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190-143
THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P M E E L E W A T E R IA L U N D ER TH IS M ARK ER lc-ap~m 10~ian95 LOCATION · CLEARANCE REPORT State of Alaska o~,. ~ ~ ~o~.~v~o~ ~0~~o~ ~,o. ~ Memorand~ To File, ~I No. /33 - 2~ ~~ ~ Operator ~/~ / KAn Loc, Zion ~ ~[~ Spud: ~ ' ~-- ,-/~ TD: SqS?, Completed No%e casing size, wt, depth, ~ vol, & procedure. Review the well file, and comment on plugging, well head status, and locatioD clearance - provide loc. clear, code. Well head cut off: ~ Marker post or plate: ~/~ Location Clearance: ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL [] GAS []] SUSPENDED [] ABANDONED [~] SERVICE [] Classification of Service Well 2. Name of Operator C I R I PRODUCT I ON COMPANY 3. Address 2525 C STREET, STE 500 ANCHOP~GE, AK 99503;;',,~-~.~,r.~L~[~;.~.~.,:.,...~>,;~ ~-.~,.~ - 4, Location of well at surface -v .,. ,:.:, ..,'- At Top Producing Interval 198~ I~L~ 1707 FEL, See. 21, T6N, ROW, SN At Total Depth 198~ F'NL, 1707 FEL, See. 21, T6N, Rgw, .SM 5. Elevation in feet (indicate KB, DF, etc.) K.B. 322.0 fi; I CIRI Fee 12. Date Spudded 13, Date T.D. Reached I 6. Lease Designation and Serial No. 17. Total Depth (MD+TVD) N/A 18. Plug Back Depth (MD+TVD¥ N/^ 7. Permit ~e, __ /~,~ 8. APl Number 5o- 133- 20§2q- 9. Unit or Lease Name West Fork Gas Field 10. Well Number West Fork 1-21 11. Field and Pool Sterling "A" and "B" 14. Date C .... ~., __.p. . 15. Water Depth, if offshore 16. No. of Completions 2/15/9~ N/A feet MS L N/A ! 19. DirectionalSurvey I -~0. Depth where SSSV set J 21. Thickness o~ Permafrost YES [] NO ~ N/A feet MO' N/A 22. Type Electric or Other Logs Run N/^ 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 13 3/8" 9 5/8" 71! P1 ace ~ 1 WT. PER FT. 4O# 26# }SS "G" GRADE ~-80 N-80 ~nt col umr SETTING DEPTH MD TOP BOTTOM surface 140' surface 2143 ' surface 5447' from 5447 to 4805' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) N/A 27. Date First Production Flow Tubing Press. N/A Date of Test Hours Tested Casin§ Pressure HOLE SIZE CEMENTING RECORD AMOUNT PULLED ~o surface to surface to 3600' inthe 7" :asing to complete P&R of B-4 sand and prepar 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERV,AL (MD) I AMOUNT& KIND OF MATERIAL USED ~992~'~5002' I squeezed 15 bbl of Class "G" cemer PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) CALCULATED 24-HOUR RATE OIL-BBL OIL-BBL GAS-MCF GAS-MCF 28. CORE DATA N/A ICHOKE SIZE GAS-OIL RATIO WATER-BBL 1 WATER-BBL OIL GRAVITY-APl (cor;i Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. for si de track. Form 10-107 .~;ul)mlt ,n duphcale Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME ] Include interval ~es~ed, pressure data. all fluids recovered and gravity,' MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . 31. LIST OF ATTACHMENTS NONE 32. I hereby certify lha't the foregoing is true and correc~ to the best of my knowledge Title ~) ~/~'~ , ~ '~ .W ,, / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on alt types of lands and leases in Alaska. Item 1' Classification of-Service Wells' Gas injection, water injection, steam injection, air injection, salt .......~v,,,., ~,-~isposal, water supply for injection, obse~'vation, 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 only 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" Form 10-407 CIRI PRODUCTION COMPANY 2525 C STREET - SUITE 5(X~- ANCHORAGE, ALASKA 99509 (~07) 274-86'38 - FAX (907) 279-8836 DAILY PROGRESS REPORT WELLI~ME-NO. WEST FORK 1-21RD (APE OW1080! RIG NO. COOPER CON~T. ~1 DEPTH TODAY DEPTH YESTERDAY 24 HR. FOOTAGE DATE 2/2/94 DA YS(from accel~ance) 0 Projected 13-3/8" Casing set at 140 9-5/8" Casing set at 2143 7" Casmg set at 5547 6" Uner set @ T.O.L. (~ I BIT DATA: I Dep~ Dep~l Bit Cc~d'~on No. Size Type In Ou~ Fee~ Hrs. Noz. (9.9 9) T B i i ~ i i i i i i BIT I RPM J PUWT. __ ! S.O. WT. I ROB. I ! Circula~g Rates Siow pump rates PUMP DATA I I MFG. MODEL LINER STROKE '~98% SPM GPM PSI ' SPM P~I · GARDNER-DENVER PZ-9 I ND. 1 r'lO.2 OILWELL214P i i i :'; ; ! "-- ~ GPM i : i i [ ~ i i i i i DRILLING FLUID j AI~ HT-HP Time Wt Funnel Vis PV YP Gets pH B Fil Cake CI Ca I I I I I I [ I ] I Pf Mf Sand ,~I Oil Cec Remarks Odlling Assembly REMARKS - Conmue riggng up. Mix kill pill 19.2~) for butlheading down tubhg. Prep to wellhead wilh high pressure ine. L.he up on mud ~ and artem~ bulhead kil. Riser valve on rig ~or began to leak. Pulled valve apart Vah/e requi'es re~uldhg. RernaJnder of rig i~ reasonably good s~a[e of readmess. Cannot fulty assess DOPE support e(z~rner~ unN BOP's ri~ed uo on well. If dama~led valve ~he onDi/~rro n d~e road w e mould expect rig acce~ance somed'ne late ~hu'sday AOGCC r~preser~atfve$ havehadDhe required 24hr. notice and a r~p. is standhg by h Ke~ai. OAIL ~ COST CUM. COST PREPA RED B r VIRGILTHRAPP ClRI PRODUCTION COMPANY 2525 C STREET - SUITE ,500- ANCHORAGE. ALASKA 99509 (S07) 274-8638- FAX (907) 27~8836 DALLY PROGRESS REPORT WELL NAME-HO. RIG NO. DEPTH TODAY DEPTH YESTERDAY 24 HR. FOOTAGE 8IT DATA: No. Size .,, WI[ST FORK 1-21RD (AFE OW1080) COOPER CON3T. ~1 DATE 2/3/94 DA YS (from acce~ance) 13-3/8" Casing set at 9-5/8" Casing set at 7" Casing set at 6" Uner set @ 0 PrO~ected 140 2143 5547 T.O.L (~ Type Depth Depth In Out Feet Hrs. Bit Condilion Noz. (9,9.9) T B .: ! .: i i i i i i ) i BIT ROB. 1'-10.2 PUMP DATA I Circulamg Rates MFG. MODEL LINER STROKE '~98% SPM GPM PSI Slow pump rates I I SPM PSi GARDr,IER-DEI',IVER PZ-9 i 6 i 9 i 0.08bps i i OtLWELL214P i 5.75 i 14 10.14bpsl i : ( Dire~on TVO'I I S~c~orl · o GPM La~ude J Departure : ; ; I i I Ca DRILLING FLUID I I APl HT-HP Time Wt Funnel Vis PV YP Gets ph Fil R! Cake ~i ~.8 i ~ ~ i i : o.s : m L m m ~ I Pf Mf Sand Sol O! Cec Remarks · : :' ! ! { i i i i i I : ii ii : : DHlling Assembly Mixing spud mud to 9.2 REMARKS - Corrdnue to fig up, Problems encountered with I~ocedure to bull head kil fi[id down the ~ubing. MullJple vaned att~m!~ts to pump down tubing was hindered by some bio,age. Could pressure m to ~ psi without an,y Meed down, D. Bulot informed us the last time they work,~ the hole there was a ice plug. Pulled BPV and bled off pressure. Installed two-wa)/check vane. NiDole down tree. Install dU~l into heater BelTn inslaling BOPE. I! appears ~hat ~he rig wll quaify for acceptance later friday 4 Feb 94 c~ce AOGCC completes BOP test. RIG UP STATUS CONTINUES OAIL'r' COST CUM. COST ,,, PREPA RED BY VIRGILTHRA PP V.1.3 / 1-4-94 ClRI PRODUCTION COMPANY 2525 C STREET - SUITE 500- ANCHORAGE, ALASKA 99509 (907) 274-8638- FAX (g07) 27'9-8836 DAILY PROGRESS REPORT WELLHAME-NO. WEST FORK 1-21RD (AFE 0W1080! RIG NO. COOPER CON3T. DEPTH TODAY DEPTH YESTF_RDAY 24 HR. FOOTAGE DATE 2/4/94 DA YS (from acceptance) 1 13-3/8" Casing set at 140 9-5/8" Casing set at 2143 7" Casing set at 5547 6" Uner set @ T.O.L (~ DATA: I Depth Depth BIT Bit Condi~on No. Size Type In Out Feet Hrs. Noz. (9,9,9) T B i ! i i i i i i i i i i ! i i i i i i ;. i ! ..' ! ! i ! ,.' ! BIT v'~r. INO.1 NO2 IPUMP DATA I Circulathg Rates ~ Siow pump rates I MFG. MODEL LINER STROKE '~98% SPM GPM PSI ' SPM PSI · GARDNER-DENVER PZ-9 OILWELL214P oep~! . I SURVEY DATA Devia~on I Oirec~on TVD I Section J LaIJlude I Departure i ~ i i i i i DRILLING FLUID I APt HT-HP 'ime WI Funnel Vis PV YP Gets pH RI RI Cake Cl Ca · I I I I I : ..' : : ! : ; i '.. : Pf Mf Sand Sol Oil Cec .: ..- i ,, .: ! i i i 60 94 i Mixing spud mud to 9.2 ! : : : Ddlling Assembly REMARKS - Rig ready for BOP test. AOGOC rep. arrived 1500 hr. Inlet Odling porbon of BOP test OKed by AOGOO rep,. State requi'ed modifica~on of ram setup. Ul~per keily cock valve waned unfl tubng pulled. Inlet Drili~g has completed lhei' portion of rig up requkements and the rig has been accepted as of 1800 hfs 2-4-94. Remarks The State is reouii~ the installation of a Row sensor system before fnal s~lnoff. Until the PVT sensors are inslalled we will be requi'ed to U~lize a pit watch.. We are dgging up to conduc~ abe wi'etine bull head kil, slidng sleeve work while awa~ng PVT system arrival. DALLY COST CUM COST PREPARED BY VIRGtLTHRA PP V.1.3/1-4-94 ~ 7:45 PM CIRI PRODUCTION COMPANY STREET - SUITE ,500- ANCHORAGE. ALASKA 99509 (907) 274-8638- FAX (907) 279-~ DAILY PROGRESS REPORT WELLNAME-NO. WEST FORK 1-21RD (AFE OW1080) RIG NO. COOPER CON3T. ~1 DEPTH TODAY DEPTH YESTERDAY 24 HR. FOOTAGE DATE 2/5/94 DA YS (from acceptance) 2 13-3/8" Casing set at 140 9-5/8" Casing set at 2143 7" Casing set at 5547 6" Uner set @ T.O.L. @ BIT DATA: J No. Size Type Depth Dec~h Bit CondilJon In Out Fee~ Hrs. Noz. (9,9.9~ T B BIT V,rl'. NO2 J PUMP DATA ! Rates ' Slow · Ckculatilg pump rates · i MFG. MODEL LINER STROKE '(~98% SPM GPM ImSI m SPM PSI i · GARDr, IER-DENVER PZ-9 ! 6 OILWELL214P i 5.75 9 !O.O~bpsi i i ~ GPM J SURVEY DATA Dev~a~on Direction TVD J sec~n j Lamde J Departure .... DRILLING FLUID J APl HT-HP Time Wt Funnel Vis PV YP Gets pH Fil Fil Cake CI Ca , , , i i i &5 i .... ; ; ; ; : ; ; ; $ i : Pf Mf Sand Sol OI Cec Remarks ..' : , ~.o i ~ i Drilling Assembly Mixing spud mudto 9.2 ~2~2 REMARKS - Alzempt to bulhead weft b~ocked by 'ice plug'. Wi'elbe tag L~ on ice plug at 48~. MullJ runs made w~ b~Ulem, speam, bo~h undervaned presstres. Break up andmove plug progressively down to 612'. Released al pr~sure and ice plug broke free and came up hole folowed by 1703 psi bubble of gas. Well stabized. 0dlhead wel. Rm in hole. open slid~ sleeve and circulate hole to fll w~ we~lhted mud. Multiple attempts to lock ou~ SSSV failed. Alzemate method employed. Circulated hole Wvo fui ~mes wilh mud to enstre all gas ctculated OL¢. J DAIL~ COST CUM. COST ] PREPARED B, VIRGILTHRAPP V.l.3/1-4-94 ClRI PRODUCTION COMPANY 2~25 C STREET- SUITE 500- AHCHORAGE. ALASKA 99.509 (907) 274.-8638- FAX (907) 27~8S36 DALLY PROGRESS REPORT WELLHAME-HO. WEST FORK 1-21RD (AFE OW1080} DATE 2/6/94 RIG HO. COOPER CONST. ~1 DA YS (from acceptance) 3 DEPTHTODAY 13-3/8" Casing set at 140 'DEPTH YESTERDAY 9-5/8" Casing set at 2143 24 HR. FOOTAGE 7"' Casing set at 5547 6" Liner set @ T.O.L. (~ i BIT DATA: J Depth Dep~ Bit Cond~on Ho. Size Type In Out Feet Hrs. Hoz. 19.9.9) T B BIT WT. i"10.1 ir.lo.2 ! RPM I PUWT. I S.O. WT. I ROB. PUMP DATA J Circulating Rates i ~ Slow pump rates MFG. MODEL LIFIER STROKE '~98% SPM GPM PSI ~ SPM PSI · GARDNER-DENVER PZ-9 i i i i OILWELL214P Oevia~on ; ~ ! ; : i i i i i DRILLING FLUID I Time Wt Funnel Vis PV AR HT-HP YP Gets pH ~ ~1 Cake CI Ca Pf Mf Sand Sol 0.1 i 0.85 :' i , 5.0 i 95 Drilling Assembly Cec Remarks Inspected to reduce fluid wt to 9.0.~pg L12/2 REMARKS - Received verbal approval from Lou Gdmaldi to proceed with puling ~ubing. Complied wi~ installation of flow monitor and hired a temporary pit watcher un~l PVT's are installed in I~s. Had some problems ge~g heater string side of aJbing hanger to strface. Removed tubhg hangers o~ bo~h sides. Pulled heater string first folowed by 2-7,8" tubing. Hole bega~ takr~g fluid 40 joints out of hole. Instructed ddler& mud man to reduce mud wei~'~t to 9.0 ppg and circulate hole. Co~mued out of hole. 0600 hr; Tul:)inq pulled. Changing out ~ipe rams~n BOP at re~:x)rt time. [ PRF_PA RED g ~ VIRGILTHRA PP V.l.3 / 1-4-94 CIRI PRODUCTION COMPANY 2525 C STREET - SUITE 500- ANCHORAGF_ ALASKA 99509 (907) 274-8638- FAX (9071279-8.S36 DAILY PROGRESS REPORT WELLNAME-NO. WEST FORK 1-21RD (AFE OW1080! RIG NO. COOPER CON3T. al DEPTH TODAY P&A portion of program DEPTH YESTERDAY 5447 24 HR. FOOTAGE ,~L~VALUE! DATE 2/7/94 DA YS Ifrom acceptance) 4 13-3/8" Casing set at 140 9-5/3" Casing set at 2143 7" Casing set at 5447 6" Uner set @ T.O.L (~ BIT DATA: J Dep~ De~t~ Bit Condi~on No. S~ze Type In Out Fee~ Hr's. r, loz. (9,9,9) T B :- Casing scraper;i ~ ; ~ ; '" ~ i i i i i i i i BIT WT. I RPM I PUWT. I S.O. WT. I RD0. NO. 1 HO.2 I PUMP DATA i Rates ~ Slow rates c~-culamg pump i MFG. MODEL LIr-IER STROKE '(~98% SPM GPM PSI ~ SPM PSI ; · GARDNER-DENVER PZ-9 ! 6 ! 9 ! 0.081~s i 60 ! 197.8 ! 800 o ~ 5.75 C~ LWELL214P ; i DRILLING FLUID I APl HT-HP Time Wt Funnel Vis PV YP Ge~s pH Fil F~ Cake CI Ca ii · i i , ~ i i i i 1 Pf Mf Sand Sol Oil Cec Remarx, s o. =i ,.o ,i o,i oi:I Tubing tail: casn~l scraper. 