The URL can be used to link to this page

Home My WebLink About201-057 Imag( .... '~roject Well History' File Cover(" ~ge 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~ (~ L- O_~? Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) ~/' Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL,,~WINDY Scanning Preparation x 30 = + = TOTALPAGES J BY: BEVERLY ROBIN VINCENT SHERYL ~INDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ' PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES NO RESCANNEDB?': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inscrts\Microfihn _ Marker.doc Permit to Drill 2010570 MD 0 TVD 0 REQUIRED INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 61412003 Well Name/No. MILNE PT UNIT SR F-33L1XX Operator BP EXPLORATION (ALASKA) INC Completion Dat Completion Statu APl No. 50-029-22689-95-00 Current Sta~ UIC N Mud Log N__.~o Sample No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y ! N Rec~.ived? Log Log Run Name Scale Media No Start Interval Stop Interval Start Stop Sent Received Daily History Received? Formation Tops (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments Dataset Number Comments Y/N YIN Comments: Compliance Reviewed By: ~, Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: Milne Pt Unit SR F-33L1 Permit # 201-057 June L~, 2001 Cancelled Permit Action Milne Pt Unit SR F-33L1XX API# 029-22689-95 This memo will remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to drill. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting redrills and or multilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to drill. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (wellbore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. CANCELED PERMITS ARE RELEASABLE 2 years from the date on the letter received from the operator requesting the permit canceled. (Memorandum January 23, 1997 by Dave Johnston, subject: Canceled and Expired Permits) Statistical Technician To: Alaska Oil & Gas Conservation Commission Date: June 13, 2001 Terrie Hubble -~0~'~ Technical Assistant Cancel Approved Permit to Drill From: Subject: Please cancel the approved Permit To Drill for MPF-33L1, APl Number 50-029- 22689-60, Permit Number 201-057. We changed this well from a multilateral to a sidetrack and submitted a revised Permit to Drill with the new name, APl number and it was approved with a new permit number. To avoid confusion, Steve McMains requested that we submit a written notification to cancel the original Permit To Drill. /tlh RECEIVED JUN 1 S ZOO1 Alaska Oil & Gas Cons. commission Anchorage Milne Point work for SLB/Nordic CTD Subject: Milne Point work for SLBINordic CTD Date: Tue, 13 Mar 2001 18:57:13 -0600 From: "Stagg, Ted O (ORBIS)" <StaggTO@bp.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak.us> CC: "Endacott, Mary S" <EndacoMS@bp.com> s requested that we ch e our schedule a before MP F-73a. This is a change from the dates given in the Permit to J Dri~_apph'cations for these two wells. The current estimate is that Nordic ~ will finish on the current KRU well in about 7 days and then move to MP ~ F-33L1. Please advise if further revisions to pending permit applications ~ "-~With respect to S-08a, the combo liner as proposed consists of 1380 ft of 2 7/8" below 682 ft of 3 3116". If we were to take a kick while running the 3 3/16" we would stop, stab on a joint of 2 7/8" w/X-O to 3 3/16" on bottom and a TIW valve on top. This would be run in to ram depth and a ram