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Home My WebLink About199-026 prD l qg —D26, Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, October 22, 2017 10:47 AM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject: CRU CD1-24(PTD 199-026) Report of Sustained Casing Pressure Follow Up Flag: Follow up Flag Status: Flagged Victoria, Alpine gas-lifted producer CD1-24(PTD 199-026) has recently experienced sustained casing pressure on the IA exceeding 2000 psi. The production casing for this well is 7",26 lb, L-80 grade casing which has a burst pressure rating of 7240 psi. The IA pressure has remained well below 45%of the production casing burst rating(the highest pressure the IA has reached to date is 2200 psi). CPAI will continue to monitor the well condition and determine an appropriate path forward. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED ' : << STATE OF ALASKA ALASKA* AND GAS CONSERVATION COMMIS. 1.OperationsPertormed: Abandon REPORT Repair SUNDRY rWELL S OPERATIONS w f eb Alter Casing fl Pull Tubing fl Perforate New Pool r Waiver r Time Extension Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development For Exploratory r 199 -026 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service - 50- 103 - 20295 -00 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25559 • " CD1 - 9. Field /Pool(s): Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 13706 feet Plugs (measured) None true vertical 6951 feet Junk (measured) None Effective Depth measured 13706 feet Packer (measured) 9807 true vertical 6951 feet (true vertucal) 6773 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2784 9.625" 2820 2390 PRODUCTION 10736 7 10771 6948 ep ARR it 10 RECEIVED' Perforation depth: Measured depth: open hole 10771' 13706' True Vertical Depth: 6948' -6951' MAR a a 0 2.01 ,Alaska Oil & Gas Cans. Canniasion Tubing (size, grade, MD, and TVD) 4.5, L -80, 9895 MD, 6813 TVD r.,..21ortin Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 9807 MD and 6773 TVD NIPPLE - CAMCO BAL-0 NIPPLE @ 1791 MD and 1705 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 10771' - 13706' Treatment descriptions including volumes used and final pressure: refer to attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 393 1508 1977 -- 193 Subsequent to operation 318 1214 1879 -- 191 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development .�� " Service r Stratigraphic 15. Well Status after work: Oil ' " Gas r WDSPL fl Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Schneider 265 -6859 Printed Name Tim Schneider Title Staff Production Engineer Signature `4/G l �/ Phone: 265-6859 Date 21-1, RBDMS MAR !A A 3. 3 « Form 10 -404 Revised 10 /2010�Submit Original Only CD1 -24 Well Work Summary DATE SUMMARY 2/22/11 Initial pressure TBG /IA /OA- 7 000/450; Facility pumped 50 bbl PW pr sh; LRS pumped 77 gallons WAW5206 into 17 bbl PW (3.1 bpm), 880/1000/450; LRS pumped 770 gallons SCW4004 into 104 bbl PW (2.7 bpm), 890/950/450; Facility pumped 1256 bbl PW overflush. Shut -in 12 hours. Returned to Production. _;gyp , WNS • CD1 -24 Iv' W. IIbo 8. 202 ( ALPINE a _ - - -_ _ -.: Well Status :Max IMO O BM Act Btm ( MD a . ,fix 'TD AIaS )i13. - K . - ;x ftK6j 3 706.0 Cane t H28 (ppm) Date Annotat on End Date KB -Grd (ft) Rig Release Date ... Well0.694 - C01- 24,2rsrz01 3E'.37 PM SSSV WRDP I Last WO: '. 43 81 8/5/2000 - -- _�_� SGremazic Actual Annotation Depth (HKB) End Date Annotation Last Mod -_ End Date Last Tag: I I Rev Reason: FORMAT UPDATE Imosbor 2/6/2011 _ Casin • Strings HANGER 33 -" Casing Description String 0... String ID ... Top (ft68) Set Depth (f... Set Depth (ND) ... String .. ng Wt.'String String Top Thrd CONDUCTOR 16 15.062 37.0 114.0 114.0 62.58 H -00 WELDED Casing Description Siring 0... String ID Top (ftK8) Set Depth (L. Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 36.6 2,820.5 2,390.1 36.00 J - 55 BTC - Casing Description String 0... Siring ID Top (ftKB) Set Depth (f Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 35.0 10,771.0 6,948.2 26.00 L BTM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt... String .. String Top Thrd OPEN HOLE 1 6 1/8 6.125 10,771.0 13 706.0 6,951 2 Tubing Strings (Tubing Description (String 0... IString ID ... Top (ftKB) Set Depth (1... Set Depth (ND) . Str ng Wt.-. String .- String Top Thrd . TUBING 37 T R, Completion Def 4 1/2 1 _ 3.958 I 32 7 I 9,896 0 I 6,813 7 ... I 12.60 L-80 I IBTM CONDUCTOR, p ails Top Depth (ND) Top Inel Nomi... Top (RKB) (ftK (1 Item Description Comment ID (in) 32.7 32.7 0.39 HANGER FMC GEN V TUBING HANGER 4.500 1,790.8 1,705.1 33 -59 NIPPLE CAMCO BAL-0 NIPPLE 3.812 _ 9,752.4 6,743.7 56.36 NIPPLE HES X NIPPLE 3.813 9,807.5 6,772.8 60.85 PACKER BAKER S-3 PACKER 3.875 WRDP, 1.791 9,883.9 6,808 3 63.92 NIPPLE HES XN NIPPLE 3.725 NIPPLE, 1,791 -- , 9,89944 . 8 8 6,8132 6431 WLEG WIRELINE RE -ENTRY GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) ...i . _- Top Depth (TVDI Top Inc' Top (ft66) (HKE) ) Description Comment Run Date ID (in) 1,790 -8 1 /C I i 59 WRDP CAMCO WRDP -2 (HSS -197) 7/21/2010 2.125 Notes: General & Safety End Date Annotation 4/14/2010 NO FE: LEAK FOUND IN GLM @ 4550' I I l 1/6/2011 NOTE: View Schematic w/ Alaska Schematic9.0 SURFACE, 37-2,820 GAS LIFT, 4,450 1 it GAS LIFT, " " "' -- 7,344 t. ' GAS LIFT,_ _ 9,692 h I� it NIPPLE, 9,752 -- PACKER, 9,807 _/ I NIPPLE, 9,884 1 � y Mandrel Details . •... , ' Depth Top Port (TVDI Inc' OD Valve Latch Size TRO Run T Stn Top(RKB) (HKB) ( °) Make Modal (in) sera Type Type (in) (Psi) Run Dale Com... WLEG, 9,895 -- 1 4,450.0 CAMCO KBG2 1 GAS LIFT DMY BK 0.000 0.0 7!19/2010 2 7,343.9 CAMCO KBG2 1 GAS LIFT GLV BK 0.188 1,722.0 7/21/2010 3 9,691.9 CAMCO KBG2 1 GAS LIFT OV BK 0.250 0.0 7/21/2010 I 1 PRODUCTION,_ _.. .... 35-19,n1 OPEN HOLE, �, 10,771 - 13,706 TD, 13,706 . r John Tonello Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 0o~~ Anchorage, AK 99510 .~ Q t7~ ~~~ Re: Colville River Field, Alpine Oil Pool, CD1-24 Sundry Number: 310-068 ~~~ NAB ~ :~. `~~~C. Dear Mr. Tonello: Enclosed is the approved Application for Sundry Approval relating to the above referenced v~ell. 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of March, 2010. Encl. • ~~(0, I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 MaR o 9 2010 ~-aska 0ii & G~ Cons. Commis~on ~ ~~~e 1. Type of Request: Abandon r Rug for Redrill ("" Perforate New Pool (~ Repair w ell ~'` Change Approved Program r Suspend ('" Rug F~rforations ~ Perforate r Pull Tubing r Time Extension Operational Shutdown [ Re-enter Susp. Well ~ Stimulate After casin g r Other.Tubing scale removal 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ . Expbratory r" 199-026 3. Address: Stratigraphic r Service (- 6. API Number. P. O. Box 100360, Anchora e, Alaska 99510 50-103-20295-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes 1- No ~ CD1-24 9. Property Designation: 10. Field/Pool(s): ADL 25559 Colville River Field 1 Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): effective Depth MD (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13706 6951 ~ 13706' 6951' Casing Length Size MD ND Burst Collapse CONDUCTOR 114 16 114' 114' SURFACE 2820 9.625 2820' ~ 2390' PRODUCTION 10771 ~ 7 10771' 6948' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole 10771'-13706' 6948'-6951' 4.5 L-80 9896 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER -BAKER S-3 PACKER MD= 9807 ND= 6773 WRDP - CAMCO WRDP (HRS-72) MD= 1790 ND= 1704 12. Attachments: Description Surrrt~ry of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ("" BOP Sketch r' Exploratory r" Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/19/2010 Oil r Gas r WDSPL I- Plugged r 16. Verbal Approval: Date: WINJ r GINJ r WAG [- Abandoned (" Commission Representative: GSTOR (~ SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Tonello ~ 670-4934 Printed Name J hn Tonello Title: Production Engineer Signature G~~~~ Phone: 670-4934 Date ~ r ~ - ,2 O t d Commis ion Use Onl Sundry Number: ~' O ~ O KJg Conditions of approval: Notify Commission so that a representative may witness Plug Integrity (- BOP Test ~" Mechanical Integrity Test (- Location Clearance ~'; Other: Subsequent Form Required: ~~' I ~~ APPROVED BY Approved by: ~ COMMISSIONER _ THE COMMISSION Date: ~ ~/ /~ w y ,r Form 10-403 Revised 12/2009 RBQ~yfS MAR 11 ~ 3' 9' ~~ Submit in Duplicate o ~ ~.~.~a t ~' ;::; ;,~ ~ a~~~~~L • CD1-24 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. Cowille River Field Well CD1-24 Sundry. Notice 10-403.Request Tubular Scale Removal via Acid March 5, 201.0 Purpose This sundry notice is to notify the AOGCC of ConocoPhillips Alaska Inc, intent to pump acid into weH CD1-24 to remove scale located in the tubing above the subsurface safety valve. Additional Information Proposed Operations: 1. Pump 27 bbls 7% HCL in CD1-24 tubing {calcium carbonate scale). 2. Flowback acid to temporary tanks and neutralize with Soda Ash. 3. .Dispose of neutralized effluent. ~ ~~ WNS ! ~(JI'tO~O~lt~~1~5 A:41SK~! !IS- ~ ~ `'y Well Attributes j 'vvelltwre APVU WI Fiald Name 7. 501032029500 ALPINE .. .. ~c ant H2S{ppm) 'Date _ wencon co7?a rutsi< - - --SSSV: WRDP j ::r: . ~ ___ Schema[ Act I A ttion IDep[h (ftK6) End Daie Annotation Last Tag: - Rev Reasol .Easing Strings ' i string oo =ia+h9lo Casing Description ~' (in1 ling Top (fiK8) coNDUc NIPPLE, SAFETY SURF GAS GAS GAS NIPPLE, NIPPLE, CONDUCTOR 16 15062 0.0 114.0 114.0 62.57 SURFACE 9 S/8 8fi97 0.0 2 820.0 2,389.8 36.01 PRODUCTION 7 fi 151 0.0 10,771.0 6,9482 26.01 OPEN HOLE i 6 1B f'~ 125 10,771.0 13,706.0 6,951.2 .Tubing Strings _ Sling OD String ID Set Depth Sat Deplh (ND) I String Wt Tubing Description (in) lint Top (ftK6) (ftKe) (ftK6) (Ibs/k) IUBING 4 V2 i'3 S8 0.0 9,896.0 fi,813J 12.61 Other In Hole (All Jewelry: Tubin Retrievable, Fish, etc.) Run & Top Depth _- (TVD) Top Inc! Top (ftK6) (ftK6) (°) Description Comment 1,790 1,704.5 33.571 NIPPLE CAMCO BAL-O SSSV NIPPLE 1,790 1,704.5 33.57 SAFE I Y VLV CAMCO WRDP (HSS-243) 4 450 3,399.3 51.43 GAS LIFT CAMCO/KBG2/1/DMY/6 W// Comment: STA 1 7,343 5,210.9 50 48 GAS LIF I CAMCO/KBG2/1/GLV/B W.188/1757/ Comment: STA 9,691 6,709.2 53.19 GAS LIFT CAMCO/KBG2/1/OV/BK/.313/1 Comment STA 3 9 752 6,743.4 56.33 NIPPLE HES X NIPPLE 9,SOJ 6,772.6 60.81 PACM:ER BAKER S-3 PACKER 9,883 6,807 9 6388 NIPPLE HES XN NIPPLE PRODUC 10,771 ~ OPEN HOLE, m ~ 13,]06 \ ~ TD, 13,]06 CD1-24 ~ TD ACt Btm (ftK6) 13.106.0 ' Rig Release Dat 8/5/2000 Entl Date 6!1312009 • • Page 1 of 1 ~~ r~~-vim Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] ~ ~~ir/`~ Sent: Wednesday, February 10, 2010 8:09 AM ~ ~~' 1 1, To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: CD1-24 (PTD 199-026) TxIA Attachments: CD1-24.pdf Guy, Tom, Jim, ~ '~ ~~P~~ Shut in Alpine Producer CD1-24 (PTD 199-026) has been reported to have hi h lA ressure which is indicative of TxIA communication. Tubing scale has prevented SL from changing out the OV which is t e suspected leak point. The well will remain SI until Coiled tubing can remove the scale and slickline changes the OV. ,~ The well has been added to our weekly SCP report. The schematic and 3 month TIO are attached. Regards MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 a~~~ ~~~ ~ ~' ~~ 2/11/2010 CRU CD1-24 PTD 199-026 2/10/2010 TIO Pressures 1~ sc 3000 II !II zzoo III Isl 2400 2100 1000 1500 1200 00 I 9 600 300 WELL NAME 0 r--------'---------------- ----- -- - PLOT START TIME MINOR TIME PLOT DUI?ATi~)N PL[)"C END TIME 16-DEC-09 02:14 MAJOR TIME WEER ®~~~~~ « c~~ » RT PICK TIME: ~ TAG NAME DESCRIPTION P-YALOE LATEST ::r1 CD1A-MOV-19-P05 FLOW TUBING CHORE 10• _~PREV WELL - - ~ ^,?A"' 'P ~_, s' 1 '+a ' -.. "CEM£ ~' NEXT WELL i~ `DE ~i t; -, ,iY ~`,.;t ~~ s'(,'.F _ ~5 pr 16.4>. Aim "77~~' ENTRY TYPE I OPERATOR VERIFIED ,_. A~ . ;will S('RATCH 43 INT3F.R ANNULUS PRES 1520. +rl '. ~,~ __ SCRATCH_43 OUTER ANNULUS PRES 500. .~ BOTH • • _ ~~~ ~ WNS ~ CD1-24 C~r}C~C~1r"111111~~ ~ I ~ Well Attributes max Angle ~ MD TD ~ ~ ~iibcr~ :I6U.YI Field Name _ _ Well Status Incl (I IdD (Itk6j Act etm (t[KB) ?.!029500 ALPINE PROD 93.94 10,696.98 13,706.0 .,,,,meM H25 (ppm) Data AnnotMion Entl Data KB-0rtl (R) Rig Releue Date ° weu co,e t ,: - - >'-tV: WRDP Last WO: 8/5/2000 . . Scnematw- nccuai- ~ - - ~~:rtau~,~ Depth (RKB) End Date Annotation Laat Mod By End Date _______ _ _ L ,.~. i ,~, Rev Reason: RESET WRDP Imosbor 6/1312009 Casin Strin s string oo strmg lu ---" see Depth set Depth Irvo) string we strin g Casing Description (in) (In) Top (RKB) (RKB) (RKB) (Iba/ft) Grade String Top Thrd -- - --~~ -- ---- CONDUCTOR 16 15.062 0.0 114.0 114.0 62.58 H-40 WELDED SURFACE 95/8 8.697 0.0 2,820.0 2,389.8 36.00 J-55 BTC-MOD €- 1 PRODUCTION 7 6.151 0.0 10,771.0 6,948.2 26.00 L-80 BTCM CONDUCTOR, q5 ~ OPEN HOLE 6 1/8 6.125 10,771.0 13,706.0 6,951.2 114 Tubin Strin s T_ ~, ', St 1 g OD ~ St ' g ID ___ Set D pth Set Depth (ND) String WI Strin g 7 Tubing Detonptlon (i I (I ) Top lkKe) (hKe) ~ (f[KB) (IbsHt) Grad e Strang TOp Thrd f TUBING . 4 1/21 3.95° "'6.0 "_ ° 6.813.7 12.60 L-80 MOD-BTC _ _,__ NIPPLE 1 790 Other I n Hole~A ll Jew, elry: Tubin g Run & Retrievable1 Fish, etc.) - --~ - ~-- ~~-- ~ - , , SAFENVLV. ToP Depth (ND) Top Incl 1'790 Top (RKB) (RKB) (°) Description Comment Run Date ID Qn) 1,790 1,704.5 33.57 NIPPLE CAMCO BAL-O SSSV NIPPLE 8/5/2000 3.812 1,790 1,704.5 33.57 SAFETY VLV CAMCO WRDP (HSS-243) 6/12/2009 2.125 4,450 3,399.3 51.43 GAS LIFT CAMCO/KBG2/1/DMYBK/// Commeni: STA 1 8/21/2007 3.938 ~',. ~ 7,343 5,210.9 50.48 GAS LIFT CAMCO/KBG2/1/GLV/BK/.188/1757/Comment: STA2 8/21/2007 3.938 suRFACE, ~ i 9 691 709.2 6 53.19 GAS LIFT CAMCO/KBG2/1/OVBK/.313//Comment: STA 3 8/24/2007 3.938 z,ezo , , , 9,752 6,743.4 56.33 NIPPLE HES X NIPPLE 8/5/2000 3.813 ' .~ 9,807 6,T/2.6 60.81 PACKER BAKER S-3 PACKER 8/5/2000 3.875 _ . 9,883 6,807.9 63.68 NIPPLE HES XN NIPPLE 8/5/2000 3.725 GAS LIFT, ! " 4,450 -~' GAS LIFT, r. 7,343 "",~ F OAS LIFT, --~* r~ 9,691 -~ ', j i J NIPPLE, 9,752 1 ~! ~ ~' .~ ~ PACKER, 9,807 ~ . jj j u I I NIPPLE, 9.893 ~ 3 I - L ~': ~' PRODUCTION. , ~~ 10.771 ,-~ OPEN HOLE, • 13,706 G TD, 13,706 STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS t Operations Performed: Abandon ~ Repair w ell Plug Perforations ~` Stimulate r Other j"` ~ "` ~ '' After Casing ~°`° Pull Tubing ("` Perforate New Pbol Waiver ~ Tr~~s~~re: ~ ,., ~,tltCki~7ifi~ ~, Change Approved Program Operat. Shutdow n Perforate Re-enter Suspended Wel{ ~'-'" 2. Operator Name: 4. Current Well Status: 5. ermit to Drill Number: Inc. ConocoPhillips Alaska Development Exploratory ~ 199-026 , 3. Address: Stratigraphic ~` Service 6~API Number: ~ P. O. Box 100360, Anchora e, Alaska 99510 50-103-20295-00 7. Pro~rty Designation: 8. Well Name and N tuber: ~ '\ ADL 25559 CD1-24 9. Field/Pool(s): Colville River Field /Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured ~ 13706 feet Plugs (measured) None true vertical ~ 6951 feet Junk (measured) None Effective Depth measured 13706' feet Packer (measured) 9807' true vertical 6951' feet (true vertucal) 6773' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114 16 114 114' SURFACE 2820 9.625 2820 2390' PRODUCTION 10771 7 10771 6948' ' ' q~'}!~ i ~ 6Z A Mtio' aJ ~ ("~ {I v e t Y ~ 1~~ ~'~~ ~ ~ ~ Perforation depth: Measured depth: -13706 open hole completion 10771 ~ ti ~ >~~ True Vertical Depth: 6948'-6951' Tubing (size, grade, MD, and TVD) 4.5, L-80, 9896 MD, 6814 TVD Packers & SSSV (type, MD, and TVD) PACKER -BAKER S-3 PACKER @ 9807 MD and 6773 TVD WRDP - CAMCO WRDP (HRS-72) 8/24/2007 @ 1790 MD and 1704 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 10771'-13706' Treatment descriptions including volumes used and final pressure: 67 bblS SC81e SgUeeZe treatment 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 412 916 647 -- 189 Subsequent to operation 212 1430 1146 -- 193 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory "" Development ~" Service . Well Status after work: Oil ', Gas WDSPL Daily Report of Well Operations XX GSTOR ~ WAG GASINJ WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Tim Schneider Cad 265-6859 Printed Name Tim Schneider Title Alpine Production Engineer Signature Phone: 265-6859 Date % _ ~ o ~~ Form 10-404 Revised 7/2009 RBDMS JAN 1120 ~~ ~/•//lo ~,~~ ~~~~ Submit Original Only '` t ~' i3~I ~ Well Attributes Max Angle 8 MD TD C/l b~~? 1 pS ~ "H ~ ~ ~ Wellbore API/UWI Fieltl Name __ Well Status Intl (°) MD (ftKB) Act Btm (ftKB) "- _ 9500 ALPINE (PROD 93.94 10.696.98 13 706 0 _, , , C rat I H25 (ppmj End Date KB-Grd (H) RigR I ase Date Data An t ton 6/tarzo w I LC fi CD ? 2g WRDp SSSV I ( ! Last WO: 8/5/2000 _x , g- , ; , Schematic Ac[ua ~ j ~ " An rotation De i p ( ) h ftKB End Date Annotation Last Mod By End Date _ _ _.. Last lag: Rev Reason: RESET WRDP Imosbor 'i 6/13/2009 - I I Casin Strin s ': String OD String ID Set Depth Set Depth (ND) String Wt String Casing Description (inl (in) Top (ftKB) (ftKB) (ftKB) (Ibs/ft) Grade String Top Thrd -- - - - - ~ CONDUCTOR i6 15.062 0.0 114.0 114.0 62.58 H-00 WELDED ~ SURFACE 95/8 8.697 0.0 2,520.0 2,389.8 36.00 J-55 BTC-MOD '' PRODUCTION 7~ 6.151 0.0 10,771.0 6,948.21 26.00 L-80 BTCM I ', OPEN HOLE 6 1/8 fi 125 10,771 0 13J06 0 6,951 2'. coNDUCroR, it4 I ~.-. - -_ Tubing Strings ~„ ' String OD Sf ray ID Set Depth Set Depth (ND) Strmg Wt Strang TubingD iption '. (inl (in) Top (ftKB) (ftKB) (kK6) (Ibs/ft) i Gade String Top Thrd TUBING I 4 V2~ 3 958 QO 9,896.0 6 813.7 12 60~L 80 }MOD BTC Other In Holee~A ll Jewelry: Tubin Run 8 Retrievable, Fish, etc. g NIPPLE, 1,790 Top Depih - ~- _ SAFEN ULV, (TVD) Top Intl t'190 Top (ftKB) (fiK81 (°) Desc 'ption ' Comment Run Date_ _ ID (in) 1,790 1,104.5 33.57 NIPPLE CAMCO BAL-O SSSV NIPPLE SIS/2000 3.812 ;. z 1,790 1,704.5 33.57 SAFE I Y VLV _ __ CAMCO WRDP (HSS-243) 6!12/2009 2.125 s ~ ' 4 450 3,399.3 51.43 GAS LIFT CAMCO/KBG2/1/DMY/BK!// Comment: STA 1 8!21/2007 3.938 ~ 7,343 5,210.9 50-48GAS LI FI" CAMCO/KBG2/1/GLV/BW.1 8 811 7 571 Comment: STA2 8/21/2007 3.938 suRFACE. ____ _ 2 826 9,691 6,709.2 53.19~GAS LIFT CAMCO/KBG2/1/OV/BK/.313//Comment: STA3 8/24/2007 ~ 3.938 4 ,, 9,752 6,743.4 56.33~NIPPLE HESXNIPPLE 8/5/2000 3.813 " 9 807 6,772.6 60.81 PACKER BAKER S-3 PACKER 8/5/2000 3.875 : 9.883 6,8029_ - 63.88 NIPPLE HES XN NIPPLE 8/5/2000 3.725~i GAS LIFT. 4,450 j I GAS LIFT, j ].343 GAS LIFT, 9,691 a j NIPPLE, 5.]52 1 w~ ~ F~, 3 PACKER. 9,607 I NIPPLE, 9,863 I ± { I i, 'a f ~, PRODUCTION, 10.]]'. OPEN HOLE, ~ « 13.]06 .~ TU, 13,]Ofi -• CJ CD1-24: 12/29109: Pumped a 67 bbl aqueous scale squeeze treatment containing 325 gallons SCW-4004 SI. Over flushed with 420 bbls Produced water (47% of planned volume). Initial treating pressure: 362 psi. SITP = 1744 psi. Shut down due to high treating pressure. , . . ~ ConocoPhillips Alaska ,¿.Jp 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 SCANNB> A?R 1 () 2007 (p \qq,Od- Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ftom the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water ftom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~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 16.9 2/16/2007 Alpine Field March 31,2007 lr¡< '- Odh Casing Detail 9.625" Surface Casing ~ '( C V { - ~Lf WELL: DATE: 1 OF 1 CD 1-24 4/23/99 PAGES ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Landing jt. 46.50 TOPS Doyon 19 RKB to landing ring = 36.581 36.58 FMC Gen V mandrel Hgr 2.43 36.58 27 Jts 9 5/8111 36#1 J-55 BTC Jt#47 - Jt #73 1009.34 39.01 9 5/811 TAM port collar 2.93 1048.35 44 Jts 9 5/811 36# J-55 BTC csg Jt #3 & Jt #46 1680.16 1051.28 95/811 Davis Lynch Float Collar 1.55 2731.44 2 Jts 9 5/811 36# J-55 STC CSQ Jt # 1 & Jt #2 85.72 2732.99 95/811 Davis Lynch Float Shoe 1.76 2818.71 2820.47 TD»> 2831 .00 Rathole»> 10.53 43 Gemeco Bow Sprina CENTRALIZERS Run centralizers in center of Jts. 1 ,2, over stop collars and over casing collars on Jts. 3- 12 and over collars of every 2nd jt to surface. 1 straight blade centralizer on Jt#46 and Jt#47 Remarks: MADE CSG UP WITH 9000 FT /LB TORQUE AND USE API MOD THREAD COMPOUND.. Doyon 19 Drilling Supervisor: Donald Lutrick {.;' r {\ t" N C\\b E. . ti'ì iì'" C rrJ! ß) n 20 0 j ~)\1,Jlr~~'\~W~ t1..!; If' (J) {f.¡¡ x.VJ . r.¡¡. ( ( , ,( ~1It. .,." ARCO Alaska, Inc. Cementing Details Well Name: CD1-24 Report Date: 04126/99 Report Number: 6 RIQ Name: Doyon 19 AFC No.: 998805 Field: Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 9 5/8" 121/4" 51 deg at shoe 2821 2731 Centralizers State type used. inteNals covered and spacing Comments: 1 bowsprlng per jt 1st 13 jts. Every other jt to surface. Total- 43. 1 straight blade centralzer on each side of the port collar. ...~d Weight: PV(prlor cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.6 24 26 36 34 Gels before: Gels after: Total Volume Circulated: 36/72 10/18 1200 Wash 0 Type: Volume: Weight: Comments: FW 100 8.3 $þåcer 0 Type: Volume: Weighl: Cpmments: ARCO Spacer 50 10.5 ,. ~~d:Cëment 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Cornriiørits: AS III LW 70 500 10.7 4.44 Additives: G+30%D053+O.6%D046+1.5%D079+ 1.5%S001 +50%D124+9%D044 TalrCe:röèrit 0 Type: Mix wtr temp: No. of Sacks: Weigh I: Yield: Comi'hetits: G 70 230 15.8 1.17 I Additives: G+0.2%D046+0.3%D065+1 %5001 :p1$p,i~ç~m~nt 0 Rate(before tail at shoe): Rate(lall around shoe): Str. WI. Up: CömiTiants: 10 10 155 I":. Reciprocation length: Reciprocation speed: Str. WI. Down: I;> 20 10fpm 120 I" , .: Theoretical Displacement: Actual Displacement: Sir. WI. In mud: "" ' 211 214 :,¡,', .", , Calculated top of cement: CP: Bumped plug: Floats held: Dale:4I25/99 yes yes Time:03:30 Remarks:Had full returns throughout entire job. Small amount of thin mud at surface when bump plug. RIH and open port collar. Pump 5 bbls mud wI no circulation. POH. RIH w/11O to TOe at 443'. Circ out cement. Pump 133 bbls AS III LW (10.7) cement to fill annulus. Cement Company: DS Rig Contractor: DOYON Approved By: Donald Lutrick - ( - ,( C. ARCO Alaska, Inc. Daily Drilling Report AFC No. I~ate RptNo Rig Accept - hrs Days Since AccepVEst: 3.6/3.6 Rig Relase - hrs: 998B05 04124199 4 04121/99 09:30:00 AM Well: CD1-24 Depth (MDrrvD) 2831/2396 Prev Depth MD: 2831 Progress: 0 Contractor: DOYON Daily Cost $ 235467 Cum Cost $ 583256 Est Cost To Date $ 575000 Rio Name: Doyon 19 Last Cso: 16" @121' Next Cso: 9 5/8" 0 2870' Shoe Test: Operation At 0600: RIH wI port collar tool. Upcoming Operations: MUD' DATA DRILLING DATA BIT DATA EH&S DRILLSlBOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOPIDIVERT LAST BOP/DRILL SPUD 2831 1 2 N TST 04122/99 04121/99 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 1 Oppg 140k 12.25 12.25 04110/99 04123/99 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 168sqc 145k HTC STC N SPACE 04111/99 04107/99 PVNP SOWT TYPE TYPE TYPE FUÈL&WATER 25/40 135k MX1 HO GELS A VG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 4172 36/70/70 Y40YX 750017 APIWl MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 400 2831 2831 04120/97 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN ., POTABLE WATER 130 6.8mV30 mln 121 2831 INJEÇ:riQN USED - BBlS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL I,'" " WEATHER& ',' ",,".,' 10% 2710 0 CD1-19 I': " PERS()NNELDATA ' "",'.' HOLE VOLUME PUMP PRES ADTIAST ADT/AST SOURCE WELL TEMP of 0 386bbl 1850 I I I 23/10 1 CD1-24 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 0 30 1 121 I 10 - 25 3.92 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 8.5 6161 I 60 - mm 1100 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 0.00 3% III .595 Water Base Muds 615 PIT VOL GPM2 JETS JETS Diesel ARCO PERSONNEL 1 425 I II 101151151151 I III II 33 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 27 $1854 I II 11910 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $20048 III 2121nola III 648 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 17 MI III e 11 I no I td III 855 PERSONNEL TOTAL 51 BHA DESCRIPTION I HO, BS. NMDC, NMS, 2 - NMDC, 3 - DC, XO, 4 HWDP, Jars, 25 HWDP DRILLPIPE DATA BHA NO 2 OD 10 WEIGHT GRADE CONNECTION CLASS 2 LENGTH BHA LENGTH 1102.26 DATE LAST INSPECTED: HOURS ON JARS: 116 "TIME ,I END HOURS OPS CODE I HOLE SECT I PHASE OPS I OPERATIONS F_ROM 0000 - 0000 12:00 AM 01 :00 AM 1.00 TRIP_OUT SURF Making Hole POH. 01 :00 AM 02:30 AM 1.50 BHA SURF Making Hole LD BHA 02:30 AM 03:00 AM 0.50 RIGS SURF Casing and Service rig Cementing 03:00 AM 03:30 AM 0.50 WIPERTRP SURF Casing and MU HO BHA. Cementing 03:30 AM 06:00 AM 2.50 WIPERTRP SURF Casing and RIH to 2756'. Reamed 1/1250' to 1474'. Cementing 06:00 AM 06:30 AM 0.50 WIPERTRP SURF Casing and Wash and ream 1/2756' to 2831'. Cementing 06:30 AM 07:30 AM 1.00 WIPERTRP SURF Casing and Circ lo/hi vis sweep Cementing Daily Drilling Report: CD 1-24 04/24/99 Page 1 , - ( 7:30 AM 12:00 PM 4.50 PRB_TH SURF Casing and POH. Tight and packing off at 1865'. Back ream to 1104'. Cementing 2:00 PM 01 :00 PM 1.00 WlPERTRP SURF Casing and POH. Cementing 1 :00 PM 02:30 PM 1.50 WIPERTRP SURF Casing and LD BHA. Cementing 2:30 PM 04:30 PM 2.00 CASG SURF Casing and Clear floor. RU to run csg. Cementing 4:30 PM 05:00 PM 0.50 CASG SURF Casing and Held pre)ob safety meeting, Cementing 5:00 PM 10:30 PM 5.50 CASG SURF Casing and RIH w/9 5/8" csg to 2821'. Push csg f/1600' to 2100', No Cementing problems. LD fill up tool. MU hanger and land csg. 1):30PM 12:00 AM 1.50 CASG SURF Casing and Clrc and condition mud. Cementing 24.00 Supervisor: DONALD LUTRICK Iy Drilling Report: CD1-24 04/24/99 Page 2 ...~ .,.'" ARCO Alaska, Inc. AFC No. 998B05 I?ate 104125/99 Well: CD1.24 Contractor: DOYON Ria Name: Doyon 19 Operation At 0600: MU BHA Upcoming Operations: CSG test and LOT MUÞDATA MUD TYPE LSND ÞfULLlNG DATA DEPTH WEIGHT 9.6PPQ VISCOSITY 40sqc ROTWT PUWT PVfYP 12/18 GELS 4112/19 APIWL 10 HTHP Wl mV30 mln SOLIDS 5% HOLE VOLUME 386bbl MBT 17.5 ph 9.0 lGS 3% SOWT AVG DRAG MAX DRAG TRO BTM TRO OFF PUMP PRES 1850 I I I PUMP NO 1 121 I LINER SZ 6161 I SPM 1 I II PIT VOL 425 GPM2 I II DAilY MUD $7817 SPS 1 III TOTAL MUD $27865 COMPANY MI SPP 1 III MUD WT 1 II RptNo 5 Depth (MDnvD) Dally Cost $ 110156 Last CSg: 16" 0121' BIT NO. 2 SIZE 12.25 MAKE STC TYPE HO SERIAL NO 750017 DEPTH OUT 2831 DEPTH IN 2831 FOOTAGE 0 ADT/AST 1 WOB2 RPM 1 TFA JETS 1111 I BIT COST DULL 1 11 I no I a GRADE e I 0 I no 1 td ( I:Ri9 Accept - hrs 04121/99 09:30:00 AM 2831/2396 Prey Depth MD: 2831 Cum Cost $ 693412 Next Csg: 9 5/8" @ 2870' Days Since AcceptlEst: 4.6/3.6 BIT ,DATA BIT NO. EH&S INCIDENT N SIZE EMPLOYER MAKE SPILL N TYPE TYPE SERIAL NO VOLUME DEPTH OUT LAST SAFETY MTG 04120/97 DEPTH IN FOOTAGE INJecTiON INJECTION WELL CD1-19 SOURCE WELL CD1-24 RATE (bpm) 3.9 PRESSURE (psi) 1120 INJECTION FLUIDS ADT/AST 1 WOB2 RPM 1 TFA JETS III II Water Base Muds 760 Diesel 30 0 BIT COST 0 DULL III GRADE III 0 TOTAL VOL (bbl) 790 TOT FOR WELL (bbl) 1538 ( Daily Drilling Report Rig Relase - hrs: Progress: 0 Est Cost To Date $ 575000 Shoe Test: ÞFìlLLSlBOP,'OATA. LAST BOPIDIVERT LAST BOPIDRILL TST 0412~9 04121/99 LAST H2S DRILL 04110/99 LAST CONFINED SPACE 04107/99 ,', LAST FIRE DRILL 04123199 LAST SPILL DRILL 04111/99 FOSL&WAtt:R , FUEL USED '" '... 5093 1005 200 ',", " ,',,','.' -17 12 90° -47.31 1 26 6 15 DRILL WATER USED- BBLS POTABLE WATER ,"" USED - BBlS ': WÊ.ATHERi'&' " ëEå$QNN~ÞP~TÁ . TEMP of WIND SPEED WIND DIRECTION CHILL FACTOR of ARCO PERSONNEL CONTRACTOR PERSONNEL MISC PERSONNEL SERVICE PERSONNEL TOTAL 48 , ,/1:1 ,'" . "''';'h:':;''.: F~1,[¡ø~~'Pt*mll!jfil$tj!ËÌ('!