6-D.C., 1 § HWDP, ,9-135 D.P. Drilling Assembly REMARKS - F'mished pulling and laying down tubing out of hole. Slit~ & cut ddll line. Pul out 2-7/8" pipe rams. InsmJ & test 3-1/2" pipe rams to ;30C0 psi. Instal test plug. Test UlOf>er and lower kelly cock to 3000 IOSi. O,K. Pu~l test piug and install wear ring. Rig t~ to pick up tail pipe. casing scraoer assy and pick t~ 3-1/2" D.P. work. s~ing. -Rm in hc~e to top of ~avet pack, packer ~-nd reverse out. Crcutate ~c~ Wscos~ ?il and begn ~-~p~nc~ out of hole. ! PREPARED B'r VIRGIL THqA PP V.1.3/1-4-94 ClRI PRODUCTION COMPANY 2525 C STREET - SUITE 500- ANCHORAGE, ALASKA 99509 (907) 274-8638- FAX (907) 279-8836 DAILY PROGRESS REPORT WELLNAME-NO. WEST FORK 1-21RD (AFE OWl080) RIG NO. COOPER CON3T. ~1 DEPTH TODAY P&A porlJon of prograrn DEPTH YESTERDAY 5447 24 HR. FOOTAGE ~VALUE! DATE 2/8/94 DA YS (fi-om acceptance) 5 13-3/8" Casing set at 140 9-5/8" Casing set at 2143 7" Casing set at 5447 6" Liner set @ T.O.L. @ BIT DATA: I Depah Deplh Bit C~dilion Ho. Size Type In Out Feet Hrs. Noz. (9,9.9) T B i i i i i i i i i i i i ~ .; i i i i i i BIT WT. It, iD.1 1'10.2 I RPM I PUWT. I S.O. WT. I ROB. I PUMP DATA MFG. MODEL LINER STROKE '(~98% SPM GPM PSI ' SPM PSI · GARDNER-DENVER PZ-9 ! 6 ! 9 ! 0.08bps ! 72 ! 237.4 i 800 OILWELLZI4P ! 5.75 i 14 i 0.14bps ~ :' ! ! :' ; ; ; ; ; I SURVEY DATA Devia~on Direction TVD I ~o. I L~de i i i i i Circula~g Rates I Slow pump rates I Departure i i i i i DRILLING FLUID I APl HT-HP Time Wt Funnel Vis PV YP Gels pH P-il Fil Cake Cl Ca Pf Mf Sand Sol Oil Cec Remarks 0.15 i 1.00 i 0 i 5.0 :: 0 i 18.0 Ddlling Assembly REMARKS - Fnish tripping out casing scraper mn. Change bosom hole assy. to gravel pack retrieving assy. Tr~ in hole to too of gravel pack assy. Reverse ctculate to wash down top of assy. Tag up and screw into gravet pac~. Begin jarring on packer to release. PREPARED BY VIRGILTHRA PP V.1.3,'1-4-94 CIRI PRODUCTION COMPANY P'~25 C STREET- ,SUITE 500- Af, ICHORAGE. ALASKA 99509 (S07) 274-8638- FA/, {907) 279-8836 DAILY PROGRESS REPORT WELLNAME-i'.IO. WEST FORK 1-21RD (AFE OW1080) RIG I"10. COOPER CONST. ~1 DEPTH TODAY P&A por'~on of program DEPTH YESTERDAY 5447 24 HR. FOOTAGE ~V/~LUE! DATE 2~/94 DA YS (from acceFtance) 6 13-3/8" Casing set at 140 9-5/8" Casing set at 2143 7" Casing set at 5447 6" Liner set @ T.O.L. (~ BIT DATA: [ Oep~ Depm Bit CondilJon r, lo. Size Type In Ou~ Fee'[ Hrs. r, loz. (9.9.9) T B ~ bLrnng shoe/wash pipe ; ~ { '.' i : ! j j i i IND.1 r-ID.2 IPUMP DATA I Circulat~g Rates I Slow pump rates I ISURVEY DATA t Dewa:on j Oir-_~on MFG. MODEL LIFIER STROf':E '~98% SPM GPM PSI ' SPM PSI · GA RDHER-DEHVER PZ-9 i 5 OLWELL214P ! 5.75 ; i ToteJ!, i ! GPM ! · : i I i i i i DRILLING FLUID ! AR k-Fi'-HP Time ;'it Funnel Vis PV 'tP Ges pM ~ FTI Cake CI Ca 0500 i gO i ~ ; 9 i 4.0 i 2'12 i 8.5 i 14 ! ! 2 i _-'200 i 40 Pf Mf Sand Sot Oil Cec qemart, s 0.25; 1.00 i 0 ! 50 :, 0 i 180 ! Drilling Assemcly Washover b,.cnin~ shoe Ass)/. :&hoe. V,' P Ext. W/P. W,"O Boot bask.~t. DbL Pin. 2 Boot baskets. bff, suo. bumper sub. oi jars. 10 DC. 14 HV'/DP REMARKS - Relieved or~y a portion of gravel Dad~ assy. Ported screen assy parted. Econorr~cs of briber a~rots to remeve remar~der of ta~v~pe assy. poor. Op~ for S~ngle run washover w~ bunng shoe taken. Called cut Tristate wi~h wesh p:pe ar~ btrnmg shoe equp,ment Tripped in hole to top of fish and began m~ling. FREPA RED B T ',/fRGIL TH2.A 2p V.1.3/1-4-94 CIRI PRODUCTION COMPANY 2525 C STREET - SUITE 500- ANCHORAGE. ALASKA 99509 (907) 274-8638- FAX (907) 27~8836 DALLY PROGRESS REPORT WELLFIAME-NO. WEST FORK 1-21RD (AFE OW1080! RIG NO. COOPER CON:ST. ~1 DEPTH TODAY P & A pc~on of program DEPTH YESTERDAY 5447 24 HR. FOOTAGE 4~/A LUE! DATE 2/10/94 OAYS (from accc'l~ance) 7 13-3/8" Casing set at 140 9-5/8" Casing set at 21,43 7" Casing set at 5447 6" Uner set @ T.O.L. (~ BIT DATA: [ Depth Deptl Bit CondilJon No. Size Type In Ou~ Fee~ Hrs. Noz. (9.9.9) T 8 b~Ting s~oeJ wash pipe ' Slow pump rates PUMP DATA I Circulamg Rates ~ HO.2 MFG. MODEL LIr, IER STROKE '~98% SPM GPM PSI ~ SPM PSI i · GARDNER-DENVERPZ-9 ! e i 9 i0.08bpsi 55 i 181.3 OILWELL214P ! 5.75 ; 0evia~on ! oir~mon TV01s~mc" ILamde I Oepar~re · : i i : : DRILLING FLUID ! APl HT-HP Time Wt Funnel Vis PV '¢P Gels pH Fit Fil Cake CI Ca OG:)0 { 9.0+ i 40 i 9 i 8,0 i 2J12 { 8,5 i 14 i :' , i · i i i . i iiii i i i 1 Pf Mf Sand Sol Oil Cec Remarks , , Ddlling Assembly REMARKS - F'ni~h bumir~ over sump packer;fish. Push same ~o 517'2'. Ci'cula[e hiqh viscosi~ swe~ around. Hydrautc li~e broke ~ ng sub ama sl~ling a~f~rox. 35 gal. Re, or, ed s~l to ADEC and was a~s~neU s~ii nurrt~er 94-2-3-~-041-1 by Gary Folley (ADEC). Pro~uc~ S~lled ceto I~as~c inet pieced ~der riq and was rno,l~ed uo w~ absorber~ Dads. ~Iaced in CaSllc ba(:~lS and l~n~,, stored in I~ed ~ berm. Pic~ u~ casir~g scr~toer assy and ran i~ ho~e m tol3 of B-6 ¢~rfora~ons a~ 514.3'. Circulated high viscose/sw e~ a~d pt~lecl ou! cf ho~. Boah mos were stow due to swabbng effec'~ of tools in ~ne hole. PRE?ARF:D B'f VIRGILTHRAPP v 1.3, ~ -4-94 CIRI PRODUCTION COMPANY 2525 C STREET - SUITE 500- ANCHORAGE. ALASKA 99509 (907) 274-8638- FAX (S07) 279-8836 DAILY PROGRESS REPORT WELLNAME-NO. WEST FORK 1-21RD (AFE OW1080} RIG NO. COOPER CON~T. ~1 DEPTH TODAY ~102 PBI' DEPTH YESTERDAY 5447 24 HR. FOOTAGE ~VA LUE'I. DATE 2/11/94 DA YS !from acceCance) 8 13-3/8" Casing set at 140 9-5/8" Casing set at 2143 7" Casing set at 5447 6" Liner set @ T.O.L. ~ I BIT DATA: J De~h Dep~ Bit Con,on No. Size Type In Out Feet Hrs. r,.Ioz. (9.9.9~ T B retainer and set, rig tool i i i i i i i i i : : .: i : : BIT WT. NO.2 J RPM j PUWT. 44k J S.O. YeT. J ROB. ~ Slow pump rates I PUMP DATA I Circulamg Rates I MFG. MODEL LINER STROt~E '(~98% SPM GPM PSI ~ SPM PSI . GARDNER-DENVER PZ-9 i 6 i 9 i 0.08bps { 55 i 181.3 -~ 550 OILWELL214P ! 5.75 i 14 10.14b~s ~ i i :' : I 55 DRILUNG FLUID I APl HT-HP T~me Wt Funnel Vis PV YP Ge~s pH P-ii ~ Cake Cl Ca i ii i , i · i i ; ; ~ ; ; ; ; ; ; : ; ; ; ; ; ; ; ; Pf Mf Sand Sol Oil Cec Remarks o.251 .oo i o i i o i I cement retainer and seizing Drilling Assembly ' REMARKS - Fnish mi3png out w~ casir~ scraper. Rig up A~as wir~tine and conducl SBT from 5100 to 2800. Mer~guiz~ang & Roger S~:kney cYoserved log[lng opera, Ohs and analyzed logs. Recon~acted AOGCC reoresemaave Blare W ondzetl regardhg a re~'esef~awe observance of ~ P & A por~ons of t~is wel. He said none would besent Pi~,,~:luDbnd~e,~b~l on w~mlne. Ranandset same ~ 51C~'. Ran~laUqe mg ancliunt basketto mo ofc~u~l. Picked up cerne~ rear,er on dali OiDe and began rumi~g in hole for 8-4 sand isola~n squeeze. ( PREPARED BY VIRGILTHRA PP v .1.3 ,' 1 -J.-94 CIRI PRODUCTION COMPANY 2525 C STREET * SUITE ~- ANCHORAGE. ALASKA 99509 (907) 274-8638- FAX (907) 279-8836 DAILY PROGRESS REPORT WFtLNAME-NO. WEST FORK 1-21RD (AFE O'~1080] RIG NO. COOPER CONST. ~1 DEPTH TODAY 4,903 PBT DEFrFH YESTERDAY 5102 24 HR. FOOTAGE ~/ALUE! DATE 2/12/94 DA YS (from acce~ance) 9 13-3/8" Casing set at 140 9-5/8" Casing set at 2143 7" Casing set at 5447 6" Uner set @ T.O.L (~ ! DATA: ~ Depth Deplh Condiion No. Size Type In Ou~ Feet Hrs. Hoz. (9.9.9l T 8 :- dualisotalJon packer assy .~ , ~ i i i i i i ., i ir, lo. 1 NO.2 MFG. MODEL PUMP DATA I Rates ~ Slow ! Ckcuiamg ! I LINER STROKE '@98% SPM GPM PSI ' SPM I · GARDNER-DEIXNER P7-9 i 6 i 9 i 0.08bps ! 55 i 181.3 ! 550 ! ; (~LWELL214P 5.75 · SURVEY DATA Deviaion Direcion , i i i i i i DRILLING FLUID ~ APl HT-HP Time Wt Funnel Vis PV YP Gets pH Ft Fit Cake CI Ca I:>f Mf Sand Sol Oil Cec Remarks 0.25 ~ : ~ ~.oo i o ; so i o , ~8.o : : : Odlling Assembly Dual isola~on oacker assy. fBI-Ill REMARKS - Run in hole w~ cernentretainer on dril pipe. Broke circulaton and set r~amer q~ 495Ct. Esta~sned crculaang rate of 1 b~m q~ 1 ~ psi. Uns3ng from packer. Batch mO( 12_0 ppg. rncramamx cement Pumped 18 bbl StUTy cemem holdng 300 psi back pressure on choke. S~g into retai~er § bus. prior to cement arrival. Reduced [~umo rate m 1/4 b~m s~j ?,-z~(j away 7 of18 bbis. Then I:~an heSr~mn soueeze waJ, in~l to soueeze one after four to ,ire minute pauses. To, at quanli~y, of cemen~ (es~rnamd) squeezed away 15 bbl. Unstt~g from pack er and reversed out Cerne~qtol~s e~v ed on bosoms up and durrped iD reserve lank. A~emots ~o im'esstxe ms[ casmng wile n hole faJed. Tri3ped ou~ of h<3le and real1~mp~d pressure tesiof caS~qg. ~tJrface casing test fmled. Called cuI 8HI toolrnan with dual isolation pa~er system. Began [esing old perfora~on zc~es from the boEom Locamd ~herf zone wtich is across ~he fui "A" sand pedoraaon zone. Tripped ou~ and caied otz HaJJburton to conoJ~ s~ueeze. (CYdered 150 sx 'G' w~ Halad,'OFR) PREPARED B ~ VIRGIL THRAPP V.1.3/1-4-94 CIRI PRODUCTION COMPANY STREET - SUITE 500- ANCHORAGE. ALASKA 99509 (907) 274-8638- FAX (9071Z79-8836 DAILY PROGRESS REPORT WELLNAME-NO. WEST FORK 1-21RD (AFE OW1080] RIG NO. COOPER CON:~T. ~1 DEPTH TOOAY ~ DEPTH YESTERDAY 4,950 24 HR. FOOTAGE -389 DATE 2/1 3/9'4 DA YS Ifrom accel~ance) 1 0 1 3-3/8" Casing set at 140 9-5/8" CaSing set at 2143 7" Casing set at 5447 6" Uner set @ T.O.L (~ BIT DATA: I Oep~ De13111 8~ Condl~on No. Size Type In O~ Feet Hrs. Noz, (9.9.9~ T B dualisola~ion pas er assy ~ '-' ~ ~ i ! i i i i i i i BIT WT. IND. 1 NO.2 I RPM [ PUWT. .44k J S.O. w-r. I ROB. IPUMP DATA I Circ~lamg Rates MFG. MODEL LINER STROKE '@98% SPM GPM PSI ~ SPM PSi GARDNER-DENVER PZ-9 i 6 ! 9 ! 0. CS~s ! 55 ! 181.3 ! 550 i ,: ~ 5.75 ::' 14 C~LWELL214P SURVEY DATA I Direction TVD J SeclJon Slow pump rates Oevia~on t La~lUde J Deoar~ure . . DRILLING FLUID ! APt HT-HP Time Wt Funnel Vis PV YP Gets pH F'd ~ Cake CI Ca i ; I ; ~ ; ; ; ; ; ; Pf Mf Sand Sol Oil Cec Remarks dual isolation Deck er assr Drilling Assembly REM ARKS - Set Iow er bridge tug at 4715 ft. First at, error to spot 4 sacks of sand on too of plug faled. Second aEernl~ O.K. leavng 1(7 of sand on plug. Pull u~ m uack er sermg o e~)tl. Rig u2 Hallbtrton. mst ines Batch mix 30+ bbt of 15.8 pog C~ass 'G' cemen~w~ CFR & Halad remrdant PurrD cement and set pe~er at 4.561' ?ior to cemen~ amVal at perfs. Be~Tn s ,aueezncj. Ir~l:Jal ~ect~n 2 bom (~ ~n0 oSL subseauer~ rams w ere at35bblaway, rate of iqec~on 1 bom. 32~p~: at S.0 bbl away. rate of hjec3on 1 bom. 47'5psi. at 6.0 bbl aw ay. rate of iqecion 1 t~m..330 psi. at 6.~ bbl away. ra~e of iniec~on 1/2 bom. 900 cs~. ~t 710 I:folaway. rate ofin~cOon 1/2bprrt 1300psi. arS.0 bbi away.rate of hle~ 1/4bpm. 1600 psi. at 9 bi31 aw ay, ram of t~jec'z)n 1,'4 bom. 19(X) psi. at 11 bbl away. rare o/iqec3on 1/4 ~m. 1925 Dst at 13bbl away. rat~ ofiniec3on 1/'2bpm. 1933 psL at 15 bbl away. rate ~ecocn 1,'3 bcm. 1940 esl. at 16bbl away;ram of i~jec~n 1,3 bom. H~:5-'~a1~n =clueez~ 4 rnn pause. 1 bbl. 1/4 borrt 18501~ bled ~o 750n 2nln. Hesitation squeeze 4 rnn pause. 1 bbl. 114 b~m. 1950 psi bled to ~ n 2 ~. H~a~n ~ze 4 mn ease. 1 ~1. 1/4 b~. 1 ~ ~ b~d ~ ~ h 2 ~n.: ~ 1 ~L 1/4 b~. 