The URL can be used to link to this page

Home My WebLink About195-090XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /"-'~"~___.) File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages' Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Diann~athan Lowell /si [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ THE MATERIAL UNDER THIS COVER HAS BEEN MICROF'ILMED · ON BEFORE JANUARY 03 2001 E PL M A T-'E IA L U N W TH IS M ARK DER E R C:LORI~IFI~M.DOC Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: 0(% '- ~~'(~ DATE Re: Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 This memo will remain at the from of the subject well ~e. 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 i the treatment of these kinds of applications for permit to ddil. 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 remair unchanged. The AP! number and in some instances the well name reflect the number of preexistin! reddils 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 ddll. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9.~ The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the AP! numbering methods descnbed in AOGCC staff memorandum "Multi-lateral (weltbore segment) Ddiling Permit Procedures. revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 22,1995 Terry Jordon, Drlg Engr Supv BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit ~ LA-O(,, ~ BP Exploration (Alaska) Inc Permit No. 95-~e- ~'O Surf Loc 103'NSL, 1663'WEL, Sec 18, T11N, R13E, UM Btmhole Loc 1351'NSL, 321'WEL, Sec 18, T11 N, R13E, UM Dear Mr dordon: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. 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 a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the Nodh Slope pager at 659-3607. Chairman. ~ BY ORDER OF THE COMMISSION dl~encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA , ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] RedrillFIIlb. Type of well. Exploratory l-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE=76.7 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchoracle, Alaska 99519-6612 ADL 28283 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o ^AC 25.025) 103' NSL, 1663' WEL, SEC 18, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1347' NSL, 1180' WEL, SEC 18, T11N, R13E U-O6A (43-18-11-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 1351' NSL, 321' WEL, SEC 18, T11N, R13E 06/26/95 $200,000.00 ;12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 28282 3928' feet No Close Approach feet 2560 10667'/8923' BKB feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) ;Kickoff depth z4oo MO feet Maximum hole angle so o Maximum surface 2850 psig At total depth (TVD) 8800'/3700 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8.5" 7" 29# 13 Cr NSCC 1750' 7250' 7396' 9000' 8594' 8.5" 7" 29# L80 NSCC 347' 9000' 8594' 9347' 8780' 177 sx Class 'G' 6" 4.5" 12.6# 13 Cr NSCT 1470' 9197' 8706' 10667' 8923' 169 sx Class 'G' r:. F F. I \ i'P 19. To be completed for Redrill, Re-entry, and Deepen Operations. l~, L ~ ~, V ~ v Present well condition summary Total depth: measured 9325 feet Plugs (measured) JUN '~ 5 1995 true vertical 9214 feet Al~sI',a 0il & Gas Cons. Commission Effective depth: measured 9280 feet Junk (measured) Anchor: ', true vertical 9173 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 20x30 8 Cu Yds 146' 146' Surface 2649' 13-3/8" 3746 Cu Ft 2685' 2685' I n t e r m e d i at e 8853' 9-5/8" 2019 Cu Ft 8889' 8812' Production -- Liner 944' 7" 271 Cu Ft 8381'- 9325' 8342'- 9214' Perforation depth: measured 8920'- 8944' (Sag), 9040'- 9082', 9096'- 9140' (Ivishak) true vertical subsea 8757'- 8780' (Sa.q), 8868'- 8961' (two Ivishak intervals) 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 requirementsl-I 21. I hereby certify that ~.~egj)ing is true and correct to the best of my knowledge Signed ~f~'l~ ff.-%.¥t-~,.~ Title DrillincjEn~ineerSupervisor Date ~) Commission Use Only Permit Number ]APl number Approval date ~- See cover letter ~'. ~""- ~'(:~) 150-4::~2. ~'-- ,~.././'/,~--- C~/ ~, .--,¢,~¢~ -- ~'..