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Home My WebLink About200-008P7 -D dao -009 Loepp, Victoria T (CED) From: Well Integrity Compliance Specialist WNS &CPF3 <n2549@conocophillips.com> Sent: Wednesday, July 17, 2019 10:10 PM To: Loepp, Victoria T (CED) Cc: CPA Wells Supt Subject: CRU Producer CD1-25 (PTD# 200-008) IA Sustained Casing Pressure Attachments: CD1-25.pdf Follow Up Flag: Follow up Flag Status: Flagged Dear Victoria, Alpine CRU Producer CD1-25 (PTD# 200-008) recently exceeded 2000 psi on the IA while SI and reached a maximum of 2300 psi. The well remains SI and the pressure was bled 7/15/19. The IA is currently at 1700 psi. The well has 7", 26 Ib/ft, L-80 grade production casing which has a burst pressure rating of 7,240 psi. We intend to trouble shoot the source of the high pressure and secure the well as soon as logistically possible. Once we determine the source of the high pressure, we will progress well work to restore the TxIA integrity. Please let us know if you have any questions or disagree with this plan. Sincerely, SaranCarlal&(HeA40/2adh.ellKa.utk Well Integrity & Compliance Specialist, WNS & C13173 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@col?.com A `�\ WNS PROD CD1-18 ConocoPhillips Alaska.!nC. wall Attributes - Max Angle ti MO TD woll"no KpuuwI Fxw Nmn wn!eon 0xhu nu 19 Y06tlO1 MI 1 501032050200 ALPINE PROD 95.58 16,6308] 15,056.0 MMYtlon EMOW 'O"Pop ) wp RNutl OYe LaY WO 44.08 12/8(10114 Comment IY9 (ppml Onlo SSSV: VIRDP CO+-te, arzprza+]5:1138 PM V I¢tlnire4c ec4u Mno1Nm M (ftl(6) EMGex oltllwl LOI Mntl ay Last Tag: Rev Raesm: PULL WRDP. GLV GO, SET ppmven WROP Entl OHs 6120/2017 HARDER) 319 CONDUCTOR', 31 alts o xo RtltlNX 12v 9AFM w,v:2024 wXOP; z,+sxe pURFACE:.B 1.158.]-• GPSLIFi,O)00.3 cAs uFT esev c0.5 uFT:+o, 1. 9LEEVe+a.av FACKER: 10.]11)0 RIFFE; In ll5 n WLEG, 10,188] PROOOCTION.aTAIIXI I OPEN XOLEFRAC: +1.M1.]� OFEX XOLF: tt 3b1 )-I6.OY 0 Casing Strings .no O"'Abon 00(in) IG on) Tap(Ma) BA-F611RNa) NM P ROR(1VD),. wNJn (k., no. To IF To CONDUCTOR 16 15.062 370 115.0 1150 62.50 H40 WELDED CYXp pwvlptlon OD no) mlint Top 1 SY0pNR(RX6) SM D&R. ITRI waLn11., GMo TOP Thou. SURFACE 9518 8921 36.2 2]59] 2,353.6 36.00 J5S BTC �p apopP, n OO lln) IOfn) oP 1 Ep10N+e I11Xa) ITVD... wlM1nn .._ ,a4e Top TMa4 PRODUCTION 7 6.2]6 33.0 11,381 ] ],0445 28.00 LA0 BTCM BI K.1 GapN al Sol DnPIR nV0)-- WIILan II_. 0. Tap TMu4 .nK OrsGip4on OO (In) 1011n) Top (RKIflN OPEN ROLE 81/8 11,3011 15,0580 7.0354 TubkV Strings TuelnB OnnipNon Sbinp YR.. TUBING 45'x3.5' 3112 23' )Otto) 2.992 Tap (XNBI 31.9 E.ID.Fai (R.. 10]06.8 SI Oap111 DVDI I... fi,BB32 W11®IR 930 Gnpo LA0 TOP [nonaction EVEMOO 9 • . I Completion Details Nomlml l0 Top (WSJ Top"D)(RMI Top trot l') Ibm M1s r Iln) 319 31.9 0.10 HANGER FMC4.5'7UBINGHANGER 4500 122.7 122.7 0221[ORPBUdng CROSSOVER 4 5 x 3 3.500 2.1524 1.990A 45.76 SAF VLV CAMCD TRM4-E SAFETY VALVE h CKEO OUT 2.812 6/212013) 10.642. 6014.1 58.5] SLEEVE BAKER CMD SLIDING SLEEVE 2.013 10] ]0 8.866.0 61 9] BACKE BAKER PREMIER PACKER 2.070 10,]]5. 6, 780 63.71 NIPPLE HES KN NIPPLE 101' w12 75- GO 2.750 10,786.3 0 64.17 WLEG NRELING GUIDE 30M Other In Hole (Wlrellne rstrlewbM plugs, Trahres, Pumps, fish, etc.) Top 111Xa1 Top jNDl ruv and (1at6) I') G.a Gun Run wlp IOOn) 2152.4 1.930.9 45 76 Vd2GP 2.81' WIR . (SN: HTS.61T, 6/171209 1.094 StimWatlons d Treatments Pnppnm Dralenw Pel PnPwmin Fnmulxnllel D.M 4121200] Stimulations & Treatments Y TOP (11X6) atm lXXa) CM EtlMImtF1uIE VW Cion Pump abl VPI911my ryW1 1 11,38 T 15.0550 4/Z200] Mandrel Inserts m _ p Top(-) Tap ITVD) MW Yp4Y OD(In) BNv Too, TYP =0) (pY n on. Com 4, 0 3 34023 DAMDD KBUG 1 GLV 8K 0. 88 2.113.0 1 ROt] 8,663,7 5.695.5 M NBUG i GAS LIFT V BK .188 2.003.0 d1 O9 3 10,554.4 8.788.2 CAMCO KBUG 1 GAS LIFE OV BK 0250 .0 1012/201 Notes: Generel8 Safety EnE OM MnoYtlon 8@5/2010 NUE: VIEW SCHEMATIC wlAlaspa SMemali 9.0 , r CD1-25 ALA.OIL AND GSTATE OF AS CON ERVAT ON COMIADION REPORT OF SUNDRY WELL OPERATIONS NOV 13 2011 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other r Alter Casing fl Pull Tubing l Stimulate-Frac r Waiver f Time Extension gitkOGCC Change Approved Program rOperat. Shutdown r Stimulate-Other Re-enter Suspended Well fl 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 7" Exploratory r 200-008 ' 3.Address: 6.API Number: Stratigraphic [® Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20325-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372095,25559 CD1-25' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 12147 feet Plugs(measured) none true vertical 7028 feet Junk(measured) none Effective Depth measured 12147 feet Packer(measured) 8486 true vertical 7028 feet (true vertical) 6869 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 114 114 SURFACE 2735 9.625 2772 2398 PRODUCTION 8852 7 8887 6980 Perforation depth: Measured depth: open hole completion 8887-12147 True Vertical Depth: 6980-7028 % AWED b-- t ' Tubing(size,grade,MD,and TVD) 4.5, L-80,8575 MD,6911 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER S-3 PACKER @ 8486 MD and 6869 ND SSSV-CAMCO BAL-O SSSV @ 1864 MD and 1711 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 127 2345 3602 -- 185 Subsequent to operation 142 2144 3397 -- 195 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory f Development 17. Service fl Stratigraphic r 16.Well Status after work: Oil 17. Gas r WDSPL r Daily Report of Well Operations -- GSTOR WINJ r WAG r GINJ r SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 312-399 Contact Michael Dammeyer Ca)265-6548 Email Michael.Dammeyer(a)conocophillips.com Printed Name Michael Dammeyer Title Sr. Production Engineer Signature � _. Phone:265-6548 Date /i /i i 1,3 �%.. ;�JSs, NOV 2 1 1/6"r i• /2//� cj � � Form 10-404 Revised 10/2012 Submit Original Only .CD1-25 Well Work Summary DATE SUMMARY 10/11/2013 Attempted to inject MI into the well, but were unable to do so due to high pressure. 0)„1 � j j -, THE STATE Alaska Oil and Gas 4' ''� a � of ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 T , 6.11'4 Michael Dammeyer Senior Production Engineer ConocoPhillips Alaska, Inc. -6)0T P.O. Box 100360 Anchorage, AK 99501 Re: Colville River Field, Alpine Oil Pool, CD 1 -25 Sundry Number: 312 -399 Dear Mr. Dammeyer: 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 holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this day of October, 2012. Encl. ' • FI_EpEIVED STATE OF ALASKA • ,� OCT 1 ? 2 ALASKA OIL AND GAS CONSERVATION COMMISSION 9 ° , ? i � ��, total( (' APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 AOGCC 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program ri Suspend r Plug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r . Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r1 200 -008 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20325 -00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes r No r CD1 - • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 372095, 25559 ' Colville River Field / Alpine Oil Pool 4 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): 12147 • 7028 • 12147' 7028' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 114' 114' SURFACE 2735 9.625 2771' 2398' PRODUCTION 8852 7 8887' 6980' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole completion 8887 - 12147 6980 - 7028 4.5 L - 8574 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER S -3 PACKER MD= 8486 TVD= 6869 SSSV - CAMCO BAL -S SSSV MD =1864 TVD= 1711 12. Attachments: Description Summary of Roposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r ' Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/29/2012 Oil r • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Michael Dammeyer @ 265 -6548 Email: Michael .Dammever(a.conocophillips.con Printed Name Michael Damme er Title: Senior Production Engineer / Signature ,..y ,� i Phone: 265 -6548 Date /,t��/ f 6 I! -z- Commission Use Only 66 Sundry Number:3 23 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No V( Subsequent Form Required: U ► // U 1_ APPROVED BY Approved by: 'i1 i COMMISSIONER THE COMMISSION Date: /6 2 3 / \/ Approved application is valid for 12 months from the date of approval. A N 0 1 A evi sed 10/2012) I/4 FIR - Submit r and Attachments in Duplicate x 0 R 16 of ,„2,3,,_ _ 8 OC1 2C1 fey, z__ WNS • CD1 -25 ConocoPhillips OP Well Attributes Max Angie & MD TD r • Alaska, If1C. Wellbore API /UWI Field Name Well Status !ncl (°) MD (ftKB) Act Btm (ftKB) Cnnocorlln� 501032032500 ALPINE PROD 91.10 10,122.31 12,147.0 "' Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date • Well Conti,: - cot -zs, 2/3r28t t 9 1 1 . 2 1 AM SSSV: WRDP Last WO: 43.40 3/17/2000 schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag: Rev Reason: FORMAT UPDATE Imosbor 2/3 /2011 Casing Strings i Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd "" IP CONDUCTOR 16 15.062 38.0 114.0 114.0 62.58 H - 40 WELDED ± ; Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd , SURFACE 95/8 8.750 36.3 2,771.5 2,398.1 36.00 J - 55 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 -( l 91 I . _e PRODUCTION 7 6.151 34.3 8,886.7 6,980.1 26.00 L -80 BTCM • Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd OPEN HOLE 61/8 6.125 8,887.0 12,147.0 7,028.0 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 32.3 8,574.9 6,910.9 12.60 L -80 IBTM Completion Details Top Depth (TVD) Top Inc! Nomi... -- Top (ftKB) (RKB) (•) Rem Description Comment ID (in) 32.3 32.3 -0.30 HANGER FMC TUBING HANGER 4.500 COND 380 1,864.3 1,710.7 40.91 SAFETY VLV CAMCO BAL -O SSSV "SSSV nipple damaged, oversize packing & 3.812 determination required to set SSSV (5/21/2002)*' — 8,442.8 6,845.2 55.07 NIPPLE HES'X NIPPLE 3.813 8,485.7 6,868.5 WIRELINE ENTRY GUIDE 58.69 PACKER BAKER S-3 PACKER 3.875 8,562.7 6,905.5 64.35 NIPPLE HES 'XN' NIPPLE 3.725 WRDP, 1,84 1 __ U '_ 1 8,573.6 6,9810.4 65.14 WLEG 3.958 SAFETV VLV 1.864 _ Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (81<8) (RKB) (°) Description Comment Run Date ID (in) 1,864.0 1,710.5 40.90 WRDP 3.812" WRDP (HVS -270) 6/10/2009 2.125 Stimulations & Treatments Bottom Min Top Max tam Top Depth Depth J SUR Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 8,887.0 10,850.0 6,980.1 6,979.4 Surfactant Wash 5/12/2002 ARDS SURFACTANT TREATMENT , 36 FACE-2,]]t Notes: General & Safety — ....... End Date Annotation 6/12/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, 4.7.4 4,834 GAS LIFT, 6338 GAS LIFT. 8,363 NIPPLE, 8.443 -- I PACKER, 8,486 NIPPLE, 8,563 — I J i EE I I I WLEG,8,574 ? Mandrel Details Top Depth Top Port (TVD) Inc] OD Valve Latch Side IRO Run Stn Top (1168) (ftKB) (1 Make Model (in) Sere Type Type (in) (psi) Run Date Com... 1 4,034.4 3,396.4 36.87 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5/13/2002 2 6,338.4 5,197.3 36.44 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/17/2000 3 8,362.7 6,795.6 48.89 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 11/8/2005 PRODUCTION, A • 34-8,887 0 Surfactant I • o Wash, 8,887 • OPEN HOLE, o t, 8, 12,147 as TD. TD, 12,147 • • • • ConocoPhillips proposes stimulating producing well CD1 -25 by injecting enriched • gas. The intent is to increase oil production rate as CD1 -25 did not return to its expected rate since an aqueous scale squeeze on 6/1/12. It is possible that water has imbibed into the formation and reduced the near - wellbore oil permeability. Note the potential for the Alpine C sand to imbibe water and reduce oil permeability is documented in SPE 84320. Enriched gas injected into the near - wellbore has the potential to restore oil permeability. Proposed treatment procedure: Inject -10 MMSCF of enriched gas down tubing within a 24 hour period, limiting injection pressure to 3000 psi. Leave well shut in for -12 hours after injection. Bring well on production& test well. STATE OF ALASKA ALFA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Fbrf orate r Other 57 Scale Inhibitor Treatment Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Stimulate - Other 1 Re -enter Suspended Well r 2. Operator Name: ' 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development rr Exploratory r 200 - 008 .. 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50 -103- 20325 -00 " 00 7. Property Designation (Lease Number): 8. Well Name and Number: ,. ADL 372095, 25559 ` CD1 - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): a none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 12147 feet Plugs (measured) None true vertical 7028 feet Junk (measured) None Effective Depth measured 12147 feet Packer (measured) 8486 true vertical 7028 feet (true vertucal) 6869 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 114 114 SURFACE 2735 9.625 2771 2398 PRODUCTION 8852 7 8887 6980 9cY JUL 2 4 d'I' RECEIVE® Perforation depth: Measured depth: open hole from 8887' - 12147' JUN 15 2012 True Vertical Depth: 6980' -7028' AOGCC Tubing (size, grade, MD, and ND) 4.5, L - 80, 8574 MD, 6910 TVD Packers & SSSV (type, MD, and ND) PACKER - BAKER S -3 PACKER @ 8486 MD and 6869 ND SSSV - CAMCO BAL - O SSSV @ 1864 MD and 1711 ND 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8887'- 12147' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure r Prior to well operation 566 2829 2581 -- 204 Subsequent to operation 303 2413 2706 -- 200 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development [7 . Service r Stratigraphic r 16. Well Status after work: f Oil I✓ Gas r WDSPL r Daily Report of Well Operations XXXX GSTOR r WINJ E WAG r GINJ r SUSP r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none , "� Contact Michael Dammeyer @ 265 -6548 W ✓f-�u�C ---/- Printed Name Michael Dammeyer Title CD1 Production Engineer Signature Phone: 265 -6548 Date G/11/12.- RE3DMS JUN 15 2 1 .dr.: , 'A"' T # tA Form 10 -404 Revised 11/2011 - /-111, / 17.i' Submit Original Only il WNS • CD1 -25 ConocoPhillips Well Attributes Max Angle & MD TD Alaska, InC. Wellbore API /UWI Field Name Well Status Inc' (°) MD (ftKB) Act Btm (ftKB) 501032032500 ALPINE PROD , 91.10 10,122.31 12,147.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date Well conra� - cot -zs 202011 s 11 21 AM SSSV: WRDP Last WO: 43.40 3/17/2000 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag Rev Reason: FORMAT UPDATE Imosbor 2/3 /2011 - , -- - -- - Casing Strings IR / lip Casing Description String 0... String ID ... Top (ftKB) Set Depth (f .. Set Depth (TVD) .. String Wt... String String Top Thrd CONDUCTOR 16 15.062 38.0 114.0 114.0 62.58 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) .. String Wt... String ... String Top Thrd SURFACE 95/8 8.750 36.3 2,771.5 2,398.1 36.00 J - 55 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 34.3 8,886.7 6,980.1 26.00 L - 80 BTCM il dll_ ' P Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd OPEN HOLE 6 1/8 6.125 8,887.0 12,147.0 7,028.0 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 32.3 8574.9 6,910.9 12.60 L -80 IBTM Completion Details Top Depth (TVD) Top Inc! Nomi... .-- -- Top (ftKB) (RKB) fl Rem Description Comment ID (In) 32.3 32.3 -0.30 HANGER FMC TUBING HANGER 4.500 CONDUCTOR,_ 1,86 1,710.7 40.91 SAFETY VLV CAMCO BAL -0 SSSV - SSSV nipple damaged, packing 3e pp ged, oversize ackin 8 3.812 determination required to set SSSV (5/21/2002)** 8,442.8 6,845.2 55.07 NIPPLE HES'X' NIPPLE 3.813 8,485.7 6,868.5 58.69 PACKER BAKER S3 PACKER 3.875 8,562.7 6,905.5 64.35 NIPPLE HES 'XN' NIPPLE 3.725 BAFET wRDP,Y l,efia . '� J 8,573.6 6,910.4 65.14 WLEG WIRELINE ENTRY GUIDE 3.958 1.864 1.864 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! ^- Top (ftKB) (ftKB) (1 Description Comment Run Date ID (in) 1,864.0 1,710.5 40.90 WRDP 3.812" WRDP (HVS -270) 6/10/2009 2.125 Stimulations &Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment SURFACE. . 