-Jan-22 21:42 10.84 856.5 236.8 187.8 7.3 0 0 .... ., ~ 2002-Jan-22 21:43 10.83 897.7 246. 195. 7.27 0 0 .. 2002-]an-Z2 21:44 10.84 920.6 255.2 202.3 7.27 0 0 2002-J~n-22 21:45 10.84 847.3 264.4 209.6 7.27 0 0 2002.. Jan-22 21:46 10.84 8'9.4 273.7 216.9 7.:3 0 0 "'- ....- .. " ~- 2002.. Jan-22 21:47 10.84 847.3 282.9 224.2 7.27 0 0 2002- Jan-22 :It:48 10.84 856.5 292.1 231.5 7.27 0 0 2002-Jan-22 21:49 10.84 874.8 301.3 238.8 7.2.7 0 0 - . 'r .. ,. 2002-3an-22 21:50 10.84 888.5 310.5 246.1 7.3 0 0 2O02-J8n-22 21:51 10.86 952.6 319.7 :l53.4 7.3 0 0 2002"'Jan-22 21:52 10.84 888.5 328.9 260.7 7.27 0 0 -::--'_0 . - -"-I--'~ -.. - .0" -." .. . " --. ¡' '7nn?l'~'1~~!", ")1,~!~~,, tQ"R~ I. ~O~,9 , ,3~~J., 26ft 7.3 0 0 ,., '" ,.,,~,o.""_-"-"'-_"'"'-~_"_._"" ",-..",.,..---..,-- -""""~'-'-'-'-'~"'~-'--'-,,~-,-- . ..... ' ", " ' : .,:. ' , From-DDYON II ~ALl 907-670-43f T-543 P.04/05 F-589 Fab-25-02 12:41 From-DOYON 1~ HALL .. -.---,- -~. -, r--- w.w . t _d '--'" CD2 IM9 A/pÌtt6 Dá;'¡¡;¡;--' Time ~ ~1- ----¡;¡;;- . , 2002-Jan-22 2002-]an.22 2002-~an-22 2002-Jan-22 200l-.Jan- 22 2002-Jan--22 2002-Jan-22 2002-J¡m.22 2002-Jan-22 2002- Jan-22 2OO2-Jan--22 2002-Jan-22 2.002..Jan-;l2 2002- ]an- 22 2002-Jiln-22 2002.. Joo-22 2002-Jän-22 2002.Jao-22 2002-Jao-22 2002-Jan~22 2002- Jan-22 2002-Jan-22 2002..Jan--22 2002-Jan~22 2002-Jan-22 2002- Jitn- 22 200Z- Jan..22 200;l-Jan-U 2002-Joo..22 2002-)1""22 2002-Jan-22 2002- Jan- 22 2002-Jan-22 2002-Jan-22 2002- Jan-23 2002-Jan-~ 24h( ~ ppg -~ 21:59 10.23 22;01 10.36 22:02 9.93 22:03 10.06 22:03 10-06 22:03 10.06 :U:O3 10.06 22:03 10.06 22:04 15-79 22:05 15.92 22:06 14.8 22:07 14.51 22:08 15.35 22:09 U..67 22:10 1S.?" 22:11 15.75 22:12 15.66 22:13 15.99 22:14 15.91 22:15 15.75 22:16 15.88 22:16 15-88 22:17 1~.aa 22:17 15.51 ~:17 15.51 22:17 15.51 22:1' 15.51 22:18 15.45 .--- 22:19 9.'16 22:~O 8.79 22:21 8.62 22:22 a.54 22:22 8.54 22:22 8.54 0:16 0:11 pel 865.7 508.5 288.7 206.3 2063 2063 206.3 206.3 380.3 343.7 439.8 371.1 490.2 467.3 476.5 412.4 503.9 531.4 439.8 430.7 503.9 503.9 503.9 119.3 119.3 119.3 1193 119.3 270.4 449. 380.3 27.74 2'1.74 27.74 NO1Æ 393.1 399.7 ~.6 407.8 407.8 107.8 "\07.8 407.8 8.33 27.54 47.37 63.24 81.65 100.S 119.7 138.6 157.9 177.3 196.8 216.2 235.6 235.6 235.6 248.2 ;!48.2 248.2 248.2 0.054 , .r- 13. 28.:l9 43.57 53.59 53.59 53.59 907-670~430J T-543 P.O5/05 F-5S9 ....... .-,- J .",..;;;;¡;¡- -( - "-./- - - ....- D2:22..Jan.:22 PHI~ 2:201 036804 STAGeIOI. T~owAt. -- - M8S88Q8 * 311.8 311.2 321-3 324.2 324.2 324.2 3:M.2 .'^ 324.:l 2.47 6.45 10.63 14.16 18.13 22..12 26.13 ~O.13 34.14 38.16 42.18 46.21 50.23 50.23 50.23 S2.9 S2.9 52.9 S2.9 0.012 3.8 9.34 15.11 18.94 18.94 18.94 Post Job SummafY ,.. . .. Aver;¡¡ge Pump Ra~es. bpm SIllIlY N2 Mua MaxImum R* ToIM Stony 7.25 -L..---. ..--L-. ].25 ..- Trø,lting Pressure Summary. psi Maimum Fln.1 A~8 Blimp Mug to ""'kdDWn -ryp., - 500 J 1 000 -L ,500 J 1 OO°----L.. . ,- Avg. N2 Pop:¡md ~~ønod Suny Vola.... ÐI*PI8.C4IIIIt.- "IJC Water "amp -~ 432 bbl 189 bbl 70 9F . cu.tonWorAuU1ariz8dR41þ_nI8\1q ... DowoIl'SupeMwo,' .' Dave, Burley. Jamas Thompson --... - - bpm 7."¿7 4.68 3.16 2.9 2.9 2..9 2.9 2.9 3.24 4.24 3.44 3.51 4.02 4.02 3.98 3.98 4.02 4.02 4.05 4.02 3.98 3.98 3.98 0- O. O. ....O. 0.069 4.51 5.13 5.18 O. O. o. 356 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 () 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 , 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Reset Volume [Sadcs]~407.8 (390 AcWa ) MDdngTaHSiuny Shutdown Drop Top Plug [SadCS];;;;248.2 (236 AC\Uï;t1 ) Reset Volume Sti1rt Pumping Wab!r ----- --' ,.,. Volume of Fluid Injeçted. bbl Mud &pqçw 1a9 L.,,~. Breakdown Fluid VoIUtnI!I M2 Denal&y bbL Ib/ga' I . ,""'.'.:' ~ .:,,'~' .:n¡)¡i.íß:!\;! ~ii\I~,'ii~.MIræ.j.'." . "",..',;JiIfiI,'f'mc",,'.. I" '""'"."""I~¡.!.':MH. :ÐI~"i 0 W.iPId Thm Petft '\"0 ft "'" . "..... =rP ~ ~ hb~ (' ( C"".d 0, om.,M.1 '0<: V _oM>on Pllilli ps Alaska, Inc. '" PHIUJPS J ""':"""""""':"::"00"" . '0.0'" 0 '0" '0'" ~,~~f~!) Dot. 0>011" ' "..'.h..'""' p", ..t...". :, O^" <0-".7<'>. CoO'd:'o'" O" ;, t"" ",t,.,.", ,0: ,." TM V,";ool D,p'h, 0'0 '0""'" OKS (Oo,on 19). !Ia. 3f:1).'3.". Structure: CD#2 Field: Alpine Field Well: 49 Location: North Slope. Alaska ¡"',n> <- West (feet) Seal. 1 inch ~ 400 ft MOO ..00 MOO 5600 "'0 'MO «00 '000 "°0 ,"00 ,"00 "°0 '000 1600 "°0 '00 400 400 MO "00 "00 '000 ,.00 ,"00 "00 ,'MO 4000 440O ..00 ,-,~'---'~_.~,,-~ ,,-~- ._--,-~-~-- "c- ~--~",.._"---~""-",,-, ~_.. '"-'-_._-~~,,-.-__'___L_~',,.-~'~~'---'-~'_~.~~_L_'_._'-~..~---"--'_-~-L_,'_~--__L~... 5600 ~ ¡¡' ','00 ~. '800 [[{I, I I I , I I , I I , I I , , I , '.""'", \ - \\",, "-""'" ~ ..."....."..,.", \, ~I., """"" I '~"".' ..,""',...,.." '. ~~ 'C""" /'i §(\ ""':':""0',,"""""'" """" ~-- \, """""""'" """'" I ""'-., \ .., "'-"""i:.::' 'I' ",'., ,'1 ",.,;; e,.".!..",.. \\ --".. ',.,..~",:~;~:,~~:i;~'::::::~::~~;~;::c;;:,;""""" \ ,.",..~C~,Y' "..", \, "".""""~"""""";:"':"."""':'."8 \ -CC.""""'- '/'1' """'\\~;::'~.' .""'" \. .,...-,l;,:¡20 "1'/""'" \.. "<"!1-.),,~'I'.e,,".'."u .. .. ,,' . / \'ìr ' . .\~, '. -'. C"."" " \\\.., /;:,o,~>?~";~;;;>;".o". / , '";\:',:\~~:"":", . // ...5;~:J"""" " " \\ ",..".", '>"" "..,..",. , ,,' ,,'" \\ .'.,.,.. " , , " ~ , I I I I , I I I I \, ~~ \ «00 '" 0 0 ~ '000 360O "°0 / .' ...;/' §J/ I I " ¡;)¡. """'D \\.. , , , I I I , , I I .. I , \\, , , ; \, ; \:illi @ S\', , I I \, [lJ\ \~\. \\\ 'i, /\ \ , , , , , ,..,......,......,.,,~,\ .. \ \\ }'\\ 7 e""" I' , \ " \ \ \:\ '\\ , , ROO \\ \~;\: :: """... \.~IJJ/'¿'"""'¡ , \ '1!f!J .. i.ìD ' ",., \ .. ' 2000 '., , .. ". Lill \ ',:\, "\~,.,. 7 co"o;\\'ìr \, \(()" .. "00 \\ 1L1 \\ ~ .. '°00 , '000 7 c",'., 2<00 . 2000 "00 1200 '°0 'aD , a U) 0 I: 3' ...... " .; , '°0 I V ...,.",.,.......... (j$"'" ,,/' .,' 2'°0 / I \ , , , , , \ , \ \ \ 11.8 ~\r 7 Coo"" , \.., \\, , I , \\\ \, \~ .. 2800 / ../ ",~"7".'O' 3800 # , <400 ,"00 0200 ,"00 ROOO , 6400 6800 ( ( C".I" by Om:".., '0" V _o"o"on ~ P J[1 ill ips Alaska, Inc. ~ ~ ~olo P""oo ' ;,,-rob-,"O) "'ol Ro"""":'"we <0-"874'> Ooo'o'"a'" .., " '", "to'"" ,I", ¡<9, Vo~"" Oop'" '" "' "on" -HO (D.,on lI!!:iI.. ~< Structure: CD#2 Field: Alpine Field Well: 49 Location: Norlh Slope, Alaska "'"", <- West (feet) Scale 1 inch ... 100 II 2100 'ODD 1900 'ODD 1700 '"DO »00 1<00 IJOO 1700 "00 ,"cO ",0 000 '00 000 '°0 .ao Jao '°0 10O '00 ,ao Joa 'oa 500 600 700 800 '00 "L,..,.__L"_"L'-<è' ~---',- , Q) '--..L._L..--_- '--~--'_~"_L_'_'~'---'--'-"-'~~'_"__L_'_'_L'_'-ø'_L_.'%..,19"_'--_L_L_.L_..'_L@'_'L----"__~--' 17oa "'00 to ;; ¡; L__.'_._.~."-_.'_. Q:J Cib..,. .,..".,..".." .;..... 'V' C.... ..... ----------. /~ -!1'~""" 1000 3' g ......,...., 000 0 0 '.. QJ """" "', .- ŒJ, 000 """'" (jS) (ß ~ """.. /..//~ '. '., ". ---- "'" ~ ')"""""' , """" ~\" I,,',""'"'.,,""'.' ",.;,::~,,'fi;~;; C.'~':,~,.."..' """""""""",".'."."~" "."/H.C','h.'.ii;';;;,C'~'" ,";," """~'f ' \Ç: ", , C..I" Þ "5/11 c,,',a..,.......,.,....,..."""':",'."':',~.;';,~,",~.':,::,.i.¡f,.,::~~~~~,:O,,~.........,"', ""'" "".';;:-. "111 C..", "", '. . .. ,..-", y /" ),J,. ,;;.c~;;¡.,""""""':'<:<" ./," / / ,.,.", \~~:\.<~,,;""',.,,""',:.:::::,',...,. ::: :==:="==~=:===----1"':3~?O::-'ft'-"'=:=-=:~==-"'-"~~'~':~:7," ,,' \\ "'~,:':~-<>I.~, .,::.'°: .. 300 ,/.." y'"I' Cool"~ . - ,.,,' ,."" "", , ~}"/IIt:OOI"'\\,., ""':.~':~,','$)-<oo .,.., ¡, 'I' c""a \ . / \ ,/ \\ \ / ..",. \::: ' " ¡ \ \\ '~ \ \ ~ - IDDO """" ',,-.-t::.~ 'I' c"'o, ,..,..,.,..,... ,1"",."".001001,"'."""""""""""" 7DO 600 '00 ŒI t:. \1 ',III ;;,,;,;,~'" "" 't:'~.'!~, _:."~'~~...... - 400 .\(10 2DO IDO (ill (J) a !: ::;: '!í( "I' c""" ,-., ;; .; Qv "",,;;;,,> ....."...."......."., ~,,::::,,~.,;;~,:.:;., I V 100 - 800 / " i,' i* \1 'I' C".I" ~oo &> '*"",01."'°.00"'."07,"'"".". ,,/' ~, "I" C,"I""",, '1'111 C..I, / // ---- /f " ~~, ------!- ------ ¡ / ,1100 12DO ~~ "I' e","'" 'pi- ObI' COO," -I.IDO ~ .. 1400 1.1. . 'I' C"'" 1500 - 1000 17DO 11100 .. 1900 ~ % 2000 ,;i- ' COO,"~ ~ @ @ ¡ i rÞ @ l!l %G @ SURFACE CASING SHOE SEPARATION FROM CD2-49 CD2-49 x y Surface Casing Shoe ASP 4 Coordinates: 371252.38 5974065.93 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 wel/* Coord. Coord. CD2-35** ---- ----- x x 1 ---- ----- ---- 1061 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 171 371098.46 5973992.48 CD2-33 (+A&B), CD2- CD2-24 301-186 7/13/2001 x x 2 39, CD2-14, CD2-15 33999 7/16/2001 1 0/9/2001 904 370630.11 5974721.81 CD2-33 B*** ---- ---- x x 4 ---- ----- ---- 1111 370155.64 5973886.23 CD2-39 301-281 1 0/9/2001 x x 2 CD2-15, CD2-47 27879 1 0/1 0/2001 11/12/2001 1180 372350.61 5973633.17 CD2-14 301-288 10/9/2001 x x 2 CD2-45, CD2-47 14835 11/13/2001 12í17/2001 1305 372202.4 7 5974960.87 CD2-15 301-308 11/6/2001 x x 2 NA 1010 370832.00 5974984.02 CD2-47 301-322 12/3/2001 x x 2 CD2-34, CD2-26 27349 12!17í2001 1 !20í2002 772 371231.72 5973294.19 CD2-34 x x 2 NA 666 371803.06 5974439.79 CD2-26 x x 2 NA 733 371798.52 5974554.55 ~. * 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 annuluar 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 12-Feb-02 .~. ( 'i"" I~ Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 14, 2002 Alaska Oil and Gas Conservation Commission 333 West th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of DrillinQ Waste on well CD2-49 Dear Sir or Madam: Phillips Alaska, Inc, hereby requests that CD2-49 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular injection on CD2-49 approximately March 24, 2002. Please find attached form 10-403 and other pertinent information as follows: 1. Form 10-403 2. Annular Disposal Transmittal Form 3, Pressure Calculations for Annular Disposal 4. . Surface Casing Description 5. Surface Casing Cementing Report & Daily Drilling Report during cement job 6. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 7. I ntermediate Casing Description 8. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 9. Formation LOT on 9-5/8" x 7" casing annulus 10. Plan View of Adjacent Wells 11. Details regarding wells within % mile radius of surface casing shoe. If you have any questions or require further information, please contact Vern Johnson at 265- 6081, or Chip Alvord at 265-6120. ffe,y, ? .........- ~ ~Ohnso Drilling Engineer cc: CD2-34 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake A TO-868 Anadarko A TO-1530 RECE\\lED f£B 1 9 2G02 Comro\ss\on 0'\ & Gas coos. A\as~a' Ancootage 1"""\:'¡"""\,1.'o"~\!.h¡ r, \'. r 'I: I " I 0 'I h I' j, I' \..f¡"(¡;~',"'¡¡\',,:,.,"!"\',!,,: l\o\)¡!'¡"A..\t ,"'0' . \ i """,....' ., ",} ,I ,I .., ,,;......-. (" ( ~7{( ~/, O~ 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 2053' FNL, 1504' FEL, Sec. 2, T11 N, R4E, UM At top of productive interval 603' FSL, 964' FWL, Sec. 2, T11 N, R4E, UM At effective depth At total depth 2043' FNL, 2377' FWL, Sec. 11, T11 N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 11874 7263 11874 7263 measured true vertical Casing Conductor Surface Length 68' 2457' Size 16" 9-5/8" Production 8853' 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 10 cu yds Portland 390 SxAS III L & 236 Sx 15.8 class G 198 Sx 15.8 class G Packers & SSSV (type & measured depth) 4.5" 12.6#, L-80 ibtm @8331' MD Tubing (size, grade, and measured depth 7" Baker S3 Permanent Packer @ 8213' MD Description summary of proposal - Detailed operations program - BOP sketch - Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic 14. Estimated date for commencing operation 15. Status of well classification as: March 24, 2002 16. If proposal was verbally approved 13. Attachments Oil_X Name of approver Date approved Service - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. A- L -i- ()¡.J / .., FOR COMMISSION USE ONL Y Conditions of approval: Notify Commission so representative may witness I Approval no. ,',\ Plug integrity- BOP Test- Location clearance- . ~ð~-O~\.....J Mechanical Integrity Test- Subsequent form required 10- rn~~~ö-",,'.)'Q..,\:~\~~ \ Original Signed By (l \ ~ \ \ t~ ~ - n. I .. Commissioner Dater) \ '-\ \\.J Q Signed ChiD Alvord Approved by order of the Commission Form 10-403 Rev 06/15/88 . Title: Alpine Drilling Team Leader í! I:: '" :' , " Re-enter suspended well - Time extension - Stimulate - Variance Perforate 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Other _X Annular Disposal Colville River Unit 8. Well number CD2-49 9. Permit number I approval number 201-249 10. API number 50-103-20401-00 11. Field / Pool Colville River Field / Alpine Oil Pool Measured Depth 114' 2494' True vertical Depth 114' 2378' 8890' 7260' RE,CEIVED FEB 1. 9 2002 Alaska Oil & Gas Cons. Comrnission Anchorage x Gas Suspended - Questions? Call Vern Johnson 265-6081 Date ~(( Ð (() 2- .....~ \ " SUBMIT IN TRIPLICATE ~ NOTE TO FILE CD2-49.. .201-249. ..302-070 I~ Request for Annular Disposal Approval Phillips (PPCo) has requested approval for annular disposal on the subject well. They have submitted the required information. This document analyzes the information and makes a recommendation regarding their request. CD2-49 is one of the early development wells on Alpine's CD2 pad. There are a total of 10 wells within % mile. The most proximate well is CD2-42. The surface shoe of this well is approximately 170' distant. The next proximate well is CD2-34 , about 660' distant. CD2-47 and -26 approximately 750' distant. Annular disposal has been applied for in all these wells. CD2-26 and -34 have recently been recommended for approval. The originally provided cementing and leakoff information for CD2-49 was incomplete. PPCo subsequently provided the necessary information. It is noted that approximately 95 bbls of cement was circulated. Based on spreadsheet calculations, gauge plus 89% XS cement was left in the well. The casing was successfully pressure tested prior to drillout. After drilling new hole below the rathole, the formation was pressured to 16.1 EMW. The leakoff curve lies to the left of the casing pressure test curve. Analysis of the casing pressure plot indicates that some amount of air was being compressed for about the first 6 strokes. Leakoff is estimated to occur at about 14.4 EMW. Curve deflection is noted around 600 psi, although there is not a clear break. During the 10 minute observation period, the pressure dropped about 250 psi. The pressure values in decline are in relative agreement with the "picked" leakoff EMW. A competent shoe is indicated. The well was drilled into the Alpine reservoir and the 7" casing string was set and cemented. The report indicates that it was not possible to reciprocate the 7)' casing. The initial injectivity test was not safisfactory. The plot showed a sharp break in pressure with continued decline while pumping. PPCo was requested to examine the information and perform an additional injection test. The new information is provided. The initial departure from linear occurs at about 870 psi. The pressure reaches a maximum of about 1050 psi, although steady pump in is indicated at about 1000 psi. After pumping was stopped, the pressure delines to about 900 psi in 2 minutes and remains essentially constant to the end of the observation period. The pressure plots for CD2-49 are similar to those presented for the other wells. A large 'Cchart" of the LOT information for the wells on CD-2 pad has been prepared. When compared to the other plots, the pressures for this test are noticeably higher. This is clear evidence of the. difference in hydrostatic head since the annulus was freeze protected during the initial operation. The calculated EMW is in agreement with other wells. Review of the plots for the wells identified to be within % mile does not contradict approving of Phillips' application. Based on the presented information, I recommend that Phillips request for annular disposal in CD2..49 (201-249) be approved. /!i~ ~ (I -~ Tom Maunder, PE Sr. Petroleum Engineer (' ~:, " Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-49 b. The depth to the base of freshwater aquifers There are no USDW aquifers in the Colville and permafrost, if present. River Unit. Base of Permafrost = 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. d. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. Types of fluids can be mud, diesel, cement, and water. Maximum volume to be pumped is 35,000 bbls. f. An estimate of maximum anticipated Maximum anticipated pressure at casing shoe pressure at the outer casing shoe during during disposal operations is 1908 psi. See annular disposal operation and calculations attached calculation page. showing how this value was determined. g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. See attached cementing reports, LOT/FIT reports, and casing reports. h. Details that show the inner and outer casing See attached casing summary sheet and strings have sufficient strength in collapse calculation page. and burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission to confirm containment of drilling wastes. NA ( ~" '" CD2-49 Pressure Calculations for Annular Disposal .... .... Q) Q) "0 "0 ro ro Q) Q) ..c. ..c. U) ëi5 0.. 0.. a a 0) a a a c N a U) N ro + + U .:t::: .:t::: = :-:::: :-:::: co U) U) ........ 0.. 0.. L() I ...... ...... 0) a a U) U) ro ro (9 (9 <=9-5/8" 36 Ibltt, J-55 BTC casing @ 2494 ft M D (2378 ft TVD) Pburst = 3520 psi, @ 85%: Pburst85% = 2992 psi .... , ..... .... .... ,.., . 'rö'ë Estimated Top of Cement @ 7750 ft MD (6772 ft TVD) (7" csg x 8-1/2" Open hole annulus) 0) c ..c :::¡ I- ~ 0) ...... C I ëi5 """ ro U <=4-1/2" 12.6 Ib/ft L-80 tubing to 8331 ft MD F-- <= 7" 26 Iblft, L-80, BTC casing @ 8890 ft MD (7260 ft TVD) Pcollapse = 5410 psi, @ 850/0: Pcollapse85% = 4598 psi ASSUMPTIONS: . Maximum 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: Pmax = PHydrostatic + P Applied - PFormation Pmax = 12.0 (0.052) (2378)+1500 - 0.4525 (2378) Pmax = 1908 psi Maximum fluid density to burst 9-5/8" casinq: Pburst85% = PHydrostatic + P Applied - PFormation 2992 = MWmax (0.052) (2378) + 1500 - 0.4525 (2378) MWmax = 20.8 ppg Maximum Fluid Density to Collapse 7" Casin(L P collapse85% = PHydrostatic + P Applied - PGasGradient - PHeader 4598 = MWmax (0.052) (6772) + 1500 - (0.1) (6772) - 2000 MWmax = 16.4 ppg (II' ( ŒlPHILLIPS Alaska, Inc. Casing Detail 9 518" Surface Casinq Well: CD2-49 Date: 1/22/2002 A Subsidiary of PHilLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LOS 36.60 FMC Gen V Hanger 1.72 36.60 Jts 3 to 57 55 Jts 9-5/8" 36# J-55 BTC Csg 2366.88 38.32 Davis Lynch Float Collar 1.58 2405.20 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 85.27 2406.78 Davis Lynch Float Shoe 1.74 2492.05 9- 5/8" shoe @ 2493.79 TO 12 1/4" Surface Hole 2500.00 RUN TOTAL 33 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 Last 11 joints stay out # 58 thru # 68. Use Best-Q-Life 2000 pipe dope Remarks: Up Wt -155 k On Wt -143 k Block Wt - 75 Supervisor: David Burley - ...... ~ ~' PHILLIPS",. \WI ~-- .",. { t PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-49 Common Well Name: CD2-49 Event Name: ROT - DRILLING Report #: Start: 1 1/17/2002 Cement Job Type: Primary Page 1 of 3 Spud Date: 1/21/2002 Report Date: 1/24/2002 End: -- '---'-.. ----""--r--- ""--_n_" ----.__._PJim8:!Y__..------....-,,--..-.. _......._-__~q!:l..ee~~..Qp~_IJ.J::!ole --..---- -___§_ggeez~- Ca~lQ9_.___.__.._......._.. ----_.._----~J.t¿g_..._._...._-..m.......__.- . Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 2,494 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 1/22/2002 sa Date: Date Set: BTM set: (ft) Csg Type: Surface Casing sa Type: Csg Type: Plug Date: Csg Size: 9.625 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger . Rot Time Start: Rec Time Start: 19:40 Cmtd. Csg: Cementer: Jim Thompson Pipe Movement Pipe Movement: Reciprocating Time End: Time End: 22:50 Avg Torque: (ft-Ibf) Drag Up: 155 (Ibs) RPM: SPM: 1 Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Max Torque: (ft-Ib~ Drag Down: 143 (Ibs) -...-----'-.----,-.-----...........--.-............-..............--- """'-"'--""'-"""'-"'-"-'-""'-"-"""""""""'--""'--""'-"-"" --.-....................'-...........---......-.--......-........-...-.....-.---....-......-.... "-----'--'-"""""""---'--""""---""'-""""""" .....-. .. Type: Cement Casing Volume Excess %: 125.00 Meas. From: Time Circ Prior To Cementing: 1.50 Mud Circ Rate: 336 (gpm) Mud Circ Press: 340 (psi) Stage No: 1 of1 Start Mix Gmt: 21 :16 Start Slurry Displ: 21:17 Start Displ: 22:18 End Pumping: 22:55 End Pump Date: 1/22/2002 Top Plug: Bottom Plug: Disp Avg Rate: 8.00 (bbl/min) Disp Max Rate: 10.00 (bbl/min) Bump Plug: Press Prior: (psi) Press Bumped: (psi) Press Held: (min) Float Held: Mud Data Type: Density: (ppg) Visc: (s/qt) Bottom Hole Circulating Temperature: CF) Displacement Fluid Type: Slurry Data Fluid Type: FLUSH Slurry Interval: 2,494.00 (ft)To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: CF) Returns: Full Total Mud Lost: Gmt Vol to Surf: (bbl) (bbl) Ann Flow After: Mixing Method: Density Meas By: densometor . PVNP: (cp)/ (lb/1 00ft2) Gels 10 see: (lb/100ft2) Gels 10 min: (lb/100ft2) Bottom Hole Static Temperature: CF) Density: (ppg) Volume: (bbl) . Stage No: 1 Slurry No: 1of4 "-' Description: Vis Water wI nut plug Gmt Vol: (bbl) Density: 8.30 (ppg) Slurry Vol: (sk) Water Vol: 40.0 (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Temperature: CF) Temperature: CF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: . . .. ..---..... Purpose: Pre flush Mix Water: (gal) Foam Job: N Temp (OF) CF) Pressure (psi) (psi) Printed: 2/4/2002 9:32:38 PM (' - ~ ---. , -, ~ PHILLIPS 1 œ -- Legal Well Name: CD2-49 Common Well Name: CD2-49 Event Name: ROT - DRILLING (, PHILLIPS ALASKA INC. Cementing Report Page 2 of 3 Report #: Start: 1 1/17/2002 Spud Date: 1/21/2002 Report Date: 1/24/2002 End: Stage No: 1 Slurry No: 2 of 4 --------.-.-.-...-...--..----.--.---.------.-----..-..-----.-------.---........-......----.----.----.--....-...-"'--"--"------'-'----'-"-'--".----..'-'-----'-"'-'-'--'---'----------"--'---"-"---'-'---... ..m'"".. .. Slurry Data Fluid Type: Spacer Slurry Interval: 2,494.00 (ft)To: (ft) Water Source: Description: ARCO Gmt Vol: (bbl) Slurry Vol: (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: ("F) Temperature: ("F) ("F) . Class: Density: 10.50 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp ("F) ("F) Stage No: 1 Slurry No: 3 of 4 . Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) .. --.--. ---.---..----------.-- --"-' -....--.--..-----.-.. -..-......-...-.----.. --.--.---.- .--. ..--.-..--.--- -. .-. ---.--- '--'---'---.--- .------. ..-.--------.-..- ----------"-----'-'----'-' --_. .-.. -..-----.. "'m"" .. ." Slurry Data Fluid Type: LEAD Slurry Interval: 1 ,994.00 (ft)To: (ft) Water Source: lake water Description: AS Lite Gmt Vol: 306.0 (bbl) Slurry Vol:390 (sk) Class: Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: ("F) ("F) . Time Compressive Strength 1: Compressive Strength 2: Temp ("F) ("F) Stage No: 1 Slurry No: 4of4 . Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,494.00 (ft)To: 1,994.00 (ft) Gmt Vol: 48.0 (bbl) Water Source: Slurry Vol:236 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: ("F) Temperature: ("F) Temperature: (OF) (OF) --------- '-----------.--- .-.------.. -_.__._- .-. -..- - --.---- -------.----.---- Class: G Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp ("F) (OF) Purpose: FILLER CEME Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: SHOE INTEG Mix Water: (gal) Foam Job: N Pressure (psi) (psi) ..-..---.----.....--...... Printed: 2/4/2002 9:32:38 PM ( ( PHILLIPS ALASKA INC. Cementing Report Page 3 of 3 Legal Well Name: CD2-49 Common Well Name: CD2-49 Event Name: ROT - DRILLING Report #: Start: 1 1/17/2002 Spud Date: 1/21/2002 Report Date: 1/24/2002 End: Casing Test Shoe Test Liner Top Test "---------------- -----------------------._------ ..--- ---------------------- ------------- --- ---- --- -- ------ ----------------.._------------------------------- -- --.-...._---------- - ------ Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 14.40 (ppge) Tool: N Open Hole: 26 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N 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 .- -----------------.--------------- --------.--------- ----- ------ -.... ----. --------- ----------------------------------- ------------------------------- _.._----.--- - __no ---.- -- - -- -- Printed: 2/4/2002 9:32:38 PM (' ( Page 1 of 2 Daily Drilling Report I JOB NUMBER i EVENT CODE! 24 HRS PROG TMD TVD DFS I REPT NO. i DATE CD2-49 I i ODR I 210.0 2,500.0 2,376.0 1.92 I 3 11/22/2002 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD DAILY TANG I CUM. TANG ____---..J?avid Burl~)I_~__--L___--_..QQYQ!1_1@QQC9..:~Q!1l_1~______:____----6IPine ------ _.11,874.0_____---.9..:90 - _1- 0.00____- - CURRENT STATUS Testing BOPE. ------__j~CCIDEN_~~~AST 24 H:::~__--- DAIL~~~TW~~~UD ----- CU~-~~~~:~~~U~-- 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD UTHO~~vBOPE. RI H w~b" ~c d@_O~[J~~:~:F ~~k~~~'::leHRs SiNC~~OL..- -'AFE- ~:::~ --- AUTH.' ~~:~~:~:9-' -~~~~;~~~-_::_~_?1_;:;' 84_~~~-~;~~~~---~~--~;~~~~~I~~~_~~~:~~---=~~;~-lNEXT~~;-- ŒL_- -LAST :p PRES ~~~T-- ----- ,.- WELL NAME --------.. ------------ -------"-- 0.00 LIME ES DENSITY(ppg) FV PVIYP 59 13/16 9.60 PP GELS WLlHTHP 7/20 10.21 FC/T.SOL 2/ 125.0 0.00 Pf/Mf / BHA I HOLE CONDITIONS STRING WT. UP STRING WT. DN STRING WT. ROT 150 150 150 ITEM DESCRIPTION NO JTS LENGTH O;D. Bit 12.25 MXC1 1 1.00 12.250 Navidril Mach 1 CI 1 28.82 8.000 ---------------------------------------..----------------------- ------------- -------- ------ --------- ------------------ -- ---- ----__om --..- -- Short ~~n-Mag DC -------------------------------------------------, -----~---____~:.9~__~:_~ ----~.O~Q..--- --------------------..--_. Non-Mag Stab - ------------------ ---~- -- 5.75 -~~--____~.8~___- ----------- MWD 1 27.98 8.000 1.920 ------------------..------------------------------------ ------- ----- ---- --------- -------.---- -,,---------- Float sub 1 2.49 8.000 1.920 -----------------______m_..___--------------------------....---------- --------------------- ----..--- ----------- --------..----- --..-------- ---------.._----..-,----- UBHO 1 3.27 8.000 3.000 ---------.----------..--------------..----------------- ----------- -------- ---..---------- -..-------------- ------------ -----...----------- ---.. - NMDC 2 61.15 8.062 2.875 ------------------- ---- ------------ ----------- ---------- --- ~gn-~_ag -§!~~--_.._----------------------------_.._.._-_.._---_.._---- -------~----------~:_~- __...?~06?- 2.875 NMDC 1 31.07 8.062 2.875 ----------------..---..-......------.,--------------..--------------------- -----' ---------- -----------------..- -..-------..- ----------- -----------------.... ------------... ---..- ..- Crossover 1 3.65 8.065 3.000 HWDP 3 88.34 5.000 3.000 Jars 1 32.38 6.250 2.250 HWDP 23 689.09 5.000 3.000 BHA NO. 1 BHA WT. BELOW JARS 20 TORQUE I UNITS 6,000 ft-Ibf 990.54 J.D. CONN SIZE CONN TYPE -----..-------....---..------- -" ----------~------_..- SIZEMANUF. 12.250 HC TYPE MXC1 SERIAL NO. R923JH JETS OR TFA - 10/12/12/18// DEPTH IN DATE INI-O~D-L~B-G-O-R 114.0 1/21/20024-7-wr-A-E-2-EC-TD BIT I RUN 1 / 1 BITS - - BIT OPERATIONS - - - -"""'-'---"-------------JI- --------.-"-"--------""-'-]--"------"""'-"--c-",---------,,---c--"'j------"---"-------"]"-"'--"-------"'-f"""----..,.. -------..----,..-- --..-..--..----------- ""-----"---r"----"------"----"-"--""-----. -" "'--,'----. BIT I RUN - WOB RPM GPM PRESS P BIT -HRS24HrDIST24Hr ROP CUM HRS CUM DEPTH CUM ROP ---------------------_.._-------..- -......--------..- ---...._-------- -------------....-------- -------- ..-----..------------ -----------..-----....--------- --------..-..-..- - 1 / 1 5/40 1511271 546 1,670 884 4.90 210.0 42.86 34.30 4,477.0 130.52 ------------ --- - -------- .- --------------.-- --------- ----..-------- -- ---------------------- ---- - .. -..-..----------- --""'----------------[--"'-------"'-""'-.--"-"--lil":-'-"--. "----:"--J-...--.----..,-----....----.....--..._--§Jl RVI;~CRA-I~ ------.--------.. ---..--------..-.---......--.....----":c--- -"""------':-r--.;...--------""- ----"-""-"'--'-,-, ""'--.-.-,'" __M.D. -~...!.~~~.....- -~!.~~-~!~--~-_!:~:~_--~IS ~~~-~~-~~~__SE~_!~~~~ -- M.~:..-,-- --~~~~___--"_AZI~~:!~_--,_.;....T.V:?:...::._~/_~_<?UM~ EIWC~_~_~,=-~~~~~--- 2,265.03 32.630 240.980 2,184.88 -186.97 -368.32 -8.84 2,444.84 32.140 241.630 2,336.69 -233.43 -452.75 -7.69 ---- -----------------_..,,--- ----------- ---------------------- ----------....--------""'- 2,360.47 32.410 241.070 2,265.36 -211.83 -413.21 -8.09 ------- ------ -------------------.- .. -------------..---------------------.------..- ---- - - - .. -----,- -----'------- ...---.,..--..-..,...--- "--------'----..-----------'~ Q.P..ê.M..IJ 0 ~.~t§U ~M~_~..t_--,--_..-------,------------,,-_._---------_:.-------_.._----------.._,----...._- FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 06:00 6.00 DRILL P DRLG SURFAC D rill fro m 22 9 0' to 2 5 0 0 '. ART = 4 . 9 06:00 07:00 1.00 DRILL P CIRC SURFAC P U m p e d 40 b b I 30 0 F V s wee pan d c i r C h 0 lee I e a n ,550 gpm 110 rpm, 1690 psi. WIPR SURFACFlow check well, static. Wiped hole to 1462' 10-2 5k over, max 50k over. RIH, no problems, no fill. SURFAC P u m p e d 40 b b I 3 0 0 F V s wee pan d c i r c h 0 lee I e a n ----------- ---------------- 07:00 09:00 2.00 DRILL P 09:00 10:00 1.00 DRILL P CIRC Printed: 2/4/2002 9:35:45 PM {' ( Page 2 of 2 Daily Drilling Report CD2-49 i JOB NUMBER I EVENT CODE 124 HRS PROG - I ODR ! 