1~ ~ b~d m 1~ PR~A RED BY VIRGIL TH~PP V 1.3,' 1-4-~ CIRi PRODUCTION COMPANY 2525 C STREET · SUITE 500. ANCHORAGE, ALASKA 99509 (907) 27~3~ ° FAX (907) 279-8836 DALLY PROGRESS REPORT WELLNAME-NO. WE[~T FORK 1-21RID (AFE RIG NO. COOPER CONST. DEPTH TODAY 4705 DEPTH YESTERDAY 4561 24 HR. FOOTAGE 144 DATE 2/t4/94 C)AY$ (from occepton~) 11 13~3,/8" Casing ~t al 140 g-5~" Casing ~t al 21~ 7" Casing sot at 5447 6" Liner set ~ TO,L, ~ BIT DATA: J Depth No. Size Type In Bit Condition T Et Depth Out Feet Hre. Noz. 4705; ~ OPENTFA , BlT WT L MFG. MODEL 1 38 k PIJMP DATA J Circulating Rates '~ Slow pump rates LINER STROKE '~;~98% SPM GPM PSI i , i i i GARDNER-DENVER PZ-9 OILWELL 214P [ 5,75 JSURVEY DATA I DRILLING FLUID I Time Wt Funnel V'm PV · · YP Oel~ pH I1.0 i 12 : I1,0 i Oil Cee RemarKs ' .: Retrmv-o-mat~c isolation packer assy. Pf ldf 9a~d Sol z.oo ~ 3.0o i 0.20 i 5.0 Drilling As~mbly APl HT-HP Fll FII Cake C! Ca P.O~; REMARKS - Release back pressure on squeeze, unseat packer, and trip out of hole, Pull wear bushing and set test plug_. Conduct BOP teat. Inaide Kill line valve would notJ~ass the test. Remainder of BOP'a tested. Contacted DSR regardlng.r~eplacement of Kitt Ilna valve. We coiq~lrit.l~l to work o!3 failing valve and eventuall7 was able to get at full test. D~R sent down three extra v~lvee, Pulled test plug and reset wear bushil~g, PicKed up 6" blt with HWDP and tripped in to. t~op of.cement, Tagged cement et 4571 It. Cement took weight. Cement h~d cured 30 hours and samples were fully hardened, Drilled off cement fo sand break on top el bridge plug. Olreulated hole clean and trip out of I~ole. O600- OPERATION' Preparing to run tn hole with Retrleve-o-m~ti~ to isolate exact theil zone. PREPARED BY VIRGIL THRAPP V. 1.31 I-4-94 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page: 1 Date: 12/21/93 SCALE DATE_RECVD 90-143 CET L 2500-5350 5 01/22/91 90-143 CET L 2500-5350 5 01/22/91 90-143 CET L 4750-5245 5 01/22/91 90-143 COMP L 4900-5200 5 01/22/91 90-143 CYB L 2145-5460 5 01/22/91 90-143 DGR/EWR/FXE/EWC L 4412-5464 2&5 01/22/91 90-143 DGR/EWR/FXE/EWC L 4412-5464 2&5 01/22/91 90-143 DIL/SFL L 140-5460 2&5 01/22/91 90-143 DIL/SFL L 2145-5460 2&5 01/22/91 90-143 GRAVEL PACK LOG L 4800-4990 5 01/22/91 90-143 LDT/CNL L 2145-5460 5 01/22/91 90-143 MUD L 140-5459 1 01/22/91 90-143 PACK L 4900-5076 5 01/22/91 90-143 PERF L 2650-5350 5 01/22/91 90-143 407 R COMP DATE: 05/06/91 05/26/91 90-143 DAILY WELL OP R 12/20/90-02/26/91 05/26/91 90-143 OPEN FLOW TEST R GAS WELL POTENTIAL FLOW 10/24/91 90-143 DRY DITCH S 120-5449, SET #798 02/12/91 90-143 4760 T 4412-5465 01/22/91 90-143 4812 T 119-5475, OH/FINAL 01/22/91 Are dry ditch samples required? ~ no And received? ~ no Was the well cored? yeF~-~h Analysis & description received? yes no tests required~~~ no ..Received? ~~ no Well is in compliance Comments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator Opera.on shutdown __ Re-enter susDendecl well __ Plugging ~ Time exlensJon __ Sbmulate __ Pull tuDmg __ Vanance __ Pedorate __ O~er __ Abandon __ Suspend __ Alter casmg __ Reoa~r v,~tl __ Change approved program __ CIRI Production Company Type of Well: 3. Address 2525 "C" Street, Anchorage, Alaska 9950 4. I..ocat~on of well at sudace 1984 FNL, 1707 FEL, Sec. 21, T6N, R9W, SM At too of productive interval 1984 FNL, ]-707 FEI,, Sec. 21, T6N, R9W, SM At effective depth 1984 P.,IL, ].707 Fgi`, Sec. 21, T6N, Rgw, SM At total depth 1984 FNL, 1707 FEL, Sec. 21, T6N, R9W, SM Oevetooment X: Exploratory __ Strat~graDnic __ Se~ce __ Datum etevauon (OF or KB at 332 7. Unit or Proper~y name West Fork Gas Field 8. Well number CIRI West Fork 1-21 9. Permtt numuer 90-143 10. APt numoer .5=0_ ].33-20424 11. Field/Pool West Fork Gas Sterlin~ 'A' and 'B' 12. Present well condition summary Total depth: measured true vert~cat 5459 feet 5459 fee[ Plugs (measured) Effective depth: measured ~ 5447 true vertical 5447 feet feet Junk (measured) Casmg Length Size Structural Conduc:or 140 ' ' 13-3/8" Sunace 2143 ' 9-5/8" Intermediate Production 5447 ' 7" Liner Perforationdepm: measured 4982'- 4992' Cemented Measured deOth Pue ve~[ca~ deeth To Surface 140' 140' To Surface 2143' 2143' To 3600' 5447' 5447' 5143'- 5153' RECEIVED truevenicat 4982'- 4992' 5143'- 5153' DEC 1 6 1995 Tuhing(sue, grade, andmeasureC~de¢m) 2-7/8", N-80, 5063' (I"[D) Alaska 011 & Gas Cons. Commission Anchorage PacXersandSSSV(typeandmeasureadeoth) Baker Model 'D ' sump packer @ 5000' (~,[D) Baker Model SC-iL ~rave! pack packer @ 4838", Baker 2-7/8" SSSV @ 455' 13. Attac. nments Oescnpt~on summary of prooosal ,~ STEPS I through 27 apply. 14. Estzma[ed date for commend:nD opera[zen 28 December 1993 16. II proposal was verOaily auorcvec Name of aDorover Oate approved OetaJied operatJons program __ ROP sketch __ 15. Status of well cJassfiicaucn as: Oil __ Gas ~ Suscenaed SerVice 17. I he-,~d~[ ~ fo~n~ correct to me pest of my knowiedge. Signed "~i~i! Thfapp' ~-- Title Consultant FOR COMMISSION USE ONLY 12-!6-93 Condmans ot aooravat: Notify Comm~smon so reoresenta,ve may w~mess P!ug mtegnw ..2/_ BOP Test __ Locauon c:earance __ Mecnan~caJ Integnty Test __ Su~sequen: form required lO- Original Signed By David W. Johnston A¢aroved by order of the CommtSS~on / ,:)~,'oved Copy. Returned 7.~- ~/';'- ~' 9 -- Comm.smoner Oate/ z../'-~ ~/'~72 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLJC.,ATE WF 1-21 RD WELL NAME' WF 1-21 RD AP! No.' Pending SummaryRECEIVED DEC ~ 6 19~3 Alaska 0il & Gas Cons. Commission Anchorage SURFACE LOCATION' 1984 FNL, 1707 FEL, SEC 21, T6N, R9W, SM AT TOTAL DEPTH' 2071 FNL, 1738 FEL, SEC 21, T6N, R9W, SM 1. Rig up over well and mix 350 bbls. of 8.9 ppg kill fluid. 2. Set BPV in tubing and release pressure on control line to close SSSV. 3. Nipple down tree and nipple up @OP's. Ensure both 2 7/8" and 3 1/2" rams installed. 4. Set test plug and test BOP's. Ensure AOGCC representatives notified and on site to witness test. Pull test plug when acceptable test complete. 5. Puli BPV from tubing string and pressure up on SSSV control line to open valve. 6. Rig up wireline unit with lubricator, run in hole with shifting tool on wireline, ope. n sliding sleeve and pull out of hole. 7. Kill well by reverse circulating kill fluid down annulus and taking returns through tubing which will be Lined up through the choke manifold. 8. Run in hole with shifting tool on wireline, close sliding sleeve and pull out of hole. 9. Pick up approximately 4700 ft of 3-1/2" I.F. drill pipe in mouse hole & stand back in derrick prior to pulling tubing string. Ensure 3 1/2" I.F. (box) x 2 7/8" AB-DSS (pin) crossover, floor valves, etc. are on the rig floor for possible well control situation while pulling and laying down tubing. 10. Pull and lay down tubing and heater string. (Remove from location - these materials will not be reused.) 11. Pick up gravel pack fishing assy., run in hole and retrieve gravel pack packer and screen assy. 12. Make up, run and shear out bull plugged snap latch seal assy. into sump packer at (5000' MD/TVD). (This is for P&A isolation of the B-6 sand [5143' - 5153'].) 13. Conduct CBL/SBT logs across the "A" sand (4635' - 4690' MD/TVD) and kick off point for whipstock (4840' MD/TVD). 14. Pick up, run and set cement retainer 5 ft. above top perforation of B-4 sand (4977 MD/TVD). 15. Conduct cement squeeze of B-4 sands (4982' - 4992' MD/TVD) with approx. 10 bbls. of Class 'G' 15.8 ppg cement. Rev. 16. Pull out of cement retainer and reverse out excess cement. 17. While still in hole just above retainer mix and displace approximately 9 bbis Class 'G', 17 ppg. cement leaving a balanced plug on top of retainer.(Estimate column height 235 ft. with top of cement approximately at 4742 ft.) This cement column is being set primarily to meet AOGCC requirements for P&A of the lower section of the well and to provide a footing for the "A" sand isolation squeeze as noted later in the program. 18. Puli enough drill pipe to be above the top of the projected cement column and reverse circulate until fluids have cleaned up. 19. Trip out of hole and pick up perforation guns and run in hole. 20. Perforate above and below the "A" sands formation for an isolation squeeze at [4630' - 4632' MD/TVD (4 SPF) and 4692' - 4694' MD/TVD (4 SPF)]. 21. Trip out of hole and lay down perforation guns. 22. Run in hole 'open-ended' with mule shoe to top of cement at approx. 4742 ft. 23. Mix and displace a balanced cement plug with the top of cement 150' (4480' MD/TVD) above the top perforation of the "A" sand as noted in item #20. 24. Pull drill string above top of projected cement column and reverse out until returns are no longer contaminated. 25. Condudt a staged bradenhead squeeze of the isolation perforations at the "A" sand by closing the pipe rams, close choke and pressuring up on drill pipe. Hold pressure on squeeze for 2 hours noting any pressure bleed down during that period. 26. Trip out of hole, pick up clean out assy. and run in to top of cement. Wait on cement, if necessary, until it will take 5,000 to 8,000 lbs. bit weight. 27. Depending on the CBL/SBT analysis of cement and collar location the 'Kick-off- point' may vary slightly to optimize the milling operation. Drill out cement to whipstock kick off point with a minimum depth of 4840' but no deeper than 4882' which is the AOGCC P&A requirements of being 100' above top perforation of B-4 sands (4982'). (Contact AOGCC representative prior to drilling off any cement as they rr~y_ wish to send a representative for observation and verification of the cement top.)J'~'E6~ I VE D Document final depth of "Top of Cement" of plug back on daily Al DC report. 28. Circulate hole clean and ensure a balanced fluid column. DLcC '~ 6 1~ Alaska 0il & Gas Cons. Co~m/ssJort 29. Pressure test casing to 1500 psi for 30 minutes. Record results per AOGCC regulation 20 AAC 25.070 (a)(1). Anchorage 30. Trip out of hole, pick up casing scraper assy. and conduct casing scraper run to kick off point. 31. Circulate hole clean and trip out of hole. 32. Run in hole with gyro survey tool and seating packer for whipstock. Run survey, orient and set seating packer. Rev. 1.1 33. Pick up whipstock and starter mill assy. and run into hole to seating packer and latch in. 34. Mill window in 7" casing. Trip for mills, as needed. 35. Once 10 ft. of open hole established conduct a formation integrity test to and equivalent weight of 13.2 ppg. 36. Pick up bent sub mud motor, orient and directionally drill 6" open hole approximately 300' to a TD of 5122 ft. Build angle at 18° per 100 feet until angle reaches 26°. and then hold angle to TD with conventional rotary assembly. 37. Wipe hole as hole conditions warrant. (Minimum - every 12 hours of drilling.) 38. Circulate and condition hole for logs and trip out of hole. 39. Conduct open hole logs. (SP, DIL, GR, Caliper) 40. Pick up underreaming assy. and underream open hole to 8" diameter. 41. Circulate bottoms up or until hole cleans up. 42. Conduct wiper trip and condition hole to run liner. 43. Run 5" liner/shoe/float/hanger. 44. Pump 90 sacks 'Trinity Lite Wate' cement (13.2 ppg) followed by liner hanger actuator wiper dart and hang liner at 4740'. 45. Trip out and pick up 7" clean out assy. and clean out 7" casing to top of liner hanger. 46. Circulate hole clean. 47. Trip out and pick up 5" clean out assy. and clean out 5" liner to float collar. 48. Circulate hole clean. 49. Test casing to 1500 psi for 30 minutes. Record results per AOGCC regulation 20 AAC 25.070 (a)(1). 50. Conduct CBI,/SBT of 5" liner and "A" sand squeeze zone (4630' - 4694' MD/TVD ). 'Cement Bond Log analysis [Evaluate and Squeeze as needed] 51. Clean pits and mix up brine completion fluid 8.6 ppg 3% KCI brine. 52. Displace hole with 8.6 ppg brine. 53. Filter Brine while circulating until NTU's <50 units at flow line. 54. Trip in hole with perforation guns and packer assy. filling tubing with sufficient brine to achieve proper underbalance. 55. Set packer and perforate B-4 zone (4990' - 4996' MD [ 4985' - 4990' TVD] (8 SPF)). Rev. 1.1 RECEIVED DEC ] 6 199,~ Alaska Oil & Gas Cons. Commission Anchorage 56. Conduct short confirmation flow test of B-4 sands through manifold into CPC's production facility. 57. Release packer, reverse circulate to kill well. 58. Trip out of hole and lay down perforation guns. 59. Pick up gauge ring and run in hole through gravel pack zone to ensure proper clearance. 60. Pick up gravel pack assy., run in hole and set across B-4 perforations and trip out. 61. Pick up gravel infuser assy., run in hole and gravel pack B-4 sands with 50-70 mesh sand. 62. Reverse out excess sand and trip out of hole. 63. Run in hole with dummy plug and isolate B-4 gravel pack and trip out. 64. Trip in hole with guns and perforate "A" zone [4635' - 4638' MD/TVD (4 SPF), 4659' - 4665' MD/TVD (4 SPF) and 4680' - 4690' MD/TVD (4 SPF)]. There is no planned conformation flow test for this sand. 65. Trip out of hole and lay down perforation guns. 66. Pick up gauge ring and run in hole through gravel pack zone to ensure proper clearance. 