8887.0 10,850.0 6,980.1 6,979.4 Surfactant Wash 5/12/2002 ARDS SURFACTANT TREATMENT 36 -2,771 Notes: General & Safety End Date Annotation 6/12/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT,_ 4034 ff GAS LIFT, -. 6,338 1 GAS LIFT. l_ 8,363 NIPPLE, 8,443 ! 1 PACKER. 8.486 NIPPLE, 8,563 i WLEG,8,574 A� Mandrel Details Top Depth Top Port (TVD) Inc( OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 4,034.4 3,396.4 36.87 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5/13/2002 2 6,338.4 5,197.3 36.44 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/172000 3 8,3627 6,795.6 48.89 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 11/8/2005 PRODUCTION, A 34-8,887 • Surfactant • Wash, 8,887 or • OPEN HOLE, o 8,887 - 12,147 • TO,12,147 • Scale Inhibition Treatment: CD1 -25 6/1/2012: Initial pressure TBG — Not given; Facility pumped 50 bbls SW preflush; LRS pumped 3.9 bbls WAW5206 (164 gal) at 0.4 bpm and facility pumped 36 bbls SW, 1100 psi; LRS pumped 39.3 bbls SCW3001WC (1651 gals) at 0.65 bpm and facility pumped 223 bbls of SW, 1375 psi; LRS pumped 3.9 bbls WAW5206 (164 gal) at 0.4 bpm and facility pumped 36 bbls SW, 1290 psi; facility pumped 982 bbls of SW over - displacement. . . Conoc~Phillips Alaska ,"in i1 §-, ¡ !\ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ,& March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 scANNED APR 1 () 2007 0- ÐOß ðvÐ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ITom 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 ITom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 1R.!=1 2/16/2007 Alpine Field March 31,2007 F:\LaserFiche\CvrPgs _ Inserts\Microfilm_ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE '~''!oo~~,. ~~-...~ " '" ' . \ '¡ ~. Permit to Drill No. 2000080 MD 12147 TVD DATA SUBMITTAL COMPLIANCE REPORT 3/21/2002 Well Name/No. COLVILLE RIV UNIT CDI-25 Operator PHILLIPS ALASKA INC. 7028 Completion Date 3/17/2000~j Completion Status 1-OIL Current Status AP1 No. I-OIL 50-103-20325-00-00 UIC N REQUIRED INFORMATION Mud Log No Samples N~o Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Na~ne c.~ SRVY RPT CDR~TVD ~/~,DR-MD Production Profi (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Scale Media No Start Stop CH Dataset Received Number Comments 25 FINAL 25 FINAL 2 FINAL 0 2400 2771 8700 12147 OH O 6980 OH 12100 OH 12031 CH 3/31/2000 SCHLUM 4/28/2000 09496 J' 2771-12147 4~28~2000 4~28~2000 6/15/2001 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORM~A~ION Well Cored? Y / ~) Chips Received? ~ Analysis Received?----Y-Z2~ Daily History Received? Y~//N Formation Tops Receuived? Q/N Comments: Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 393' FNL, 2874' FEL, Sec. 5, T11N, R5E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (asp's 385830, 5975736) 6. Datum elevation (DF or KB feet) RKB 37 feet 7. Unit or Property name Colville River Unit 8. Well number CD1-25 At top of productive interval 2448' FSL, 1274' FWL, Sec. 4, T11N, R5E, UM At effective depth At total depth 596' FNL, 2304' FEL, Sec. 9, T11N, R5E, UM (asp's 391614, 5970167) 9. Permit number / approval number 200-008 / 301-212 10. APl number 50-103-20325 11. Field / Pool Alpine Oil Pool 12. Present well condition summary Total depth: measured true vertical 12147 7028 feet feet Plugs (measured) Effective depth: measured true vertical 12147 feet 7028 feet Junk (measured) Casing Length CONDUCTOR 114' SURF CASING 2771' PROD CASING 8887' OPEN HOLE 3260' OPEN HOLE Perforation depth: measured None Size 16" 9-5/8" 7" Cemented 10 cu yds Portland Type 3 391 sx AS III LW, 230 sx Class G 136 sx Class G Measured Depth 114' 2771' 8887' 12147' True vertical Depth 114' 2398' 6980' 7028' RECEIVED true vertical None Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 8575' MD. Packers & SSSV (type & measured depth) BAKER S3 PACKER @ 8486' MD. CAMCO BAL-O @ 1864' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) 8887' - 10850' Treatment description including volumes used and final pressure See attachment 14. Prior to well operation Subsequent to operation OiI-Bbl 4900 Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl 4100 0 4937 4127 0 Casing Pressure Tubing Pressure - 231 242 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Gas _ Suspended _ Service _ 17. I hereby certify that the f~oregoing is true and correct to the best of my knowledge. Signed ~~~~_ Title: Alpine Engineer Chris R. Piersdn ~ Questions? Call Chris Pierson 265-6112 Date Prepared by Sharon Al~sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE CD1-25 Event History Date 3/19/2OO2 3/21/2002 3/23/2OO2 3/24/2002 3/25/2OO2 3/27/2002 4/3/2002 4/6/2002 4/7/2002 4/8/2002 4/9/2OO2 Summary PULLED SSSV @ 1864' RKB. MAKE SEVERAL RUNS ATTEMPTING TO SET PXN PLUG BUT RUN INTO MUD AT 8330' WLM WELL TOO DIRTY TO SLICKLINE IN. WASHED TUBING WITH VORTECH NOZZLE, DIESEL & GELLED DIESEL. CLEANED OPENHOLE TO 10,550' IN 2 BITES WITH GEL SWEEPS. WORKED FROM 10,600' TO 11,070' WITH DIFFICULTY, COULD NOT PASS 11,070'. APPEARS TO BE HEAVY DEBRIS AND/OR EXCESSIVE PIPE FRICTION BELOW 10,600'. NEVER SAW SOLIDS IN RETURNS UNTIL WE DRAINED THE FLOW BACK TANKS.[] [FCC, Vortech] ATTEMPTED TO RUN WEATHERFORD BHA TO 12,000'. MADE IT TO 10,400' CTMD O-RING BELOW INJECTOR HEAD ABOVE BOP'S FAILED. PULLED CCH. PREP TO CHANGE O-RING, CONTINUE IN THE MORNING.[] [FOCI ATTEMPTED TO RIH WITH FDR TOOL ABOVE A 2 3/8" PDM TO ACHIEVE A TARGET DEPTH OF 12,000'. 11,000' WAS ACHIEVED TODAY WITH A FAIR AMOUNT OF EASE. DURING A WIPER RUN AT 11,000' THE FDR APPEARED TO QUIT WORKING. TRIP PIPE TO INSPECT TOOLS, FOUND THAT FDR PRESSURE INTEGRITY WAS AT FAULT. RE-DRESS TOOL, AND PREPARE TO RE-RUN IN THE MORNING.[] [FOCI AFTER TWO RUNS WITH THE WEATHERFORD FDR TOOL WE WERE ABLE TO ACHIEVE A CTMD OF 10,304.5'. THE FDR TOOL, AND PDM WERE WORKING. PRIOR TO POOH PACK OFF HOSE BECAME PLUGGED ALLOWING DIESEL TO SPRINKLE ON THE SNOW, FLOW LINES, AND A FEW WELL HOUSES. NOTIFIED ALL PERSONAL IN THE ALPINE CONTINGENCY PROGRAM FOR CLEANUP. FUTURE OF SURFACTANT TREATMENT TO BE DISCUSSED WITH ANCHORAGE. QUITE POSSIBLY TO BE AT A LATER DATE. r~ BLOW DOWN CTU #6 COIL WITH NITROGEN FOR REEL SWAP. TAGGED OBSTRUCTION @ 8585' WLM. RECOVERED BAILER FULL OF MUD & SMALL ROCKS. ATTEMPT SET SSSV. UNABLE TO ESTABLISH CL INTEGRITY. PULL SSSV. SUSPECT POSSIBLE NIPPLE DAMAGE. PLAN TRY OVERSIZE PKG LATER.[] [Tag, SSSV Work] ENCOUNTERED SOLIDS ON LOW SIDE OF HOLE F/4780' WLM TO BOTTOM. RECOVERED SAMPLE. CALLED TO EXPLORATION SUPPORT, JOB SUSPENDED. BAILED MUD IN TBG FROM 5720' TO 5780' WLM. IN PROGRESS. RAN BAILER INSIDE 3.70 BELL GUIDE; BAILED FROM 5780 ' TO 5797' WLM, POOR PROGRESS. ATTEMPT SET SSSV, NO SUCCESS. IN PROGRESS.[] [SSSV Work] BRUSH SCSSSV NIPPLE @ 1834' WLM SET 3.812 WRDP-2 SCSSSV @ 1834' WLM GOOD CLOSURE TEST BUT VALVE WOULD NOT HOLD HYDRULIC PRESSURE PULL SCSSSV BACK OUT & R/D CD1-25 Event History 4/11/2002 4/12/2002 4/29/2OO2 5/9/2002 5/11/2002 5/12/2O02 5/13/2002 5/14/2002 5/16/2002 5/19/2002 SET SPECIAL BUILT SCSSSV @ 1864' RKB TEST PERFECT SCSSSV IN SERVICE. TURN WELL OVER TO DRILL SITES FOR PRE-PRODUCTION SET UP. LITTLE RED ON LOC TO ASSIST START UP FLOW BACK PROCEDURES OF CD1-25. WELL ON LINE AND CURRENTLY FLOWING AT 9200 BOPD. 115 DEG. 78% CHOKE. 445 FWHP. LEAVE WELL FLOWING RELEASE LITTLE RED BACK TO KUPARUK. APRIL RENTAL FOR SIDE POCKET GAUGE PULLED 3.813 SPECIAL CAMCO WRDP-2 W/OVERSIZE PKG @ 1836' WLM DRIFT TUBING W/3.70 DRIFT TOOL WENT TO 8574' WLM +25' CORRECTION = 8599' RKB ABOUT 24' BELOW EOT MUD IN BAILER MADE I ATTEMPT TO BOTTOM W/MHA/STABILIZERNIBRATOR/WGT BAR/3" JS NOZZLE; AT 10,280' FDR PLUGGED. 2ND ATTEMPT, CHANGED BHA TO ONLY MHA/X-OVER/2.4" JS NOZZLE, BULLHEADING 43 BBL OF COCKTAIL IN HOPES OF REDUCING PIPE FRICTION; HUNG UP ON LEDGE, UNABLE TO EXIT SHOE. 3RD ATTEMPT, RIH W/ MHANIBRATOR/STABILIZER/X-OVER/2.4" JS NOZZLE. JETTED SURFACTANT WHILE RIH THRU OPENHOLE, SET DOWN AT 10,850', BEGAN TREATING FROM THERE. TREATED TO 10,130' BEFORE SHUTTING DOWN DUE TO SPILL, 232 BBL SURFACTANT PUMPED SO FAR. CONT'D ON NEXT WSR.[3 [Other Stim] TREATED OPENHOLE FROM 8887' TO 10,850' CTM W/1150 BBLS 150 DEG. SURFACTANT/DIESEL COCKTAIL AT 5'-10'/MIN, 1.5 BPM. TREATMENT SIZED FOR AVERAGE 26" PENETRATION FROM WELLBORE. TREATING PRESSURE STEADY THROUGHOUT JOB AT -100 PSI OVER SHUT-IN PRESSURE.E} [Other Stim] TRY TO PULL GLV'S & EMR GOT 1" SPARTEK EMR OUT OF BOTTOM GLM HAVE TO LAY LUB DOWN AFTER EACH TRIP TO CLEAN PACKED MUD OUT. TOOLS MOVE VERY SLOW IN & OUT OF WELL MUD EVERYWHERE IN TUBING GOT CATCHER TO XN NIPPLE @ 8540' WLM TOOK TWO HOURS TO GET THERE. WELL NEEDS TO CLEAN UP. PUT 1' OV IN BOTTOM GLM & PULL 1" OV OUT OF TOP GLM & SET 1" DUMMY GLV IN TOP GLM SHUT DOWN FOR NITE WILL CONTINUE TOMORROW.r~ [Pressure Data, GLV] PULLED 3.810 CATCHER SUB FROM XN NIPPLE @ 8540' WLM TRY TO SET SCSSSV WOULD NOT HOLD PRESSURE WILL WAIT ON WELL TO CLEAN UP. PULL SCSSSV OUT R/D POST SURFACTANT FLOWBACK TO TANKS AND SWITCH TO FACILITIES TRY TO SET SCSSSV IN DAMAGED BAL-O NIPPLE RAN SPECIAL 3.812 WRDP W/OVERSIZE PACKING & SET IN DAMAGED BAL-O NIPPLE @ 1864' RKB WOULD NOT PASS STATE TEST PULLED BACK OUT NO SCSSSV IN WELL CD1-25 Event History 5/21/2002 SET SPECIALLY PREPARED 3.812 CAMCO WRDP-1 SCSSSV W/ OVERSIZE PACKING IN DAMAGED BAL-O NIPPLE @ 1864' RKB PERFECT SET & PERFECT STATE TEST JOB COMPLETE SCSSSV IN SERVICE PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Pierson Phone (907) 265-6112 Fax: (907) 265-6224 June 10,2002 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations CD 1-25 (200-008 / 301-212) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation treatment operations on the Alpine well CD 1-25. If there are any questions, please contact me at 265-6112. Sincerely, C. Pierson Alpine Production Engineer Phillips Alaska, Inc. CRP/skad RECEIVED JUi'I i 2 2002 Naska 0ii & Gas Cons, [;omm~ss~or Anchorage ORi®i AL PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 25, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the second quarter of 2000, as well as total .volumes injected into annuli for which injection authorization expired during the second quarter of 2000. Annular Injection during the second quarter of 2000: ~ h(1)~ h(2)' h(~) Totaifor Previous New Well Name Volume Volume Volume Quarter Total Total 2N-341 20406 100 0 20506 0 20506 2L-313 4640 100 0 4740 12533 17273 CD1-40 108 100 0 208 32669 32877 CD1-23 16751 100 0 16851 17135 33986 CDI-16 25 0 0 25 29025 29050 CD1-32 82 100 0 182 33331 33513 CD1-38 11056 100 0 11156 9164 20320 CD1-27 32333 100 0 32433 381 32814 1L-28 5853 100 0 5953 3984 9937 ~' 1D-11 135 100 0 235 0 235 1D-14 1337.6 100 0 1437.6 0 1437.6 CD1-25 8141 100 0 8241 386 8627 CD1-34 278 100 0 378 0 378 Annular Dis ~osal durin the second quarter of 2001: /'¢%//5 h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date / 1C-17 33139 100 0 33239 0 33239 May01 Jun01 1¢-133, lC-121, 1¢-123, 1¢-127 > 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N'314, 1J-03 16904 100 0 17004 13120 30124 Mar 01 May 01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2001: ............................... j ............. ~ .................. ~. ,.,. ~. Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus ~ 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 ' 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- ~ 2000 35, CD 1-32, CD 1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only - CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the third quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 2000. Annular Injection during the third quarter of 2000: h(1) h(~) h(3) Totalfor Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 D CD1-03 33505 100 0 33605 385 33990 ? 1D-14 33916 100 0 34016 1487.5 35503.6 ~CD1-25 24860 100 0 24960 8627. 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _X Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 37' feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__ Colville River Unit 4. Location of well at surface 8. Well number 393' FNL, 2874' FEL, Sec. 5, T11 N, R5E, UM (asp's 385830, 5975736) CD1-25 At top of productive interval 9. Permit number / approval number 2448' FSL, 1274' FWL, SEC. 4, T11 N, R5E, UM (asp's 389948, 5973240) 200-008 At effective depth 10. APl number 50-103-20325 At total depth 11. Field / Pool 596' FNL, 2304' FEL, Sec. 9, T11N, R5E, UM (asp's 391614, 5970167) Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured 12147 feet Plugs (measured) true vertical 7028 feet Effective depth: measured 12147 feet Junk (measured) true vertical 7028 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 114' 16" lO cu yds Portland Type 3 114' 114' SURF CASING 2771' 9-5/8" 391 SxAS III LW, 230 Sx Class G 2771' 2398' PROD CASING 8887' 7" 136 Sx Class G 8887' 6980' OPEN HOLE 3260' 6.125" 8887'-12147' OPEN HOLE Perforation depth: measured None RECEIVED true vertical None JUL Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 Tbg @ 8575' MD. Alaska Oil & Gas Cons. Commission Anchorage i Packers & SSSV (type & measured depth) BAKER S3 PACKER @ 8486' MD. CAMCO BAL-O @ 1864' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: August 15, 2001 16. If proposal was verbally approved Oil __X Gas __ Suspended Name of approver Date approved Service 17. I hereb,,ycertify that the foregoing is true and correct to the best of my knowledge. Questions? Call Michael Erwin @ 265-1478. Signe . Title: Alpine Production Engineer Dat Michael :twin Prepared b~/ Sharon AIIsup-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: PlugN°tifYintegrityC°mmissi°n__ so representatiVeBoP Test __ may witneSSLocation clearance__~' , ,.. I Approval no.3(~ [ '"'C:~' ~ r~ Mechanical Integrity Test _ Subsequent form required 10- ORIGIN~ SIGNED i~¥ , - Approved by order of the Commission J' j~° J'J~J~' Commissioner Date Form 10-403 Rev 06/15/88 · ORI INIAL SUBMIT IN TRIPLICATE Stimulation Procedure Colville River Field CD1-25 Conversion operations will commence on or after August 1,2001. Completion is expected before December 15,2001. This procedure is designed to reduce the residual water saturation (water block) and stimulate a producing well by restoring the initial fluid saturation to the wellbore. 1. RU coil tubing unit. GIH with jet nozzle into the 6-1/8" open hole to circulate and wash the hole clean of debris or sand with diesel. 2. Spot one wellbore volume of 2-3% mutual solvents and surfactants blended into a diesel base fluid in the openhole interval. 3. Pump approximately 1000 bbl. of solvent and diesel at matrix injection rates. 4. POOH and RD coil tubing. 5. Allow the breaker to soak for 24 hours. 6. Return the well to production. Flowback and clean up the well. Annular Disposal durin the second 'uarter o~2001: h(1) h(2) h(3) Total for Previous New Start End SourCe Wells Well Name Volume Volume Volume ,Quarter Total Total ,, Date Date 1C-17 33139 100 0 33239 0 33239 May01 Jun01 1c-133, 1c-121, 1c-123, 1c-127 2N-318 2883 100 0 2983 1399~ 16978 Dec 00 Jun 01 2N-302, 2N-314, ,,, 1J.03 16904 100 0 17004 13120 30124 Mar01 May01 ~ 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2.24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli for which Disposal Authorization Expired during, the second quarter 2001' ' Total Volume ' ' Start End ' Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Free'ze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down ..... 