210.0 I REPT NO. I DATE 3 : 1/22/2002 WELL NAME OPERATIONS SUMMARY TROUBLE SUB I PHASE I DESCRIPTION CIRC SURFAC wit h 650 9 pm, 1 1 0 r p m 1 85 0 psi. TRIP SURFACFlow check well, static. POH, no problems, max 0 ver 25k. Flowcheck well at BHA, static. Stand ba ck hwdp and 8" DC's. - -------------------_.--- PULD SURFAC Lay d 0 W nub h 0 sub, M W D, s tab, po n y coil a ran d motor. ---- ----- -------- ._------- ----- -------------- ----------- --------- -------------------------------- --------- - J...~:30 ~~:45 -_1.:~___~ASE P __n_____'3~RD -- SURFAC R U ---'-~~~~i_I_~~__~-~_!~~-~~---~-~--_c a ~i_~iL!--~~_~~' 14:45 15:00 0.25 CASE P SFTY SURFAC He I d pre - job sa f e t y and 0 per a t ion s me e tin 9 wit h rig crew. -----..--------- RUNC SURFAC Ran 57 j 0 i n t s 0 f 9 - 51 8 ", 3 6 #, J - 5 5 cas i n g. M U h a nger and landing joint and land casing with shoe @ 2494', FC @ 2405'. RURD SURFAC Lay d 0 w n fill u P too I and M U c e men the ad. CIRC SURFAC S tag e d p u m p sup to 8. 0 b P man d con d it ion mud f or cementing. PJSM. PUMP SURFAC P u m p 40 b b Iso f B i 0 Z a n wIn u t p lug pre flu s h, t est cement lines to 2500 psi. Pump 50 bbls of 10.5 ppg spacer, 390 sxs of 10.7 ppg lead and 236 sx -------- -------- ---------- --------- _-__n__--- -~--- 0 f 1 5 _:_~- p g t a ¡Ie e m e n t . ---------------- --- - --- 22:15 23:00 0.75 CEMENT DISP SURFAC D i s P I ace d wit h 20 b b Iso f F Wan d 1 67 b b Iso f m u d, bumped plugs to 1000 psi, floats held, CIP @ 2255 hrs. --------------------------- --------------,-- ---------------- ,------ -------- ----------------------------------------------- ------- 23:00 00:00 1.00 CEMENT RURD SURFAC M 0 nit 0 ran nul us, s tat i c, flu s h con d u c tor and b low down lines. RD cement head, lay down landing j -- 0 i n t -~~~~~~_!L b a iJ~_~__--------------- - FROM TO HOURS I CODE 09:00 10:00 1.00 DRILL P 10:00 12:30 2_50 DRILL P ------- -------- ------ 12:30 13:30 1.00 DRILL P -- --- ------ ------ ----------- ------- 15:00 19:00 4.00 CASE P 19:00 19:30 19:30 20:45 0.50 1.25 CEMENT CEMENT 20:45 22:15 1.50 CEMENT --- -------- --- --- -- --------- - ---------..-------- ---- ------------ ---------------------------- 24 H_~_~~_~MARX~_I?..~~~...!rom 22~.9_~_!~5Q9~_~~~r trip t~~62', ~O~.:__£3U and run 9-5/8" ca~ingJo 249~~--___-------------------- PERSONNEL DATA NQ HOURS COMPANY 2 Sperry Sun 26 DSR 2 ACI 3 FMC 2 SERVICE -- NO. - 2 4 5 1 - COMPAN'( Phillips Doyon Baker Inteq MI Drilling Fluids Dowell HOURS - - MATERIALS I CONSUMPTION. - ~~~r, ~:~g ~-----=~~Lf~f=- =~~fw~~ ::t~~'T~-r~~1~I= ----------- --,--------~--------------------- -,------- ----------"'---------------- SUPPORT CRAFT -- :D2=~ TYPE--=t~1~~~~-RE~KS~-==---=-¡= -- TY~""::~ ..f N~í~-=--~~~~==: Printed: 2/4/2002 9:35:45 PM CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-49 Date: 1/23/2002 Supervisor: David Burle}' Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8",36#, J-55, BTC CSG Casing Setting Depth: 2,494' TMD 2,378' TVD Hole Depth: 2,520' TMD 2,400' TVD Mud Weight: 9.5 ppg 26' Length of Open Hole Section: EMW= Leak-off Press. + Mud Weight 0.052 x TVD 600 psi 0.052 x 2,378' + 9.5 ppg = EMW for open hole section = 14.4 ppg Used cement unit Rio pump used NO #2 Pump output = 0.0997 bps Fluid Pumped = 0.9 bbls Fluid Bled Back = 0.6 bbls 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi I I!I!I!!"¡"...,, 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi W 1,800 psi 0::: 1,700 psi :J 1,600 psi ~ 1,500 ps~ W 1,400 pSI 0::: 1,300 psi a. 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi """ 600 psi , 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 ....... , . ! ! I; I ; I-, I , '. I¿--.~.-i-..........-.- I ¡ i i j i TIME LINE ONEMINlJTETICKS ~ ¡ i i I I i j j j j 1 I i i j T i I I ~ LEAK-OFF TEST ~CASING TEST ww!> " LOT SHUT IN TIME -i- CASING TEST SHUT IN TIME í ~TIME LINE ¡ I j i j ->] I T j j j 30 STROKES 40 50 10 20 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above "_Æ..~" h.. C'_~H D~..~~I"~ MINUTES MINUTES ffiR ffiR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE r---------- ----T-------õ_n_--- rn---Õ- -p-si - --- -: r------- - - --- - --r--Õ-šti( š---r - ---õ--p-sT --I ~---------- n_n+-__n____n___- ~------- - ---- ---- -I ~_____n- ---- - --+-------- --- ___+n_____n- ---- --4 : I 1.0 : 100 psi: I I 2 stks I 100 psi: }---------- -----+---------------t------- ------.--- of }------ - ---- - --- +---------- - -- -+ - -- ----- ---- -; ---t L----- - ------ --1.--- -~: ~______L_~~_~ _p'~-'--.} \ ~1j--- - ----- --_1._-~-~!~~--_1. - -~-~Q -p-~~ --.1 L------------j----~:~------i --}.?_~_p.~L~, ~~- --- ---- - -j---~-~! ~~---L- -~-~QJ?_~L --1 ~--------- -------i------~:~---- --~---~~-~-p.~.ï- - ~ ,~----- - --- ---~ ---~-~! ~~---~ ---~-~Q_p_~L --~ l::::::::=:::::!:::::~~::::::t: ::~~~:~~::~ ~~::::::: ::::!::J:~:~¡~{: i:J:~~~ ):::1 L-------------L----!.:~------L-!.~-~_P.~L*t4-Ð-__--------L-~-~-~!~~--L-!!~~_~_p'~_i--1 ! ! 8.0 ! 770 psi. It! 16 stks ! 1,400 psi! r------------ --r---- 9~ Õ-----T--S2õ"psf-tt S~----- - --- ---r-fa-5 i kš--r {6"fõ- psT: }--------------- +-------------- -t---------- - --- --of }---- - --- - - _n__+ ___n__- ------ + ___n____- - _n.-- i : : : : : : 20 stks : 1,830 pSI: >---------- - -----'------- - --------~----------- -----.. ~---- - --- __n__--'- _____n__----- -'- --- ___n_- - -- ---. ! ! i ! i ! 22 stks ! 2,070 psi! .---______n__--~------------ --- t- ---------- _n__" t---- - - _n- --___~__n_- ------ - - -to--- -------- -- --- ~ ! ! ! ! ! ! 24 stks ! 2,300 psi ¡ r-- ---------- ---.------ ----------r ------------- -- -, r------ - -- ------,-------- - -- --- ,- ----------- --.-- ~ : : : : : I 26 stks : 2,520 pSI I }---------------+---- - ----------t -------------- --of }--------------- + ----------- ---+- - __n__-- -- ----t I I I I I I I I I I I I I I I I >---------------'--------------- -~---------- - --- - -.. ~--------- ---- ---'--------- - - - ----'-- - -------- - --- --. I I I I I I I I I I I I I I I I I I I I I I I I ,----------- ----~-----______n_t- ---------- -----.. t---- - --- - - ------to ---- ---- - ------to ---------- - --- --~ I I I I I I I I I I I I I I I I I I I I I I I I r----------------'---------------- r------------ ----, r---- ------ -----,------- -------,--- ------ - - --- --~ I I I I I I I I I I I I I I I I }-----______n_+____----- ------t -------- - --- - ---of }------- ---- ---- +------- ----- -- +--- --------- - --- i I I I I I I I I I I I I I I I I >---------------'---------- ------~--------- ---- ---.. ~------ ----- -----'----------- - ---'-- - ------ ___n___. I I I I I I I I I I I I I I I I I I I I I , I I .-__n_____n___~__-------------t-------______n_" - - , , I , I I I I I I I I r----------------.--____n_--- ---- rn--------- -----, I I I I I I I I }____n________+___n____nn- t-------- - ------- of I I I I I I I I >---------------....................................,.............................. I I I I I I I I I I I I LEAK-OFF DATA i ] j J J I I I ! SHUT IN TIME! SHUT IN PRESSURE r----- __n_n--- -,------------- ------------- ---- - -_. I 0.0 min : i 820 psi! }---------.----+---------------t------------.---of : 1.0 mm I I 740 pSI: ...------ ___n_- _-'-__n_____n__- ~- ------- - --- ----.. ! 2.0 min ! ! 700 psi! ,------------- --~--------- ------t ------- - --- - ---.. ! 3.0 min ! ! 670 psi! r-__n--------- -.-------------- --r------- --- - __no, : 4.0 min : : 650 psi: }o---- -----,----+-------- --- ----t--------- ----.--- of : 5.0 mm I I 625 pSI I >------______n-'-___----- -------~-------- ---- - ----I ! 6.0 min ! ! 610 psi! ,---------------~---------------t----------------" ! 7.0 min ! ! 600 psi! r--------- -------,------ ---n-----r ------- --- ---- --, : 8.0 min : I 590 psi: }-----------.----+------______n_tn______-----.---of : 9.0 mm : I 580 pSI: [I9~2~~]~~I~~~~~~~~~~~~~~ [~~?~~~ p.~C] 60 ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COIvIPANY CASING TEST DATA /-""'- ! SHUT IN TIME! SHUT IN PRESSURE r----- --- ---- - - -, ------ __n-- ---,- ---------- ----. --~ : 0.0 min I : 2,520 pSI: }---- -- _n_-:--- -+ ------ ------- -+--- ------- - ---.--t I 1.0 mm : : 2,520 pSI I ~------ ----- --- - -'- ------ - --------'-- -- -- --- - -- -- ---. ! 2.0 min ! ! 2,510 psi! [--3,0 -rñi n-- r------ ---- - --r 2~5fõ -psfl r------ ----- ----,------ --- - - - --, ---------- - --- --~ I 4.0 mín : : 2,510 psi I }--- - --- ---:-- - -+------ --------+--- -------- ---.-- i I 5.0 mm : : 2,500 pSI: >---- - --- ----- - --'- ------ - - -- --- --'- --- --__-o-_n__. ! 6.0 min ! ! 2,500 psi! t-------------- - -to------ - --- --- --to --- ----- - --- - --- ~ ! 7.0 min ! ! 2,500 psi! r------ - ___n__- ,_____n__-- - -- ,-- ------ --------~ : 8.0 min I I 2,500 psi I }---- - --- - --:-- - -+--------- - --- -+ --- ------- - ---.- - i I 9.0 mm I : 2,500 pSI: >---- - --- ----- ---'- -------------- -'---- ------ ---- ---. ! 10.0 min ! ! 2,500 psi! t------- ---- --- --to------- - -- --- - -to--- --- -- - --- - --- ~ ! 15.0 min ! ! 2,490 psi! r------- ---- - --- ,------- -------,- ------- - --- - ---~ : 20.0 min : : 2,490 psi I }------- -- ---: - -_+____n__- -- - --+ ---------- - ---.--t : 25.0 mm : I 2,480 pSI: t-~o---O-- ---:- - -7---------- ---7--2--4--8-.0--- ---.--t L:-- - ~--_J.::!!!. -1..-------- -- - --1.- -- L_- -- e~Ll ~" NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY t' ( Casing Detail ]" Intermediate Casinq Well: CD2-49 Date: 1/29/2002 Phillips Alaska, Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LOS 35.20 FMC 11" X 7" Hanger 2.40 35.20 Jts 3 to 217 215 Jts 7" 26# L-80 BTCM Csg 8768.57 37.60 7" Davis Lynch Float Collar 1.43 8806.17 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 81.45 8807.60 7" Davis Lynch Float Shoe 1.70 8889.05 8890.75 8-1/2" TO 8901.00 1 straight blade centralizer per jt # 1 thru # 25 Jt. 158, 159, 160, then every other jt 162 to 216 56 total centralizers Joints 218-230 stay out (13 joints) Use Best-o-Life 2000 pipe dope Remarks: Up Wt =??? On Wt =??? Block Wt= 75K SupeNisor: Don Mickey (: f PHILLIPS ALASKA INC. Cementing Report Page 1 of 2 Legal Well Name: CD2-49 Common Well Name: CD2-49 Event Name: ROT - DRILLING Report #: Start: 2 1/17/2002 Spud Date: 1/21/2002 Report Date: 1/30/2002 End: Cement Job Type: Primary ,..------.._---- ---...---- --_.._------__--!:!Jæ~!Y___.._-_.. --...--------- -- ------------ §-g-~~z_e,..QP~i!-- tiQI~--_--__- --- ----- -- --------------S 9.~-~~:?.~-ç- a s ~~g------ --"-,, --- _._---_._._----__--___EJ..I:I._g. ------ -- - ----.-- - - --.--- Hole Size: 8.500 (in) Hole Size: Hole Size: Hole Size: TMD Set: 8,891 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 1/30/2002 sa Date: Date Set: BTM set: (ft) Csg Type: Intermediate Casing/Li sa Type: Csg Type: Plug Date: Csg Size: 7.000 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Intermediate Casing/Lin Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jim Thompson Pipe Movement: No movement Pipe Movement Rot Time Start: : Rec Time Start: : Time End: : Time End: : RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Max Torque: (ft-lbD Drag Down: (Ibs) Stage No: 1 of1 -- -- -- -- -- ---- -- -- -----------..----..----------- ----------- -----------..-----,--------.--..-----..--...---------..-------- --------..-..-"-- ..-- - -- ..-.-------------.------ ---'--------------,----------.--..--.------------ -------------- .. '----n Type: Cement Casing Start Mix Gmt: 23:00 Disp Avg Rate: 5.00 (bbl/min) Returns: FULL Volume Excess %: 40.00 Start Slurry Displ: 23:20 Disp Max Rate: 5.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: Start Displ: 23:30 Bump Plug: Y Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 00:25 Press Prior: 800 (psi) To Cementing: 1.75 End Pump Date: 1/30/2002 Press Bumped: 1,600 (psi) Ann Flow After: N Mud Circ Rate: 189 (gpm) Top Plug: Y Press Held: 5 (min) Mixing Method: Mud Circ Press: 450 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Mud Data Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 38 (s/qt) Bottom Hole Circulating Temperature: 98 CF) Displacement Fluid Type: Mud PVIYP: 8 (cp)/15 (lb/100ft2) Gels 10 see: 7 (lb/100ft2) Gels 10 min: 9 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 317.00 (bbl) Stage No: 1 Slurry No: 1 of 3 -- -- -- ------ --------- ---------------- ----.-- ---------.---------- ----------------------------------...--------- ---- ----_..---,--------------- -----..-- ------ _.. ----- ------..--- ------ --- Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) Description: ARCO WASH Gmt Vol: 20.0 (bbl) Density: 8.30 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Purpose: Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: CF) Temperature: CF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Printed: 2/4/2002 9:33:35 PM ( (' \ PHILLIPS ALASKA INC. Cementing Report Page 2 of 2 Legal Well Name: CD2-49 Common Well Name: CD2-49 Event Name: ROT - DRILLING Report #: Start: 2 1/17/2002 Spud Date: 1/21/2002 Report Date: 1/30/2002 End: Stage No: 1 Slurry No: 2 of 3 -------------------------- ------ ------------------------------- --------- - -------- -- ----------------- - --------- ------- -------- -- ---------------- -------- ...-------- ------- - -- - - ----- -- --- Slurry Data Fluid Type: SPACER Slurry Interval: (ft) To: (ft) Water Source: Description: ARCO SPACERE Class: Cmt Vol: 50.0 (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: CF) Temperature: CF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) CF) Pressure (psi) (psi) CF) Stage No: 1 Slurry No: 3 of 3 ------------.---------- --- ------------------'------------..- --------------- ---------..---- ---.---------_._------ ------ --- - .. ------~---_._-- -.---.-.- ----------------------------..-- - -------..----.. ..-.---..--- -- - - - - -- -- -.. Slurry Data Fluid Type: LEAD Description: Slurry Interval: 8,891.00 (ft)To: 7,750.00 (ft) Cmt Vol: 40.0 (bbl) Water Source: Slurry Vol:198 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: CF) Temperature: (OF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) CF) Pressure (psi) (psi) CF) Casing Test Shoe Test Liner Top Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 12.50 (ppge) Tool: N Open Hole: 31 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (ft) N Remarks Unable to move pipe once landed in well head - up wt. 325 K unable to break over Printed: 2/4/2002 9:33:35 PM (' ( ~ ...... ,-- -, ~ II..., 1111 II'" ,. ..... - ~ '"t "'~I) Page 1 of 2 Daily Drilling Report I JOB NUMBER i EVENT CODE 124 HRS PROG TMD T TVD I DFS :1. REPT NO. ; DATE CD2-49 I! ODR 8,901.0 I 7,260.0 I 8.92 , 10 ~ 1/29/2002 SUPERVI~~~ ~iCk~L~__n__J~:A~_~;9;~1@QQCO.CO_Q}J5L____¡~~~~-~~_ME~~~~:~----_:~;,;~4.0 DAILY ~~~~,oo ,1J~~::_:_~;.Q...0.