67. Run in hole and retrieve dummy plug on top of B-4 gravel pack. 68. Pick up "A'° sand.gravel pack assy., run in hole and set across "A" perforations and trip out. 69. Pick up gravel infuser assy., run in hole and gravel pack "A" sands with 50-70 mesh sand. 70. Reverse out excess sand and trip out of hole. 71. Run 2-1/16" and 2-3/8" dual completion tubing on Baker AL-5 Dual Packer and 3000' of heater string. 72. Set BPV's in tubing strings. 73. Nipple down BOP's and nipple up and test Production Tree. 74. Pull BPV's. 75. Rig up slick line and nitrogen equipment, surge tank and flare boom. 76. Displace each string with nitrogen and flare separately. 77. Lay down 3-1/2" drill pipe in mouse hole. 78. Release rig. RECEIVED DEC 1 6 1993 Alaska 0il & Gas Cons. Commission Anchorage Rev. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 March 31, 1992 Margaret L. Brown CIRI Production Company P. O. Box 93330 Anchorage, Alaska 99509-3330 Re: West Fork Field Development Dear Ms. Brown: This letter will serve as a summary of the situation regarding continued development of the West Fork Gas Field. The West Fork 1-21 well was permitted in 1990, drilled and completed in 1991 and gas production commenced in September 1991. This well is located in section 21, T6N, R9W, Seward Meridian. The southwest quarter of this section is unleased federal acreage. The accepted drilling unit for a gas well in Alaska is 640 acres or one section. Since CIRI does not own all of the gas rights in this drilling unit, 20 AAC 25.055(d) requires a pooling agreement for development. The Commission recently approved the West Fork 2-21 well permit with. conditions regarding the pooling agreement. ~.~ Io Also, 20 AAC 25.517 requires a plan of development and integration of interests be submitted to the Commission for approval prior to development and operation of a gas pool. In addition the commission recommends that CIRI Production Company apply for a pool rules hearing to define the gas pool and prescribe rules for development. These issues have been discussed with Erik Opstad and Kevin Brown. The Commission appreciates their efforts to address our concerns and work towards timely solutions. Sincerely Russell A. Douglass Commissioner CIRI PRODUCTION COMPANY WEST FORK 1-21 SAMPLE NO. 1 SAMPLED~ 1-26-91 @ 0826 HOURS 461 PSIG & 89.09OF H~D~N~YSIS OF SEPARATOR~a.S SEPARATOR GAS COMPONENT GPM @ MOL % 14.70 PSIA HYDROGEN SULFIDE 0.00 CARBON DIOXIDE 0.03 NITROGEN 1.39 METHANE 98.48 ETHANE 0.10 PROPANE 0.00 ISO-BUTANE 0.00 N-BUTANE 0.00 ISO-PENTANE 0.00 N-PENTANE 0.00 HEXANES 0.00 HEPTANES PLUS 0.00 0.027' 0.000 0.000 0.000 0.000 0.000 0.000 0.000 TOTALS 100.00 0.027 CALC. GAS SPECIFIC GRAVITY (AIR=i.00) = 0.5613 SEPARATOR~ GAS SEP. GAS HEAT OF. COMB. (BTU/CU. FT. @ 14.70 PSIA & 60OF) DRY = 998.6 REAL SEP. GAS HEAT OF COMB. (BTU/CU. FT. @ 14.70 PSIA a 60°F) WET m 981.2 WATER SAT. SEP. GAS COMPRESSIBILITY (6 i ATM & 60°F) Z m 0.9981 REPORT NO. 4936-4881 PAGE 2 OF 3 CIRI PRODUCTION COMPANY WEST FORK 1-21 SAMPLE NO. 2 SAMPLED= 1-26-91 @ 0846 HOURS 471 PSIG & 86.07°F HND~NANALYSIS OF SEPARATOR C~S COMPONENT SEPARATOR GAS GPM @ MOL % 14.70 PSIA HYDROGEN SULFIDE '0.00 CARBON DIOXIDE 0.03 NITROGEN 1.11 METHANE 98.75 ETHANE 0.11 PROPANE 0.00 Iso-BUTANE 0.00 N-BUTANE 0.00 ISO-PENTANE 0.00 N-PENTANE 0.00 HEXANES 0.00 HEPTANES PLUS 0.00 0.029 0.000 0.000 0.000 '0.000 0.000 0.000 0.000 TOTALS 100.00 0.029 CALC. GAS SPECIFIC GRAVITY (AIR=I.00) = 0.5602 SEPARATOR GAS SEP. GAS HEAT OF COMB. (BTU/CU. FT. @ 14.70 PSIA & 60°F) DRY = 1001.6 HEAL SEP. GAS HEAT OF COMB. (BTU/CU. FT. @ 14.70 PSIA & 60°F) WET = 984.0 WATER SAT. SEP. GAS COMPRESSIBILITY (6 I ATM & 60°F) 'Z ~ 0.9980 REPORT NO. 4936-4881 I UJ'(RTH(RLY~LRBORRTORI(S] PAGE 3 OF 3 ALASKA OIL/k~ GAS CO~SER¥~XTIO~ COMMISSIO~ December 4, 199I WALTER J. HICKE/.., GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501<3192 PHONE: (907} 279-14.33 TELECOPY: (907) 276.7542 Karen Wood Alaska Center for the Environment 519 West 8th Ave, Suite 201 Anchorage, Alaska 99501 ' ................................. .i... ,:.~ ........... ~::::~ ...................... q ~ ,,,-- r ~',,' /'~t~'~';' West FOrk 1-21, ~er Disposal Permit Dear Ms. Wood: Thank you for forwarding a copy of your November 22, 1991 letter to Mr. Dolan concerning the West Fork 1-21 well. I want to take this opporumity to clear up certain miconceptions you have concerning AOGCC's "recommendations'' to CIRI to pursue surface disposal. Because of the geotechnical considerations, an injection option in the area of the West Fork 1-21 well may not be certain. Accordingly, we suggested that CIRI consult with the Department of Environmental Conservation about surface disposal. Given the Iow TDS content of the produced waters reported by CI~, surface disposal may be permissible under ADEC regulations. We believe it is prudent for any operator to consider all alternatives' before committing to an injection program, which may not be necessary in this case if the produced waste stream meets freshwater standards. Should ADEC determine that surface disposal is acceptable, drilling a designated injection well would prove unnecessary. Commission statutes def'me the drilling of unnecessary wells as waste under AS 31.05.170(14)(J). Should injection prove to be the only feasible disposal option, Commission oversight will help insure that no underground sources of drinking water are endangered and that injected fluid does not escape to the surface. To date, there have been no documented instances of contamination of fresh.water aquifers due to Class II injection. While ACE may not have confidence in our ability to adequately monitor and regulate injection activity, our. track record Speaks for itself. Since achieving primacy for the state's UIC Class II program in 1986, the Commission has worked closely with the U. S. Environmental Protection Agency to develop a sound and responsible program. EPA's annual reviews have concluded that we administer an effective program with considerable technical expertise. In the future, should you have any question concerning our position, I encourage you to contact us directly. CC. Robert Dolan, DEC Eric Opstad, CIRI L071- I ~9 West 8th Ave. #201 · Anchorage, Alaska 995()1 · (9()7) 2~.,i4a~-{~2'1 ~/:,,. , November 22, 1991 · ~a_a~~ Mr. Robert Dolan ' -g~p ~. ~aska DePartment of Environmental Conservation ~ECEiVED Southcentral Regional Office ~'~~~ 3601 C Street ~chorage, ~ 99503 NOV 6 lggl SUBJECT: west. Fork 1-2i wastewater Dispo ,&mal~.~n Dear Mr. Dolan: ~ o -/~J' The Alaska Center for the Environment finds the surface discharge of produced waters by CIRI Production Company, as proposed in the West Fork 1-21 Wastewater Disposal Permit application to be an unacceptable disposal method for the following reasons: 1) discharging produced waters into a wetland area, especially one located on the Kenai National Wildlife Refuge, poses unacceptable risk to the flora, fauna and habitat of the area when other, options with potentially less impact (injection) are available; 2) the permit application does not provide crUcial infOrmation needed to evaluate the potential impact of the produced water discharge on the affected pond/wetlands; 3) the proposed discharge will potentially cause the pond/wetlands water to exceed state water quality criteria; 4) ACE feels the U.S. Fish and Wildlife Service has had inadequate time to evaluate the impact of the proposed discharge on the Refuge. ACE recommends that at the very. least, DEC extend the comment period to allow USFWS time to comment thoroughly and to allow CIRI and DEC the opportunity to resolve the outstanding concerns explained below. Surface DisCharge vs. Underground Injection It is not clear why the Alaska Oil and Gas Conservation Commission (AOGCC) recommended that CIRI discharge the produced water resulting from the West Fork 1- 21 gas well onto the surface instead of reinjecting it. Especially when the CIRI lands to be developed are surrounded by the Kenai National Wildlife Refuge, protection of the surface lands, waters, and' habitat is critical. Is it a cost factor that caused CIRI to pursue surface disposal? AOGCC's recommendation assumes that the characteristics of the produced water will remain the same throughout the duration of the drilling project. This is an unsafe assumption given the variability of reservoir pockets and the cumulative impact of extraction on well conditions (for example, changing gas to water ratio). While ACE does .not have full confidence in the ability of the AOGCC to adequately monitor and regulate the produced water reinjection process, injecting the water seems less risky biologically than surface disposal. Incomplete Permit Application The permit application does not include information on several of the chemical and physical properties required under "K. Characteristics of Waste Flow" of the permit application, specifically temperature, dissolved oxygen, color, metals, total hydrocarbons, and total aromatic hydrocarbons (ACE recognizes that some testing for specific hydrocarbons is included). ACE recommends that the Department of Environmental Conservation (DEC) require that al___!l of the parameters specified in the regulations be analyzed by CIRI and evaluated by DEC before the Department grants the permit. Potential Impact of Discharge on Pond/Wetlands Secondly, it appears that the produced water, with the chemical and physical properties for which CIRI provided analysis, may cause the pond and wetlands water to exceed the water quality criteria established in 18 AAC 70.020 at the rate and duration of discharge. ACE requests information on the size and volume of water in the "small, contained perched pond" targeted for discharge and expects the Department to delay issuing of a permit until that information is known and used to evaluate the impact on water quality. The volume of water in the discharge area is critical data for evaluation of impact. As a pond and wetlands area within the Kenai National Wildlife Refuge, the discharge area meets two of the protected fresh water use classes, secondary recreation and growth and propagation of fish, shellfish, other aquatic life, and wildlife [18 AAC 70.020 (a)(1)(B)(ii) and (C)]. Therefore, as per the regulations, the most stringent criteria of the two classes applies [18 AAC 70.030 (1)]. Several of the levels of contaminants in the produced water raise concern at this time. Total dissolved solids in the wetlands water, for example, were measured by CIRI to be 50 mg/1. Analysis of total dissolved solids in the produced water showed ranges from 2380 to 2660 mg/1. The water quality criteria state that Total dissolved solids shall not exceed a maximum of 1,500 mg/1 including natural conditions. Increase in TDS shall not exceed one-third of the concentration of the natural condition of the body of water. After ten years of discharge at a rate of 1-2,000 gallons per day, 365 days per year, a substantial increase in TDS levels in the wetlands/pond waters seems quite likely. ACE is also concerned about the 500+ mg/1 chloride levels in the produced water. Has DEC or CIRI determined if the chloride released in the proposed produced water discharge would remain as free ions or be attached to cations? Which cations and what concentrations of them are present in the produced water and the pond/wetland waters? If the chloride was to remain in free ion form, the pH of the pond could rise, causing the pond water to become much more alkaline. This would impact the vegetation and other organisms liv'~ng in the pond/wetlands. Or alternatively, if the chloride was attached to cations, the produced water discharge could be toxic (either immediately or cumulatively) to the freshwater communities present in the pond/wetlands through direct toxicity to an organism or through habitat degradation. The impact of the discharge on the p.ond/wetlands pH is quite imp()rtant. The water quality criteria for pH state that the it "shall not be less than 6.5 or greater than 9.0. Shall not vary more than 0.5 pH unit from natural condition." Because the pH of the wetlands water