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only , CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD 1-NQ1 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 31, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 - REVISED Dear Ms. Mahan: Please find attached the revised report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. We have revised the amount for CD2-42 because the original manifest incorrectly reported the CD2-24 annulus used for the disposal. Please call me at 263,4603 should you have any questions. Sincerely, . Paul Mazzolini Drilling Team Leader PM/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 17, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC: Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morfison and M. Cunningham Sharon Allsup-Drake Well Files RECEIVED JUL 1 9 2001 Alaska Oil & Gas Cons. Commission Anchorage Annular Disposal durin the second quarter of 2001: · h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1c-133, 1c-121, 1c-123, 1c-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 16902 100 0 17002 0 17002 May 01 Jun 01 CD2-24 .......... 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annul £or which Disposal Authorization Expired during the second quarter 2001: ' Total Volume T . Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus ,,, 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD 1-32, CD 1-24, ... CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down .... CD1,34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CDi2 33, CD1-NQ1 =~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 393' FNL, 2874' FEL, Sec. 5, T11N, R5E, UM At top of productive interval 2448' FSL, 1274' FWL, SEC. 4, T11N, R5E, UM At effective depth At total depth 596' FNL, 2304' FEL, Sec. 9, T11N, R5E, UM 5. Type of Well: Development __X Explorato~___ Stratigraph lc__ Service__ (asp's 385830, 5975736) (asp's 389948, 5973240) (asp's 391614, 5970167) 6. Datum elevation (DF or KB feet) RKB 37' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-25 9. Permit number / approval number 200-008 / 301-110 10. APl number 50-103-20325 11. Field / Pool Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 114' SURF CASING 2771' PROD CASING 8887' OPEN HOLE 3260' Size 16" 9-5/8" 7" 6.125" 12147 7028 12147 7028 feet Plugs (measured) feet feet Junk (measured) feet Cemented 10 cu yds Podland Type 3 391 Sx AS III/W, 230 Sx Class 136 Sx Class G Measured Depth True verticalDeplh 114' 114' 2771' 2398' 8887' 6980' 8887'-12147' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 8575' MD. Packers & SSSV (type & measured depth) BAKER S3 PACKER @ 8486' MD. CAMCO BAL-O @ 1864' MD. RECEIVED JUN 1 2001 Alaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 3502 Subsequent to operation 3201 Representative Daily Average Production orlnjection Data Gas-Md W~er-Bbl 3494 0 3171 1 Casing Pressure Tubing Pressure 353 392 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended _ Service 17. I her~y certify that the foregoing is true and correct to the best of my knowledge. Sign Title Alpine Production Engineer Michael Erwin Prepared by Sharon A//sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE Operations Summary CD1-25 4/29/2001: PULL SCSSSV FROM 1864' RKB, INSTALL CATCHER AT 8563' RKB, PULL DGLV #3 FROM 8362' RKB, SET SPARTEK GAUGE AT 8362' RKB, PULL CATCHER FROM 8563'RKB LEFT SCSSSV OUT 5/6/2001: FORMIC ACID TREATMENT COMPLETED. LAYED 127 BBLS OF 8% FORMIC ACID ACROSS 3013' OF THE OPEN HOLE SECTION 11900'- 8887', MAINTAINING RETURNS @ .8 TO 1.THEN SQUEEZED IN THE REMAINING 46 BBLS. USED BOTH THE PIPE STRAIGHTENER & FDR TO MAKE DEPTH BUT SHORT OF TD @ 12147'. FREEZE PROTECTED WELLBORE DOWN TO 2000' W/DIESEL. 5/7/2001: POST FORMIC ACID TREATMENT FLOWBACK COMPLETED. TOTAL LIQUID FLOWED BACK WAS 389 BBLS (150 BBLS DIESEL, 120 BBLS ACID/BRINE, 155 BBLS CRUDE, & 147 MSCF GAS). UTILIZED L/G TO KICK THE WELL OFF. ACID WATER RETURNS BROUGHT BACK SOLIDS/EMULSIONS & PH OF 4. RETURNS SHOWED TO BE 100% CRUDE AT THE END. TURNED WELL BACK INTO PRODUCTION. 5/22/2001- SET WRDP-2 (HRS-276) @ 1846' SLM. [SSSV Work] STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing_ Repair well _ Plugging _ Time extension _ Stimulate _X Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 37' feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Colville River Unit 4. Location of well at surface 8. Well number 393' FNL, 2874' FEL, Sec. 5, T11N, R5E , UM (asp's 385830, 5975736) CD1-25 At top of productive interval 9. Permit number / approval number 2448' FSL, 1274' FWL, SEC. 4, T11 N, R5E, UM (asp's 389948, 5973240) 200-008 At effective depth 10. APl number 50-103-20325 At total depth 11. Field / Pool 596' FNL, 2304' FEL, Sec. 9, T11N, R5E, UM (asp's 39~614, 5970~67) Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured 12147 feet Plugs (measured) true vertical 7028 feet Effective depth: measured 12147 feet Junk (measured) true vertical 7028 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 114' 16" 10 cu yds Portland Type 3 114' 114' SURF CASING 2771' 9-5/8" 391 Sx AS I11LW, 230 Sx Class G 2771' 2398' PROD CASING 8887' 7" 136 Sx Class G 8887' 6980' OPEN HOLE 3260' 6.125" 8887'-12147' OPEN HOLE Perforation depth: measured NoneNECEIVED / PR 2 7 2001 true vertical None A~ OW & Gas Cons. Commission Tubing (size, grade, and measured depth 4-1/2'', 12.6#, L-80 Tbg @ 8575' MD. "~c~e Packers & SSSV (type & measured depth) BAKER S3 PACKER @ 8486' MD. CAMCO BAL-O @ 1864' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: May 1,2001 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Michael Erwin @ 265-1478. Signed i ~' -[.*~Lt. ¢3-(k;,~( ~ " L,.~~ Title: Alpine Production Engineer Date Michael Erwin Prepared by Sharon AIIsup-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- ORIGINAL SIGNED BY D Taylor Seamount Approved by order of the Commission Commissioner Date ~' q, 0 [ Form 10-403 Rev 06/15/88 · nRIRIkiAI SUBMIT IN TRIPLICATE Stimulation Procedure Colville River Field CD1-25 Conversion operations will commence following ice road construction on or about April 1,2001. Completion is expected on or about May 15,2001. This procedure is designed to clean out and stimulate a newly drilled producer. The goal is to remove filtercake, drilled solids, and polymer from the openhole completion. 1. RU coil tubing unit. GIH with jet nozzle into the 6-1/8" open hole to circulate and wash the hole clean of debris or sand with diesel. 2. Spot +/-150 bbl. of DS 8% formic acid mixed in a 6% KCL base fluid in the openholeinterval. ~ ~ ~ 3. POOH and RD coil tubing. 4. Allow the breaker to soak for 4-6 hours. 5. Return the well to production. CTD BOP Detail 1'~ CT Injector Head Methanol Injection '""?'~'} I -- 7" Riser tis 7" WLA Quick I' 'l onnect - I I I 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Hydril Model B Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure I 2 3/8" Slips 3/8" Pipes Kill line check valve Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpip manifold 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic xo spool 3 1/8' x 71/6' or as necessary 2' Side outlets I Blind/Shear I 2" Combi Pipe/Slip 2 flanged gate valves Single or Double Manual Master Valves THA I Tubing Spool F 7" Annulus 9 5/8" Annulus MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, ~ ,~.~' DATE: March 30, 2001 Commissioner *~ Tom Maunder, P. !. Supervisor FROM' Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Colville River Unit CD1 Pad F. riday, March .30, 2001: ! traveled to the Phillips Alaska's Alpine Field and witnessed a portion of the safety valve System tests on CD1. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 8 wells and 24 components with no failures observed. The Rosemount Iow-pressure switches (located in the manifold building) performed very well tripping at the set point on all wells tested. The surface safety valves on these wells operate very slowly probablY due to being exposed to the elements and the length of the control line from the hyd' panel to the wellhead. · Gary Saltenreick conducted the testing today he demonstrated a good working knowledge of the system and was a pleasure to work with. summary: I Witnessed a portion of the semi-annual SVS testing at the CD1 Pad in the Alpine Field. CRU CD1 Pad, 8 wells, 24 components, 0 failures Attachment: SVS CRU CD1 Pad 3-30-01 CS .... X. unclassified Confidential (Unclassified if doc. Removed) SVS CRU CD1 3-30-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ,,.Phillips Operator Rep: Jack Kralick .. -:-. _. : , i AOGCC Rep: Chuck Seheve Submitted By: Chuck Scheve Field/Unit/Pad: Alphe/CRU/CD1 Separator psi: LPS 143 Date: 3/30/01 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, Gm J, Numbe.r,., .Numbe. r PSI PSI Trip Code Code Code Passed GAS or CYCLE CD 1-01 1990460 CD1-06 2000830 t. CD1-09 2000710 cDI-13 .... 1990520 ............................................ CDI-16 1990940 CDI'17 2001450 145' 100' ...... 100 ..... P ..... P P ................ oIL CD1-22A ,.2001100 143 ...... 100 100 ,.p p p ........... OIL :cD1-24 1996260' 143 100 "i00 P 'P ...... P .... OIL ~ "20006S0 "143 .... 100i" '100 "' V .... P" P .... oil CD 1-27 2000060 CDI'30 2001320 cD1-32 1991040 CD1-34 2000430 cDi-'35 1990380 143'1 ..... i'00 'i00 '" P "' P P ............... 0i£ CD1-38 2000030 . CD 1-40 1990440 CD1-41 2000170 CDI'-~3 2001060 ........... ' · ,-.,, ~ , , ,~ ~ , , t , ,,,~,, ~ , , , . , , . , ~ _. ,i , ~ ,. , , ,, CD1-44 2000550 CD1-04 " '2001170 1~43 1'00 " i00 P "' P "' e ........ OiL cDI-10 5001710! 143 100 100 P P 1~' OIL CD1-29 143 10'0 100 P' P P OIL Wells: 8 Components: 24 Failures: 0 Failure Rate: 0.00% f'39o Day Remarks: RJF 1/16/01 Page 1 ofl 010330-SVS CRU CDI-CS PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: ~? ~ :~ ~,,~ Please find reposed below the volumes injected into surlhce casing by ~6duct~on casing annuli during the third queer of 2000, as well as total volumes injected into annuli for which injection authorization expired during the third queer of 2000. Annular Injection during the third quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 CD1-03 33505 100 0 33605 385 33990. , 1D-14 33916 100 0 34016 1487.5 35503.6 CD1-25 24860 100 0 24960 8627 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907. 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 Ms. Wendy Mahan AOGCC Third Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the third ,uarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD1-39 31408 100 0 31508 Open, Freeze Protected 1D-12 32791 100 0 32891 Open, Freeze Protected CD1-37 32487 100 0 32587 Open, Freeze Protected CD 1-23 33886 100 0 33986 Open, Freeze Protected CD1-01 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files Schhnnberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121389 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine 4/19/00 Color Well JOb # Log Description Date BL Sepia Prints CD CD1-23 20158 SCMT 000331 1 teD-2 Ut ¢.. INJECTION PROFILE 000406 I 1 ~-D-2 ~,~ RST/WFL 000406 I 1 CD1-25 20162 MD CDR 000314 I 1 .... CD1-25 20162 TVD CDR 000314 I 1 CD1-25 4'~..~ ~'~ C~; 20162 M10/CDR IMPULSE 000314 1 ...... I RjCEiVi D s~*.~~ ~^,~: APR 28 ~000 Alaska 0ii & Gas C=~;~. ~u.~missi0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank~0rage · ' TEST and FORMATION INTEGRITY TEST !~ Well Name: CD1-25 Date: 3/11/00 SuPervisor: Donald Lutrick [] Initial Casing Shoe TeSt Reason(s) for test: [] Formation AdeqdanCy for Annular Injection [] Deep TeSt: Open Hole AdeqUacy for Higher Mud Weight CaSing size and D~sCripti°n: 9 5/8" 36# J-55 BTC cSG X 7" 26# L-80 aTCM CSG casing Setting DePth: Mud Weight: TOC 2,772' TMD Hole Depth: 8,140' TMD 2,400' TVD 6,625' TVD 9.6 ppg Length of Open Hole: 4,388' + Mud Weight - 661 psi + 9.6 ppg -- 0~0.52 X 2,400' EMW ~;!4 9 ppg I press ; 052XTVD pump OUtpUt = .020 BPS Fluid Pumped = 11.0 bbl **~US~ cement unit BLED BACK = BBLS LEAK-OFF DATA MINU'FES FOR LOT BELS PRESSURE 0.0 bbls 0.5 bbls 41 psi 1.0 bbls 61 psi 1.5 bbls 2.0 bbls 2.5 bbls 3.0 bbls 3.5 bbls 4.0 bbls 4.5 bbls 5.0 bbls 384 psi 5~5 bbls 444 PSi t6.0 bbls 510 psi 6.5 bbls ........ I 7.0 bbls .......... ~ 7.5 bbls ' 8,0 bbls 1.0 mir 611 psi 2.0 miR 596 psi 3.0 mir 594 psi 4.0 miR ~. 591 psi 5.0 miR ; _59_J..P.s~i_. 6.0 mir j . 581 psi 7.0miR ! i 596~_~i '-~.0 mi~-] .......... .-l-'~"~' psi'" ........ · ! ........... J ............ ~OTE: STROKES TURN TO MINuTEs DURING "SHUT IN TIUE":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS ~E DELETE PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Doug Chester Phone (907) 263-4792 Fax: (907) 265-6224 May 17, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ORIGINAL Subject: CD 1-25 (Permit No. 200-08) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on CD 1-25. If there are any questions, please call 263-4792. Sincerely, D. ~~st~~ er5/~/~/~~ ..... Alpine Drilling Team Leader PAl Drilling DC/skad RECEIVED ' 2- 2000 A~aska Oi! & Gas Cons. Comi'nis't'.~io~', STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r'~ Gas D Suspended D Abandoned D Service D 2. Name of Operator ' [OC,,~~' 7. Permit Number Phillips Alaska, Inc. V~ 200-08 3. Address ..~4J¢1~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~,,~~ 50-103-20325-00 4. Location of well at surface c --~ 9. Unit or Lease Name 394' FNL, 2405' FWL, Sec. 5, T11 N, R5E, UM (ASP: x:385,830, y: 5975,735), : Colville River Unit ~ 10. Well Number At Top Producing Interval ! ~,: ,-~/"7: 2448' FSL, 1274' FWL, Sec. 4, T11N, R5E, UM (ASP: 389948, 5973240) ! _~__.. CD1-25 At Total Depth ;'',,~.~. 11. Field and Pool 596' FNL, 2304' FEL~ Sec. 9~ T11N~ R5E~ UM (ASP: 391614~ 5970167) ......... ' " Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. Alpine Oil Pool 37' RKB feetI ADL 372095 & 25559 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions March 3, 2000 March 14, 2000 March 17, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12147' MD/7028'TVD YES [~] No E]I 1864' feetMD 1678' 12147' MD/7028' TVD 22. Type Electric or Other Logs Run GR/Res/Neut/Dens 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP BO-I-I'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2771' 12.25" 391 sx ASIII LW & 230 sx Class Gl 7" 26# L-80 Surface 8887' 8.5" 136 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" 8575' 8486' 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.) Waiting on Facility Start-Up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. Alpine C GEOLOGIC MARKERS NAME MEAS. DEPTH 8644' TRUE VERT. DEPTH 6937' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 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. Signed X~~/~~' C~~/~,g ....... Title ' v v-//este7 ~, · -, ,,- Alpine Drilling Team Leader Questions? Call Brian Robertson 265-6034 Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 04/14/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-25 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: ALPINE SPUD:03/03/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: --- WI: 0% SECURITY:0 API NUMBER: 50-103-20325-00 03/03/00 (D1) TD/TVD: 535/535 SUPV:DONALD LUTRICK MW: 8.9 VISC: 250 PV/YP: 14/72 (535) DRLG AT 1000' APIWL: 19.0 Move rig from CD1-27 to CD1-25. NU diverter system and function test. Held pre-spud meeting. Drilling from 114' to 444'. Gyro each std. 8" motor not building angle as needed. POH. RIH. Motor froze. Pull motor into riser. Apply steam. Check bit for plugged nozzles. RIH. Drilling from 444' to 535' 03/04/00 (D2) MW: 9.6 VISC: 190 PV/YP: 15/55 APIWL: 12.0 TD/TVD: 2782/2406 (2247) RU TO RUN 9 5/8" CSG SUPV:DONALD LUTRICK Drilling from 535' to 2782'. Circ hi vis sweep. Wiper trip to 1450'. No problems. Circ hi vis sweep. 