closed on the 2 7/8". This is close to the procedure that would be followed if the entire liner were 2 7/8". The difference is that with all 2 7~8" we would stab a TIW valve. With 3 3/16" we would stab a 2 7~8" joint w/TIW valve. The time difference between these two operations would be very little. If time were a serious factor we would close blind/shear rams on either liner size. With this in mind, the length of 3 3/16" does not appear to me to add much risk to the operation. This procedure is what we would use if we took a kick when running a slotted liner. Please let me and/or Mary know if we need to change something on the S-08a completion. Ted lofl ALASIKA OIL/kND GAS CONSI~RYATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re'. Milne Point Unit MPF-33L1 BP Exploration (Alaska) Inc. Permit No: 201-057 Sur Loc: 1905'NSL, 2660'WEL, Sec. 06, T13N, R10E, UM Btmhole Loc. 27'NSL, 4126'WEL, Sec. 30, T14N, R10E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The permit is for a new wellbore segment of existing well MPF-33, Permit No 196-123, API 029-22689. Production should continue to be reported as a function of the original API number stated above. 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 witness 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. Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~'"- 7~'(-- day of March, 2001 dlffEnclosures cc: Department offish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,L AND GAS CONSERVATION COM,- . SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill Bll Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 40.54' Milne Point Unit / Sag River 3. Address 6. Property Designation P.O. Box 196612, Anchorage~ Alaska 99519-6612 ADL 355018 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AAC 25.025) 1905' NSL, 2660' WEL, SEC. 06, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 3003' NSL, 2329' WEL, SEC. 31, T14N, R10E, UM MPF-33L1 Number 2S100302630-277 At total depth 9. Approximate spud date 27' NSL, 4126' WEL, SEC. 30, T14N, R10E, UM 04/02/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355017, 4126' MDI No Close Approach 5083 14827' MD / 6407' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11705' MD Maximum Hole Angle 100 ° Maximum surface 3356 psig, At total depth (TVD) 8700' / 3000 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Len.qth MD TVD MD TVD (include stare data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 3267' 11560' 8570' 14827' 6407' Uncemented Slotted Liner , , 19. To be completed for 'Redrill, Re-entry, and Deepen Operations. ' ...... Present well condition summary Total depth: measured 12380 feet Plugs (measured) true vertical 9192 feet Effective depth: measured 12282 feet Junk (measured) true vertical 9125 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 250 sx Arcticset I (Approx.) 110' 110' Surface 4703' 9'5/8" 1250 SX PF 'E', 250 SX 'G', 150 SX PF 'E' 4734' 4419' Intermediate Production 12334' 7" 600 sx Class 'G' 12363' 9181' Liner RECEIVED Perforation depth: measured 11748'-11788' I~,/~R ~. 3 ~00] true vertical 8746' - 8775' Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, '564-4694 Prepared By Name/Number: Terrie Hubble, 5644628 2i. '1 hereby certify that, 't~ue and correct to'the besi of 'my knowledge -?'//~ '~'/~ ' Signed Ted Stagg Title CT Drilling Engineer Date ¢ Permit Number I APl Number I Approval Date I See cover letter .2. ~ / --- O ~ ~ 50- 029-22689-60 r.~ --/..