- ------ CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTW/O MUD CUM INTANG WI MUD Testing BOPE O.QQ____n___- -------- 0.00--_- 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD LiTH. OLOG~est BOPE - M._ld__~-.- Y!3':' B, }~~:{~,gF :~~~ff~~A"" HRS S",¡Nc.IN'¡pr~~~~~~.L.._- AFE' -- 24.-~ 13~, -- AUT.-H._1'67§..1~_~- -,-' - ~ 14.31 998E01 3,803,379 LAST SURVEY: DATE TMD -----------INC----------~AZIMILAST CASING -- ----}NEXTCASING ---------------LAS:¡'BOP PRES TEST--- ...J1?712QQ~______...§,263.07_____"§~I?Q_____J70.3.1.Q._Lz:oO..Q...(LIJL@ 8,890.0 Cf!L ~4.:500 -Qr!L@---___§_,31~JUf!L- _____J./23/2002 ------- DENSITv(pP9) -1-9.60-----rPI;-ln_----_-~ ECD r--Tñi1UD DAT Å-CDAILY c6STl-----o.oo---~-TcuMCOSTT--o~oò-____n- FV,. PVIYP GELS WLlHTHP FC/T.SOL OILIWAT %Sand/MBT _,Ph/pM ,', Pf/Mf CI.,., .Ca H2S LIME ES 38 8/15 7/9 4.2/10.2 11 I 115.0 8.61 I WELL NAME BHA NO. I 3 I BHA WT. BELOW JARS STRING WT. UP BHA I HOLE CONDITIONS STRING WT. DN STRING WT. ROT BIT NO. 3 TORQUE I UNITS BHA LENGTH ft-Ibf 1,068.71 I.D. CONN SIZE CONN TYPE ~~ - ITEM DESCRIPTION NO JTS LENGTH O.D. Bit 1 1.00 8.500 Navidrill Mach 1XL-AKO 1 23.02 6.750 ----~- __.'n______-------------------'-------- --------- ------ -------- ---..--..-- ---------------- --------- ,--- -- Cross-over 1 2.71 6.750 2.940 -- --..---.---.------ ------------------.---------------- ----------------..--------- -----.--..- ---------- -----.--- ---------------, --- LWD Gamma Res 1 25.89 6.750 1.920 ----~------------"---'-------'-- --- MWD 1 20.48 6.750 1.920 --_._--~-_.._--_._--------_...-_..__..._-------------------- .....----.----- --------- -----. ------- -------- ----------------- Float Sub 1 1.90 6.750 1.920 ---------------------.------------.---------- ----------.. ------------,.------------..--- --------- --------_.'._---~-------"-------- --. - --- ~~ÇSDPJ~_!ex_Collar~_..___----------.._-------_...._~----------------~--- - 88.~.!.- ---____~~9~..?__- ..___~75 --------...--,------______m______u_--- Crossover 1 1.67 6.250 2.250 - HWDP 3 88.34 5.000 3.000 .~---------------------..-----------------~--------------------- ------------- ------...------- ---------- ----_..---~----- -------------..-- ------------- ,- ------ Jars 1 32.38 6.250 2.250 ----------_._----------------_.._---------_..._._----~--_.--------.._------ ..--.------..---------- ..----------..-.- ------------..--- ------------ ...-..-------- ------- -,-----.--. -.. HWDP 23 689.09 5.000 3.000 Crossover 1 1.37 6.500 2.500 HWDP 3 92.05 4.000 2.562 ------- . -----------..----..---____--_m__- BIT I RUN 31 - BITS SIZE MANUF; TYPE SERIAL NO. - JETSORTFA-- 8.800 HUGHES-CHR MX-09DX S34DH 15/15/15/11 - 3 DEPTH IN DA TEINI.O-D-L-B.G.O-R 7,669.0 1/26/20021-2-WT-A-E-I-EC-TD -- BIT OPERATIONS -- BIT I RUN WOB RPM GPM PRESS P BIT. HR5. 24Hr DIST 24HrROP CUM HRS CUM DEPTH CUM ROP -,,----------------------"--"""------"--- ----------------,,--_.- _____n_--___- -----..-..----..--- ----------------.----...----------'------ ..._-------- '---'------'-- --'---------------- -------- ..-...------ 3 I 3 25 I 35 182 1282 546 2,980 988 56.40 32.20 1,851.0 57.48 ------------- ..------- ._L_____- ---------- ----....--.--- ------ --..-- ---- ---.--- ..----------- ----- -----.. -, -- - ,-, ------ - - --------,----------",------"-----""-----'--" --------~.. .......:..._~- ------'-"--- -------.._~'-- -..---.,,--..---..--- -_.._----_--_....9fJ: ~_~J~QN§__§J~:LM M~ R Y.."-----,------_c----"""--,,,,,,----,---,,------,,""':..---.....--.--..-..-------.---..----..-----.-...--.--...-----... ..!ROM --_"TO:...__~~U~~-- _.__s.~E~__- !ROU_~~~__~~~B_____~HAS§..___----_._-----_.-C.-,-----c_-----~..BE~..c~~.!~_~!'L..___._---------_.._..__.- - .. 00:00 02:00 2.00 DRILL P TRIP INTRM1 POOH F I 3706' TO 1 068 I (B H A) - m 0 nit 0 r well @ 2493' --- ----- ------ ---------...- ---------------.---.- ---_...__--m" ... 02:00 04:00 2.00 DRILL P TRIP INTRM1 POOH wI B H A - L D M W D, mot 0 r, & bit - m 0 nit 0 r w ell - static -----...-------- OTHR INTRM1 Pull we arb u s h i n 9 - set t est pi u g - C h a n get 0 p pi pe rams to 7" & test to 5000 psi - pull test plug - set thin wall wear bushing RURD INTRM1 Rig up tor un 7" cas i n g - He I d P J S M RUNC INTRM1 Run 7" 26# L-80 MBTC csg 217 its. - landed wI s hoe @ 8891' FC @ 8806' - Circulate bottoms up @ 2486', 5088', & 7337' - worked through tight s --- --- --.---- 04:00 06:30 2.50 DRILL P 06:30 08:00 1.50 08:00 20:30 12.50 CASE P CASE P Printed: 2/4/2002 9:39:24 PM (' t " .... ..... ..... '- - -, ~ ¡1M II tI p! l' ... --.. ~ ~~ " íJ) -.,- Page 2 of 2 CD2-49 Daily Drilling Report i JOB NUMBER I EVENT CODE ¡ 24 HRS PROG I TMD ITVD IDFS I REPT NO. i DATE I I ODR I I 8,901.0 7,260.0 8.92 i 10 11/29/2002 WELL NAME .--.--. -- 22:30 00:00 OPERATIONS SUMMARY PHASE: IINTRM1 pot s f I 8238' to 8470 I INTRM1 RD tongs & fill up tool - install cement head - rig up cement line -1----.-- INTRM1 Circulate and condition for cement job - held PJS M ...--.-- ---- ----- -~._---_.._- -----_. -----..---. ._---_._-_.._-~-----...- 1.50 CEMENT F PUMP INTRM1 C e men t 7" cas i n g P u m p e d 5 b b I s Arc 0 was h - t e st lines to 3500 psi - pumped 15 bbls Arco wash - pumped 50 bbls Arco spacer @ 12.5 ppg - drop btm plug - mix & pump 40 bbls cmt slurry @ 15.8 ppg (198 sks) - drop top plug - pumped 20 bbls w ater - switch to rig pumps & displace wI 9.6 ppg mud @ 5 bblsl min 24 HR SUMMARY: Finish POOH - LD BHA - Prep to run 7" csg - Run 217 jts. 7" 26# L-80 MBTC csg - Circ & cmt FROM TO HOURS CODE TROUBLE SUB 08:00 20:30 12.50 I CASE P RUNC 20:30 21 :00 0.50 CEMENT F RURD DESCRIPTION ---- .. 21 :00 22:30 1.50 CEMENT F CIRC . PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY Phillips 2 Sperry Sun Doyon 27 DSR Baker Inteq 2 ACI - ---....--.--..-------- -----.. - -~ Drilling Flui~_- 3 FMC Dowell 2 GBR .---.--------...--------- ------------------...------ -------- ------ --------- . . . . SERVICE NO. HOURS 2 4 5 --- ------------- --.--..-".... . -....---....--..- -.. .. -. . 1 1 .--------.-...--... .-------- --.---------..------- ---....------....- ----.-...-...........---- _'__0.-_-_____0___-_'-_-___"0'_--_------ _--__0___- ----"-------------------'--------"-'..-....... " , MATERIALS I CONSUMPTION , ' ;;~~~j---~:~_~~~~ter, ~:::- ~- I ÜNJ~~ j~G:of~~-- - --'-' -- __-0- ~ ---"- '- ,,---- .., ------"- ,--"'--- , 'SUPPORT CRAFT ,TYPE NO. REMARKS TYPE CD2-45 299 CD2-49 -'---'_'__"_0_--.. NO. , . REMARKS Printed: 2/4/2002 9:39:24 PM (' ( Page 1 of 2 Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG TMD TVD DFS I REPT NO'1 DATE CD2-49 I I ODR 8,901.0 7,260.0 9.92 I 11 I 1/30/2002 SUPERVISOR ¡ RIG NAME & NO. ! FIELD NAME 1 OCS NO. AUTH MD DAILY TANG I CUM. TANG _____Don Mick~L_____1 d--oy'Qn1@~~çQ.com 1~____.__Lj~__--- Alpine -- -- 1~,874.0 0.00- I O.OO_--~- CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTWIO MUD CUM INTANG WI MUD __Dri!li.r"1fL§.1/8" hole @ 8928'_____------------------ _____00______------ ----- 0.09.._____----- 0.00_---- _24 HR FORECAST '--- n_____Ç).'r.il!.~U/8~'EhO,le -----------1:----- DATE ~~lLA~;9~~; MEE=N__::AILY_~:~~L6'329 --------------~~: CO~~:; ~-~, ~?_-- LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE AUTH. --------- ----- -------- - ---------------- _____14.31 -- 998E01 - ___~~!.379._._- LAST SURVEY: DATE TMD INC AZIM ]LAST CASING NEXT CASING LAST BOP PRES TEST ___Jj27/20_Q.~--_---____§.,2~3.0L___- 55.720 -_J}O~:L1Q...-- _.JßOO Q!}L@ 8,890.0 ft 4.500 Ü!JL@ 8,314.0 @ _....1!30~_9_Q.~___- WELL NAME -------------- ------------ ----- ---- --------- DENSITY(ppg) FV PVIYP 38 8/16 9.60 PP GELS WLlHTHP 6/9 7.4/10.8 ECD MUD DATA DAILY COST FC/T;SOL OILIWAT %Sand/MBT Ph/pM 11 I 115.0 9.61 0.00 LIME ES BHA NO. 4 BHA WT. BELOW JARS STRING WT. UP BHA I HOLE CONDITIONS - STRING WT. DN STRING WT. ROT TORQUE / UNITS - ITEM DESCRIPTION NO JTS LENGTH O.D. Bit 6.125"STR386 PDC 1 0.75 6.125 Turbo-Back Stab 1 0.83 4.750 ---------------------------------------..-------------- ----------- -------- -------- -------------- -------- ------.._--- ---------- Navidrill Mach 1X 1 20.64 4.750 -----------------..------------------------------------------------------ -- -------- -- --- --------...- -------------- ------------- ---- ----.. ......- ---.. -- NM Stab 8.5" 1 3.70 4.750 2.375 ---------- -------------..------------------------..----..----- ----- LWD Gamma R_~L______-------------- -------------~---- -__?_~.50 __.-!?50_____1..:..~0 ------------- MWD 1 19.42 4.750 1.250 ------------------..-----------------------..------------- ---------------- ---- ---------- ------------- ------------------- -,- - Hang-off Sub 1 11.22 4.750 2.815 ---------------...-..-------------..------------ ---..----------- - -- Non-mag Flex Collars 3 93.14 3.500 2.375 ------------------..- ------- --- -- ---- ------- --"----'---'------ Crossover 1 1.20 5.250 2.500 -------------------------------------.....------------------- ----..----------- ---- Heavy ~~ DrilL!:ipe -------------_.._-------------------------~----- 92.05 ______4.0°Q.....______~56~..____-----_.._------------- ..- Jars 1 32.00 4.750 2.250 Heavy Wall Drill Pipe 2 61.35 4.000 2.562 I.D. 360.80 CONN SIZE CONN TYPE - ------- ------....---------- ..-- BITS BIT I RUN 41 4 SIZE MANUF. TYPE 6.125 HUGHES-CHR STR386D JETS OR TFA 15/15/15/15/1 DEPTH-IN-..DATE'IN I~O-D.L~B.G~O-R 8,901.0 1/30/2002 0-2-WT-G-D-1-CT-TD WeB --"'~ -~-",---------,---'----"-------_._--- ------, P~_M.P...LH ,(QJ~A~ L!Ç D A T A- -'-,----'-'---,-- ,"",--'--- ._--~--'----,----------.._-- NO. MAKE OF ~~~~-------,--_____STROK!(in) _.l:I~_ER(i~ ~-~"-...E(gpm) - PR!SSjpS9- TOTALQ ~ILL SPM -'-~~~~~UR~..--- 1 Continental Emsco 12.000 6.000 43 180.00 1,240 180.00 ..--------------- ------- --- 00:30 01:00 0.50 01:00 03:00 2.00 03:00 04:00 1.00 04:00 09:00 5.00 ------------- ---------- ------- ------ ----.. -,-------.-.--,--- -----",.._-"--------,----,-OPER~IJ9N§J)UIV!MA...RV:_-,-___--,-,.._--------- - - -'-----..----."-----"------------- FROM -~- HOUR~__~_~)D~ TI~p~"~~¥._~UB~__- P~ASE- ----'---------~---'- - DES_CRIPT~~- - ---.....------------ - 00:00 00:30 0.50 CEMENT DISP INTRM1 Fin ish d i s P I a c in g c em e n t pup m i n g 5 b b I S I m in @ 8 00 psi - bumped plug wI 1600 psi - floats held .. ------------- --------------- C _I P @ 0 0 2 5 h r s . ---- ----------------------- CEMENT PULD INTRM1 Rig do W n c m the a d - L D I and i n g j 0 in t DRILL P OTHR INTRM1 Flu S h s t a c k - pull t h in wall we arb u s h i n g - Set & test pack off to 5000 psi BOPE INTRM1 Set t est p lug - c h a n get 0 p pip era m S b a c k t 0 3 1 1 2" X 6" VRB PJSM BOPE INTRM1 T est BOP E - Pip era m s, c h 0 k e man i f 0 I d val v e s, k WELCTL P WELCTL P Printed: 2/4/2002 9:37:13 PM (' ( ~ ....... ,- - '- ~ ;JHILLIPS l' ( ~~ "Aot ) Page 2 of 2 '.J ..... Daily Drilling Report WELL NAME I JOB NUMBER I EVENT CODE 124 HRS PROG ITMD ITVD DFS I REPT NO. [DATE CD2-49 I i ODR 8,901.0 7,260.0 9.92 11 .. 1/30/2002 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 04:00 09:00 5.00 WELCTL P BOPE INTRM1 ill & choke Ii n e valves, f 100 r & top d r i ve valves, b I i n d ram s to 250 psi low & 5000 psi hi g h - t est H y d r i I to 250 psi low & 3500 psi hi g h - Witnessin g of t est waived by AOGCC - pull t est pi u g - set we a r bushinø - b I ow down kill & choke Ii n e s ----- ------------- --------------- ------ -------- ----- ------- - ---------- ---------- -- ---- -- - 09:00 13:00 4.00 DRILL P PULD PROD PU b a ¡Is & elevators - pj S M - PU 6 1 18" BHA - M U MWD - orient motor & MWD - RIH to 361' - s h a I low t est MWD -1------- __n__--_- --------- ------ - ---- ------- 13:00 16:00 3.00 DRILL P PULD PROD RIH wI 6 1 18" bit to 3509' - PU 99 j t s. 4" d rill pi pe fI pip e shed 16:00 18:00 2.00 DRILL P TRIP PROD S lip & cut d rill Ii n e - service top d r i v e 18:00 20:30 2.50 DRILL P TRIP PROD Continue RIH fl 3509' to 8694' 20:30 21:00 0.50 DRILL P OTHR PROD Tag up @ 8694 - C/O cmt stringers to 8757' 21:00 22:00 1.00 DRILL P CIRC PROD Circulate bottoms up for csg t est 22:00 23:00 1.00 DRILL P OTHR PROD Rig up & t est 7" casing to 3500 psi for 30 m ins. 23:00 00:00 1.00 DRILL P OTHR PROD CIO cmt fI 8757' to 8804 ' - d rill wi per pi u 9 s fI 8 804 ' 24 HR SUMMARY: Displaced cmt - Set & tested pack-off - Tested BOPE - MU BHA & RIH - S&C drill line - test csg - C/O cmt fl 8757' to 8804' - Drill up wiper plugs @ 8804' - ------ -- -. -- -- -- -- - ---------- ---- -- PERSONNEL DATA -- -- -- ..--------c"-----------------.o...--.---.----------_o--'.....--"-------------.--...--- ..--..----..""---"--- -----:........:-..--..-- -'.--"""-'-"""""""'"-"'-'-"'-'0-"""'0__- .---..---.....---_o_---,-------'C"---..--------- -..--.---..------- _0--".._.--__--0..----__..---- ---_o,-_CO~~~~~-----_._----- SERVICE NO. _.~?.~~~~. ._._._--.--._------.C~~_ \N~____.._-,,---- -- SERVICE NO. HOURS ----.------""- -"'--".--...--.......----...-----..-.--.----- -_...-----..-,,--._--- _._-----------_._-,,---0'_"0-_""'---__---0-"------ --""""",..------- ..---"..-.,,-- -- ...... Phillips 2 ~perry S~~------ 2 ----- -------------------------------.---- ---,,-_..-.."--- ---- -------------- ------ -------.--- ." Doyon 25 DSR 4 --..---- Baker Inteq 2 ACI 5 ------------.- -----------..-..-----.---.---------- -------- ------- -- -------------- MI Drilling Fluids 3 Tech limits 1 -- ----- ---- --------- ------------ -------- ------------------ Dowell 2 -- MATERIALS I CONSUMPTION ITEM -- UNITS USAGE ON HAND ITEM UNITS-- USAGE ON HAND Fuel 2,295 -22,925 Water, Potable 90 -1,092 Water, Drilling 1,325 -5,769 SUPPORT CRAFT TYPE NO. REMARKS TYPE NO. REMARKS CD2-45 1,342 CD2-49 Printed: 2/4/2002 9:37:13 PM Well Name: CASING TEST and FORMATION INTEGRITY TEST Date: CD2-49 1/30/2002 Supervisor: D. ~lckey Reason(s) for test: D Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC X 7" 26# L-80 BTMC Casing Setting Depth: Toe 7,750' TMD 6,772' TVD EMW= 2,494' TMD 2,384' TVD Hole Depth: Used cement unit Ria pump used 700 psi 600 ps' 500 psi w . a:: 400 pSI => U) U) w a:: 300 psi a.. 200 psi 100 psi Mud Weight: 9.6 ppg 5,256' Length of Open Hole Section: Leak-off Press. 0.052 x TVD 496 psi 0.052 x 2,384' + Mud Weight + 9.6 ppg = EMW for open hole section ::: 13.6 ppg yes #<2 Pump output = bbls pumped Fluid Pumped = 9.0 bbls Fluid Bled Back = 0.0 bbls I ;1 ~ LEAK-OFF TEST ~CASING TEST ...... LOT SHUT IN TIME -..