was measured as 4.85, ACE assumes the second statement regarding variance from the natural condition applies. ACE is also concerned about the proposed discharge's impact on the dissolved oxygen levels, temperature, and color of the pond/wetlands water. USFWS Involvement ACE was disturbed to learn that the U.S. Fish and Wildlife Service at the National Wildlife Refuge had not been notified of this permit application until late last week. Notably, it was a concerned local resident who brought the issue to USFWS attention --not DEC or CIRI. Mr. Dolan told ACE the permit application was sent by fax to the Wildlife Refuge on the morning of November 22, leaving USFWS less than one working day to evaluate and comment. ACE feels this is inadequate time allowed to the keepers of the Refuge for determination of the discharge's impact on the Refuge. Monitoring ACE recommends that at the very least, DEC require monthly testing of the produced waters and quarterly testing of pond/wetland waters. Mr. Dolan stated on the telephone his intention to require quarterly testing of the discharge waters and annual testing of the pond/wetland waters. ACE regards the latter schedule as highly inadequate, given the variability in contaminant levels of produced waters. ACE also recommends that if DEC decides to grant a wastewater discharge permit, it be granted for one year only. The wisdom of allowing the produced waters to be discharged into the wetlands/pond area should be reevaluated by DEC and AOGCC each year, depending upon actual measured impact on the pond from the discharge to date, and the produced water contaminant load. Thank you for the opportunity to comment. Please forWard a copy of CIRI's solid waste disposal permit to ACE when available. ACE looks forWard to DEC's response to the above questions and concerns about the wastewater discharge permit. Sincerely, Karen Wood Waste Reduction Specialist cc: AOGCC November 12,' 1991 Ms. Joan Miller Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Ms. Miller: Per our conversation this morning, I am writing to you to clarify that the West Fork Gas ', Field is operated by CIRI Production Company. Therefore, the operator's name should be CIRi Production Company (or CPC in short). Please make the necessary changes where needed. Sincerely, CIRI PRODUCTION COMPANY M~~' -' ;enggui Zhang '~~ Operations Engineer MZ:rc:047 RECEIVED NOV 14 1991 Alaska Oil & (;as Cons. Commissio. Anchorage CIR! BUILDING 2525 "C" STREET P.O. BOX 93330 ANCHORAGE, ALASKA 99509-3330 (907) 274-8638 TELECOPIER (907) 279,8836 TELEX 090-26-465 October 31,1991 GIRl PRODU COMPANY Mr. Robert Dolan Alaska Department of Environmental Conservation Southcentral Regional Office 3601 C Street Anchorage, Alaska 99503 SUBJECT: West Fork 1-21 Wastewater Disposal Permit ADEC File No. 9123-DB012 Dear Mr. Dolan, You have requested additional information regarding CIRI Production Company's (CPC) application for a permit to discharge produced water from the CIRI West Fork 1-21 natural gas well onto a surface location adjacent to the well site. Specifically, you have asked why CPC decided to pursue surface disposal rather than annular injection. When CPC first experienced produced water at the West Fork 1-21 well, we discussed the situation with the Alaska Oil and Gas Conservation Commission (AOGCC). On September 24, CPC representatives met with commissioners Johnston and Douglas. Based on this discussion and a review of the facts surrounding the West Forkgas field, AOGCC recommended that CPC make application to ADEC for a permit to discharge the produced water on the surface. AOGCC offered CPC several reasons for their recommendation. First, 20 AAC 25.252(b) states that the Operator (in this case CPC)"has the burden of demonstrating that the proposed disposal or storage operation will not allow the movement of fluid into sources of fresh water." Since the West Fork 1-21 annulus is largely open for over one thousand feet, injected produced water could migrate into any number of fresh water aquifers. While it is possible that CPC could be granted a Freshwater Aquifer Exemption (20 AAC 25.440), 'the criteria for such an exemption requires injection into a specifically confined zone. Given the nature of the West Fork 1-21 well and subsurface geology, we would have no control over which zone, or combination of zones might accept the injected water. Thus we would need multiple exemptions. AGOCC does not favor granting such multiple exemptions. Second, 20 AAC 25.412(a) states that "wells that inject fluids for...disposal of non- hazardous oil field waste fluids...must be cased with safe and appropriate casing and be tubed to prevent leakage, and must be cemented to protect oil, gas and freshwater CIRI BUILDING 2525 "C" STREET P.O. BOX 93330 ANCHORAGE, ALASKA 99509-3330 (907) 274-8638 TELEC©PIER (907) 279-8836 TELEX 090-26-465 Mr Robert Dolan Octoberr 31, 1991 Page 2 sources." West Fork 1-21 is a production well and can not be simultaneously used an an injector for an extended period of time, even though one time annular injection of drilling fluids is allowed under EPA exemption. Upon consideration of a variety of factors, including the nature of the West Fork reservoir, the West Fork 1-21 well, state and federal regulations, the costs and impacts of drilling a separate deep disposal well, and the apparent quality of the produced water from West Fork 1-21, AOGCC reached its recommendation that CPC pursue surface disposal through application to ADEC for a Wastewater Discharge Permit. If you have any further questions, please contact Chip Dennerlein at 274-8638. Sincerely, CIRI PRODUCTION COMPANY Kevin A. Brown Vice President CD:092 October 22, 1991 Mr. Robert Dolan Alaska Department of Environmental Conservation Southcentral Regional Office 3601 C Street.- Anchorage, Alaska 99503 SUBIECT: West Fork 1-21 Wastewater Disposal Permit/Additional Tests ADEC File No. 9123-DB012 Dear Mr. Dolan, CIRI Production Company (CPC) acknowledges receipt of the letter of October 15 from ADEC Regional Administrator Svend Brandt-Erichsen requesting additional analysis of the produced water from the CIRI West Fork 1-21 natural gas well. Water samples have been taken and the tests for the metal ions listed in 18 AAC 080 (a) (1) are being accomplished. In addition, pursuant to your October 17 phone conversation with Chip Dennerlein, CPC has also requested the lab to test the produced water for Ammonia. Test results should be available from the lab by October 25. CPC will transmit the test results to you as soon as we receive them. If you have any further questions, please call. Sincerely, CnlDof'~ I ' O ,,~, , ,,,.,DUCTION COM, .A,,, · Vice President KAB:CD:088 cc: Chip Dennerlein Eric Opstad File 061,300.024 CIRI BUILDING 2525 "C" STREET P,O. BOX 93330 ANCHORAGE, ALASKA 99509-3330 (907) 274-8638 TELECCPIE? ':)07~ 279-8836 TELEX 090-26-465 STATE OF ALASKA ALASK,:, ,~iL AND GAS CONSERVATION C~MMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT , ' INITIAL ~ lb. TYPE TEST STABILIZED [] '. ANNUAL l-q MULTIPOINT ~] c~-_JT. 1 a. TEST: 2. Name of Operator SPECIAL .OTHER 7. Permit No. CIRI PRODUCTION COMPANY 3. Address P.O. Box 93330, 2525 4. Location of Well 1984 FNL, "C" #500, Anchorage, AK Section 21, T6N, R9W, SM 1725 FEL, 5. Elevation in feet (indicate KB, DF etc,) KB 322 o 0 Lease Designation and Serial No. Kenai Natives Assn - Surface CIRI - Sub'surface 99509 ENG ASST 1, 8. APl Number so- 133-20424 9. Unit or Lease Name ;"..::, ~r~:O L ASSTj-- I 10. Well Number ' CIRI West Fd~'~'~_~22~, ., 11. Field and Pool West Fork Gas Field 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. Perforations: From To · 7" 27 6.276" 5446 4982 - 4992 5146 - 5156 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 2 7/8" 6.5 2.44i 5063 J20. APl Liquid Hydrocarbons i8. Packer set at ft. J 19. GOR cf/bbl. 4837 & 5000 J ~/A , 22. Producing thru: Reservoir Temp. o F. Mean Annual Temp. o F. Tbg. '~] Csg. [] 97 34 " 23. Length of flow channel (L) Vertical Depth fH) J Go. J % CO? J ~ N2 % H2S Prover J Meter run Taps ~0~3 ~o6~ i 10.03 J~.~ o I x 21. Specific Gravity Flowing fluid (G) 0.562 Barometric Pressure (Pa), psia 14.65 24. Fibw Data .... 'J'ubing D~ta ' Casing Oat'a Duration of Prover Choke Pressure Diff, Temp. Pressure Temp. Pressure Temp Line X Orifice ' Flow No. Size (in.) Size (in.) psig hw ° F. psig °F. psig ° F. Hr. ~. . 3. 826 X 2.0 ~ 645 49 80 1387 J, 81 Pac.ker 2 [:. I 3.826 X 2.0 645 j 65 J 79 1320 I 81 2 [...~., i3.8~.6 x ~..0 i 650 i 7~'J 7~ ~.87j8~ t' ~- '- 4. f 3.826 × 2.0 i 655 t 86 I 78 1214 81 J 2 -- i ! '' i I "' Basic Coefficient Pressure Flow Temp. Gravity Super Comp. (24-Hour) -'~ hwPm Factor Factor Factor Rate of Flow No. Fb or Fp Pm Ft Fg Fpv Q, Mcfd 1. j 19.58 ' 645 0.9813 t 1.3339 1.090 4970 !..2. i 19.58 ~ ~~\~:~ 645 0.9822 ! 1.3339 1.891 5722 ~3. j 19.58 .,~ ~%--~ ! ¥ ~'- 650 0.9822 J 1.3339 1.089 6084 L 4. J 19'. 58 ..... 1 655 0. 9831 1. 3339 1. 087 6626 ~. I OcT ~ ~ '~1~ ...... -- ~"'~ ~r" ~r~9~' 1 for Separator for Flowing I~mperature Pr T Tr Z Gas Fluid No. Gg G [:'.' ~'. "~".9598 ~ 540 , 1.569 0.9205 2. J 0.9598l, 539 I ~.568 0.9205 3. j 0.9673 J 539 J 1.568 0.9199 .... o,,~,, P.~,,,,' '~72.0 ' "'~. ~ o.~?~? I 838 j ~.56~ o.9~9] ~,,=,~,moe~.~ I ]~.0 , .~' ~ ... ~ ~ ,_~' .... Form 10-421 CONTINUED ON REVERSE SIDE Submit in duplicate Rev. 7-1.80 Pc 1778. 3161284 pf 2015 pf2406022 No. Pt Pt2 Pc2 - Pt2 Pw Pw2 1. 1387 . 1,320 1287 1214 1237515 504915 687,4.,,88 Pc2-Pw2 Ps , Ps2 PfZ-Ps2 1747 1008216 1173624 .,1,6,99 1678 1635 1244541 1387000 25. AOF (Mcfd) 19800 Remarks: n0.987 I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .Title Operations Menggui Zhang EnqineeuOate_10/23/91 . AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/--VfhwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor=~/1/Z dimensionless F lowing tempe'rature factor, dimensionless Specific gravity of flowing fluid (air=l.000), dimensionless Specific Gravity of separator gas (air= 1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless · 'Flowing pressure at vertica! depth H, psia F lowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual Of Back. 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' ! l' ' II111 I II I 11 II II111 ' ' I I~ ................... 11 I11 I I11 Illll IIII II II111~1/11111 N~ I11._.. .~', q_~J~{N/llllllllllll ~ ""~',J"'-,.~',., J-P-,'.,/ '"'/-IIIIIIIIII lllllll'fllllll[lllll-II, ll-l"fll "" IIIIIIIIIIIIIk~"-'",~/, II.: IIIIIIIIII I I I~1 I I1_JI/,IIIIIIIIIIJ. IIIJJLIIIJ. IIII .. I,, , -lYkllll IIIIIII1: '-";\ II -- Iit11,1111I _ES .'7'-"IIII.YHH-tlIIrI'ridlI-1FllI~FTF"-" '"'lll'T. glBIIl, l~llll~f- '-", : --- -'----,-fl-F-",~.'--X'll~ll.llll~ I 1't.,,.,'~.;,,,I IIPIlTFt.,~I I I/I.,q',NJ'N.,f.+.H,JAj[I,,..,~'"',.,-.--~r,¢l'H,,I lll/~lqllll ~1 ..~-- /,,v,-..~..,,,i/- q.-l.,,,--, ,. I :1,,1'11"t"~ I I~ l L,/~'lllll rllll i-II . IIIIII I] It~/I ~ll~il ' t' ,.''- ,,.:: I/I,IIIIAILI II ' I~l~'illlJ~il%l I~!!t I~ II :11[~1 II l:~F:'...~il'l I I I I I I I IIIIIII i IIIIII I1 ,t [I IIJ !iiil ' II ,.llltl~ill I~:t:...,,ji;,I Ii -I-I..I.1..I,.-I .......... 1,1,1,1,1,,I--I,I .... I .... I,I .... I,I ..... I,l,l,H,l,l,l.l,l,l-I-I-I,l,l,l,,I,l,-I,I. ...... 1.1,1 ........ I,-I ..... 1,1,,I,1,1 ..... I,,I.1.-I ...... I,,I-I,1-1,1.1 I-I-I.l,l.l.l,l.l.l-I,l,l,l.l.I ,I,l,l,l,l,l,H,l,l.l,l,l,l,I, I-I,1,1,1,..I-I--I-I-I-I .I,1.1,1,1,1,1,1.1.1-1.1.1. I..I.l.H,l,I .I.1,1-1,-I.I, PERFORATION & GRAVEL PACK SUMMARY (CIRI West Fork 1-21) Objective: Perforate two productive intervals and gravel pack upper zone for sand control. Proposed Operations: 1. Rig up Schlumberger. 2. With rig on location, use Schlumberger 5" Casing Gun 90° phase: Perforate 4982' - 4992' @ 6 SPF Perforate 5143' - 5153' @ 12 SPF 3. Rig down Schlumberger, rig up Baker. 4. Set Sump Packer @ +5000'. 5. Set 26', 3¼" base pipe and 0.012 gage gravel pack stainless steel screen. 6. Set Baker SC-1L gravel packer @ +4837'. 7. Mix completion gel and filter to 2 microns. 8. Add sand and circulate gravel pack slurry at 2 Bbls/min. 9. Run Photon Gravel Pack Log. 10. Rig down Baker. 