03/05/00 (D3) MW: 9.6 VISC: 50 PV/YP: 13/11 APIWL: 18.0 TD/TVD: 2782/2406 ( 0) TEST 9 5/8" CSG SUPV:DONALD LUTRICK Circ hole clean. POH. Tight at 1150' Held PJSM. RIH w/9-5/8" casing. No problems. PJSM. Pump cement. Bumped plug. Check floats. ND diverter. NU BOPE and test to 300/3500 psi. 03/06/00 (D4) MW: 9.6 VISC: 43 PV/YP: 11/23 APIWL: 6.3 TD/TVD: 3825/3229 (1043) DRLG AT 4608' SUPV:LUTRICK/REILLY/CHESTER Finish test BOPE. Rebuild manifold valve #13. Replace dies in top drive grabs. Work on sheared bolts in top drive. Tag up at 2660'. CBU. Test casing to 2500 psi. Drill out cement, float equipment and 20' new formation to 2802'. CBU. Perform FIT, 16 ppg EMW. Displace to 9.6 LSND mud. Drilling from 2802' to 3825'. Circ hole clean. Wiper trip to shoe. No problems. 03/07/00 (D5) MW: 9.6 VISC: 40 PV/YP: 8/23 APIWL: 5.7 TD/TVD: 6680/5470 (2855) DRLG AT 7300' SUPV:LUTRICK/REILLY/CHESTER Drilling from 3825' to 5347'. CBU. Wiper trip to 3825'. No problems. BOP drill while tripping. Drilling from 5247' to 6680' MAY 25 20O0 ~i ? i~:':~!i~i !".i~?!?! Date: 04/14/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 03/08/00 (D6) MW: 9.7 VISC: 41 PV/YP: 8/20 APIWL: 5.4 TD/TVD: 7943/6471 (1263) DRILLING ~ 8250 SUPV:REILLY/LUTRICK Drill from 6680'-7441'. Lost 300 psi pump pressure, spot LCM pill ~ 7441' Drill from 7441' to 7917' Sweep hole CBU. Pull 16 stands to 6394', work tight spots. POOH. RIH to 7825', wash to bottom. Drill from 7917' to 7943' 03/09/00 (D7) MW: 9.6 VISC: 43 PV/YP: 12/21 APIWL: 4.8 TD/TVD: 8897/6981 (954) TOOH SUPV:REILLY/LUTRICK Drilling from 7943' to 8583'. Pump sweep out. Drill from 8583' to 8897'. Circ high vis sweep. 03/10/00 (D8) TD/TVD: 8897/6981 ( SUPV:REILLY/LUTRICK MW: 9.6 VISC: 43 PV/YP: 11/17 APIWL: 4.0 0) CHANGING RAM, TOP DRIVE, AND FLOOR EQUIPMENT TO 3.5" Pump sweep, condition hole. Short trip to 6300'. Pump sweep and condition hole. POOH. PJSM. Run 7" casing. CBU. Continue to run 7" casing. 03/11/00 (D9) TD/TVD: 8897/6981 ( SUPV:REILLY/LUTRICK MW: 9.5 VISC: 51 PV/YP: 9/15 0) DRLG AT 9050' APIWL: 4.8 Pump cement to top and bottom plug. Test BOPE. Drill Float equipment and cement to 8887' 03/12/00 (D10) MW: 9.2 VISC: 45 PV/YP: 9/23 APIWL: 4.6 TD/TVD:10084/6983 (1187) PREPARING TO SWEEP. SUPV:REILLY/LUTRICK Control drill 20' to 8918'. CBU. FIT EMW 12.5 ppg. PJSM. Drill from 8918' to 10084' 03/13/00 (Dll) MW: 9.2 VISC: 45 PV/YP: 9/23 APIWL: 4.7 TD/TVD:lllll/6981 (1027) DRLG AT 11350' SUPV:DONALD LUTRICK Drilling from 10084' to 10360' Circ lo/hi sweep. Pump out to shoe. No problems. CBU while rotate and reciprocate pipe. RIH to TD. No problems. Drilling from 10360' to 11111' 03/14/00 (D12) MW: 9.2 VISC: 46 PV/YP: 11/25 APIWL: 4.2 TD/TVD:12147/7028 (1036) DISPLACE TO BRINE SUPV:DONALD LUTRICK Drilling from 11111' to 12147'. Circ lo/hi vis sweep. Monitor well. Static. Pump out to shoe. 03/15/00 (D13) MW: 9.2 VISC: 27 PV/YP: 1/ 2 APIWL: 0.0 TD/TVD:12147/7028 ( 0) CONTINUE TO POOH TO RUN 4-1/2" CASING. LOSS RATE ~ 12 SUPV: SCOTT D REYNOLDS ~=.~:~'~: .... ~ "i~ ........ ~i~ ,:! Continue to pump out to 8903' Observe well static. ....... ~?~' .......... Reciprocate and rotate while circulating. Pump hi vis MAY 23 20O0 Date: 04/14/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 sweep. Circulate until hole clean. Displace flo-pro w/brine. Observe well. Loss rate 8 28 bph. POOH slow to shoe. Observe well. Loss rate ~ 38 bph. POOH to 4130' Observe well. Loss rate ~ 31 bph. CBU. Circulating loss rate ~ 49 bph. Spot Hivis pill. Observe well. Static losses @ 8.4 bph. 03/16/00 (D14) MW: 9.2 VISC: 27 PV/YP: 1/ 2 APIWL: 0.0 TD/TVD:12147/7028 ( 0) DISPLACING 9.2 PPG BRINE IN ANNULUS WITH 9.6 PPG INHIB SUPV:SCOTT D REYNOLDS POOH to 8885' Monitor well. POOH. Monitor well, loss rate ~ 8 bph. PJSM. Run 4.5" tubing and completion jewelry. ND BOPE. 03/17/00 (D15) MW: 0.0 VISC: 27 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12147/7028 ( 0) DRILLING SURFACE HOLE ON CD1-41 SUPV:SCOTT D REYNOLDS ND BOPE. MU control lines to FMC uni-head and test to 5000 psi. No leaks. NU tree and test to 5000 psi. Good test. Set packer and test. Release rig 3/17/00 10:00 hrs. SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00015 Sidetrack No. Page 1 of 7 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig #19 Field ALPINE FIELD Well Name & No. PAD CD#1/25 ' Survey Section Name Definitive Survey BHI Rep, MILCHAK / GEHRES jr~ WELL DATA Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -394.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ ssE~ Target Description Target Coord. E/W Slot Coord. E/W 2405.00 Magn. Declination 25.870 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build~Walk\DL per: 100ft[~ 30m~ lomr-] Vert. Sec.. Azim. 121.06 Magn. to Map Corr. 25.870 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F-r) (DE)) (DD) (F-r) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 03-MAR-00 GSS 115.00 0.00 0.00 115.00 115.00 0.00 0.00 0.00 0.00 0.00 8" M1C 1.4 DEG AKO 03-MAR-00 GSS 185.00 0.25 351.00 70.00 185.00 -0.10 0.15 -0.02 0.36 0.36 03-MAR-00 GSS 274.00 0.50 110.00 89.00 274.00 0.16 0.21 0.31 0.74 0.28 03-MAR-o0 GSS 366.00 1.25 134.00 92.00 365.99 1.53 -0.62 1.41 0,89 0.82 04-MAR-00 GSS 456.00 2.75 138.00 90.00 455.93 4.55 -2.91 3.56 1.67 1,67 04-MAR-00 GSS 545.00 5.00 142.00 89.00 544.72 10.22 -7.55 7.38 2.54 2.53 ! 4.49 9 1/2" MlC 1.4 DEG AKO 04-MAR-00 GSS 637.00 7.50 136.00 92.00 636.17 19.76 -15.03 14.02 2.80 2.72 -6.52 04-MAR-00 GSS 724.00 10.00 139.00 87.00 722.15 32.44 -24.82 22.92 2.92 2.87 3.45 04-MAR-00 MWD 832.76 12.42 136.56 108.76 828.83 52.70 -40.44 37.16 2.27 2.23 -2.24 04-MAR-00 MWD 919.07 14.84 134.97 86.31 912.70 72.37 -55.00 51.36 2.84 2.80 -1.84 04-MAR-00 MWD 1008.70 18.06 131.46 89.63 998.65 97.19 -72.31 69.90 3.76 3.59 -3.92 04-MAR-00 MWD 1104.82 22.50 126.65 96.12 1088.80 130.16 -93.17 95.84 4.93 4.62 -5.00 04-MAR-00 MWD ' 1200.64 26.15 121.13 95.82 1176.11 169.54 -115.04 128.64 4.48 3.81 -5.76 04-MAR-00 MWD 1294.91 28.88 120.36 94.27 1259.71 213.09 -137.29 166.07 2.92 2.90 -0.82 04-MAR-00 MWD 1389.12 33.31 119.82 94.21 1340.36 261.73 -161.66 208.16 4.71 4.70 -0.57 04-MAR-00 MWD 1486.74 37.79 117.63 97.62 1419.77 318.41 -188.8~ 257.94 4.77 4.59 -2.24 04-MAR-O0 MWD 1580.55 40.71 116.70 93.81 1492.41 377.62 -215.96 310.75 3.18 3.11 -0.99 04-MAR-O0 MWD 1677.77 39.82 116.38 97.22 1566,59 440.26 -244.03 366.97 0.94 -0.92 -0.35 04-MAR-O0 MWD 1 771.03 38.44 116.17 93.26 1638,93 498.90 -270,07 419.75 1.49 -1.48 -0.20 04-MAR-00 MWD 1960.65 41.88 117.95 93.75 1782.97 621.92 -326.69 529.25 0.99 0.96 0.37 04-MAR-00 MWD 2056.21 41.53 117.68 95.56 1854.31 685.39 -356.36 565.48 0.41 -0.37 -0.28 04-MAR-O0 MWD 2150.95 41.26 117.61 94.74 1925.38 747.93 -385.43 640.97 0.29 -0.28 -0.07 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00015 Sidetrack No. Page 2 of 7 I~1~/__/~! Company ARCO ALASKA, lNG. Rig Contractor & No. Doyon Drilling Co.-Rig #19 Field ALPINE FIELD Well Name & No. PAD CD#1/25 Survey Section Name Definitive Survey BHI Rep. MILCHAK/GEHRES ~NI"~"~I~ WELL DATA Target TVD (FT) Target Coord, N/S Slot Coord, N/S -394,00 Grid Correction 0.000 Depths Measured FrOm: RKB ~ MSL 0 SS[- Target Description Target Coord, E/W Slot Coord, E/W 2405.00 Magn. Declination 25.870 Calculation Method MINIMUM CURVATURE Target Direction (OD) Buil~Walk\DL per: 10Oft[~ 30m~ 10m~ Vert. Sec. Azim. 121,06 Magn. to Map Corr, ' 25.870 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (-t-) Right (+) Comment Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (FT) (DO) (DD) (FT) (F'r) (FT) (F~ (Per 100 F'r) Drop (-) Left (-) 04-MAR-O0 MWD 2246.97 41.05 117.74 96.02 1997.68 811.01 -414.78 696.93 0.24 -0.22 0.14 04-MAR-O0 MWD 2341.1 7 40.99 117.72 94.20 2068.75 872.73 -443.54 751.66 0.07 -0.06 -0.02 04-MAR-00 MWD 2436.50 40.49 118.07 95.33 2140.98 934.85 -472.65 806.64 0.58 -0.52 0.37, 04-MAR-00 MWD 2532.17 40.15 118.49 95.67 2213.92 996.68 -501.98 861.16 0.45 -0.36 0.44 04-MAR-00 MWD 2627.64 39.79 118.66 95.47 2287.09 1057.95 -531.31 915.02 0.39 -0.38 0.18 04-MAR-00 MWD 2721.07 39.51 118.47 93.43 2359.03 1117.51 -559.82 967.38 0.33 -0.30 -0.20 06-MAR-O0 MWD 2810.60 38.68 118.56 89.53 2428.51 1173.91 -586.77 1016.99 0.93 -0.93 0.10 6 3/4' M1/XL 1.2 DEC AKO 06-MAR-00 MWD 2906.46 37.92 118.83 95.86 2503.74 1233.27 -615.29 1069.10 0.81 -0.79 0.28 06-MAR-00 MWD 3000.38 37.38 118.62 93.92 2578.10 1290.60 -642.87 1119.41 0.59 -0.57 -0.22 06-MAR-00 MWD 3096.54 37.28 118.99 96.16 2654.56 1348.86 -670.96 1170.51 0.26 -0.10 0.38 06-MAR-00 MWD 3191.35 37.18 117.27 94.81 2730.05 1406.14 -698.01 1221.09 1.10 -0.11 -1.81 06-MAR-O0 MWD 3286.54 36.86 117.33 95.19 2806.06 1463.33 -724.29 1272.02 0.34 -0.34 0.06 06-MAR-O0 MWD 3382.09 38.79 118.20 95.55 2881.53 1521.83 -751.60 1323.86 2.10 2.02 0.91 06-MAR-O0 MWD ' 3476.57 38.49 117.10 94.48 2955.32 1580.72 -778.98 1376.12 0.79 -0.32 -1.16 06-MAR-00 MWD 3572.21 38.48 116.78 95.64 3030.19 1640.08 -805.94 1429.17 0.21 -0.01 -0.33 06-MAR-O0 MWD 3667.64 37.90 116.52 95.43 3105.19 1698.91 -832.41 1481.91 0.63 -O.61 -0.27 . ~ .~,~-, ,. ';~ ...... ...... 06--MAR-O0 MWD 3762.12 38.08 119.68 94.48 3179.66 1756.97 -859.79 1533.19 2.07 0.19 3.34 07-MAR-00 MWD 3857.75 37.39 119.14 95.63 3255.29 1815.47 -888.53 1564.17 0.80 -0.72 -0.56 j¥|~ E.~J /-UUIJ ..... 07-MAR-O0 MWD 3952.70 36.84 118.41 94.95 3331.01 1872.72 -916.11 1634.39 0.74 -0.58 -0.77 .~'~c~}.',~,'"~: i .... ',,., ~.~.~r-':. ~/~, ;-~,~,.~ ,,,,w~. ~'"'"~v~',~;i!~':~ ..... :~:~.~ _ 07-MAR-00 MWD 4048.08 36.98 118.46 95.38 3407.27 1929.94 -943.39 1684.76 0.15 0.15 0.05 07-MAR-00 MWD 4142.69 37.72 118.26 94.61 3482.48 1987.27 -970.65 1735.27 0.79 0.78 --0.21 07-MAR-O0 MWD 4238.71 37.33 117.75 96.02 3568.63 2045.68 -998.12 1786.91 0.52 -0.41 -0.53 07-MAR-O0 MWD 4334.05 40.45 120.64 95.34 3632.84 2105.48 -1027.30 1839.14 3.75 3.27 2.93 07-MAR-00 MWD 4428.82 40.37 120.17 94.77 3705.00 2166.91 -1058.35 1892.16 0.27 -0.08 -0.39 SURVEY CALCULATION AND FIELD WORKSHEET' Job No. S de. ack No. Page 3 of Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co, - Rig #19 Field ALPINE FIELD Well Name & No. PAD CD#1/25 Survey Section Name Definitive Survey BHI Rep. MILCHAK/GEHRES INT~~ WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -394.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W 2405.00 Magn. Declination 25.870 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build~Walk\DL per: lOOft[~ 30mE] lOmE] Vert. Sec. Azim. 121.06 Magn. to Map Corr. 25.870 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F'r) (DO) (DB) (FT) (F'r) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 07-MAR-O0 MWD 4524.28 40.16 120.16 95.46 3777.84 2228.60 -1089.35 1945.50 0.22 -0.22 -0.01 07-MAR-O0 MWD 4619.83 39.98 119.55 95.55 3850.96 2290,10 -1119.97 1998.84 0.45 -0.19 -0.64 07-MAR-O0 MWD 4714.24 39.42 118.89 94.41 3923.60 2350.37 -1149.41 2051.47 0.74 -0.59 -0.70 07-MAR-O0 MWD 4809.81 38.94 118.86 95.57 3997.68 2410.70 -1178.57 2104.34 0.50 -0.50 -0.03 07-MAR-O0 MWD 4905.58 38.59 117.71 95.77 4072.36 2470.60 -1206.98 2157.15 0.84 -0.37 -1.20 07-MAR-O0 MWD 5000.46 38.26 117.48 94.88 4146.69 2529.45 -1234.30 2209.40 0,38 -0.35 -0.24 07-MAR-O0 MWD 5095.93 37.75 116.81 95.47 4221.91 2588.10 -1261.12 2261.71 0.69 -0.53 -0.70 07-MAR-O0 MWD 5190.83 36.81 116.46 94.90 4297.42 ' 2645.41 -1286.89 2313.09 1.02 -0.99 -0.37 07-MAR-O0 MWD 5284.08 36.51 115.55 93.25 4372.23 2700.87 -1311.30 2363.13 0.67 -0.32 -0.98 07-MAR-O0 MWD 5379.39 39.06 118.64 95.31 4447.55 2759.11 -1337.93 2415.08 3.33 2.68 3.24 07-MAR-O0 MWD 5474.92 39.37 118.51 95.53 4521.57 2819.45 -1366.82 2468.12 0.34 0.32 -0.14 07-MAR-O0 MWD 5570.50 39.11 117.60 95.58 4595.60 2879.82 -1395.25 2521.47 0.66 -0.27 -0.95 07-MAR-O0 MWD 5665.77 38.78 116.72 95.27 4669.69 2939.57 -1422.59 2574.75 0.68 -0.35 -0.92 07-MAR-O0 MWD ' 5760.37 39.70 119.96 94.60 4742.97 2999.32 -1451.00 2627.40 2.37 0.97 3.42 07-MAR-O0 MWD 5856.64 39.09 120.14 96.27 4817.36 3060.41 -1481.60 2680.28 0.64 -0.63 O. 19 07-MAR-O0 MWD 5952.70 38.70 119.30 96.06 4892.13 3120.71 -1511.50 2732.66 0.68 -0.41 -0.87 __ 07-MAR-O0 MWD 6047.52 38.25 11'9.23 94.82 4966.38 3179.68 -1540.34' 2784.13 0.48 -0.47 .0.07 ~. 7~ ~;~, ,...--,~' ~.,,~.~ ~ !~ i ', 07-MAR-00 MWD 6142.82 37.86 118.44 95.30 5041.40 3238.38 -1568.67 2635.59 0.65 -0,41 -0.63 07-MAR-O0 MWD 6237.23 37.21 118.08 94.41 5116.27 3295.83 -1595.91 2886.25 0.73 -0.69 -0.38 j~,~%y ,', '"' 07-MAR-O0 MWD 6332.64 36.47 117.98 95.41 5192.62 3352.95 -1622.79 2936.75 0.78 -0.78 -0.10 07-MAR-O0 MWD 6427.86 35.98 117.12 95.22 5269.44 3409.12 -1 648.82 2986.63 0.74 -0.51 -0.90 ,. ,; :,,, '-: .~;.. ~ ~, . 07-MAR-O0 MWD 6522.12 38.47 118.12 94.26 5344.49 3466.03 -1675.26 3037.15 2.72 2.64 1.06 07-MAR-O0 MWD 6616.16 37.89 117.41 94.04 5418.41 3524.06 -1702.35 3088.58 0.77 -0.62 -0.75 -- 08-MAR-O0 MWD 6712.61 37.47 117.41 96.45 5494,74 3582.90 -1729.49 3140.92 0.44 -0.44 0.00 ii ~1! I I1111 II ., 111 i Job No. 0450-00015 Sidetrack No. Page 4 of 7 · '- [1~,~-' I :/~-~ Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig #19 Field ALPINE FIELD Well Name & No. PAD CD#1/25 Survey Section Name Definitive Survey BHI Rep. MILCHAK/GEHRES l~li~"~~ WELL DATA Target TVD (F~) Target Coord, N/S Slot Coord. N/S -394.00 Grid Correction 0,000 Depths Measured From: RKB ~ MSL ~ SS0 Target Description Target Coord. E/W Slot Coord. E/W 2405,00 Magn. Declination 25.870 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build~Walk\DL per: 100ft[~ 30m~] 10m~ Vert, Sec, Azim. 121.06 Magn. to Map Corr, 25.870 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Type Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL (FT) (DD) (DD) (FT) (F'r) (FT) (F'r) (Per 100 F-r) Drop (-) Left (-) 08-MAR-O0 MWD 6807,81 38,70 118,66 95,20 5569,68 3641,54 -1757,09 3192,74 1,52 1,29 1,31 08-MAR-O0 MWD 6903,31 38,47 118,52 95.50 5644,33 3701,04 -1785,59 3245,04 0.26 -0.24 -0,15 08-MAR-O0 MWD 6998,01 37.61. 117,16 94,70 5718,91 3759,30 -1812,85 3296,63 1,27 -0,91 -1,44 08-MAR-O0 MWD 7092,85 36,69 116,84 94,84 5794,50 3816,43 -1838,85 3347,66 0,99 -0,97 -0,34 08-MAR-O0 MWD 7188,13 38,48 119,32 95,28 5870,01 3874,46 -1866.22 3398,91 2,46 1,88 2,60 08-MAR-O0 MWD 7283,75 37,81 118,76 95,62 5945,21 3933,48 -1894,90 3450,55 0,79 -0,70 -0.59 08-MAR-00 MWD 7378,72 36,98 118,36 94.97 6020.66 3991,10 -1922.47 3501,20 0,91 -0,87 -0,42 08-MAR-00 MWD 7472,71 36.94 117.32 93.99 6095.76 4047,52 -1948.86 3551,17 0.67 -0.04 -1.11 08-MAR-OO MWD 7569,45 37,98 120,11 96,74 6172.56 4106,29 -1977,14 3602,76 2,06 1,08 2,88 08-MAR-O0 MWD 7663.69 37,75 119,37 94.24 6246.96 4164.12 -2005,83 3652,98 0.54 -0,24 -0.79 08-MAR-O0 MWD 7759,34 36.78 119,10 95,65 6323,08 4222,01 -2034,12 3703.52 1,03 -1,01 -0,28 08-MAR-O0 MWD 7854,09 36.39 118,27 94,75 6399,16 4278.43 -2061.23 3753.06 0.66 -0.41 -0.88 09-MAR-00 MWD 7944,16 36.55 118.36 90.07 6471,59 4331.91 -2086.62 3800.19 0,19 0,18 0,10 6 3/4" MlX 1,5 DEG AKO 09-MAR-00 MWD . 