>:tVlnQÖÕÔ,i;löõôt\,:,i;:¡::><hji:';;1¡:;:¡'~::, Circ and condtlon mud. 10 bpm at 1050 psi. Pumped celloflake as fluid caliper, Celloflake to surface at 50 bbls over guage hole. Prejob safety meeting on cementing. Tested lines to 2500 psI. Pumped 100 bbls FW, 50 bbls 10.5 spacer, 395 bbls 10.5 lead (500 sX), 49 bbls 15.8 tail (230 sX), 20 bbls h20. Dispalèe with mud with rig pumps. Bumped plug. Full returns throughout job. No cement to surface. RD csg equipment. RU to run DP. [:::i;¡;:5tt;¡j1t¡1¡(:.:::,IYL!SatfiíJj\;,\)'k::;;;::iH~:ø,RSr :'';.\1 :;:tJö.'8$'::Õ(Q~a,' )iF:)' > HÖwêiSãÖï ' ,¡liêFl~$S¡'øêä .. 12:00 AM 01:00 AM 1.00 CIRC SURF Casing and Cementing 01 :00 AM 04:00 AM 3,00 CEMENT 04:00 AM 05:00 AM 1.00 OTHER 05:00 AM 06:00 AM 1.00 TRIP_IN 06:00 AM 07:30 AM 1.50 OTHER 07:30 AM 08:30 AM 1.00 TRIP ßUT 08:30 AM 12:00 PM 3.50 PRB_MISC Daily Drilling Report: CD1-24 04/25/99 SURF Casing and Cementing SURF Casing and Cementing SURF Casing and Cementing SURF Casing and Cementing SURF Casing and Cementing SURF Casing and Cementing RIH wI port collar tool. Latch and open tool. Pump 5 bbls at 2 bpm at 500 psi. No returns. Close port collar. Drop and shear ball. RD. POH and LD tool. Prep to run 1" CS Hydrlll pipe. Unable to work mule into conductor pipe. Modify mule shoe. No success. Cut of 3" nipple on conductor. Page 1 - - It' 12:00 PM 02:30 PM 2.50 OTHER SURF Casing and RIH w/1" pipe to TOC at 443'. Cementing 02:30 PM 04:00 PM 1.50 CIRC SURF Casing and Clrc out 20 bbls cement. Pump 93 bbls FW. Cementing 04:00 PM 07:00 PM 3.00 CEMENT SURF Casing and . Pumped 133 bbls 10.5 cement (168 sx) to fill annulus. Cementing 07:00 PM 09:30 PM 2.50 NU_ND SURF Casing and ND dlverter. NU well head. Cementing 09:30 PM 11:00 PM 1.50 NU_ND P1 Making Hole NU BOPE. 11:00 PM 12:00 AM 1.00 BOPE P1 Making Hole Install test plug. Test BOP to 300-4000 psi. 24.00 Supervisor. DONALD LUTRICK Daily Drilling Report: CD 1-24 04/25/99 Page 2 Wen Name: Date: 4/26/99 Supervisor: Donald Lutrick CD1-24 [2] Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequancy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Casing Setting Depth: 2,8211 TMD Hole Depth: 2,8511 TMD 2,3891 TVD 2,407' TVD Mud Weight: 9.6 PPG Length of Open Hole: 30' EMW= 475 + Mud Weight 475 psi 9.6 PPG 0.052 x 2389 - 0.052 x 2,407' Pump output = .101 BPS ....._.:..~ 'ì J w = 13.4 ppg U I- L- LJ..;'LJ I\. '-' I " .v """'L..I'a.."" . - I Jml¡~¡: : I\J~ i 2.800 psi I I I! i I /'! I():--J~: MINUTF. ~:Cj{~ 2.700 psi I I I V I! . /.. ' 2.600 psi I i'! 7 ..I" I . . . ... . I I I I 2,500 psi i : 2.400 psi I I I i/ Iii' -'n_- w - " I i J I . ~m - .~- ; i i 2,300 psi I 71 I 2,200 psi / ! : 2,100 psi 7 I i .. 2,000 psi I : : i' i ; 1.900 psi / I ~ I 1,800 psi I , . .. 1.700 psi ! ~ 1.600psi II i ... I 'II I ::::I 1.500psi ! I J I ! I ~ 1.400 psi ~ I I f' I I ~ 1.300 psi 1.1 I I : i. c.. 1.200 psi II ít 4.[. ....~- I 1.1 00 psi II " Itl\r I ! i ...- 1,000 psi I 900 psi II ' all" I I : .. I ~ .. I ..I~ : 800 psi I -e- LEAK-OFF TESï , l/!k, I - t'-1 If I 700 psi ,j j 7' l')é~ 600 psi 'II IJ I ~CASING TEST 500 psi I -~*,._.. LOT SHUT IN ïlME 400 psi ~ i 300 psi ~ CASING TEST ~3HIJ" N i IME i 200 psi i 100 psi -f- TIME LINE 0 psi , ! : i 0 2 4 6 8 10 12 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 70 72 74 76 78 BO 82 Bd B6 B8 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE --------- --- i i 0 stks i 100 psi i I-------------t I f I : 2 stks I 280 psi: 1-----------1 I . 1 1 4 stks 1 450 Psi i I I I I r-------l- 6 stks -r-ššoPši! ¡----------T 8 stliST64Õ psi --¡ '-------;----1------t ! I 10 stks 1 700 psi I I--------------.{ . I ! ! 12 stks ! 800 psi! ,---------,-----------.,-------------1' I I , I !-----------J--------------Î--------------J I I I I I f I I I I I I I-----------_---I-----~---------"'¡ : I : : I I I I 1-------- I ------i----------f I I . I !-----i------i---------i I I . I : I : I ,-----------,------------.,-----------------, I I I I I---------J----------..I----------------l I I I , I , , I I__________l___---------L...-------______I I I I I . I I . !--------------1-----------i--------------i !---------------i-----------i-------------! I I I . I I I I I---------------"-----------~-----------' I I I I !--------------J-----------L------------: : I : : , I I I :-------------1------------i-------------f I . I I !------------i-------------i------------f I I I , !-----------~----------+------i : : : I I I I I I------------¡------i----------~ I I . I I I I I :-----------1-------1-------------: 1 I I 1 I I I I CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE r-- i 0 stks ¡ 100 psi 1 ~--~----~-----f i-------i-..?- stks D30 ~si -~ i i 4 stks i 460 psi i 1-------' 6 stks ! 720 psi 1 r---- ! 8 stks -1 890pŠi1 :-----------t--~ ~-------- i 10 stks i - 1,030 pSI i ~----- I 12 stks I 1,190 ps! !4!' ! i 14 stks ¡ 1,340 psi ~, [=___1_16_~~s ï 1,500 pSi-¡ i I 18 stks ! 1,710 ps;.Ao.., I---------------- 1-- ~----------- I 20 stks ~~1 0 PS~-i I I 22 stks i 2,120 psi I r---------124- stks ¡ 2,340 psTl o------------+-----------J L_________l_..26_~~~_1_~,500J~~U I I I I 1 I . . ~-------------t----------+-------------1 ~-------------+-------+----------------i ~---------+--------------+------------i L---------l..------------l-----------J : I I I I I I I t-----------t--------------+------------1 t I I , . ! J - I I i SHUT IN TIME i SHUT IN PRESSURE I----~----------r-------' ! 0.0 min i ! 2,500 psi! ¡-1 .0 -mïñ!-----------T 2,480-psil !2-:ürñ-rnr--------¡2,480 psr"'I "_----_..0._----------+-::--::------- ¡ SHUTlN TIME ¡ SHUT IN PRESSURE i 3.0 min ! I 2,470 psi (' I----------"-----------~----' ~----------+-----------+-------i i 0.0 min ! i 750 psi 1 ! 4.0 min i ! 2,450 psi~ .-------....------------..--------1 ...------------.----------r--------- ~-, ! 1.0 min i i 730 psi i i 5.0 min i ! 2,445 ps r2~Õ min -r----------¡-S90 psil r-s'-Õ-miñT------ ! 2,430 psi I .-------.....-----------~---. ....---~--------.... ~ i 3.0 min i ! 670 psi! i 7.0 min ! ! 2,425 psi i I-----~-i-----------i---------~---t I------+-------- . i 1 4.0 mln 1 I 650 pSI 1 I 8.0 min I I 2,420 pSI 1 I-----------f---------'{-----------' 1-----+------+ --i i 5.0 min ! ! 640 psi! i 9.0 min ! ! 2,410 psi! r- 6.0 miñ--r--------!64õ pSi-¡ r-10.0 miñT---------!2:41opSiI r'7:õ-r¡:iinl---------T63õ psi f f15.0 min \--------- f 2,400 psi 1 ¡---ã~õ- miñ-r---------T-S30 psi! !2Õj) min-r--------T 2,400 psr! I-----:----I-----------+-----t :- -------------+----------'1 1 9.0 mln 1 1 630 psi I I 25.0 min I 1 2,390 psi: I-----i-------------+--------I I----------+--------------"------------i L_1Q.:Q_~if!J____--_-L_~~ps!j L 30 :.Q_!!!~_L_-_----______L 2,~~ ~~!J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY .99 10 : 31 From-ALPINE CO~J~~ MAN ( - . T-~ð~ P.03/05 F-157 Casing Detail 7" Intermediate Casing WELL: CD1..24 DATE: 513/99 1 OF 1 PAGES ~RCO Alaska, Inc. iubsldlary of Atlantic Richfield Company t# ITEMS COMPLETE DeSCRIPTION OF EQUIPMENT RUN LENGTH DePTH 7" DAVIS LYNCH FLOAT SHOE 1.18 10771.00 2jts 711 28# LSO BTM CSG 79.09 7" DAVIS LYNCH FLOAT COLLAR 1.40 10715.36 263JTS (JTS#3-#265) 7" 26# LBO BTM CSG 10628.41. 1 PIECE (JT# 266) 7" 26# Lao 8TM 25.92 (LANDED CSG WITH 140K ON SLIPS) RT TO CSG HEAD LDS 35.00 7" csg set AND CEMENTED (& 10771.00 RUN ONE STRAIGHT BLADE CENTRALIZER ON JTS" 429. AND JTS # 31,33.35 37.39.41.43.45 AND #47. TOTAL 38 STRAIGHT BLADES. RUN ONE BOW SPRING CENTRALIZER ON JTS # 196.197.AND 198. TOTAL 3 BOWSPRINGS. DRIFTED TO 6.151" USED BEST..O-LIFE 2000 DOPE MAKE EVERY JT UP TO BASE OF TRIANGLE RUN PIPE SLOW.. KEEP IT FULL - RECORD DISPLACEMENT WASH TO BTM WITH FILL UP TOOL AND CIRC BEFORE MU CMT HEAD WILL DISPLACE CMT WITH RIG PUMPS @ a BPM. ¡ ,4 11.o't (0 eoltitlJ, 7 ,/f5 10 í toCj,R ¡ -^..-r~ 1017/,,00 ''/''''t'-r::z::::J '7. I' 1 3 Z Remarks: RAN CSG AND LANDED ON LANDING RING - LOST 20 BBlS MUD RUNNING C$G. UNABl TO CIRC - PACKED OFF AND PUMPING IN. CSG STUCK WITH SHOE AT 10771. CEMENTED WITH PAR RETURNS. LANDED CSG WITH 140K ON SLIPS. Doyon 19 Drilling Supervisor: MIKE WHITELEY - ( f ~. ARCO AI k c f D t 1 as a, nc. emen Ing e al S Well Name: CD1-24 Report Date: 05/04199 Report Number: 14 Ria Name: Doyon 19 AFC No.: 99BB05 Field: Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 7 8.5 93.8 10771 10689 Cehtrallzers State type used, intervals covered and spacing Comments: RAN ONE 7" X 8.5"OD STRAIGHT BLADE CENT. ON J1S 11-129 AND ON JTSl31,33,35,37.39,41.43.45. AND 147. RAN 3 BOW SPRING ACROSS 9 5/8" SHOE ON JTS '196,197. AND 198. NlÏid Weight: PV(prlor cond): PV(after cond): YP(prior cond): YP(after cond): Cöniments: 10.3+ OUT RÄNCSGTOBTMS, HOLE Gels before: Gels after: Total Volume Circulated: TOÖK:20BBLSWHILE ~l,I~NING~G.UNAâLE TO PUMPED 475 BBS - 5% RETURNS. UNABLE TO CIRC piRC; plÌM'~EbAWAY +/- 400 AND COND MUD. ,~~~'MUD; Wä9h 0 Type: Volume: Weight: C<jrnmenls: ARCO 20 8.4 $~~'~ 0 Type: Volume: Weight: Comrriønts: ARCO Spacer 50 12.5 , . t.~d;'cÖmêrit 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: :b6rriments: Additives: ". :TØiljëÐm&nt 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: 'Comments: G 65 283 15.8 1.15 , Additives: , " "',' ." .". D46 0.2%, D065 0.25%, D800 0.25%, D167 0.180% Displacement 0 .".,.'.' Rate(before tall at shoe): Rate(tall around shoe): Str. WI. Up: Comments: '.".' 7 7 325 It ,. Reciprocation length: Reciprocation speed: Str. Wt. Down: ... ,. STUCK 0 150 I,:,;::,!:::":,, . .".".;><i' ,'..' ., "" Theoretical Displacement: Actual Displacement: Str. WI. in mUd: , 410 410 140 Calculated top of cement: CP: Bumped plug: Floats held: 8205 Date:5-4-99 YES YES Time:1900 Remarks: Cement Company: Rig Contractor: Approved By: - ( ( ...... .,." ARCO Alaska, Inc. Daily Drilling Report AFC No. I~ate RptNo I :RiQ Accept. hrs Days Since AccepVEst: 13.6/13.6 Rig Relase - hrs: 998B05 05104199 14 04121/99 09:30:00 AM Well: CD1-24 Depth (MDfTVD) 10796/6947 Prey Depth MD: 10796 Progress: 0 Contractor: Dally Cost $ 273415 Cum Cost $ 2088288 Est Cost To Date $ 2000000 Rig Name: Doyon 19 Last Cso: 7" @ 10,771' Next Cso: none Shoe Test: 13.4 Operalion At 0600: FREezE PROTECT 9 518" X 7" CSG I NU BOPS Upcoming Operations: RUN TBG AND FREezE PROTECT ND BOP'S, NU TREE . MUD DATA . J)RILLINGDATA BITDATÄ EH&S DRILLSIB.OPDATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOPIDIVERT LAST BOPIDRILL BRINE 10796 NIA NIA N TST 04128/99 04126199 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.2ppa 04128199 05102199 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 26sqc N SPACE 05102199 05103199 PVNP SOWT TYPE TYPE TYPE i ,.FUEL'!í:WAT.ËR . I I"",,' : : "'," " GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 4413 /I APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 600 05103199 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN " ."""" "..,' POTABLE WATER 97.6 mV30 mln INJg.C:nON. ,: ",,:, USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL I':, ,.',' "". ':,':: ,WEATHÊR& ' % CD1-19 .., ,~~F,Í$QNN~WjjÂ"~ . HOLE VOLUME PUMP PRES ADTIAST ADT/AST SOURCE WELL TEMP OF .2 Obbl III I I CD1-24 MBT PUMP NO WOB2 WOB2 RATE (bpm) WI NO SPEED 4 1121 I 2 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 45. ') 6161 I 650 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR.F -2.00 % III Water Base Muds 582 PIT VOL GPM2 JETS JETS Diesel ARCO PERSONNEL 2 0 I II I 1111 III II 32 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $12511 I II 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 1 $119123 III III III 614 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 11 MI 9.211 I III III 6342 PERSONNEL TOTAL 40 "TIME I END HOURS I OPS CODE I HOLE SECT I PHASE OPS I OPERATIONS FROM 0000 .'0000 ~2:00 AM 10:00 AM 10,00 CASG P1 Casing and RAN 7" 26# LBO BTM CSG TO 10787'. HOLE TOOK 20 BBLS I Cementing WHILE RUNNING PIPE. 10:00 AM 04:00 PM 6.00 PRB_CSG P1 Casing and WORK PIPE AND ATTEMPT TO BREAK CIRC.HOLE Cementing PACKED OFF- PUMPING INTO FORMATION AT 1.2 BPM 650 PSI. SWABBING BACK SOME RETURNS WHEN MOVING PIPE UP. LOST +1- 400 BBLS MUD. MUD WT OUT 10.3+. STUCK 7" CSG. SHOE AT 10,771'. 04:00 PM 04:30 PM 0.50 PRB_CSG P1 Casing and WORKED STUCK CSG PULLING 125K OVER UP WT. NO Cementing MOVEMENT. 04:30 PM 07:00 PM 2.50 CEMENT P1 Casing and PJSM. ESTABLISHED PUMP RATE WITH MUD - 8 BBPM @ - Cementing 1,140 PSI. PUMPED TOTAL 72 BBLS. DOWELL CEMENTED ~ ~ ~~ 7" WITH SHOE AT 10,771'. PUMPED 20 BBLS ARCO WASH, "-- ~ Lo~~ ~J1 'lSò 50 BBLS SPACER AT 12.5 PPG, AND 58 BBLS CEMENT AT ~ j~l~ ~~~: l~bIJ. 15.8 PPG. DISPLACED WITH 77 BBLS FW AND 333 BBLS 9.2 BRINE AT 7 BPM. HAD 30%-40% RETURNS WITH CEMENT OUT SHOE. CSG STUCK - DID NOT RECIPICATE. - - - - - - BUMPED PLUG AND PRESS UP TO 3,500 PSI. WELL FLOWING BACK - CLOSED HYDRIL ON 7" CSG.- 150 PSI SICP. CIP @ 1900 HRS. Daily Drilling Report: CD1-24 05/04/99 -- L-^,..J()~ - ~ 1'0 fi.:fi'O.J 7u MNV W1~ \::~ ::,.r:ç\~~:~ç ~ ~ f4~ (IA1\&pag~~ ~~"-~ ( 07:00 PM 07:30 PM 0.50 CMT_CSG 07:30 PM 12:00 AM 4.50 PRB_CMT 24.00 P1 Casing and Cementing Casing and Cementing ( HELD 3,500 PSI ON CSG FOR 5 MIN. HELD. FLOATS HELD. WOC . CLEAN PITS, CHANGED SHAKER SCREENS, LOAD TBG IN PIPE SHED, PREPARE TO PU BOP'S. Daily Drilling Report: CD 1-24 05/04/99 P1 Supervisor: MIKE WHITELEY Page 2 .... ~,.. ARCO Alaska, Inc. AFC No. 998805 Well: CD1-24 I~ate 105103199 RptNo 13 Depth (MDfTVD) { I :R19 Accept - hrs 04121/99 09:30:00 AM 10796/6947 Prey Depth MD: 10511 Days Since AccepVEst: 12.6/12 Contractor: Daily Cost $ 123962 Ria Name: Doyon 19 Last Csg: 9 518" @ 2,831' Operation At 0600: RUNNING 7" CSG . 170JTS IN HOLE Upcoming Operations: SET AND CEMENT 7" CSG 'MÜCDATA MUD lYPE LSND WEIGHT 8.8DDa VISCOSllY 48sqc PV/YP 12/30 GELS 14/22/35 APIWL 4.4 HTHP WL 12.6mV30 min SOLIDS 9.0% HOLE VOLUME 692bbl MBT 25 ph 9.0 LGS 3.1% PIT VOL 424 DAILY MUD $7991 TOTAL MUD $106611 COMPANY MI DRILLING DATA DEPTH 10796 ROTWT 195K PUWT 290K SOWT 160K A VG DRAG MAX DRAG TRO BTM 23K TRO OFF 23K PUMP PRES 2800 I I I PUMP NO 1121 I LINER SZ 6161 I SPM 1 631671 I GPM2 267 I 284 I I SPS 1 40130 I I SPP 1 725 I 600 I I MUD WT 9.811 I Water Base Muds 575 JETS JETS Diesel ARCO PERSONNEL 151151151 I I 11111. 30 Fresh Water 10 BIT COST BIT COST CONTRACTOR 10,940 0 PERSONNEL 0 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 2151BTIG II I 615 GRADE GRADE TOT FOR WELL (bbl) SERVICE X 11/8 I RG 1 TD III 5728 PERSONNEL BIT NO. 4 SIZE 8.5 MAKE HTC lYPE GTPS09 SERIAL NO B14YN DEPTH OUT 10796 DEPTH IN 9630 FOOTAGE 1166 ADTIAST 26.25/19.25 WOB2 10 - 20 RPM 1 0- 80 TFA .517 DRILL WATER USED- BBLS '" "',',' POTABLE WATER 'IN~EbrtPN ., USED - BBLS INJECTION WELL CD1-19 SOURCE WELL CD1.24 RATE (bpm) 4.0 PRESSURE (psi) 750 INJECTION FLUIDS Cum Cost $ 1814873 Next Csg: 7" 0 10,601' BIT DATA BIT NO. NIA EH&.S INCIDENT N SIZE EMPLOYER MAKE SPILL N TYPE TYPE SERIAL NO VOLUME DEPTH OUT LAST SAFETY MTG 05103199 DEPTH IN FOOTAGE ADT/AST 1 WOB2 RPM1 TFA tf:?,1:~rf11j¡¡'1:!>;iîlt<):::éßHifE :" " ':"'H~l¡¡Flá},n" '¡,!lj:¡:¡!:(jim$::¡~~l5å:i:~:!l.' ',;ìl1l~tU;¡;:SEQm;: ',,:::H!ÞJ\l~$Sil~I!I};W¡:':;:: '; 12:00 AM 06:30 AM 6.50 DRIL Pi Making Hole 06:30 AM 08:30 AM 2.00 CIRC P1 Making Hole 08:30 AM 10:30 AM 2.00 WIPERTRP Pi Making Hole 10:30 AM 01 :00 PM 2.50 CIRC Pi Making Hole 01 :00 PM 07:30 PM 6.50 TRIP _OUT P1 Making Hole 07:30 PM 08:00 PM 0.50 CASG Pi Casing and Cementing 08:00 PM 09:30 PM 1.50 CASG Pi Casing and Cementing 09:30 PM 12:00 AM 2.50 CASG P1 Casing and Cementing 24.00 Daily Drilling Report: CD 1-24 05/03/99 ( Daily Drilling Report Rig Relase - hrs: Progress: 285 Est Cost To Date $1600000 Shoe Test: 13.4 " ." øaILL.SI80PØATA LAST BOP/DIVERT LAST BOPIDRILL TST 04128/99 04126/99 LAST H2S DRILL 04128/99 LAST CONFINED SPACE 05103199 " I..." FUEL USED LAST FIRE DRILL 05/02199 LAST SPILL DRILL 05102199 FUËL8i''WÄfËR " .. '. . 3350 500 97.6 WEATHER & PERSONNEL DATA TEMP OF 0 WIND SPEED 3 WIND DIRECTION 45° CHILL FACTOR of 0.00 26 2 11 TOTAL '.;:¡,E';:., ... ,;}l!jlill¡:,:ø:~âmiÄ:mj~tìitS;1i1it#t(¡;¡M(óóf¡)ô'I~~ôØÔQ:i},.., .., ; ¡... . . DRILL FROM 10,511' - 10,796'. ART = 2.4 HRS, AST = 1.9 HRS. CIRC AND CONDITION MUD FOR SHORT TRIP - PUMP SWEEPS AROUND. SHORT TRIP FROM 10,796' - 9,176' - HOLE IN GOOD SHAPE. CIRC AND COND MUD AND HOLE TO RUN 7" CSG - PUMP SWEEPS. POOH TO RUN 7" CSG - NO PROBLEMS - LD BHA. PULL WEAR BUSHING - CLEAR RIG FLOOR. 40 RU CASERS - PJSM. RUN 7" 26# L80'CSG- Supervisor: MIKE WHITELEY Page 1 . .. ( { ..~ ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. I~ate RptNo I :Ig Accept. hrs Days Since Accept/Est: 14.6/14.6 Rig Relase - hrs: 05105199 03:30:00 PM 998B05 05105199 15 04121/99 09:30:00 AM Well: CD1-24 Depth (MDfTVD) 10796/6947 Pr8V Depth MD: 10796 Progress: 0 Contractor; Dailv Cost $ 28703 Cum Cost $ 2116991 Est Cost To Date $ 2075000 Rio Name: Dovon 19 Last Cso: 7" 010,771' Next Csg: none Shoe Test: 13.4 Operation At 0600: RIG RELEASED- BALL MILL RELEASED AT 14:45 HRS Upcoming Operations: MOVE RIG TO CD1-35 MUPPATA' ,PRILLlNGDATA . BIT DATA EH&S PRILLSII30PÞATA " MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOPIDIVERT LAST BOPIDRILL BRINE 10796 N/A N/A N TST 04128/99 04126199 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.2DOO 04128/99 05102199 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL sqc N SPACE 05102199 05103199 PV/yP SOWT TYPE TYPE TYPE FOEL.litWATER ' I > , '" , ' ,' GELS A VG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 2637 /I APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 100 05105/99 BBLS HTHP WL TRO BTM DEPTH IN DEPTH IN " .' .;,::i POTABLE WATER 92.8 mV30 mln I " INJECTiON USED - BBLS SOLIDS TRO OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & % CD1-19 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP OF 18 Obbl I I I / I CD1-24 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 6 1121 I 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 330° 6161 I 850 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 11.06 % I I I Water Base Muds 69 PIT VOL GPM2 JETS JETS Cement ARCO PERSONNEL 1 0 I I I I I I I I I I I I I 75 Fresh Water 10 DAILY MUD SPS 1 BIT COST BIT COST Diesel CONTRACTOR 28 $ I I I 35 PERSONNEL Other 418 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 1 $ I I I I I I I I I 607 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 9 MI 9.21 I I I I I I I I 6949 PERSONNEL TOTAL 39 ii<;;;$iMa!( .',:¡liiliMiiI!N15:i¡:jšHi i',': ::.':i:j!f;l'o\lil~$:i::;¡i(:TI:!il!iii,:¡,\:ØêiS::(j~~êl:i,:¡i:.lll:¡¡:::iiìBm~S,$Øømll:.:; '; !idiFiIH~S:g;:~I?,$; ,: ,.'!î¡lk\.: ,:,'" ',\ ~'::::,'iii:(;ìti\Šjj¡jli¡mj~N$!':FtRQNI::óØ'ØÔIMQõÔ:di!ii!". . .~,. " 12:00 AM 01 :00 AM 1.00 PRB_CMT P1 Casing and WOC. Cementing 01 :00 AM 01 :30 AM 0.50 PRB_CMT P1 Casing and NO PRESSURE ON ANNULUS. OPEN HYDRIL. OBSERVE Cementing WELL. PU STACK. 01 :30 AM 02:30 AM 1.00 PRB_~ ~í P1 Casing and SET SLIPS ON 7" CSG. LANDED 7" CSG WITH 140K ON Cementing SLIPS. CUT OFF 7". 02:30 AM 03:00 AM 0.50 PRB-:pm t.k r P1 Casing and LAY DOWN LANDING JT, HANGER, AND PIECE 7". Cementing 03:00 AM 03:30 AM 0.50 PRB_9ß'G CMT' P1 Casing and SET BOP'S BACK. Cementing 03:30 AM 05:30 AM 2.00 PRB_~G ell'("" P1 Casing and MAKE FINAL CUT AND DRESS STUB. Cementing 05:30 AM 06:00 AM 0.50 CASG P1 Casing and INSTALL 7" PACK OFF AND TEST TO 3,500 PSI. Cementing 06:00 AM 06:30 AM 0.50 PRB_~ ~1" P1 Casing and NU BOPS. Cementing 06:30 AM 10:00 AM 3.50 PRB_C$ð C f'1,. r P1 Casing and RIH PICKING UP 51 JTS 4.5" TUBING. M.U, HANGER AND Cementing INSTALL TWCV. MAKE UP LANDING JT.LAND TUBING AND RILDS.FREEZE PROTECTED 9 5/8" X 7" ANNULUS TO 1.600'. PUMPED 150 BBLS WATER 150 BBLS DIESEL. Daily Drilling Report: CD1-24 05/05/99 Page 1 ( \' ( 10:00 AM 10:30 AM 0.50 OTHER P1 Casing and CLEAR RIG FLOOR OF CSG I TUBING HANDLING TOOLS. Cementing 10:30 AM 12:00 PM 1.50 NU_ND P1 Casing and ND BOP'S. Cementing 12:00 PM 01 :30 PM 1.50 NU_ND P1 Casing and NU ADAPTOR FLANGE AND 4 1/16" 5M TREE. TEST TO 3 Cementing 500 PSI, HELD.PULLED TWCV. 01 :30 PM 03:00 PM 1.50 CIRC P1 Casing and RU TO CIRC, FREEZE PROTECT 4.5. TUBING I ANNULUS Cementing TO 1625'. PUMPED 150 BBLS WATER AHEAD 148 BBLS DIESEL 03:00 PM 03:30 PM 0.50 OTHER P1 Casing and SET BPV.INSTALLED GAGES.RIG RELEASED @ 15:30 HRS ..-..._-_.~ ".-" .-.-". . " Cementing 5-5-99, 03:30' PM 04:00 PM 0.50 OTHER P1 Casing and CLEAN CELLAR Cementing 16.00 Supervisor: MIKE WHITELEY Daily Drilling Report: CD1-24 05/05/99 Page 2 -05-99 10:36 (1 Q4S P.01/05 F-157 F rom-ALP I NE COMR-~!!X tAAN ( - , . ~, "'.. . . ""-. . . " I j U ~t¥; ~ ~ I~)N rø ~ CO -.oJ t>'\ ~/~ ~ ~~~~~(Ii~ ~~\.VQQ~"""'CQ ~ ~ ~ """"'-''-' I v..\~""'~~CQ-...I~ ~W~--~ ~~ ~ 0::. ,~ ~ ~ ~'ç:) <::> ~ I;> c:> ~ " ~ ~ ..,w;. ~ (b I ::h ~~~~~~~~~~~ t 1...J N ..... G> t) O(? ~ > ,~(f'¡' (n Lr¡. ~~l '\"1 'V) ~ C> C>.6, ~ ~ In ,;j ~ 01 h ~ J.J R~ G~ 1:::., -I,' "-I1IQ~v -~. ~ -- " ". :,r .'?:' ~ ,... .~ ~ ~ ...f"'_..~ï "" '. .. , '::! '.: ."~. .; ~. '\ \ ~. '\ ;( ~II' .... I . . : =i ~ ~i - ":' r ,.. '. . ... ":15. ~..... ~ ~; ~~~ ~~ ~ ~~~:. ~ 'fb ~...... " ....0 ~ ('.. I ~ ~ ~~ ~ .;: ~. ;.~ Š' fl.:; ~ ...( I /. r" . ,I. C, t~J ':lcT~ .o~ O'l'-, ~f~ ¡-;L::',,',' . '\ fl. l\ \ r 1- """ . " .t Ll \ I 1"-; ,-, ,,'\ ¡:! \ I ~ ¡ , , ¡ ,: I' n, I ¡ II ~,.~,::~,/' LJ~..! l..,'~ ~."'-~ '-=':J. r~rl-11 f¡ -lr.-::.._,' FÀ\'\' ~I"-I ,/A\ C,rlJ. I,ll? /Ä.\ ¡ I ' / L \ . !l l U \ ,';-") \ r \ (U \ ~1L U LfL.} L_:::i Lr\~ Cu, LJ \~ u--u FRANK H. MURKOWSKI, GOVERNOR AltASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. -¡rH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 February 3, 2004 Matt Elmer Alpine Operations Manager ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 Re: Notice of Violation Colville River Unit CD 1-24 I q 9 .- 0 1(, Dear Mr. Elmer: This letter is to inform you that ConocoPhillips (Alaska), Inc. response on October 1, 2003 addresses the Alaska Oil and Gas Conservation Commission ("Commission") concerns regarding the discovery of the defeated surface safety valve (S8V) on the above mentioned well. This Commission will take no further action is this matter. Sincerely, ~ Daniel T. Seamount, Jr. Commissioner ,,. ~ , . y ConocoPhillips Matt Elmer Alpine Operations Manager ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Phone: 907.276.1215 October 1,2003 '''''.'-'' :':" b '\..1..,.0,,'0 ~,,~ ~ \,/ ::~~:, (:J ~'.'--.... '1'.:.-"..,., Commissioner Ruedrich Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 0 CT 0 1 ?nn'J: .-,-,r......... I}, t (.:. S t: ::~ 2 ~~" Gas CC¡!,1,~;. CrC:¡lÙ;S;2!\ Dear Commissioner Ruedrich: This letter was requested in response to the Notice of Violation dated September 15, 2003 issued for the CD1-24 defeated safety valve system SVS incident (received via certified mail by ConocoPhillips on September 18, 2003). The purpose of the letter is to provide an explanation of how this event happened and what will be done to prevent its occurrence at Alpine in the future. The device in question was the surface safety valve (SSV) on well CD1-24. The SSV low-pressure pilot was found to be defeated during the AOGCC-witnessed semi-annual testing of the wellhead safety shut down systems at CD1 on September 15, 2003. The on site drill site operator and the on site board operator were unaware that the device had been defeated. There was no notice or tag posted in the wellhouse to alert the drill site operator to the defeated device. Our investigation determined that the SVS on well CD1-24 was defeated on July 27,2003 in preparation for the annual Alpine facility maintenance turnaround. The well was returned to service on September 11, 2003 at 2200 hours with the low-pressure switch in bypass. It remained in that configuration until the device was found defeated during state testing. A tag was not in place on the wing valve or pilot to alert the operator of the non-normal position of the safety device. The investigation further revealed that the "Bypass List" that is generated by SetCim and reviewed at least twice daily by the board operator did not correctly identify the well name. This resulted in the board operator being unaware of the defeated device on CD1-24. In addition, SetCim did not visually alert the board operator as to the status of the device. The administrative practices and procedures in place at Alpine did not adequately prevent thjs event and will be improved as follows: . The standard operating procedure (SOP) for shutting in a well will be clarified to ensure that a tag is placed on the wing valve when the low-pressure switch is defeated. The SOP for returning the well to service will be adjusted to ensure that the low-pressure switch has been placed back in service prior to bringing the well online. The printed version of the SetCim Bypass List has been corrected to properly identify the well so that confusion doesn't exist in the future. The identification of other Alpine wells on the Bypass List will also be checked for accuracy. All operators will be required to sign off on the Bypass List to increase awareness of defeated devices in their area of responsibility. Currently, only the board operator is required to sign off on the Bypass List for all areas. . . , . , " "- , , " Commissioner Ruedrich Page 2 . The drill site well display on SetCim has been improved to make it visually apparent to the board operator that a low-pressure switch is defeated. Emphasis will be placed on communicating these policy revisions to the operators. . We believe that the improvements mentioned above will increase the reliability of the Alpine SVS systems while reducing as much as possible the likelihood of similar events occurring in the future. Please do not hesitate to contact me if you have any questions or concerns about this matter or the revised procedure. ;;;¡EL---- Matt Elmer Alpine Operations Manager 907 -263-4414 (Anchorage) 907 -670-4024 (Alpine) "? . Cf'f: rt~' : ; ~..... ~~' l, t: ¡, L.-", ~..-.." A r ('rl\ 1;'-'; \1\ j IJ: '7"\ ¡'''; r:"\ .,(=:,", r! /i ! ^. ,¡ ft' \ l \ U ! k ! I F~ U:o L~j'l~ è~~) U \~\ FRANK H. MURKOWSKI, GOVERNOR AT,ASIiA OIL AND GAS CONSERVATION COMMISSION CERTIFIED MAIL - RETURN RECEIPT REQUESTED 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 7002 0510 0000 0453 3275 September 18, 2003 Mr. Matt Elmore ConocoPhillips Alaska, Inc. PO Box 100360 Þuachorage,AJ( 99510 Subject: Notice of Violation Dear Mr. Elmore: On September 15, 2003, AOGCC Inspector Jeff Jones, accompanied by a ConocoPhillips Alaska Inc. (CP A) representative, perfoffi1ed safety valve system (SVS) inspections of wells located on Alpine CD 1 pad. Mr. Jones found the defeated surface safety valve (SSV) on Well CDI-24 (pilot was bypassed in the control room). Further investigation revealed the control board operator and pad operator were unaware of the bypassed pilot. There were no notices posted at the well or in the control room to explain the bypass status, and there were no active well work being performed. A copy of the inspection report is attached. You are reminded that Conservation Order 443, Rule 5 modifies the requirements of 20 AAC 25.265 ("Automatic Shut-in Equipment") as follows: (a) All production wells must be equipped with a fail-safe automatic surface safety valve (SSV) and a surface controlled subsurface safety valve (SSSV). (b) Injection wells must be equipped with a double check valve arrangement. (c) Safety Valve Systems (SVS's) must be tested on a six-month frequency. Sufficient notice l11,ust be given so that a representative of the Commission can witness the tests. ' (d) Subswface safety valves may only be removed after demonstrating to the Commission that the well is not capable of unassisted flow of hydrocarbons. Sufficient notice must be given so that a representative of the Commission can witness the tests. Failure to maintain an operable SVS is a violation of State regulations. Within 14 days of receipt of this letter, you must provide the Commission with an explanation of how this event happened and what will be done in the future to prevent its OCCUITence in at Alpine. Should you have any questions, please contact Mr. James Regg at (907) 793-1236. Sincerely, /'~~ ~~ Randy Ruedrich Commissioner Attach. . I . t- Alaska Oil and Gas Consenration Commission Safety Valve System Test Report Submitted By: Jeff Jones FieldlUnitlPad: Alpine / CD 1 Separator psi: LPS 185 Date: 9/15/2003 Operator: CP AI Operator Rep: Shorty Davis AOGCC Rep: Jeff Jones HPS 3800 (comp.) :".'