11. Run 2-7/8" tubing w/SSSV and heat string. 12. Circulate out brine and-replace with diesel. 13. Install wellhead, chain valves closed. 14. Rig down. BAKER SAND CONTROL CIRI PRODUCTION WEST FORK WELL NO. 1-21 DETAIL COMPLETION PROCEDURE I. CASING TEST PROCEDURE 1. Move rig and rig up over the hole. 2. RIH with a 7" Baker Model "N-I" Mechanical Set CIBP and set at 4,710' (+-) spot 15' of sand. POOH with setting tool. 3. Run in with Baker "EA" Cementer Retrievamatic packer. Cement squeeze perfs. 4,635'-4,690'. POOH with packer. Run in with bit, drill out cement to 4,695'. POOH with bit 4. Run in with Baker "EA" Cementer Retrievamatic packer and test casing to 1500 psi for 30 min. If no test is obtained then recement squeeze. 5. Run in with drill bit and drill out bridge plug. II. COMPLETION PROCEDURE 1. Run in with Baker wireline retrievable bridge plug set @ 4,970'. POOH w/wireline. 2. Pickup Baker Model "M" wash over retrieving head 2-7/8" workstring and RIH open ended with casing scraper and for 7" casing to 4,700'. Change the completion fluid over in the wellbore using D.E. filtered 3% KCL brine as follows: Monitor turbidity readings of fluid coming out of the wellbore during the entire change over. Plot this data as a function of time (see attached example). The actual reading is not as important as whether or not the readings are stable. A. Pump 45 bbls of filtered brine and caustic soda spacer with a pH 12 to 13. Circulate the pill through the system at maximum "critical rate". Reciprocate the pipe while circulating. B. Mix and pump 26 bbls HEC-filtered brine spacer with 25#/bbl coarse frac sand. C. Mix and pump 80 bbls sweep containing FIW and one drum Dirt Magnet (4.2#/bbl). D. Circulate one wellbore volume of FIW at a maximum "critical rate" until clean. BAKER SAND CONTROL Page 2 E. Reverse circulate 1.5 workstring volumes. Measure the turbidity of the fluid when "bottoms up" is attained. If the Turbidity is less that 35 NTU's proceed to step F. If greater than 35 NTU's contact the office. F. Pump 20 bbls HEC spacer. G. Displace the hole with completion fluid (3% KCL,) until the density pumped equals the density at the flowline. H. Filter the completion fluid with a Baker DE filter unit with a capacity of +/- 4 bpm followed by a 2 micron absolute filter until returns are less than 35 NTU's on a turbidity meter. I. Wash over and retrieve bridge plug. w/retrieving tool and bridge plug. POOH 3. Run in with work string open ended, clean out to 5778' by reverse circulating with filtered brine. Pickle the work string with a mild acid. Mix and pump 30 bbls of 650 cps Baker Hec Gel Pill with breaker. POOH. 4. RIH with Model "D" Sump packer and set at 5010' DIL. IV. Gravel Pack Completion 1. Pick up the gravel packing screen assembly as follows: A) Wireline Entry Guide B) Baker Model 'R' No-Go Seating Nipple, size 2.25 C) 10' 2-7/8" Tubing Pup "special clearance" D) Baker Model 'F' Seating Nipple, size 2.25 E) 45' 2-7/8" Tubing "special clearance" F) Baker Model "S-22" snaplatch seal assembly, size 80-32, with two (2) additional seal units G) Baker Isolation Glass Disc H) ~ of 3-1/2" Baker-weld wire wrapped 0.012 gauge stainless steel screen. Centralized for 7", 26#, J-55 casing, two sets per joint BAKER SAND CONTROL Page 3 I) 96' of blank liner J) 128' 2-1/16" tubing run concentrically inside the screen for tail pipe K) Baker Model "S" Gravel pack extension with a sliding sleeve, size 80-40 L) Baker Model 70B4-40 "SC-IL" gravel pack packer, size M) Baker Model "SC" 80-40 crossover tool with "SC" setting tool, size 70 NOTE: Items K thru M are picked up as one unit. 2. Run the gravel pack assembly into the well slowly. Space out the work string prior to snapping into the sump packer to obtain a safe working height at the rotary table. Snap into the sump packer and then snap back out again to verify depth. Snap latch seal assembly back into sump packer. 3. With the workstring in the neutral position, circulate 10 bbls of filtered brine at 2 bpm to insure ball seat and tubing are clear of any potential debris prior to dropping the ball. 4. Drop the 1-7/16" Kirksite setting ball and allow 30 minutes for the ball to gravitate down. To set the "SC-iL" packer, pressure up against the ball seat in 500 psi increaments to 2,000 psi (DO NOT SHEAR BALL SEAT) hold for 5 min. Test SC-1L packer by pulling 30,000# over string weight, then pressure annulus to 500 psi for 5 min. Release from the "SC-IL" packer by actuating the hydraulic release and pick straight up. Blow the ball seat with the tool in the reverse circulating possition. 5. Position and test the crossover tool in the squeeze, circulating, and reverse circulating positions. Obtain injection and circulation rates. 6. With the crossover tool in the reverse circulating position, mix and pump at 3 bpm the following slurry volumes: A) 5 bbls 350 cps Baker HEC Gel Pre Pad B) 5 bbls of slurry (10 cu ft of 20-40 Baker low fine gravel, mix at 10 ppg) C) 5 bbls 350 cps Baker HEC Gel after-pad BAKER SAND CONTROL Page 4 When the pre-pad reaches the crossover tool, place crossover tool into the circulating position. Reduce the rate to 2 bpm, choke the returns by 50% and continue pumping until a sand-out pressure of 1500 psi over circulating pressure is obtained. Position the crossover tool into the reverse position, reverse circulate the workstring clean. Pull crossover tool above the "SC-IL" packer and wait 3 hours. 7. Lower the crossover tool into the circulating position, restress pack to 1500 psi over circulating pressure. If pack fails to test or a sand-out was not achieved previously, remix and pump with the crossover tool placed in the circulating position an additional batch as determined, until a sand-out pressure of 1500 psi over circulating pressure is achieved. 8. Rig up wireline and run gravel pack log (Photon Log). 9. If no voids are present, proceed with completion. If voids are present transmit logs and wait for instructions. 10. Run in with tapered sinker bar on slickline and break glass disc. POOH 11. Pick up and run in with Baker Model 'S-22' locator seal assembly with completion equipment. 12. Rig down and move off well. CIRI\Q09 PRO 02-07-91 BAKER SAND CONTROL EQUIPMENT AND MATERIALS Page 1 of 2 DOWN HOLE EQUIPMENT REQUIREMENTS ITEM QUANTITY 1. 1 2. 1 3. 1 4 . 96' 5. 25' 6. 1 7. 1 8. 1 9. 55' 10. 1 11. 1 12. 1 DESCRIPTION Baker Model "SC-I" 70B4-40 Packer Model "S" G.P. Extension and Sliding w/22' lower extension size 80-40 Cross-over 5-1/2" X 3-1/2" 3-1/2" N-80 Blank w/centralizers 3-1/2" Baker-Weld wire wrapped .012 gage screen centralized for 7" 26# csg. Baker Model "S-22" Snap Latch Seal Assembly with 2 additional seal units size 80-32 Baker Model "S-22" Locator Seal Assembly with 6 additional Seal Units size 80-40 Baker Model "D" Packer size 84-32 2-7/8" Tubing w/2-7/8" NU 10 RD B X P w/special clearance collars Baker Model "F" Seating Nipple size 2.25 Baker Model "R" No-Go Seating Nipple size 2.25 Wireline Entry Guide RENTAL TOOL REQUIREMENTS ITEM QUANTITY 1. 2. 1 3. 1 4. 1 5. 1 6. 7. 1 8. 1 9. 128' DESCRIPTION BAker Model "J" Hydraulic Setting Tool BAker Model "SCH" Hydraulic Setting Tool Baker Model "SC" Cross-over Tool with additional seal units for low bottom hole pressure, size 80-40 Polish Stinger size 1.90" Baker Model "S-I" Shifting Tool Baker Model "S-I" Closing Tool Lifting Nipples f/3-1/2" Liner Baker Model "S" Retrieving Tool 2-1/16" Hydril Tail Pipe MATERIAL REQUIREMENTS ITEM QUANTITY 1. 20 cu. ft 2. 13 bbls 3. 50 bbls DESCRIPTION 20-40 Baker Low Fine Gravel Baker Clean Self-Breaking Gel, 350 cps Baker Clean Self-Breaking Gel, 650 cps BAKER SAND CONTROL EQUIPMENT AND MATERIALS Page 2 of 2 PUMPING EQUIPMENT REQUIREMENTS ITEM QUANTITY DESCRIPTION 1. 1 2. 1 3. 1 4. 1 5. 1 Gravel Pack Manifold w/gauges 25 bbl Blending Unit 6V-71 Power Pack Galigher Centrifugal BJ Single Pump Skid w/displacement tanks D.E. FILTER EQUIPMENT ITEM QUANTITY 1. 1 2. 1 3. 1 4, 1 DESCRIPTION 400 sq. ft. D.E. Filter Press Dual D.E. Blender Skid Polish Filter w/2 micron absolute elements Hose Basket /- R-CEIVED OCT - 9' 1991 October 9, 1991 Mr. Robert Dolan Alaska Department of Environmental Conservation Southcentral Regional Office 3601 C Street Anchorage, Alaska 99503 DEPARTMENT OF ~.ENVIRONMENTAL CONSERVATION CIRI PRODUGTION COMPANY SUBJECT: West Fork 1-21 Wastewater Disposal Permit Dear Mr. Dolan, With this letter, and the enclosed permit application forms and attachments, GIRl Production Company (CPC) hereby makes application for a permit to discharge produced water from the GIRl West Fork 1-21 natural gas well onto a surface location adjacent to the well site. When CPC first experienced produced water at the West Fork -i~21 well, we discussed the situation with the Alaska Oil and Gas Conservation Commission (AOGCC). Based upon the apparent quality of the produced water, AOGCC staff recommended that rather than injection back down the well, CPC obtain permission from DEC to dispose of the water on the surface. Subsequently, Chip Dennerlein contacted you to discuss the appropriate steps to obtain such approval. Scientific testing has confirmed the fresh water quality of the produced water from West Fork 1-21 and CPC is proceeding with the permit process. Pursuant to your recommendations, we are submitting both the DEC permit application form and the Coastal Project Questionnaire and Certification Statement. We plan to dispose of the produced water into a small, contained perched pond and seasonal wetland area adjacent to the well site on private property under the control of CPC. The Division of Habitat, Department of Fish and Game has reviewed the proposed discharge location and determined that the wetland is not connected via drainage pattern to other water bodies and does not appear in the anadromous fish catalogue. ADF&G has advised CPC that a Fish Habitat Permit is not required for this project. I believe that we have included all pertinent information necessary for review and approval of our permit request by DEC. Should you have any further questions regarding our application, please contact Chip Dennerlein or me at 274-8638. Thank you for your prompt attention to our application. Sincerely, GIRl PRODUCTION COMPANY Vice President CD:080 File 061,300.024 GIRl BUILDING 2525 "G" STREET P.O. BOX 93330 ANGHORAGE, ALASKA 99509-3330 (907) 274-8638 TELECOPIER (907) 279-8836 TELEX 090-26-465 STATE OF ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION APPLICATION FOR WASTEWATER DISPOSAL PERMIT in accordance with Alaska Statutes, Title 46, ."Water, Air, and Environmental Conservation", Chapter 03, Section 46.03.100, and rules and regulations promulgated thereunder, the following application is made: Name of App#Clnt: Phone Numbe~: d.