8038,83 37.17 120.13 94.67 6547.34 4388.66 -2114.37 3849.73 1.30 0.65 1,87 09-MAR-00 MWD 8135.53 36.61 120.58 96,70 6624.68 4446,7'1 -2143,74 3899.80 0.67 -0,58 0,57 09-MAR-00 MWD 8201,28 36.49 123,62 65.75 6677,50 4485,85 -2164,57 3932.94 2.67 -0,18 4,47 09-MAR-00 MWD 8230,33 38.45 127,04 29.05 6700,56 4503,46 -2174.80 3947,35 9.84 6,75 11.77 09-MAR-O0 MWD 8261.56 40.91 130.36 31.33 6724,67 4523.28 -2187,31 3962,94 10,36 7,85 10.60 09-MAR-O0 MWD 8293,29 43,58 133,05 31.63 6748.09 4544.17 -2201.47 3978.80 10.19 8.44 8.50 09-MAR-O0 MWD 8325.12 46.16 134.90 31.83 6770.65 4566,05 -2217.06 3994.96 9.08 8.11 5,81 09-MAR-00 MWD 8356.78 48,64 136.97 31,66 6792,08 4588.57 -2233.81 4011.16 9.19 7,83 6,54 I 09-MAR-O0 MWD 8388.87 50.89 1 38.77 32.09 6812.80 4612.01 -2251.98 4027.58 8.22 7.01 5.61 i 09-MAR-O0 MWD 8420.70 53.33 140.60 31.83 6832.35 4635.81 -2271.14 4043.83 8,91 7.67 5.75 " 09-MAR-O0 MWD 8452.48 55.81 142.22 31.78 6850.77 4660.09 -2291.38 4059.97 8.84 7.80 5.10 .' :.L.;iv:" . , II ,' ~ i' SURVEY CALCULATION AND FIELD WORKSHEET Job.o. S d eck · -= [ li~-= I ::~"~ Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig #19 Field ALPINE FIELD Well Name & No. PAD CD#1/25 Survey Section Name Definitive Survey BHI Rep. MILCHAK/GEHRES J~N"r~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -394.00 Grid Correction 0.000 Depths Measured From: RKB I~ MSL ~] SS~ Target Description Target Coord. E/W Slot Coord. E/W 2405.00 Magn. Declination 25.870 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: 100ft[~ 30m~ 10mu Vert. Sec. Azim. 121.06 Magn. to Map Corr. 25.870 Map North to: OTHER i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Type Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL (F'D (DD) (DD) (FT) 0=1') (FT) (FT) (Per m0 F-r) Drop (-) Left (-) 09-MAR-O0 MWD 8483.65 58.19 143.69 31,17 6867.75 4684.34 -2312.24 4075.72 8.60 7.64 4.72 09-MAR-O0 MWD 8513.48 60.65 144.55 29.83 6882.92 4707.96 -2333.05 4090.76 8.61 8.25 2,88 09-MAR-00 MWD 8549.24 63.17 146.23 35.76 6899.76 4736.70 -2359.02 4108.68 8.18 7.05 4.70 09-MAR-O0 MWD 8580.89 65.67 147.47 31.65 6913.43 4762.40 -2382.92 4124.28 8.65 7.90 3.92 09-MAR-00 MWD 8612,22 67.94 148.78 31.33 6925.77 4788.04 -2407.37 4139.48 8.20 7.25 4.18 09-MAR-O0 MWD 8645.08 70.86 149.27 32.86 6937.33 4815.21 -2433.74 4155.31 8.99 8.89 1.49 09-MAR-00 MWD 8676.76 73.44 149.62 31.68 6947.04 4841.73 -2459.71 4170.64 8.21 8.14 1.10 09-MAR-O0 MWD 8707.21 75.87 149.62 30.45 6955.09 4867.52 -2485.04 4185.49 7.98 7.98 0.00 09-MAR-00 MWD 8740.34 78.42 149.72 33.13 6962.46 4895.88 -2512.91 4201.80 7.70 7.70 0.30 09-MAR-00 MWD 8772.34 80.57 149.68 32.00 6968.30 4923.49 -2540.08 4217.67 6.72 6.72 -0.12 09-MAR-O0 MWD 8801.74 82.84 148.39 29.40 6972.54 4949.18 -2565.02 4232.64 8.86 7.72 -4.39 09-MAR-00 MWD 8829.64 84.28 148.66 27,90 6975.67 4973.78 -2588.66 4247.12 5,25 5.16 0,97 12-MAR-OO MWD 8911.78 87.46 147.84 82.14 6981.58 5046.64 -2658.32 4290.22 4.00 3.87 -1.00 4 3/4' M1/XL 1.2 DEG AKO 12-MAR-00 MWD . 9005.86 88.42 148.90 94.08 6984.97 5130.18 -2738.37 4339.53 1.52 1.02 1.13 12-MAR-00 MWD 9101.72 88.94 149.16 95.86 6987.17 5214.82 -2820.54 4388.84 0.61 0.54 0.27 12-MAR-O0 MWD 9196.16 89.83 148.81 94.44 6988.19 5298.26 -2901.48 4437.50 1.01 0.94 -0.37 12-MAR-00 MWD 9288.32 90.75 148.17 92.16 6987.72 5380.06 -2980.04 4485.67 1.22 1.00 -0.69 12-MAR.00 MWD 9380,13 90.03 148.64 91.81 6987.10 5461.60 -3058.24 4533.76 0.94 -0.78 0.51 12-MAR-OO MWD 9472.96 90.62 149.48 92.83 6986.57 5543,56 -3137.86 4581.49 1.11 0.64 0.90 12-MAR-O0 MWD 9566.63 89.69 150.26 93.67 6986.32 5625.64 -3218.87 4628.51 1.30 -0.~ 0.83 12-MAR-00 MWD 9659.82 90.21 1 50.02 93.19 6986,40 5707.08 -3299.69 4674.91 0,61 0.56 -0.26 12-MAR-O0 MWD 9752.74 90.65 151.27 92.92 6985.70 5787.88 -3380.68 4720.46 1.43 0.47 1.35 '~ ' ~';~'; "' '; "; ~'-* ~' '~ '~ '"~:~"':':-' ' :: 12-MAR-00 MWD 9843.82 91.03 151.63 91.08 6984.37 5866.44 -3460,67 4763.98 0.57 0.42 0.40 12-MAR-00 MWD 9938.65 89.83 151.98 94.83 6983.65 5947.94 -3544.25 4808.78 1.32 -1.27 0.37 SURVEY CALCULATION AND FIELI WORKSHEET Job No. 0450-00015 Sidetrack No. Page 6 of 7 Company ARCO ALASKA, INC, Rig Contractor & No. Doyon Drilling Co. - Rig #19 Field ALPINE FIELD Well Name & No. PAD CD#1/25 Survey Section Name Definitive Survey BHI Rep. MILCHAK/GEHRES ~'~ ~ ,~1~ WELL DATA Target'l'VD (F-r) Target Coord. N/S Slot Coord. N/S -394.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 2405.00 Magn. Declination 25.870 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: 100ft[~ 30mr-1 10m[~ Vert. Sec. Azim. 121.06 Magn. to Map Corr. ' 25.870 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DD) (FT) (FT) (FT) (FT) (Per 100 F'T)Drop (-) Left (-) 12-MAR-O0 MWD 10031.23 90.45 152.44 92,58 6983.43 6027.17 -3626.15 4851.95 0.83 0.67 0.50 13-MAR-00 MWD 10122.31 91.10 152.31 91.08 6982.20 6104.97 -3706.84 4894.17 0.73 0.71 -0.14 13-MAR-00 MWD 10214.99 89.69 151.97 92.68 6981.56 6184.34 -3788.77 4937.48 1.56 -1.52 -0.37. 13-MAR-O0 MWD 10306.86 90.55 152.70 91.87 6981.37 6262.86 -3870.14 4980.14 1.23 0.94 0.79 13-MAR-O0 MWD 10398.86 89.93 153.71 92.00 6980.98 6340.76 -3952.26 5021.61 1.29 -0.67 1.10 13-MAR-O0 MWD 10489.87 90.03 154.40 91.01 6981.01 6417.09 -4034.09 5061.43 0.77 0.11 0.76 13-MAR-00 MWD 10582.49 90.51 154.08 92.62 6980.58 6494.61 -4117.51 5101.68 0.62 0.52 -0.35 13-MAR-00 MWD 10674.52 90.79 154.15 92.03 .6979.53 6571.74 -4200.30 5141.85 0.31 0.30 0.08 13-MAR-O0 MWD 10766.06 90.21 152.22 91.54 6978.73 6649.25 -4281.99 5183.15 2.20 -0.63 -2.11 13-MAR-00 MWD 10857.42 88.66 150.37 91.36 6979.63 6728.18 -4362.11 5227.02 2.64 -1.70 -2.02 13-MAR-00 MWD 10948.76 89.73 149.37 91.34 6980.92 6808.20 -4441.1 0 5272.86 1.60 1.17 -1.09 13-MAR-00 MWD 11043.63 90.07 150.66 94.87 6981.08 6891.21 -4523.27 5320.28 1.41 0.36 1.36 14-MAR-O0 MWD 11136.46 89.25 151.00 92.83 6981.63 6971.79 -4604.32 5365.52 0.96 -0.88 0.37 14-MAR-O0 MWD 11228.31 89.42 150.72 91.85 6982.70 7051.48 -4684.54 5410.24 0.36 0.19 -0.30 14-MAR-00 MWD 11321.97 86.50 149.43 93.66 6986.03 7133.33 -4765.65 5456.93 3.41 -3.12 -1.38 14-MAR-00 MWD 11412.56 87.08 149.83 90.59 6991.11 7212.76 -4843.69 5502.66 0.78 0.64 0.44 ..... 14-MAR-00 MWD 11505.07 87.84 149.69 92.51 6995.21 7293.83 -4923.53 5549.20 0.84 0..82 -0.15 14-MAR-00 MWD 11598.29 87.46 149.89 93.22 6999.03 7375.50 -5004.02 5596.07 0.46 -0.41 0.21 14-MAR-O0 MWD 11688.76 87.15 149.84 90.47 7003.28 7454.69 -5082.18 5641.44 0.35 -0.34 -0.06 , , 14-MAR-00 MWD 11781.84 86.26 149.32 93.08 7008.63 7536.34 -5162.31 5688.49 1.11 -0.96 -0.56 . 14-MAR-O0 MWD 11875.15 85.92 150.48 93.31 7014.99 7617.88 -5242.85 5735.18 1.29 -0.36 1.24 ~ ~',V ~..~.: .'~ 14-MAR-O0 MWD 11969,09 87.08 150.62 93,94 7020.73 7699.50 -5324.50 5781.28 1.24 1.23 O. 15 .. 14-MAR-OO MWD 12062.50 87.67 150.79 93.41 7025.01 7780.59 -5405.88 5826.93 0.66 0.63 0.18 14-MAR-OO MWD 12090.34 88.01 151.21 27.84 7026.06 7804.70 -5430.21 5840.42 1.94 1.22 1.51 1 SURVEY CALCULATION AND FIELD WORKSHEET Jo~No. ~~15 S~etrackNo. Page 7 o, 7 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co,- Rig #19 Field ALPINE FIELD Well Name & No. PAD CD#1/25 Survey Section Name Definitive Survey BHI Rep. MILCHAK / GEHRES ~'JqlllrJP'~l~ WELL DATA Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -394,00 Grid Correction 0.000 Depths Measured From: RKB ~ .MSL I-] SS~ Target Description Target Coord, E/W Slot Coord, F_,/W 2405,00 Magn, Declination 25,870 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 10Oft~ 30m~ lOm~ Vert, Sec, Azim, 121,06 Magn. to Map Corr, 25,870 Map North to: OTHER SURVEY DATA Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Type Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL (FT) (DD) (DD) (F'I~ (F~ (FT) (F'r) (Per 400 FT) Drop (-) Left (-) 14-MAR-O0 MWD 12147.00 88.01 151.21 56.66 7028.02 7853.67 -5479.84 5867.69 0.00 0.00 0.00 Projected Data - NO SURVEY ,, ~ ',i ]VI~ 1 ~ ..... Aia~ Oil & Gas CMs. r-,,,..~ .:.,..-, ANADRILL SCHLUMBERGER Survey report 14-Mar-2000 23:15:51 Page 1 of 6 Client ................... : ARCO Alaska, Inc. Field .................... : Coville River Well ..................... : CD1-25 API number ............... : 50-103-20325-00 Engineer ................. : Rathert Rig: ..................... : Doyon 19 State: ................... : Alaska Spud date ................ : 03-Mar-00 Total accepted surveys...: 145, MD of first survey ....... : 0.00 ft. MD of last survey ........ : 12147.00 ft Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ....... · .... : Mason & Taylor Depth reference -- Permanent datum .......... : Mean Sea Level Magnetic dip ............. :80.48 degrees Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : 0.00 ft DF above permanent ....... : 55.80 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point ........ Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 151.86 degrees Geomagnetic data --- Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 03-Mar-2000 Magnetic field strength..: 1144.66 HCNT Magnetic dec (+E/W-) ..... : 25.87 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.66 HCNT Reference Dip ............ : 80.48 degrees Tolerance of S ........... : (+/) 2.50 mSal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.87 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.87 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 RECEIVED ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 0.00 2 115.00 0.00 0.00 115.00 3 185.00 0.25 351.00 70.00 4 274.00 0.50 110.00 89.00 5 366.00 1.25 134.00 92.00 6 456.00 2.75 138.00 7 545.00 5.00 142.00 8 637.00 7.50 136.00 9 724.00 10.00 139.00 10 832.76 12.42 136.56 90.00 89.00 92.00 87.00 108.76 TVD depth (ft) 0.00 115.00 185.00 274.00 365.99 455.93 544.72 636.17 722.15 828.83 11 919.07 14.84 134.97 86.31 912.70 12 1008.70 18.06 131.46 89.63 998.65 13 1104.82 22.50 126.65 96.12 1088.80 14 1200.64 26.15 121.13 95.82 1176.11 15 1294.91 28.88 120.36 94.27 1259.71 16 1389.12 33.31 119.82 94.21 17 1486.74 37.79 117.63 97.62 18 1580.55 40.71 116.70 93.81 19 1677.77 39.82 116.36 97.22 20. 1771.03 38.44 116.17 93.26 1340.36 1419.77 1492.41 1566.59 1638.93 21 1866.90 40.98 117.60 95.87 1712.68 22 1960.65 41.88 117.95 93.75 1782.97 23 2056.21 41.53 117.68 95.56 .1854.31 24 2150.95 41.26 117.61 94.74 1925.38 25 2246.97 41.05 117.74 96.02 1997.68 26 2341.17 40.99 117.72 94.20 2068.75 27 2436.50 40.49 118.07 95.33 2140.98 28 2532.17 40.15 118.49 95.67 2213.92 29 2627.64 39.79 118.66 95.47 2287.09 30 2721.07 39.51 118.47 93.43 2359.03 14-Mar-2000 23:15:51 ' Page 2 of 6 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 0.00 0.00 0.00 0.00 0.00 0.00 -0.14 0.15 -0.02 -0.04 0.21 0.31 1.22 -0.62 1.41 19.87 -15.03 14.02 32.70 -24.82 22.92 53.19 -40.44 37.16 72.72 -55.00 51.36 96.73 -72.31 69.90 127.35 -93.17 95.84 162.11 -115.04 128.64 199.38 -137.29 166.07 240.73 -161.66 208.16 288.21 -188.88 257.94 336.99 -215.96 310.75 388.25 -244.03 366.97 436.11 -270.07 419.75 486.31 -297.78 474.36 537.68 -326.69 529.25 590.36 -356.36 585.48 642.17 -385.43 640.97 694.44 -414.78 696.93 745.62 -443.54 751.66 797.22 -472.65 806.64 848.79 -501.98 861.16 900.06 -531.31 915.02 949.89 -559.~2 967.38 0.00 0.00 0.00 TIP 0.00 0.00 0.00 GYR 0.15 351.00 0.36 GYR 0.37 55.97 0.74 GYR 1.54 113.90 0.89 GYR 4.60 129.27 1.67 GYR - 10.56 135.68 2.54 GYR - 20.56 137.00 2.80 GYR - 33.78 137.28 2.92 GYR - 54.92 137.42 2.27 MWD 6-axis 75.25 136.96 2.84 MWD 100.57 135.97 3.76 MWD '133.66 134.19 4.93 MWD 172.57 131.81 4.48 MWD 215.47 129.58 2.92 MWD 263.56 127.83 4.71 MWD 319.70 126.21 4.77 MWD 378.42 124.80 3.18 MWD 440.70 123.62 0.94 MWD 499.12 122.76 1.49 MWD 560.08 122.12 2.82 MWD 621.96 121.69 0.99 MWD 685.40 -121.33 0.41 MWD 747.93 121.02 0.29 MWD 811.02 120.76 0.24 MWD 872.76 120.54 0.07 934.92 120.37 0.58 996.78 120.24 0.45 1058.09 120.14 0.39 1117.68 120.06 0.33 RECEIVED 2000 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 14-Mar-2000 23:15:51 Page 3 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 2810.60 38,68. 118.56 89.53 32 2906.46 37.92 118.83 95.86 33 3000.38 37.38 118.62 93.92 34 3096.54 37.28 118.99 96.16 35 3191.35 37.18 117.27 94.81 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg (ft) (ft) (ft) (ft) (ft) (deg) 100f 2428.51 2503.74 2578.10 2654.56 2730.05 997.05 -586.77 1016.99 1046.78 -615.29 1069.10 1094.82 -642.87 1119.41 1143.70 -670.96 1170.51 1191.40 -698.01 1221.09 36 3286.54 36.86 117.33 95.19 2806.06 1238.60 -724.29 1272.02 37 3382.09 38.79 118.20 95.55 2881.53 1287.13 -751.60 1323.86 38 3476.57 38.49 117.10 94.48 2955.32 1335.91 -778.98 1376.11 39 3572.21 38.48 116.78 95.64 3030.19 1384.71 -805.94 1429.17 40 3667.64 37.90 116.52 95.43 3105.19 1432.92 -832.41 1481.91 41 3762.12 38.08 119.68 94.48 3179.66 1481.26 -859.79 1533.19 42 3857.75 37.39 119.14 95.63 3255.29 1530.65 -888.53 1584.17 43 3952.70 36.84 118.41 94.95 3331.01 1578.65 -916.11 1634.39 44 4048.08 36.98 118.46 95.38 3407.27 1626.46 -943.39 1684.76 45 4142.69 37.72 1'18.26 94.61 3482.48 1674.32 -970.65 1735.27 46 4238.71 37.33 117.75 96.02 3558.63 47 4334.05 40.45 120.54 95.34 3632.84 48 4428.82 40.37 120.17 94.77 3705.00 49 4524.28 40.16 120.16 95.46 3777.84 50 4619.83 39.98 119.55 95.55 3850.96 51 4714.24 39.42 118.89 94.41. 3923.60 52 4809.81 38.94 118.86 95.57 3997.68 53 4905.58 38.59 117.71 95.77 4072.36 54 5000.46 38.26 117.48 94.88 4146.69 55 5095.93 37.75 116.81 95.47 4221.91 56 5190.83 36.81 116.46 94.90 4297.42 57 5284.08 36.51 115.55 93.25 4372.23 58 5379.39 39.06 118.64 95.31 4447.55 59 5474.92 39.37 118.51 95.53 4521.57 60 5570.50 39.11 117.60 95.58 4595.60 1722.89 -998.12 1773.26 -1027.30 1825.64 -1058.35 1878.14 -1089.35 1930.30 -1119.97 1786.91 1839.14 1892.16 1945.50 1998.84 1981.08 -1149.41 2051.47 2031.72 -1178.57. 2104.34 2081.68 -1206.98 2157.15 2130.42 -1234.30 2209.40 2178.74 -1261.12 2261.71 2225,69 -1286.89 2270.82 -1311.30 2318.80 -1337.93 2369.29 -1366.82 2419.53 -1395.25 2313.09 2363.13 2415.08 2468.12 2521.47 1174.12 119.98 0.93 1233.52 119.92 0.81 1290.87 119.87 0.59 1349.18 119.82 0.26 1406.51 119.75 1.10 Srvy Tool / tool qual ) type type MWD MWD MWD MWD MWD. 1463.77 119.66 0.34 1522.33 119.58 2.10 1581.30 119.51 0.79 1640.75 119.42 0.21 1699.69 119.32 0.63 MWD MWD MWD MWD MWD 1757.82 119.28 2.07 1816.34 119.29 0.80 1873.63 119.27 0.74 1930.91 119.25 0.15 1988.30 119.22 0.79 MWD MwD MWD MWD MWD 2046.77 119.19 0.52 2106.61 119.19 3.75 2168.03 119.22 0.27 2229.72 119.25 0.22 2291.22 119.26 0.45 MWD MWD MWD MWD MWD 2351.53 119.26 0.74 2411.90 119.25 0.50 2471.86 119.23 0.84 2530.80 119.19 0.38 2589.55 119.14 0.69 MWD MWD MWD MWD MWD 2646.98 119.09 1.02 2702.57 119.03 0.67 2760.92 118.99 3.33 2821.31 118.98 0.34 2881.76 118.96 0.66 RECEIVED Alaska Oil & Gas Cons. Cemmissio~ Anchorage MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 14-Mar-2000 23:15:51 Page 4 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 61 5665.77 38.78 116.72 62 5760.37 39.70 119.96 63 5856.64 39.09 120.14 64 5952.70 38.70 119.30 65 6047.52 38.25 119.23 66 6142.82 37.86 118.44 67 6237.23 37.21 118.08 68 6332.64 36.47 117.98 69 6427.86 35.98 117.12 70 6522.12 38.47 118.12 95.27 94.60 96.27 96.06 94.82 95.30 94.41 95.41 95.22 94.26 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 4669.69 4742.97 4817.36 4892.13 4966.36 5041.40 5116.27 5192.62 5269.44 5344.49 71 6616.16 37.89 117.41 94.04 5418.41 72 6712.62 37.47 117.41 96.46 5494.75 73 6807.81 38.70 118.66 95.19 5569.68 74 6903.31 38.47 118.52 95.50 5644'.33 75 6998.01 37.61 i17.16 94.70 5718.91 76 7092.85 36.69 116.84 94.84 5794.50 77 7188.13 38.48 119.32 95.28 5870.01 78 7283.75 37.81 118.76 95.62 5945.21 79 7378.72 36.98 118.36 94.97 6020.66 80 7472.71 36.94 117.32 93.99 6095.76 81 7569.45 37.98 120.11 96.7.4 6172.56 82 7663.69 37.75 119.37 94.24 6246.96 83 7759.34 36.78 119.10 95.65 6323.08 84 7854.09 36.39 118.27 94.7.5 6399.16 85 7944.16 36.55 118.36 90.07 6471.59 86 8038.83 37.17 120.13 94.67 6547.34 87 8135.53 36.61 120.68 96.70 6624.68 88 8201.28 36.49 123.62 65.75 6677.50 89 8230.33 38.45 127.04 29.05 6700.56 90 8261.66 40.91 130.36 31.33 6724.67 2468.76 -1422.59 2518.65 -1451.00 2570.57 -1481.60 2621.64 -1511.50 2671.34 -1540.34 2574.75 2627.40 2680.28 2732.66 2784.13 2720.59 -1568.67 2768.50 -1595.91 2816.02 -1622.79 2862.50 -1648.82 2909.65 -1675.27 2835.59 2886.25 2936.75 2986.63 3037.15 2957.79 -1702.35 3006.41 -1729.49 3055.19 -1757.09 3104.98 -1785.59 3153.35 -1812.85 3088.58 3140.92 3192.74 3245.04 3296.63 3200.35 -1838.85 3248.66 -1866.23 3298.29 -1894.90 3346.50 -1922.47 3393.33 -1948.86 3347.66 3398.91 3450.55 3501.20 3551.17 3442.60 -1977.14 3491.59 -2005.83 3540.36 -2034.12 3587.63 -2061.23 3632.25 -2086.62 3602.76 3652.98 3703.52 3753.06 3800.19 3680.09 -2114.37 3729.60 -2143.75 3763.60 -2164.58 3779.41 -2174.80 3797.80 -2187.31 3849.73 3899.80 3932.94 3947.35 3962.94 2941.62 118.92 0.68 3001.44 118.91 2.37 3062.52 118.93 0.64 3122.83 118.95 0.68 3181.83 118.95 0.48 3240.57 118.95 0.65 3298.08 118.94 0.73 3355.28 118.92 0.78 3411.54 118.90 0.74 3468.54 118.88 2.72 3526.66 11'8.86 0.77 3585.60 118.84 0.44 3644.31 118.83 1.52 3703.87 118.82 0.26 3762.21 118.81 1.27 3819.46 118.78 0.99 3877.55 118.77 2.46 3936.61 118.77 0.79 3994.29 118.77 0.91 4050.79 118.76 0.67 4109.61 118.76 2.06 4167.45 118.77 0.54 4225.36 118.78 1.03 4281.83 118.78 0.66 4335.37 118.77 0.19 4392.15 118.78 1.30 4450.17 118.80 0.67 4489.25 118.83 2.67 4506.81 118.85 9.84 MAR 2000 ;\i' r, ....