~'" -- ~/ fOr other requirements Conditions of Approval:' Sampl'e's Required ' ' [] Yes ']~ No Mud Log Required •'Yes i~1 NO' Hydrogen Sulfide Measures ,J~ Yes [] No Directional Survey Required [] Yes [] No ~[]5K []10K []15K [] 3.5K psi for CTU Required Working Pressure for BOPE F'I2K []3K Othe r:O R~ G t N ~-*. L ~5 i,,i.i.'i~ N ii:'.::. '~, f:!'~ "~' D Taylor ~,e..~rnour~'i by order of Approved By _ Commissioner the commission Date,-~ ~,'/'~"-~ ~,/ Form 10-401 Rev. 12-01-85 ORIGINAL Submit In Triplicate bp MPF-33L1 Sidetrack Summary of Operations: MPF-33 is a fraced Sag River producer that has declined to an uneconomic production rate. This sidetrack, F-33L1, will be a horizontal Sag River producer that will extend into an adjacent fault block to access new reserves. F-33L1 will be completed with a slotted liner and production from the existing Sag perfs will be retained. Prior to the coil sidetrack, rig 4ES will pull the existing ESP completion, set a standing valve just above existing Sag R. perfs, set a 7" flow-through whipstock and install a new 4 Y2" tubing string set up for a jet pump. The standing valve immediately below the flow-through whipstock will permit continued production from the existing Sag R. perfs. Phase 1: ( to be performed by N 4ES) Set standing valve, set whipstock. Planned for March 25 · Set standing valve at approx. 11,734', just above perfs at 11748-11788. · Set retrievable flow-through whipstock at 11,700' (8,671ss). Phase 2: Mill window, Drill and Complete sidetrack: Planned for April 2, 2001. Drilling coil will be used to mill the window and drill the directional hole as per attached plan. The sidetrack will be completed with a slotted liner. Top of 2 7/8" liner to be approx. 11,560' MD (8,570' SS). Mud Program: · Phase 1:8.5 ppg brine · Phase 2: FIo-Pro (8.6 to 9.7 ppg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to KRU 1R Pad. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8" slotted liner will be run from TD to approx. 11,560 (8,570ss). Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3~5e1~ psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan. BHL (State Plane)' 540,354; 6,044,030. Max. hole angle is 100 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over all of the open hole section. · A real time Resistivity or a Memory Induction Log will be run in open hole. Hazards · The highest H2S recorded to date on MPF Pad is less than 5 ppm. · Lost circulation risk is Iow. RECEIVED ,Alaska Oil & Gas Cons. Cornmissior~ Anchorage Length of hole to drill is high (3122' with TD at 14,827') and may not be achievable. Small faults may cause the wellbore to exit the Sag River formation. Reservoir Pressure On 12/1/99 res. press, was measured at 3000 psi at 8700ss (6.6 ppg). Initial window milling and drilling will be done with 8.6 ppg fluid. However, after crossing a fault at the far end of the sidetrack the reservoir pressure may be as high as 4400 psi (9.7 ppg). If indications of underbalance are detected during the drilling operation then fluid densities will be increased accordingly. Max. surface pressure with gas (0.12 psi/ft) to surface is 3356 psi, assuming 4400 psi pore pressure: Tree: 2 9/16"- 5M CIW MPU F-33 Orig. DF Elev. = 29.14' (N 22E) Wellhead: 11" x 7" 5M FMC Gen 5A Orig. GL Elev. = 11.4' w/ 2 7/8" FMC Tbg Hng, 3" Acme DF To 7" csg. hnr. = 28.6' (N 22E) , lift threads on top and 2 7~8" 8 rd on bottom, 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 ~ KOP @ 2500' sidepocket KBMM GLM