-CASING TEST SHUT IN TIME -+- TIME LINE 10 20 30 BARRELS 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE r--------------T------õ------ -r----Õ--p-s¡----1 I I I I r---------- - -----r---- ------- ----r----------------., I : 0.5 I 0 psi I ~---------------+---------------~-----------;-----I I : 1.0 I 5 pSI I ,---------- ------'--------------- - ~-------- --- -----.4 ! ! 1.5 ! 10psi ! t---------------"""---------------~----------------" ! ! 2.0 ! 15psi ! r---------------r---- ---------- -r-------- ---- ----., I : 2.5 ; 20 psi : ~-------------__+___n______----~------------;-----I I I 3.0 : 40 pSI : '----------------'-------- - -------~ --------- --- -- --.4 ! ! 3.5 ! 66 psi ! r -- - - - -- -- - ---- T- ---4 ~ õ- - - -- T --:f;fõ np- sr-1 1----- ----------+--------------~-----______n- --4 I : 4.5 : 217 psi: ~------------ --+------ ___n__~___------- ---.----1 I : 5.0 : 268 pSI: ,--------------......------ ----- - --~ --------- ---- - -_.4 ! i 5.5 ! 313 psi! t-----______n--"""____-----------~------------- - --.. ! ! 6.0 ! 389 psi! ,...--------------r------ ----- ---r------------- ---., I I 6.5 : 444 psi I }---- ----------+------ ----- ---~ -------------.- ---I ; : 7.0 : 496 pSI I r--------------I-----7 ~ S-----I---3"š-gf)Sf--1 t---------------...,..------ ---------~ n______- ---- ---.. ¡ ! 8.0 ! 369 psi! r----------------r--------------r --------- ---- ---., : : 8.5 : 353 psi: ~----------- --- -+------- ----- ---~ -------------.----1 I I 9.0 : 338 pSI I '----------------'---------------~----------------.4 ! ! 9.5 i 323 psi! ¡---------- ---- r---1 õ~õ ----1- --2"fffpsr-l r----------- -----r---------------r------------- ---., : I 10.5 I 278 psi I ~-------------- +------ --------~-----------------I I I I I I I I I ,----------------".............................4................................1 I I I I I I I I ! I ,_~ ¡ SHUT IN TIME! SHUT IN PRESSURE r----------- -----r--------- -----r ------------ -----. : 0.0 min ; I 278 psi i I-----------.----+---------------~---_____--n_.----I I 1.0 m¡n I ; 232 pSI I '----------------'--------------- -~------- ---- - ----.4 ! 2.0 min ! ! 217 psi! t------------------______n__n~_____-----------" ! 3.0 min ! ! 202 psi! r--- -------- ---- -r---------------r ----------- -- ---., I 4.0 min I : 197 psi I ~-----------.---- +------ - --------~- -------- - ---.----1 I 5.0 mm I : 187 pSI I ,--------- - -----'-------- --- __n_~ ------------- ---.4 ! 6.0 min ! ! 187 psi! t---------------...,..----------- --- - ~----------- - ----.. ! 7.0 min ! ! 182 psi! ""'----------.--- --r--------- -----r ------------- ---., I 8.0 m¡n I I 182 psi I ~-----------.--- -+------___--__n~ --____--_n_-.----I I 9.0 m¡n I I 172 pSI I ,----------------'-------- --- ---- -~------------- ---.4 1..:_9.: Q_~l!!_l____------ - -_-_L-~-~.? -p.~.i---l 60 8PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE r--- ------ - --- - r--õ-s tï< š---T -----f-p-šT - --1 I I I I r---- -- ---- - ---- .,..------- ------ -.,.. _--n___- - --- - --~ I I I I I I I I ~---- ------ - --- - +------ - --- -- --+- -------- - --- - --t I I I I I I I I ,----- - ---- - ---- --__n_- - ----- ---- --------- - ------ 4 I I I I I I I I I I I I .---- ------ - --- - ...,...------- ------ -...,... - ------- -- --- - --~ I I I I I I I I I I I I r-__n- ---- - --- - .,..------ - --- ----.,.. --------- - --- - --~ I I I I I I I I ~----- - ------ - -- +------- --- ---- +--- ------ - --- - -- t I I I I I I I I "__n_n- ---- - -----______n- - --- ----- ------ - - - ---- 4 , I I I , I I I , I I I .-_n- -- ---- - - --...,... -------- - ----- ...,...--- -------- - ---- ~ I I I I , I I I , I I I r------ - - --- - - --.,.. -------- - --- - - .,..--- __--n__-----~ , I I I ~__n_--- --- ----+ -------- - --- - -+-------- --- - ---- i I I I I , I I I "----------- - ----'--------- - ---------- -------- - ____4 I I I I I I I I I I I I .----- -- - __n--_""'" -------- - ---- -...,..._____n- --- --- --~ I I I I I I I I I I I I r---- --- - - -- -- --.,.. -------- - --- --.,..-------- ------ --~ I . I I I I I I ~----- -- - --- - - --+ -------- - --- - - + __--_n___- -- ---t I , I I I I I I "___n_- --- - -- - --- -------- ---- ---- --- ----- --- - -- --4 I , I I I . I I I I I I .------- - - -- - - --...,... -______n__- - -...,...-------------- --~ I , I I I , I I I I I I r------- - --- - ---.,.. ___n__- ---- --.,..-------- ----- ---~ I I I I I I I I ~------- - --- - ---+ -------- - __n- +----------- -----t I I I I I I I I "----- - --- ------ ---------------- ____n_--_---- --4 I I I I I I I I I I ! - _-.! ~ ! SHUT IN TIME! SHUT IN PRESSURE r------- ----. ----.,..---------------,-- ------- ---:-----~ I 0.0 mln : I 0 pSI I ~---- ---- ---: - ---+-____--_n__- -+ - --------- --- _nt I 1.0 mln : I : "------- - - -- - - ---------------- - --- -------- - --- -- --4 ! 2.0 min ! ! ! .---- --- - - -- ----...,..._____n- ---- - -...,... - ------- --- --- --~ ! 3.0 mín ! ! ! r---- --- -- -- ----.,.. -------- ----- -.,.. - ---------- -----~ ; 4.0 mín : I : ~---- ---- -- -. _n_+____----- --- - -+ ----------------t I 5.0 mln I I : "--------- -- __n-- ------------- --- -------- ---- -- --4 ! 6.0 min ¡ ! ¡ .------- - --- ----...,...------------- -...,... - ------- ------ --~ ! 7.0 min ! i ! r----- -- - ---- - --.,.. -------- - --- - -.,..--- -------- - ---- ~ I 8.0 min : I I ~----- - -- ---:-- -- +-------- -- - - -- +--- ___n_- - -----t I 9.0 mln I : I "----- ------- - ---'- -------- - --- - -.... - _n___- --- - ---- 4 ! 10.0 min ¡ ! ! .---- --- - --- -- --...,...--------------...,... - ------- ---- - - --~ ! 15.0 min ! ! ! r----- -- - --- ~ ---.,..--------- --- - -.,.. - ------- ------ --~ I 20.0 mm : I : ~------- ----~ - --+ --------- --- - -+ - _--n_n______-t I 25.0 mm : I I "-------- --- - - ---'- -------- - --- - -.... - ------- --- -----4 I 30 0 . I I I L----;-- _I]]! ~-1--------- --- - _1- ------------ ---1 -~ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Re: CD2-49 packer placement at Alpine (' f D t " d-'1 Cj ~ Subject: Re: CD2-49 packer placement at Alpine Date: Mon, 28 Jan 2002 12:42:24 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Vernon T Johnson <vjohnso1 @ppco.com> Vern, Sorry, t was out of town. Yes, it is acceptable to use the rules as developed for CD2-15. Tom Maunder, PE AOGCC Vernon T Johnson wrote: > Tom, > We are currently drilling CD-49, a horizontal injector. > Some of the same issues exist with respect to packer placement, so we would > like to use the same packer placement "rules" as used on CD2-15. Please > confirm whether or not this is acceptable. > > Vern Johnson > 907-265..6081 (w) > 907..265-6472 (fax) > 907-242-8157 (Cell) > 907-267-0566 (pgr) > vjohnso 1@ppco.com > ----- Forwarded by Vernon T Johnson/PPCO on 01/24/2002 10:28 AM ---..- > > > > > > > Company > > > > > Vern, Cliff, Chip and Dave(?), > Below is the wording I have proposed to the Commissioners with regard to > "raising the packers". Your proposal for CD2-15 is acceptable. > Tom Maunder, PI: > AOGCC > > 1. Phillips is allowed to determine the placement of injection well packers > such that the angle at their tailpipe nipple is about 60°. > 2. The packer depth cannot be more than 200' tvd above the top of the > Alpine. > 3. Phillips shall pump sufficient cement to place cement a minimum of 500' >md > above the top of the Alpine or 1.5 times the distance from the top of the > Alpine to the proposed packer depth which ever is greater. Normal excess > volume factors shall be added to the calculated cement volume. > 4. Phillips may run the Cement Evaluation Log after running the completion, > however nothing in this rule precludes them from running the log prior to 1of3 Tom Maunder <tom_maunder@admin.state.ak.us> 10/19/2001 04:39 PM To: Vernon T Johnson/PPCO@Phil/ips cc: Clifford L Crabtree/PPCO@Phillips, Chip Alvord/PPCO@Phillips, Doyon 19 Man/PPCO@Phillips Subject: Re: CD2-15 packer placement 1/28/02 12:46 PM Re: CD2-49 packer placement at Alpine "- ( ~. > running the completion. > 5. If analysis of the evaluation log does not give confidence that > sufficient > isolation has been achieved, Phillips will need to demonstrate external > isolation using other methods or perform remedial operations to achieve > satisfactory isolation. > > Vernon T Johnson wrote: > > > Tom , > > As discussed, here are the details regarding the calculated cement top > and > > proposed packer setting depth. Based on our conversation, the packer > > setting depth be/ow corresponds to the highest depth we would place the > > packer. We may run the packer slightly deeper than this. » > > Casing: 7" 26 ppf in 8-1/2" open hole > > 7" casing shoe: 9829' > > Float collar: 9743' > > Top of A/pine: 9609' > > Estimated TOC: 8985' (30 bbl pumped, assumed 1.4 OH excess) > > Proposed packer depth (2/3 of the distance between the TOC and the top of > > A/pinel leaving at least 1/2 as much cement above the packer as there is > > between the packer and the top afthe Alpine) > > 9193' (54.0 deg inc, 7005' TVD, 416' MD from the top of the > > A/pinel in the HRZ with +/.. 208' of cement above it. > > End of tbg tail: 9307' (58.2 deg inc., 7069' TVD) » > > Let me know if this is sufficient. It so, I will let the rig know that >we > > can adjust our packer setting depth. » > > Vern Johnson > > 907-265-6081 (w) > > 907-265-6472 (fax) > > 907-242-8157 (Cell) > > 907-267-0566 (pgr) :> :> vjohns01@ppco.com > (See attached file: tom_maunder. vet) . ~~ Maunder ~tom ~:-~~~;admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission l______--- ---. 2 of3 1/28/02 12:43 PM ,,( d. \ ~V~VŒ ffi)~ !A\~~~æ!A\ ~.. ALAS KA. 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. ¡n< AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Vern Johnson Drilling Engineer Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 Re: Colville River Unit CD2-49 Phillips Alaska, Inc. Permit No: 201-249 Sur. Loc. 2053' FNL, 1504' FEL, Sec. 2, TIIN, R4E, UM Btmhole Loc. 2043' FNL, 2377' FWL, Sec. 11, TIIN, R4E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Atmular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on CD2 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pennit . to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; . and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test ~ Permit No: 201-249 January 8, 2002 Page 2 of2 /1,' ( <t o~ before operation, and of the BOPE test perfonned before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ( ~(kU' ~~ C:nmy Oec~sli Taylor Chair BY ORDER OF THE COMMISSION DATED this 8th day of January, 2002 jjc/Enclosures cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. <" ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ðl4H- t I s/ùr 1a. Type of Work Drill X Redrill 1b Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry Deepen Service X Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (OF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 52' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchoraqe, AK 99510-0360 ADL 380075 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 MC 25.025) 2053' FNL, 1504' FEL, Sec.2, T11 N, R4E, UM Colville River Unit Statewide At target (=7" casing point) 8. Well number Number 603' FSL, 964' FWL, Sec. 2, T11 N, R4E, UM CD2-49 #59-52-180 At total depth 9. Approximate spud date Amount 2043' FNL, 2377' FWL, Sec. 11, T11 N, R4E, UM 01/12/2002 $200,000 12. Distance to nearest 13. Distance to nearest well 14, Number of acres in property 15. Proposed depth (MD and TVD) Property line CD2-47 11874' MD 2053' FNL See 2 feet 18.5' at 475' MD Feet 4397 7281' TVD feet T11 N R4E 16. To be completed for deviated wells 17. Anticipated pressure (see 20 MC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 89.7Q Maximum surface 2560 psig At total depth (TVD) 3271 at psig 7229' TVD.SS 18. Casing program Settina Deoth size Specifications Too Bottom Quantity of cement Hole Casinq Weiqht Grade Couplinq Lenath MD TVD MD TVD (include staqe data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' 10 cu yds Portland 3 Gmt 12.25" 9.625" 36# J-55 BTC 2463' 37' 37' 2500' 2389' 534 Sx Arcticset III L & 230 Sx Class G 8.5' 7' 26# L-80 BTC-M 8836' 37' 37' 8873' 7266' 147 Sx Class G N/A 4.5' 12.6# L-80 IBT-M 8282' 32' 32' 8314' 7130' Tubinq 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural RECEIVED Conductor Surface Intermediate Production Liner DEC 2 1 2001 Perforation depth: measured true vertical Alaska Oil & Gas Cons. Commission 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch l\nCnorage:>riliing program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed A~A_~.f O/{~ Title Drillinq Team Leader Date t 2-(2. I (0 ( .... '-.. Commission Use On Iv Permit NU~/-Z ,-/e¡ I API numbe3 2 ~ I I Approval date ' Ii 'ak See cover letter for 50- 10- o. 0 Other reQuirements Conditions of approval Samples required Yes ~: Mud log eq~lred Yes @ Hydrogen sulfide measures Yes @) Directional survey required ".~ No Required working pressure for BOPE 2M 3M G 10M ,15M , d Other: 'Test-- ßprt:- +0 50170 fU) ~ t ~UA1, Iii fa] r€1'UVl(: .fJl 'J: T. Original Signed By by order of , ~ ()~ Approved by - ... , ,. Commissioner the commission Date Form 10-401 Rev. 7-24-89 .. ,Subrt it in triplicate ORIGINAL ( ( CD2-49 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/411 Hole / 9-5/8' Event Conductor Broach Well Collision Gas Hydrates Casin Interval Risk Level Low Low Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVO Lost Circulation Low Low 8-1/2' Hole /7' Casin Interval Event Risk Level Abnormal Pressure in low Surface Formations >2000' TVO Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low M iti ation Strate Monitor cellar continuous! durin interval. Close a roach olicies, ro sin Ie shots. Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Oiverter drills, increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries M iti ation Strate BOPE drills, Keep mud weight above 9.3 ppg. Check for flow during connections and if needed, increase mud wei ht. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheolo ,lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted swee s. Well control drills, increased mud weight. No mapped faults occur within 700. of the planned wellbore. H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1/8' Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir . Pressure Medium Hydrogen Sulfide gas Low M iti ation Strate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheolo ,lost circulation material Reduced trip speeds, Pump out to T shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. BOPE drills, Keep mud weight above 9.2 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGIN,AL l ( £ \ Alpine: CD2-49 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 16. 17. 18. 19. 20. 21. 