(~.: ~i' ~jnr~ Srvy tool type MWD MWD MWD MWD MWD MWD . MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-~xis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 14-Mar-2000 23:15:51 Page 5 of 6 Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 91 8293.29 43.58 133.05 92 8325.12 46.16 134.90 93 8356.78 48.64 136.97 94 8388.87 50.89 138.77 95 8420.70 53.33 140.60 96 8452.48 55.81 142.22 97 8483.65 58.19 143.69 98 8513.48 60.65 144.55 99 8549.24 63.17 146.23 100 8580.89 65.67 147.47 101 8612.22 67.94 148.78 102 8645.08 70.86 149.27 103 8676.76. 73.44 149.62 104 8707.21 75.87 149.62 105 8740.34 78.42 149.72 106 8772.34 80.57 149.68 107 880t.74 82.84 148.39 108 8829.64 84.28 148.66 109 8911.78 87.46 147.84 110 9005.86 88.42 148.90 111 9101.72 88.94 149.16 112 9196.1'6 89.83 148.81 113 9288.32 90.75 148.17 114 9380.13 90.03 148.64 115 9472.96 90.62 149.48 116 9566.63 89.69 150.26 117 9659.82 90.21 150.02 118 9752.74 90.65 151.27 119 9843.82 91.03 151.63 120 9938.65 89.83 151.98 Course length (ft) 31.63 31.83 31.66 32.09 31.83 31.78 31.17 29.83 35.76 31.65 31.33 32.86 31.68 30.45 33.13 32.00 29.40 27.90 82.14 94.08 95.86 94.44 92.16 91.81 92.83 93.67 93.19 92.92 91.08 94.83 TVD Vertical Displ Displ Total At DLS Srvy depth section +N/S- +E/W- displ Azim (deg/ tool (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 6748.09 6770.65 6792.08 6812.80 6832.35 6850.77 6867.75 6882.92 6899.76 6913.43 6925.77 6937.33 6947.04 6955.10 6962.47 6968.30 6972.54 6975.67 6981.59 6984.97 6987.18 6988.19 6987.73 6987.10 6986.57 6986.32 6986.40 6985.71 6984.37 6983.66 3817.76 -2201.47 3839.13 -2217.06 3861.54 -2233.81 3885.31 -2251.98 3909.87 -2271.14 3978.80 3994.96 4011.16 4027.58 4043.83 3935.33 -2291.38 3961.15 -2312.24 3986.60 -2333.05 4017.94 -2359.02 4046.38 -2382.92 4059.97 4075.72 4090.76 4108.68 4124.28 4075.11 -2407.37 4139.48 4105.83 -2433.74 4155.31 4135.95 -2459.70 4170.64 4165.29 -2485.04 4185.49 4197.56 .2512.91 4201.80 4229.00 -2540.08 4258.06 -2565.02 4285.73 -2588.66 4367.49 -2658.32 4461.33 -2738.37 4217.67 4232.64 4247.11 4290.22 4339.53 4557.05 -2820.54 4651.36 -2901.48 4743.36 -2980.04 4835.00 -3058.24 4927.72 -3137.86 4388.84 4437.50 4485.66 4533.76 4581.49 5021.33 -3218.87 5114.48 -3299.69 5207.37 -3380.68 5298.44 -3460.67 5393.26 -3544.25 4628.51 4674.90 4720.45 4763.98 4808.78 4547.24 118.96 10.19 MWD 4568.92 119.03 9.08 MWD 4591.22 119.11 9.19 MWD 4614.42 119.21 8.22 MWD 4637.95 119.32 8.91 MWD 4661.95 119.44 8.84 MWD 4685.93 119.57 8.60 MWD 4709.30 119.70 8.61 MWD 4737.74 119.86 8.18 MWD 4763.19 120.02 8.62 MWD 4788.61 120.18 8.23 MWD 4815.57 120.36 9.00 MWD 4841.94 120.53 8.21 MWD 4867.62 120.70 7.98 MWD 4895.90 120.88 7.70 MWD 4923.49 121.06 6.72 MWD 4949.20 121.22 8.86 MWD 4973.85 121.36 5.25 MWD 5047.04 121.78 4.00 MWD 5131.29 122.25 1.52 MWD 5217.03 122.73 0.61 MWD 5301.88 123.18 1.01 MWD 5385.34 123.60 1.22 MWD 5468.81 124.00 0.94 MWD 5553.04 124.41 1.11 MWD 5637.75 5722.12 5806.17 5888.27 5973.78 124.82 1.30 MWD 125.22 0.61 MWD 125.61 1.43 MWD 126.00 0.57 MWD 126.39 1.32 MWD 'RECEIVED MAR Alaska Oil & Gas Cons. Com. mismort Tool qual type 6-axis 6-axis 6-axis 6-axis 6-&xis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 14-Mar-2000 23:15:51 Page 6 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 10031.23 90.45 152.44 122 10122.31 91.10 1'52.31 123 10214.99 89.69 151.97 124 10306.86 90.55 152.70 125 10398.86 89.93 153.71 126 10489.87 90.03 154.40 127 10582.49 90.51 154.08 128 10674.52 90.79 154.15 129 10766.06 90.21 152.22 130 10857.42 88.66 150.37 131 10948.76 89.73 149.37 132 11043.63 90.07 150.66 133 11136.46 89.25 151.00 134 11228.31 89.42 150.72 135 11321.97 86.50 149.43 136 11412.56 87.08 149.83 137 11505.07 87.84 149.69 138 11598.29 87.46 149.89 139 11688.76 87.15 149.84 140 11781.84 86.26 149.32 141 11875.15 85.92 150.48 142 11969.09 87.08 150.62 143 12062.50 87.67 150.79 144 12090.34 88.01 151.21 Projected to TD of 12147 ft 145 12147.00 88.01 151.21 92.58 91.08 92.68 91.87 92.00 91.01 92.62 92.03 91.54 91.36 91.34 94.87 92.83 91.85 93.66 90.59 92.51 93.22 90.47 93.08 93.31 93.94 93.41 27.84 56.66 TVD Vertical Dispt Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 6983.43 6982.20 6981.56 6981.37 6980.98 6981.02 6980.58 6979.53 6978.74 6979.64 6980.92 6981.09 6981.64 6982.70 6986.04 6991.11 6995.21 6999.03 7003.28 7008.63 7'015.00 7020.73 7025.01 7026.06 7028.03 5485.84 -3626.15 5576.91 -3706.84 5669.58 -3788.77 5761.45 -3870.14 5853.42 -3952,26 4851.94 4894.17 4937.48 4980.14 5021.61 5944.36 -4034.09 6036.90 ~4117.51 6128.85 -4200.30 6220.36 -4281.99 6311.71 -4362.11 5061.43 5101.68 5141.85 5183.14 5227.02 6402.98 -4441.10 6497.80 -4523.27 6590.61 -4604.32 6682.44 -4684.54 6775.98 -4765.65 5272.86 5320.27 5365.52 5410.24 5456.93 6866.36 -4843.69 6958.72 -4923.53 7051.80 -5004.02 7142.11 -5082.18 7234.97 -5162.31 5502.66 5549.20 5596.07 5641.44 5688.49 7328.00 -5242.85 7421.74 -5324.50 7515.03 -5405.88 7542.85 -5430.21 5735.17 5781.27 5826.93 5840.42 7599.47 -5479.83 5867.69 6057.25 126.77 0.83 6139.51 127.14 0.73 6223'.62 127.50 1.56 6307.12 127.85 1.23 6390.37. 128.20 1.29 6472.40 128.56 0.77 6555.99 128.91 0.62 6639.36 129.24 0.31 6723.12 129.56 2.20 6808.06 129.85 2.64 6893.94 130.11 1.60 6983.21 130.37 1.41 7070.26 130.63 0.96 7156.51 130.89 0.36 7244.97 131.13 3.41 7330.80 131.36 0.78 7418.55 131.58 0.84 7507.08 131.80 0.46 7593.05 132.01 0.35 7681,69 132.22 1.11 7770.44 132.43 1.29 7859.61 ,132,64 1.24 7948.37 132.85 0.66 7974.81 132.92 1.94 8028.60 133.04 0.00 Srvy' Tool tool qual type type MWD. 6-axis MWD 6-axis MWD - MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD - MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis [(c)2000 Anadrill IDEAL ID6 0C 07] RECEIVED Alaska Oil & Gas Cons. Gom.'r~ssior~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ' 11 Type of request: Aband~n _ Suspend _ O~erational shutdoWn _' ....... R~u-~nter ~s-p~r~l-~-d ~-~i--- ....................................................................... Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _ Change approved program _ Pull tubing _ Vadance Perforate _ Annular Injection - X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development_X RKB 56' feet 3. Address iExploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ iAnchorage, AK 99510-0360 Service Colville River Unit !4. Location of well at surface 8. Well number ==394' FNL, 2405' FWL, Sec.5, T11N, R5E, UM CD1-25 At target (7" casing point in Alpine)) 9. Permit number / approval number 2286' FSL, 1429' FWL, Sec 4, T11 N, R5E, UM .... per APD 200-08 At effective depth 10. APl number 50-103-20325-00 At total depth 11. Field / Pool 364' FNL, 2449' FEL, Sec.9, T11 N, RSE, UM ...... per APD Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured 12147 feet true vertical 7028 feet Effective depth: measured 12147 feet true vertical 7028 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 77' 16" 10 cu.yds, Portland Type 3 114 114 Surface 2735' 9.625" 391 sx ASL3, 230 sx Class G 2771' 2400' Production 8852' 7" 136 sx Class G 8887' 6981' CD1-25is asan open hole production well. Itwas suspended after being completed with 4-1/2" tubing.' -- "EIVED Itis intended that the 9~5/8" x 7" annulus be used for injection of associated drilling waste as per the previously applied for annular waste disposal permit application.APR1 82000 0 RIG IN ~!. '~asl(a 0it & Gas C~s. Commlssioi Anchorage 13. Attachments Description summary of proposal__ Detailed operations program _ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: April 30, 2000 16. If proposal was verbally approved Oil ~ Gas __ Suspended __ Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ::Signed /~ ~/~[~/ N ~) . ~,~,~ $ i~.¢,,~- Title: Drilling Team Leader Date /'?t"// '7/ O O . FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witnessIIAppr°val no.....~ /O,~, Plug integrity_ BOP Test __ Location clearance _ Mechanical Integrity Test_ Subsequent form required 10-~.'~ ~.~0~ ~ ~;ir,~r..~C.~ ~=:~:.~_,_A. ~ .......... ,.., Commissioner Date Approved by order of the Commission ...... ~ e ,~1~ e. a e~, ~=~ ~,~. ......... Robert N. Ghristen$on /~,pproved Copy Returned Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 17, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on well: CD1-25 Dear Sirs: ARCO Alaska, Inc. hereby requests that CD1-25 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Please find attached form 10-403 and other pertinent information as follows: , 2. 3. 4. 5. 6. 7. Form 10-403 Surface Casing Description Surface Casing Cementing Report Copy of the Daily Drilling Report covering surface casing cementing. Casing and Formation Test Integrity Report (LOT at surface casing shoe), Formation LOT on 9-5/8" x 7" casing annulus. CD1-25 Well Completion Schematic. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robertson Senior Drilling Engineer CC. CD1-25 Well File Alpine Files Doug Chester Gracie Stefanescu ANO-382 Anadarko R _CEJVED APR 8 2_000 Alaska 0it 8, Ga.~ Cons, Cofnmission ARCO Alaska. luc is a Subsidiary ,of Atla*:ticRichfieidCompany Casing Detail Well: CD1-25 9 5/8" Surface Casin.q Date: 3/5/00 ARCO Alaska, Inc. Subsidiary of Atla~ Subsidiary of Atlantic Richfield Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.30 FMC Gen V Hanger 2.40 36.30 Jts 3 to 72 70 Jts 9-5/8" 36# J-55 BTC Csg 2643.81 38.70 Davis Lynch Float Collar 1.50 2682.51 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 85.70 2684.01 Davis Lynch Float Shoe 1.77 2769.71 2771.48 TD 12 1/4" Surface Hole 2782.00 RUN TOTAL 41 BOWSPRING CENTRALIZERS - I per jt on Jt #1 - #12 (On stop rings of Jt #1 & ~2) #14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62, 64, 66, 68, 7O 3 Jts left out #73 - #75 ,.--CE Use Best-o-Life 2000 pipe dope Flemarks: Up Wt - 150k Dn Wt -121 k ~o~a ~ & Block Wt - 70k ~'~'~'"~ Supe~isoc D. Lutrick ARCO Alaska, Inc. Cementing Details Well Name: CD1-25 Report Date: 0310512000 Report Number: 3 Ri~l Name: Doyen 19 AFC No.: 998C04 Field: Alpine Centralizers State type used, intervals covered and spacing Comments: Ran total 41 Bow Spring Centralizers. One per joint on first 12 its, every other joint to surface. · I Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): comments: 9.6 16 13 46 11 Gels before: Gels after: Total Volume Circulated: 23~86 13/11 600 bbls Wash 0 Type: Volume: Weight: Comments: GELH20 40 8.5 Gelled w/Biozan w/6Sx coarse nut plug Spacer 0 Type: Volume: Weight: Comments: ARCO Spacer 50 10.5 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: comments: AS III LW 70 391 10.7 4.42 ·: Additives: 30% D53, 0.6% D46, 1.5% D79, 1.5% S1, 50% D-124, 9% D44 Tail Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G 70 230 15.8 1.15 Additives: 0.2% D46, 0.3% D65, 1% S1 Di~placement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 9.6 bpm 9.5 bpm 150k Reciprocation length: Reciprocation speed: Str. Wt. Down: 20' 10 fpm 121k Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 208 bbl 208 bbls Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:3/5/2000 yes yes Time: Remarks:No problems while RIH. Had full returns throughout job. Reciprocated csg until 75 bbls lead cement around shoe. Had approx 76 bble 10.7 cement to surface. Cement Company: I Rig Contractor: IApproved By: DS I DOYEN I Donald Lutrick RECEIVED APR 1 8 2_000 Oil & Gas Cons, Commission RF FIVED APR 1 8 2000 Alaska 0ii & Gas Cons. Commission Daily Drillirt l rt ARCO Alaska, Inc. I AFC No. I Date Rpt No I Rig Accept - hrs Days Since Accept/Est: 2.79 / 2.7 998C04 ~03/05/2000 3 ~03/03/2000 07:00:00 Rig Relase - hrs: I lAM Well: CD1-25 Depth (MD/I'VD) 2782/2406 Prev Depth MD: 2782 Progress: 0 Contractor: DOYON Daily Cost $199211 Cum Cost $ 522597 Est Cost To Date $ 522000 Rig Name: Doyon 19 Last Csg: 16" at 114' Next Cs~: 9 5~8" at 2748 Shoe Test: n/a Operation At 0600: Test 9 5/8" csg Upcoming Operations: LOT. Drill 8 1/2" hole .... MUD DATA DRiE~iN~ DATA i BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) 'LAST BOP/DIVERT LAST BOP/DRILL SPUD I N TST 02/24/2000 03/03/2000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.6pp~ 12.25 01/03/2000 02/20/2000 VISCOSITY PU w-r MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 50sqc HTC N SPACE 02/22/2000 06/2112000 PV/YP SO w'r TYPE TYPE TYPE FUEL & WATER 13 / 11 MXC1 _ 4320 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 4 / 2 / 3 D80ZJ APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1170 18.0 2782 02/29/2000 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN i POTABLE WATER 85 mi/30 rain 114 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 7,0% 2668 CD196 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F -17 186bbl 21001 I I 14.65/7.51 / CD1~25 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 20 20.0 I 121 I 15- 30 1-4 3h LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 80° 8.0 5.5 I 6.0 I I 166- 240 1200 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F -62.71 4.4% 70 1701 I .546 Water Base Muds 1740 PIT VOL GPM 2 JETS JETS Diesel ARCO PERSONNEL 1 126 250129711 IIIII IIIII 60 Other 155 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 27 $5886 III 11900 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $15221 I I I 1 I 2 I ECl G I I 1955 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 18 M~ 9.6 1 I I E I I I WTITD I I 24576 PERSONNEL TOTAL 51 ~i~E :1 : EN~;: IPHASEOPS I OPERATIONS FROM0000-O000 ..... 12:00 AM 12:30 AM 0,50 ClRC SURF Making Hole Circ hole clean. 12:30 AM 02:30 AM 2.00 TRIP_OUT SURF Making Hole POH. Tight at 1150'. 02:30 AM 04:30 AM 2.00 BHA SURF Making Hole LD DC's, Stabs, MWD and motor.(Dus for inspection and repair) 04:30 AM 10:30 AM 6.00 CASG SURF Casing and RU to run csg. Held PJSM. RIH w/9 5~8" csg to 2782'. No Cementing problems. 10:30 AM 12:30 PM 2.00 CIRC SURF Casing and MU cement head. Circ and condition mud. Final circ rate - Cementing 10 bpm at 700 psi. 12:30 PM 02:30 PM 2.00 CEMENT SURF Casing and PJSM. Pump 40 bbls vis water w/6 sx coarse nut plug, 50 Cementing bbls 10.5 spacer, 308 bbls 10.7 cement, 47 bbls 15.8 cement, drop top plug, 20 bbls h2o and 188 bbls mud. Displaced mud w/rig pumps. Bumped plug. 02:30 PM 05:00 PM 2.50 CASG SURF Casing and Check floats. LD LJ. Clear floor. Change bales. PU wash Cementing tool and wash out diverter. 05:00 PM 06:30 PM 1.50 NU_ND SURF Casing and ND diverter. NU well head. Test seal to 1000 psi. Cementing 06:30 PM 07:30 PM 1.00 NU_ND P1 Other NU DOPE. 07:30 PM 08:30 PM 1.00 DOPE P1 Other RU to test BOP. Install test plug. 08:30 PM 12:00 AM 3.50 DOPE PROD Other Test DOPE to 300 - 3500 psi. w/annular to 2500 psi. Witness od test was waived by AOGCC rep John Spalding. Daily Drilling Report: CD1-25 03/05/2000 Page 1 CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1,25 Date: Supervisor: Donald Lutrick Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep TeSt: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Hole Depth: 2,802' TMD 2,410' TVD Casing Setting Depth: 2,772' TMD 2,400' TVD Mud Weight: 9.6 ppg Length of Open Hote: 30' NOTE: STROKEs TURN TO MINUTES DURING "SHUT IN TIME":see time line above STROKES Fluid pumped = 1.1 BBL BLED BACK .