~ for other requirements ConSiti~ns ~)f approval Samples required [] Yes .E~ No Mud Icg required []Yes ~No Hydrogen sulfide measures ,'~ Yes [] No Directional survey required ,~ Yes [] No Required working pressure for BOPE []2M; O3M; 1~5M; I--I10M; []15M; Other: Original Signed By by order of f " _Approved by David W. Johnston Commissioner ~ne comm,ssion Date//P ?~ Form 10-401 Rev. 12-1-85 Submit I Well Name: I U-06A Redrill Plan Summary IType of Redrill (producer or injector): IPRODUCER Surface Location: 102 FSL 1663 FEL S18 T11N R13E Tie-in/KOP 101 FSL 1543 FEL S18 T11N R13E Target Location: 1347 FSL 1180 FEL S18 T11N R13E Bottom Hole Location: 1351 FSL 321 FEL S18 TllN R13E I AFE Number: 14P0700 Estimated Start Date:1 6/26195 IMD: 110667' I I Rig: I NABORS 18E I Operating days: iT VD: l~923' bkb J I Well Design (conventional, slimhole) 125 I KBE: 176.7' I High Angle, Big Bore Sidetrack I I I I Objective Replace the current U-06 well (250 BOPD, 90% high water cut) with a horizontal well in Zone 4. Establish a new drainage area and reduce competition with U-14. Mud Program: Special design considerations No special hazards or concerns are anticipated. The selection of a fresh water sidetrack fluid through the Kingak means that Boreplate, Barotrol and Baranex should be used to prevent shale problems. Milling Fluid - Fresh Water Bentonite/Biozan System Density Vis YP 10SEC 10MIN FL (PPG) (gIFT) GEL GEL cc/30min 9.8 200-300 50-70 30-50 50-60 6.0 to to to to to to 9.8 150-200 40-60 20-40 30-50 6.0 RECEIVED J U N 1 5 1995 Intermediate Section - Freshwater Sidetrack Fluid Depth Density PV YP 10SEC 10MIN FL (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min 7400 9.7 40-50 12-15 4-8 8-14 15.0 to to to to to to to 9347 9.8 50-60 15-20 10-12 12-16 15.0 A!~.ska 0~1 & Gas Cons. Commission Anchor: , Redrill Plan Summary Page 1 Reservoir Section - Flopro System Density LSR Vis ChlOrides pH FL (PPG) cc/30min 9.0-9.2 40-60K 40,000 9.0 <6.0 Directional: I KOP: 1 7400' MD IMaximum Hole Angle: 88° Close Approach Well: NONE The above listed wells will be secured during the close approach. Casing/Tubing Program: Hole ' Csg/ 'Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/I'VD MD/I'VD 8.5" 7" 29# 13 Cr NSCC 1750' 7250'/7396' 9000'/8594' 8.5" 7" 29# L80 NSCC 347' 9000'/8594' 9347'/8780' 6" 4.5" 12.6# 13 Cr NSCT 1470' 9197'/8706' 10667'/8923' Tubing 4.5" 12.6# 13 Cr NSCT 10800' 30/30' 9100'/8653' Cement Calculations: I Liner Size: 17" 29#/ft Basis[ Cement will be brought to 1000' above the Sag River (shallowest hydrocarbon). - !. Volume based on 50% excess in open hole and an 80' shoetrack. Total Cement Volume: I 1771 sxs of Class G Blend @ 1.17 ft3/sx I Liner Size: 14 1/2" 12.6#/ft I Basis[ Volume based on 30% excess in open hole, 80' shoetrack, 150' liner lap and ·! 200' above the liner top with drillpipe in the 7" liner. Total Cement Volume: I 1691 sxs of Class G Blend @ 1.17 ft3/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Anticipated Bottom Hole Pressure 3700 psi @ 8800' TVDSS Maximum Anticipated Surface Pressure 2850 psi Planned Completion Fluid 8.6 ppg filtered sea water Anch0rr" Redrill Plan Summary Page 2 Notes: a. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). b. Based on previous logs on U Pad, no hydrocarbon zones are anticipated above the Sag River. c. No potential hazardous levels of H2S are anticipated in this well. d. Drilling hazards: No special hazards identified. Redrill Plan Summary Page 3 SUMMARY PROCEDURE: 1. Pre-rig work: Kill well. . 3. 4. 5. . , 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. Redrill Rig up for full bore abandonment through tubing. Pump 27 bbls of cement to cover the perforations to 8600' MD. (This is equivalent to laying a plug from 100' below the bottom perf to 320' above the top perf, with 3.3 bbls squeezed away.) AOGCC rep should witness tagging the cement top. Cut the 4-1/2" tubing above the packer at around 8300' MD. Freeze protect and set a BPV. Move in drilling rig. Test casing pack-off if not done during pre-rig work. Pull BPV. Circulate diesel cap from the well and recover for future use. Install a BPV. Remove the production tree and install BOPE. Pull BPV with lubricator