.,;,,;.;,rY~!",\JJ:~~~'i,}"";':;,N'(;,.:.. It;\;(:..:;/,)';:{,.~>: ,"',' ,,\',t;;i\~ll ~;" :, ''':''''','>'... .'.X',.g:)i,/;F"";" "i'::.""'~:":"":': ,:~~~;fi¡;: t~~~'~:#i~ig~~;'ti~,~:, }Æ~ll/tfW.R~;;,~>} '../',: W;~ ;.:::t-~F., ..',",' <,.."r( cc ::':;;:,::S,:>~'.;:', ;' ':>:;.: Well Permit Separ Set LIP Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, Sf CD 1-01 1990460 CD 1-02 2001720 2400 1600 1590 P P P GINJ CD 1-03 1991200 CD 1-04 2001170 185 250 237 P P P OIL CD 1-05 1991280 CD 1-06 2000830 2440 1600 1600 P P P GINJ CD 1-09 2000710 CD 1-1 0 2001710 185 100 98 P P P OIL CD 1-13 1990520 CD 1-14 2010380 2400 1600 1600 P P P GINJ CD 1-16 1990940 2510 1900 1900 P P P GINJ CD 1-17 2001450 CD 1-21 2010060 Cp 1-229 2002150 CDl-22A 2001100 185 100 98 P P P OIL CDl-23 1990630 CD 1-24 1990260 185 '100 97 1 P P Passed R/T 9/15/03 OIL CDI-25 2000080 185 100 100 P P P OIL CD 1-26 1990880 2215 1600 ~ 1600 P P P GINJ CD 1-27 2000060 185 100 97 P P P OIL CDl-28 2001990 185 100 98 P P P OIL CD 1-30 2001320 185 100 98 P P 9 OIL CD 1- 31 2001180 CD 1-32 1991040 CD 1- 33 2002120 3590 1900 1900 P P P GINJ CDl-34 2000430 CDl-35 1990380 185 100 100 P P P OIL CDl-36 1991120 3530 1600 1600 P P P GINJ CD 1- 37 1990670 CD 1- 38 2000030 CD 1-39 1990800 2965 1900 1900 P P P GINJ CD 1-40 1990440 CD 1-41 2000170 CD 1-42 1991190 3165 1900 1900 P P P GINJ CD 1-43 2001060 CD 1-44 2000550 KJþ' U~. 1 ')/U2 page 1 ot 1. ~ V ~ CKU LV 1 ')-1: -Uj JJ.Xls 4 . , " Weliiiåtå''::;''>;,:/: '' ',: '",,' >:': !,ilots .' ,', ',' "",": ':~$V; ~$~V 1Je~ffl~i~~Il.~~f)#~~: :~W~~l:,-rÝþÌ!.':""': " : ':y" , " ,: '"".", ,,":-' ".," ',> :-" ":','"', Well Permit Separ Set LIP Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI CD] -45 1 991 01 0 3000 ] 600 1 600 P P 8 GINJ 19 Components: 57 Failures: 3 Failure Rate: 5.26% 090 Day Wells: Remarks: The pilot on well CDl-24 failed to trip and was found bypassed in the control room. CDl-24 pilot was put in service and passed are-test. The SSSV on well CDl-30 failed the pressure test. The SSSV on well CDl-45 failed to close RJF 09/19/02 Page 2 of2 SVS CRU CD 1 9-15-03 JJ.xls "Î " ,-.. -~) pr.- ALASKA OIL & GAS CONSERVATION COMMJSSI,ON FAX 907-276-7542 PHONE 907-279-1433 FACSJM1LE TRANSM1TTAL SHEET, TO: t\J\~\<f M~n\s COMP ANYC: P'- I í \ \J)t\.Jt.( \\ t \ \ \ f \ .-.., .1\ \ p \1\ e. FAX NUMBER.:a . , UJ7 -G 7°'- 40% PHONE NUMBER.: ' FROM: ,- ~J ~ìM \~~- c- 1-tQ,-03 DATE: TOTAL NO. OF PAGES JNCLUDlNG COVER: 4- RE: SENDER'S REFERENCE NUMBER: Cf07- 7C¡3--J73Ç:o YOUR REFE:RENCE NUMBER: . ~ùv - CD\- zA~ 0 URGENT, 0 FOR REVIEW 0 PLEASE'COMMENT 0 PLEASE REPLY 0 PLEASE RECYCLE NOTES/COMMENTS: AOGCC 333 WEST 7TH AVENUE, SUJTE 100 ,.1I.lrUI"'I'DAr.:¡; AI( ()()C,01-3935 SHUTDOWN CAUSES OSD Group Name OSDDI-D2-1-20 Pg XÂ.~ OSD NàME DESCRIPTION VALUE TRIP BYPASS In:SI~T 1 OSD-DI-04 CDl~PALL30101-04 CDI-IA Slot 4 W-04 Flowline Pressure OK 250. NORMAL OSD-DI-07 CDI-PALL30101-07 CDI-IA Slot 7 W-09 Flowline Pressure OK 250. HY~^S~ OSD-DI-08 CDI-PALL30101-08 CDI-IA Slot 8 W-IO Flowline Pressure OK 100. NORMAL OSD-D1-09 CDI-PALL30101-09 CDl-1A Slot 9 Flowline Pressure OK 100. NORMAL OSD-DI-12 CDI-PALL30101-12 CDl-1A Slot 12 W-17 Flowline Pressure OK 250. OYP^SS '=iSD-Dl-16 CDI-FALL30J.DI-IG CDt-IÞ, Slot 16 \'.'-229 FlowliûB Pressure ,ð,L\RH 100. NORMAL OSD-DI-17 CDI-PALL30101-17 CDl-1A Slot 17 W-35 Flowline Pressure OK 100. NORMAL OSD-Dl-18 CD1-PALL30101-18 CDI-1A Slot IB W-22 Flowline Pressure OK 100. NORMAL OSD-DI-19 CDI-PALL30101-19 CDI-IA Slot 19 W-24 Flowline Pressure OK 100. NORMAL OSD-D1-20 CDI-PALL30101-20 CDI-1A Slot 20 W-25 Flowline Pressure OK 100. NORMAL OSD-D2-01 CD1-PALL49008-01 CD1-1A Slot 1 W-01 Flowline Pressure OK 1600. NORMAL OSD-D2-02 CD1-P..0,ll49G08-G2 C~Dl--ll\ Slc)t / ft?--02 f'lcn¥line Pr.e~;~=;l1re .~Li-\F~[,{ 400. UY~~I,~\~3:~ OSD-D2-03 CD1-PALL4900B-03 CDI-IA Slot 3 W-03 Flowline Pressure OK 400. NORMAL OSD-D2-05 CDI-P.\I.L~'][HJ8-05 CD1-j..\ Slot ') ""'~C1S Flowli_ile PTessure iH"ð,PJIc 400. n-/f'..\:;:; OSD-D2-06 CDI-PALL4900B-06 CD1-1A Slot 6 W-06 Flowline Pressure OK 1600. NORMAL OSD-D2-10 CD1-PALL49008-10 CD1-1A Slot 10 W-13 Flowline Pressure OK 400. NORMAL OSD-D2-ll CDI-PALL4900B-ll CDI-IA Slot 11 W-14 Flowline Pressure OK 1600. NORMAL OSD-D2-13 CDI-PALL49008-13 CDI-IA Slot 13 W-16 Flowline Pressure OK 1900. NORMAL OSD-D2-14 CDI-PALL4900B-14 CDI-IA Slot 14 W-21 Flowline Pressure OK 400. NORMAL OSD-D2-15 CDI-PALL49008-15 CD 1-1A Slot 15 W-23 Flowline Pressure OK 400. [':\'-;~','<;~~ 1/ n:I!Ia, l' 080-01-04 SHUTDOWN EFFECTS Page /1 ~~ NOTES t~ }.ddLinc ril~¡~~ / 1 ~~ Tagname Description Value CDI-HS-66101-04 CDI-IA Slot #4 W-04 SSV-30001-04 OPEN CDl-SLOT4-DIVRT CDI-IA Slot #4 W-04 Divert To Test CLOSED 1"11) 1 i', -V(ìH - 4 (''-1'017E ("Ií'}',rRnT ';'\nn (' i- 1, e..-- -d 63 9 - r C~ " 1.-' '~L ~H ih .~-> ,r'. V_li~L,'~L 1: _r, _on _TO .Lv-_OT. . NO rec()fzl OJ 01-z.?\ ? o~r.:;¡eL'1 'b~ f{Cj':L~.Q NOTES æII }.ddLinc ril~ff:~ 1 ' /l~~" NO rec()R:l cJ 'b~ f{Cj':L~.Q CD 1- z.t\ ?' o~he L'1 P'!lnnti",,, C:;:on 1 ~ ?nn-:t 11 .n~ pr.A -~.-:-- _',---.4_-.'''-' SHUTDOWN CAUSES OSD Group Name OSDD1-D2-21-4 P XA~ OSD NAME DESCRIPTION VALUE TRIP BYPi\SS RESET 9 1 OSD-Dl-21 CDI-PALL30101-21 CD1-1B Slot 21 W-27 Flowline Pressure OK 100. NORMAL OSD-Dl-24 CDI-PALL30101-24 CD1-1B Slot 24 W-2B Flowline Pressure OK 100. NORMAL OSD-Dl-26 CD1-PALL30101-26 CD1-1B Slot 26 W-30 Flowline Pressure OK 100. NORMAL OSD-Dl-27 CD1-PALL30101-27 CD1-1B Slot 27 W-32 Flowline Pressure OK 100. NORMAL OSD-Dl-2B CDI-PALL30101-2B CD1-1B Slot 2B W-34 Flowline Pressure OK 100. NORMAL OSD-D1-29 CD.L-PALL3010.l-29 CDl-113 Slot 29 flowline PreSS1Jre Þ~L1\ R}l 100. n y [' /'. ~;~; OSD-D1-32 CDI-PALL30101-32 CD1-1B Slot 32 W-3B Flowline Pressure OK 100. NORMAL OSD-D1-33 CDI-PALL30101-33 CD1-1B Slot 33 W-40 Flowline Pressure OK 100. NORMAL OSD-D1-35 CDI-PALL30101-35 CD1-1B Slot 35 W-41 Flowline Pressure OK 100. NORMAL OSD-Dl-3B CDI-PALL30101-3B CD1-1B Slot 3B W-43 Flowline Pressure OK 100. NORMAL OSD-Dl-40 CD1-PALL30101-40 CD1-1B Slot 40 W-44 Flowline Pressure OK 100. NORMAL OSD-D2-22 CDI-PALL4900B-22 CDI-IB Slot 22 W-26 Flowline Pressure OK 1600. NORMAL OSD-D2-23 (: D .t M P 7\1-4 L 4 ¡J D 0 8 -:2 3 CD1-1B SJ.ot 23 w- D F 1 c1~1 i ne Press n roe þ, L Þ,. P)õ"{ 400. n F:{ ~I l\ ~:"~ ~:: OSD-D2-25 CD1-PALL4900B-25 CD1-1B Slot 25 W-31 Flowline Pressure OK 400. NORMAL OSD-D2-30 CD1-PALL4900B-30 CD1-1B Slot 30 W-33 Flowline Pressure OK 1900. NORMAL OSD-D2-31 CD1-PALL4900B-31 CD1-1B Slot 31 W-36 Flowline Pressure OK 1600. NORMAL OSD-D2-34 CD1-PALL4900B-34 CD1-1B Slot 34 W-37 Flowline Pressure OK 400. NORMAL OSD-D2-36 CD1-PALL4900B-36 CD1-1B Slot 36 W-39 Flowline Pressure OK 1900. NORMAL OSD-D2-37 CDI-PALL4900B-37 CD1-1B Slot 37 W-42 Flowline Pressure OK 1900. NORMAL OSD-D2-39 CD1-PALL49008-39 CD1-1B Slot 39 W-45 Flowline Pressure OK 1600. NORMAL OSD-Dl-21 SHUTDOWN EFFECTS 1/ ......~' NOTES (II t / Page /1 êrJdLine l)d::{c'! /.l~~v Tagname Description Value CD1-HS-S6101-21 CDl-1A Slot #21 W-2í SSV-30001-21 OPEN CD 1- SLOT21-, D IVRT CDI-IB Slot #21 W-2í Divert To Test CLOSED CDIB-HO\/-21 SLOT 21 W-27 CHOKE Con'trol record BO.O NOTES (II êrJdLine Pd::{C'! t / /.l~~v 1mmmI~~~Lmmllmmm1Imm8!BmJ1~-' ,,". _.a.. Im!R8mmB11l.!ii1.Dñ8mDm1~l!r1ImIImm&DImma1i8mm'DD " . , ' : - , IJInIlH;f~læR~~2,~èjt'FiI e1-PI-33ÐÐ8~ HP Inj eolltp 1 Stg Sctn Prss eee 148.2 PSI rJm 4h c ., ,J:;'-:(~:C_;, ~ :'~"" '.,'(¡, .' ¿' ont Mondav. SeD 15. 2003 11 :06 PM OPEN/SI CHOKE INJ PRES INJ TEMP SSV WH PRES ORIF DP INJ RATE REC RATE PRIORITY 0 CPRIME Âøt JII 27. 2392.1 OPEt.~ 3.9 8860. 8500. 1 I- - 6 -- Ø6 0. 2437.3 OPEN -0.1 0. 2000. 3 - 11 II 19. 2398.1 OPEN 0.3 151. 2000. 3 14 Â 13 II 16 27. 2509.9 0 P E ~{ 3.1 7911. 7500. 2 , Â 22 JI 68. 2214.8 I] f) E r'~ 1.9 6194. 5600. 2 26 Â 30 JII 33 31. 3589.1 II F~ E ¡.~ 1.7 5817. 3800. 2 - Â 31 III 31. 3531.8 {JPEf"~ 5.6 10613. 11300. 1 36 Â 36 JIll 39 7. 2964.2 0 P E t,~ 5.8 10881. 8500. 2 Â 37 II 10. 3163.1 9263. 42 OPEN 4.2 7700. 1 Â 39 III 45 10. 2995.0 0 P E ti 5.9 10916. 8500. 1 ~ III III III ! I I ~ I Enrich Fluid Press FroI Gas/Liq Exch MANIFOLD HYD MOV OSD CD1A II II III CD1B III II II II WELL EVENTS SUM -- WELL SYMBOLS -- III PREV WELLS II TEST FAC TFCD1 III ADDTL WELL DATA II NEXT WELLS 1!mIIIImmm8~~~rmJID~~~IilmDI_, . f.!mImImE!JIIImmJ.8EEmi11&m![gmmEiDlmmE7Dl~£ElmJI&V8' ~'~ I nnnF'iof~~ß~{t'Yl;11:hl C1-PI-3300S.ß HP Inj COIllP 1 Stg Setn Prss cee 143.? PSI ~ 4h 3876 - 0 PSIG OIL H2O GAS III III 11111 CD 1 III .II III III III -- CD2 II - II OIL GAS H2O III TP DOWN ALL . GAS WELLS II TP UP ALL WELL SCHEMATICS GAS WELLS -- -_.~---..-.---~-~-~-~-~------. III WI" SUMMARY lliI S SQL RETURNED 10 GAS WELLS :,:;.r ~r_. ;,'. . ~o",-.',:'l)j 1- ~ ODE Monday, Sep 15, 2003 11 :00 PM SLOT II '1 WELL II OPEN/SI CHOKE FTP FIT SSV LG PRES LG TEMP ORIF OP LG RATE LG RECOM TEST OVRT 'I - . I 4 III I 64. I 636.01 117.81 OPEN I -0.21 71.21 0.11 0.0 I 0. I CLOSED II 04 7 III 1161.1 64.0 1060.1 68.8 -0.2 0.0 0. I CLOSED 09 0. OPEN 8 II 22. 399.8 104.6 OPEN 883.5 69.0 -0.1 0.0 0. I CLOSED 10 12 II I 0. I 1681 . 0 I 64.31 1 797.41 67.91 -0.11 0.0 I 0. I 17 OPEr'.~ CLOSED 18 III I 48. I 227.41 109.61 OPEN I 1253 . 3 1 75.81 12.71 1918.9 I 1000. 22 t ~ I 19 JII I 100. I 258.71 106.61 I 807.41 70.81 -0.01 24 [I F1 Er~-~ 0.0 1 0. I CLOSED 20 III I 95. I 242.0 I 104.71 í]FEì~i 1 1058 . 6 1 66.71 4.81 1085 . 3 I le0e. I CLOSED 25 21 III I 80. I 247.4\ 100.61 1 1165 .11 70.91 4.41 1099 . 6 1 27 (1~;E~) 100e. I CLOSED 24 III I 47. I 234.31 95.61 OPFN I 787.31 52.61 3.71 799.71 0. I CLOSED 28 26 III I 35. I 775.21 61.01 I 701.41 30 OPEN 73.81 -0.01 0.0 I 0. I CLOSED 27 III I 65. I 237.41 110.31 I 325.71 75.71 -0.01 0.0 1 0. I 32 lIPEr-{ CLOSED 28 II I 80. I 225.11 104.51 34 OFJEr'~ I 1022.81 64.11 4.51 1021. 21. lee0. I CLOSED MANIFOLD HYD MOV OSD OIL H2O GAS OIL GAS H2O WELL SCHEMATICS I COlA II 1111 111111- CD 1 111111111 - TP DOWN ALL II TP UP ALL III II 1111 111111111 CD2 111111 OIL WELLS ",. OIL WELLS ,. CDIB - III WT SUMMARY II WELL EVENTS SUM II WELL SYMnnL~ . .... J "'......... 11.L.L.8........... - III PREV WELLS -- TEST FAC TFCDl II ADDTL WELL DATA III NEXT WELLS 1mma8_. _..~ ~~mmlDrmrm8~~ (m:miD.. .' . mDD~~mmDlmJJJmImmRII,' . , _lIInnl~I~MJ.ß]E~~i'1§Y;~Ti;¡ C1-PI-33008-A HP Inj COIl8P 1 Stg Setn PI"SS CCC 148.5 PSI K!Jm 4h <..:""." ~:'}.:i,~,~-' :'.< .':.'.\ :1.',:,','r 6r._~-;, J,..':j-*,-.;~;;'-; Mnnrl~v ,~~n 1 S ?OO:\ 10'S9 PM SLOT # WELL # OPEN/SI CHOKE FIT LG PRES ø HYD MOV OSD OIL H2O GAS OIL GAS H2O II II 8 111111111 CD! - III JII III II II III -- -- CD2 III 111111 -- -~---.~~------.-~.-..-..- II TIllS SQL RETIJRNED 19 OIL WELLS 14?3 PSI .~c~,",-,~".' ~.~. -.'--,~..,"'-~", - ,'.0- -",<':"_.¡#.:_,~-.',-} .'-',:~,f~~._,,-<-.~)f,..,;,¡-~ 1? III 79. 260.9 108.9 0 F E r'~ 670.1 72.0 -0.2 Ø.0 0. 35 CLOSED - - 32 III 38 93. 240.5 104.1 [I P E .Ii 1006.9 63.4 4.2 988.4 800. CLOSED - . 33 III 55. 202.3 93.5 OPEi1 1222.3 72.8 2.3 802.7 800. CLOSED 40 35 III 41 80. 205.4 90.4 !JFEr~ 1941.0 104.4 1.2 711.6 1000. CLOSED 38 JIll 50. 212.6 107.9 C¡PEt.~ 759.4 71.4 0.1 Ø.0 0. CLOSED 43 40 III 44 50. 209.5 107.1 0 }) E f'~ 899.4 77.1 0.0 0.0 0. CLOSED - . 16 III 0. 10.4 67.5 CLOSED 861.8 68.6 -0.3 0.0 0. CLOSED å,i~w 229 I~I III ~ III JI I ::0:-1 '~ III i -",. - I ¡ '-f':0 í~-I I~I III I . I Ld ~ III 11' p,l~ ,I ¡ ~I FTP SSV LG TEMP ORIF DP LG RATE LG RECOM TEST DVRT III TP DOWN ALL OIL WELLS -- WT SUMMARY WELL SCHEMATICS - TP UP ALL - ~' OIL WELLS ~. II WELL EVENTS SUM MANIFOLD CDlA CD1B Mondav. SeD 15. 2003 11 :00 PM . CtL) t:îT' n;\\', ~fr rr= \,,"\ !, ¡ i L\ ¡ [ ¡;.: ,-,-',\ ~'I,,-~¡ II II ~~~' ,,/ L~~ L" \.,l LJ L~':; q~\!") rE rÃ\ 11'"1 /Ã\\ (Ci.:} rl?' ¡\ !' !' r-- I 1\, ¡ . I! \ '\ '\.., ì ¡ \ .. ' I ;' ¡' I .-: \ ; ¡ l L.~ l 7" \ '¡ ¡ \ \ \ U¿,.,. Ll II L L~::j LJ\J \,,~) LJ \} FRANK H. MURKOWSKI, GOVERNOR AltA~1iA OIL AND GAS CONSERVATION COMMISSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 February 3, 2004 Matt Elmer Alpine Operations Manager ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 Re: Notice of Violation Colville River Unit CD 1-24 Dear Mr. Elmer: This letter is to inform you that ConocoPhillips (Alaska), Inc. response on October 1, 2003 addresses the Alaska Oil and Gas Conservation Commission ("Commission") concerns regarding the discovery of the defeated surface safety valve (SSV) on the above mentioned well. This Commission will take no further action is this matter. Sincerely, ~ Daniel T. Seamount, Jr. Commissioner ,~ .0 ( ( /99 -OCJéo y ConocoPhillips Matt Elmer Alpine Operations Manager ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Phone: 907.276.1215 October 1 , 2003 f"'"'''''',,,, ~'\... f, \,/ ~~~:, [) Commissioner Ruedrich Alaska Oil & Gas Commission 333 West ¡th Avenue, Suite 100 Anchorage, AK 99501 OCT 0 1 2003 ¡\\aZ!{,2 ~;~~, G;as- Coni Sa Dear Commissioner Ruedrich: This letter was requested in response to the Notice of Violation dated September 15, 2003 issued for the CD1-24 defeated safety valve system SVS incident (received via certified mail by ConocoPhillips on September 18, 2003). The purpose of the letter is to provide an explanation of how this event happened and what will be done to prevent its occurrence at Alpine in the future. The device in question was the surface safety valve (SSV) on well CD1-24. The SSV low-pressure pilot was found to be defeated during the AOGCC-witnessed semi-annual testing of the wellhead safety shut down systems at CD1 on September 15, 2003. The on site drill site operator and the on site board operator were unaware that the device had been defeated. There was no notice or tag posted in the wellhouse to alert the drill site operator to the defeated device. Our investigation determined that the SVS on well CD1-24 was defeated on July 27,2003 in preparation for the annual Alpine facility maintenance turnaround. The well was returned to service on September 11, 2003 at 2200 hours with the low-pressure switch in bypass. It remained in that configuration until the device was found defeated during state testing. A tag was not in place on the wing valve or pilot to alert the operator of the non-normal position of the safety device. The investigation further revealed that the "Bypass List" that is generated by SetCim and reviewed at least twice daily by the board operator did not correctly identify the well name. This resulted in the board operator being unaware of the defeated device on CD1-24. In addition, SetCim did not visually alert the board operator as to the status of the device. The administrative practices and procedures in place at Alpine did not adequately prevent this event and will be improved as follows: . The standard operating procedure (SOP) for shutting in a well will be clarified to ensure that a tag is placed on the wing valve when the low-pressure switch is defeated. The SOP for returning the well to service will be adjusted to ensure that the low-pressure switch has been placed back in service prior to bringing the well online. The printed version of the SetCim Bypass List has been corrected to properly identify the well so that confusion doesn't exist in the future. The identification of other Alpine wells on the Bypass List will also be checked for accuracy. All operators will be required to sign off on the Bypass List to increase awareness of defeated devices in their area of responsibility. Currently, only the board operator is required to sign off on the Bypass List for all areas. . . $CANNED OCT 1 4 2003 ." I " . ..,.,. ( (' Commissioner Ruedrich Page 2 . The drill site well display on SetCim has been improved to make it visually apparent to the board operator that a low-pressure switch is defeated. Emphasis will be placed on communicating these policy revisions to the operators. . We believe that the improvements mentioned above will increase the reliability of the Alpine SVS systems while reducing as much as possible the likelihood of similar events occurring in the future. Please do not hesitate to contact me if you have any questions or concerns about this matter or the revised procedure. ;;;¡~ Matt Elmer Alpine Operations Manager 907 -263-4414 (Anchorage) 907-670-4024 (Alpine) Attach. · /_. L,t(' ..... 01L AND GAS CONSERVATION COM VlISSION CERTIFIED MAIL- RETURN RECEIPT REQUESTED FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 7002 0510 0000 0453 3275 September 18, 2003 Mr. Matt Elmore ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Subject: Notice of Violation Dear Mr. Elmore: On September 15, 2003, AOGCC Inspector Jeff Jones, accompanied by a ConocoPhillips Alaska Inc. (CPA) representative, performed safety valve system (SVS) inspections of wells located on Alpine CD1 pad. Mr. Jones found the defeated surface safety valve (SSV) on Well CD1-24 (pilot was bypassed in the control room). Further investigation revealed the control board operator and pad operator were unaware of the bypassed pilot. There were no notices posted at the well or in the control room to explain the bypass status, and there were no active well work being performed. A copy of the inspection report is attached. You are reminded that Conservation Order 443, Rule 5 modifies the requirements of 20 AAC 25.265 ("Automatic Shut-in Equipment") as follows: (a) All production wells must be equipped with a fail-safe automatic surface safety valve (SSV) and a surface controlled subsurface safety valve (SSSV). (b) Injection wells must be equipped with a double check valve arrangement. (c) Safety Valve Systems (SVS's) must be tested on a six-month frequency. Sufficient notice must be given so that a representative of the Commission can witness the tests. (d) Subsurface safety valves may only be removed after demonstrating to the Commission that the well is not capable of unassisted flow of hydrocarbons. Sufficient notice must be given so that a representative of the Commission can witness the tests. Failure to maintain an operable SVS is a violation of State regulations. Within 14 days of receipt of this letter, you must provide the Commission with an explanation of how this event happened and what will be done in the future to prevent its occurrence in at Alpine. Should you have any questions, please contact Mr. James Regg at (907) 793-1236. Sincerely, Randy Ruedrich Commissioner Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: CPAI Operator Rep: Shorty Davis AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: Alpine / CD 1 Separator psi: LPS 185 Date: 9/15/2003 HPS 3800 (comp.) Well Permit Separ Set L/P Test Test Test Date Tested and or Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI CD 1-01 1990460 CD1-02 2001720 2400 1600 1590 P P P GINJ CD 1-03 1991200 CD1-04 2001170 185 250 237 P P P OIL CD1-05 1991280 CD1-06 2000830 2440 1600 1600 P P P GINJ CD1-09 2000710 CDI-10 2001710 185 100 98 P P P OIL ~CDI-13 1990520 CDI-14 2010380 2400 1600 1600 P P P GINJ CDI-16 1990940 2510 1900 1900 P P P GINJ CDI-17 2001450 CD 1-21 2010060 CD1-229 2002150 CD 1-22A 2001100 185 100 98 P P P OIL CD1-23 1990630 CD 1-24 1990260 185 100 97 1 P P Passed R/T 9/15/03 OIL CD 1-25 2000080 185 100 100 P P P OIL CD1-26 1990880 2215 1600! 1600 P P P GINJ CD1-27 2000060 185 100 97~ P P P OIL CD 1-28 2001990 185 100 98 P P P OIL CD 1-30 2001320 185 100 98 P P 9 OIL CD 1-31 2001180 CD1-32 1991040 CD1-33 2002120 3590 1900 1900 P P P GINJ CD1-34 2000430 CD1-35 1990380 185 100, 100 P P P OIL CD1-36 1991120 3530 1600: 1600 P P P GINJ CD1-37 1990670 CD 1-38 2000030i CD1-39 1990800' 2965 1900 1900 P P P GINJ ,, 'CD1-40 1990440 "CD 1-41 2000170 CD1-42 1991190 3165! 1900 1900 P P e GINJ CD1-43 2001060 CD1-44 2000550 }Veil Data Pih~ts SSV SSSV Test/Retest~SI Date Wel~Type Well Permit Separ Set L/P Test Test Test Date Tested and or oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI CD1-45 1991010 3000 1600 1600 P P 8 GINJ Wells: 19 Components: 57 Failures: 3 Failure Rate: 5.26% I-190 Day Remarks: The pilot on well CD 1-24 failed to trip and was found bypassed in the control room. CD 1-24 pilot was put in service and passed a re-test. The SSSV on well CD1-30 failed the pressure test. The SSSV on well CD 1-45 failed to close RJF 09/19/02 Page 2 of 2 SVS CRU CD1 9-15-03 JJ.xls ternS 1, 2, and 3. Also complete com~!?.te_j --'.cted Delivery is desire.d.'_.,,rse item 4~ff Hes_~ ,~,a addreSS on tt~e Print ~?ur n_a~,~.;~n the card to you.. so tha ~W.e u~.~,j-~-..-+~,, back of the mmlpleu~, Atta~t~h's. cain, t,un"a~e ~ermits- or on the tron~ ~ ~'~'" 1. Article Addressed to: '2. AKic~e Number (COpy fr°m se' ? ~ 0 ~ 'PS Form ~8 A. Received by (Please Print Clearly) C. Signature address different ~rom item I~ YES, enter deINerY address below: . 3. Service Type Certifie d Mail ~ Express E3 Registered ~ Return El c.o.~ 4. Restricted Delivery? (Extra Fee) 0000 04~3 3275 Domestic Return Receipt B. Date o~ Delivery 1~ Agent E3 Yes \, S~ 102595-00-M'0952 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-I CD-2 WELLS DEPTH VOLUME TYPE SACKS BBLS Cement CD1-1 2.25' 0.3 WI 1.8 CD1-2 4' 0.6 WI 3.6 CD~-3 ' '10' 1.4 MI 8.5 CD1-4 7.33' 1 -- P .... 6.0 CD1-5 4' 0.6 MI---- 3.6 CD1-6 10.42' 1.4 Gl 8.5 CD1-16 14.33' 2 WI 12.1 -- CD1-17 8.75' 1.2 P 7.2 CD1-21 13' 1.8 MI 10.9 CD1-22 1.83' 0.3 P 1.8 CD1-23 15.42' 2.1 MI 12.7 CD1-24 2' 0.3 P 1.8 CD1-25 5.66' 0.8 P 4.8 CD1-27 18.83' 2.6 P 15.7 CD1-28 6.75' 1 P 6.0 CD1-32 8.33' 1.2 P 7.2 CD1-34 41.83' 5.7 P 34.4 CD1-36 16.75' 2.3 WI 13.9 CDI-38 3.5' 0.5 P 3.0 CD1-42 5.83' 0.8 MI 4.8 CD2-16 11.66' 1.6 INJ 9.7 CD2-17 18' 2.5INJ 15.1 CD2-19 11.66' 1.6 P 9.7 CD2-22 13.5' 1.8 INJ 10.9 CD2-25 27.25' 3.7 P 22.3 CD2-26 10.42' 1.4 INJ 8.5 CD2-32 8.5' 1.2 INJ 7.2 CD2-33 --- 7' 1 P 6.0 ................ ............. ...... CD2-41 11.83' 1.6 P 9.7 CD2o46 7.42' 1 INJ 6.0 CD2-48 10.33' 1.4 INJ 8.5 CD2o49 9.33' 1.3 INJ 7.8 CD2o50 1.66' 0.25 P 1.5 ConocOPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD 1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor /~lpi~Je beme~lt lop Pill Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 2003 17:38:26-0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual 404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cement. I believe 34 wells were treated. Chuck Scheve > and John Crisp were notified but declined to witness when we told them what > we were doing. Some time past we had agreed to submit a 10-404 for this > kind of work. Due to the number of these, is a 10-404 needed on each well? > I don't want to commit the time to doing this if it is not necessary; > I0-404's are time consuming to prepare. Would a list of the jobs suffice, > or something similar? We have the well numbers, depth to cement top, and > sacks used to fill the void. My proposal would not affect future > submissions of 10-404's for this work. What do you think? Thanks! > Jerry Dethlefs (See attached file: tom_maunder.vcf) of CANNE 8 2_003 4/24/2003 7:55 AIr ,. ~/~..~, Name: AOGCC ALPINE cement top outs 04-16-03. xls [ AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) I Encoding' base64 I Name: Cement Top Fill AOGCC Letter 04-23-03.doc DCement Top Fill AOGCC Letter 04-23-03.docI Type: WlNWORD File (application/msword) I Encoding: base64 Tom Maunder <tom maunder@admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 4/24/2003 7:55 Arv Permitto Drill 1990260 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. COLVILLE RIV UNIT CD1-24 Operator PHILLIPS ALASKA INC. MD 13706 1-VD 6951 Completion Dat 8/4/2000'~'"~ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-103-20295-00-00 UIC N REQUIRED INFORMATION Mud Log No Sample N_9o Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Interval Data Digital Digital Log Log Run OH I Dataset Type Media~ Fmt Name Scale Media No Start Stop CH Received Number Comments 2821 13706 Open 9/26/2000 09723z----~21-13706 ~ 2771 10794 Open 6/10/1999 0921~-10794 ~T'~'~ 2771 10794 Open 11/23/1999 0939(Y-~ZT~'1-10794 L ,L-'"~ CDR/IMP-MD 2/5 FINAL 2821 13659 OH 9/26/2000 2821-13659 4/26/99 THRU L ~,"'",~ CDR-TVD 2/5 FINAL 6652 6950 OH 9/26/2000 6652-6950 5/3/99 THRU C ~ 9723 2-4 OH 9/26/2000 972~HLUM IMP/CDPJADN tR~/.~- 4/26/99 THR R SRVY RPT 0 13706 OH 8/18/2000 SCHLUM 0-13706.34 R SRVY RPT 115 10796 OH 5/11/1999 SCHLUM 115-10796. L CDR-MD FINAL 2821 10759 OH 6/10/1999 2821-10759 L ADN-MD FINAL 9539 10705 OH 6/10/1999 9539-10705 L ADN-TVD FINAL 6630 6950 OH 6/10/1999 6630-6950 L ~'/J/ CDR-'I'VD FINAL 2400 6940 OH 6/10/1999 2400-6940 L ~ SCMT 5 FINAL 9000 10156 CH 7/26/1999 BL(C) 9000-10156 L ~/'~ ADN-MD 2/5 FINAL 9500 10700 OH 11/23/1999 9500-10700 REV2UIC L '~ ADN-TVD 2/5 FINAL 6600 6950 OH 11/23/1999 6600-6950 REV 2UIC 9390 2 OH 11/23/1999 9390~--~!SCHLUM CDR/ADN-PDC REV 2 Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments Permit to Drill 1990260 M D 13706 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. COLVILLE RIV UNIT CD1-24 Operator PHILLIPS ALASKA INC. 6951 Completion Dat 8/4/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-103-20295-00-00 UIC N ADDITIONAL INFORMATION Well Cored? Y/~,,~ Chips Received? '"'"~ / N Analysis Daily History Received? (~ N Formation Tops ~)/N Comments: Compliance Reviewed By: Date: Annular Dis 9osal durit the third 'uarter ~ 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-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, 1C-117, lC-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May2001 July2001 CD2-24, CD2-33 CD2-24 . 30443 100 0 30543 375 30918 June2001 Sept2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 1C-16 19579 100 0 19679 0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 CD2-14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli for which Disposal Authorization Expired during the third 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 CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-141, 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1D-36, 1D-34 2N-318 ' 17498 100 0 17598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-316 ?:o '2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. The volumes for the expired permit applies just to that permit. 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 Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 386' FNL, 2867' FEL, Sec. 5, T11N, R5E, UM At top of productive interval 1330' FNL, 1448' FEL, SEC. 4, T11N, R5E, UM At effective depth At total depth 4464' FNL, 4879' FEL, Sec. 3, T11N, R5E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (asp's 385837, 5975742) (asp's 392530, 5974746) (asp's 394333, 5971537) 6. Datum elevation (DF or KB feet) RKB 36' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-24 9. Permit number / approval number 199-026 10. APl number 50-103-20295 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 2820' PROD CASING 10771' OPEN HOLE 2935' OPEN HOLE Size 16" 9-5/8" 7" 6.125" 13706 feet Plugs (measured) 6951 feet 13706 feet Junk (measured) 6951 feet Cemented lO cu yds Portland Type 3 500 Sx AS III LW, 230 Sx Class G 283 Sx Class G Measured Depth True vedicalDepth 114' 114' 2820' 2390' 10771' 6948' 10771'-13706' Perforation depth: measu red None true vertical None Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 Tbg @ 9896' MD. BAKER S-3 PACKER @ 9807' MD. CAMCO BAL-O SSSV @ 1790' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch .~_ 15. Status of well classification as: 14. Estimated date for commencing operation May 6, 2001 16. If proposal was verbally approved Name of approver Date approved Oil X Gas Suspended __ -- -- Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S~gned ' ~. ~. ~,4~,~0(~(., Title: Alpine Production Engineer Michael E~ih'~; · '~' Questions? Call Michael Erwin @ 265-1478. Prepared by Sharon AIIsup-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test Location clearance - - Mechanical Integrity Test__ Subsequent form required 10- ORIGINAL SIGNED BY Approved b_.y p,(d~,(.,ofL,the,.C,.qr2'ij~sion D [ayior,~8~ocJr~. r ~. I Commissioner Approval no. Date '-~"~'~ / CUDMIT ............. i1~1 i i'~11 ~,..1~.,~-~,1 L.. Stimulation Procedure Colville River Field CD1-24 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 openhole interval. ¢--. ~ 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 ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure I-- 7" Riser Methanol Injection ~ I Otis 7" WLA Quick I' "1 Connect '" I J 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 2 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 7 1/6" or as necessary 2' Side outlets IBlind/ShearI 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 State of Alaska THRU: Tom Maunder, P. I. Supervisor Alaska Oil and Gas Conservation Commission 'TO: Julie Heusser, '~ ~ ~ Commissioner ~- ~~ DATE: FROM: Chuck Scheve; SUBJECT: Petroleum Inspector March 30, 2001 Safety Valve Tests Colville River Unit CD1 Pad Friday, March 30. 2001' I 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 dueto 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 Attach .rnent:. 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: ph.i.i!ips Operator Rep: Jack Kraliek AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: '..Alpine/._ CRU/~D 1 Separator psi: LPS .... ,143,, Date: 3/30/01 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number, .Number ,.,PSI PS! , ,, Trip . Code Code . Code passed GaS or CYCLe.: CD1-01 1990460 cD1-0~' 2000830 CD1-09 2000710 .............. CDI-13 1990520 CDI-16 1990940 , CDI"i7 '2001,i50 '14j ' 100 100 .... P P .... P ..... oiL /SD1-52A ''2001100 143' fOb ' i06 ' 'P ' "p p ...... OIL " ':- i990260 .... 1~3 "'100 100 ' -p ' p "P ..... OIL COl.~5}=~" 2000080 143" loOi" '100 'V .... e'' p ....... OIL CD!,-27 20090601................. CD1-30 2001320:.... CI~1-32 1991040 ........... CD1-34 2000430 ci~'i-35 '"1990380 'i43 ' 106 .... i00 p " p p ....... 0Ii~" C,pl-38 2000030 ................. ~CD1-40 1990440 , CD 1-41 .... 3.00~) 170 CD143 2001060 .. . CD1-44 2000550 Ci~1'-04 2001170' ' 143 '"1'00 100 p p ' ~ p' ' ' OiL CDI-10 20017'10 .... 143 .... 1'00. .106 P '' V 'p',.,, '' , ',, ' 0iL cD1"-2'9 ...... 1~43 lOO lOO p p p OIL 24 Failures: 0 Failure Rate: 0.00% Wells: 8 Components: .......... Remarks: RJF 1/16/01 Page 1 of 1 010330-SVS CRU CD1-CS Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 526 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine 9/19/00 Color Well Job # Log Description Date BL sePia Prints CD 'CD1-24 20346 M1 CDR/ADN/IMPULSE ~ ~'~ 000804 1 CD1-24 20346 MD C D R~/~'/,~/.,,¢'~ 000804 I 1 CD1-24 20346 TVD CDR 000804 I 1 r~' I~/', r' ! T! r' ~ _ I~. L%,L I v ~, ~,~ ~..t,~ ~ e_c~_/~.,,~,~.,-s~_ .,-~ A~ ~s~ 8EP 2~ 2000 SIGNED: ~~~~ DATE: ~ - ~ch0rage Please sign and return one copy of this transmiffal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 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 [~] Gas [~ Suspended ~] ~ Abandoned [~] Service r~ . .. 2. Name of Operator , ~ 7. Permit Number Phillips Alaska, Inc. .:Lr,.,X.~IIr~'~ 99-26 / 300-176 3. Address v ~-r~,~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~ 50-103-20295-00 4. Location of well at surface ,.~1,.~, ~· 9. Unit or Lease Name 387' FNL, 2412' FWL, Sec. 5, T11N, REE, UM (ASP: 385837, 5975742) ~ ~ L~';:" ::'. ~:;.: ~ Colville River Unit At Top Producing Interval 10. Well Number 1330' FNL, 1448' FEL, SEC 4, T11 N, REE, UM (ASP: 392530, 5974746) CD1-24 At Total Depth ~ ~ ~: 11. Field and Pool 809' FSL, 399' FWL, Sec. 3, Tll N, REE, UM (ASP: 394333, 5971537) ~. :;.;"::';;:;'~ ;' 7~.~ Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. Alpine Oil Pool 36' RKB teet[ ADL 25559 ALK 4717 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. ~15. Water Depth, if offshore 16. No. of Com~ietions April ~, 1999 August 3, 2000 August 5, 2000] N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey ~20. Depth where SSSV set 21. Thickne~ o~' PermafrOst 13706' MD / 6951' ~D 13706' MD / 6951' ~D YES ~ No ~~ 1790' feet MD 859' 22. T~e Ele~ric or Other Logs Run GR/Res/Neu~Dens 23. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. G~DE TOP BO~OM HOLE SIZE CEME~ING RECORD~ AMOUNT PULLED ,, 16" 62.5~ H-40 Surface 114' 42" 10 cu yds Podland T~e 3 9.625" 36~ J-55 Surface 2821' 12.25" 500 sx AS III LW, 230 sx Cla~ G 7" 26~ L-80 Surface 10771' 8.5" 283 sx Cla~ G 24. Perorations open to Production (MD + TVD of Top and Bo~om and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 9896' 9807' Open hole completion 6.125" OH from 10771' to 13706' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED .... N/A Clkl A I 27. PRODUCTION TEST ~ I ~ [ ~ I ~ ~ ~ L Date First Production Method el Operation (Flowing, gas li~, etc.) Waiting on Facili~ Start-up Date el Test Hours Tested Production for OIL-BBL ~S-MCF WATER-BBL CHOKE SIZE ~GAS-OIL RATIO I Test Pedod > Flow Tubing Casing Pressure Calculated OIL-BBL ~S-MCF WATER-BBL OIL GRAVITY - APl (coif) 24-Hour Rate > 28. CORE DATA Brief description of litholo~, porosi~, fractures, ~parent dips and pressence el oil, gas orwater. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. Alpine D Base Alpine NAME GEOLOGIC MARKERS MEAS. DEPTH 9998' 10531' TRUE VERT. DEPTH 6856' 6957' 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 tree and correct to the best o! my knowledge. G. C. Alvord Title Alpine Drillin.q Team Leader Questions? Call Scott Reynolds 265-6253 INSTRUCTIONS Prepared by Sharon A//sup-Drake 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: 09/08/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-24 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: ALPINE SPUD:04/22/99 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20295-00 04/21/99 (D1) MW: 8.8 VISC: 270 PV/YP: 22/53 APIWL: 12.4 TD/TVD: 0/0 ( 0) DRLG AT 540' SUPV:DONALD LUTRICK/DOUGCHESTER Move rig from CDi-19 to CD1-24. NU diverter system and test. PJSM. UPCOMING OPERATIONS:DRILL 04/22/99 (D2) MW: 9.3 VISC: 150 PV/YP: 24/44 APIWL: 9.6 TD/TVD: 1572/1519 (1572) DRLG AT 2050' SUPV:DONALD LUTRICK/DOUG CHESTER Drilling from 121' to 1162'. Ball mill pump sanded up. Hole tight and swabbing. Pump out from 981' to 713'. Drilling from 1162' to 1572' UPCOMING OPERATIONS:TD WELL 04/23/99 (D3) MW: 9.7 VISC: 118 PV/YP: 24/36 APIWL: 9.7 TD/TVD: 2831/2396 (1259) CIRC AND CONDITION HOLE SUPV:DONALD LUTRICK Drilling from 1572' to 2831' Hole tight and packing off. Back ream from 1200' to 550'. UPCOMING OPERATIONS:POH W/ HO AND RUN CSG. 04/24/99 (D4) TD/TVD: 2831/2396 ( SUPV:DONALD LUTRICK MW: 10.0 VISC: 168 PV/YP: 25/40 0) RIH W/ PORT COLLAR TOOL. APIWL: 0.0 Reamed from 1250' to 1474' Wash and ream from 2756' to 2831' Circ lo/hi vis sweep. Tight and packing off at 1865' Back ream to 1104' Held PJSM. RIH w/9-5/8" casing. UPCOMING OPERATIONS: 04/25/99 (D5) MW: 9.6 VISC: 40 PV/YP: 12/18 APIWL: 10.0 TD/TVD: 2831/2396 ( 0) MU BHA SUPV:DONALD LUTRICK PJSM. Pump cement. No cement to surface. ND diverter. NU BOPE and test to 300/4000 psi. UPCOMING OPERATIONS:CSG TEST AND LOT Date: 09/08/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/26/99 (D6) TD/TVD: 2831/2396 ( SUPV:DONALD LUTRICK MW: 9.7 VISC: 46 PV/YP: 15/15 0) DRLG @ 3800" APIWL: 4.0 Test BOPE to 300/3500 psi. Wash and ream from 2665' to 2731'. Drill out cement and float equipment to 2821'. Drill 20' new hole to 2851' Performed LOT 13.4 EMW. Drilling from 2851' to 3300' Hole packed off while drilling at 3200' due to high ROP in clay section. UPCOMING OPERATIONS:DRILL 04/27/99 (D7) MW: 10.0 VISC: 68 PV/YP: 24/34 TD/TVD: 5001/3736 (2170) DRLG AT 5600' SUPV:DONALD LUTRICK Drilling from 3300' to 5001' UPCOMING OPERATIONS:DRLG - WIPERTRIP APIWL: 4.0 04/28/99 (D8) MW: 10.0 VISC: 54 PV/YP: 16/22 TD/TVD: 6681/4790 (1680) DRILLING AT 7,175' SUPV:MIKE WHITELEY APIWL: 4.0 Drill from 5001' to 5919'. Pump low/high sweeps around. Circ hole clean. Monitor well, hole breathing. Flowed back 5 bbls. Wash 40' to bottom. Drill from 5919' to 6681' Spill and H2S drill. UPCOMING OPERATIONS:DRILL / SHORT TRIP 04/29/99 (D9) MW: 9.9 VISC: 49 PV/YP: 12/33 APIWL: 3.2 TD/TVD: 8108/5700 (1427) DRILLING AHEAD AT 8,500' SUPV:MIKE WHITELEY Drill from 6681'-7822' Circ hole clean. Pump low/high vis sweeps around. Wash 30' to bottom at 7822'. Drill from 7822'-8108' UPCOMING OPERATIONS:DRILL TO 9,680' - TRIP FOR BHA 04/30/99 (D10) MW: 9.9 VISC: 48 PV/YP: 12/29 APIWL: 3.6 TD/TVD: 9630/6672 (1522) POOH FOR BHA CHANGE SUPV:MIKE WHITELEY Drill from 8108' to 9630'. Circ, pump sweeps around, prepare to POOH for BHA change. UPCOMING OPERATIONS:RIH - DRILL 05/01/99 (Dll) MW: 9.8 VISC: 48 PV/YP: 12/32 TD/TVD: 9785/6763 ( 155) DRILLING AT 9960' SUPV:MIKE WHITELEY APIWL: 3.6 Finish circ hole clean. POOH for BHA change. Tight from 9120'-8930'. RIH w/BHA #4. Hole tight and packing off. Wash and ream from 9239' to bottom at 9630'. Drill from 9630'-9785' UPCOMING OPERATIONS:DRILL Date: 09/08/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 05/02/99 (D12) MW: 9.8 VISC: 48 PV/YP: 11/33 APIWL: 4.4 TD/TVD:10511/6955 ( 726) DRILLING AT 10, 785' SUPV:MIKE WHITELEY Drill from 9785'-10785'. Fire and spill drills. UPCOMING OPERATIONS:DRILL TO TD. CIRC CLEAN, SHORT TRIP, CIRC CLEAN, POOH TO RUN 7" CSG 05/03/99 (D13) MW: 9.8 VISC: 48 PV/YP: 12/30 APIWL: 4.4 TD/TVD:10796/6947 (285) RUNNING 7" CSG - 170JTS IN HOLE SUPV:MIKE WHITELEY Drill from 10511' to 10796'. Circ and condition mud for short trip, pump sweeps around. Short trip from 10796'-9176'. PJSM. Run 7" casing. UPCOMING OPERATIONS:SET AND CEMENT 7" CSG 05/04/99 (D14) TD/TVD:10796/6947 ( SUPV:MIKE WHITELEY MW: 9.2 VISC: 26 PV/YP: 0/ 0 APIWL: 0.0 0)FREEZE PROTECT 9 5/8" X 7" CSG / NU BOPS Ran 7" casing to 10787' Hole took 20 bbls while running pipe. Work pipe and attempt to break circ. Hole packed off, pumping into formation at 102 bpm. Swabbing back some returns when moving pipe up. Lost +/- 400 bbls mud. Stuck 7" casing. Worked stuck casing, no movement. PJSM. Pump cement. Casing stuck. Bumped plug. Well flowing back. UPCOMING OPERATIONS:RUN TBG AND FREEZE PROTECT , ND BOP'S, NU TREE 05/05/99 (D15) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:10796/6947 ( 0) RIG RELEASED- BALL MILL RELEASED AT 14:45 HRS SUPV:MIKE WHITELEY WOC. Install 7" pack off and test to 3500 psi. NU BOPs. Freeze protect well. ND BOPs. NU tree and test to 3500 psi. Rig released @ 1530 hrs. 5/5/99. UPCOMING OPERATIONS:MOVE RIG TO CD1-35 07/30/00 (D16) MW: 9.2 VISC: 26 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:10796/6947 ( 0) LD 4 1/2" KILL STRING SUPV:LUTRICK / CUNNINGHAM Move rig from CD1-32 to CD1-24. PJSM. Displace diesel with brine. ND tree. NU BOPE and test to 250/3500 psi. 07/31/00 (D17) MW: 9.2 VISC: 51 PV/YP: 11/23 APIWL: 3.9 TD/TVD:10816/6946 ( 20) RIH W/ DIRECTIONAL BHA SUPV:LUTRICK / CUNNINGHAM Finish test BOPE to 250/3500 psi. PJSM. RIH. Tag up at 10478' Displace well to flo-pro. Wash to top of firm cement at 10612' Drill out cement, float equipment and new formation to 10816'. Circ and condition mud. Perform LOT, 11.0 EMW. POH. Date: 09/08/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 08/01/00 (D18) MW: 9.3 VISC: 47 PV/YP: 11/23 APIWL: 4.3 TD/TVD:l1800/6912 ( 984) DRLG AT 12240' SUPV:DONALD LUTRICK POH. RIH to 10816' Displace well with flo-pro mud. Drilling from 10816' to 11800' 08/02/00 (D19) MW: 9.2 VISC: 48 PV/YP: 11/21 APIWL: 3.8 TD/TVD:13115/6923 (1315) DRILLING AT 13432 SUPV:DONALD LUTRICK Drilled from 11800'-12640' Fire drill/spill drill. Pump lo/high sweep around. Wiper trip, pumped out to 10787'. No problems. RIH to 12640', no problems. Drilled from 12640'-13115'. 08/03/00 (D20) MW: 9.2 VISC: TD/TVD:13706/6952 ( 591) LD BHA SUPV:MIKE WHITELEY 0 PV/YP: 0/ 0 APIWL: 0.0 Drilled from 13115'-13706'. Pump lo/high sweep around and circ clean for wiper trip. Pumped out of hole to 10750'. No problems. RIH. Circ hole clean for brine displacement. Displace hole with brine. Observe well, taking 15 bph brine. POOH to 12170'. Observe well, hole taking 18 bph brine. Spot hi vis LCM pill. POOH to shoe. Observe well, hole taking 6 bph brine. POOH to run tubing. 08/04/00 (D21) TD/TVD:13706/6952 ( SUPV:MIKE WHITELEY MW: 9.2 VISC: 0 PV/YP: 0/ 0 0)PUMPING FREEZE PROTECT DIESEL APIWL: 0.0 RU to run tubing. PJSM. RIH with 4.5" tubing. ND BOP's. NU tree and test to 5000 psi. 08/05/00 (D22) TD/TVD:13706/6952 ( SUPV:MIKE WHITELEY MW: 9.6 VISC: 0 PV/YP: 0/ 0 0) RIG RELEASED AT 08:00 HRS 8-5-2000 APIWL: 0.0 Set packer at 9807'. Test packer/casing to 3500 psi., held. Freeze protect well. Set BPV. Rig release @ 0800 hrs. 8/5/OO. SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-04721 Sidetrack No. Page t of 2 i Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE Well Name & No. CD#1/24 Survey Section Name CD#1-24 MWD BHI Rep. D NEWLON / E BROWN WELL DATA Target TVD (FT) Target Coord, N/S Slot Coord, N/S -386,11 Grid Correction 0,000 Depths Measured From: RKB ~ MSL~ SSE Target Description Target Coord, E/W Slot Coord, E/W 2413,09 Magn, Declination 25,740 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: lOOftr~ 30mE~ lom~ Vert, Sec, Azim, 151,81 Magn, to Map Corr, ' 25,740 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) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 Fr) Drop (-) Left (-) MWD 10727,33 93,88 152,65 . . 6950,46 4660,24 -1474,16 7112,53 TIE IN POINT 01-AUG-00 MWD 10803,00 91,88 151,74 75,67 6946,66 4734,81 -1541,00 7147,78 2,90 -2,64 -1,20 4 3/4" M1XL 1,2 DEG AKO 01 -AUG-00 MWD 10899,00 92,71 153,33 96,00 6942,81 4830,72 -1626,11 7192,02 1,87 0,86 1,66 01 -AUG-00 MWD 10990,00 91,68 149,71 91,00 6939,33 4921,64 -1706,03 7235,37 4,13 -1,13 -3.98 01 -AUG-00 MWD 11085,00 92,23 151,67 95,00 '6936,09 5016,56 -1788,81 7281,85 2,14 0,58 2,06 01 -AUG-00 MWD 11179,00 92,81 149,12 94,00 6931,95 5110,43 -1870,45 7328,24 2,78 0,62 -2,71 ___ 01 -AUG-O0 MWD 11273.00 91,95 148,58 94,00 6928,05 5204,22 -1950,83 7376,82 1,08 -0,91 -0,57 01 -AUG-O0 MWD 11367,00 92,50 150,15 94,00 6924,40 5298,06 -2031,65 7424,68 1,77 0,59 1,67 ...... 01 -AUG-00 MWD 11460,00 91,89 149,12 93,00 6920,84 5390,93 -2111,83 7471,66 1,29 -0,66 -1,11 01 -AUG-00 MWD 11553,01 92,47 150,28 93,01 6917,30 5483,81 -2192,07 7518,55 1,39 0,62 1,25 ....... 01 -AUG-00 MWD 11648,00 90.65 152,83 94,99 6914,71 5578,75 -2275,56 7563,77 3,30 -1,92 2,68 02-AUG-00 MWD 11741,00 91,23 152,69 93,00 6913,19 5671,72 -2358,23 7606,34 0,64 0,62 -0,15 02-AUG-00 MWD 11836,00 90.55 151.17 95.00 6911.71 5766.71 -2442,04 7651.03 1,75 -0,72 -1,60 -- 'T" 02-AUG-00 MWD 11928.00 90,07 151.33 92.00 6911,21 5858,70 -2522,70 7695,28 0,55 -0,52 0,17 · 02-AUG-00 MwD 12024,00 90,65 148,79 96,00 6910,61 5954,65 -2605.88 7743,19 2,71 0,60 -2,65 ... 02-AUG-00 MWD 12117,00 90,86 150,72 93,00 6909,39 6047,57 -2686,21 7790,03 2,09 0,23 2,08 02-AUG-00 MWD 12210,00 91.27 149.33 93,00 6907,66 6140.51 -2766,75 7836.48 1,56 0,44 -1.49 02-AUG-00 MWD 12305.00 91,92 148,36 95.00 6905.01 6235,34 -2848,02 7885.61 1,23 0.68 -1,02 02-AUG-00 MWD 12398.00 89,62 152,02 93,00 6903,76 6328,28 -2928,69 7931,83 4,65 -2,47 3,94 02-AUG-O0 MWD 12493.00 90,24 149,51 95,00 6903,88 6423,25 -3011.58 7978,22 2.72 0,65 -2,64 02-AUG-O0 MWD 12586.00 89,42 148,47 93,00 6904,15 6516.14 -3091.29 8026,13 1,42 -0.88 -1.12 -- 02-AUG-O0 MWD' :12680'00 89'86' 149.65 94.00 6904.75 6610.03 -3171.91 8074.46 1.34 0.47 1.26 02-AUG-00 MWD 12774.00 88.70 149,58 94,00 6905.93 6703.95 -3252.99 8122.00 1.24 -1.23 -0.07 -0-2-~(~3-0 .... -I~V~ ..... i~6'9~00 ..... -87.22-'. 1-4-c~i-3 .......... ~'~i~--- --6-~-09.--.~-----6~.80 -3334.67 8170.39 1.63 -1.56 -0.47 r "' " SURVEY CALCULATION AND FIELD WORKSHEET i ~'r~ I, -= [!-=1 ::~--~ Job No. 0451-04721 Sidetrack No. Page 2 of 2 £4 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE Well Name & No. CD#1/24 Survey Section Name CD#1-24 MWD BHI Rep. D NEWLON / E BROWN J~lll~l=[l~ WELL DATA Target TVD (ET) Target Coord. N/S Slot Coord. N/S -386.11 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[-] SS[~ Target Description Target Coord. E/W Slot Coord. E/W 2413.09 Magn. Declination 25.740 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. 151.81 Magn. to Map Corr. ' 25.740 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) (DD) (DD) (FT) (FT) (FT) (F'r) (Per 100 F'r) Drop (-) Left (-) 02-AUG-00 MWD 12963.00 86.61 153.66 9.4.00 6914.37 6892.63 -3417.05 8215.32 4.86 -0.65 4.82 · 03-AUG-00 MWD 13057.00 87.02 151.54 94.00 6919.59 6986.47 -3500.37 8258.51 2.29 0.44 -2.26 03-AUG-00 MWD 13150.00 87.46 152.96 93.00 6924.07 7079.36 -3582.58 8301.76 1.60 0.47 1.53 03-AUG-00 MWD 13244.00 87.70 152.80 94.00 6928.04 7173.26 -3666.17 8344.57 0.31 0.26 -0.17 03-AUG-00 MWD 13338.00 88.01 152.83 94.00 '6931.56 7267.18 -3749.72 8387.49 0.33 0.33 0.03 03-AUG-00 MWD 13432.00 86.95 152.41 94.00 6935.69 7361.08 -3833.11 8430.67 1.21 -1.13 -0.45 03-AUG-00 MWD 13526.00 87.50 152.59 94.00 6940.24 7454.96 -3916.39 8474.03 0.62 0.59 0.19 03-AUG-00 MWD 13620.00 86.12 151.51 94.00 6945.47 7548.81 -3999.30 8518.02 1.86 -1.47 -1 .t 5 03-AUG-00 MWD 13647.42 86.19 151.70 27.42 6947.31 7576.17 -4023.36 8531.03 0.74 0.26 0.69 , 03-AUG-00 MWD 13706.34 86.19 151.70' 58.92 6951.23 7634.96 -4075.13 8558.90 0.00 0.00 0.00 Projected Data - NO SURVEY , · MWDILWD Log Product Delivery Customer Phillips Alaska Inc Dispatched To: ^OGCC Well No CD1-24 Date Dispatche 13-^ug-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 RECE VED AlaSka 0il & Gas C,c ns. Commission Anchor Jge Received By: ~~_,~ Please sign and return to: Anadrill LWD Division 3940 Arctic Bird, Suite 300 Anchorage, Alaska 99503 rose(~ianchorage.anadrill.slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc. Field .................... : Colville River Well ..................... : CD1-24 API number ............... : 50-103-20295-00 Engineer ................. : R. Whittum Rig: ....................... : Doyon 19 State: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : 0.00 ft DF above permanent ....... : 56.01 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: 151.81 degrees 7-Aug-2000 13:05:48 Page 1 of 10 ORIG1NA[ Spud date ................ : 01 August 00 Last survey date ......... : 03-Aug-00 Total accepted surveys...: 251 MD of first survey ....... : 0.00 ft MD of last survey ........ : 13706.34 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 24-Jul-2000 Magnetic field strength..: 1147.14 HCNT Magnetic dec (+E/W-) ..... : 25.68 degrees Magnetic dip ............. : 80.54 degrees ..... MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.14 HCNT Reference Dip ............ : 80.54 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections ...... Magnetic dec (+E/W-) ..... : 25.74 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.74 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadritl IDEAL ID6 lB 48] RECEIVED AUG 1 8 2000 Alaska 0[[ & G~s Co~s. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 1 0.00 0.00 0.00 2 100.00 0.36 291.93 3 200.00 0.32 290.34 4 300.00 0.39 289.65 5 400.00 0.34 283.22 Course length (ft) 0.00 100.00 100.00 100.00 100.00 6 500.00 1.45 103.48 7 600.00 4.72 103.99 8 700.00 7.11 103.28 9 800.00 9.21 103.16 10 900.00 12.80 104.63 TVD depth (ft) 0.00 100.00 200.00 300.00 399.99 11 950.00 14.77 104.40 12 1000.00 17.07 103.95 13 1050.00 19.49 103.34 14 1100.00 21.72 102.80 15 1150.00 23.20 100.75 7-Aug-2000 13:05:48 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 0.00 0.00 0.00 -0.24 0.12 -0.29 -0.69 0.33 -0.84 -1.15 0.54 -1.43 -1.60 0.73 -2.04 100.00 499.98 -0.96 0.50 -1.09 100.00 599.83 2.65 -0.79 4.13 100.00 699.29 9.51 -3.21 14.15 100.00 798.27 18.90 -6.45 27.96 100.00 896.41 31.72 -11.07 46.48 50.00 944.97 39.80 -14.06 58.01 50.00 993.05 49.03 -17.41 71.31 50.00 1040.52 59.49 -21.11 86.55 50.00 1087.32 71.09 -25.08 103.69 50.00 1133.53 83.35 -28.97 122.39 16 1200.00 23.55 97.19 50.00 17 1250.00 23.47 94.79 50.00 18 1300.00 23.76 94.62 50.00 19 1350.00 24.50 95.40 50.00 20 1400.00 25.32 95.60 50.00 21 1450.00 25.27 95.74 50.00 22 1500.00 25.51 95.95 50.00 23 1550.00 27.94 95.86 50.00 24 1600.00 28.58 95.75 50.00 25 1650.00 29.27 95.33 50.00 1179.43 95.32 -32.06 141.98 1225.28 106.53 -34.14 161.81 1271.09 117.40 -35.78 181.77 1316.72 128.60 -37.57 202.13 1362.07 140.28 -39.59 223.10 1407.28 152.18 -41.70 244.36 1452.45 164.18 -43.88 265.68 1497.10 176.79 -46.19 288.05 1541.14 190.02 -48.59 311.60 1584.90 203.45 -50.92 335.67 Page 2 of 10 26 1700.00 31.10 94.77 50.00 27 1750.00 31.76 94.75 50.00 28 1800.00 33.91 94.35 50.00 29 1850.00 35.63 93.97 50.00 30 1900.00 38.34 93.31 50.00 [(C)2000 Anadrill IDEAL ID6 lB 48] Total At DLS displ Azim (deg/ (ft) (deg) t00f) 0.00 0.00 0.00 0.31 291.93 0.36 0.91 291.44 0.04 1.53 290.84 0.07 2.16 289.61 0.06 1.20 294.48 1.79 4.20 100.85 3.27 14.51 102.78 2.39 28.70 102.99 2.10 47.78 103.40 3.60 Srvy tool type TIP GYRO GYRO GYRO GYRO Tool qual type 59.69 103.62 3.94 73.41 103.72 4.61 89.09 103.70 4.86 106.68 103.60 4.48 125.77 103.32 3.35 GYRO GYRO GYRO GYRO GYRO 145.55 102.72 2.91 165.37 101.91 1.92 185.26 101.14 0.60 205.59 100.53 1.61 226.58 100.06 1.65 GYRO GYRO GYRO GYRO GYRO 247.89 99.68 0.16 269.28 99.38 0.51 291.73 99.11 4.86 315.36 98.86 1.28 339.51 98.63 1.44 GYRO GYRO GYRO GYRO GYRO 1628.12 217.23 -53.13 360.71 364.60 98.38 1670.79 231.41 -55.29 386.69 390.63 98.14 1712.80 246.07 -57.44 413.72 417.69 97.90 1753.87 261.32 -59.51 442.16 446.14 97.67 1793.80 277.18 -61.41 472.17 476.15 97.41 GYRO GYRO GYRO GYRO GYRO 3.70 GYR~ 1.32 GYRO 4.32 GYRO 3.47 GYRO 5.48 GYRO RECEIVED AUG 1 8 OOC Alask~ Oil & Ga, s Co~s. Commission Af~chomge ANADRILL SCHLUMBERGER Survey Report 7-Aug-2000 13:05:48 Page 3 of 10 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 31 1950.00 40.42 93.12 32 2000.00 43.17 93.29 33 2050.00 45.30 93.28 34 2100.00 47.67 93.40 35 2150.00 49.23 94.23 Course length (ft) 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) 1832.45 1869.72 1905.54 1939.97 1973.13 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 293.71 -63.19 503.84 311.07 -65.05 537.11 329.28 -67.05 571.93 348.24 -69.17 608.13 368.07 -71.66 645.46 Total displ (ft) 507.79 541.04 575.85 612.05 649.43 At DLS Srvy Azim (deg/ tool (deg) 100f) type 97.15 4.17 GYRO 96.91 5.50 GYRO 96.69 4.26 GYRO 96.49 4.74 GYRO 96.33 3.36 GYRO Tool qual type 36 2200.00 50.84 95.79 50.00 2005.25 389.06 -75.01 683.63 687.74 37 2250.00 50.91 96.14 50.00 2036.80 410.84 -79.04 722.21 726.52 38 2300.00 51.20 96.62 50.00 2068.23 432.90 -83.36 760.86 765.41 39 2350.00 51.65 97.37 50.00 2099.40 455.43 -88.12 799.66 804.50 40 2400.00 51.39 97.66 50.00 2130.52 478.27 -93.24 838.46 843.63 96.26 4.01 GYRO 96.25 0.56 GYRO 96.25 0.95 GYRO 96.29 1.48 GYRO 96.35 0.69 GYRO 41 2450.00 51.24 97.71 50.00 2161.77 42 2500.00 51.37 97.86 50.00 2193.03 43 2550.00 51.23 98.08 50.00 2224.29 44 2600.00 51.31 98.16 50.00 2255.57 45 2650.00 52.54 98.00 50.00 2286.41 501.14 -98.46 877.14 882.65 524.07 -103.75 915.80 921.66 547.09 -109.16 954.45 960.67 570.19 -114.67 993.06 999.66 593.47 -120.20 1032.03 1039.01 96.40 0.31 GYRO 96.46 0.35 GYRO 96.52 0.44 GYRO 96.59 0.20 GYRO 96.64 2.47 GYRO 46 2700.00 53.08 97.94 50.00 2316.63 47 2750.00 52.26 97.81 50.00 2346.95 48 2800.00 52.30 97.81 50.00 2377.54 49 2850.00 52.25 97.85 50.00 2408.13 50 2900.00 52.33 97.69 50.00 2438.72 616.97 -125.72 1071.48 1078.83 640.38 -131.17 1110.86 1118.58 663.63 -136.54 1150.05 1158.12 686.88 -141.93 1189.22 1197.66 710.11 -147.28 1228.42 1237.21 96.69 1.08 GYRO 96.73 1.65 GYRO 96.77 0.08 GYRO 96.81 0.12 GYRO 96.84 0.30 GYRO 51 2950.00 52.15 97.52 50.00 2469.33 52 3000.00 51.86 97.37 50.00 2500.11 53 3050.00 51.76 97.16 50.00 2531.03 54 3100.00 51.63 97.05 50.00 2562.02 55 3150.00 51.48 96.98 50.00 2593.11 733.23 -152.51 1267.60 1276.74 756.19 -157.62 1306.67 1316.14 778.98 -162.59 1345.65 1355.44 801.65 -167.44 1384.59 1394.67 824.23 -172.22 1423.45 1433.83 96.86 0.45 GYRO 96.88 0.63 GYRO 96.89 0.39 GYRO 96.90 0.31 GYRO 96.90 0.32 GYRO 56 3200.00 51.55 96.94 50.00 2624.22 57 3250.00 51.58 96.88 50.00 2655.30 58 3300.00 51.35 96.85 50.00 2686.45 59 3350.00 51.24 96.85 50.00 2717.72 60 3400.00 51.34 96.87 50.00 2748.99 [(C)2000 Anadrill IDEAL ID6 lB 48] 846.76 -176.97 1462.30 1472.97 869.28 -181.68 1501.18 1512.14 891.75 -186.35 1540.02 1551.25 914.15 -191.01 1578.76 1590.27 936.56 -195.67 1617.49 1629.28 96.90 0.15 GYRO 96.90 0.11 GYRO 96.90 0.46 GYRO 96.90 0.22 GYRO 96.90 0.20 GYRO RECEIVED AUG 1 8 2000 Aiask~ 0[[ & Ga, s Cor~s. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD % depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 61 3450.00 51.22 96.94 50.00 2780.26 62 3500.00 51.31 96.94 50,00 2811.55 63 3550.00 51.11 96.86 50.00 2842,87 64 3600.00 51.03 96.82 50.00 2874.29 65 3650.00 51.06 96.84 50.00 2905.73 7-Aug-2000 13:05:48 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 958.99 -200.36 1656.22 981.43 -205.07 1694.94 1003.83 -2'09.75 1733.63 1026.16 -214.38 1772.25 1048.47 -219.01 1810.85 66 3700.00 50.82 96.90 50.00 2937.23 1070.77 -223.65 1849.40 67 3750.00 50.55 96.86 50.00 2968.91 1093.00 -228.29 1887.80 68 3800.00 50.65 96.88 50.00 3000.65 1115.20 -232.91 1926.16 69 3850.00 52.17 96.88 50.00 3031.84 1137.65 -237.59 1964.96 70 3900.00 52.23 96.95 50.00 3062.48 1160.37 -242.35 2004.18 71 3950.00 52.11 96.87 50.00 3093.15 72 4000.00 51.93 96.72 50.00 3123.92 73 4050.00 51.71 96.60 50.00 3154.82 74 4100.00 51.53 96.44 50.00 3185.87 75 4150.00 51.54 96.53 50.00 3216.97 1183.08 -247.10 2043.39 1205.67 -251.76 2082.52 1228.13 -256.32 2121.56 1250.45 -260.77 2160.50 1272.73 -265.19 2199.40 76 4200.00 52.91 98.11 50.00 3247.60 1295.68 -270.23 2238.59 77 4250.00 53.12 98.65 50.00 3277.68 1319.48 -276.05 2278.11 78 4300.00 52.86 98.80 50.00 3307.78 1343.46 -282.11 2317.57 79 4350.00 52.57 98.95 50.00 3338.06 1367.44 -288.25 2356.88 80 4400.00 52.14 99.04 50.00 3368.60 1391.37 -294.44 2395.98 81 4450.00 51.73 98.87 50.00 3399.43 1415.14 -300.56 2434.87 82 4500.00 51.50 98.67 50.00 3430.48 1438.70 -306.54 2473.60 83 4550.00 51.57 98.63 50.00 3461.58 1462.18 -312.43 2512.31 84 4600.00 51.22 98.50 50.00 3492.78 1485.56 -318.25 2550.94 85 4650.00 51.11 98.37 50.00 3524.13 1508.79 -323.96 2589.47 86 4700.00 51.09 98.29 50.00 3555.53 1531.95 -329.60 2627.97 87 4750.00 51.02 98.18 50.00 3586.96 1555.04 -335.17 2666.46 88 4800.00 53.52 98.08 50.00 3617.55 1578.46 -340.76 2705.60 89 4850.00 53.96 98.06 50.00 3647.12 1602.30 -346.42 2745.52 90 4900.00 54.23 98.07 50.00 3676.45 1626.25 -352.10 2785.62 [(c)2000 Anadrill IDEAL ID6 lB 48] Page 4 of 10 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) 100f) type 1668.30 96.90 0.26 GYRO 1707.30 96.90 0.18 GYRO 1746.27 96.90 0.42 GYRO 1785.17 96.90 0.17 GYRO 1824.05 96.90 0.07 GYRO 1862.87 96.90 0.49 GYRO 1901.56 96.90 0.54 GYRO 1940.19 96.89 0.20 GYRO 1979.27 96.89 3.04 GYRO 2018.78 96.89 0.16 GYRO 2058.27 96.90 0.27 GYRO 2097.68 96.89 0.43 GYRO 2136.99 96.89 0.48 GYRO 2176.18 96.88 0.44 GYRO 2215.33 96.88 0.14 GYRO 2254.85 96.88 3.71 GYRO 2294.77 96.91 0.96 GYRO 2334.68 96.94 0.57 GYRO 2374.44 96.97 0.63 GYRO 2414.00 97.01 0.87 GYRO 2453.35 97.04 0.86 GYRO 2492.52 97.06 0.56 GYRO 2531.66 97.09 0.15 GYRO 2570.72 97.11 0.73 GYRO 2609.66 97.13 0.30 GYRO 2648.56 97.15 0.13 GYRO 2687.44 97.16 0.22 GYRO 2726.98 97.18 5.00 GYRO 2767.2997.190.88 GYRO 2807.789~200[C[i~[DGYRO Anchorage Tool quat type ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD % depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 91 4950.00 53.86 98.04 50.00 3705.80 92 5000.00 53.55 97.93 50.00 3735.40 93 5050.00 53.56 97.38 50.00 3765.10 94 5100.00 53.47 96.13 50.00 3794.84 95 5150.00 53.37 95.91 50.00 3824.63 96 5200.00 53.46 95.92 50.00 3854.43 97 5250.00 53.41 95.93 50.00 3884.22 98 5300.00 53.13 95.82 50.00 3914.12 99 5350.00 53.07 95.72 50.00 3944.14 100 5400.00 53.35 95.74 50.00 3974.09 101 5450.00 53.01 95.65 50.00 4004.05 102 5500.00 52.76 95.59 50.00 4034.22 103 5550.00 51.48 95.72 50.00 4064.92 104 5600.00 50.91 95.74 50.00 4096.26 105 5650.00 50.76 95.72 50.00 4127.83 106 5700.00 50.85 95.73 50.00 4159.43 107 5750.00 50.90 95.81 50.00 4190.98 108 5800.00 50.65 95.52 50.00 4222.60 109 5850.00 50.93 95.39 50.00 4254.21 110 5900.00 50.48 95.05 50.00 4285.88 111 5950.00 50.33 94.82 50.00 4317.74 112 6000.00 50.39 95.70 50.00 4349.64 113 6050.00 50.37 96.39 50.00 4381.53 114 6100.00 50.22 96.34 50.00 4413.47 115 6150.00 50.09 96.36 50.00 4445.50 7-Aug-2000 13:05:48 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 1650.18 -357.77 2825.69 1673.97 -363.37 2865.60 1697.52 -368.73 2905.46 1720.55 -373.46 2945.38 1743.12 -377.67 2985.31 1765.64 -381.80 3025.25 178.8.16 -385.95 3065.19 1810.61 -390.05 3105.06 1832.94 -394.07 3144.84 1855.29 -398.07 3184.68 1877.60 -402.04 3224.51 1899.79 -405.95 3264.19 1921.77 -409.83 3303.46 1943.51 -413.72 3342.23 1965.14 -417.59 3380.80 1986.76 -421.46 3419.36 2008.43 -425.36 3457.95 2030.01 -429.18 3496.49 2051.48 -432.87 3535.06 2072.78 -436.39 3573.59 2093.84 -439.70 3611.98 2115.06 -443.23 3650.32 2136.73 -447.29 3688.62 2158.55 -451.55 3726.85 2180.31 -455.80 3765.00 116 6200.00 49.95 96.25 50.00 4477.63 2202.01 -460.01 3803.09 117 6250.00 49.83 96.05 50.00 4509.84 2223.58 -464.10 3841.11 118 6300.00 50.24 95.72 50.00 4541.96 2245.05 -468.03 3879.23 119 6350.00 50.38 95.59 50.00 4573.89 2266.48 -471.82 3917.51 120 6400.00 50.21 95.51 50.00 4605.83 2287.85 -475.54 3955.80 [(C)2000 Anadrilt IDEAL ID6 lB 48] Page 5 of 10 Total At DLS displ Azim (deg/ (ft) (deg) 100f) 2848.25 97.22 0.74 2888.55 97.23 0.64 2928.77 97.23 0.89 2968.97 97.23 2.02 3009.11 97.21 0.41 Srvy tool type GYRO GYRO GYRO GYRO GYRO 3049.25 97.19 0.18 3089.40 97.18 0.10 3129.46 97.16 0.59 3169.43 97.14 0.20 3209.46 97.12 0.56 GYRO GYRO GYRO GYRO GYRO 32~9.47 97.11 0.70 3289.33 97.09 0.51 3328.78 97.07 2.57 3367.74 97.06 1.14 3406.49 97.04 0.30 GYRO GYRO GYRO GYRO GYRO 3445.23 97.03 0.18 3484.01 97.01 0.16 3522.74 97.00 0.67 3561.46 96.98 0.60 3600.14 96.96 1.04 GYRO GYRO GYRO GYRO GYRO 3638.65 96.94 0.46 3677.13 96.92 1.36 3715.64 96.91 1.06 3754.11 96.91 0.31 3792.49 96.90 0.26 GYRO GYRO GYRO GYRe GYRO 3830.80 96.90 0.33 3869.04 96.89 0.39 3907.36 96.88 0.96 3945.82 96.87 0.34 3984.28 96.85 0.36 RECEIV GYRO GYRO GYRO GYRO GYRO ID AUG 8 """" , "£ T Li L' Alask~ Oil & Gas Co:qs. Commission Tool qual type -- -- -- ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD % depth angle angle length depth - (ft) (deg) (deg)' (ft) (ft) 121 6450.00 50.07 95.45 50.00 4637.88 122 6500.00 49.75 95.43 50.00 4670.08 123 6550.00 49.67 95.40 50.00 4702.41 124 6600.00 49.46 95.29 50.00 4734.84 125 6650.00 49.27 95.33 50.00 4767.40 7-Aug-2000 13:05:48 Vertical Displ Dispt section +N/S- +E/W- (ft) (ft) (ft) 2309.13 -479.21 3994.01 2330.31 -482.83 4032.09 2351.42 -486.43 4070.05 2372.44 -489.98 4107.95 2393.39 -493.49 4145.73 126 6700.00 50.54 95.64 50.00 4799.60 2414.59 -497.15 4183.80 127 6750.00 51.06 95.69 50.00 4831.21 2436.18 -500.97 4222.36 128 6800.00 50.94 95.50 50.00 4862.67 2457.79 -504.76 4261.03 129 6850.00 50.66 95.29 50.00 4894.27 2479.22 -508.40 4299.60 130 6900.00 50.45 95.13 50.00 4926.04 2500.48 -511.91 4338.06 131 6950.00 50.31 94.97 50.00 4957.92 2521.59 -515.30 4376.42 132 7000.00 49.89 94.82 50.00 4990.00 2542.53 -518.57 4414.64 133 7050.00 49.54 94.63 50.00 5022.33 2563.25 -521.72 4452.65 134 7100.00 49.33 94.52 50.00 5054.84 2583.81 -524.75 4490.51 135 7150.00 49.50 94.73 50.00 5087.37 2604.39 -527.81 4528.36 136 7200.00 50.02 95.41 50.00 5119.67 2625.32 -531.18 4566.38 137 7250.00 50.24 95.79 50.00 5151.72 2646.66 -534.93 4604.57 138 7300.00 50.54 96.21 50.00 5183.60 2668.31 -538.95 4642.88 139 7350.00 50.47 96.15 50.00 5215.40 2690.09 -543.11 4681.24 140 7400.00 50.10 96.16 50.00 5247.35 2711.79 -547.23 4719.48 141 7450.00 50.00 97.19 50.00 5279.46 2733.70 -551.69 4757.55 142 7500.00 49.84 97.30 50.00 5311.65 2755.88 -556.51 4795.50 143 7550.00 50.14 97.82 50.00 5343.79 2778.26 -561.55 4833.46 144 7600.00 50.07 97.78 50.00 5375.86 2800.80 -566.75 4871.47 145 7650.00 50.25 98.06 50.00 5407.90 2823.43 -572.04 4909.50 146 7700.00 50.33 97.95 50.00 5439.84 2846.14 -577.40 4947.58 147 7750.00 50.12 97.75 50.00 5471.83 2868.75 -582.65 4985.65 148 7800.00 50.12 97.66 50.00 5503.89 2891.24 -587.79 5023.68 149 7850.00 49.91 97.61 50.00 5536.02 2913.67 -592.88 5061.65 150 7900.00 50.29 97.85 50.00 5568.09 2936.17 -598.04 5099.66 [(c)2000 Anadrilt IDEAL !D6 lB 48] Page 6 of 10 Total At DLS displ Azim (deg/ (ft) (deg) 100f) 4022.65 96.84 0.29 4060.89 96.83 0.64 4099.02 96.82 0.17 4137.06 96.80 0.45 4174.99 96.79 0.38 Srvy tool type GYRO GYRO GYRO GYRO GYRO Tool qual type 4213.23 96.78 2.58 4251.97 96.77 1.04 4290.82 96.76 0.38 4329.56 96.74 0.,65 4368.16 96.73 0.49 GYRO GYRO GYRO GYRO GYRO 4406.65 96.72 0.37 4444.99 96.70 0.87 4483.11 96.68 0.76 4521.07 96.67 0.45 4559.02 96.65 0.47 GYRO GYRO GYRO GYRO GYRO 4597.17 96.64 1.47 4635.54 96.63 0.73 4674.06 96.62 0.88 4712.64 96.62 0.17 4751.10 96.61 0.74 GYRO GYRO GYRO GYRO GYRO 4789.43 96.61 1.59 4827.68 96.62 0.36 4865.97 96.63 1.00 4904.33 96.64 0.15 4942.71 96.65 0.56 GYRO GYRO GYRO GYRO GYRO 4981.16 96.66 5019.58 96.67 5057.95 96.67 5096.25 96.68 5134.60 96.69 R 0.23 GYRO 0.52 GYRO 0.14 GYRO 0.43 GYRO 0.84 GYRO ECEIVED AUG Alaska Oil & Ge, s C.O~s. Commissio,q Ar~choraae ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 15t 7950.00 51.50 97.97 50.00 152 8000.00 51.30 98.09 50.00 153 8050.00 51.24 98.07 50.00 154 8100.00 51.19 98.06 50.00 155 8150.00 50.96 98.04 50.00 7-Aug-2000 13:05:48 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 5599.63 2959.03 -603.38 5138.09 5630.82 2982.12 -608.84 5176.78 5662.10 3005.20 -614.32 5215.40 5693.42 3028.25 -619.79 5253.99 5724.84 3051.24 -625.24 5292.50 156 8200.00 50.70 97.82 50.00 5756.42 3074.09 -630.59 5330.90 157 8250.00 50.63 97.72 50.00 5788.11 3096.80 -635.82 5369.21 158 8300.00 50.35 97.62 50.00 5819.92 3119.40 -640.96 5407.44 159 8350.00 50.17 97.58 50.00 5851.89 3141.88 -646.05 5445.55 160 8400.00 50.09 97.57 50.00 5883.94 3164.31 -651.11 5483.59 161 8450.00 49.90 97.45 50.00 5916.08 3186.66 -656.11 5521.56 162 8500.00 49.78 97.50 50.00 5948.33 3208.94 -661.09 5559.45 163 8550.00 49.62 97.33 50.00 5980.67 3231.14 -666.01 5597.27 164 8600.00 49.43 97.37 50.00 6013.12 3253.25 -670.87 5634.99 165 8650.00 49.25 97.51 50.00 6045.70 3275.35 -675.78 5672.60 166 8700.00 49.55 97.60 50.00 6078.24 3297.52 -680.78 5710.23 167 8750.00 49.39 97.86 50.00 6110.73 3319.82 -685.89 5747.89 168 8800.00 49.19 97.96 50.00 6143.34 3342.15 -691.10 5785.43 169 8850.00 49.39 97.98 50.00 6175.96 3364.51 -696.36 5822.96 170 8900.00 49.92 97.94 50.00 6208.33 3386.99 -701.64 5860.70 171 8950.00 49.68 97.90 50.00 6240.60 3409.50 -706.90 5898.53 172 9000.00 51.13 97.39 50.00 6272.47 3432.05 -712.02 5936.71 173 9050.00 51.39 97.26 50.00 6303.75 3454.71 -716.99 5975.40 174 9100.00 51.03 97.14 50.00 6335.08 3477.28 -721.88 6014.06 175 9150.00 50.83 96.88 50.00 6366.59 3499.66 -726.62 6052.59 176 9200.00 50.54 96.76 50.00 6398.27 3521.85 -731.21 6091.00 177 9250.00 50.39 96.65 50.00 6430.10 3543.91 -735.71 6129.30 178 9300.00 49.90 96.43 50.00 6462.14 3565.78 -740.08 6167.43 179 9350.00 50.07 96.40 50.00 6494.29 3587.53 -744.36 6205.48 180 9400.00 51.05 96.03 50.00 6526.05 3609.34 -748.54 6243.87 [(C)2000 Anadrill IDEAL ID6 lB 48] Page 7 of 10 Total At displ Azim (ft) (deg) 5173.39 96.70 5212.46 96.71 5251,45 96.72 5290.42 96.73 5329.31 96.74 DLS Srvy (deg/ tool 100f) type 2.43 GYRO 0.44 GYRO 0.12 GYRO 0.10 GYRO 0.46 GYRO Tool qual type -- -- -- 5368.06 96.75 5406.73 96.75 5445.30 96.76 5483.74 96.77 5522.11 96.77 0.62 GYRO 0.21 GYRO 0.58 GYRO 0.37 GYRO 0.16 GYRO 5560.41 96.78 5598.62 96.78 5636.75 96.79 5674.78 96.79 5712.71 96.79 0.42 GYRO 0.25 GYRO 0.41 GYRO 0.38 GYRO 0.42 GYRO 5750.67 96.80 5788.67 96.80 5826.56 96.81 5864.45 96.82 5902.55 96.83 0.62 GYRO 0.51 GYRO 0.43 GYRO 0.40 GYRO 1.06 GYRO 5940.74 96.83 5979.26 96.84 6018.26 96.84 6057.23 96.84 6096.05 96.85 0.48 GYRO 3.00 GYRO 0.56 GYRO 0.74 GYRO 0.57 GYRO 6134.73 96.85 6173.29 96.84 6211.68 96.84 6249.97 96.84 6288.58 96.84 0.61 GYRO 0.34 GYRO 1.04 GYRO 0.34 GYRO 2.04 GYRO RECEIVED AUG Alaska Oil & G~s Co~s. Anchorage ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 181 9450.00 50.78 95.98 182 9500.00 50.54 95.96 183 9550.00 50.70 95.91 184 9600.00 50.76 95.85 185 9650.00 51.26 97.92 7-Aug-2000 13:05:48 Course TVD Vertical Displ Displ length depth section +N/S- +E/W- (ft) (ft) (ft) (ft) (ft) 50.00 6557.58 3631.15 -752.60 6282.47 50.00 6589.27 3652.87 -756.62 6320.93 50.00 6621.00 3674.55 -760.62 6359.37 50.00 6652.65 3696.23 -764.59 6397.88 50.00 6684.11 3718.57 -769.25 6436.45 186 9700.00 53.77 103.36 50.00 6714.55 3743.45 -776.60 6475.41 187 9750.00 57.00 108.09 50.00 6742.96 3772.00 -787.78 6514.99 188 9780.00 58.61 110.74 30.00 6758.94 3790.75 -796.22 6538.93 189 9809.50 61.02 114.57 29.50 6773.78 3810.52 -806.05 6562.45 190 9840.25 61.91 117.53 30.75 6788.47 3832.44 -817.91 6586.71 191 9871.75 63.22 119.31 31.50 6802.98 3855.78 -831.22 6611.30 192 9905.75 64.71 122.01 34.00 6817.91 3881.93 -846.80 6637.57 193 9936.85 65.84 122.97 31.10 6830.92 3906.55 -861.97 6661.39 194 9967.15 66.82 124.96 30.30 6843.08 3931.09 -877.48 6684.41 195 10000.53 68.07 126.31 33.38 6855.88 3958.76 -895.44 6709.46 31.49 6867.30 3985.47 -913.24 6732.78 32.14 6878.25 4013.35 -932.30 6756.23 31.11 6888.30 4040.73 -951.33 6778.70 32.43 6898.25 4069.76 -971.97 6801.64 30.52 6906.98 4097.56 -992.19 6822.77 196 10032.02 69.42 128.40 197 10064.16 70.76 129.80 198 10095.27 71.53 130.71 199 10127.70 72.74 133.25 200 10158.22 74.02 134.22 32.49 31.70 31.19 32.04 31.26 201 10190.71 75.62 137.87 202 10222.41 77.24 140.34 203 10253.60 78.76 142.92 204 10285.64 80.76 145.14 205 10316.90 82.69 147.11 32.41 31.56 31.78 31.31 32.25 206 10349.31 84.60 149.52 207 10380.87 86.08 151.37 208 10412.65 86.25 151.57 209 10443.96 86.14 151.73 210 10476.21 86.00 151.82 6915.49 6922.93 6929.41 6935.11 6939.61 6943.20 6945.76 6947.89 6949.97 6952.18 [(c)2000 Anadrill IDEAL ID6 lB 48] -- -- 4127.73 -1014.76 4157.79 -1038.05 4187.81 -1061.97 4219.05 -1087.48 4249.83 -1113.17 6844.53 6864.70 6883.63 6902.15 6919.39 4281.98 -1140.57 4313.42 -1167.94 4345.13 -1195.79 4376.37 -1223.29 4408.55 -1251.64 6936.30 6951.82 6966.96 6981.80 6997.01 Page 8 of 10 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) 100f) type 6327.39 96.83 0.55 GYRO 6366.05 96.83 0.48 GYRO 6404.70 96.82 0.33 GYRO 6443.40 96.81 0.15 GYRO 6482.26 96.82 3.37 GYRO 6521.81 96.84 9.98 GYRO 6562.44 96.89 10.11 GYRO 6587.22 96.94 9.20 GYRO 6611.76 97.00 13.88 MWD 6637.30 97.08 8.94 MWD 6663.34 97.17 6.52 MWD 6691.37 97.27 8.37 MWD 6716.93 97.37 4.59 MWD 6741.76 97.48 6.83 MWD 6768.95 97.60 5.29 MWD 6794.44 97.72 7.53 MWD 6820.26 97.86 5.84 MWD 6845.13 97.99 3.71 MWD 6870.74 98.13 8.34 MWD 6894.54 98.27 5.18 MWD 6919.34 98.43 11.91 MWD 6942.74 98.60 9.14 MWD 6965.07 98.77 9.45 MWD 6987.29 98.95 9.24 MWD 7008.36 99.14 8.78 MWD 7029.45 99.34 9.45 MWD 7049.24 99.54 7.49 MWD 7068.84 99.74 0.82 MWD 7088.15 99.94 0.62 MWD 7108.08 100.14 0.52 MWD RECEIVED ! 8 Alaska Oil & G~$ Cons. Commission Anchorage 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-Axi s 6-Axis 6-Axis 6-Axis 6-Axis 6-Axis 6-Axis 6-Axis ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD % depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 211 10507.13 85.85 151.70 30.92 6954.37 212 10537.82 86.78 152.99 30.69 6956.35 213 10570.44 88.66 152.46 32.62 6957.64 214 10603.04 91.03 152.55 32.60 6957.73 215 10633.89 93.11 153.46 30.85 6956.62 216 10666.75 93.92 152.74 217 10696.97 93.94 152.35 218 10727.33 93.88 152.65 219 10803.00 91.88 151.74 220 10899.00 92.71 153.33 32.86 30.22 30.36 75.67 96.00 221 10990.00 91.68 149.71 222 11085.00 92.23 151.67 223 11179.00 92.81 149.12 224 11273.00 91.95 148.58 225 11367.00 92.50 150.15 91.00 95.00 94.00 94.00 94.00 226 11460.00 91.89 149.12 227 11553.01 92.47 150.28 228 11648.00 90.65 152.83 229 11741.00 91.23 152.69 230 11836.00 90.55 151.17 93.00 93.01 94.99 93.00 95.00 231 11928.00 90.07 151.33 232 12024.00 90.65 148.79 233 12117.00 90.86 150.72 234 12210.00 91.27 149.33 235 12305.00 91.92 148.36 92.00 96.00 93.00 93.00 95.00 236 12398.00 89.62 152.02 237 12493.00 90.24 149.51 238 12586.00 89.42 148.47 239 12680.00 89.86 149.65 240 12774.00 88.70 149.58 93.00 95.00 93.00 94.00 94.00 [(c)2000 Anadrill IDEAL ID6_lB_48] 6954.60 6952.53 6950.46 6946.66 6942.82 6939.33 6936.09 6931.95 6928.05 6924.40 6920.84 6917.30 6914.71 6913.19 6911.71 6911.22 6910.61 6909.39 6907.66 6905.01 6903.76 6903.88 6904.16 6904.75 6905.93 7-Aug-2000 13:05:48 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 4439.39 -1278.81 7011.61 4470.01 -1305.93 7025.82 4502.60 -1334.90 7040.76 4535.20 -1363.82 7055.81 4566.02 -1391.29 7069.80 4598.81 -1420.54 4628.95 -1447.29 4659.24 -1474.16 4734.81 -1541.00 4830.72 -1626.11 Page 9 of 10 4921.63 -1706.02 5016.56 -1788.81 5110.43 -1870.45 5204.22 -1950.83 5298.06 -2031.64 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 7127.27 100.34 0.62 MWD 6-Axis 7146.16 100.53 5.17 MWD 6-Axis 7166.19 100.74 5.99 MWD 6-Axis 7186.41 100.94 7.28 MWD 6-Axis 7205.40 101.13 7.36 MWD 6-Axis 5390.92 -2111.83 5483.80 -2192.07 5578.74 -2275.55 5671.72 -2358.23 5766.70 -2442.04 7084.64 7225.65 101.34 7098.54 7244.58 101.52 7112.53 7263.69 101.71 7147.78 7312.00 102.17 7192.02 7373.56 102.74 5858.70 -2522.70 5954.64 -2605.88 6047.57 -2686.21 6140.51 -2766.75 6235.34 -2848.02 7235.37 7433.78 103.27 7281.85 7498.34 103.80 7328.24 7563.18 104.32 7376.82 7630.41 104.81 7424.68 7697.63 105.30 6328.27 -2928.68 6423.25 -3011.58 6516.13 -3091.28 6610.02 -3171.90 6703.95 -3252.98 7471.66 7764.37 105.78 7518.55 7831.59 106.25 7563.77 7898.66 106.74 7606.33 7963.51 107.23 7651.03 8031.30 107.70 7695.28 8098.23 108.15 7743.19 8169.91 108.60 7790.02 8240.16 109.03 7836.48 8310.55 109.45 7885.61 8384.15 109.86 7931.82 8455.24 110.27 7978.22 8527.69 110.68 8026.13 8600.86 111.06 8074.46 8675.13 111.45 8122.00 8749.21 111.83 3.30 MWD 1.29 MWD 1.01 MWD 2.90 IMP 1.87 IMP 4.13 IMP 2.14 IMP 2.78 IMP 1.08 IMP 1.77 IMP 1.29 IMP 1.39 IMP 3.30 IMP 0.64 IMP 1.75 IMP 0.55 IMP 2.71 IMP 2.09 IMP 1.56 IMP 1.23 IMP RE 4.65 IMP 2.72 IMP 1.42 IMP 1.34 IMP 1.24 IMP CEiVED AUG ! 8 Alaska Oil & Gas Cons. Commission /~nnhnr~rm. 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 7-Aug-2000 13:05:48 Page 10 of 10 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool % depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) i00f) type type 241 12869.00 87.22 149.13 95.00 6909.31 6798.79 -3334.66 8170.39 8824.69 112.20 1.63 IMP 6-axis 242 12963.00 86.61 153.66 94.00 6914.37 6892.63 -3417.05 8215.32 8897.62 112.58 4.86 IMP 6-axis 243 13057.00 87.02 151.54 94.00 6919.59 6986.47 -3500.37 8258.51 8969.70 112.97 2.29 IMP 6-axis 244 13150.00 87.46 152.96 93.00 6924.07 7079.36 -3582.57 8301.76 9041.79 113.34 1.60 IMP 6-axis 245 13244.00 87.70 152.80 94.00 6928.04 7173.26 -3666.16 8344.57 9114.42 113.72 0.31 IMP 6-axis 246 13338.00 88.01 152.83 94.00 6931.56 7267.18 -3749.72 8387.48 9187.51 114.09 0.33 247 13432.00 86.95 152.41 94.00 6935.69 7361.08 -3833.11 8430.67 9261.15 114.45 1.21 248 13526.00 87.50 152.59 94.00 6940.24 7454.96 -3916.39 8474.02 9335.27 114.80 0.62 249 13620.00 86.12 151.51 94.00 6945.47 7548.81 -3999.29 8518.01 9410.15 115.15 1.86 250 13647.42 86.19 151.70 27.42 6947.31 7576.16 -4023.36 8531.02 9432.17 115.25 0.74 IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis Survey Projected to total depth: 251 13706.34 86.19 151.70 58.92 6951.23 7634.95 -4075.12 8558.89 9479.52 115.46 0.00 MWD [(c)2000 Anadrill IDEAL ID6 lB 48] Schlumberger Rig Elevation Form Field: Colville River Well: CD1-24 Rig- Doyon 19 Date: 1-Aug-00 Landing Ring Elevation (from as-built plat): 19.50 ft Actual Rig Height (RT-Landing Ring): 36.51 ft Actual Rig Elevation: 56.01 ft Comments: RT-LR distance provided by rig APl# 50-103-20295-00 AFE# 998B05 Client ................... : ARCO Alaska, Inc. Field .................... : Colville River Well ..................... : CD1-24 API number ............... : 50-103-20295-00 Engineer ................. : Dammeyer Rig: .................... : Doyon 19 State: .................. : Alaska ANADRILL SCHLUMBERGER Survey report Survey calculation methods ..... Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor ...... Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill floor GL above permanent ....... : 19.5 ft KB above permanent ....... : Top Drive DF above permanent ....... : 56.0 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: 99.74 degrees [(c) 1999 Anadrilt IDEAL ID5 0C 01R] 3-May-99 07:11:11 Page 1 of 6 Spud date ................ : 21-Apr-99 Last survey date ......... : 03-May-99 Total accepted surveys...: 138 MD of first survey ....... : 115.00 ft MD of last survey ........ : 10796.00 ft ORIGINAL Geomagnetic data - Magnetic model ........... : BGGM version 1997 Magnetic date ............ : 08-July-1998 Magnetic field strength..: 1144.00 HCNT Magnetic dec (+E/W-) ..... : 26.37 degrees Magnetic dip ............. : 80.49 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.00 HCNT Reference Dip ............ : 80.49 degrees Tolerance of G ........... : (+/-) 3.00 mGal Tolerance of H ........... : (+/-) 7.00 HCNT Tolerance of Dip ......... : (+/-) 0.30 degrees Corrections Magnetic dec (+E/W-) ..... : 26.37 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.37 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 RECEIVED v 1 1 1999 Alaska & Gas Co s. Commi ion Ano om e ~ADRILL SCHLUMBERGER Survey Report 3-May-99 07:11:11 Page 2 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 115.00 0.00 0.0 2 201.15 0.14 312.5 3 291.05 0.21 275.4 4 383.70 0.54 278.1 5 467.79 0.31 129.7 6 7 9 10 11 12 13 14 15 16 17 18 19 20 21 22 i 23 24 25 558.40 3.11 102.4 647.24 5.58 103.5 736.44 7.74 101.3 825.94 10.37 103.6 915.24 13.52 106.8 1003.93 17.31 104.4 1094.16 21.67 104.1 1193.28 23.73 97.3 1285.76 23.87 94.1 1381.05 25.45 97.0 1477.14 25.21 96.1 1569.51 28.45 96.5 1666.09 29.69 96.4 1760.91 32.00 96.1 1856.57 35.93 95.7 1950.91 40.27 95.2 2047.76 45.16 94.3 2142.05 48.71 95.1 2237.74 51.24 96.8 2331.71 52.00 97.9 26 2427.88 51.58 98.0 27 2523.50 51.67 98.5 28 2618.83 51.59 99.5 29 2714.17 53.04 98.6 30 2766.99 52.86 98.3 0.00 86.10 89.90 92.70 84.10 90.60 88.80 89.20 89.50 89.30 88.70 90.30 99.10 92.50 95.30 96.00 92.40 96.60 94.80 95.70 94.30 96.90 94.30 95.60 94.00 96.20 95.60 95.30 95.40 52.80 TVD depth (ft) 115.00 201.10 291.00 383.70 467.80 558.35 646.89 735.48 823.86 911.21 996.71 1081.81 1173.25 1257.88 1344.49 1431.26 1513.71 1598.13 1679.52 1758.88 1833.07 1904.24 1968.62 2030.10 2088.47 2147.97 2207.32 2266.48 2324.80 2356.61 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) (ft) 0.00 0.00 -0.09 0.07 -0.35 0.16 -0.95 0.24 -1.15 0.15 1.52 -0.54 8.23 -2.06 18.57 -4.25 32.63 -7.33 51.01 -12.23 74.46 -18.52 104.49 -25.92 142.67 -32.91 179.89 -36.62 219.54 -40.49 260.54 -45.18 302.17 -49.76 349.02 -55.03 397.54 -60.32 450.87 -65.81 508.88 -71.32 574.34 -76.74 642.96 -82.39 715.99 -90.00 789.61 -99.43 865.17 -109.89 940.09 -120.64 1014.80 -132.33 1090.29 -144.20 1132.42 -150.39 0.00 -0.08 -0.32 -0.92 -1.14 1.45 8.00 18.11 31.85 49.66 72.37 101.57 139.11 176.24 215.80 256.60 298.04 344.68 393.00 446.17 504.08 569.57 638.22 711.02 784.10 858.96 933.13 1006.92 1081.48 1123.16 At DLS Azim (deg/ (deg) 100f) 0.00 0.00 312.50 0.16 296.49 0.14 284.46 0.36 277.43 0.98 0.00 0.11 0.36 0.95 1.15 1.54 8.26 18.60 32.68 51.14 74.71 104.83 142.95 180.00 219.56 260.55 302.17 349.05 397.60 451.00 509.10 574.71 643.51 716.69 790.37 865.96 940.89 1015.58 1091.05 1133.19 110.30 3.13 104.45 2.78 103.21 2.44 102.95 2.97 103.84 3.60 104.35 4.33 104.32 4.83 103.31 3.36 101.74 1.40 100.63 2.09 99.99 0.47 99.48 3.51 99.07 1.28 98.73 2.44 98.39 4.11 98.05 4.61 97.67 5.09 97.36 3.82 97.21 2.98 97.23 1.22 97.29 0.44 97.37 0.42 97.49 0.83 97.59 1.69 97.63 0.57 Srvy tool type TIP MWD M MWD M MWD M -- MWD M MWD M MWD M MWD M MWD M MWD M Tool qual type -- -- -- -- [(c)1999 Anadrill IDEAL ID5 0C 01R] -- ANADRILL SCHLUMBERGER Survey Report 3-May-99 07:11:11 Page 3 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 2902.65 52.16 97.9 32 2997.86 51.96 97.8 33 3093.16 51.68 97.3 34 3189.42 51.68 97.0 35 3285.01 51.33 98.4 36 3378.59 51.19 97.3 37 3473.77 51.25 97.2 'i 38 3569.30 51.10 97.3 ?' 39 3664.81 50.95 97.0 40 3759.80 50.47 96.9 41 3856.07 52.37 97.4 42 3951.01 52.08 96.7 43 4045.99 51.66 96.0 44 4140.82 51.29 96.3 45 4236.65 53.28 99.2 46 4332.26 52.61 98.5 47 4425.25 51.78 99.6 48 4520.50 51.39 99.2 49 4616.15 51.11 98.4 50 4711.14 50.88 99.0 51 4805.85 53.75 99.6 52 4902.80 53.81 99.1 i':: 53 4997.24 53.50 99.1 54 5092.12 53.49 96.8 55 5187.61 53,34 96.6 56 5282.81 53.04 96.7 57 5378.43 53.04 96.0 58 5474.11 52.89 96.0 59 5569.79 50.81 96.1 60 5665.04 50.73 95.4 135.60 95.30 95.30 96.20 95.60 93.60 95.20 95.50 95.50 95.00 96.30 94.90 95.00 94.80 95.80 95.70 93.00 95.20 95.60 95.00 94.80 96.90 94.40 94.90 95.50 95.20 95.60 95.70 95.70 95.20 TVD depth (ft) 2439.14 2497.73 2556.64 2616.29 2675.80 2734.37 2794.00 2853.87 2913.94 2974.10 3034,15 3092.28 3150.94 3209.98 3268.59 3326.26 3383.27 3442.42 3502.26 3562.05 3620.00 3677.26 3733,20 3789,66 3846.58 3903.62 3961.10 4018.74 4077.86 4138.06 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 1239.96 1315.08 1389.94 1465.34 1540.11 1613.07 1687.22 1761.55 1835.72 1909.15 1984.35 2059.28 2133.88 2207.90 2283.62 2359.98 2433.45 2508.04 2582.59 2656.40 2731.41 2809.59 2885.62 2961.85 3038.43 3114.54 3190.79 3267.02 3342.12 3415.69 -165.55 1229.68 -175.82 1304.14 -185.66 1378.40 -195.06 1453.29 -205.08 1527.43 -215.05 1599.75 -224.42 1673.37 -233.80 1747.18 -243.05 1820.84 -251.94 1893.83 -261.32 1968.52 -270.52 2042.96 -278.79 2117.23 -286.73 2190.97 -296.98 2266.04 -308.73 2341.50 -320.28 2414.07 -332.47 2487.66 -343.87 2561.33 -355.04 2634.31 -367.17 2708.34 -379.87 2785.47 -391.90 2860.55 -402.44 2936.09 -411.39 3012.25 -420.22 3087.96 -428.67 3163.88 -436.65 3239.85 -444.58 3314.69 -451.97 3388.06 1240.78 1315.93 1390.85 1466.32 1541.14 97.67 97.68 97.67 97.64 97.65 1614.14 1688.35 1762.75 1836.99 1910.51 97.66 97.64 97.62 97.60 97.58 1985.79 2060.80 2135.51 2209.65 2285.42 97.56 97.54 97.50 97.46 97.47 2361.77 2435.22 2509.77 2584.31 2658.13 97.51 97.56 97.61 97.65 97.68 2733.11 2811.25 2887.27 2963.54 3040.21 97.72 97.77 97.80 97.80 97.78 3116.42 3192.78 3269.14 3344.37 3418.07 97.75 97.72 97.68 97.64 97.60 0.57 0.23 0.51 0.24 1.20 0.93 0.10 0.18 0.29 0.51 2.01 0.66 0.73 0.46 3.17 0.91 1.29 0.53 0.72 0.55 3.07 0.42 0.33 1.95 0.23 0.33 0.59 0.16 2.18 0.58 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 I~D 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 [ (c)1999 Anadrill IDEAL ID5 0C 01R] -- __ ANADRILL SCHLUMBERGER Survey Report 3-May-99 07:11:11 Page 4 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 5760.57 50.79 94.9 95.60 62 5854.17 50.36 94.2 93.60 63 5950.50 50.26 94.7 96.30 64 6045.73 50.26 96.2 95.20 65 6139.26 50.03 96.7 93.60 66 6234.04 49.71 96.5 94.70 67 6330.64 50.41 96.2 96.60 ! 68 6424.65 50.15 95.6 94.00 69 6520.13 49.63 95.4 95.50 70 6615.69 49.19 95.8 95.60 71 6709.89 51.30 96.5 94.20 72 6805.13 50.78 96.1 95.20 73 6901.66 50.39 96.0 96.60 74 6996.45 49.96 95.2 94.80 75 7091.25 49.33 94.9 94.80 76 7186.99 50.13 96.0 95.70 77 7282.99 50.68 96.2 96.00 78 7377.77 50.18 95.3 94.80 79 7472.86 49.81 96.9 95.10 80 7567.74 50.15 97.4 94.80 81 7663.58 50.31 97.6 95.90 82 7757.21 50.11 97.1 93.60 ! 83 7853.01 49.85 97.7 95.80 84 7946.75 51.34 99.1 93.70 85 8043.24 51.27 100.0 96.50 86 8138.56 51.04 98.9 95.40 87 8233.74 50.62 97.7 95.10 88 8329.35 50.14 97.7 95.70 89 8423.33 49.96 97.4 93.90 90 8518.01 49.79 97.3 94.70 TVD depth (ft) 4198.54 4257.98 4319.48 4380.35 4440.33 4501.37 4563.38 4623.45 4684.98 4747.18 4807.42 4867.28 4928.61 4989.33 5050.71 5112.57 5173.76 5234.15 5295.28 5356.25 5417.59 5477.50 5539.10 5598.58 5658.91 5718.75 5778.82 5839.85 5900.14 5961.17 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 3489.49 3561.49 3635.28 3708.28 3780.01 3852.31 3926.24 3998.38 4071.22 4143.63 4215.90 4289.80 4364.27 4436.89 4508.89 4581.70 4655.52 4728.42 4801.12 4873.64 4947.29 5019.15 5092.46 5164.83 5240.15 5314.45 5388.15 5461.82 5533.75 5606.10 -458.62 3461.80 -464.35 3533.87 -470.10 3607.75 -477.06 3680.62 -485.13 3752.02 -493.45 3823.95 -501.64 3897.56 -509.07 3969.48 -516.07 4042.18 -523.16 4114.43 -530.92 4186.43 -539.05 4260.01 -546.91 4334.22 -554.02 4406.68 -560.38 4478.64 -567.32 4551.33 -575.18 4624.88 -582.50 4697.59 -590.24 4770.02 -599.28 4842.05 -608.90 4915.13 -618.10 4986.46 -627.55 5059.22 -638.13 5130.83 -650.63 5205.10 -662.83 5278.40 -673.47 5351.35 -683.35 5424.40 -692.81 5495.76 -702.07 5567.58 3492.05 3564.25 3638.25 3711.41 3783.26 3855.66 3929.71 4001.99 4074.99 4147.56 4219.96 4293.98 4368.59 4441.37 4513.56 4586.55 4660.51 4733.57 4806.40 4879.00 4952.70 5024.62 5097.99 5170.36 5245.61 5319.85 5393.56 5467.27 5539.26 5611.67 97.55 97.49 97.42 97.39 97.37 97.35 97.33 97.31 97.28 97.25 97.23 97.21 97.19 97.17 97.13 97.11 97.09 97.07 97.05 97.06 97.06 97.07 97.07 97.09 97.12 97.16 97.17 97.18 97.18 97.19 0.41 0.74 0.41 1.21 0.48 0.37 0.76 0.56 0.57 0.56 2.31 0.64 0.41 0.79 0.71 1.21 0.59 0.90 1.35 0.54 0.23 0.46 0.55 1.97 0.73 0.93 1.07 0.50 0.31 0.20 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 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 [(c)1999 Anadrill IDEAL ID5 0C 01R] ANADRILL SCHLUMBERGER Survey Report 3-May-99 07:11:11 Page 5 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 8613.19 49.36 97.4 92 8708.57 49.53 97.1 93 8804.66 49.06 97.6 94 8899.08 49.79 98.0 95 8994.55 51.22 97.6 96 9089.50 50.84 97.6 97 9184.48 50.49 97.3 ~ 98 9280.95 49.94 96.8 99 9375.42 51.02 96.7 100 9471.43 50.57 96.3 101 9566.26 50.51 97.3 102 9617.90 50.13 97.2 103 9650.28 51.25 99.1 104 9681.03 52.82 102.0 105 9713.52 55.00 106.5 106 9745.76 56.95 109.0 107 9775.96 58.89 112.2 108 9809.50 61.02 114.6 109 9840.25 61.91 117.5 110 9871.75 63.22 119.3 111 9905.75 64.71 122.0 112 9936.85 65.84 123.0 9113 9967.15 66.82 125.0 114 10000.53 68.07 126.3 115 10032.02 69.42 128.4 116 10064.16 70.76 129.8 117 10095.27 71.53 130.7 118 10127.70 72.74 133.2 119 10158.22 74.02 134.2 120 10190.71 75.62 137.9 95.20 95.40 96.10 94.40 95.40 95.00 95.00 96.50 94.40 96.00 94.90 51.60 32.40 30.70 32.50 32.30 30.20 33.50 30.80 31.40 34.00 31.10 30.30 33.40 31.50 32.20 31.10 32.40 30.50 32.50 TVD depth (ft) 6022.90 6084.93 6147.60 6209.00 6269.68 6329.43 6389.64 6451.39 6511.46 6572.14 6632.46 6665.40 6685.93 6704.82 6723.97 6742.04 6758.08 6774.86 6789.57 6804.04 6818.97 6831.97 6844.14 6856.95 6868.37 6879.34 6889.39 6899.33 6908.05 6916.57 Vertical Displ Displ Total At section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (deg) 5678.51 -711.34 5639.45 5750.92 -720.49 5711.36 5823.71 -729.81 5783.61 5895.37 -739.54 5854.65 5968.94 -749.53 5927.58 6042.75 -759.30 6000.79 6116.17 -768.83 6073.65 6190.24 -777.93 6147.24 6262.96 -786.49 6219.56 6337.23 -794.91 6293.47 6410.41 -803.58 6366.22 6450.08 -808.60 6405.62 6475.14 -812.15 6430.43 6499.33 -816.59 6454.22 6525.50 -823.06 6479.66 6552.00 -831.23 6505.15 6577.13 -840.24 6529.09 6605.30 -851.76 6555.70 6631.26 -863.64 6580.00 6657.66 -876.90 6604.51 6686.20 -892.47 6630.79 6712.24 -907.65 6654.61 6737.54 -923.17 6677.61 6765.28 -941.15 6702.68 6791.29 -958.96 6726.01 6817.68 -978.05 6749.50 6843.03 -997.07 6771.97 6869.12 -1017.68 6794.90 6893.36 -1037.88 6816.02 6918.63 -1060.46 6837.79 5684.14 5756.62 5829.47 5901.17 5974.78 6048.64 6122.12 6196.27 6269.09 6343.47 6416.74 6456.45 6481.51 6505.67 6531.72 6558.04 6582.93 6610.80 6636.44 6662.47 6690.58 6716.23 6741.13 6768.43 6794.03 6820.00 6844.97 6870.68 6894.59 6919.53 97.19 97.19 97.19 97.20 97.21 97.21 97.21 97.21 97.21 97.20 97.19 97.19 97.20 97.21 97.24 97.28 97.33 97.40 97.48 97.56 97.67 97.77 97.87 97.99 98.11 98.25 98.38 98.52 98.66 98.82 DLS (deg/ iOOf) 0.46 0,30 0.63 0.84 1.53 0.40 0.44 0.70 1.15 0.57 0.82 0.75 5.70 9.03 13.04 8.81 11.04 8.88 8.76 6.58 8.37 4.66 6.86 5.19 7.55 5.83 3.69 8.24 5.24 12.04 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-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 [(c)1999 Anadrill IDEAL ID5 0C 01R] __ -- ANADRILL SCHLUMBERGER Survey Report 3-May-99 07:11:11 Page 6 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 10222.41 77.24 140.3 31.70 122 10253.60 78.76 142.9 31.20 123 10285.64 80.76 145.1 32.00 124 10316.90 82.69 147.1 31.30 125 10349.31 84.60 149.5 32.40 126 10380.87 86.08 151.4 31.60 127 10412.65 86.25 151.6 31.80 128 10443.96 86.14 151.7 31.30 129 10476.21 86.00 151.8 32.20 130 10507.13 85.85 151.7 30.90 131 10537.82 86.78 153.0 30.70 132 10570.44 88.66 152.5 32.60 133 10603.04 91.03 152.5 32.60 134 10633.89 93.11 153.5 30.90 135 10666.75 93.92 152.7 32.90 136 10696,97 93.94 152.4 30.20 137 10727.33 93.88 152.6 30.30 Final survey projected to TD 138 10796.00 93.88 152.6 68.70 TVD depth (ft) 6924.00 6930.49 6936.18 6940.69 6944.27 6946.84 6948.97 6951.04 6953.25 6955.45 6957.42 6958.72 6958.81 6957.69 6955.67 6953.60 6951.54 6946.89 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) ('ft) 6942.45 -1083.75 6965.18 -1107.66 6987.72 -1133.14 7009.10 -1158.84 7030.41 -1186.24 6857.96 6876.91 6895.42 6912.69 6929.61 7050.35 -1213.63 7069.99 -1241.52 7089.25 -1269.00 7109.03 -1297.30 7128.00 -1324.45 6945. 