-e-- LEAK-OFF TEST -.e'"*CASING TEST Pump output = .101 BPS EMW = 15.98 ppg Press EMW = ~ Mud Weight 0.052 xTVD 800 psi + 9.6 ppg 0.052 x 2,400' 2418 t"' LOT SHUT IN TIME ~- CASING TEST SHUT IN TIME [ TIME UNE LEAK-OFF DATA MINUTES MINUTES FOR LOT STROKES PRESSURE cea TEST sTROKES pRESSURE i 2 stks 200 psi ............. ;---~ s~--~ ,r---gfi~-~-~T--1 ? ................ f .......'---- ...... '----i i- ................. L...6. s._t_k._s__. i 8 stks 660 psi j '~'~'~'k'~ '~ I~'~i~ J 10 StkS !;100 P-~i { i 4 StkS ,420 Psi ? ........... ,, ......................... 'J .................... -J-S-~t~ 1,610 psi i' ......................... ~ ................. -t ................. ~- ...... ,~' ............................ ' ................. ! J ................. _22..~S_t ks.___: 20 Stks 2,220 PSi ' 2,440 PSi 25 StkS 2,520 psi I ' I ~ ........ ' ..........+ ................ ! SHUT IN 'rIME i .............i- ....... ,J J 0.0min J 2,500psi I i ! 5.0 min 2,495 Psi C ......... , j ! i............'---2,490--~'~i"~ i SHLFFINTIME [ ~HUT IN PREESUR~ 15.0 min ' .......... ._ 1.0 min J I 670 ~ 25.0 min ,.j_. 2~j 2.0 min[.; I 625 psi 30.0 rain , , 2,475 psi , /_..3.:g_.m. Lg_..J ...... j____60_0_Ds_J._i ..... : ............. ~...:;: _:=_...: J' 40min ! i 595Dsi J ..... " .......... [ ...... t ..... ~-""t ....... !---''''--'-"~' '~'-' -'"'- ...... ...... / 6.0 min J i 580 DSi .j 7.0 mln , ,~_ .580.~s.,~ !----;--:--:-.------~ .......... '=~ . -- .... ?---"~ -----.---~ · ;~....u....u_.mj..n....~ ............ .~__~_u.u_Ds__~ ..~ ___ .... ..... : .......... 9.0min [ [ 580psi _j L..]..o.=g...m. Ln. ...... ,.._5 8_o.p_s_i .............. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DE~ KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-25 Date: 3/11/00 Supervisor: Donald Lutrick Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 518" 36# J-55 BTC CSG X Casing Setting Depth: 2,772' TMD 2,400' TVD 7" 26# L-80 BTCM CSG TOC Hole Depth: 8,140'TMD 6,625' TVD Mud Weight: 9.6 ppg Length of Open Hole: 4,388' EMW = Press .052 X TVD + Mud Weight 661 psi + 9.6 ppg 0.052 x 2,400' EMW = 14.9 ppg Pump output = .020 BPS Fluid Pumped = ' 1.0 bbl Used cement umt BLED BACK --e-- LEAK-OFF TEST LOT SHUT N T ME Bills NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT BBLS 0.0 bbls T PRESSURE 30pSi 3.5 bbls J 222 psi ..... 5.0 bbls / 884 pSi 6.0 bbls i 510 psi .......... 6.5 bbls ]--~' .............. 7-0 bbls i:~l 7.5 bbls 8.0 bbls 11.0 bbls SH~ IN ~ME SHUT [N~RESSURE 0.0 min 631 1.0 min 61! psi 2.0 min 3.0 min ;594 psi 4.0 min 5.0 min 6.0 min 7.0 min 8.0 min 9.0 min 10.0 min NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DEEETE {iver Field 16" C0ndUct0r t0 1i4, Completed 4-1/2" Camco BAL.O SSSV Nipple (3.812" ID) at 1864' MD Isolation Sleeve with DB-6 No-Go Lock (3,812" OD) run in profile Dual 1/4" x 0,049" s/s control lines ;5/8" 36 ppf J-55 BTC Surface Casing @ 2771' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" E Dummy with 1" BK-2 Latch 4-1/2" 12,6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube pipe dope Camco KBG-2 GLM (3.909" ID) E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3,909" ID) & I" Camco DCK-2 Shear Valve {Sheared oatl Baker S3 Packer at +/- 8486' WRDP-2 SSSV (2,125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 nee KCI Brine with 2000' TVD diesel ca0 Tubing Subended with diesel to lowest GLM ComDletion MD Tubing Hanger 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1864' 4-1/2~, 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4034' 4-1/2", 12.6#/ft, ~BT-Mod Tubing Camco KBG-2 GLM (3,909" ID) 6338' 4-1/2", 12.6~/ft, IBT-Mod Tubing Camco KBG-2 GLM (3,909" ID) 8362 4-1/2" tubing joints (2) HES "X" (3.813~ ID) 8443' 4-1/2" tubing joint [1) 3aker S3 Packer 8486' 4-1/2" tubing joint (2) HES "XN" (3.725" ID/ 8563' 4-1/2" 10' ~up joint WEG I+/- 63 deg) 8575' Note: 86 solid body aluminum centralizers installed 3e~ween joints 97 and 182. Calculated TOC @ +/- 8140' MD RECEIVED APR 1 8 000 7" 26 ppf L-80 BT,(; Mod Production Casing @ 8887 MD @ 88 deg Well TD at 12147' MD / 7028' TVD MWD/LWD Log Product Delivery Customer Arco Alaska, Inc. ~...~ Dispatched To: AOGCC Well No CD1-25 ~-rO ~ Date Dispatche 21-Mar-00 Installation/Rig Doyon 19 Dispatched By: Nathan Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 Received BY: ~i!~~ ) 3940 Anadr, II Please sign and return to: Arctic LWD Blvd. Division Suite 300 Anchorage. Alaska 99503 rose@anchorage.anadrill.slb.com ~) ~ ~ r' ! % ff r" ~, Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 200e Aias~ Oil & Gas Cons. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' Robert Christenson,/~ DATE: March 11, 2000 Chairman THRU: Blair Wondzell, ~O.~ P. I. Supervisor 3;h~o~ FROM' John Crisp,~/.~/~w. ~. SUBJECT: Petroleum Ihbpector BOP Test Doyon 19 pine CD1-25 D :20008--'~-~ March 11~ 2000: I traveled to Arco's Alpine Field from NPR-A Clover location to witness the weekly BOP test on Doyon 19 drilling well CD1-25. The AOGCC BOP test report is attached for reference. One failure was witnessed during the test. The manual valve on the kill line failed to hold pressure. This valve was repaired immediately. The Rig is in excellent condition. All Rig personnel involved with this test were very familiar with BOP equipment & test procedures. It was a pleasure testing BOP's on Doyon Rig 19. SUMMARY: I witnessed the weekly BOPE test on Doyon Rig 19 drilling well CD1-25 in the Alpine Field. BOP test Doyon 19. Test time 5 hours. One failure. Attachments: BOP Doyon 19 3-11-00jc cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMI:SSlON BOPE Test Report OPERATION: Ddg: X Workover: DATE: 3/11/99 Drlg Contractor: Doyen Drlg. Rig No. 19 PTD # 20008 Rig Ph.# 907 263-3000 Operator: Arco Alaska Inc. Rep.: Donnie Lutn'ck Well Name: Alipine CD1-25 Rig Rep.: Ron Matteson Casing Size: 7" Set @ 8870' Location: Sec. 5 T. 11N R. 6E Meridian UM Test: Initial Weekly x Other Test MISC. INSPECTIONS: Location Gen.: OK , Housekeeping: OK (Gert) PTD On Location YES Standing Order Posted YES Well Sign YES Drl. Rig OK Hazard Sec. YES FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Quan. Pressure P/F I 250/3, 500 P I 250/3, 500 P 1 250/3, 500 P I 250/3, 500 P BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves 1 Check Valve Test Press. P/F 250/2, 500 P 250/3, 500 P 250/3, 500 P 250/3, 500 P 250/3, 500 250/3, 500 250/3, 500 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 250/3, 500 P 36 250/3, 500 P I YES Functioned Functioned YES ACCUMULATOR SYSTEM: ~ System Pressure ~,000~,, 1,, IP Pressure After Closure 450 ,J P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure ~es ~ sec. Trip Tank YES YES System Pressure Attained 3 minutes~ sec. Pit Level Indicators YES YES Blind Switch Covers: Master: YES Remote: YES Flow Indicator YES YES Nitgn. Btrs: 4 Btls, @ 1975psi, ave. Meth Gas Detector YES YES Psig. H2S Gas Detector YES YES "Number of FailureS: (/'~ 1 "~2 ,TeStTime:' :~ ~:)urs:~ ' ~'~:~Number: °f valveS: teSt~e~ .... 20 Repair or Replacement of Equipment will be made within ~,...--/ 0 (~ Notify the Inspector and follow within or Faxed verification to the AOGCC Commission Office at: F-~'x No.~- 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Manual valve on kill line failed pressure test. Repaired & retested 01~ Rig is in excellent condition. Rig Manager, Ddlier & all personnel involved w/ testing BOPs were very familiar with equipment & test procedures. All personnel were a pleasure to work with. Distribution: orig-Well File c- Open/Rig c- Database c - Trip Rpt File FI-021L (Rev. 12/94) C -Inspector STATE WITNESS REQUIRED? YES X NO 24- HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John Crisp 19 3-11.O0jc.~ls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson, Chairman THRU: Blair Wondzell, P. I. Supervisor DATE: FROM' Jo h n Crisp,L~/7~o~v ~__~' SUBJECT: Petroleum I~spector March 11, 2000 BOP Test Doyon 19 Alpine CD1-25 PTD 20008 March 11, 2000: I traveled to Arco's Alpine Field from NPR-A Clover location to witness the weekly BOP test on Doyon 19 drilling well CD1-25. The AOGCC BOP test report is attached for reference. One failure was witnessed during the test. The manual valve on the kill line failed to hold pressure. This valve was repaired immediately. The Rig is in excellent condition. All Rig personnel involved with this test were very familiar with BOP equipment & test procedures. It was a pleasure testing BOP's on Doyon Rig 19. SUMMARY: I witnessed the weekly BOPE test on Doyon Rig 19 drilling well CD1-25 in the Alpine Field. BOP test Doyon 19. Test time 5 hours. One failure. Attachments: BOP Doyon 19 3-11-00jc cc; STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial X Workover: __ / DATE: Doyon Drlg. Rig No. '/9 PTD # 20008 Rig Ph.# 907 263-3000 Arco Alaska Inc. Rep.: Donnie Lutrick Alipine CD~-25 Rig Rep.: Ron Matteson Set @ 8870' Location: Sec. 5 T. I'/N R. 6E Meridian UM Weekly x Other Test MISC. INSPECTIONS: Location Gen.: OK Well Sign Housekeeping: OK (Gen) Drl. Rig PTD On Location YES Hazard Sec. Standing Order Posted YES ,, YES OK YES FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Quan. Pressure P/F 1 250/3, 500 P 250/3, 500 P 250/3, 500 P 250/3, 500 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F ~ 250/2, 500 P 250/3,500 P 250/3,500 P 250/3,500 P 250/3, 500 P 250/3,500 P 250/3,500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 250/3,500 P 36 250/3,500 P ~ YES Functioned Functioned YES ACCUMULATOR SYSTEM: System Pressure 3,000 P Pressure After Closure ~,450 ~ P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 28 Trip Tank YES YES System Pressure Attained 3 minutes 9 Pit Level Indicators YES YES Blind Switch Covers: Master: YES Remote: Flow Indicator YES YES Nitgn. Btl's: 4 Btls. @ 1975psi. ave. Meth Gas Detector YES YES '" Psig. H2S Gas Detector YES YES ," sec. sec. YES Equipment will be made within' 0 ~ Notify the Inspector and follow within or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No, 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. h Supervisor at 279-1433 REMARKS: Manual valve on kill line failed pressure test. Repaired & retested OK. Rig is in excellent condition. Rig Manager, Driller & all personnel involved w/ testing BOPs were very familiar with equipment & test procedures. All personnel were a pleasure to work with. ~ Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspel~t.(~,lL (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John Crisp 'on 193-11-00jc Re: Extension of Horizontal Section Well CD1-25 ·" it No. 200-008 Subject: Re: Extension of Horizontal Section Well CD1-25: Permit No. 200-008 Date: Wed, 15 Mar 2000 16:13:37 -0900 -~ From: Blair Wondzell <blair_wondzell~admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Brian Robertson <BROBERT4~mail.aai.arco.com> CC: Douglas K Chester <DCHESTER~mail.aai.arco.com>, Douglas G Knock <DKNOCK~mail.aai.arco.com> Brian, Sorry I just now got to this email. No problem with drilling the additional hole provided a spacing exception is not needed; if so, it may delay the production of the well. We hope it makes a good well. Regards, Blair Wondzell 3/15/00. Brian Robertson wrote: Blair, We are nearing the end of the horizontal section on the subject well. Inclination is currently about 86 degrees and we are moving down in section to try and find the base of the sand (for geological information). However the sand appears to be a bit thicker than prognosed and I believe that we could end up as much as 40Oft past the end point coordinates provided in the APD before we hit the base. There are no other wells out in front of us so collision avoidance is not an issue. The end point coordinates submitted in the APD were 364' FNL, 2449' FEL Sec 9, TllN, R5E. We can see no downside to extending the length of this wellbore. I'd appreciate your thoughts and concurrence. We will be drilling this extension this evening. Please call / e-mail me to discuss. Regards Brian Robertson - Alpine Drilling Engineer (907) 265 - 6034 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION Doug Chester Drilling Team Leader ARCO Alaska. lnc. P O Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re~ CD 1-25 ARCO Alaska. Inc. Permit No: 200-08 Sur. Loc. 394'FNL. 2405'FWL? Sec. 05. 'Fl IN. R5E. UM Btmholc Loc. 364'FNL. 2449'FEL. Sec. 09. TI IN. R5E. UM Dear Mr. Chester: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other rcquircd permitting determinations arc made. Annular disposal of drilling wastes will not bc approved for this well until sufficient data is submitted to ensure that thc requirements of 20 AAC 25.080 arc met. Annular disposal of drilling waste will bc contingent on obtaining a well cemented surface casing confirmed bv a valid Formation Integrity Test (FIT). Cementing records. FIT data. and any CQLs must bc submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which arc pumped down thc surface/production casing annulus of a xx-cll approved for annular disposal on Drill Site CD I must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill docs not authorize disposal of drilling waste in a volume greater than 35.000 barrels through thc annular space of a single well or to usc that xx.cll for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of thc Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting thc Commission petroleum field inspector on thc North Slope pager at 659-3607. Robert N. Christcnson. P.E. Chair BY ORDER OF ~'~OMMISSION DATED this day of February, 2000 dlf/Enclosures cc~ Depamnent of Fish & Game. Habitat Section w/o cncl. Depamnent of Environmental Conservation wlo encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~ lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation ~ Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559 ~'~.~5-,,~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 394' FNL, 2405' FWL, Sec.5, T11N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 2286' FSL, 1429' FWL, Sec. 4, T11N, R5E, UM CD1-25 #U-630610 At total depth 9. Approximate spud date Amount 364' FNL, 2449' FEL, Sec. 9, T11N, R5E, UM 02/18/00 $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 Alpine CD1- 24 11,871' MD Crosses Sec. 4 to feet 9.8' @ 294' Feet 2560 7,006' TVD feet Sec 9 T11 N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 91 o Maximum surface 2469 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quanti~ of cement Hole Casin~l Wei~lht Grade Couplinc, l Len~Ith MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2709' 37' 37' 2746' 2400' 533 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 8833' 37' 37' 8870' 7001' 135 sx Class G N/A 4.5" 12.6# L-80 IBT-M 8427' 37' 37' 8464' 6884' Tubing 19. To be completed for Redrill, Re-entry. and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Structural Intermediate Production r.~ [.~... ~ ~..~. ~ i , Liner~/ [~ I '~ ~ ' ~ ';' : ~ ' Perforation depth: measured : 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch '~ ..... Ddli'ng program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify/~hat the foregoing is true and correct to the best of my knowledge // Signed,,A~,~_..../! Title Drillin9 Team Leader Date "'7' 0 Permit Number APl number Approval date See cover letter for 50- -,2 --I D .-- Other requirements Conditions of approval Samples required Yes /'"'~'.) Mud Icg required Yes Hydrogen sulfide measures Yes (/~N~~'""~-- Directional survey required ('"~ No Required working pressure for BOPE 2M 3M ~ 10M 15M "~5q3~ Other: ONIGINAL SIGNED 9¥'~ by order of App~oved by Robert N. Christensor~ Commissioner the commission Date ~;~'~'/ Form 10-401 Rev. 7-24-89 Submit in triplicate Alpine: CD1-25 Procedure 1. Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8-1/2" hole to the intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule 20 AC 25.030. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. 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 Y2, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels 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. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus Set BPV and secure well. Move rig off. . 3. 4. 5. 6. 7. 8. . 11. 12. 13. 14. 15. 16. 17. 18. 19. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-24 will be the closest well to CD1-25 (9.8' at 294' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 8.2' at 328' MD. Drillinq Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: There are no faults mapped within the immediate vicinity of CD1-25. The closest fault parallels the CD1-25 horizontal section, approximately 700' away. The potential for lost circulation in the Alpine Sand is therefore considered to be Iow. However if losses are encountered, conventional LCM treatments have been successful in controlling losses when encountered in previous CD1 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 Pumpin_~ Operations: Incidental fluids developed from drilling operations on well CD1-25 will be injected into the annulus of a permitted well. The CD1-25 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CDt-25 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi - 2,998 psi Pore Pressure - 1,086 psi Therefore Differential -- 2998 - 1086 -- 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi ..... 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi CD1-25 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 Y2" Section - 6 1/8" point- 12 ¼" 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 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 <10 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _+ 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 / 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 Iow 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 a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. 16" Conductor to 114' r Field Updated 01!25/! 4-1/2" Camco BAL-O SSSV Nipple (3.812' ID) at 1700' TVD = 1860' MD isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" s/s control lines 9~5/8" 36 ppf J-55 BTC Surface Casing @ 2746' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3,909" ID) at 3400~ TVD for E Dummy with 1" 8K-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3~909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" iD1 & 1" Camco OCK-2 Shear Valve ~inned for casing sloe snear@ + ~ 2000 psi set2joints abovethe Xlanding nipple Baker S3 Packe~ at +/- 8464' WRDP-2 SSSV (2,125"1D) w/DB-6 No-Go Lock (3,812" OD) -to be installed later Pecker Fluid mix: 9.6 eeo KCl Brine with 2000' TVD diesel cae Tubing 8upended with diesel to lowest GLM Completion M~D TVD Tubing Hanger 32' 32' 4-1/2", 12,6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1860' 1700' 4-1/2", 12.6#/ft, iBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4013' 3400' 4-1/2~, 12.6#/ft, iBT-Mod Tubing Camco KBG-2 GLM (3,909" ID) 6293' 5200' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3,909" ID) 8363' 6825' 4-1/2" tubing joints (2) HES X (3,813 ID) 8432' 6869 4-1/2 tubing joint (t) Baker S3 Packer 8464' 6884 4-1/2" tubing joint (2) HES "XN" f3.725" ID'~ 8529' 6919 4-1/2 10' puPlOmt WEG I./- 63 deg) 8540' 6924 Note: solid Doay aluminum centralizers installed between 2400' TVD (=2746'] and 4500' TVD (=5407') TOO @ +/- 8092' M t500' MD above tOD Alpine) Well TD at 11871' MD / Top Aleine at 8592' MD / 6946' TVD 7 26 ppf L~80 BTO Mod Production Casing @ 8870 MD / 7001 TVD @ 90 deg J 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3,812" ID), WRDP-2 SSSV (2.25" ID) and DB-6 No-Go Lock (3.812" OD) with dual 1/4" x 0~049" s/s control line @ 1700' TVD = 1860' MD )-5/8" 36 ppf J-55 BTC Surface Casing @ 2746' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'ri'Seal pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" 9K-2 Latch (A) Bonzai 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 Cellar - 4-1/2" joint (1- 2) blank - Guide Shoe (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,I0 ECP (anchor) - Muleshoe / Entry Guide (C) Open Hole Bridqe Pluq Assembly Baker Payzone ECP (cement inflated) -XO -Float Collar -4-1/2 Float Shoe Camco KBG-2 GLM (3.909" ID) 1" & Camco DCK-2 Shear Valve Pinned for casing side shear @ 2000 osi set 2 joints above the X landing nipple TOC @ +/- 8092' ME (500' MD above fop Alpine) 5aker S3 Packer se[ at + - 3464' Well TD at 11871' MD / 7006' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8870' MD / 7001'TVD @ 90 deg CD1-25 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MDFFVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2746 / 2400 14.2 1086 1532 7" 8870 / 7001 16.0 3167 2469 N/A 11871 / 7006 16.0 3170 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) ~ 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 -- Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP- (0.1 x D) Where; FPP - Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 } D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) -- 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP =[(FG x 0.052) - 0.1} D = [(14.2 x 0.052) - 0.1] x 2400 - 1532 psi OR ASP = FPP - (0.1 x D) = 3167 - (0.1 x 7001') = 2467 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3170 - (0.1 x 7006') = 2469 psi ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT -5500 -6500 -7500 8 10 11 12 13 EQUIVALENT MUD WEIGHT 14 15 16 17 AIp,..u, CD1-25 Well Cementinq Requir,..,~ents 9 5/8" Surface Casing run to 2746 MD / 2400' TVD. Cement from 2746' MD to 2246' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2246' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2246'-1677') X 0.3132 ft3/ft X 1.5 (50% excess) = 267.3 ft3 below permafrost 1677' X 0.3132 ft3/ft X 4 (300% excess) = 2100.9 ft3 above permafrost Total volume = 267.3 + 2100.9 = 2368.2 ft3 => 533 Sx @ 4.44 fta/sk System: Tail slurry: 533 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 8870 MD / 7001' TVD Cement from 8870' MD to +/- 8092' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (8870'- 8092') X 0.1268 ft3/ft X 1.4 (40% excess) = 138.1 ft3 annular volume 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 138.1 + 17.2 = 155.3 ft3 => 135 Sx @ 1.15 ft3/sk System: 135 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk i By Weight Of mix Water, all other additives are BWOCement ARCO Alaska, Inc. 350 StruCture: CDt~I Well : 25 · Field : Alpine Field Location : North Slope, Alaska 0 TRKB Elevation: 56' -- ........ ~ KOP J, 3.00 ~ I ~ nn I c,.,~,. ~ For: 350 ~ .... Begin Turn to Tgt / O~t..~d:~--~..-2000 / ~ 10.19 / Plot Referenc~ Im CDI-25 V,l~llon ~6, I ~ 18.00 ITru. vi~ttcol ecrm, ~,~ 21.00 DLS: .5.00 deg per 100 ft | ~ / 1050 ~1 24'.00 West Sok / ~ I ~- 27.00 -- x, ,o.oo h,~ 33.00 % 3~.oo 1400 '~, EeC 1750 ~mofrost =,oo x, ZmUTU ~XX~¢ 05/8 Cosincj Pt. K-$ AVERAGE ANGLE ~-2 4000 5250 5600 X Albi°n-97 5950 Albion-9§ 6500 90 DEG 6650 _ LCU Miluveoch A Alpine D DLS: 9.00 deg per 100 ft ' 75 93 7000Tgt- EOC - 7~50 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 550 0 550 700 1050 1400 1750 21 O0 2450 2800 3150 3500 5850 4200 4550 4900 5250 5600 59 Vertical Section (feet) -> Azimuth 121.06 with reference 0,00 S, 0.00 E from slot #25 2450 2800 (D 3150 3500 3850 I--- 4200 I v ~55o ~'~"~ For: B Robertson] Dote plotted: 24-Jun-2000 Plot Re~erence is C01-25 Vera;on Coordinotes ore in feet reference slot ~25. I [rue Verti¢(~l Depths ore reference RKB (Doyon 1~19).[ ARCO Alaska, Inc. Structure : CD#I Well : 25 Field : Alpine Field Location: North Slope, Alaska 5800 6000 6200 6400 r..> 6600 ..+-. > 6800 {.._ 7000 I 7200 7400 AVERAGE ANGLE 37.87 DEG 151.86 AZIMUTH 7325' (TO TD) ***Plane of Proposol*** TARGET ANGLE 90 DEG 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 ii i i i i i i i I i i i i i i i 5200 5400 ,:3600 3800 4000 4200 4400 4600 4800 6000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 Verficol Section (feet) -> Azimuth 151.86 with reference 0.00 N, 0.00 E from slot #25 For: B. Robert~on ARCO Alaska, Inc. Structure : CD#t We{~: 75 Field : Alpine Field Looaflon: Nodh Slope, Alaska 450 45O 0 45O go0 1550 1800 2250 2700 5150 5600 4050 4500 4950 5400 5850 6500 6750 7200 450 Easf (feel) -> 0 ,50 900 1350 1600 =50 2700 5,50 3800 SURFACE LOCATION: Be in Turn to Tgi ~'~G[~egEns[~e Sok 394' FNL, 2405' FWL SEC. 5, T11N, RSE K-3 K-2 Alblon-97 Albion -96 HRZ TARGET / CA~INO PT LOCATION~ INTERMEDIATE PT LOC~TION: 984' FSL, 2119' P~L SEC. 4, T11N, R5E JTO LOCATION: ] 564' FNL, 2449' FEL SEC. 9, TI1N, R5E · 50 900 1550 1800 2250 2700 3150 5600 4050 4500 4950 East (feet) -> 6750 450 0 450 900 1350 - 1800 2250 0 4500 4950 -5400 -6300 -6750 7200 6750 ¢,~t.~ ~ ~a,,.. For: B, Robertson Dots plott~: 24-J~-2000 Plot Re~erence i8 CDI-25 Ve~ion ~6. Coordlnotee ore in f~ reference slo~ ~25. I True Vert~col Depths ore reference RKB ARCO Alaska, Inc. Structure : CD#I Field : Alpine Field Well : 25 Location : North Slope, Alaska PoTnt KOP Begin Turn to Tgt West Sa k EOC Permafrost C40 C50 9 5/8 Casing Pt. C20 K-5 K-2 Albion-97 Albian-96 HRZ Bgn Trn/BId to Tgt K-1 LCU Miluveach A Alpine D Alpine Tgt - EOC - Csg Pt Begin Final Build End Final Build Begin Final Drop ntermediate Pt. End Final Drop TD - Csg Pt Base Alpine MD 250.00 485.55 1069.70 1529.02 1 677.40 2469.08 2741.42 2746.49 5205.77 4508.47 4805.61 7145.21 7525.22 7955.89 8212.85 8217.57 8546.98 8496.68 8542.55 8592.16 8870.21 8870.26 8998.05 10502.40 10545.25 10391.00 11871.31 11 871.35 PROFILE COMMENT Inc Dir TVD 0.00 155.00 250.00 7.00 135.00 482.75 24.09 118.72 1046.00 57.87 118.72 1458.87 37.87 118.72 1556.00 37.87 118.72 2181.00 57.87 118.72 2596.00 37.87 118.72 2400.00 37.87 118.72 2761.00 37.87 118.72 5791.00 57.87 118.72 4024.00 37.87 11 8.72 5871.00 37.87 118.72 6171.00 57.87 118.72 6511.00 37.87 11 8.72 6715.45 58.11 119.04 6719.00 47.62 129.04 6814.00 59.57 157.28 6905.00 63.04 1 39.38 6925.00 67.09 141.51 6946.00 90.00 151.86 7001.00 90.00 151.86 7001.00 91.28 151.86 6999.57 91.28 151.86 6970.48 90.00 152.01 6970.00 88.63 1 52.01 6970.55 88.63 1 52.01 7006.00 88.65 152.01 7006.00 DATA North 0.00 -10.07 -88.59 -201.90 -245.66 -479.14 -559.46 -560.95 -695.81 -1080.59 - 11 67.65 -1857.61 -1969.68 -2096.70 -2175.07 -2174.41 -2224.15 -2506.66 -2336.56 -2571.4O -2597.82 -2597.87 -2710.55 -5860.48 -5898.27 -5958.69 -5245.42 -5245.44 East 0.00 10.07 145.50 550.15 430.00 856.18 1002.79 1005.51 1251.68 1954.02 2112.90 3572.55 5576.92 5808.76 5948.17 5950.60 4025.00 4110.04 4156.64 41 65.59 4512.99 4515.02 4573.27 4988.20 5008.35 5029.84 5724.45 5724.46 V. Sect 0.00 13.82 168.46 404.09 495.09 980.63 1147.66 115O.76 1431.21 2231.38 2412.39 3847.25 4080.31 4344.45 4503.26 4506.04 4595.72 4710.86 4749.07 4791.67 5054.94 5034.98 5144.74 6264.81 6301.57 6540.83 7610.07 7610.09 Deg/lO0 0.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 9.00 9.00 9.00 9.00 9.00 9.00 1.00 1.00 0.00 3.00 3.00 0.00 0.00 ARCO Alaska, Inc. CD#1 25 slot #25 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD1-25 Version #6 Our ref : prop3524 License : Date printed : 24-Jan-2000 Date created : 10-Aug-1999 Last revised : 24-Jan-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 33.229,w150 55 35.750 Slot Grid coordinates are N 5975735.372, E 385830.277 Slot local coordinates are 393.21 S 2406.11 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-9236'>,,22,CD#1 PGMS <0-10255'>,,WD2,CD#1 PMSS <0-10796'>,,24,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <0-11300'>,,13,CD#1 PMSS <7755-11134'>,,26,CD#1 PMSS <0-8350'>,,26PHi,CD#1 PMSS <0-9357'>,,16PHi,CD#1 PMSS <8393 - 12600'>,,16,CD#1 PMSS <0-11067'>,,32PHi,CD#1 PMSS <10016 - 11136'>,,32,CD#1 PMSS <472 - 1545'>,,36PHi,CD#1 PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <0-10897'>,,3,CD#1 PMSS <0-12055'>,,40,CD#1 PMSS <0-7331'>,,1PHi,CD#1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <384 - 14477'>,,23,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <0-10224'>,,39PHi,CD#1 PMSS <9146 - 13289'>,,39,CD#1 PMSS <0-8844'>,,45PHi,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <0-10504'>,,5PHi,CD#1 PMSS <9499 - 14515'>,,5,CD#1 PMSS <0-10548'>,,19,CD#1 CD1-38 Version #4a,,38,CD#1 CD1-27 Version #7,,27,CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 28-Jun-1999 28-Jun-1999 28-Jun-1999 28-Jun-1999 15-Ju1-1999 1-Nov-1999 4-Jan-2000 4-Jan-2000 25-0ct-1999 4-Jan-2000 23-Dec-1999 4-Jan-2000 4-Jan-2000 22-Dec-1999 23-Dec-1999 4-Jan-2000 28-Jun-1999 4-Jan-2000 27-Jun-1999 18-Aug-1999 26-Aug-1999 4-Jan-2000 22-Sep-1999 4-Jan-2000 16-Nov-1999 23-Jan-2000 23-Jan-2000 28-Jun-1999 13-Jan-2000 17-Jan-2000 29.4 1157.2 9.8 99.9 119.8 10.2 10.2 90.0 90.0 69 7 69 7 110 1 110 1 110 1 170 0 219 8 150 1 239 6 239 6 19 9 120 1 140 0 140 0 199 9 199 9 198 9 198.9 59.3 129.7 20.0 294.4 1066.8 294.4 100.0 100.0 100.0 100.0 100.0 100.0 350.0 350.0 100.0 100.0 100 0 100 0 261 1 100 0 250 0 250 0 100 0 00 100 0 100 0 200 0 200 0 305 6 305 6 338 9 200 0 200 0 294.4 1066 8 294 4 100 0 8464 5 11360 0 100 0 2340 0 11871 3 350 0 350 0 100 0 100 0 100 0 100 0 7800 0 100 0 250.0 10860.0 11760.0 11871.3 383.3 383.3 200.0 200.0 305.6 8706.7 338.9 11871.3 11871.3 ARCO Alaska, InC Post Office bo× 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 26,2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-25 Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is February 18, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-25 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole producer. At the end of the work program, the well will be closed in awaiting field start up. 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 lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, ~ Brian Rober~son Senior Drilling Engineer Attachments CC: CD1-25 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 AND 382 AND 384 Anadarko- Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com ARCO Alaska, Inc. Kuparuk Unit Disbursement Account P.O, Box 102776 .: AnChorage; AK 99510-2776 .: PAY TO THE ORDER OF: STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMi 300:i PORCUPINE DRIVE :73~426 839 0997587 ~O~.D: ::~ER: 1.90 DAYS. The First National Bank of ChiCago-0710 Chicago, Illinois Payable Through Republic Bank Shelbyville;,: Kentucky ~::~ '::~ : '~ACE ~UMB~R:''¥ WELL PERMIT CHECKLIST COMPANY //'-~)/~ WELL NAME ~/~. ~--~)/- ~'"'PROGRAM: exp~dev~ , FIELD&POOL /~-(..~ ,/~.~.~"~ INIT CLASS ?.~? N ADMINISTRATION 1. Permit fee attached. 2. Lease number approl~ri~it~.' ~' ~,~'~r~.~ .~}~.~.~.' i .~.'i/.~i-~/i DATE A '/,3~R ~-/-~) 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. DOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~ ~'~ ~ .psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. ¢/redrll ~ serv ~ wellbore seg ann. disposal para req ~ UNIT# (~"4~ ~__-~"~ ON/OFF SHORE ....... (~/7 GEOLOGY 30. 31. 32. ¢.-/- ~ 34. ANNULAR DISPOSAL 35. APPR DATE V~r¢/ 7~ i/2.~o0 Permit can be issued w/o hydrogen sulfide measures ..... N Data presented on potential overpressure zones ....... N Seismic analysis of shallow gas zones ............ Y N Seabed condition survey (if off-shore) ............. Y N Contact name/phone for weekly progress reports [exploratory only](.~N With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (~ N (B) will notcontaminatefreshwater;orcausedrillingwaste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a (~ N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. N G EOLO. G~,Y~, ENGINEERING: UIC/Annular COMMISSION: RP~ BEW WM t'd¢3 ~,1/~:::~ OWJ SF JDH~ RNC Comments/Instructions: - c:\msoffice\wordian\diana\checklist (rev. 09/27/99)