and install 2-way check valve. Test BOPE to 5000 psi. Pull the 2-way check valve with lubricator. Pull and lay down the 4-1/2" tubing. RIH with a 9-5/8" bridge plug and set at 7650' MD. Release from bridge plug, test casing to 3500 psi. Displace the well to milling fluid and spot a 18 ppg pill on bottom. RIH with a section mill and cut a 50' window starting from about 7400'MD. Spot a balanced cement kick-off plug (180 cubic feet minimum) through open- ended drillpipe from 100' below the base of the section to 200' above. Run in with an 8-1/2" steerable drilling assembly and dress the cement to 5' below the section top. Kickoff and directionally drill to the intermediate liner point at the top of the Sag River at approximately 9347' MD. Run a 7" 29# 13 Cr/L-80 liner assembly to bottom. Space the liner hanger and top isolation packer 150' up inside the 9-5/8" casing. (Packer will be set at approx 9100' MD, so 13-Or casing should be run below 9000' MD) Cement the liner in place with the total cement volume based upon 50 % excess on open-hole plus the 80' shoe volume. The cement will be brought up to 1000' above the shoe in the Sag River (shallowest hydrocarbon.) Run in hole with a 6" steerable assembly and test the casing to 3500 psi. Drill float equipment and 10' of new hole. Displace the well to FIo-Pro. Drill to TD. Obtain Direction / GR / Resistivity formation evaluation logs while drilling. DP conveyed logs may be required depending on MWD results. Run a 4 1/2" 13-Cr liner assembly to bottom. Space the liner hanger and top isolation packer about 150' up inside the 7" casing. Cement the liner in place with the total cement volume based upon 30 % excess on open-hole plus the 80' shoe volume, 150' lap volume and 200' excess on top of the liner with drillpipe in the hole. RIH with 6" bit and 7" scraper and cleanout to top of 4 1/2" liner. RIH with 3 3/4" mill and clean out to the landing collar. Test liner and liner lap to 3500 psi. Reverse circulate the well to clean filtered seawater. RIH with 2 3/4" perforating guns and perforate as required. Run the 4-1/2" 13-Cr completion string assembly. Drop ball and set packer. Install a BPV. Remove BOP's and nipple up tree. Pull the BPV with lubricator and install a 2-way check valve. Test the production tree to 5000 psi. Pull 2-way check valve with lubricator. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. ,.~.~. Set BPV and release rig. ~, Complete appropriate documentation and hand-over to Production · Plan Summary ix\9;~" r'~age 4 _ ' ' _ ~ iiin I[ _ , ",SHARED 'SER,,VZ'CES' DRILLZN6_ , .... II_l - J[[ I I - -- I I - U-O6A (P31 VERTICAL SECTION VIEW. Il I [ I I I I Sectton at: 89.74 TVD Scale.' I inch = 1200 feet Dep Sce]e.' ~ Snch = tEOO-feet l~rker ldenliflcat$on ~ BK~ ~CTN INCLN A) TIE-IN S~VEY 7394 7390 120 ~,13 B) T~ ~ NINDO~ 7395 · 7391 120 1,13 C) K~/CURVE 6/100 7dOg.' .73~ 120 1,12 ........ O) E~ 6/tO0 CURVE 8307 .Q176 -15 53.87 El ~VE g/lO0 8630 g~7 -111 53,87 Fl ....... T~OE~ ....... '~a07 ~3. 4Bd 88,00 G) E~ 9/100 C~VE g~7~_ ~g3 dB4 88.00 ...... H) TD S0667 8923 1343 88.00 , , ,~ ,. . ,, i,, . i . ... I . ... , . 0 500 1~00 ' ' :=400 3000 3600 4200 4BO0 5400' 60.~' .... ' Section Departure ........ .. "- SHAB'.ED SER,V, :'C.ES' D,R.,ILI ZN6_,,..'. ..... VERTICAL SECTION VIEW. Section at: 89,74 TVD Scale · I inch -13001.f.eet Oep Scale t Inch - 300 feet.' u | Drawn. · 06/]3/95 ' ...:, I . ! ! "]la:~'/L"'C6'- ~ ......... ~ ........... u, , 0-- : ..... M~rke~ Id~ntiflc~tlon MI) ~$ S'ECIN INCLN , Al TIE-IN SUftVEY 7~94 1390 Ii~ I. 13 ' B) TOP OF WINOOW 1395 7391 1~0 1,13 Il · ' C) KI:)~/C~VE 6/100 741)0 73~ D- .............. O) ENO 6/100 C~V£ 837 8t76 -15 03.87 E) CLM:~VE g/lO0 01)30 8~7 -111 53,87 F) ....... TARGET ....... 9B07 '1)093 ' 4B,4 08.00' 3--- G) END g/lO0 C~ 0807 8803 484 88,00 'z:k- '"/¢~¢ ................. ..-- ~' ............ H) 1'0 100§7. 8923 .1~3 BEi-.O0 ,__ Ii ,, ; .... /' ,__ 4 ,,!, · I . _ , . ... · ~rk--~r---.; .............. 1- ..~,.~ ....... ~l~ea'l~F ~¢ .........'~l.---~ ~ ~ ~ · .~~~. ........ ~ ............. , ............................. , ................. · , .. · ,*. , ~* ~:..,;..