6960. 6975. 6990. 7004. At Azim (deg) 98.98 99.15 99.33 99.52 99.71 7146.60 -1351.59 7166.20 -1380.55 7185.93 -1409.46 7204.40 -1436.97 7223.99 -1466.26 6943.06 6965.54 6987.90 7009.15 7030.41 14 7050.38 99.91 28 7070.14 100.11 11 7089.61 100.31 31 7109.67 100.51 90 7129.01 100.71 7019.12 7148.06 100.90 7034.03 7168.23 101.10 7049.08 7188.61 101.31 7063.10 7207.80 101.50 7077.96 7228.24 101.70 7242.20 -1492.99 7091.85 7260.50 -1519.81 7105.81 7301.88 -1580.66 7137.35 DLS (deg/ 100f) 8.96 9.50 9.21 8.83 9.43 7.61 0.82 0.47 0.53 0.58 5.20 5.97 7.27 7.47 3.46 7247.30 101.89 0.99 7266.52 102.07 0.69 7310.28 102.49 0.00 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD M 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-axis ~i [(c)1999 Anadrill IDEAL ID5 0C 01R] -- -- 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 _ Change approved program _X Pull tubing _ Variance _ Perforate _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 387' FNL, 2412' FWL, Sec.5, T11 N, R5E, UM At target (Top Alpine)) 1770' FNL, 1103' FEL, Sec.4, T11 N, R5E, UM At effective depth At REVISED total depth 2630' FSL, 2167' FWL, Sec.10, T11 N, R5E, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service __ Other _ Annular Injection per APD requested new TD 6. Datum elevation (DF or KB feet) RKB 56' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-24 9. Permit number / approval number 199-026 10. APl number 50-103-20295-00 11. Field / Pool Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured 10796 feet true vertical 6947 feet Effective depth: measured 10715 feet landing collar in 7" casing. true vertical 6952 feet Casing Length Size Cemented Conductor 77' 16" 10 cu.yds, Portland Type 3 Surface 2784' 9.625" 500 sx ASL3, 230 sx Class G Production 10736' 7" 283 sx Class G Measured Depth True vertical Depth 114 114 2821' 2389' 10771' 6949' Per the attached memo. CD1-24 has been temporarily suspended at the 7" casing point. It is requested that the horizontal section be extended past the point proposed in the original APD. In addition, the proposed completion plan has been altered to reflect curren~,~i ~,~¢~ r, i% ~ [i=~, completion practices as opposed to what was envisaged at the time of writing the permit. The new TD coordinates for the well will be as indicated above. ~3(,az~,..~,~ c.~',,,,.~ o,,t 0RIG ,JUL 0 6 2000 Alaska 0it & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal _ i 14. Estimated date for commencing operation August 1,2000 6. If proposal was verbally approved Name of approver Date approved Detailed operations program BOP sketch _ I15. Status of well classification as: Oil X Gas __ Service _ Suspended 17. I hereby certify th,,~t the foregoing is true and correct to the best of my knowledge. Signed ~ ~' .,, _._._,Tj,tJe: Drilling Team Leader /7 - FOR COMMISSION USE ONLY Conditions of approt~l: Notify Commission so representative may witness Plug integrity _ BOP Test ~ Location clearance _ Mechanical Integrity Test _ Subsequent form required 10- J~O ~ ORIGINAL SIGNP--b : Approved by order of the Commission O Taylor Seamou¢ Date IAppr°val,,~O" I rz~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE . , . . 7. 8. 9. 10. 11. 12. 13. 14. Note: CD1-24 Program ,..utline (Production Hole and Com~..don Operations) Move on Doyon 19. Circulate out the diesel freeze protection from the well. Install the 2-way check. Remove tubing head adapter assembly. Install BOPE. Pressure test BOPE to 3500 psi. Recover the 2-way check. Remove the tubing hanger and lay down the tubing kill string. Make up a mill tooth bit / slick clean out assembly, RIH and tag up on the float collar at 10715'. Displace the well to 9.2 ppg 'clean out' mud. Pressure test casing to 3500 psi / 30 mins. Drill out the float equipment and 20' of new formation. Perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off to drill ahead is 11.5 ppg EMW. Displace the well to 9.2 ppg FIo-Pro drill in fluid. POH. M/U and run the drilling assembly. Drill 6 1/8" horizontal section to well TD at 17593' MD / 6931' TVD. Displace the well to 9.2 ppg brine and pull out of hole. Run 4 1~, 12.6 #, L-80 tubing with S-3 packer, gas lift mandrels (bottom with DCK-2 shear valve, others with dummy valves), BAL-O ported SSSV nipple (packing sleeve installed) and control line. M/U hanger and pressure test the control line to 5000 psi. Land hanger. Back out landing joint. Install 2-way check with rods. M/U landing joint and test hanger seals to 5000 psi. Nipple down BOP. Install wellhead adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2-way check with lubricator, Drop RHC ball and set packer. Test tubing to 3500 psi / 30 rains. Test casing annulus to 3500 psi / 30 rains. (hold 2500 psi tubing pressure to avoid shearing out the DCK-2 valve). Bleed off tubing pressure to shear out the DCK-2 valve. Circulate in 9.6 ppg inhibited brine and sufficient diesel to fill the tubing to the lowermost gas lift mandrel plus provide 2000' TVD of diesel freeze protection on the annulus. Set BPV and secure well. Move rig off. A slickline unit will return to the well to remove the packing sleeve and RHC nipple prior to preparing the well for production. This will be done after the rig moves off location. Colville River Fie~.. CD1-24 Temporary Suspension Schematic Wellhead installed with tubing hanger pressure tested to 3500 psi , No BPV installed (removed during wellwork) 4-1/2" tubing kill string run to 1626' Diesel Freeze Protection in casing and tubing to 1626'. 16" Conductor to 114' 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2821' MD / 2389' TVD cemented to surface 10.0 + ppg drilling mud in annulus r 9.2 ppg brine Updated 9/20/99 TOC at +/- 9650' MD (from CBL) ,~, '~ ;.0 3500 psi 7" 26 ppf L-80 R3 BTC-Mod Production Casing at 10771' MD / 6949' TVD @ 94 deg Colville River Field CD1-24 Production Well Completion Plan 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID)at 1700' TVD = 1785 MD ' Isolation Sleeve with DB-6 No-Go Lock (3.812" OD)run in profile ',, SINGLE 1/4" x 0.049" s/s control lines 9'5/8 36 ppf J-55 BTC surface casing @ 2821' MD / 2389' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch WRDP-2 SSSV (2.125"1D) w/DB- 6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod. R._~.3 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" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ +/- 2000 psi set 1~ joint~above the X landing nipple Baker 83 Packer at +/- 9836' TOC at 9650' MD (from CBL Icg) Tubing Supended with diesel to lowest GLM Completion MD TVD Tubing Hanger 35' 35' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1785' 1700' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4452' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 7324' 5200' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 9750' 6744' 4-1/2" tubing joint (1) HES "X" (3.813" ID) 9795' 6768' 4-1/2" tubing joint (1) S3 Packer (c/w handling pups) 9836' 6788' 4-1/2" tubing joint (1) HES "XN" (3.725" ID) 9889' 6812' 4-1/2" 10' pup joint WEG (+/- 65 deg) 9900' 6817' Run 1 per joint Weatherford thermal centralizers between 4500' TVD (=6233' MD) and 2821' MD (approx. 85 in total). Well TD at 17593' MD / 6931' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 10771' MD / 6949' TVD @ 94 deg PHILLIPS Alaska, Inc. Sfruoture: CD#1 Well: 24 Field : Alpine Field Looafion :Norfh Slope, Alaska 8OO 1200 16OO 2000 2400 2800 3200 3600 (l) 4000 -+-- 4400 0 4800 I v 5200 5600 6000 6400 68O0 7200 7600 8000 Easf (feet) -> 6000 6400 6800 7200 7600 8000 8400 8800 9200 9600 10000 10400 10800 11200 I I I I I I I I I I I I 6950 Tie-In / KOP Begin Angle Drop End Angle Drop [9CD1-24 INTERM PT LOCATION: 1045' FSL, 202' FWL SEC___.__&. $, T11N, R5E 48 · I , I I I I I I I TgL - InLrmd Pt End Final Drop I ~ I I I 6906 CD1-24 TD LOCATION: 2630' FSL, 2167' FWL SEC. 10, T11N, R5E Tgt- TD 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 6000 6400 6800 7200 7600 8000 8400 8800 9200 9600 10000 10400 10800 11200 800 1200 1600 2000 2400 2800 3200 5600 0 4000 ~- 4400 ~ 4800 I v 5200 5600 6000 6400 6800 7200 7600 8000 East (feet) -> c.,ot~ b~ ~e~ For: B Roberteon Dote plotted: 50-Jun-2000 13~[ Referer~ ;e CD1-24 Ve,'alon Co~rdinetes are [n feet reference s~ ~24. True Vat,col ~ths ore r~ere~e RKB (~ ~19). 1PHILLIPS Alaska, Inc. Structure : CD#! Well : 24 Field : Alpine Field Location: Norfh Slope, Alaska 151 .§ 1 AZIMUTH 11524' (TO TD) ***Plane of Proposal*** 5950- 6300 6650 7000 7550 TANGENT ANGLE FINAL ANGLE 90.41 DEG ~'~o~ 89.71 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 i i i i i i i i i i i i i i i i ! i 5850 4200 4550 4900 5250 5600 5950 6,:300 6650 7000 7550 7700 8050 8400 8750 91 O0 9450 9800 10150 10500 10850 11200 11550 11900 Verficol Section (feel) -> Azimufh 151.81 wifh reference 0.00 S, 0.00 W from sial #24 c~ted b~ b,~c~ For: B Rober[son Dote plotted: ~O-Jon-2OO0 Plot Ref~ ia CDI-24 V~n ~5. C~rdinutes ute in f~ r~er~ s~t ~24. True Verti~l ~ths ore r~ere~e RKB (~yon PHILLIPS Alaska, Inc. Sfructure : CD#I Field : Alpine Field Well : 24 Lo=(sfion: Norfh Slope, Alesko PROFILE Point MD Inc Tie-In / KOP 10796.00 95.88 Begin Angle Drop 10900.00 93.88 End Angle Drop 11251.49 90.41 Tgt- Intrmd Pt 15405.45 90.41 End Final Drop 15479.74 89.71 COMMENT DATA Dir TVD North East 152.60 6945.46 -1555.07 7144.14 152.60 6958.45 -1627.19 7191.90 152.06 6925.28 -1938.22 7354.98 152.06 6910.00 -3841.08 8564.14 151.81 6909.95 -3906.64 8599.08 V. Sect Deg/lO0 4727.47 0.00 4851.22 0.00 51 82.4O 1.00 7556.28 0.00 741 0.57 1.00 Tgt - TD 17595.01 89.71 151.81 6951.00 -7532.09 1 0341.93 11523.79 0.00 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 05, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Change the Well Program: CD1-247 Permit No. 199-26~ APl No. 50-103-20295 Dear Sirs: Phillips Alaska, Inc. hereby requests approval to modify the program on production well CD1-24. These modifications relate to: a. b, An extension of the length of the horizontal section over what was originally proposed. The new planned bottom hole location is 2630' FSL, 2167' FWL, Sec 10, T11N, R5E. A modified completion configuration. This reflects current completion practices as opposed to what was envisaged at the time the permit was submitted. Please find attached form 10-403 plus the following information: a. An outline program. A suspension schematic showing the current well status. A proposed final completion drawing. Directional drilling information. The well is presently suspended with 7" casing set in the Alpine reservoir at 10771' MD / 6949' TVD. It is estimated that the well will be re-entered around 1 August 2000. Well construction operations will then re-commence and the horizontal production section will be drilled prior to running a 4-1/2" gas lift completion. 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. CD1-24 Well File Sharon AIIsup-Drake Doug Chester Mike Erwin G racie Stefanescu ATO-1054 ANO-382 ANO-383 Anadarko Scblmberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 12928 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 11/12/99 Field: Alpine lq~,· o 2 m $ iq~ .oq~ Color Well Job # Log Description Date BL Sepia Prints CD CD1-24(REPROCESSED) LA[(... 99215 CDZ~/ADN (mDC) -~ ~'~ 0 990503 1 CD1-24 (REPROCESSED) j 99215 ADN 990503 I 1 CD1-24 (REPROCESSED)~ 99215 ADN ~D 990503 I 1 CD1-40 (REPROCESSED) 99251 ~/cD~ (~) ~ ~'~ 990527 1 CD1-40 (REPROCESSED) 99251 ~ 990527 I 1 CD1-40 (REPROCESSED) 99251 ~ ~ 990527 I 1 CD1-01 (~PROCESSED) 99286 CDR/ADN (PDC) ~ ~~ 990626 1 CD1-01 (~PROCESSED) 99286 ADN 990626 1 1 lCD1-01 (~PROCESSED) 99286 ADN TVD 990626 I 1 CD1-13 99403 SCMT 991001 1 .~. '~ ~ '~ ~ ~. ~ ,~ ~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Re: Colville River Unit CD 1-24, Pe...perwork P ~e~'uired for Work Stoppage Subject: Re: ColviHe River Unit CD1-24, Permit No. 99-26, AP1 No. 50-103 -20295 RE: Clarification of Paperwork Required for Work Stoppage Date: Thu, 16 Sep 1999 15:34:35 -0900 From: "Brian Robertson" <B ROBERT4~mail.aai.arco.com> To: Blair Wondzell <blair_wondzell~admin. state.ak.us> CC: "Sharon Allsup-Drake" <SALLSUP~mail.aai.arco.com>, "Douglas K Chester" <DCHESTER~mail.aai.arco.com> Further to your clarification e-mail dated 09/02/99, the suspension details for well CD1-24 are as follows: A. There were both logistical and reservoir damage avoidance reasons for not drilling the horizontal / reservoir section of the well upon the initial rig visit. It was deemed better to suspend the well at the 7" casing point and incur the cost of a move back to the well than leave the reservoir open to wellbore fluid for what would be in excess of 1 year before start up. B. CD1-24 was spudded on 21 April 1999. Rig release date was 05 May 1999. C. Well TD (at intermediate casing point) was 10796' MD / 6947' TVD. D. 7" casing depth was 10771' MD / 6949' TVD. Casing was pressure tested to 3500 psi on plug bump. Floats held. E. 9-5/8" x 7" casing was flushed with 150 bbls of fresh water followed by 50 bbls of diesel to freeze protect to 1600' MD. F. 4-1/2" tubing inner string was run to 1626' and landed off on a tubing hanger. The tubing and tubing / casing annulus were freeze protected to 1626'. A BPV was set in the casing hanger profile. G. The expected date for moving back on to the well is June 2000. At this point the 7" casing will be drilled out and the horizontal section drilled prior to the well being completed (as per the permit submission). If you require further information on this well, please respond to this e-mail or call me on 265-6034. Regards Brian Robertson - Drilling Eng. - Alpine Project. 1 of 1 9/17/99 8:08 AM Re: Colville River Unit CD 1-24, Pe...perworkmequired for Work Stoppage Subject: Re: Colville River Unit CD1-24, Permit No. 99-26, AP1 No. 50-103-20295 Clarification of Paperwork Required for Work Stoppage Date: Thu, 02 Sep 1999 14:44:07 -0800 From: Blair Wondzell <blair_wondzell~admin. state.ak.us> Organization: State ofAlaska, Dept of Admin, Oil & Gas To: Brian Robertson <BROBERT4~mail.aai.arco.com> Brian, I pulled the CD1-24 well file and noted that Step 9 "Suspend well and move off rig." and Step 10 "Move in rig. Install and test BOPE to 3500 psi." There are no reasons for moving off and back on nor are there dates, or events. For these wells we would like to see an E-mail, fax, or equivalent for each well immediately after suspension that provides the following information: 1. Spud date and suspend date. 2. Condition of well, e.g., 7" csg was run and cemented at __' and will not be drilled out; freeze protected annulus to ' with . 2. Event and approximate date for move back in for completion. (e.g., prior to start up in June 2000 is ok). Brian, this would be about the easiest way to have our files reflect well conditions. When you are ready to enter and complete the wells, you could notify us by E-mail of a single well or a schedule of wells. If you want to discuss, please call me at 279-1433 ext 226. Thanks, Blair 9/2/99 Brian Robertson wrote: > Blair, > > Referencing our discussion this morning. Attached is a copy of an e-mail that > doug Chester sent previously. > Regards > > Brian. > Forwarded by Brian Robertson/AAI/ARCO on 09/02/99 12:19 >PM > > Douglas K Chester > 07/29/99 03:39 PM > > To: blair wondzell@admin.state.ak.us -- > cc: (bcc: Brian Robertson/AAI/ARCO) > Subject: Colville River Unit CD1-24, Permit No. 99-26, API No. 50-103-20295 > RE: Clarification of Paperwork Required for Work Stoppage > > Mr. Wondzell, > > Currently the CD1-24 well is closed in after running and cementing the 7" > intermediate casing per plan submitted to the AOGCC by form 10-401. The well > was secured with plans to drill the productive interval and complete the well > before production facility start-up in June 2000. ARCO Alaska Inc. requests > clarification on what paperwork is required to satisfy the AOGCC's requirements > without creating unnecessary paperwork. Currently ARCO Alaska Inc. has two > additional wells with this same status: CD1-35 and CD1-40. > > ARCO Alaska Inc. sees three possible options: > 1) Submit a 10-403 with suspended status and revise upon well completion in > March of 2000. > 2) Submit a 10-404 now and then submit a 10-403 upon well completion in March > of 2000 referencing any redundant data submitted with the 10-404. > 3) No paperwork required at this time because the plan submitted and approved > in the permit has not changed. > 1 of 2 9/2/99 2:51 PM ~,Re: Colville River Unit CD 1-24, Pe...perwork.nequired for Work Stoppage We would propose option number 3 as the scope is consistent with the approved permit. This would help reduce the amount of paperwork for both organizations, which would be a positive result. ARCO Alaska Inc. will be happy to supply any additional information or discuss this further at your convenience. Doug Chester Alpine Drilling Team Leader 263-4792 FAX 265-1515 2 of 2 9/2/99 2:51 PM 7/15/99 Scblumberger No. 12691 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine (Cased Hole) Color Well Job # Log Description Date BL Sepia Prints CD CD1-24 99270 SCMT 990612 I .... CD1-01 99277 USlT 990628 1 ~, ~ ~ ~.'.'~i!~- ~.·,. '. SlGNE ~ ~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. 5/21/99 GeoQuest GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503 ATTN: Sherrie NO. 12585 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Colville River Well Job # Log Description Date BL Sepia CD-R CD1~24 ::~ c~ I ~. 99215 CDR/ADN(PDC) 990~!3 1 CD1-24 99215 CDR 990503 1 1 CD1-24 99215 CDR TVD 990503 1 1 CD1-24 99215 ADN 990503 1 1 C D1-24 99215 ADN TVD 990503 1 1 WD-2 fi,'['l L.~ R.A. INJECTION PROFILE 990411 1 1 SIGN _ ._..~~ Please sign and return one c~~)of this transmittal to Sherrie at the above address. Thank you. Anadrill MWD/LWD Log Product Delivery Customer Arco Alaska, Inc. Well No CD1-24 g~c-i - O-~-~O.;:) Installation/Rig Doyon 19 Dispatched To: AOGCC Date Dispatche 7-May-99 Dispatched By: Joey LeBlanc LOG Run No. Scale Original Film No Of Prints No of Floppiesi No of Tapes Perform Letter 2 Surveys (Paper) 2 Received By: ~lease si~n and return to: ~ Anadrill LWD Division 3940 Arctic Blvd Anchorage, Alaska 99503 Fax: 907-561-8417 I ~AI~ I ~ ~1: ..... LWD Log Delivery V1.1, Dec '97 MEMORANDUM State of Alaska TO: THRU: Alaska Oil and Gas Conservation Commission Robert Christenson,~ Chairman · Blair Wondzell, P. I. Supervisor FROM' Lou Grimaldi, ~- SUBJECT: Petroleum Ins ep~ctor DATE: April 26, 1999 FILE NO: 4RMJDZGF.DOC Leak Off Test Arco CD1-24 Colville River Field PTD #99-26 CONFIDENTIAL Monday April 26, 1999; I witnessed the Leak Off Test at the Surface casing shoe on Arco Development well CD1-24 in the Colville River Field. The cement job on the surface casing had failed to reach surface requiring a "Top Job". I felt a witness of the Surface Shoe competency was needed. I arrived this morning at the appointed time to find the rig crew picking up the Bottom-hole assembly. I was informed by Donnie Lutrick (Drilling Foreman) that it would be a little while as the crew had to slip some drilling line and he wanted to perform a trip drill. I agreed that these were good reasons to hold off on the test. The rig finished the Bottom-hole assembly, tripped in the hole to the Float Collar, and tagged the wiper plug. At that time Donnie instructed the driller to pull and rack back three stands. A Flow at the picture nipple was simulated and the crew initiated their Kick while tripping procedure. The floor safety valve was picked up and stabbed, then shut in. Shut-in pressures were taken and a circulation schedule was calculated. The crew lubricated (stripped) the three stands back in the hole against approximately 250-psi. During the strip to bottom, the annular hydraulic pressure was reduced to allow for easier stripping. Overall, this was a good drill. The crew responded quickly, and seemed to know the drill and procedures for both controlling a kick and lubricating back to bottom. I had the impression though that when Donnie told the driller to rack back three stands that tipped the crew off to a Kick and strip drill might be coming although I do not know this as a certainty. I noticed during the drill that the floor safety valve had installed in the top of it a thread protector with a steel bar welded horizontally across the top of it to facilitate stabbing the valve. This is used in many places in the same or slightly different configuration. This lifting sub had a one-inch square cutout as the only flow outlet in it, I felt that in a strong flow it may hinder or prevent stabbing the valve. I spoke with Donnie about this and was assured after the test this would be opened up to at least the I.D. of the valve. 4RMJDZGF.DOC Page 1 of 2 4RMJDZGF.DOC Page 2 of 2 The casing was tested to 2500 psi and after a small initial decline held steady for thirty minutes. The Wiper plug and float collar were drilled as was the cement to the shoe and twenty feet of new hole. I observed returns and saw a indication of clay and shale coming across the shakers. The hole was circulated clean with a 9.6 mud weight constant going in and coming out of the hole. The leak off test was started and the drillpipe pressure raised slowly to 510 psi @ 5 strokes (approx. 14 p.p.g. EMW) where I noticed a decline of the rate of pressure increase per stroke. The pumps were run a total of a 12 strokes to a pressure of 790 psi. The last two to three strokes were at a higher pump rate due to at touchy pump control. The pumps were shut down with forty psi lost in the first ten seconds. The pressure was watched for ten minutes with less then a ten- psi decline stabilized at the end. A calculated E.M.W. of 13.4 p.p.g, was arrived at. SUMMARY: I witnessed a Trip and Strip drill and the Leak Off Test of the Surface casing shoe on Arco well CD1-24 in the Colville River Field. Attachments: 4RMJDZGF.XLS CC; Kuparuk River Drilling CONFIDENTIAL AOGCC Confidential CD1-24 L.O.T. PLOT Page 3 lOOO 9oo 800 7OO 6OO 5OO 4OO 3OO 2OO lOO Casing [ Maximum Volume Test Line For L.O.T. SHUT-IN TIME IN MINUTES (tbr-x-) X - Leak Off Point Bxr~-~,S,~op Pump & Close C - 10 Second Shut-in Pressure D - End Of Test 0 1 2 3 4 5 6 7 8 10 12:10 1 2 3 4 5 6 7 8 9 10 Strokes/Minutes --o-- Casing test Leak Off test --x- Shut-in Max L.O.V. 4RMJDZGF.xls Page 3 of 3 Updated by L.G. 8/4/98 4/27/99 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION April 2, 1999 Doug Chester, Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Colville River Unit CD 1-24 ARCO Alaska, Inc. Permit No: 99-26 Sur Loc: 387'FNL, 2412'FWL, Sec. 5, T11N, R5E, UM Btmhole Loc. 1045'FSL, 202'FWL, Sec. 3, T1 IN, R5E, UM 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dear Mr. Chester: Enclosed is thc approved application for permit to drill thc above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation IntegriW Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to thc Commission on form 10-403 prior to thc start of disposal operations. Please note that an,,' disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site CD1 must comply vdth the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well 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 the Commission to ~vitness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~obert N. Christenson, P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc; Department of Fish & Game, Habitat Section w/o encl. Depamnent of Enviromnental Consen'ation v~qo 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 SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 57' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559, ALK 4717 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 387' FNL, 2412' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1770' FNL, 1103' FEL, Sec. 4, T11 N, R5E, UM CD1-24 #U-630610 At total depth 9. Approximate spud date Amount 1045' FSL, 202' FWL, Sec. 3, T11N, R5E, UM 4/01/99 $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 CD1-22 13,393' MD 202' @ TD feet 15.5' @ 711' feet 2560 6,919' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 96° Maximum surface 2447 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 84' 37' 37' 121' 121' Pre-installed 12.25" 9.625" 36# J-55 BTC 2833' 37' 37' 2870' 2407' 405 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 10564' 37' 37' 10601' 6942' 180 sx Class G N/A 4.5" 12.6# L-80 IBT-M 10514' 37' 37' 10551' 6943' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate LPirn°ed?Cti°n0 R IGINAL Perforation depth: measured true vertical 20. Attachments Filingfee X Property plat X BOP Sketch DiverterSketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certi~, that the foregoing is true and correct to the best of my knowledge Signed ~,-~;iii...~!-~';~:;?,~ Title Drilling Team Leader Date ~z Commission Use Only Permit Number IAPIn~m_.,%r I Approvaldate ~(__...r~_ ~.~,~ I See cover letter for 9~',~ ~' 50-/'¢...~b,~'"~'' ~-~ ~;~_- ? ,~ Otherr~uirements Mud log required Yes Conditi6ns of approval Samples required.~.