~ ~opOcT/0~3 com~~y dc?a~ 7_7 q- ~E OF INDUS--/OPtiON: / L~: L~0[ 0[ W~ [ISC~GING ~l~(S): W~ [IS~[[ V0~E ~B~C W~~R IN[US~A W~~R C~UN~ W~R ~W WA~ SUP~Y: . ~E OF REC~ .WA~~[ OF RECE~NG ~ 18-0312 (Revised 8/89) Page 2 of 3 I. DESCRIPTION OF SOURCES: Give a detailed description of the sources of all industrial/domestic wastes within your facility. Include a schematic flow diagram showing the sources of all wastes and their flow pattern. Submit this information with your application as Exhibit 1. J. WASTEWATER TREATMENT: Describe waste treatment practices used on this discharge with a brief narrative (i.e. primary, secondary, cooling, oil/water separator, etc.). Include the disposal method for any sludge generated by the treatment system. Submit this information with your application as Exhibit 2. CHARACTERISTICS OF WASTE FLOW: · Describe in detail the chemical and physical properties of the effluent to be discharged to State waters (including but not limited to temperature, pH, dissolved oxygen, color, dissolved solids, suspended solids, BOD~, COD, oils, phenols, metals, chlorinated hydrocarbons, biocides, total hydrocarbons, total aromatic hydrocarbons, alkalinity, etc.) and the flow quantities of all wastewater streams associated with each of these contaminants. Also include a description of sampling and analytic methods used to derive this information. Submit this irr~rmation with your application as Exhibit 3. L PLANT OPERATION; Days per Year- Average M. MW MATERIAL AND CHEMICALS USED IN PROCESSESS: Brand Name Chemical, Scientific or Actual Name Quantity Used per Day* Average Maximum N. PRODUCT PRODUCED: Item Page 3 of 3 Quantity Produced Per Day* Average Maximum Oe *Please specify units (i.e. Tons per day, pounds per day, barrels per day, etc.). SEASONAl. VARIATION: Explain any seasonal variation in waste discharge volumes, plant operations, raw materials, and chemicals used in processes and/or production. tooto P. SYSTEM PLAN APPROVAL: NOTE: It is not re(]uired that the aD_DliCam submIt Dlans for a wastewater system wIth this Dermlt aDDIication, HOWEVER, receiDt and aDDroval of _Dians bv the Department iS reauired Drlor to construction, alteration, or oDerati0n of any wastewater collection, treatment, or disDosal ~ystem. a-_ Drovidecl under 18 AAC 72. The information given on this application is complete and accurate to the best of knowledge. Pfihtecl Name 'i~tle J CIRI PRODUCTION COMPANY WASTEWATER DISPOSAL PERMIT APPLICATION EXHIBIT I The facility supports a single natural gas well (West Fork 1-21) which is currently in production. The primary product of the facility is natural gas which is produced through a dehydration unit and odorization unit into a natural gas pipeline connected to the well site. A secondary product of the operation is produced water associated with the gas well. The produced water currently flows into a storage tank on site. Granting of this permit would allow the water to be piped from the storage/settling tank via pipeline to a surface discharge location within a small, contained perched pond surrounded by wetland and seasonal wetland areas. While there will be no permanent caretaker facilities, a small office structure will be located on the site. Human wastes generated by use of this facility will be handled by containment and removal or by a separately permited septic system. No wastes of any kind will be co-mingled with the produced fresh water stream which is the subject of this permit application. CIRI PRODUCTION COMPANY WASTEWATER DISPOSAL PERMIT APPLICATION EXHIBIT 2 The produced water, while technically a "waste" resulting from gas well operations, is extremely clean, as documented by the test results included as Exhibit 3 with this permit application. The water does exhibit slight discoloration due to the suspended solids (primarily clay) in the water. The water will be produced directly into a large capacity holding tank where some primary settling of suspended solids will occur. From the holding tank, the water will be routed through an earthen/sand filtration unit to provide clarification of the water and removal of remaining suspended solids. The clarified water will then be piped to a secondary settling basin constructed on site. This basin will have approximately 40,000 gallon capacity and will be lined with an impermeable membrane and bermed. In addition to providing secondary settling the basin will also serve as a source for fresh water if needed for future operations and as a water source for enhanced fire suppression capabilities. As a final stage in the water disposal process, water from the basin will be drawn off and conveyed via pipe or spillway directly to the surface discharge site. Settling of the water will result in very small amounts of inert clay material being produced over a period of time. Periodically, as needed, any accumulated material solids will be removed and disposed of in an approved solid waste disposal facility permitted for the gas well project. A simplified schematic of the system appears below. (PRODUCED WATER SOURCE) HOLDING TANK NATURAL GAS WELL EARTHEN/SAND FILTRATION UNIT LINED SETTLING BASIN '.~ I~ SURFACE DISPOSAL AREA CIRI PRODUCTION COMPANY WASTEWATER DISPOSAL PERMIT APPLICATION EXHIBIT 3 - PAGE I Prior to water sampling, the sampling process, including the specific tests required were discussed with the Alaska Department of Environmental Conservation. Water samples were taken directly from the well head into standard water analysis bottles by a registered geologist (Alaska Registration no. AA 183). The bottles were stamped and sealed and sent to Analytical Laboratory Service, Inc. for analysis. The projected produced water volume stream will be generally between 1000 gallons and 2000 gallons per day. The water quality test results appear as Exhibit 3, Pages 2 and 3. FROH T~LRBS 18.84.1991 ANALYTICAL LABORATORY SERVICE, INC. 12051 RIVEP, A ROAD, SANTA FE SPRINGS, CA 90,~70..2289 TELEPHONE (2133 698-0086 FAX ('Z13) 69~-1021 Client Project LABORATORY ANALYSIS REPORT AROMATIC VOLATII.R ORGANICS EPA Method CIRI Production Company File Number : 42439 West Fork Gas Field Date Reported : 10/04/91 Sample ID : CPC-9127001 CPC-9127002 Lab ID : C3353 C2567 Blank Matrix : Water Water Date Sampled : 09/27/91 09/27/91 Date Received: 10/02/91 10/02/91 Date Analyzed: 10/03/91 10/03/91 10/03/91 PAP~.METER~ RESULTS DET. LIMIT (ug/L) - ppb (ug/L) Benzene ND ND ND 0.5 Toluene ND ND ND 0.5 Chlorobenzene ND ND ND 0.5 Ethylbenzene ND ND ND 0.5 1,3-Dichlorobenzene ND ND ND 0.5 1,4-Dichlorobenzene ND ND ND 0.5 1,2-Dichlorobenzene ND ND ND 0.5 Xylenes, Total ND ND ND 1.5 ND - Not Detected · EXHIBIT 3 - PAGE 2 FROH T~LRBS '~-~ 18.84.1991 12~_. P. 3 ANALYTICAL LABORATORY SERVICE, INC. 12051 RiVERA ROAD, SANTA FE SPRINGS, CA g0~70-2289 TELEPHONE (213) 098-008{~ FAX (213) 88,5-102! LABORATORY ANALYSES REPORT Client : CIRI Production Company File Number : 42439 Project I West Fork Gas Field Date Received: 10/02/91 Date J~alyzod: 10/02-03/91 Matrix : Water Date Repoz~ced ~ 10/04/91 Sample ID: CPC-9127001 CPC-9127002 Lab ID: C3352 C3353 DETECTION UNIT LIMIT HET}IOD pH 7.50 7.53 ........ EPA 9040 Total Dissolved 2560 2450 mg/L 4.0 APHA 209A Solids Total Suspended 30 10 mG/L 2.0 APHA 209C Solids Chloride 541 510 mg/L 5.0 EPA 325.3 Conductance 4080 3770 umhog/cm 1.0 APHA 205 EXHIBIT 3 - PAGE 3 CIRI PRODUCTION COMPANY WASTEWATER DISPOSAL PERMIT APPLICATION EXHIBIT 4 o 17 _,_~,:_~P R 0 DI ~1 'C/ESI 20 F ...... 29 28 SCALE IN MILES T6N __ LOCATION MAP, CIRIPRODUCTION COMPANY 'CIRI WEST FORK 1-21' Lab Arseni= ND ND 0.02 EPA 6010 B~!li~ ND ND 0.03 ~PA 6010 0=~$~ ND ND 0. O~ ~A GOl0 ~r~i~ ND ND 0.03 EPA 6010 ~p~r 0.03 ND O. 02 SPA 6010 ~ad 0,1~ ND 0 · 04 EPA 6010 ~e~eu~ RD ND 0.0X EPA 7470 N/;~I ND N0 O. 02 ~PA 6010 ~eleni~ Silva= ND ~D 0.05 EPA ~010 Thall!~ ' " ND ND 0,37 EPA 6010 ~tno 0.04 ' 0.04 0,02 ~A 6010 ND - No~ De~ect~t I~ LABORATOP~- SERVICE, INC. 12051 RIVERA ROAD, SANTA FE SPRINGS, ( TELEPHONE (213) 698-0086 FAX (213) 696-1021 ,'0-228,9 Client : ProJect : Matrix : Water LABORATORY ANALYSES REPORT CIRI Production Company West Fork Gas Field Sample ID: WF-911016-04 Lab ID: C3503 WF-911016-06 C3505 UNIT File Number : Date Received: Date Analyzed: Date Reported: 42474 10/22/91 10/22-30/91 10/30/91 DETECTION LIMIT METHOD pH 9.80 4.85 .... .... EPA 9040 Total Dissolved 2300 Solids Chloride ~ 50 46.3 mg/L mg/L 4.0 APHA 209A 5.0 EPA 325.3 Sample ID: Lab ID: WF-911016-05 C3504 Total Dissolved Solids 2380 ammonia ND ND - Not Detected UNIT DETECTION LIMIT METHOD 4.0 APHA 209A mg/L 0.1 EPA 350.2 Nelida M. Es~'ritu Please answer all qu~t~on~ To avoid a delay in ~g, please call the agency if you answer "yes" to any of the questions related ~ that d~;~~t. Include mal~ or plan drawin~ with your packet. An inmmj~ qu~tionnair~ may be ra'urn~ and taill dday th~ r~ie~ of your paelcet. APPLICANT INFORMATION PROJECT INFO ON 1. Provide a brief de~ription of your entire project and ALLa.~sodated fadlitte~ (c.a~qak~ fac'illtte~, waste disposal site~, etc.) bO~T' b"og-k i-Z[ fOATOI~L~ ~ g0~_d_..) L.~'J'~-'~ Star~g date for project. Pt c.. Iq ~ 0 Ending date for project:. Z The project is on: ~] State land [-1 Federal land 3. The project is located in which region (see attached map): I PROJECT LOCATION 1. Please give location of project (include nmrest communify or identifiable body of land or water). ~'/Private land r-'J Municipal land [~ Northern ~/southcentral J-'] Southeast CURRENT APPROVALS 1. Do you currently have any State or federal approvals for this project? Note: Approm/mean~ permit or any other form of authorization. If "yes," please list below. APPROVAL TYI~ APPROVAL # DERAL PROVALS 1. Will you be phdng s~cmres or fil~ m any of the fo~o~g: ti~ (ocean) watem, strea~, hkes or wetlands'? FJ(PIRATION DAlE No 5'rATE REvr~w [DSS Yes No / 'If you ar~ not c..trtain wl,~th~r your proposed protect is in a wetLand, contact tt~ U.S. Corps of Engir~rs, Regulatory Branch at (907) 75.t-2720 for a r~lands d~t~mination (out$t'de the Anchora~ area, call toll free !-800-478-2712.) If yes, have you applied for or do you intend to apply for a U.S. Arm Corps Yes of Engineers (COE) permit? If "yes," give date of submittal: / 1 No Alpmcy, NaUonalPollutto-~'~ .~itargeElimina~onS~~~--,.. mnit? (Not~ For information regarcttng th,_ ~,eed for a NPDES permit, conta~ F., . at (!~) 271-5083.) 3. Have you appliat for, or do you intend to apply for, permi~ from any other federal a~? If #yes,~ plmse list below. Ye~ A~'v An, sov~t Tv~ DAT~ scr~gl'r~ (OR ~ TO s'daMrT) ! DEPARTMENT OF NATURAL RESOURCES APPROVALS Is the proposed project on State-owned land or will you need to cross State lands for access? No~ 2. Is any portion of your project phced below the ordinary high water line of a str~_ m, river, lake or mean high water line of a saltwater body? 3. Will you be dredging? If yes, location of dredges is: Towz~hip . Ran~ M~r!,41-., Section Location of disposal site for dredged materials Township l~np M~!_dl-q ~__,~ 4. Will you be f~lllug with rock, sand, or l~ravel? If "yes," amount: Location of source:, row~lp ~-~ge ~_,~-. Location of ~l site: Towrahip ~ange 5. Do you plan to use any of the following State-owned resources: · Timber Will you be harvesting timber from 10 or more acres? If "yes," amount:., Location of SOLtrce: Township Range Meridian · Other mat~riai~? If "yea," what material? Location of source: rowr~p 6. Are you planning to use any fresh water? If "yes," amount (gallons per day): Source: 7. Will you be building or altering a dam? 8. Do you plan to drill a geothermal well? 9. Will you be exploring for or extracting coal? 10. Will you be exploring for or extracting minerals on State-owned land? 11. Will you be exploring for or extracting oil and gas on State-owned land? ~ect/on (peat, bugdin$ stone, silt, overlmrden, em.) Range Mendisn Section Yes '12. Will you be ~vestigatin~_~ removing historical or archaeologica./'. ~u-ces on State- '' owned land? 13. Will the pro}ect be located in a unit of the Alaska State Park System? It you armwered "No~ to ALL questions in this section, you do not need an approval from the Alaska Depm~me~t of Natm~ Resotrrces (DNR). Continue to next section. If you answered "Yes" to ANY questions in this section, contact DNR to identi~ and obtain neces~jr appUcation forms. Based on your discussion with DNR, plea.se complete the following: APPROVAL TYI~ NEEDED DATE SUI~lV~Trl~ (OR INTEND TO St~) Ye~ Have you paid the ~tng fees required for the DNR permits? If you are not applying for DNR pernuts, indicate reason below: ['-] a. (DNR contact) told me on .(date) that no DNR approvals or permii~ were required on this project. Y~ No DEPARTMENT OF FISH & GAME APPROVALS 1. Will you be working in, or placing anything in, a stream, river, or lake? (This includes work in running water or on ice, within the active flood plain, on islands, the face of the banks, or the stream tid~ down to mean low tide.) Name of stream or river:. Name of lake.: Will you be doing any of the foUowing: a) Building a dam, rivet training structure or instream impoundment? b) Using the water? c) Diverting or altering the natural channel stream? d) Blocking or damming the stream (temporarily or permanently)? e) Changing the water flow or the water channel? t') Pumping water out of the slream or lake? Introducing silt, g~,avel, rock, petroleum products, debris, chemicals or wastes of any type into the water? h) Using the stream as a road (even when l:rozen), or crossing the stream with tracked or wheeled vehicles, log-dragging or excavation equipment (backhoes, bulldozers, etc.)