22. Procedure Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. (Directional only MWD) Run and cement 9 5/8 inch surface casing. / Install and test BOPE to 5000 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. t() (. Drill 8 Y2" hole to the intermediate casing point in the Alpine Reservoir. (LWD tools: dir/GR/Res) Run and cement 7;n,ch casing as per program. Top of cement +1-700 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" x T' casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. y 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. ý" Drill 6-1/8' horizontal section to well TD (LWD tools: dir/GR/Res). 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 4-1/2' 12.6 #, L-80 tubing with lower gas lift mandrel, DB nipple, and production 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 psi 130 min. Set BPV and secure well. Move rig off. ORIGINAL ( ( Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CO2-24 will be the closest well to CO2-49, 19.7' at 400' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 17.7' at 400' 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 to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpina Operations: Incidental fluids developed from drilling operations on well CD2-49 will be injected into a permitted annulus on CO2 pad. The CD2-49 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 20001 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..49 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 USDWls 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 below the base of the Schrader Bluff Formation (C-40). These 450-500. 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) * (2389') + 1 ,500 psi = 2,991 psi = 1,081 psi Pore Pressure Therefore Differential = 2991 ' 1081 = 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 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8' 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2.992 psi 7' 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi 7,240 psi 6,154 psi ORIGINAL (' ( CD2-49 DRILLING FLUID PROGRAM SPUD to Intermediate hole to T Production Hole 9-5/8' surface casing casing point' 8 Y2' Section' 6 1/8' point' 12 %' Density 8.8' 9.6 ppg 9.6' 9.8 ppg 9.2 ppg PV 10' 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 i n 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 wellbore 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. ORIGINAL ( ( Colville River Field CD2-49 Injection Well Completion Plan 16" Conductor to 114' Updated 12/19/01 4-1/2" Camco DB Nipple (3.812" 10) at 2000' TVD = 2039' MD A1 Injection Valve (2.125"10) - to be installed later 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2500' MD 1 2389' 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 1ST Mod. R3. tubing run with Jet lube pipe dope Tubing Supended with diesel TOC @ +1- 8018' MD (+546' MD above top Alpine C) ...~.~.~.~..... ~~............. "".... ~-~"""'" Top Alpine C at 8564' MD 1 ""------..------------------ 7223' TVD Completion .MQ ]]lQ Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB Nipple 2039' 2000' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" 10) 8090' 7009' 4-1/2" tubing joint (2) R3 S3 Packer (c/w handling pups) 8200' 7073' 4-1/2" tubing joint (2) R3 HES "XN" (3.725" 10) - 61.7° 8302' 7125' 4-1/2" 1 0' pup joint WEG - 62.2° 8314' 7130' Camco KBG-2 GLM (3.909" ID) & 1" dummy valve 'i¡:~i¡~~mr,~~.... Baker S3 Packer at +/- 8200' l<200' TVD above toe Aleine ) ~"'" .-.~~..... ......-----.------.-.-. Well TD at 11874' MDI 7281' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8873' MD 17266' TVD @ 89.7° ORIGINAL ( ( Colville River Field CD2-49 Injection Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' Updated 12/19/01 4-1/2" Camco DB Nipple (3.812" ID) @ 2000' TVD = 2389' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2500' MD / 2389' TVD cemented to surface (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 4-1/2" 12.6 ppf L -80 IBT Mod. tubing run with Jet Lube Run'n'Seal pipe dope (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-1 0 ECP (anchor) - Muleshoe / Entry Guide (C) Open Hole Bridf;Je Plug Assemblv - Baker Payzone ECP (cement inflated) -XC -Float Collar - 4-1/2" Float Shoe TOC @ +1- 8018' MD (+546' MD above top Alpine C) ....................... """, """"..' , "'... , '..........-- Camco KBG-2 GLM (3.909" 10) & 1" dummy installed, set 2 joints above Packer ,¡:r~~t>-....,~aker 83 Packer set at +/- 8200' " ""-... Well TD at 11874' Me I 7281' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8873' MD /7266' TVD @ 89.7° ORIGINAL (' ( CD2-49 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting F ractu re Pore pressure ASP Drilling (in) Depth Gradient (lbs. I (psi) (psi) MDfTVD(ft) qal) 16 114/114 10.9 52 53 95/8 2500 I 2389 14.5 1081 1562 l' 8873 I 7266 16.0 3288 2560 N/A 11874 I 7281 16.0 3295 N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTJ.ÇpATED 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]0 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 0 = 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} 0 = [(10.9 x 0.052)' 0.1] x 114 = 53 psi OR ASP = FPP' (0.1 x D) = 1081 ' (0.1 x 2389') = 842 psi 2. Drilling below surface casing (9 5/8') ASP = [(FG x 0.052)' 0.1] D = [(14.5 x 0.052)' 0.1] x 2389 = 1562 psi OR ASP = FPP' (0.1 x D) = 3288' (0.1 x 7266') = 2561 psi 3. Drilling below intermediate casing (1') ASP = FPP' (0.1 x D) = 3288' (0.1 x 7281 ') = 2560 psi ORIGINAL f ( Alpine. CD2-49 Well Cementing Requirements 95/8' Surface Casing run to 2500 MD /2389' TVD. Cement from 2500' MD to 2450' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2450' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: System: Tail slurry: System: (2450'-1558') X 0.3132 felft X 1.5 (50% excess) = 419.1 fe below permafrost 1558' X 0.3132 fe/ft X 4 (300% excess) = 1951.9 fe above permafrost Total volume = 419.1 + 1951.9 = 2371.0 ft3 => 534 Sx @ 4.44 fe/sk 534 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 fe/sk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% SO01 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 fe/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 fe 1ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 fe/sk 230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % SO01 accelerator @ 15.8 PPG yielding 1.17 fe/sk 7' Intermediate Casing run to 8873' MD /7266' TVD Cement from 8873' MO to +/- 8018' MO (cement 546' above packer depth) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (8873" 8018') X 0.1268 felft X 1.4 (40% excess) = 151.8 fe annular volume 80' X 0.2148 fe /ft = 17.2 fe shoe joint volume Total volume = 151.8 + 17.2 = 170.0 fe => 147 Sx @ 1.15 fe/sk 147 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk ORIGINAL 1 By Weight Of mix Water, all other additives are BWOCement C ::x:J - - ~ - - ~ r-- Created by "",ichael For: V Johnson Date plcHed 17-Dec-2COí ?Ict 'eference is CD2-49 Vers;o~#8. Cocrdinotes ace in 'eet refereoce slot #49. Vertical Depths ace referecce RK3 (Doyon ~"",,..-- "~ . FiT!'!) Phillips Alasl-{a, Inco Structure: CO#2 Field: Alpine Field Well: 49 Location: North Slope, Alaska ~~~~ ----- Point ----- KOP EOC Begin Drop EOO VI/est Sak KOP Bose Permafrost EOC C-40 9 5/8 Casing C-30 C-20 K-3 K-2 Aioian-97 Albian-96 Begin Fnl Bld/Trn HRZ K-j LCU Miluveacn A A!Dine D }\!oine C : ' Taroet-EOC-Cso pt . J J TO - Cso pt . mnnnm..nnnm.mnnmnnnmnd-mm..nnn.mmn.nnmnmnnnm MD 300.00 550.00 800.00 í 050.00 1067.59 í í 00.00 1557.96 2209.67 2299.76 2499.54 2511.51 2655.06 4247.36 45 Î 5.33 4943.61 6332.53 7383.39 7835.54 8126.99 8288.13 8467.43 8522.44 8564. í 2 8873.31 ! 1873.67 .00...._.00...00.........00............' PROF!L~ [no 0.00 5.00 5.00 0.00 0.00 0.00 13.74 33.29 33.29 33.29 33.29 33.29 33.29 33.29 33.29 33.29 33.29 42.08 53.68 61.00 69.56 72.24 74.29 89.71 89.71 COMMENT OJ: 242.00 242.00 242.00 242.00 242.00 242.00 241.20 241.20 241.20 241.20 241.20 241.20 241.20 241.20 241.20 241.20 241.20 198.32 ¡ 80.54 í 73.02 1 65.84 í 63.81 í 62.31 151.86 0000..............0000..00..' .......m m""n",',"""n"" ""000000000000"00 í 51 .86 TVD 300.00 549.68 798.73 1048.41 1066.00 1098.4 í 1552.00 2146.70 2222.00 2389.00 2399.00 2519.00 3850.00 4074.00 4432.00 5593.00 6471.¿2 6835.00 7031.00 7118.00 7193.00 7211.00 7223.00 7266.00 DATA North 0.00 -5.12 - í 5.35 -20.47 -20.47 -20.L7 -46.79 -171.L7 - 195.29 -248.13 -251.29 -289.25 -7:0.35 -781.22 -89L.48 -~ 261.79 -'539.69 -17iL7.20 -:958.96 -209fÍ.13 -2253.88 -2304.04 - 23iL2. 22 -2622.78 7281.00 -5268.46 .mm..mmmmmnnm.mmm.mnnnm""nmnnOO.nn.n..n nnm...n..mm ~~~~ =..05-;:' 0.00 -9.63 - 28.86 -38.49 -38.49 -38.49 -86.37 -313.12 -356.45 -452.5L -L58.29 -527.3L -1293.18 -: 422.07 - í 628.06 -2296.09 -2801.52 -2960.87 -2992.92 -2984.95 -2954.78 -294:.16 -2929.53 -2810.36 - í 395.32 m.mm.nnm"..nm,""nnn",'nn V. Sect 0.00 10.53 3: .57 42.10 42. í 0 L2. ~ 0 95.07 3/c5.91 393.8"1 500. i 3 506.50 582.88 1430.08 1572.66 1800.54 2.539.53 3098.66 3356.73 3524.61J 361í.01J 3697.98 3722.25 3739.80 384"1. '¡ 0 4614.72 '----" Oeg/100 0.00 2.00 0.00 2.00 0.00 0.00 -..5.00 3.00 0.00 0.00 c.oo C.OO 0.00 0.00 0.00 -~. 0.00 0.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 0.0 Cron:.e Oy om'".o, For: V ,Johnson' Dot. pIO::'O : puG,,- 2001 !'Iet "e'e'e"ce :, CO2 <9 Ve"'o'!d, Coordlno'" O" " 'oct "r.,.nee 010: #49, huc Vertlcol Dcpt" O'C ,cfercnce RKB (Doyon: 9),: -::;::- 2400, Q) Q) "I- '--" 2700 - ..c - :J 0 If) I V ¡¡¡:;¡¡¡¡ "..:,:rQ ".,"',:\, ¡:;T~'.\ ~200 j90D ..1600 ..1300 ( : P l~ i 1 ~L i '0 S J.. Structure: CDli2 Field: Alpine Field <- West (feet) ..1000 71DO nOD 2~OO 0 226.98 AZIMUTH 3844' (TO TARGET) 300 ...Plone of Propos(JI... 600 ~. t, 1\ ~ [8(] 900 - TRUE 1200 1500 lSDO 2100 ----------,..-"..,--,- - --",_..- ",..", TARGET LOCATION: 603' FSL, 964' FWL S[C. 2, T11 N, 1'<4[ 3000 3:500 " 3600 3900 "' 4200- 4500 4800 5100 5~00 5700 "' ~1> 1-.-a ~\. 1-.- Albian-96 Fnl Bld/Trn Target - [DC- C5g pt, ~ ~ 'óJ 6- '"7 ¿. -,-,-------- -,--------- TO LOCATION: 2043' IcNL, 23/7' ICWL SEC, 11, T11 N, RifE i\lasl<a, Well: 49 ( "L JCc C . "':'=--"'~"" ". ""-, ~~.-li'IF~.i ,,' , H __L . ::1: " ~ : f .. ~ i i ,~;:>... Location: North Slope, Alaska lS00 150D ORIGINAL 1700 900 D 6DO jOD Base permakrost "?i <f;~<fò~~ 1--0 q,~. E£& '0 v " íJ 9 5/8 Casing~~jo ~) þ..!--> /'-20 ?-b.~ SURFACE I,_OCATION: 2053' FNL, 1504' FEL SEC. 2, T11 N, R4E __-00------"------------- - Csg pt 0 ~oo 800 1200. 1600 2000 2400 ,,--..., +- Q) 2800 Q) '1- '-...../ ..£: 3200 +- 0.. Q) 0 3600 0 () +- 4000 - L Q) > Q) 4400 - ::¡ L I- I 4800 - V 5200.. 5600 6000 - 6~00 - 6800 .. 7200 - 7600 400 ( ,Pllilli ~p S , eKe "",li,", ". KGf' 2.00 4.00 WC Begin Drop 4,00 2.00 COO ~Öþt Sak 3.00 6.00 9.00 DLS: 3.00 dog per 1 :;1,00 B I' I t 15.00 ase erma ros 18.00 21.00 24.00 27.00 :50.00 33.00 LOC C-40 9 518 Casing C-.,)O C..:;10 TANGENT ANGLE 33.29 DEG 0 400 800 1200 Alasl<:a, ì '(1 rì ~~ '--'a Structure: CO¡¡2 Well: 49 Field: Alpine Field Location: North Slope, Alaska 100 It 226.90 AZIMUTH ~3B44' (TO TAHGET) ...["Iane or ['raposal'" \'\ \" ,<;\Ò ~'" . \' ,<;eo,' f /::: . -:"'~ :~- ) rnlï.i.lr~ ( ~" J '--....-~"'" r...alon oy I>,";chao' For: V Johnson D"I"pl"",,d,'I-IJ"c-~OO1 Pial ReI"r""ce ;" r.D~-'9 v"",;,,"NA. Cooed;"o"" ore in feet ,eloccnee ,lot H,g. rene Vertical Dopth, 0" ro'oco"ee RKß (Doyon 19). "~=f~: ",lEu TARGET ANGLE 89.71 DEG DI.S: 6.00 dog per 100 It ~~1.- '?- /" c,~ f. c» ,,¡eOe \) Ci 'v,¡~;v. 9t' "e "'\~~<:¡' \"(..:~ (,<;0, -0(,/ /'<,; e'. o,cs, 1600 2000 2400 2800 3200 3600 4000 Vertical Section (feet) -> Azimuth 226.98 with reference 0.00 N, 0.00 E from slot #49 ORIGINAL <;>" c;<;t~ / '\\) till 4400 4800 5200 C ::0 - - ~ - - <= ::t:::.. r-- ".--.., -+- Q) Q) '+- '--" ..c -+- 0... Q) 0 +- L Q) > Q) :J L l- I V 0 0 - - -- -- - - - - - - - - - -- --~---- - --- ---- -- ------------ ------------ - ----- : Created by bmichael For: V Johnson Date platted: 17-Dec-2001 Plat Reference is CD2-49 Versian#8- ! Coordinates are in feet reference slat #49- , !True Vertical Depths are reference RKB (Dayan 19)_! , ~- ' - ....-.. , ~~= """--Q ------------~---------------~------------------------ 6400 ~ Begin Fnl Bld/Trn 33_31 . \ 33.98, 35.55 37.90 40.89 44.39 48.29 52.50 56.94 61.55 66.30 76.07 6600 OLS: 6.00 deg per 100 ft TARGET/FINAL ANGLE 89.71 DEG 6800 7000 7200 7400 7600 200 800 0 200 400 600 ---------------------------------------------------------------~------~--------------------------------------------------- Phillips Alaska, Inc. -~-------- -------------- --- ---------------- ------------~--------- -------- --- -- -------- ------ -- -- - -- - ------- Structure: CO#2 Field: Alpine Field Well: 49 Location North Slope, Alaska: 151.86 AZIMUTH 987' (TO TARGET) ***Plone of Proposol*** -LI --> """"""'J <¡>\.. (",,0; <:0(,""'- "-,,v '\ o{O;e 1000 1200 2000 2800 2200 2400 2600 1400 1600 1800 Vertical Section (feet) -> Azimuth 151.86 with reference 0.00 N, 0.00 E from slot #49 3000 TO - Csg Pl 3200 3600 3400 3800 4000 - -n. 4200 4400 C) ::tJ - - ~ - - :æ: ::t::=.. r-- ~~_-_'~~m m_'m_'~m ! Created "y bmichael For: V Johnson' Date platted: 18-Dec-2D01 Plat Reference is CD2-49 Versian#8, Caardinates are in feet reference slat #49, ¡True Vertical Depths are reference RKB (Dayan 19).: _.~- rn.OS:-:' ,~~~ .". .,... 360 340 320 300 280 6V 6P ,,1500 "'_'m'_'_'_~n_.m_,--.._.~.._"m_----"--n_. ~-,--_. "___'n ..._'_m. -- mn. nn_.. _n__-- 'm_m ¡Phillips Alaska, Inc. , Structure: CD#2 Well: 49 L.__--~~~~_:_~~~,~~_e--n~~~,~~--,--,.n,-,~~,=~-~~~_m:,--~.~~~-~~O P e ~~~~~J 260 240 220 ~ /-//^(3> " 11 00 ",-1'300 ///-/ /// ///// //(5;0 " í 300 ////// / /// //// //'/ /// /// /",'1700 // ///// " // //'//// /// /// //// /' /",/1900 / /,//' //// ~/// / / / / / / / / / / / / 21 oCZ- / ~ 500 / " / / / / / / / / / / / c§> c§5/ & <- West (feet) 200 80 20 60 40 20 0 180 160 140 120 100 c§> & "700 40 60 .f45\ ~.... 500 e300 ...,......", ", 13~~ ,,1100 /B300 """1~~.. /'-ŠÓOe300 "'~.s 130,0./ ~ 700 y;, /// .e ~ 900 1500fK700 /"'500 1100 // 5500 / / e300 - /'.. //"'700 // / .. 900 9 300 9 / -700 . ,K 00 / /"Í 300 e 300 0 2300 700 / / / / " 70 - 1 500 ~ ' // 5700 @300 Ib / / /1"-500 " .. 900 300 500. 900 iÄ / / 63'" "ZJ /: / / / ~ 59£300 /' 1700 /7 500 / /'" /,,/11 00 1100 .. 700 . / , " / / / / / ~ -4900 .- 120 . 700 ~ " 900 - 900 . 2700 I 140 . 900 I 160 . 1100 180 .. 900 " 1100 .., 1300 e 300 ~ 700 - 250u e300 @300 -E7 30000 ~ " , i i , " 5900 - 700 .. 130D900 , , " 1500 '\- 1700 ¡ 1 300 i " 2900 " 1100 , , , '" 3100 " 6100 , / i , @& - 1100 (!;@ @ @ . 700 . 900 B B 40 ,-. 20 0 20 40 60 (/) 0 c - :J ,..