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Home My WebLink About209-131 • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c. _a - L Well History File Identifier 1 Organizing (done) ❑ Two -sided III III IIIII lII ❑ Rescan Needed 1 I I11111 11111 RES DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: ❑ Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: Li Other:: BY: Ma ria Date: d10 I I /s/ me Project Proofing III 111111 1111 BY: Date: c g.. p__. /s/ P Scanning Preparation c x 30 = l90 + / = TOTAL PAGES 4' 1 (Count does not include cover sheet) WI BY: Maria Date: O a DI '' /s/ Production Scanning II I Stage 1 Page Count from Scanned File: 6 (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Date: / pr- 11 / ,s,(4410 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 11 1111111111 ReScanned I BY: Maria Date: /s/ Comments about this file: Quality Checked III 1111111 I 10/6/2005 Well History File Cover Page.doc r " Field & Pool Well Name: KUPARUK RIV UNIT 1B -17L1 Program DEV Well bore seg n PTD #:2091310 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Entire horizontal lateral wellbore will lie within ADL 25648 3 Unique well name and number Yes 4 Well located in a defined pool Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432C 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit 6 Well located proper distance from other wells Yes boundaries and no interwell spacing restrictions. Wellbore will be more than 3 -1/2 miles 7 Sufficient acreage available in drilling unit Yes from an external property line where ownership or landownership changes. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes SFD 11/2/2009 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes Area Injection Order No. 2B 115 All wells within 1/4 mile area of review identified (For service well only) Yes KRU 1B-08 • 16 Pre- produced injector: duration of pre production less than 3 months (For service well only) Yes Lateral wellbore - well will be produced for -6 months, then converted to injection. 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided NA Conductor set in 1B-17 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 1B -17 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented to GL in 1B-17 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in 1B -17 22 CMT will cover all known productive horizons No OH slotted liner completion 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re-drill, has a 10 -403 for abandonment been approved NA using flow thru whipstock to allow 1B-17 to flow after S /Ts are drilled. 26 Adequate wellbore separation proposed Yes Proximity analysis performed. No issues. 27 If diverter required, does it meet regulations NA Wellhead already in place...BOP stack installed. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure = 2113 psi ( 6.3 ppg) Drilling with 8.6 ppg mud ( using MPD technique) GLS 11/4/2009 ',29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 1457 psi Will test BOP to 3500 psi 31 Choke manifold complies w /API RP -53 (May 84) Yes • 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S reported on 1B pad. Rig has alarms and sensors. 134 Mechanical condition of wells within AOR verified (For service well only) Yes Well plan is to convert to injector after 6 months of prod. AOR complete. - — 35 Permit can be issued w/o hydrogen sulfide measures No 1B-17 measured 30 ppm H2S on 8/6/09; measures required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 6.3 ppg EMW; will be drilled with 8.6 ppg mud using Managed ----- - - - - -- Appr Date 37 Seismic analysis of shallow gas zones NA Pressure Drilling techniques. SFD 11/2/2009 38 Seabed condition survey (if off- shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering P ' Lateral wellbore. Will be pre - produced for about 6 months prior to conversion to injector. Date: Date Date Commissioner: Co missioner: , ne om 1 � its- I t fi b-Of