*,,, · , , ,, . .. .;.. . . . _ - .. ~ . , · . . ** -500 (JknmOri)l (cig3 ~GAP3 Bt.5?. 10;2~ AN l] ~300 - 150 0 150 300 450 600 750 gOO 1050.. 1~00~380 1500 ., _ i [ i · i il · lmlll i i i ~ . l An~dr'i]] $c~]~/mber,¢er, ,, I ,,,SFtARED S_ERVlCES ................... DRILLING I Ill Il I Il I I I I II I I I U-06A (P3) PLAN V]:E~ CLOSURE · 1830 feet at Az~th 46,96 · ~500 ECLINATIDN.: 29.135 E CALE ....... : ~' inch = 300 f?t Marker. Identification RD N/S E/W , I lIE-I# SUI~VEY 7394 ~ lOP Glr YZ~OW 7395 2 120 ) ' :) K~/CIJflVE 6/tO0 7400 ~ S20 ~- " I) E~ 6/~00 CURVE 8307 365 :) CLRVE. g/tO0 8630 50~ ~]3 ' ./~'"~ ' '! ...... TAqGET ..... 9B07 1245 478~ EN3 9/tOOCURVE 9807 1245 478 ~ !0667 1249 )33 ....... L054~ ~ ........ · .. ~ , , \ ' , . it" . ,, 900 750 609 450 · 31:)0 150 ~ 150 3~ 450. 600 750 900 1050 IL;N)Q 1350 ISOQ II~F~ ~BO0 <~ NEST ' EIk~'I -) I II ii i · ilml i I · · i i · · i 1. Type of Request: i ;lATE ~ ~' ~ ~ OF ALASKA ALASKA OIL A ~ID (.. ~S CONSERVATION COMMISSION APPLICATIONi !I)R SUNDRY APpROvALS Abandon ~ Suspend Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repalr well __ Plugging x Time extension __ Stlmulate Change approved program __ Pull tubing __ Variance __ Perforate Other X Plugback for Redrlll 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 103' NSL, 1663' WEL, SEC. 18, T11N, R13E At top of productive interval 515'NSL, 1464' WEL, SEC. 18, T11N, R13E At effective depth 641' NSL, 1421' WEL, SEC. 18, T11N, R13E At total depth 663'NSL, 1415' WEL, SEC. 18, T11N, R13E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service 9325' feet Plugs (measured) 9214' feet BKB Datum elevation (DF or KB) KBE = 77 feet Unit or Property name Prudhoe Bay Unit 8. Well number U-06 (34-18-11-13) 9. Permit number 84-78 10. APl number 50-.. 029-21117 11. Field/Pool Prudhoe Bay Field~Oil Pool Effective depth: measured true vertical 9280' feet Junk (measured) 9173' feet BKB Casing Length Size Cemented Structural Conductor 110 20x30 8 cu yds Surface 2649 13-3/8 3746 cu ft Intermediate 8853 9-5/8 2019 cu ft Production -- .Liner 944 7 271 cu ft Perforation depth: measured 8920'-8944' (Sag) 9040'-9082', 9096'-9140' (Ivishak) Measured depth True vertical depth BKB 146 146 2685 2685 8889 8812 8381-9325 8342-9214 RECEIVED true vertical subsea 8757'-8780' (Sag) 8868'-8961' (two Ivishak intervals) JUN 1 Z 1995 Tubing (size, grade, and measured depth) 4-1/2" L-80 to 8413'MD ^laska 0Il & Gas Cons. CommisslOrl Anch0r~. Packers and SSSV (type and measured depth) 9-5/8" Baker permanent packer at 8323', 4-1/2" Otis SSSV at 2097' 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation June 15, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that th%foregoing is true and correct to the best of my knowledge. Signed ¢~ / ,.~~.~/~ Title Drilling Engineering Supervisor /' ( ) FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ,..j BOP Test t,.-' Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 Date ¢f/¢ '¢ I Appr°val N~;;~./,/z,Z' Commissioner Date .L~ --//~::, - SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST UNIT# PROGRAM: exp [] dev [] redrll~ aery [] 0 OFF OW0 ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... ' 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... Y N N · N N N N N N ENGINEERING 14. Conductor string provided ................ Y ~ 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf csg.. Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ ~ N ~~ 20. Adequate tankage or reserve pit ............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved. N 22. Adequate wellbore separation proposed .......... N 23. If diverter required, is it adequate ........... ~ DA 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to 'E~;.,~' psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... .~----~~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/~ 32. Seismic analysis 9f shallow gas zones .......... /~ N ////~-7 _ 33. Seabed condition survey (if off-shore) ....... 34. Contact name/phone for weekly progress reports . . ~/.. Y N [ex~lora~ry only] ~ . GEOLOGY: ENGINEERING: COMMISSION: C~mments/Instructions: HOW/Jo - A:%'=ORMSk:heklist rev 03/94