--... -+, CD CD - '---" 100 I V -" 200 <::> :xJ - - ø - - <: )::::... r--- -- ---- - --- -- ---- --- ------- - - ----- --- ------- ------ ¡ Created by bmichael For: V Johnson; Date plotted: i B-Dec-2001 Plot Reference is CD2-49 Version flB- Coordinates are in feel reference sial #49- iTwe Vertical Depths are reference RKB (Doyon 19).: =::;;-~ -~-- £;-,TIè-Q 1500 1440 1380 1320 1260 1200 25~0,- 3700 .. 3900 ~ tØ (§> !Phillips Alaska, ------------------------------------------ Ine -----------~---~---- ---------------------------- Structure: CO#2 Well: 49 "------- Fiel~~ Alpin..:!~-=~~-------------------~~~~!ion --~ North Slope~--~~~--=~~J <- West (feet) 1140 840 780 c§> ~\" ~:'J , .'); -- ~C) , -- /' 21 OSk -- 1700/ ,/ -- -- "'1500 / -- / ---- h/2í 00 ---- /// -- /23~0 1900 /,/// -- -- / / / ¥ 1700 .. /,/ // / ",/ /><2300/ 2500 / / ,// /// /'- --/ // / /// / /"'-2700 21 00" /*25~O / / /// /// /// ""2900 // // //// 27~~ / /",w31O0 2300 _/ " //¿/ / -'// ....--::)-ðÓO / / / ;;i;~' // /// 2500 / / "'~~GÓ/ "/ / // / / / /3;~~~'/// / / / //"'3100 //- // 390~ / / /- /// -- ~2700 // / / - ,-,' / / // / 41 OQ.- / / />:;;00 @ / / /-//// '@'> ~/ ~ 4500..~ /,JZ'& //// /' /- ~?~Q;'21 00 .. 4-900///// ,,3100- /'/// .. 5100 ,----// - / //- ~ 3300 /" 2300' 5300.. /'// ~ _..,,/291JO 5500.. -,-/---//' -,,'-/"-//-'/ 5700. -//"-' W "/"'/---"// t)j) 1080 1020 960 900 4700.. " 3500 '" 2100 ~ - 2300 .. 4900 " 5100 ... 2500 .. 5300 &> 720 600 540 360 240 480 420 300 660 6» .. 2900 " 3700 &@ " 350q! // & 1590. ; 1700 " 1900 .. 3900 " 4100 1700. .. 4300 ./1900 6700 . 1700 .. 4500 " 1900 ¥ 5900 .. 4700 i 2100. 1900 . 7100 @ @@ \5 180 @ 120 180 240 300 360 (..f) 0 420 C -+ :J r-... 480 - CD CD -+ '---' 540 I V 600 660 720 780 840 -., @ - ~' \ ( ( Phillip s Alaska, Inc. Fö~:V jöhn~ö';;:i I Dole plotted: '7-Do<-2001 Structure: CD#2 Field: Alpine Field Location: North Slope, Alaska Well: 49 Piol R.f.,.n.. i. CD2-49 V.",ion'S. Coo'dinat.. 0'. in f..t ,.f".n.. SiD: *49, v.,ti.ol D.pths 0'. ,.fe,.n.e RKB (Doyon Eil8 IIAIIH: - I NTH) <- West (feet) .3750 .3500 .3250 .3000 2750 2500 2250 2000 1750 1500 1250 1000 750 /2100 / ' 7100 " 21 09 ~ " 3600 /2100 / / ¡ 2600 / ¡ " 26Øo " 2600 / .' /' .3100/3100 / / / 3600 .' ; ! ; / / 14100 I .' I / .I ;' ¡ , 4600 ; I / / / / I i 5100 ¡ I / ¡ / ! I ;:~~ ;~o~ 1 00 &>:>f~ ."" / .. ~ ...." / ."",.,.. // ,,"// .2600-600 ..",....' 3609,;"'5600 ~600 ,," ,/' .. ::;, ,,'" " y , ......"..".. /' 3600 " ". ,3-rÔO ,,6too 5100 ",," ,,' "...4100 *'-' ..,6600......ríoo ",,"",,'4íoo,,3100 ..6600 " 5600" " 36OÓ ","4600 " " "/' 4600//'" 6109.,""" "./,/ .. ' / " " ,11<.'4600 /5100 " / 3600 )If 660~/, "" 41,90" .. / ' / I ;0'-5100 I / 460q. t//.. 4100 A"S~OO ,// ,~, 7100 .. 5 1 ~96"1"~0 \ ~~~o .' ,,/,,/' ,...A600 \ 1><'], '" \ ."ç-<' \ \ \ \ \7266 \ , , , , , , , , , , , , , , , , , , , \ , , I/! , , .. 4600 , , , , , , , , , \ , , , ! , I )j 5600 /\ ! , i , I , / , / \ ¡ , I , / , i 6100 , / 'till / & && ~ ~ 5100 71.°8"""""""'" .......-<)6 0 ~...,,;:.,,;""'" W'" .. 6100 ~ 7100 ...' ,/ *,5600 .../ / rØ' & " 3100 '" 5100 & '" 3600 3600* '" 4100 *,' 5600 4100 ~ \ \, \, \ \ \ " \ \ " \ \ \ \. \\ \. \. " 5100 \\ \. @W§ '; 6100 4600" ,,5100 " 6600 " 5600 @ ORIGINAL 500 " 5100 250 0 250 500 750 2600.. 1000 " 4100 1250 1500 % 1750 2000 3100... 2250 - 2500 ,,4600 (j) 2750 0 C -+ :r .3000 r-... -+. CD 3600.. CD -+ .3250 "-'" I V .3500 .3750 4000 4100" 4250 4500 ŒQJ 4750 5000 4600" 5250 00 5500 :( { : P 11 i 11 i ~p s "-A.l2-ska, III C ~ ¿;f~-"'=-"""""" ~ pl-il! ! IP~ 1> ... . ¡ ...... ¡ ~ i /I . ! i ~ ~ . t ~ ~ \,,'. ,~ ---,..---- Ccea:eo oy bm;eMel For: V .Johnson Dot. pIO".d: :7..0.e.2001 Structure: CD#2 Well: 49 "rot Relere,ae :, CI1,-49 Vc"¡cr~B, Field: Alpine Field Location: North Slope, Alaska :oo'd:,olo, o'c ¡, tee: 'cle'eoee "01 ,¥49. Vcr::col ¡)ep:h, are 'elorence RKB (Ooyon 19), ¡:¡;-¡¡ 'I!! ~= -.. !~!'t:i.\ :S 1 0 rj§) 300 TRU E NORTI-I <> %3 s O~ ~'-O:~ @1 0 340 .2600 * 500 2'0("')0 * 1 ~or/oo 2 1 D . '1 0\ ------- -..;¿QOJ ¡it 500 * 8~ ~:%'Dð 1 QCSûà 70 1 Q 800 *12~ & :SjO "","""~6ÖO'" "/*, 2300 JJ'ò...""'.' 3 2 0 :,;'1' :,J 30 * liOO 40,.. .,\1Ð """.,,' 50 ~ 2000 ~ * 60 290 ,~ ~l() 280 80 270 90 260 100 I~ ,icY 240 & 2~30 "fii°. 0 * 1 400 /}!) ~O 250 10 130 220 2 1 ct * 1400 + 17Œ200 @\3 _. @O 180 Normal Plarìe Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well 140 * 1100 150 160 ~ 170 \@) ~ ORIGINAL ( ( Phillips Alaska, Inc. CD#2 49 slot #49 Alpine Field North Slope, Alaska PROPOSAL LIS TIN G by Baker Hughes INTEQ Your ref: CD2-49 Version#8 Our ref: prop4444 License: Date printed: 17-Dec-2001 Date created: 31-Jan-2001 Last revised: 17-Dec-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 16.908,w151 2 26.868 Slot Grid coordinates are N 5974303.706, E 371732.056 Slot local coordinates are 2053.00 S 1502.79 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL ( Phillips Alaska, Inc. CD#2,49 Alpine Field,North 5lope, Alaska Measured Inclin Depth Degrees 0.00 100.00 200.00 300.00 400.00 500.00 550.00 800.00 850.00 950.00 1050.00 1067.59 1100.00 1200.00 1300.00 1400.00 1500.00 1557.96 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2209.67 2299.76 2499.54 2500.00 2511. 51 2655.06 3000.00 3500.00 4000.00 4247.36 4500.00 4515.33 4943.61 5000.00 5500.00 6000.00 6332.53 6500.00 7000.00 7383.39 7400.00 7500.00 7600.00 7700.00 7800.00 0.00 0.00 0.00 0.00 2.00 0.00 242.00 242.00 242.00 242.00 4.00 5.00 5.00 4.00 2.00 242.00 242.00 242.00 242.00 242.00 0.00 0.00 0.00 3.00 6.00 242.00 242.00 242.00 241.20 241.20 9.00 12.00 13.74 15.00 18.00 241.20 241.20 241.20 241.20 241.20 21. 00 24.00 27.00 30.00 33.00 241.20 241.20 241.20 241.20 241.20 33.29 33.29 33.29 33.29 33.29 241.20 241.20 241.20 241.20 241.20 33.29 33.29 33.29 33.29 33.29 241.20 241.20 241.20 241.20 241.20 33.29 33.29 33.29 33.29 33.29 241.20 241.20 241.20 241.20 241.20 33.29 33.29 33.29 33.29 33.29 241.20 241.20 241.20 241. 20 241.20 33.31 33.98 35.55 37.90 40.89 239.38 228.61 218.44 209.19 200.99 Azimuth True Vert Degrees Depth 0.00 100.00 200.00 300.00 399.98 499.84 549.68 798.73 848.58 948.43 1048.41 1066.00 1098.41 1198.37 1298.05 1397.18 1495.50 1552.00 1592.72 1688.59 1782.85 1875.22 1965.47 2053.34 2138.60 2146.70 2222.00 2389.00 2389.38 2399.00 2519.00 2807.33 3225.28 3643.23 3850.00 4061.18 4074.00 4432.00 4479.13 4897.09 5315.04 5593.00 5732.99 6150.94 6471.42 6485.30 6568.62 6650.84 6731.05 6808.38 R E C TAN G U LA R COO R DIN ATE 5 O.OON O.OON O.OON O.OON 0.825 3.285 5.125 15.355 17.195 19.655 20.475 20.475 20.475 21. 735 25.515 31. 795 40.575 46.795 51.825 65.505 81.585 100.025 120.765 143.755 168.925 171.475 195.295 248.135 248.255 251.295 289.255 380.485 512.705 644.935 710.355 777.165 781. 225 894.485 909.395 1041. 625 1173.855 1261.795 1306.075 1438.305 1539.695 1544.215 1576.715 1617.995 1667.615 1725.035 6.16W 9.63W 28.86W 32.33W 36.95W 38.49W 38.49W 38.49W 40.78W 47.66W 59.09W 75.06W 86.37W 95.51W 120.40W 149.65W 183.18W 220.90W 262.70W 308.48W 313.12W 356.45W 452.54W 452.76w 458.29W 527.34W 693.24W 933.73W 1174.21W 1293.18W l414.70W 1422.07W 1628.06W 1655.18W 1895.67W 2136. l5W 2296.09W 2376.64W 2617.12W 2801.52W 2809.44W 2854.08W 2893.15W 2926.23W 2952.96W ( PROPO5AL LI5TING Page 1 Your ref: CD2-49 Version#8 Last revised: 17-Dec-2001 G RID COO R D 5 Easting Northing O.OOE O.OOE O.OOE O.OOE 1. 54W 371732.06 371732.06 371732.06 371732.06 371730.50 5974303.71 5974303.71 5974303.71 5974303.71 5974302.91 5974300.53 5974298.75 5974288.85 5974287.07 5974284.69 5974283.90 5974283.90 5974283.90 5974282.67 5974279.01 5974272.92 5974264.41 5974258.38 5974253.51 5974240.25 5974224.67 5974206.80 5974186.71 5974164.43 5974140.04 5974137.57 5974114.48 5974063.29 5974063.17 5974060.22 5974023.43 5973935.03 5973806.90 5973678.77 5973615.38 5973550.63 5973546.71 5973436.95 5973422.50 5973294.37 5973166.23 5973081. 02 5973038.10 5972909.97 5972811. 72 5972807.33 5972775.60 5972734.99 5972685.93 5972628.98 G E 0 G RAP H I C COO R DIN ATE 5 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 n70 20 05.36 n70 20 04.49 n70 20 04.05 n70 20 02.75 n70 20 01. 75 n70 20 n70 20 n70 20 n70 20 n70 19 16.91 16.91 16.91 16.91 16.90 w151 w151 w151 w151 w151 2 26.87 2 26.87 2 26.87 2 26.87 2 26.91 371725.84 371722.35 371702.94 371699.45 371694.78 371693.23 371693.23 371693.23 371690.92 371683.98 371672.44 371656.33 371644.91 371635.69 371610.58 371581. 06 371547.23 371509.17 371466.98 371420.79 371416.11 371372.39 371275.43 371275.20 371269.62 371199.95 371032.54 370789.87 370547.21 370427.16 370304.54 370297.10 370089.24 370061. 87 369819.21 369576.54 369415.15 369333.88 369091.21 368905.14 368897.15 368851.97 368812.21 368778.29 368750.60 16.88 16.86 16.76 16.74 16.71 w151 w151 w151 w151 w151 2 27.05 2 27.15 2 27.71 2 27.81 2 27.95 16.71 16.71 16.71 16.69 16.66 w151 w151 w151 w151 w151 2 27.99 2 27.99 2 27.99 2 28.06 2 28.26 16.59 16.51 16.45 16.40 16.26 w151 w151 w151 w151 w151 2 28.59 2 29.06 2 29.39 2 29.66 2 30.38 16.10 15.92 15.72 15 ,,49 15.25 w151 w151 w151 w151 w151 2 31.24 2 32.22 2 33.32 2 34.54 2 35.88 15.22 14.99 14.47 14.46 14.44 w151 w151 w151 w151 w151 2 36.01 2 37.28 2 40.08 2 40.09 2 40.25 14.06 13.16 11.86 10.56 09.92 w151 w151 w151 w151 w151 2 42.27 2 47.11 2 54.13 3 01.16 3 04.63 09.26 w151 09.22 w151 08.11 w151 07.96 w151 06.66 w151 3 08.18 3 08.39 3 14.41 3 15.20 3 22.22 w151 w151 w151 w151 w151 3 29.24 3 33.91 3 36.26 3 43.28 3 48.67 01. 71 01. 39 00.98 00.50 59.93 w151 w151 w151 w151 w151 3 48.90 3 50.20 3 51.34 3 52.31 3 53.09 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #49 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 5450.11 on azimuth 194.83 degrees from wellhead. Total Dogleg for wellpath is 132.69 degrees. Vertical section is from wellhead on azimuth 226.98 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL (I ( Phillips Alaska, Inc. PROPOSAL LISTING Page 2 CD#2,49 Your ref : CD2-49 Version#8 Alpine Fie1d,North Slope, Alaska Last revised : 17-Dec-2001 Measured Inc1in Azimuth True Vert R E C TANGU LA R G RID COO R D S G EO G RAP H I C Depth Degrees Degrees Depth COO R DIN A T E S Easting Northing COO R DIN ATE S 7835.54 42.08 198.32 6835.00 1747.205 2960.87W 368742.32 5972606.95 n70 19 59.71 w151 3 53.32 7900.00 44.39 193.79 6881.97 1789.625 2973.04W 368729.43 5972564.75 n70 19 59.30 w151 3 53.67 8000.00 48.29 187.49 6951.03 1860.665 2986.26w 368715.02 5972493.94 n70 19 58.60 w151 3 54.06 8100.00 52.50 181. 93 7014.79 1937.395 2992.46w 368707.52 5972417.34 n70 19 57.84 w151 3 54.24 8126.99 53.68 180.54 7031.00 1958.965 2992.92W 368706.69 5972395.78 n70 19 57.63 w151 3 54.25 8200.00 56.94 176.98 7072.56 2018.95S 2991.58W 368707.02 5972335.78 n70 19 57.04 w151 3 54.21 8288.13 61.00 173.02 7118.00 2094.135 2984.95W 368712.38 5972260.50 n70 19 56.30 w151 3 54.01 8300.00 61. 55 172.51 7123.71 2104.465 2983.64W 368713.52 5972250.15 n70 19 56.20 w151 3 53.97 8400.00 66.30 168.42 7167.66 2192.985 2968.71W 368726.95 5972161. 40 n70 19 55.33 w151 3 53.54 8467.43 69.56 165.84 7193.00 2253.88S 2954.78W 368739.84 5972100.28 n70 19 54.73 w151 3 53.13 8500.00 71.15 164.63 7203.95 2283.545 2946.96W 368747.16 5972070.50 n70 19 54.44 w151 3 52.90 8522.44 72 .24 163.81 7211. 00 2304.045 2941.16W 368752.61 5972049.90 n70 19 54.24 w151 3 52.73 8564.12 74.29 162.31 7223.00 2342.225 2929.53W 368763.59 5972011.53 n70 19 53.86 w151 3 52.39 8600.00 76.07 161. 05 7232.18 2375.15S 2918.63W 368773.93 5971978.43 n70 19 53.54 w151 3 52.07 8700.00 81.04 157.62 7252.02 2466.805 2884.03W 368806.98 5971886.22 n70 19 52.64 w151 3 51. 06 8800.00 86.04 154.28 7263.28 2557.495 2843.53W 368845.93 5971794.86 n70 19 51.74 w151 3 49.88 8873.31 89.71 151. 86 7266.00 2622. 78S 2810.36W 368877.99 5971729.02 n70 19 51.10 w151 3 48.91 8873.33 89.71 151. 86 7266.00 2622.805 2810.35W 368878.00 5971729.00 n70 19 51.10 w151 3 48.91 9000.00 89.71 151.86 7266.63 2734.505 2750.61W 368935.84 5971616.32 n70 19 50.00 w151 3 47.16 9500.00 89.71 151. 86 7269.13 3175.395 2514.80W 369164.14 5971171. 54 n70 19 45.67 w151 3 40.27 10000.00 89.71 151. 86 7271.63 3616.285 2278.99W 369392.45 5970726.76 n70 19 41. 33 w151 3 33.38 10500.00 89.71 151. 86 7274.13 4057.185 2043.17W 369620.76 5970281.98 n70 19 37.00 w151 3 26.49 11000.00 89.71 151.86 7276.63 4498.075 1807.36w 369849.06 5969837.20 n70 19 32.66 w151 3 19.60 11500.00 89.71 151.86 7279.13 4938.965 1571.55W 370077.37 5969392.42 n70 19 28.33 w151 3 12.71 11873.67 89.71 151.86 7281.00 5268.465 1395.32W 370247.99 5969060.02 n70 19 25.09 w151 3 07.56 11873.69 89.71 151.86 7281.00 5268.485 1395.31W 370248.00 5969060.00 n70 19 25.09 w151 3 07.56 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #49 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 5450.11 on azimuth 194.83 degrees from wellhead. Total Dogleg for we11path is 132.69 degrees. Vertical section is from wellhead on azimuth 226.98 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL ( ;( Phillips Alaska, Inc. CD#2,49 Alpine Field,North 51ope, Alaska PROPO5AL LI5TING Page 3 Your ref: CD2-49 Version#8 Last revised: 17-Dec-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300.00 300.00 O.OON O.OOE KOP 550.00 549.68 5.125 9.63W EOC 800.00 798.73 15.355 28.86W Begin Drop 1050.00 1048.41 20.475 38.49W EOD 1067.59 1066.00 20.475 38.49W West 5ak 1100.00 1098.41 20.475 38.49W KOP 1557.96 1552.00 46.795 86.37W Base Permafrost 2209.67 2146.70 171.475 313 .12W EOC 2299.76 2222.00 195.295 356.45W C-40 2499.54 2389.00 248.135 452.54W 9 5/8" Casing 2511.51 2399.00 251.295 458.29W C-30 2655.06 2519.00 289.255 527.34W C-20 4247.36 3850.00 710.355 1293.18W K-3 4515.33 4074.00 781.225 1422. 07W K-2 4943.61 4432.00 894.485 1628.06W A1bian-97 6332.53 5593.00 1261.795 2296.09W A1bian-96 7383.39 6471.42 1539.695 2801. 52W Begin Fn1 Bld/Trn 7835.54 6835.00 1747.205 2960.87W HRZ 8126.99 7031. 00 1958.965 2992. 92W K-l 8288.13 7118.00 2094.135 2984.95W LCU 8467.43 7193.00 2253.885 2954.78W Miluveach A 8522.44 7211.00 2304.045 2941.16W Alpine D 8564.12 7223.00 2342.225 2929.53W Alpine C 8873.31 7266.00 2622.785 2810.36W Target-EOC-Csg Pt. 8873.33 7266.00 2622.805 2810.35W CD2-49 Heel Rvsd 19-Nov-01 11873.67 7281. 00 5268.465 1395. 32W TD - Csg pt 11873.69 7281. 00 5268.485 1395.31W CD2-49 Toe Rvsd 19-Nov-01 Casing positions in string 'A' ------------------------------ ------------------------------ Top MD TOp TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O. OON O.OON O.OOE O.OOE 8873.33 2499.54 7266.00 2389.00 2622.805 248.135 2810.35W 452.54W 7" Casing 9 5/8" Casing Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- CD2-49 Heel Rvsd 19- 368878.000,5971729.000,2.0000 CD2-49 Toe Rvsd 19-N 370248.000,5969060.000,0.0000 7266.00 7281.00 2622.805 5268.485 2810.35W 1395.31W 15-0ct-1997 15-0ct-1997 ORIGINAL VJ6A 1/1/07- ~ ( PHIlliPS ~ @ Phillips Alaska, Inc. Post Office Box 1 00360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 21,2001 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-49 Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Water Alternating Gas (WAG) injection well fr°JJ1. the Alpine CD2 drilling pad. The intended spud date for this well is January 12, 2002. It is intended that Doyon Rig 19 be used to drill the well. The CD2-49 will be drilled to penetrate the Alpine reservoir horizontally. T casing will then be run and cemented in place. A horizontal section will then be drilled and the well will be completed as an open hole injector. At the end of the work program, the well will be shut in awaiting connection to surface facilities. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. . 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. RECEIVED U' 7-. DEC 21 ZO01 Ve rn J 0 h n so n Alaska au & Gas Cons. Commission Drilling Engineer 0 RIG I N A L f\nCIIOI3ge (' Attachments cc: CD2-49 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin 4" \ ATO 1530 A TO 868 ATO 848 A TO 844 Anadarko - Houston Kuukpik Corporation e-mail: Tommy_Thompson @ anadarko.com ORIGINAL RECEIVED DEC 2 1 2001 Alaska Oil & Gas Cons. Commission Anchorage --- PHILLIPS ~ Check¡EFf#: Phillips Alaska, Inc. P. O. Box 102776 Anchorage, AK 99510-2776 ( Date: ,ù 12/21/0\ Pay Entity: Page of 0 1 0 1 3 8 4 00101384 Vendor #: VOUCHER SOURCE ID GROSS' 0201 DISCO U NT I AD J USTME.NTS NOOO09838600 JA'rE INVOICE NUMBER NET 12/2 /01 VR122101SJDOI YO12A 12 1 SJD FILING FEE FOR PERMTI TO DRILL WELL CD2-49 100.00 100.00 , ' , , , .. ,,""" ' " ,^", " ~ ,", ".' >' ':":':~'/"" ;t,:',,:'tÇ-,:>;,", ':", ,," ,;r':-.': " " :" ," "", " , , , ",. RECE VED , ' " ",," , " ", Df:C 2 ~J ':.zØÔ;l":",::,:,";r,", ::' AlaslraOil & .~o~ .. ~'< ' ' . ' , ," , :"",' , , ',:"....' \".-:', , .. ,:',';,,' ",';'<,::-';:":'}::',:\:','>~i,'>'::;~~""..,,':,(\.~:',:': >, ,";"-'-'<:,';;~"""';..:H~}:\>""~';<,~':,,, ' , , , ' '..'" , , , , " ,"'<",..\T,.:', ", > , ,: ,', ..r :~', ".., ,'.... ,', , ' ' ,""", ',; " , " , , " estions regarding this remittance can be made by calling or writing: ~T 907/265-6904 P,O, BOX 103560, Anchorage, AK 99510-3560 \TLS907/265-6904 P,O, BOX ]03560, Anchorage, AK 99510-3560 CS 907/265-6080 P,O, BOX ]03240, Anchorage, AK 99510-3240 AL 907)63-4422 Detach check before depositing . - .. Phillips Alaska, Inc. P. O. Box 102776 Anchorage, AK 99510-2776 "¡:':, ,:::,:"',', i:,':: ,,:-:":',:,:,:: ::'::::'>,:::::'::",::,',:::',;::,,':'::::,:::,;:',,',:~,;:':::,,',:'::::::::::::::?:::":"::':,',',:':,"" ".. ,', ," '" :::;::,'::::",:J,,:,:l!:::',:'::::'::::;;:,:;::::::':':::!!"'::':':"r'::::;::'::'~.',::':':':, , ..", ',', ",,',' ":,',', ":", ,,"" ':' '"",.." ':,' " .., ,," . - . . : 8 8 .. ;"~~~JgË~ ~ ~:~.j" i' ~~~~~' t.7:' ~:;~ <: ;:~J'!( ¡;":' Republic B¡¡Ilk,Shelbyvillè'!<G'Qi}5(~i~84/' Pay ONE HUNDRED DOLLARS AND NO CENTS 0101384 To the order of: STATE OF ALASKA AOGCC 333 W, 7TH AVENUE, SUITE 100 ANCHORAGE AK 995013539 Date 12-21-01 **************100.00* Amount Void after 90 days / "",'^", ""',"^""','" ,'""',', :,"""',..""", ,..:"',,, """""""""',"""",,, III 0 00 0 ~ 0 ~ ~ 8 ~ III 1:08 :190 ~ 2 b 21: 09 90000111 CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT RED RILL EXPLORA TION INJECTION WELL v INJECTION WELL REDRILL ( t TRANSMIT AL LETTER CHECK LIST CIR CLE APPRO PRIA TE LETIERIP ARA GRAPHS TO BEINCLUDEDINTRANSNUTTALLETTER WELL NAME êR¿¿ @z-<f1 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 6.0-69) PILOT HOLE (PH) ANNULAR DISPOSAL <-) NO ANNULAR DISPOSAL <-) YES ANNULAR DISPOSAL THIS WELL DISPOSA:2INT i OTHER ANNULUS YES + SP ACING EXCEPTION Templates are located m drive\jody\templates "CLUE" The permit is for a new well bore segment of existing weD . Permit No, , API No. . ' Production should continue to be reported as a function of the original API number stated above. In accordance with 2.0 AAC 25..0.05(1), 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 (5.0 -7.0/8.0) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal, of drilling wastes will not be approved. . . An~;r. D)s~os~1 of drilling ~tÏ'ii~.1 no~ be ,aPYJoved . .. . /~. . q. I /11 ¿:::s~. ~l-¡t;f> ~fl¿/-S tbé'-/ II ~--( 11-1./ ri" r pl. (J - -, --/.u-h1--A..L- ~nv'd~ ~<.c Please note that iSP~Jf ò( ffuTd~ generated.. !rJ 'V;;;>-' /!,7u/;4. .~, h~tn.,.1L yi;5 t~ç¿I(I¿??.: /(4~ ~\"I'e.CW UiL/t; 6è A2lA)"n /V/I,~ <J ¿;;:..A'l/1.U /t )' S. (J, ~ Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 2.0 AAC 25..055. Approval to peñorate 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 COMPANY - ~ WELL NAME to 2.'~ t,c;- PROGRAM: exp - dev - redrll FIELD & POOL I ZD I CXJ INIT CLASS ~ §r-- A? wl$/,.v GEOl AREA E39D ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . '~ N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . . N, 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . ~ N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . , N 10. Operator has appropriate bond in force. . . . . . . . . . . . . "'\ N 11. Permit can be issued without conselVation order. . . . . . . . N A% ~A7E ~. 12. Permit ca~.be issued without administrativ~ approval.. . . . . N . .D¿,-- 13. Can permit be approved before 15-day walt.. . . . . . . . . . Y N ENGINEERING 14. Conductor string provided .. . . . . . . .. . . . . . . . . . ~ N ..Pr~- ~ . 15. Surface casing protects all known USDWs. . . . . . . . NN AfÍt' /"'/ lLC;..'te ~ . ~'l i . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . .~ 17. CMT vol àdequate to .tie-in long string to surf csg. . . . . . . . tf} ~A -+-: 18. CMT will cover all known productive horizons. . . . .'. . . . . y ~ ~~'L ù.,~{.< VY"-- 19. Casing designs adequate for C, T, B & permafrost. . . . . . . fO N 20. Adequate tankage or reselVe pit.. . . . . . . . . . . . . . . . . ~ N ~ l q 21. If a re-drill, has a 10-403 for abandonment been approved. . . N ¡J/~ 22. Adequate weilbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it 'meet regulations. . . . . . . . . . N 24. Drilling .fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N -P.o'-if( ¡, -I-: \ APPR JïifTE 26. BOPE press rating appropriate: tesllD SVOQ . psig. N J~ "'-ff.14("-- Y<""- .~e ~ ZStP¡ px.. \¡J4A I' O'L . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . .. , N 28. Work will occur without operation shutdbwn. . . . . . . . . . . Y t:l 29. Is presence of H25 gas probable.. . . . . . . . . . . . . . . . (tV 30. Permit can be issued w/o hydrogen sulfide measures. . . . ,. Y Y- 31. Data presented on potential overpressure zones. . . . . .. . 1 f\. ".-- N 32. Seismic analysis of shallow gas zones. . . . . . . . . . . .. IV" Y N APPR DATE 33. Seabed condition sulVey ("If off-shore). . . . . . . . . . ./ Y N If 7'07--, 34. Contact name/phone for weekly progress reports [exp)Pfátory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; .' (C) will not impair mechanical integrity pf the well used for disposal; (0) will not damage producing fonnation or impair recovery from a pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y GE~OLOGY: 'FEE, R~: 'UIC/Annular COMMISSION: ~~ .. v" WM -8~s . JM serv wellbore seg _ann. disposal para req - UNIT# OÐ=3({) ON/OFF SHORE C//'1 "fOn1\CU) f'~~~ .~- kit}- Will 'tt-.. ' mttcLL.. oJ-' C<- ~~c:~t-" I c 0 Z 0 ( ~ :E :::0 - ~. m - z ~ :I: - en » :::0 ( m » GEOLOGY ~~ A vliJ y~- 1110(', vo[. At u ~D W' . APPR DATE ~ 117/0Z- /1'0.... Com me nts/lns tructions: 0')-- c:\msoffice\wordian\diana\checklist (rev. 11/01/100) .~. ~, Well History File APPENDIX Information of detailed nature that is not , particularly germane to the Well Permitting Process but is part of the history file. , To improve the readability of the Well History file and to simplify finding infonnation information of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically" . organize this category of information. ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Oct 01 15:05:20 2002 Reel Header Service name............ .LISTPE Date.....................02/10/01 Origin...................STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Tape Header Service name............ .LISTPE Date.....................02/10/01 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22014 M. HANIK D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD { \ Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services CD2-49 501032040100 PHILLIPS Alaska, Inc. Sperry Sun 01-0CT-02 MWD RUN 3 AK-MW-22014 R. KRELL D. BURLEY MWD RUN 4 AK-MW-22014 R. KRELL D. MICKEY 2 llN 4E 2053 1504 .00 52.70 15.90 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 2494.0 8.500 7.000 8891.0 # 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 ao (-caLf 9 Jllgb ~ g' '" ( (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. GAMMA RAY LOGGED BEHIND CASING FROM 2460' MD, 2350' TVD, TO 2494', 2378' TVD. 5. GAMMA RAY LOGGED BEHIND CASING FROM 8872' MD, 7258' TVD, TO 8891', 7258' TVD. RESISTIVITY DATA LOGGED BEHIND CASING FROM 8865' MD, 7257' TVD TO 8891', 7258' 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 CD2-49 WITH API # 50-103-20401-00. THIS WELL REACHED A TOTAL DEPTH OF 11874' MD, 7263' 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...... .02/10/01 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 2459.5 2484.0 2484.0 2484.0 2484.0 2484.0 2500.5 STOP DEPTH 11831.0 11838.5 11838.5 11838.5 11838.5 11838.5 11874.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ ,1' \ i~ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2459.5 7669.0 MWD 3 7669.5 8901.0 MWD 4 8901.5 11874.0 $ # 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 2459.5 11874 7166.75 18830 2459.5 11874 ROP MWD FT/H 0.11 394.31 125.362 18748 2500.5 11874 GR MWD API 27.54 395.59 94.052 18744 2459.5 11831 RPX MWD OHMM 0.05 1645.2 7.69134 18710 2484 11838.5 RPS MWD OHMM 0.26 1530.65 8.3713 18710 2484 11838.5 RPM MWD OHMM 0.23 2000 12.483 18710 2484 11838.5 RPD MWD OHMM 0.22 2000 14.2332 18710 2484 11838.5 FET MWD HR 0.21 65.61 1. 09551 18710 2484 11838.5 First Reading For Entire File......... .2459.5 Last Reading For Entire File...... .... .11874 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/01 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... ....02/10/01 Maximum Physical Record..65535 File Type........... .... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 ii' ~ RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ i 1\ header data for each bit run in separate files. 2 .5000 START DEPTH 2459.5 2484.0 2484.0 2484.0 2484.0 2484.0 2500.5 STOP DEPTH 7628.0 7620.5 7620.5 7620.5 7620.5 7620.5 7669.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 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..................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 26-JAN-02 Insite 4.05.5 66.16 Memory 7669.0 31.4 38.2 TOOL NUMBER PB02236HWRGV6 PB02236HWRGV6 8.500 LSND 9.60 39.0 9.2 450 6.2 .900 .475 1. 500 1. 400 65.0 129.2 65.0 65.0 I~ ( 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 2459.5 7669 5064.25 10420 2459.5 7669 ROP MWD020 FT/H 0.68 394.31 168.026 10338 2500.5 7669 GR MWD020 API 43 200.72 111. 809 10338 2459.5 7628 RPX MWD020 OHMM 0.05 16.87 4.79083 10274 2484 7620.5 RPS MWD020 OHMM 0.34 16.4 4.81661 10274 2484 7620.5 RPM MWD020 OHMM 0.23 28.48 4.79265 10274 2484 7620.5 RPD MWD020 OHMM 0.22 2000 6.28869 10274 2484 7620.5 FET MWD020 HR 0.21 43.19 0.730362 10274 2484 7620.5 First Reading For Entire File......... .2459.5 Last Reading For Entire File... ...... ..7669 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/01 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...... .02/10/01 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 7621.0 7621.0 7621.0 7621.0 7621.0 7628.5 7669.5 STOP DEPTH 8864.5 8864.5 8864.5 8864.5 8864.5 8872.0 8901.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): 28-JAN-02 Insite 4.05.5 66.16 Memory 8901.0 ( 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. ..0 ,1\ 39.8 88.6 TOOL NUMBER PB2236HWRGV6 PB2236HWRGV6 8.500 8891. 0 LSND 9.60 40.0 9.4 500 4.8 2.100 1. 098 2.100 3.000 70.0 140.0 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 7621 8901 8261 2561 7621 8901 ROP MWD030 FT/H 0.11 265.03 65.5238 2464 7669.5 8901 GR MWD030 API 44.41 395.59 116.989 2488 7628.5 8872 RPX MWD030 OHMM 1. 53 27.45 7.43819 2488 7621 8864.5 RPS MWD030 OHMM 1. 48 26.46 7.65691 2488 7621 8864.5 RPM MWD030 OHMM 1. 45 30.08 7.75701 2488 7621 8864.5 RPD MWD030 OHMM 1.5 26.79 7.90764 2488 7621 8864.5 FET MWD030 HR 0.38 15.14 1. 50869 2488 7621 8864.5 if ,J .1 "\ First Reading For Entire File..... .....7621 Last Reading For Entire File. ......... .8901 File Trailer Service name....... ..... .STSLIB.003 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .02/10/01 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...... .02/10/01 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 8865.0 8865.0 8865.0 8865.0 8865.0 8872.5 8901.5 STOP DEPTH 11838.5 11838.5 11838.5 11838.5 11838.5 11831.0 11874.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 02-FEB-02 Insite 4.05.5 66.37 Memory. 11874.0 88.0 91. 7 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02355HAGR4 PB02355HAGR4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLOPRO 9.15 50.0 9.1 23500 i{ " ( 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: 3.6 .080 .038 .120 .160 70.0 153.0 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction.. ............. ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record..... ....... .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP 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 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8865 11874 10369.5 6019 8865 11874 ROP MWD040 FT/H 0.15 174.62 75.983 5946 8901.5 11874 GR MWD040 API 27.54 84.97 53.3896 5918 8872.5 11831 RPX MWD040 OHMM 0.22 1645.2 12.8073 5948 8865 11838.5 RPS MWD040 OHMM 0.26 1530.65 14.8102 5948 8865 11838.5 RPM MWD040 OHMM 7.09 2000 27.7433 5948 8865 11838.5 RPD MWD040 OHMM 9.07 2000 30.6016 5948 8865 11838.5 FET MWD040 FT/H 0.31 65.61 1.5534 5948 8865 11838.5 First Reading For Entire File...... ....8865 Last Reading For Entire File........ ...11874 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................02/10/01 Origin...................STS Tape Name............... . UNKNOWN ( Continuation Number. ... ..01 Next Tape Name.......... . UNKNOWN Comments...... ... ....... .STS LIS Writing Library. Reel Trailer Service name............ .LISTPE Date.....................02/10/01 Origin...................STS Reel Name........ ....... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments......... ....... .STS LIS wri ting Library. Physical EOF Physical EOF End Of LIS File { Scientific Technical Services Scientific Technical Services