\ YesI'~'~D i/~l~°~rectional survey required ~ Hydrogen sulfide measures Yes [No) No Required working pressure for BOPE~2M 5M 10M 15M Other: ORIGINAL SIGNED BY byorderof Approved by Rnhprt i~1 ~hdstenson Commissioner the commission Date .......... Form 10-401 Rev. 7-24-89 Submit in triplicate CONFIDENTIAL Well Name: Alpine CD1-24 Surface Location: 387' FNL, 2412' FWL,Sec. 5, T11N, RSE, UM Target Location; 1770' FNL, 1103' FEL, Sec. 4, T11N, R5E, UM Bottomhole Location: 1045' FSL, 202' FWL, Sec. 3, T11N, R5E, UM Scale: 1" = 2,000' 3-18-99 99031607A00 _K4716 ~557 ' I Surface Location RSE/2 Target Location 31e Mar-l?-99 11:22am From-ALPINE ^PC--- +19074804055 --~ T-53Z P.03/05 F-O03 , ~1 WCJN'~TY MAP" ' NOT TO SCALE / / 3~ 2 5004 ~ / 130o,2 , 21o020 / 250'22 290028 31 0030 % ,/ ~ o°~ ~ / ~ 370°36 390°38 4~o°40 ,LEGEND ~3°°4~ / e EXISTING CONDUCTORS 45 0 044 / C/15t ~ ~soc~s, ~NC. / i ...... i i ARCO Alaska, Inc. z& A~INEPROJECT ~ c~1 ~ CONgUCTO~S Subsidi=cy of Atlontic Richfield Comp=ny AS-BUILT LOCA~ONS ..~, ... . , ,, ..... ~ ,,,LKO63D1 5/5/99 CE-CD10T663DI l OF 5 i .......... ~ ' Mar-17-98 11:22am From-ALPINE APC ...... +18074804056 ..... -532 P.04/05 F-O03 ALL CONDUCTORS ARE LOCATED IN SEC 5, t 11 N, R 5 E, UMIAT MERIDIAN Sec Line O/S Well 'Y' 'X' Eat. ('N) Long. ~W) F'Nk FWL. ..Gnd Pad CD1,-1 5,975,905.0 386,000.0 70' 20' 3,4..92" 150' 55' '30.8v" 222' 2,_572' 1.3.0' 19.5' CD1-2 5,975,897-9 385,992.9 70' .20' 54.85" 150' 5,5' 51.07" 229' 2,565' 1,3.0' 19.5' CDI-3 5,9']5,890.9 385,985.9 70' 20' 34.78" 150' 55' 5i'27" 256' 2,'558" 15.1' "19.5' CDI-4 5,975,883.8 385,978.8 70' 20' 34.71" 1,50' 55' 31.4~f' 2'4,3" 2,551' 13.2' 19.5' CDI-5 5,975,876.7 385,971.7 70' 20' 34.64" 150' '55' 51.6B" 25i' 2,54~' 15.5' 19.5' CD1-'6 5,975,869.6 ~85,964.6 70' 20' -34.57" 150' 55' 31.8_',['; 25~' 2,557' 13.4' 1g.5'__ -CDI-7 5,975,862.6 385,957.6 " 70' 20' 34.50" 150' 55' 32.09-~' 265' 2,'550' 13.3~___ 19.5_____L' CD1-'8 5,975,855.5 385,_950.5 70; 20' 34.43" 150' '55" 52.29" 272' 2,525' 13.2' 19.5'_ C01-9 5,975,848.4 . 585,943..4- 70' 20' 34.36" 150' 55' 52..4_'3" 279' 2,517' 15:1' '19.5'_ C[~1-I0 5,975,841.54 385,936.18 70' 20' 34.287" 15~3' 55' 32.7.33" 286' 2,510' 13.0' 19.5' ~;D1-11 5,975,834..~ 385,929.3 70' 20' 34.2~'j 150' 55' 32.93" 294-' 2,503' 12,9' 19.5'__ CD1-12 5,975,827.2 585,922.2 70* 20' 54.1 150' 55' .~3.10" 501' 2,496' 12.8~ 19..5' -~1'Di-15 5,975,82~.00 585,915.06 7.0' '20' 34.0.74" 150; 55' 33,3i1" 308' 2,489' 12.7' 19.5' CD1-1'4 5,975,8'12.97 .3B`5,908.00 70' 20' 34.004" 150' 55' 35.514" 315' 2,4.82' 12.6' 19.5' CD1-15 5,975,'806.0 385,901.0 7(7 20' ,33.95" 150' 5.5' 3'5.72" 32~_' 2,4475' 12.5' 19.5' CD1--16 5,975,798.86 58..5,894.08 70' 20'" 53.863" 150' 5`5' 55.914," 350' 2,44.68' 12.4-' 19.5' CD1-1'~7 5,975,791:81 38`5,8.86.844 70' 20" 33;793" 150' 55' 54~'1':~.5" 557' 2,4461' 12.3' 19.5' C01-18 5,97`5,784.91 .385,879.88 70" 20' 33.724" 150' .5,5' 3~..525" 544-' 2,4454' 12.2' 19.5' CD1-19 5,975,777.92 585,872.81 70' 20' 55.6,544" 150' 55' 54-.526" 35.1; 2,4-47' 12.1' 19.5'__ CD1-20 5,975,770.7 585,865.7 70' 20"'33.58" 150' 5.5' ~4.75" 5`58' 2,,4.40' 12.0" 19.5'_ CD1-21 5,g75,763.6 585,~58.~ 70' 20' 33.51" 150; 55' 34.94" 365' 2,435' 111~); 19.5' '*CD1-22 5,975,756.446 '585,851.10 70' 20' 35;~40" 15D' 55' 34.151" 37.5' '~,426' 11 19.'5' CD1 -~3 5,975,749.4 -'585,8~-4.4. 7O' 20' 35.'57". 15'0' 55' 35.34" .380'_ __2.,419' '"' 12.0' 19.5' CD1-24 5,975,742.4 385,837.4 70' 20' ,35.30" 150; 55' 35.5~5_~, 387' 2,412' 12.2'__.19.5' CD1-25 "5,975,735.3 ..385,830.5 70'-20' 33.25" 150' 55' 55./ 594' 2[405' 12.4' 19.5'__ cD1-26 5,975,728.2 585,.823.2 7'0' 20' 33.16" 150' 5`5' 35. g'5" 4~31' '2,398'. 12.6' 19.5' CD1-27 5,97,5,721.2 585,816.2 70' 20' 35.09" 150' .5,5' 56.1'6" 4-08' 2,39,1' 12.8' 19.5' . ,.,6 416~' 2,384' i'.3.0' 19.5' CD1-28 5,975,714.1 385,809.1 70' 20' .33.02" 150' .55' $6.'~" CD1-29 5,.975,707.0 385,802.0 70"20' 32.95" 150' `5.5' 36.=,6" 423' 2,37:7' 'i3.2' 19,5' CD1-30 5,975,699.9 385,794.9 70' 20' 32.88"- 150' `55' 36.'/7" 430' 2,37(~' i'$.4' 19.5' CD1-31 5,975,692.9 385,787.9 70~ 20' 32.80" 150' 5-5' 56.~7" 4437-' 2,363' .15.3' 19.5- CD1-32 5,97.5,685.8 385,7'80.8 70' 20' ,.32.75" 150' 55' 37.~7" 444.' "'2,356' .13,2' 19.5'_ CD1-~3 5,975,67.8.7 385,775.7 70' 20' 32.66" 150' 55' 57.48" 452' 2~.349' 13.i' 19.5' CDI-34. 5,975,671.,7 '-'_.5.85,766.7 70' 20' 32.'59" 150'..55' 57..~8" -459' 2,342' 1,:3.0' 19.5' CD1-35 5,975,6§4.6 385,759.6 70' 20' 32.52" 150' 55' 57./8" 466' 2,335' 12.9' 19.5' '-CD1-.36 `5,.975,657..5 385,752.5 70' 20' 32.45" .1.`50' 55""37.~9" 4'7'5' 2,328' 12,8'. 19.5' CD1-37 5,975,650.4 385,745.4" 70' 20" 32~3~" 150' 55' 38.'19" '-' 480' '2~321" 12.7' .19.5' cD1--'38 5, g75,643.4 385,738.4. 70" 20' 52.31" 150~ 55.' 38.3-9" 4:.87'_21514' 12.6' 19.5'__ CD1-39 5,975,636.3 385,751.3 70' 20' 32.24" i'50' 55' 38.60" . 495' 2,507' 12.5' 19.5' CD12L40 5,975,629.2 385,7244..2 70' 20' .32.17"- 150' 55' 58.80" 502' 2,300' 12.,4.' 1g.5' CD1-41 `5,975,622-_2 385,717,2 70' 20,' 32.10" 150' 55' 59.i1.0" 509' 2,295' ~2.5' 19..5' 'CD1-42 5,975,615.1 585,710.1 70' 20' 32.03" I,50' 55; 59.2.1" 516' 2,2_86' 12.2' 19.5 CD1-443 5,"97.5,608.0 385,703:0 70' 20' 31.96" 150" 55; 39.,~1" ~25' 2,27.9' ....12.1'.19.'5' -~:'D1-4.44 5,g75,600.9 585,695.9 70' 20' 31.89" 150' 55' 59.61". 531' 2,272' 12.0' 19.5' -CD1-45 5,975~593.9 ,385,688-9 70' 20'"31.8.2" ...150"55' '59.8,2" 55~' 2,265'.. 12.0' 19.5~ * CD1-22 CONDUCTOR WAS AS-BUILT 2/11/98. ! , · "~ ..... LOUNSBURY . ~/~[_'~1 & ASSOCIATES, INC. ! .. ARCO Alaska, Inc. PROJECT ~' OD'1 WELL CONDUCTORS~ Subsidiary of Atlantic Richfield Company AS-BUILT LOCATIONS --(~ADD FiLE NO.I ! DRAWING NO: ...... i SHl!~Ti LK665q1 3/5/..99 CE-CDlO-663D1 2 or ~ 1... Mar-l?-09 11 .'22am From-ALPINE 11.3/5~/991MRTI I ' I Per A99001ACS +19074804056 T-532 P.05,)05 F-OO3 NOTES 1. THIS DRAW1NG SHOWS THE LOCATIONS FOR A TOTAL, OF 45 CONDUCTORS- CD1-22 WAS INSTALLED AND DRILLED IN MARCH, 1998. 2, CELLARS ARE IN PLACE AT THE TIME OF' THE ISSUANCE OF THIS DRAWING, ASSISTANCE WILL BE GIVEN BY LOUNSBURY & ASSOCIATES IN ALIGNING THE KELLY BAR FOR CONDUCTOR DRILLING OPERATIONS. ~ 5. ALL COORDINATES ARE ALASKA STATE PLANE, ZONt~ 4, NAD 27. 4. ELEVATIONS ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS ARE INTERPOLATED F'ROM MICHAEL BAKER JR. DWG. CE-CDlO-102, SHT 1, REV. '0. 5. EIASiS OF' LOCATION AND ELEVATION ARE TEMPORARY ALPINE MONUMENTS 5 &: 4 BY LOUNSBURY &: ASSOCIATES. 6. DATE OF SURVEY: WELL CONDUCTORS 10, 15, 14, ~ 16-19 WERE AS-BUILT 5/10/99, REF. FIELD BOOK L99-20, PAGES 5-11. I I . I I , ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company rADD FILE NO. I IDRAwlN~ NO: LK663D1 I .~/5/9 9 ...... - SURVEYOR'S CERTIF'ICA TE ! HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALI.. DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF ?????????? LouN'sBURY' ASSOCIATES, INC. F.~NI~I~R$ pLANNERS SURVEYORS ALPINE PROJECT CD1 WELL CONDUCTORS AS-BUILT LOCATIONS ";' ISHEET: CE-CD10-66_,,D1 ,,. 3 __ REV: 1 Alpine · CD1-24 PROPOSED DRILLING PROGRAM Procedure . 3. 4. 5. 6. 7. . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in drilling rig. Install diverter and function test. (16" conductor pre-installed) 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. Note LWD will be run over this section. Run and cement 7 inch casing as per program. Displace cement with brine. Top of cement 500 feet above Alpine reservoir as per Rule 20 AC 25.030. Freeze protect casing annulus and casing. Suspend well and move off rig. Move in drilling rig. Install and test BOPE to 3500 psi. _ , -- Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test. Drill 6 1/8" horizontal section to well TD. Contingency - set ECP scab liner or slotted liner if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). - See Note 1. Displace well to weighted brine and pull out of hole. Run liner hanger (without liner) with flapper valve and 2 7/8" displacement string. Displace horizontal section to diesel. POH. Run 4 1~, 12.6 #, L-80 tubing and sting into liner hanger. Freeze protect completion with diesel. Test tubing and tubing-casing annulus separately to 3500 psi. Nipple down BOP. Nipple up x-tree. Pressure test to 5000 psi. Set BPV and secure well. Move rig off. Note 1 :The Alpine development wells will have open hole completions. Rock mechanic studies have indicated that there is sufficient rock strength to maintain wellbore stability throughout the life of the well. However this assumes that a. the 6-1/8" horizontal well stays within the sand section over it's full length and b. the well does not cross any weaker formations (e.g. faulted or fractured zones). In the event that the conditions described in either a. or b. are seen while drilling the horizontal section, it will be necessary to cover these sections. The proposed methods for doing this is utilize ECP liner assemblies. The attached drawing shows the various options for formation isolation that are proposed. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-22 will be the closest well to CD1-24 (15.5' at 711' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells is 11.7' at 722' MD. Drillin_~ Area Risks: There are no high-risk events (e.g. overpressured zones) anticipated in well CD1-24. The surface hole is extremely soft and unconsolidated. CD2-35 encountered tight hole problems during a wiper trip at section TD (worst around the base of the West Sak). Drilling practices will be modified to ensure that hole cleaning is optimized. The proposed annular injection zone at 2450' TVD may be gas bearing. On the offset wells, mud weights in the range of 9.6 - 10 ppg have always been sufficient to provide only minor surface gas readings. The mud weight will be 9.6 ppg before drilling out of the shoe. Lost circulation: Mud losses within the Alpine reservoir have been recorded in some offset wells. Faulting within the reservoir is considered to be the most likely reason for these losses having been encountered. Although no faults in the vicinity of the CD1-24 well path have been identified, it is recognized that sub- seismic faulting may still be present. An addition of loss circulation material to the drilling fluid has cured past losses. Good drilling practices will be stressed to ensure that mechanically induced losses are kept to a minimum. 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. There is potential for differential sticking in the reservoir. The BHA design and 9.2 ppg mud weight have been developed to minimize this potential. However; vigilance through careful adherence to the directional plan will be required to ensure that wellbore geometry does not aggravate the potential for differential sticking. Annular Pumping Operations: Incidental fluids developed from drilling surface and intermediate hole on well CD1-24 will be either be hauled to the Class II injection facility on 1R pad of the KRU or injected into the annulus of well CD1-19 (assuming annular injection is permitted by the AOGCC). This decision will be partially driven by the availability of road links between Alpine and Kuparuk. After the rig returns to drill the 6-1/8" horizontal section it is intended that the incidental fluids be disposed of via an available well. The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The CD1-24 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing. 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 CDI-24 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080 (including clean up from mud and brine mixing operations at the Alpine mud plant facility). We also request that cement rinseate be included in the list of permissible injection fluids. 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 : (lz.U ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2407') + 1,500 psi : 3,002 psi Pore Pressure = 1,089 psi Therefore Differential = 3002 - 1089 - 1913 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 27992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 47599 psi 7,240 psi 6,154 psi CD1-24 DRILLING FLUID PROGRAM SPUD to Intermediate hole to Production Hole 9-5/8"surface casing 7" casing point - 8 ~" Section - 6 1/8" point- 12 ¼" Density 9.5 - 9.8 ppg 9.5 - 10.0 ppg 9.2 ppg PV 10 - 25 12 -18 YP 20 - 60 15 - 25 35 - 45 Funnel Viscosity 120 - 200 Initial Gels 4 - 8 18 - 22 10 minute gels <18 23 - 27 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min HPHT Fluid Loss at 160 8.5 - 9.0 9.0 - 10.0 <10 cc/30 min pH 9.0 - 9.5 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 permafrost and gravel, then reducing to 100-120 sec/qt by casing depth. Pump hi-vis sweeps if needed for supplemental hole cleaning. Maintain mud weight < 9.8 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 maintaining Iow end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 10 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids 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. Drilling Fluid System: 3 - Derrick 4 panel Hi-G Shale Shakers Demco Desanders Derrick 20 cone Desilter Derrick DE-1000 Centrifuge Pit Level Indicators, Trip Tank, Fluid Flow Sensor, Fluid Agitators Pit Confiquration: Capacity (BBLS) Pit 1 183 Pit 2 171 Trip Tank 137 Mini-trip Tank 22 Water Tank 247 Pit 3 175 Pit 4 172 Pit 5 139 Pill Tank 47 Pit 6 156 Colville River Fielo CD1-24 Temporary Suspension Schematic Wellhead installed with tubing hanger and BPV set and pressure . tested to 3500 psi Diesel Freeze Protection in casing and annulus to 1200' TVD. 16" Conductor to 121' 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2870' MD / 2407' TVD cemented to surface 10.0 ppg drilling mud in annulus [ 9.2 ppg brine with diesel freeze protection to 1200' TVD. i ure TOC at 9537' MD / Casing press tested to 3500 psi 6614' TVD (500' MD ~',,~ ,, on pl~m~ p. above top Alpine Updated 3/16/99 7" 26 ppf L-80 R3 BTC-Mod Production Casing at 10601' MD / 6942' TVD @ 90 deg Colville River Field CD1-24 Production Well Completion Plan 16" Conductor to 121' 9-5/8" TAM Port Collar @1000' 4-1/2" Camco TRM-4PE-CF (6.937" OD, 3.812" ID) SSSV and DB-6 Lock (3.812" ID) with single 1/4" x 0.049" s/s control line @ 1,000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2870' MD / 2407' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-5 Top Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Packer Fluid mix' 9.2 ppg KCI Brine with 1200' diesel cap Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-5 Top Latch 4-1/2" Tailpipe Assembly: (~)- Baker GBH-22 seal assembly (3.958" ID) with 12' stroke, combo nitrile/viton seals TOC 500' MD above Alpine @ +/- 9537' MD / 6614' TVD HES "X" (3.813" ID) Set at 60-65 deg Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2900 psi set 2 joints above the X landing nipple Baker Packer set +/-50' above 7" shoe ®® Packer Assembly ®- Baker SLZXP Dbl Grip ZX Liner Packer (4.75" ID) with 12' Type 2 Extension on top (~)- 4-1/2" joint (1) blank pipe (3.958" ID) (~)- HES "XN" (3.725" ID)landing nipple (~- 4-1/2" x 10' pup joint w/centralizer (~)- Baker Model 'C' KOIV flapper check (3.81" ID) (~- 4-1/2" joint (1) blank pipe (3.958"1D) (~)- 1/2 muleshoe joint 7" 26 ppf L-80 BTC Mod Production Casing @ 10601' MD / 6942' TVD, 90 deg Updated 3/16/99 Colville River Field CD1-24 Production Well Completion Plan (w/ Isolation Options) 16" Conductor to 121' 9-5/8" TAM Port Collar @1000' 4-1/2" Camco TRM-4PE-CF (6.937" OD, 3.812" ID) SSSV and DB-6 Lock (3.812" ID) with single 1/4" x 0.049" s/s control line @ 1,000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2870' MD / 2407' TVD cemented to surface Packer Fluid mix' 9.2 ppg KCI Brine with 1200' diesel cap Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-5 Top Latch 4-1/2" Tubing Tailpipe Assembly; Baker GBH-22 seal assembly (3.958" ID) with 12' stroke, combo nitrile/viton seals, 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-5 Top Latch Hydraulics Set Liner Hanger Packer Assembly (~) - Baker SLZXP Packer (4.75" ID) with 12' Type 2 Extension on top O - 4-1/2" joint (1) blank tubing (~) -HES "XN" (3.725" ID) LN (~) - blank 4-1/2" liner (TBD) (~) - Baker Payzone ECP O - 4-1/2" joints (2) blank tbg ~ - Baker Model 'C' KOIV (~) - 4-1/2" joint (1) blank tbg Q - wireline entry guide with ECP cement inflated camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2900 psi set 2 joints above the X landing nipple TOC +/- 500' MD above Alpine HES "X" (3.813" ID) Set at 60-65 deg 1/2 Muleshoe on end of tubin Baker packer +/-150' above 7" shoe 7" 26 ppf L-80 BTC Mod Production Casing 10601' MD / 6942' TVD@ 90 deg Open Hole Scab Liner (~)- Baker Payzone ECP ([~)- 4-1/2" joints (TBD) blank tbg with centralizers as required (~) - Baker Model XL-10 ECP with ECP's cement inflated Open Hole Bridge Plug (~)- Baker Payzone ECP (~)- 4-1/2" joints (TBD) blank tbg and centralizers as required (~)- 4-1/2" guide shoe with ECP's cement inflated .......... ..U. ........... ...................................... N ............ ..u... .... 4-1/2" 12.6 ppf L-80 blank IBT Mod. liner Updated 3/16/99 CD1-24 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 the Alpine CD1-24 well · Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 121 / 121 10.9 52 56 9 5/8 2870 / 2407 14.2 1089 1537 7" 10601 / 6942 16.0 3141 2447 N/A 13393 / 6919 16.0 3130 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 121 = 56 psi OR ASP = FPP - (0.1 x D) = 1089 - (0.1 x 2407') = 848 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 2407 = 1537 psi OR ASP = FPP - (0.1 x D) = 3141 - (0.1 x 6942') - 2447 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3141 - (0.1 x 6942') = 2447 psi Alpine CD1-24 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 5OO -500 -1500 -2500 -3500 -4500 -5500 -6500 -7500 10 11 12 13 14 EQUIVALENT MUD WEIGHT 15 16 17 Alpine, CD1-24 Well Cementinq Requirefnents 9 5/8" Surface Casing run to 2870' MD/2407' TVD, TAM port Collar @ +/- 1000' MD Cement from 2870' MD to 2370' MD (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2370' MD to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2370'- 859') X 0.3132 ft3/ft X 1.5 (50% excess) = 709.9 ft3 below permafrost 859' X 0.3132 ft3/ft Z 4 (300% excess) = 1076.2 ft3 above permafrost Total volume = 709.9 + 1076.2 = 1786.1 ft3 => 405 Sx @ 4.44 ft3/sk System: 405 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 Tail slurry: 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 10,601' MD/6942' TVD Cement from 10601' MD to +/- 9537' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (10601' - 9537') X 0.1268 ft3/ft X 1.4 (40% excess) = 188.9 ft3 annular volume 80' X 0.2148 ft3/ft = 17.2 ft~ shoe joint volume Total volume = 188.9 + 17.2 = 206.1 ft~ => 180 Sx @ 1.15 fta/sk System: 180 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 ftS/sk ~ By Weight Of mix Water, all other additives are BWOCement Cr~t~ ~ M~h~llefl FOR: ROBERTSON Dote plokted Coo~lno~ ore rn ~me Venial ~p~s o~ mfe~n~ ~tlmot~ RKB.I I ARCO Alaska, Inc. Struatura: CD#I Well : 24 field: Alpine Field L~;ation: Norfh Slope. Alaska 500 500 1000 1500 2000 2500 Q. `5000 ~) ,5500 4000 4500 I v 5000 5500 6000 6500 7000 7500 RKB ELEVATION: 57' KOP ,5.00 DLS: ,5.00 deg per 100 ft 9'OOj?ermqJrost~ uegm [urn lo Torget West Sok 20.99 26.98 52.98 DLS: 5.00 de9 per 100 ft 58.98 44.98 EOC C-40 C-50 9 5/8 Cosing Pt C-20 99.74 AZIMUTH 7182' (TO TARGET) ***Plone of Proposol*** TANGENT ANGLE 50.87 DEG K-5 K-2 TARGET ANGLE 90.47 DEG DLS: 9.00 deg per 100 ft Albion 97 Albion 96 HRZ Begin K-L1CU Alpine D _ Al pi,n,e ~ase Alpine TARCET-EOC-7 Cos;n9 Pt 500 0 500 1000 1500 2000 2500 5000 5500 4000 4500 5000 5500 6000 6500 7000 7500 Verficol Secfion (feel) -> Azimufh 99.74 wifh reference 0.00 S, 0.00 E from slof #24 C,.t.d ~, Mr.~.~.- FOR: ROBERTSON Dote plotted : 17-Mot-1999 Plot Refer,-nce ~s CD1-24 Vers~onl~4A. Coord~notes ore ~n feet reference slot ~24. rrue Vsrticol Depths ore reference Estimoted RKB, INTE~ ARCO Alaska, Inc. Sfruoture: CD~I Well: 24 Iqelcl: Alpine F'leld Lo¢oflon : North Slope, Alosko 6000 6200 6400 6600 6800 7000 7200 7400 7600 TARGET ANGLE 90.47 DEG I I t I I I [ I I I [ I t ~ I I I I I t I I I I [ [ [ tI I I I t I [ I I I I I I I I I 5400 5600 5800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 Vertical Section (feet) -> Azimuth 151.95 with reference 0.00 N, 0.00 E from slot #24 5OO 500 1000 15OO 2000 2500 03 3000 I V 3500 4O00 4500 5000 55OO O=t*d ~ ~=~', FOR: ROBERTSON Dote plotted : 17-Yor-1999 Plot Reference ~s CD1-24 Vers~oni~4A. Coerdlnotes ore in feet reference slot 1~24. True Vsrticol Depths ore reference EeUmeted RKB. INT~Q ARCO Alaska, Inc. Sfru~um: CDt¢I Well: 24 Field : Alpine Field location : North Slope, AIosko Eost (feet) 500 0 500 1000 1500 2000 2500 3000 5500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I zoo ~ ~--~' ?; ,..~ .q- _ ~ ,,&o o.'t,.', .:,*-, ..o°9 S $8 Deepest Point S EOC Begin Drop ARGET-EOC-7 Cos[ng Pt SEC. 4, T11N, RSE ~~~- TD - Cosing Pt TD LOCATION: 1045' FSL, 202' FWL SEC. 3, T11N, R5E I I I I I I [ I I I I I I I I I I , I I I I I I I I I I I I ~ [ [ I I I I I I I I I 500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 5OO 5OO 1000 1500 2000 2500 3000 3500 4000 4500 5000 55OO East (feet) -> c~,o ~ ~.~. FOR: ROBERTSON Dote plotted : 17-Mor-1999 Plot Refsrence iS CD1-24 Vsrs;on~4A. Coord~notss are ~n fs~t referencs slot ~2.4. True Vsrticol Depths ore reference Estlmoted RKB, INTEQ ARCO Alaska, Inc. Sfru~ure: CD#I Well: 24 Field : Alpine Flsld Locution : North Slops, Alosku PROFILE COMMENT DATA Point KOP Permafrost Begin Turn To Target ~/ West Sak EOC C-40 C-30 9 5/8 Casing Pt C-20 K-3 K-2 Albion 97 Albion 96 HRZ K-1 Begin Build/Turn LCU Miluveoch A Alpine D Alpine Base Alpine Deepest Point EOC Begin Drop TARGET-EOC-7 Casing TD - Casinq Pt MD 500.00 859.11 1 000.00 1044.54 2196.64 2520.95 2855.75 2869.58 5447.98 5080.19 5389.20 8400.06 9018.08 9558.18 9625.42 9684.92 9777.64 9947.19 9998.25 0056.65 0258.16 0591.81 0455.01 0543.38 0601.32 5592.88 Inc Dir TVD North East V. Sect 0.00 0.00 500.00 0.00 0.00 0.00 10.77 100.00 857.00 -5.85 53.15 55.66 15.00 100.00 994.51 - 11.50 64.09 65.08 1 6.53 99.67 1057.00 - 15.54 75.88 77.05 50.87 97.02 1982.55 -97.72 698.14 704.61 50.87 97.02 2187.00 - 128.45 947.84 955.91 50.87 97.02 2597.00 - 159.98 1204.06 1215.77 50.87 97.02 2407.00 -161.48 1216.26 1226.05 50.87 97.02 2772.00 -21 6.28 1 661.59 1 674.25 50.87 97.02 5802.00 -570.92 2918.29 2958.97 50.87 97.02 5997.00 -400.20 5156.21 5178.41 50.87 97.02 5897.00 -685.46 5474.58 5511.44 50.87 97.02 6287.00 -744.01 5950.22 5990.52 50.87 97.02 6489.00 -774.54 6196.68 6258.56 50.87 97.02 6669.00 -801.56 641 6.50 6459.58 50.87 97.02 6707.81 -807.19 6465.64 6507.05 54.62 106.59 6764.00 -822.27 6555.75 6580.63 65.07 121.28 6852.00 -881.57 6667.42 6720.42 65.90 125.29 6874.00 -906.66 6705.92 6762.64 68.10 128.18 6889.00 -927.80 6754.25 6794.12 80.51 142.16 6944.00 -1065.18 6869.78 6950.96 90.00 1 52.07 6957.00 - 1193.49 6952.61 7054.31 95.69 152.07 6955.87 - 1249.24 6982.1 6 7092.86 95.69 152.07 6945.11 -1526.95 7025.54 7146.60 90.47 151.93 6942.00 -1578.00 7050.50 7182.00 90.47 151.93 6919.00 -3841.09 8564.07 8893.36 Deg/10u 0.00 5.00 5.00 5.00 5.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0 0.00 0.00 0.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 0.00 9.00 0.00 4O 2O ~ 0 0 4O I X/ 60 80 1 oo 120 140 c~t~ ~ ~l~ FOR: ROBERTSON Dote plotted : 17-Mcr-1999 Plot Referenc= Je CD1-24 VersJonji4A. CoordJnotes ore Jn feet reference slot ~2.4. True Vertical Depths ore reference £stimoted RKB. ARCO Alaska, Inc. Sfru~ure: CD~I Well: 24 Field : Alpine Irle|d Locoflon : North Slope, Aloeko East (feet) -> 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 500 520 I I I I I I I [ I I I I I I I J I I I .,,---.~1I I I I I I I I I I I I I I I I I I I I I ~ ~oo /~oo "o?°°° 13u . ~..~... 800 -,_..... 900 ~ 1000 '~'~-'-'--,--- 1100 ~ ~2oo ~ 1300 ~ 1400 1400 ~ 1600 .'o ' .' ' ,; ' 'o ' ' ' lo ' ,,.'o ' .' .......................... 0 0 2 0 0 80 1 O0 120 140 160 180 200 220 240 260 280 ..T~O 0 320 East (feet) -> 80 60 40 2O O I 60 V 8o 100 120 140 5OO 500 1000 1500 2000 2500 I V 3o0o 3500 4000 4500 500O c.me, ~ M~c~x~,<~ FOR: ROBERTSON Dote plotted: 17-Mor-1999 Plot Reference ~s C01-24 Vers~ont~4A. Coordinates ore ~n feet reference slot ~24. True Vertical Depths ore reference Estimoted RKB. ARCO Alaska, Inc. Struature: CD#I Well: 24 field: Alpine Field Location: North Slope, Alaska East (feet) -> 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 go00 9500 10000 10500 I I I I t I I I I I I I I I I I I I I I I I I I I I I I I I I I I i ~00 ~ 68OO 6900 t I I I I I I 500 2000 2500 2600 2900 5200 5500 3800 4100 4400 4700 5000 5500 5600 5900 6200 6500 5OO 0 5O0 1000 15oo 0 2000 2500 ...+. I 3000 V 5500 4000 4500 5000 i i i i i i i i i i i i i i i i i i i i i i I i i i i i i i i i i i i i i i i i i 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 go00 9500 10000 10500 East (feet) -> c~ ~ u~h~,, FOR: ROBERT~ON] Dot~ Dlo~[~d: 17-Mor-lggg Plat ~ference ;. CD1-24 Ve~ion~ Coo~lna~ om tn f~t ~ereece slot ~24. Tree Venial ~g~s om mfemn~ Estlmot~ RKB.~ ARCO Alaska, Inc. Sfruature: CD~I Well : 24 Reid: Alpine Field Loaation: Nar~h Slope, Alaska 320 30 1100 540 TRUE NORTH ,3500 10 2O 30 40 510 50 300 60 290 70 280 80 27O 9O 26O 100 250 110 240 120 230 130 22O 140 210 20O 190 Normal Plane Travelling Cylinder - Feet 180 170 160 150 All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. 