Max. hole angle = 51 to 55 deg. f/4600' to 10,850' Hole angle thru' perfs = 45 deg DLS = 4.3 deg./100' @ 4350' 9 5/8", 40 ppf L-80 Btrc. ~ ~ 2 7/8" 6.5 ppf, L-SO, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf) Sag River Completion 7", 26 ppf, L-80, Btrc. production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) i Centrilift FPMTARC Pump I 11542,I FC 650 w/184 stage ~ (GRSTZBARH6) ~! Centrilift GSTGDBHL111'563'1 Stimulation Summary seal section 08/19/96- 144 M lbs. of 20/40 Carbolite was placed behind pipe. No screenout.~ 50 hp, 1250 v. / 23 amps. Centrilift PHD Perforation Summary [7" x 20' short joint from11,587' to Ref lo.q: CR / CCL 08/08196 11,607' wlm w/RA tag on top. Size SPF Interval (TVD) Sag, River 3 3/8" 6 11,748'-11,788' 8741'-8770') J 22 gm. Jumbo Jet charges (EHD = 0.76" TTP = 6.4") @ 135 / 45 deg. phasing Last w/I tag 09/11/97 [ 7" float collar (PBTD) 7" float shoe [ 12363' J DATE REV. BY COMMENTS MILNE POINT UNIT 08/07/96 JBF Drilled and Cased by Nabors 22E WELL F-33 09/12/96 JBF Initial ESP completion by Nabors 4ES APl NO: 50-029-22689 07/16/97 M. Linder RWO 4-ES 09/13/97 U. Linder RWO 4-ES BP EXPLORATION (AK) Yree: 2 9/16" - 5M CIW ~-~-~ead: 11" x 7" 5M FM,C, Gen SA t" ~ MPF'33L1 Proposed Completion' w/ 2 7/8" FMC Tbg Hng, 3 Acme ' lift threads on top and 2 7/8" 8 rd on bottom, 2.5" CIW H BPV profile 20" 91.1ppf, H-40 I 115' I Orig. DF Elev. = 29.14' (N 22E) 'ig. GL Elev.: 11.4' ~F To 7" csg. hnr. = 28.6' (N 22E) KOP @ 25O0' Max. hole angle = 51 to 55 deg. f/4600' to 10,850' Hole angle thru' perfs = 45 deg DLS = 4.3 deg./100' @ 4350' Camco 2 7/8" x 1" I sidepocket KBMM GLM I 126' 9 5/8", 40 ppf L-80 Btrc. 14734' mdl 7", 26 ppf, L-80, Btm. production casing ( drift ID = 6.151 ", cap. - 0.0383 bpf ) 4 1/2" Jet Pump tubing to be installed by 4ES prior to CTD sidetrack into Sag R. 4 1/2" WLEG approx. 11,600'. Top of 2 7/8" slotted liner approx. 11,560'. 4 1/2" X Nipple Mechanical whipstock to be set at approx. 11,700' for CTD sidetrack 7" x 20' short joint from11,587' to 11,607' wlm w/RA tag on top. 2 7/8" slotted liner to be installed in Sag R. lateral Perforation Summary Ref Ioq: CR / CCL 08/08/96 Size SPF Interval (TVD) Sag, River 3 3/8" 6 1,748'-11,788' (I ~741'-8770') 22 gm. Jumbo Jet charges (EHD - 0.76", TTP - 6.4") @ 135 / 45 deg. phasing ~"~standing valve in Model D Packer Sag River Completion Last w/I tag 09/11/97 7" float collar (PBTD) 7" float shoe I12168' 2282' 2363' ,~ Ms MPF-33 Vertical Section Pdh Distance (Feet) 0 500 1,000 1,500 2,000 2,51/0 3,000 8500 4,000 &800 8500 f 8550 8500 8650 ~8700 8750 MPF 33a case 103 Jan. 1[), 200} Ted x4694 8800 8880 Tot Drld:3122 fl 8900 ME~ke_r_Depths 60ri9 Wel~b_gj2_- I'SAG 8667ss I 8,667jfl'iVD 8,7t0 [_~_~i~.7~ ti TVD 8,735~fl ~\/D Kick Off Deprfr @KO L._J_?o.sJ fl MD 6,407 fl j MD KO Pt 11,7051 MD New Hale 3}22 / Totat MD t .4_~.~Zl TVDTD 8,710~ DLS __d~/]00 _~ool Face Length C.~e~ I ~°1 ~9oj _55oI Cg~e3 Cu~e4 Cu~e5 Curve 6 Cu~e7 Cu~e8 Drawn: 3/12/200} 11:07 Pon Name: Case 122 MPF-33 IWell Name MPF-,33 ] 9,000 ~\~365; 6,044,028 (8710ss) 8,500 8,000 7,500 ' 7,000 MPF 330 Case 103 Jan. 10, 2001 Ted x4694 -2,500 2,000 1500 -1,000 500 0 X distance from Sfc Loc r) 6,500 6,000 500 1,000 CLOSURE Distance 8,810 ft Az 350 de~[ NEW HOLE E/w (x) 'fl) jTDstate Plane I J _...