24 slot #24 A1 pi ne Fi el d North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : CD1-24 Version~4A Our ref : prop3007 License : Date printed : 17-Mar-99 Date created : 27-Jun-98 Last revised : 17-Mar-99 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 33.299,w150 55 35.546 Slot Grid coordinates are N 5975742.365, E 385837.365 Slot local coordinates are 386.11S 2413.09 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. CD~1,24 Alpine Field,North Slope. Alaska PROPOSAL LISTING Page 1 Your ref : CD1-24 Version~4A Last revised : 17-Mar-99 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S Dogleg Vert Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 S 0.00 E 0.00 500.00 0.00 0.00 500.00 0.00 S 0.00 E 0.00 600.00 3.00 100.00 599.95 0.45 S 2.58 E 3.00 700.00 6.00 100.00 699.63 1.82 S 10.30 E 3.00 800.00 9.00 100.00 798.77 4.08 S 23.16 E 3.00 0.00 O. O0 KOP 2.62 10.46 23.51 859.11 10.77 100.00 857.00 5.85 S 33.15 E 3.00 900.00 12.00 100.00 897.08 7.25 S 41.10 E 3.00 1000.00 15.00 100.00 994.31 11.30 S 64.09 E 3.00 1044.34 16.33 99.67 1037.00 13.34 S 75.88 E 3.00 1100.00 17.99 99.33 1090.18 16.05 S 92.08 E 3.00 33.66 Permafrost 41.73 65.08 Begin Turn To Target 77.05 West Sak 93.47 1200.00 20.99 98.85 1184.44 21.31S 125.03 E 3.00 1300.00 23.99 98.48 1276.82 27.07 S 162.84 E 3.00 1400.00 26.98 98.19 1367.08 33.30 S 205.40 E 3.00 1500.00 29.98 97.96 1454.97 39.99 S 252.62 E 3.00 1600.00 32.98 97.76 1540.24 47.12 S 304.34 E 3.00 126.83 165.07 208.08 255.74 307.93 1700.00 35.98 97.59 1622.67 54.68 S 360.44 E 3.00 1800.00 38.98 97.45 1702.01 62.64 S 420.76 E 3.00 1900.00 41.98 97.32 1778.07 70.98 S 485.12 E 3.00 2000.00 44.98 97.21 1850.63 79.67 S 553.37 E 3.00 2100.00 47.97 97.10 1919.49 88.70 S 625.30 E 3.00 364.50 425.29 490.14 558.87 631.30 2196.64 50.87 97.02 1982.35 97.72 S 698.14 E 3.00 2500.00 50.87 97.02 2173.78 126.47 S 931.71E 0.00 2520.95 50.87 97.02 2187.00 128.45 S 947.84 E 0.00 2853.73 50.87 97.02 2397.00 159.98 S 1204.06 E 0.00 2869.58 50.87 97.02 2407.00 161.48 S 1216.26 E 0.00 704.61EOC 939.67 955.91 C-40 1213.77 C-30 1226.05 9 5/8" Casing Pt 3000.00 50.87 97.02 2489.30 173.84 S 1316.68 E 0.00 1327.11 3447.98 50.87 97.02 2772.00 216.28 S 1661.59 E 0.00 1674.23 C-20 3500.00 50.87 97.02 2804.83 221.21S 1701.65 E 0.00 1714.54 4000.00 50.87 97.02 3120.35 268.58 S 2086.61 E 0.00 2101.97 4500.00 50.87 97.02 3435.88 315.95 S 2471.58 E 0.00 2489.41 5000.00 50.87 97.02 3751.40 363.32 S 2856.55 E 0.00 2876.84 5080.19 50.87 97.02 3802.00 370.92 S 2918.29 E 0.00 2938.97 K-3 5389.20 50.87 97.02 3997.00 400.20 S 3156.21 E 0.00 3178.41 K-2 5500.00 50.87 97.02 4066.92 410.69 S 3241.52 E 0.00 3264.27 6000.00 50.87 97.02 4382.45 458.07 S 3626.49 E 0.00 3651.71 6500.00 50.87 97.02 4697.97 505.44 S 4011.46 E 0.00 4039.14 7000.00 50.87 97.02 5013.49 552.81S 4396.42 E 0.00 4426.57 7500.00 50.87 97.02 5329.02 600.18 S 4781.39 E 0.00 4814.01 8000.00 50.87 97.02 5644.54 647.55 S 5166.36 E 0.00 5201.44 8400.06 50.87 97.02 5897.00 685.46 S 5474.38 E 0.00 5511.44 Albian 97 8500.00 50.87 97.02 5960.07 694.92 S 5551.33 E 0.00 5588.87 9000.00 50.87 97.02 6275.59 742.30 S 5936.30 E 0.00 5976.31 9018.08 50.87 97.02 6287.00 744.01S 5950.22 E 0.00 5990.32 Albian 96 9338.18 50.87 97.02 6489.00 774.34 S 6196.68 E 0.00 6238.36 HRZ 9500.00 50.87 97.02 6591.11 789.67 S 6321.27 E 0.00 6363.74 9623.42 50.87 97.02 6669.00 801.36 S 6416.30 E 0.00 6459.38 K-1 9684.92 50.87 97.02 6707.81 807.19 S 6463.64 E 0.00 6507.03 Begin Build/Turn 9700.00 51.43 98.60 6717.27 808.78 S 6475.28 E 9.00 6518.77 9777.64 54.62 106.39 6764.00 822.27 S 6535.73 E 9.00 6580.63 LCU 9800.00 55.63 108.51 6776.79 827.77 S 6553.23 E 9.00 6598.80 All data is in feet unless otherwise stated. Coordinates from slot#24 and TVD from Estimated RKB (57.00 Ft above mean sea level). Bottom hole distance is 9203.91 on azimuth 114.67 degrees from wellhead. Total Dogleg for wellpath is 125.43 degrees. Vertical section is from wellhead on azimuth 99.74 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. CD#1,24 Alpine Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 9900.00 60.55 117.40 6829.70 860.98 S 6631.18 E 9947.19 63.07 121.28 6852.00 881.37 S 6667.42 E 9998.25 65.90 125.29 6874.00 906.66 S 6705.92 E 10000.00 66.00 125.42 6874.71 907.59 S 6707.22 E 10036.65 68.10 128.18 6889.00 927.80 S 6734.23 E 10100.00 71.84 132.77 6910.70 966.44 S 6779.47 E 10200.00 77.93 139.63 6936.80 1036.10 S 6846.15 E 10238.16 80.31 142.16 6944.00 1065.18 S 6869.78 E 10300.00 84.19 146.19 6952.34 1114.85 S 6905.62 E 10391.81 90.00 152.07 6957.00 1193.49 S 6952.61 E 10391.83 90.00 152.07 6957.00 1193.50 S 6952.62 E 10400.00 90.74 152.07 6956.95 1200.72 S 6956.45 E 10455.01 95.69 152.07 6953.87 1249.24 S 6982.16 E 10500.00 95.69 152.07 6949.41 1288.79 S 7003.13 E 10543.38 95.69 152.07 6945.11 1326.93 S 7023.34 E 10600.00 90.59 151.93 6942.01 1376.83 S 7049.88 E 10601.32 90.47 151.93 6942.00 1378.00 S 7050.50 E 10601.34 90.47 151.93 6942.00 1378.02 S 7050.51 E 10700.00 90.47 151.93 6941.19 1465.07 S 7096.93 E 10800.00 90.47 151.93 6940.37 1553.30 S 7143.99 E PROPOSAL LISTING Page 2 Your ref : CD1-24 Version~qA Last revised : 17-Mar-99 Dogleg Vert Deg/lOOft Sect 9.00 6681.25 9.00 6720.42 Miluveach A 9.00 6762.64 Alpine D 9.00 6764.08 9.00 6794.12 Alpine 9.00 6845.24 9.00 6922.75 9.00 6950.96 Base Alpine 9.00 6994.68 9.00 7054.31 Deepest Point 9.00 7054.32 CD1-24 DeepstPt Rvsd 18-Feb-99 9.00 7059.31 9.00 7092.86 EOC 0.00 7120.22 0.00 7146.60 Begin Drop 9.00 7181.19 9.00 7182.00 TARGET-EOC-7" Casing Pt 9.00 7182.01 CD1-24 Heel/CsgPtRvsd18-Feb-99 0.00 7242.49 0.00 7303.80 10900.00 90.47 151.93 6939.54 1641.53 S 7191.05 E 0.00 7365.11 11000.00 90.47 151.93 6938.72 1729.77 S 7238.10 E 0.00 7426.41 11100.00 90.47 151.93 6937.90 1818.00 S 7285.16 E 0.00 7487.72 11200.00 90.47 151.93 6937.08 1906.23 S 7332.21E 0.00 7549.02 11300.00 90.47 151.93 6936.25 1994.46 S 7379.27 E 0.00 7610.33 11400.00 90.47 151.93 6935.43 2082.70 S 7426.33 E 0.00 7671.63 11500.00 90.47 151.93 6934.61 2170.93 S 7473.38 E 0.00 7732.94 11600.00 90.47 151.93 6933.78 2259.16 S 7520.44 E 0.00 7794.24 11700.00 90.47 151.93 6932.96 2347.40 S 7567.49 E 0.00 7855.55 11800.00 90.47 151.93 6932.14 2435.63 S 7614.55 E 0.00 7916.85 11900.00 90.47 151.93 6931.31 2523.86 S 7661.60 E 0.00 7978.16 12000.00 90.47 151.93 6930.49 2612.10 S 7708.66 E 0.00 8039.46 12100.00 90.47 151.93 6929.67 2700.33 S 7755.71E 0.00 8100.77 12200.00 90.47 151.93 6928.84 2788.56 S 7802.77 E 0.00 8162.07 12300.00 90.47 151.93 6928.02 2876.80 S 7849.82 E 0.00 8223.38 12400.00 90.47 151.93 6927.19 2965.03 S 7896.88 E 0.00 8284.68 12500.00 90.47 151.93 6926.37 3053.26 S 7943.93 E 0.00 8345.99 12600.00 90.47 151.93 6925.54 3141.50 S 7990.99 E 0.00 8407.29 12700.00 90.47 151.93 6924.72 3229.73 S 8038.04 E 0.00 8468.60 12800.00 90.47 151.93 6923.89 3317.97 S 8085.10 E 0.00 8529.90 12900.00 90.47 151.93 6923.07 3406.20 S 8132.15 E 0.00 8591.20 13000.00 90.47 151.93 6922.24 3494.43 S 8179.20 E 0.00 8652.51 13100.00 90.47 151.93 6921.42 3582.67 S 8226.26 E 0.00 8713.81 13200.00 90.47 151.93 6920.59 3670.90 S 8273.31E 0.00 8775.12 13300.00 90.47 151.93 6919.77 3759.14 S 8320.37 E 0.00 8836.42 13392.88 90.47 151.93 6919.00 3841.09 S 8364.07 E 13392.90 90.47 151.93 6919.00 3841.10 S 8364.08 E 0.00 8893.36 TD - Casing Pt 0.01 8893.37 CD1-24 Toe Rvsd 18-Feb-99 All data is in feet unless otherwise stated. Coordinates from slot#24 and TVD from Estimated RKB (57.00 Ft above mean sea level). Bottom hole distance is 9203.91 on azimuth 114.67 degrees from wellhead. Total Dogleg for wellpath is 125.43 degrees. Vertical section is from wellhead on azimuth 99.74 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. CD~1,24 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : CD1-24 Version#4A Last revised : 17-Mar-99 Comments in wellpath MD TVD Rectangular Coords. Comment 500.00 500.00 0 859.11 857.00 5 1000.00 994.31 11 1044.34 1037.00 13 2196.64 1982.35 97 2520.95 2187.00 128 2853.73 2397.00 159 2869.58 2407.00 161 3447.98 2772.00 216 5080.19 3802.00 370 5389.20 3997.00 400 8400.06 5897.00 685 9018.08 6287.00 744 9338.18 6489.00 774 9623.42 6669.00 801 9684.92 6707.81 807 9777.64 6764.00 822 9947.19 6852.00 881 9998.25 6874.00 906 10036.65 6889.00 927 10238.16 6944.00 1065 10391.81 6957.00 1193 10391.83 6957.00 1193 10455.01 6953.87 1249 10543.38 6945.11 1326 10601.32 6942.00 1378 10601.34 6942.00 1378 13392.88 6919.00 3841 13392.90 6919.00 3841 .00 S 0.00 E KOP .85 S 33.15 E Permafrost .30 S 64.09 E Begin Turn To Target .34 S 75.88 E West Sak .72 S 698.14 EEOC .45 S 947.84 E C-40 .98 S 1204.06 E C-30 .48 S 1216.26 E 9 5/8" Casing Pt .28 S 1661.59 E C-20 .92 S 2918.29 E K-3 .20 S 3156.21E K-2 .46 S 5474.38 E Albian 97 .01S 5950.22 E Albian 96 34 S 6196.68 E HRZ 36 S 6416.30 E K-1 19 S 6463.64 E Begin Build/Turn 27 S 6535.73 E LCU 37 S 6667.42 E Miluveach A 66 S 6705.92 E Alpine D 80 S 6734.23 E Alpine 18 S 6869.78 E Base Alpine 49 S 6952.61E Deepest Point 50 S 6952.62 E CD1-24 DeepstPt Rvsd 18-Feb-99 24 S 6982.16 E EOC 93 S 7023.34 E Begin Drop O0 S 7050.50 E TARGET-EOC-7" Casing Pt 02 S 7050.51E CD1-24 Heel/CsgPtRvsd18-Feb-99 09 S 8364.07 ETD - Casing Pt 10 S 8364.08 E CD1-24 Toe Rvsd 18-Feb-99 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ........................................................................................................... 0.00 0.00 O.OOS O.OOE 2858.48 2400.00 160.43S 1207.72E 9 5/8" 0.00 0.00 O.OOS O.OOE 10601.30 6942.00 1377.98S 7050.49E 7 0.00 0.00 O.OOS O.OOE 13392.90 6919.00 3841.10S 8364.08E 4 1/2" Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised ........................................................................................................... CD1-24 DeepstPt Rvsd 392770.000,5974441.000,2.0000 6957.00 1193.50S 6952.62E 19-Jun-98 CD1-24 Heel/CsgPtRvs 392865.000,5974255.000,-2.000 6942.00 1378.02S 7050.51E 25-Sep-98 CD1-24 Toe Rvsd 18-F 394140.000,5971772.000,0.0000 6919.00 3841.10S 8364.08E 19-Jun-98 ARCO Alaska, Inc. CD~i, 24 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : CD1-24 Version~4A Last revised : 17-Mar-99 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 0.00 0.00 0.00 0.00 O.OOS O.OOE 0.00 0.00 385837.37 5975742.37 500.00 0.00 0.00 500.00 O.OOS O.OOE 0.00 0.00 385837.37 5975742.37 600.00 3.00 100.00 599.95 0.45S 2.58E 3.00 2.62 385839.94 5975741.87 700.00 6.00 100.00 699.63 1.82S 10.30E 3.00 10.46 385847.64 5975740.39 800.00 9.00 100.00 798.77 4.08S 23.16E 3.00 23.51 385860.45 5975737.92 859.11 10.77 100.00 857.00 5.85S 33.15E 3.00 33.66 385870.42 5975736.01 900.00 12.00 100.00 897.08 7.25S 41.10E 3.00 41.73 385878.34 5975734.48 1000.00 15.00 100.00 994.31 11.30S 64.09E 3.00 65.08 385901.26 5975730.07 1044.34 16.33 99.67 1037.00 13.34S 75.88E 3.00 77.05 385913.03 5975727.84 1100.00 17.99 99.33 1090.18 16.05S 92.08E 3.00 93.47 385929.18 5975724.88 1200.00 20.99 98.85 1184.44 21.31S 125.03E 3.00 126.83 385962.03 5975719.11 1300.00 23.99 98.48 1276.82 27.07S 162.84E 3.00 165.07 385999.75 5975712.77 1400.00 26.98 98.19 1367.08 33.30S 205.40E 3.00 208.08 386042.21 5975705.88 1500.00 29.98 97.96 1454.97 39.99S 252.62E 3.00 255.74 386089.31 5975698.45 1600.00 32.98 97.76 1540.24 47.12S 304.34E 3.00 307.93 386140.91 5975690.52 1700.00 35.98 97.59 1622.67 54.68S 360.44E 3.00 364.50 386196.88 5975682.09 1800.00 38.98 97.45 1702.01 62.64S 420.76E 3.00 425.29 386257.06 5975673.20 1900.00 41.98 97.32 1778.07 70.98S 485.12E 3.00 490.14 386321.29 5975663.86 2000.00 44.98 97.21 1850.63 79.67S 553.37E 3.00 558.87 386389.38 5975654.10 2100.00 47.97 97.10 1919.49 88.70S 625.30E 3.00 631.30 386461.16 5975643.96 2196.64 50.87 97.02 1982.35 97.72S 698.14E 3.00 704.61 386533.84 5975633.81 2500.00 50.87 97.02 2173.78 126.47S 931.71E 0.00 939.67 386766.92 5975601.44 2520.95 50.87 97.02 2187.00 128.45S 947.84E 0.00 955.91 386783.01 5975599.20 2853.73 50.87 97.02 2397.00 159.98S 1204.06E 0.00 1213.77 387038.69 5975563.70 2869.58 50.87 97.02 2407.00 161.48S 1216.26E 0.00 1226.05 387050.86 5975562.01 3000.00 50.87 97.02 2489.30 173.84S 1316.68E 0.00 1327.11 387151.07 5975548.09 3447.98 50.87 97.02 2772.00 216.28S 1661.59E 0.00 1674.23 387495.25 5975500.29 3500.00 50.87 97.02 2804.83 221.21S 1701.65E 0.00 1714.54 387535.22 5975494.74 4000.00 50.87 97.02 3120.35 268.58S 2086.61E 0.00 2101.97 387919.37 5975441.40 4500.00 50.87 97.02 3435.88 315.95S 2471.58E 0.00 2489.41 388303.53 5975388.05 5000.00 50.87 97.02 3751.40 363.32S 2856.55E 0.00 2876.84 388687.68 5975334.70 5080.19 50.87 97.02 3802.00 370.92S 2918.29E 0.00 2938.97 388749.29 5975326.15 5389.20 50.87 97.02 3997.00 400.20S 3156.21E 0.00 3178.41 388986.70 5975293.18 5500.00 50.87 97.02 4066.92 410.69S 3241.52E 0.00 3264.27 389071.83 5975281.35 6000.00 50.87 97.02 4382.45 458.07S 3626.49E 0.00 3651.71 389455.99 5975228.01 6500.00 50.87 97.02 4697.97 505.44S 4011.46E 0.00 4039.14 389840.14 5975174.66 7000.00 50.87 97.02 5013.49 552.81S 4396.42E 0.00 4426.57 390224.29 5975121.31 7500.00 50.87 97.02 5329.02 600.18S 4781.39E 0.00 4814.01 390608.44 5975067.96 8000.00 50.87 97.02 5644.54 647.55S 5166.36E 0.00 5201.44 390992.60 5975014.61 8400.06 50.87 97.02 5897.00 685.46S 5474.38E 0.00 5511.44 391299.97 5974971.93 8500.00 50.87 97.02 5960.07 694.92S 5551.33E 0.00 5588.87 391376.75 5974961.27 9000.00 50.87 97.02 6275.59 742.30S 5936.30E 0.00 5976.31 391760.90 5974907.92 9018.08 50.87 97.02 6287.00 744.01S 5950.22E 0.00 5990.32 391774.79 5974905.99 9338.18 50.87 97.02 6489.00 774.34S 6196.68E 0.00 6238.36 392020.73 5974871.84 9500.00 50.87 97.02 6591.11 789.67S 6321.27E 0.00 6363.74 392145.05 5974854.57 9623.42 50.87 97.02 6669.00 801.36S 6416.30E 0.00 6459.38 392239.88 5974841.40 9684.92 50.87 97.02 6707.81 807.19S 6463.64E 0.00 6507.03 392287.13 5974834.84 9700.00 51.43 98.60 6717.27 808.78S 6475.28E 9.00 6518.77 392298.74 5974833.06 9777.64 54.62 106.39 6764.00 822.27S 6535.73E 9.00 6580.63 392358.97 5974818.64 9800.00 55.63 108.51 6776.79 827.77S 6553.23E 9.00 6598.80 392376.38 5974812.87 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #24 and TVD from Estimated RKB (57.00 Ft above mean sea level). Bottom hole distance is 9203.91 on azimuth 114.67 degrees from wellhead. Total Dogleg for wellpath is 125.43 degrees. Vertical section is from wellhead on azimuth 99.74 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. CD~i, 24 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : CD1-24 Version#4A Last revised : 17-Mar-99 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 9900.00 60.55 117.40 6829.70 860.98S 6631.18E 9.00 6681.25 392453.80 5974778.45 9947.19 63.07 121.28 6852.00 881.37S 6667.42E 9.00 6720.42 392489.71 5974757.51 9998.25 65.90 125.29 6874.00 906.66S 6705.92E 9.00 6762.64 392527.81 5974731.62 10000.00 66.00 125.42 6874.71 907.59S 6707.22E 9.00 6764.08 392529.09 5974730.68 10036.65 68.10 128.18 6889.00 927.80S 6734.23E 9.00 6794.12 392555.79 5974710.04 10100.00 71.84 132.77 6910.70 966.44S 6779.47E 9.00 6845.24 392600.41 5974670.71 10200.00 77.93 139.63 6936.80 1036.10S 6846.15E 9.00 6922.75 392665.99 5974600.03 10238.16 80.31 142.16 6944.00 1065.18S 6869.78E 9.00 6950.96 392689.17 5974570.58 10300.00 84.19 146.19 6952.34 1114.85S 6905.62E 9.00 6994.68 392724.23 5974520.37 10391.81 90.00 152.07 6957.00 1193.49S 6952.61E 9.00 7054.31 392769.99 5974441.02 10391.83 90.00 152.07 6957.00 1193.50S 6952.62E 9.00 7054.32 392770.00 5974441.00 10400.00 90.74 152.07 6956.95 1200.72S 6956.45E 9.00 7059.31 392773.71 5974433.72 10455.01 95.69 152.07 6953.87 1249.24S 6982.16E 9.00 7092.86 392798.67 5974384.82 10500.00 95.69 152.07 6949.41 1288.79S 7003.13E 0.00 7120.22 392819.02 5974344.95 10543.38 95.69 152.07 6945.11 1326.93S 7023.34E 0.00 7146.60 392838.63 5974306.50 10600.00 90.59 151.93 6942.01 1376.83S 7049.88E 9.00 7181.19 392864.39 5974256.20 10601.32 90.47 151.93 6942.00 1378.00S 7050.50E 9.00 7182.00 392864.99 5974255.02 10601.34 90.47 151.93 6942.00 1378.02S 7050.51E 9.00 7182.01 392865.00 5974255.00 10700.00 90.47 151.93 6941.19 1465.07S 7096.93E 0.00 7242.49 392910.06 5974167.25 10800.00 90.47 151.93 6940.37 1553.30S 7143.99E 0.00 7303.80 392955.74 5974078.30 10900.00 90.47 151.93 6939.54 1641.53S 7191.05E 0.00 7365.11 393001.41 5973989.36 11000.00 90.47 151.93 6938.72 1729.77S 7238.10E 0.00 7426.41 393047.08 5973900.41 11100.00 90.47 151.93 6937.90 1818.00S 7285.16E 0.00 7487.72 393092.76 5973811.46 11200.00 90.47 151.93 6937.08 1906.23S 7332.21E 0.00 7549.02 393138.43 5973722.52 11300.00 90.47 151.93 6936.25 1994.46S 7379.27E 0.00 7610.33 393184.11 5973633.57 11400.00 90.47 151.93 6935.43 2082.70S 7426.33E 0.00 7671.63 393229.78 5973544.62 11500.00 90.47 151.93 6934.61 2170.93S 7473.38E 0.00 7732.94 393275.46 5973455.68 11600.00 90.47 151.93 6933.78 2259.16S 7520.44E 0.00 7794.24 393321.13 5973366.73 11700.00 90.47 151.93 6932.96 2347.40S 7567.49E 0.00 7855.55 393366.80 5973277.78 11800.00 90.47 151.93 6932.14 2435.63S 7614.55E 0.00 7916.85 393412.48 5973188.84 11900.00 90.47 151.93 6931.31 2523.86S 7661.60E 0.00 7978.16 393458.15 5973099.89 12000.00 90.47 151.93 6930.49 2612.10S 7708.66E 0.00 8039.46 393503.82 5973010.94 12100.00 90.47 151.93 6929.67 2700.33S 7755.71E 0.00 8100.77 393549.50 5972922.00 12200.00 90.47 151.93 6928.84 2788.56S 7802.77E 0.00 8162.07 393595.17 5972833.05 12300.00 90.47 151.93 6928.02 2876.80S 7849.82E 0.00 8223.38 393640.84 5972744.10 12400.00 90.47 151.93 6927.19 2965.03S 7896.88E 0.00 8284.68 393686.52 5972655.16 12500.00 90.47 151.93 6926.37 3053.26S 7943.93E 0.00 8345.99 393732.19 5972566.21 12600.00 90.47 151.93 6925.54 3141.50S 7990.99E 0.00 8407.29 393777.86 5972477.26 12700.00 90.47 151.93 6924.72 3229.73S 8038.04E 0.00 8468.60 393823.54 5972388.31 12800.00 90.47 151.93 6923.89 3317.97S 8085.10E 0.00 8529.90 393869.21 5972299.37 12900.00 90.47 151.93 6923.07 3406.20S 8132.15E 0.00 8591.20 393914.88 5972210.42 13000.00 90.47 151.93 6922.24 3494.43S 8179.20E 0.00 8652.51 393960.55 5972121.47 13100.00 90.47 151.93 6921.42 3582.67S 8226.26E 0.00 8713.81 394006.23 5972032.52 13200.00 90.47 151.93 6920.59 3670.90S 8273.31E 0.00 8775.12 394051.90 5971943.58 13300.00 90.47 151.93 6919.77 3759.14S 8320.37E 0.00 8836.42 394097.57 5971854.63 13392.88 90.47 151.93 6919.00 3841.09S 8364.07E 0.00 8893.36 394139.99 5971772.01 13392.90 90.47 151.93 6919.00 3841.10S 8364.08E 0.01 8893.37 394140.00 5971772.00 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #24 and TVD from Estimated RKB (57.00 Ft above mean sea level). Bottom hole distance is 9203.91 on azimuth 114.67 degrees from wellhead. Total Dogleg for wellpath is 125.43 degrees. Vertical section is from wellhead on azimuth 99.74 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. CD~1,24 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : CD1-24 Version#4A Last revised : 17-Mar-99 Comments in wellpath MD TVD Rectangular Coords. Comment 500 O0 500.00 O.OOS O.OOE KOP 859 1000 1044 2196 2520 2853 2869 3447 5080 5389 8400 9018 9338 9623 9684 9777 9947 9998 10036 10238 10391 10391 10455 10543 10601 10601 13392 13392 11 857.00 O0 994.31 34 1037.00 64 1982.35 95 2187.00 73 2397.00 58 2407.00 98 2772.00 19 3802.00 20 3997.00 06 5897.00 08 6287.00 18 6489.00 42 6669.00 92 6707.81 64 6764.00 19 6852.00 .25 6874.00 .65 6889.00 .16 6944.00 .81 6957.00 .83 6957.00 .01 6953.87 .38 6945.11 .32 6942.00 .34 6942.00 .88 6919.00 .90 6919.00 5.85S 11.30S 13.34S 97.72S 128.45S 159.98S 161.48S 216.28S 370.92S 400.20S 685.46S 744.01S 774.34S 801.36S 807.19S 822.27S 881.37S 906.66S 927.80S 1065.18S 1193.49S 1193 50S 1249 24S 1326 93S 1378 OOS 1378 02S 3841 09S 3841 10S 33.15E 64.09E 75.88E 698.14E 947.84E 1204.06E 1216.26E 1661 59E 2918 29E 3156 21E 5474 38E 5950 22E 6196 68E 6416 30E 6463 64E 6535 73E 6667 42E 6705 92E 6734 23E 6869 78E 6952 61E 6952 62E 6982 16E 7023 34E 7050 50E 7050.51E 8364.07E 8364.08E Permafrost Begin Turn To Target West Sak EOC C-40 C-30 9 5/8" Casing Pt C-20 K-3 K-2 A1 bi an 97 A1 bi an 96 HRZ K-1 Begin Bui 1 d/Turn LCU Mil uveach A A1 pi ne D A1 pi ne Base A1 pi ne Deepest Poi nt CD1-24 DeepstPt Rvsd 18-Feb-99 EOC Begin Drop TARGET-EOC- 7" Casing Pt CD1- 24 Heel/CsgPtRvsd18- Feb- 99 TD - Casing Pt CD1-24 Toe Rvsd 18-Feb-99 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ........................................................................................................... 0.00 0.00 O.OOS O.OOE 2858.48 2400.00 160.43S 1207.72E 9 5/8" 0.00 0.00 O.OOS O.OOE 10601.30 6942.00 1377.98S 7050.49E 7 0.00 0.00 O.OOS O.OOE 13392.90 6919.00 3841.10S 8364.08E 4 1/2" Targets associated with this wellpath Target name Geographic Location T,V.D. Rectangular Coordinates Revised CD1-24 DeepstPt Rvsd 392770.000,5974441.000,2.0000 6957.00 1193.50S 6952.62E 19-Jun-98 CD1-24 Heel/CsgPtRvs 392865.000,5974255.000,-2.000 6942.00 1378.02S 7050.51E 25-Sep-98 CD1-24 Toe Rvsd 18-F 394140.000,5971772.000,0.0000 6919.00 3841.10S 8364.08E 19-Jun-98 ARCO Alaska, Inc. CD~I 24 slot #24 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD1-24 Version#4A Our ref : prop3007 License : Date printed : 17-Mar-99 Date created : 27-Jun-98 Last revised : 17-Mar-99 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 33.299,w150 55 35.546 Slot Grid coordinates are N 5975742.365, E 385837.365 Slot local coordinates are 386.11 S 2413.09 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath CD1-19 Version ~4A,,19,CD~l WD-2 Version #5,,WD2,CD~i PMSS <O-9714'>,,CD1-22,CD~l Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 2-Mar-99 50.0 300.0 300.0 2-Mar-99 1051.6 1877.8 1877.8 2-Mar-99 15.5 711.1 10365.6 ARCO Alaska, Inc. CD~I 24 slot #24 A1 pi ne Fi el d North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : CD1-24 Version#4A Our ref : prop3007 License : Date printed : 17-Mar-99 Date created : 27-Jun-98 Last revised : 17-Mar-99 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 33.299,w150 55 35.546 Slot Grid coordinates are N 5975742.365, E 385837.365 Slot local coordinates are 386.11S 2413.09 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. CD1-19 Version #4A,,19,CD~l 2-Mar-99 )48.2( 380.0 380.0 WD-2 Version#5,,WD2,CD~l 2-Mar-99 )1013.7( 2011.1 2011.1 PMSS <0-9714'>,,CD1-22,CD~l 2-Mar-99 )11.7( 722.2 10365.6 M.D. 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 ARCO Alaska, Inc. CD#l, 24 Alpine Field,North Slope, Alaska Reference wellpath CLEARANCE LISTING Page 1 Your ref : CD1-24 Version#4A Last revised : 17-Mar-99 Object wellpath : CD1-19 Version #4A..19,CD~l Horiz Min'm Ellipse T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 O.OS O.OE 0.0 0.0 35.9N 34.8E 44.1 50.0 N/A 100.0 O.OS O.OE 100.0 100.0 35.9N 34.8E 44.1 50.0 )49.5( 200.0 O.OS O.OE 200.0 200.0 35.9N 34.8E 44.1 50.0 )49.0( 300.0 O.OS O.OE 300.0 300.0 35.9N 34.8E 44.1 50.0 )48.4( 400.0 O.OS O.OE 399.6 399.5 37.9N 33.2E 41.2 50.4 )48.3( 500.0 O.OS O.OE 498.7 498.3 43.9N 28.3E 32.8 52.3 )49.6( 600.0 0.5S 2.6E 596.3 595.1 53.7N 20.4E 18.2 57.2 )53.9( 699.6 1.8S 10.3E 691.1 688.4 66.9N 9.7E 359.5 69.7 )65.6( 798.8 4.1S 23.2E 782.5 777.4 83.0N 3.3W 343.1 93.5 )88.9( 897.1 7.2S 41.1E 872.0 864.1 102.1N 15.2W 332.8 127.3 )122.1( 994.3 11.3S 64.1E 959.6 948.4 123.9N 24.3W 326.8 167.9 )161.8( 1090.2 16.1S 92.1E 1045.3 1030.2 148.2N 30.8W 323.2 213.7 )206.5( 1184.4 21.3S 125.0E 1128.6 1109.1 174.7N 34.9W 320.8 263.9 )255.3( 1276.8 27.1S 162.8E 1209.6 1185.1 203.0N 36.6W 319.1 318.0 )307.7( 1367.1 33.3S 205.4E 1288.1 1257.7 232.8N 36.2W 317.8 375.7 )363.5( 1455.0 40.0S 252.6E 1364.0 1326.8 263.8N 34.0W 316.7 436.8 )422.3( 1540.2 47.1S 304.3E 1437.1 1392.5 295.6N 30.OW 315.7 501.1 )484.0( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot#24 and TVD from Estimated RKB (57.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 99.74 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ M,D. 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1900.0 ARCO Alaska, Inc. CD#1,24 Alpine Field,North Slope, Alaska CLEARANCE LISTING Page 2 Your ref : CD1-24 Version#4A Last revised : 17-Mar-99 Reference wellpath Object wellpath : PMSS <O-9714'>,,CD1-22,CD#1 Horiz Min'm Ellipse T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 O.OS O.OE 0.0 12.0 14.4N 13.5E 43.3 23.1 N/A 100.0 O.OS O.OE 88.0 100.0 14.4N 13.5E 43.3 19.7' )19.2( 200.0 O.OS O.OE 188.0 200.0 14.3N 13.4E 43.1 19.6' )18.6( 300.0 O.OS O.OE 288.0 300.0 14.4N 13.0E 42.0 19.4' )17.9( 400.0 O.OS O.OE 388.0 400.0 14.6N 12.7E 41.1 19.4' )17.3( 500.0 O.OS O.OE 488.0 500.0 14.9N 12.4E 39.9 19.4 )16.8( 600.0 0.5S 2.6E 588.1 600.1 14.5N 12.5E 33.7 18.0' )14.8( 699.6 1.8S 10.3E 687.8 699.8 13.5N 12.8E 9.1 15.5' )11.8( 798.8 4.1S 23.2E 786.9 798.9 12.6N 13.2E 329.3 19.4 )15.1( 897.1 7.2S 41.1E 885.3 897.3 12.0N 13.6E 305.0 33.6 )28.7( 994.3 11.3S 64.1E 983.1 995.1 11.5N 14.5E 294.7 54.5 )49.2( 1090.2 16.1S 92.1E 1079.5 1091.5 11.0N 16.1E 289.6 80.7 )74.7( 1184.4 21.3S 125.0E 1174.3 1186.2 10.7N 17.6E 286.6 112.1 )105.5( 1276.8 27.1S 162.8E 1267.3 1279.2 10.6N 19.0E 284.7 148.7 )141.4( 1367.1 33.3S 205.4E 1359.3 1371.2 10.4N 20.8E 283.3 189.8 )181.9( 1455.0 40.0S 252.6E 1447.8 1459.7 10.3N 22.6E 282.3 235.5 )226.9( 1540.2 47.1S 304.3E 1534.4 1546.3 10.2N 24.4E 281.6 285.8 )276.5( 1622.7 54.7S 360.4E 1618.2 1630.1 10.1N 26.3E 281.0 340.5 )330.4( 1702.0 62.6S 420.8E 1699.3 1711.2 10.1N 28.1E 280.5 399.4 )388.6( 1778.1 71.0S 485.1E 1776.5 1788.3 lO.ON 29.9E 280.1 462.4 )450.9( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot#24 and TVD from Estimated RKB (57.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 99.74 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Post Office B~,,, 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 March 18, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-24 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 April 1, 1999. It is intended that Doyon Rig 19 be used to drill the well. The well will be drilled to horizontally penetrate the Alpine reservoir. It is intended that operations on this well be split into two distinct phases. The first visit by the drilling rig will drill the well down to the 7" intermediate casing point. The well will then be suspended and the rig moved onto other operations. At a later date, estimated at March 2000, the rig will return and the horizontal reservoir leg will be drilled prior to completion. Upon completion, 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 you review. Pertinent information attached to this application includes the following: . 2. 3. 4. . . 7. 8. 9. 10. 11. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). Plat, identifying the property and location of the proposed CD1-24 well. A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary and description of the drilling fluids handlin,g system. Proposed suspension diagram. Proposed completion diagram. Proposed completion diagram with open hole isolation options. Pressure information as required by 20 ACC 25.035 (d)(2). Proposed cementing program and calculations. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Diagrams of the BOP equipment and diverter equipment as required by 20 ACC 25.035 (a) and (b) were provided with the drilling permit submission for well CD1-19, dated March 09, 1999. No over-pressured strata are predicted for well CD1-24. Prediction of over-pressured strata as required by 20 ACC 25.033 (e), was fully covered under the drilling permit submission for well CD1-22, dated December 19, 1997. Seismic refraction and reflection analysis, as required by 20 ACC 25.061 (a), was submitted under the drilling permit submission for well CD1-22. Please note, ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment operating on well CD1-24. ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely,_ Brian Hobertson Senior Drilling Engineer Attachments CC; CD1-24 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Lanston Chin ATO 1054 ANO 382 ANO 384 Kuukpik Corporation ARCO Alaska, Inc. ~ ~-.~, ~,~ ~.~ 205088670 ~ AAI PAYABLES P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: The First Nationai Bank:o~ Chi:cago-0710 Ch icag.o;~ i! I liinoi s Payable Througl~: Republic Bank Shelbyville, Kentucky MARCH 8, 1999 0997579 ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION COMMI .. . . . ~ 3001 PORCUPINE DRIVE 'i ! **~ VOID: ~FTER q0 D^YS *** · ~'': 'EXACTLY *********~*1,00 DOLLARS AND O0 CENTs $'%*******.100.00 TRACE NUMBER: 205088670 ,' 20 c;oB~. F= ?0,' I.'OP. =. cio [, ;~ F= i~,.· OCiCi ? c; ?ci,, WELL PERMIT CHECKLIST COMPANY WELL NAME~-,~(-.,t' CZ)/_~..z.// PROGRAM: exp dev ~ redrll serv wellbore seg ann. disposal para req !/'''~' FIELD&POOL /~/~(:~ INITCLASS ~e.,c,, /-~'j GEOLAREA ~>~'~ UNIT# ~.5'-~ _~('~'~) ON/OFFSHORE ADMINIS m ~L~.TION 1. N . 3. 4. 5. 6. 7. 8. 9. 10. 11. DA,TE? 12. ENGINEERING 14. DATE Permit fee attached ....................... Lease number apprepdate ................... Unique well name and number .................. Well located in a defined pool .................. Well located preper distance from ddlling unit boundary .... Well located preper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operetor only affected party ................... Operetor has apprepriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 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 hodzons .......... 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. BOPEs, do they meet regulation ................ 26. 27. 28. 29. ~EOLOGY 30. 31. 32. APPR D~TE/ 33. _,~ ~/~: ?"~'¢ 34. ANNULAR DISPOSAL APPR DATE ~)N (~ N (~N Y N N BOPE press rating appropriate; test to ~(3(~ psig. (~ N Choke manifold complies w/APl RP-53 (~l~y 84) ........ ~ N Work will occur without operation shutdown ........... Y ~ Is presence of H2S gas probable ................. Y (.b]~ 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause ddlling waste... 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 pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Permit can be issued w/o hydrogen sulfide measures ..... Y N Data presented on potential overpressure zones ....... y Seismic analysis of shallow gas zones ............. Y~N Seabed condition survey (if off-shore) ............. ~ N Contact name/phone for weekly progress reports [exploratory o.~] Y N N N GEOLOGY: ENGINEERING: UIC/Annular J DH ~_.---~...~ COMMISSION: DWJ ~ RNC ' CO ~--[~l,l~. co Comments/Instructions: c:\msoffice\wordian\diana\checklist