~4~, '~54J. 6,044,030j Surface Loc 541.904 6.035,357 DLS -871 STol, ooTool Face Length 921 5401 Drawn: 3/12/200 11:07 Plan Norne: Case 122 2 3/8" CT ~1 I I I Pack-Off Lubricat°r-~ I MPF-33L1 CT Drilling & Completion BOP 7 1/16" Annular 7 1/16" 5000 psi Blind/Shear 71/16" Pipe/Slip -~ 2 3~8" Pipe/Slips ~ 2 7~8" 71/16" Pipe/Slips ~ 2 3/8" SWAB OR MASTER VALVE H !.82857 DATE 012901 PYMT ( HANDL INVOKE / CRED~ MEMO CKO12901H ;OMMENTS: Perm INST' S/H THE A'ITACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. .. ~ DESCRIPTION ~it to Deill -- Teeeie Hub CaROSS 'ee 100.00 X4&28 VENDOR ALASKAO I LA O0 DISCOUNT NET 100. O0 100.00 100.00 412 PAY o~;~..::,&~,~¢~.~;i;i~ ::;:'88:~, ~ oo***~,~,,:~.~..~.~*******~:.~',~-,'~**;'~· .'~a:;,~:: ~ ~?;::: .... :~:..:._?:~: ~.:: ~:::_ '?]: ~;? '~:;;.'~;:-: ;;:~:~:~-......:~::~'~:~;:::" ~];~ '-;?;::?:::~?~ .DATE- ::];~;;~;;;:.~'~ :'.-::?:..:..;~:~?';~: ::.:'.-~-: .¥.:'?~.~MOuNT ':'-" ":"'-' ...... -:::::' ........ -'-: ......... :" .... ':': .... r,---~-:-'.-"- ~,--~ ,~oo~' L ~ I I ,'I,.°.pS,~?,' m:Ohl, SO38~iSm: 008, m.,hl,~i,' ,, , .mPF- WELL NAME .~.~ ~...~ PROGRAM: exp ~ dev ~/redrll ~ serv. WELL pERMIT'CHECKLIST ' CoMpANy n f . _ wellbore sag .~/Xann. disposal para req_ FIELD & POOL x~__ ~ /,~' 0 INIT CLASS ./~,~-4~ /- rT~,'/ GEOL AREA g 7 o UNIT# ././,~ 2...y ON/OFF SHORE <3/L,J ADMINISTRATION 3. 4. 5. 6. 8. 10. 12. 13. 14. Conduetor string provided ................... Y N"~ ' 15. Surface casing protects all known USDWs ........... Y~ ~,~r,~l~ i ~ e_~\~-I' '~-,¢ ~ ~: ~ ~, 16. CMT vol adequate to circulate on conductor & surf csg ..... Y 17: CMT vol adequate to tie-in long string to surf csg ........ YL'~~,' c-~ ~L,,,~ \~r~.~-,,`~,t" Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available' in ddlling unit ............ If deviated, is wellbore plat included ............. ... Operator only affected party ................... Operator has appropriate 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 ........... ENGINEERING 18. CMT will COver all known productive horizons. 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage orreserve pit ................. (~ N e._.'~'k'..,~--k ~--~,. ~"t ~. ! c~-~>..5,e..~,~e_ ?~,'¥. · 21. If a re-drill, has a 10-403 for abandonment been approved... ---Y---N ~ {~ ~'~-~'~-~--~'~ ~-,,~-~,,~c~\ ~ ~:~.'~-,,~ t--. ,. 22. Adequate wellbore separation proposed ....... ; ...... 23. If diverter required, does it meet regulations ....... . . . 24. Dnlhng.fiu~d program schematic & equ,p hst adequate ..... (,,Y~N 25. BOPEs, do they meet regulation ............. . . . (~.) N ' '~ ,---~. ~ 26. BOPE press rating appropriate; test to ~(~{::~ r~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ......... 28. Work will occur without operation shutdown ........ . . . 29. Is presence of H2S gas probable ........ ......... Y N(N(N~ 30. Permit can be issued wlo hydrogen sulfide measures ...... Y 31. Data presented on Potential overpressure zones ..... . . 32. Seismic analysis of shallow gas zones... ....... ~' N /~,/"/, 33. seabed condition survey (if off-shore)..; .......... ~ Y N - · 34. Contact name/phone for weekly progress reports [explorat?~only] Y N ANNULAR DISPOSAL35. With proper cementing recOrds, this plan (A) will contain waste in a suitable receiving zonei ....... Y N ~,PPR DATE (B) willto surface;n°t contaminate freShwater; or cause drilling waste..... Y N (C) will not impair mechaniCal integrity of the Well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E). will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGI .NEERING: ' UlC/~ular COMMISsIoN: Comments/Instructions: GEOLOGY c:~soffice\wordian~diana\checklist (rev. 111011/00) 0 0 Z 0 -i