? i) Altering or stabilizing the banks? j) Mining or digging in the beds or banks? k) Using explosives? 1) Building a bridge (including an ice bridge)? Ye~ No o) Other in-sUuam structure not mentioned above~ 2. Is your project located in a designated State Came Refuge, Critiml Habitat Area, or State Game Sa~ctuaW? 3. Does your project ind~ the con.struc~on and operation of a salmon hatchery? 4. Does your project affect, or is it related to, a previously, ~ed salmon hatchery? 5. Doe~ ]rom* project include the construction of an aquat~ farm? If you m~wered 'No" to ALL questions in this section, you do not need an approval fromthe Al~ka Department of Fish and Gmne (DFC). Continue to next section. If you ~ "Yes" to ANY questions under ! or 2, contlct the Regional DFC Habitat Division Office/or hLformation and appflcatton forum If you answered "Yes' to questions 3, 4 or S, contact the DF*G at the PR. KD. division headqum~s for information and application forms. Based on ~our ~on with DFG, pl,~e complete the following: that no DFG approval or permits were required on this project. [-] b. Other:. (date) DEPARTMENT OF ENVIRONMENTAL CONSERVATION APPROVALS 1. W'dl a discharge of wastewater/rom industrial or commercial operations occur? (See #2 in "Federal Approvals" section.) No 2_ Do you intend to comuuct, in~tall or modify any part of a wastewater (sewage or greywater) disposal syst~n? ~'~ 3. If "yes," will the dischar~ be ~)0 ~d or greater? ~ 4. Do you expect to request a mixing zone for your proposed project? [~ If your raas2umter discharge r~l exceed Alaska water aualit'y, standards, you may a~y for a mixing zone. If so, please contact DEC ta discus~ information required under I$ .-L-lC 70.032. Will the project result in dredging or disposal fill in wetlands or placement of a structure in waterways? (Note: Your a~li~ion for this ac-t:r~tv to th~ Cer~ of Engir~r~ taftl also serve as your aivision to DECJ 6. Will your project produce any domestic or ~ndustnal solid waste? 7. Will your project require the application of oil or pestiades to the surface of the land? 4 e b. Do you ha~ ca~ or mor~ units of fuel burning equipment with a heat input ratinE of $O Do you h~w ~n ~tur with a rated capacity of ! ~ ~ ~ h~r or ~or~ or do you incinerate sludg~? Do you have any of the following proces____,~_: asphalt plant, petroleum refiner),, coal preparation facility, or portland cement plant? e. Does your facility meet any of the following criteria: le Use the following equipment: d~gs~ ggctr~c gg~,affng ~ (total capacity' of 1750 k~rm~ff);oo~fi~ ~ (total heat input ratin§ of 100 ~ (total heat input mtin~ of 65 mE],~n Bf~ ~r im~r); com~tfo~ fm'~i~ (total rated power output of 8000 2. Bum more than the following per year in statiomry equipment: oa; 900 nail/on cub/~ faa of natuna i'm; or 35,000 It you have answer~"y~s" tO any of the above questions, have you installed, replac~ or modified any fuel bumin$ or processing equi~t sinca 9. Will you be altering a public water system? 10. Will your project require offshore drilling or vessel transport of oil or other petroleum products as cargo, or indude onshore facilitie~ with an effective storage capacity of greater than 10~30 barrels of such products? 11. Will you be subdividing lands into two or more lots (parcels)? If you answegtsd NO m ALL questions in this section, you do not need a permit or appmvM from the Alaska Department of Environmental Conservation (DEC). Please continue to the Certification Statement. If you answered YES to ANY of these questions (see #S note), contact the DEC Regional Office for information and application forms. Based on your discussion with DEC, please complete the following: APPROVAL TYPE NEEDED DATE SU13MrrrED (OR tNT~D 1'o su~) Ye~ If you are not applying for permits, indicate reason below:. [~] a. (DEC contact) told me on that no DEC approval or permits were required on this project. [:] b. Other. (date) --5-- C cation Statement The~ ~ ~ ~ true and con~lete to the best of my ~led~;e..Zcez~ that the ~osed · To complete 2our p~ please attach your State pennit app~ and copies My, mr federal permit: applf~tfom to this questionnaire. OPSTAD AND ASS,._,2IATES P.O. BOX 190754 ANCHORAGE, ALASKA 99519 Geoscience and Engineering 907/345-6346 Lonnie Smith Commissioner Alaska Oil & Gas Conservation Commission May 8, 1991 Re: West Fork 1-21: Completion, Sundry Notice, 10-403 & 10-404 Forms Dear Lonnie: Following on our telephone conversation last week I've enclosed a con'ected Form 10-407 which does not refer to West Fork 1-21 as a "tempormSly suspended" well. Also attached is an updated gravel pack assembly schematic. There have been several versions of this diagram, and I believe I attached an em'ly draft copy to the Folm 407 submitted last week. In any case this schematic is con'ect and should be the document of record for WF 1-21. As requested I've also inclosed is a copy of the daily operations summaD, which provides a detailed well history. Lastly, I've inclosedv~ ...... _ ~n._~.~,,. ' --~--~-..~_.,,-~~Xla ~,~ ,n~ .~:.,. relevant attachments/i Please let me know if you require any additional information. Best regards, Consultant wf:A5891 -/--'~i' '~ STATEOF ALASKA ALASKAi~:~iL/~ND GAS CONSERVATION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL [] .,, GAS · sUSpENDED ABANDONED [] SERVICE [] Classification of Service Well Name of Operator CIRI ._PRODUCTION COMPANY 3. Address 2525 "C" Street, Suite 500, Anchorage, Alaska, USA 4. Location of well at surface 1984' FNL & 1-707' FEL, Sec 21 ~P 6N, R~nA~A'gW. At Top Producing Interval ' At Total Depth As Above 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial 322 ~.~, 302 I 12. Date Spudded 13. Date T.D. Reached 20-~ec-90 04-3a~-91 17. Total Depth (MD+TVD) 5,459 MD 7. Permit Number 90-143 8. APl Number 5o-133-20424 9. Unit or Lease Name West Fork Gas Field 10. Well Number ' 1-21 11. Field and Pool West Fork (Sterling) 18.Plug Back Depth (MD+TVD) N/A 14. Date Comp., Susp. orAband, 15. Water Depth, ifoffshore 116'N°'ofC°mpletions 26-Feb-91 (Comp.) N/A feet MSLI One 19, Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost YES [] SS NO [] 455 feet MD 22. Type Electric or Other Logs Run GR/ILD/ILM/SFLU - NPHI/DPHI/TEN/BMNO/BMIN/CALI DGR/EWR/FXE (MWD)(Recorded) 23. CASING, LINER AND CEMEN,TING RECORD (Wireline) CET CASING SIZE WT. PER FT. GRADE HOLE SIZE CEMENTING RECORD AMOUNT PULLED 4O '26 · N-80 N-80 N-80 SETTING DEPTH MD TOP BOTTOM .0 140 0 2]43' 0 5447" 17-1/2" 12-1/4" 8-1/2" To Surface '660 SX Class G 300 SX Class G 24. Perforations open to Production {MD+TVD of Top and Bottom and interval, size and number) >~.- · 4982' 4992' MD @ 18 5143~ - 5153~ MD @ 12 Nominal 0,78" 25. TUBING RECORD :SIZE DEPTH SET (MD) I PACKER SET (MD) 2-7/8" 4837.7' MD I48_37~.7'MD' (GPA) Gravel Pack StrinR To 506,4-".[5000.0t M'D. (GPA) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC, DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A N/A 27. PRODUCTION T~ST Date First Production N/A Date of Test I Hours Tested 01/25/91 I :24 Flow Tubing Casing Pressure Press. 1500 .- N/A IMethod of Operation (Flowing, gas lift, etc.) TEST PERIOD I~ CALCULATED i~ I OIL~B~L =24-HOUR RATE -~ GAS-MCF 10,000.. GAS-MCF 10,000 WATER-BBL 0 WATER-BBL 0 N/A CHOKE SIZE GAS-OIL RATIO 18/64 I .N/A ~~~#~ GAS See Gas Analysis Attached 28. CORE DATA Brief description of lithology, porosity, fracttJres, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED NIA'f 0 1991 Alaska 0il & Gas O0ns. c0mmiss_Io_n ~oh0r~g~ No Core Cut Ditch Samples Submitted to AOGCC Form 10~,07 Rev, 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ~29. ., 30. GEOLOGIC MARKERS FORMATION TESTS · ,, NA~E __ Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · · , ,. Sterl±ng A - Sand 4621' MD -+ 4621' TVD 4680 - 4690 4659 - 4665 @ + 5,000 Mcf/D Gas, 0 Water 4635 - 4638. B4 - Sand 4980' MD -+ 4980' TVD 4982 - 4992 @· +101000 Mcf/D Gas, 0 Water B6 - Sand 51.38' MD -+ 51.38' TVD 5143 - 5153 @ -+ 5,50© Mcf/D Gas, 0 Water (See Attached) ; 31. L]S%OFAYTACHMENTS Gravel Pack Assembly Schematic - Gas Analyses - Reservoir Section Lo~ Erik A. OpStad~ Tit~o Consultant Date April 26, 1991 . Signed INSTRUCTIONS , ~ · ~, . General: 'This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other Spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from ~ore than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 12 15 I& 19 SIZE WEIGHT GRADE THREAD OPERATOR CIRI CASING 7- COMPANY REP, PHi ERIK BPSTAD / Brio GARDNER / VIRGIL THRAPP LINER FIELD WELL NO. YE:ST FDRK 1-i~1 TUBING STATE LEA~E ALASKA KENA[ BOROUGH VEST FI:IRK WKSTRG 3 SEE BELB'W' BO N~M£ PHi ;OklP, FLUID HHIBI[ORJ gATE SLIBMrl-r~D JOB ~~CREEN SiZE ~.AND SIZE F'/~4/91 3 1/2" ,012' 6AGE ~0-40 B^KER LB%/ FINE DARRYL SNB~ 563-08~5 NO. DEPTH LENGTH O, D. I, D. DESCRIPTION [ 4837,70 4,17 5,96 4,00 BAKER HUbEL 'SC-IL' GRAVEL PACK PACKER SIZE 70B~-40 ~ 4841,87 4,81 5,50 5,00 UPPER EXTENSION 3 4846.68 1,64 5,75 4,75 HBDEL 'S' SLIBING SLEEVE 4 4848,3~ i,49 5,50 4,00 SEAL BORE 5 4849,81 et,85 5,00 4,31 LUWER EXTENSION 6 4871.66 .~5 5,00 ~.99 CROSSOVER SUB 7 487LBJ 3L51 3.50 8,99 3 1/8' NU 10 RD BLANK PIPE ~/ CENTRALIZERS 4903.42 3t,55 3,50 ~,99 · 4934,97 31,50 3.50 2,99 - 4966,47 5,89 3,50 ~,99 - 8 497[.76 ~6,30 4,13 2,99 BAKER~ELD 3 1/2' ,01~ GAGE ~IRE WRAPPED SCREEN 9 4998,06 t,07 4,50 3,00 BAKER ISOLATION DISC I0 4999,13 .87/3,41 4,63 8,44 BAKER HBDEL 'S-~' SNAP LATCH SEAL ASSY SIZE 80-3~ [1 5000,00 .70/2.75 5.86 2.25 ~AKER HODEL 'D' SUNP PACKER SIZE 94-32 t~ 5003,4] 30.~7 ~,875 ~.44 1 JOINT ~ 7/8~ 6,5ff NSO TUBING ~/SPECIAL CLEARANCE 13 5033.58 15,06 ~,875 ~,44 8 7/8' NU 10 RD TUBING JOINT ~/SPEC[AL CLEARANCE [4 5048,64 ,98 3,18 ~5 BAKER HBDEL 'F' SEATING NIPPLE t5 5049,62 tO,06 ~,875 8,44 ~ 7/8' NU 10 RD TUBING JOINT W/SPECIAL CLEARANCE 16 5059,68 ,81 3.18 ~.18 BAKER HODEL 'R' SEATING NIPPLE SIZE ~,~5 ~/~,197' NO-GO 17 5060,4~ ~.55 ~,875 8,44 ~ 7/8' NU lO RD TUBING dBINT W/SPEC[AL CLEARANCE [8 5062.04 ,68 3.18 ~,18 ~IRELINE ]NTRY GUIDE TUBING TAIL BOTTON AT 5063,78' ' gLL LISTED ~EPTHS ARE TDDL TOPS ~k,,IATION: PERFORATIONS 4992-4992 \CIR[\I-21 ENSR Consulting and Engineer,., Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT EN, IR Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr Bit No. Bit No. Drilling Setup: CIRI West Fork 1-21 West Fork 5459 (TD) 322 0600 Hrs. 2/25/91 KB, Total Drilling Days: 68.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs size make & type in T feet rotating hrs Report No. 69 February 26, 1991 Date: Contractor: to 2400 Hrs. 2/26/91 Total Rotating Hours: 100.5 KB, Depth -5137 SS. Rotary Speed RPM. jet sizes in , , Notes: Grace Rig 211 jet sizes in , B , G , Notes: out out Formation(s): Cased Hole Last Casing: Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. 7' 26#, N-80 @ 5447 ft size & grade depth SPM Pump Output: (GPM)(BPM) FPM Annular Velocity (collars): FPM or % Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: 8.6 (PPG), weight yield point % sand Detail: Milpark 3% KCI Brine mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. 6 % pH filter cake solids % 28,000 ppm % 0.447 psi/fi oil chlorides water mud gradient Ran production tubing as follows: Baker stab-in seal assembly, XO, 1-joint of 2-7/8" AB-DS tubing, XO, 1- sliding sleeve valve assembly, XO, 141 joints of 2-7/8" AB-DS tubing, XO, subsurface safety valve (455' FM tubing hanger), XO, 14 joints 2-7/8" AB-DS tubing, XO, 22'-2-7/8" EV 8RD pup joint, XO, tubing. Hanger heater string total to tubing hanger 454'. Land tubing hanger. Nipple down B.O.P. Nipple up production stack. Test annulus to 500 psi. Stack test complete. Road conditions extremely icy. Must condition road prior to calling out displacement diesel pumping unit, wireline crew (sliding sleeve) to displace annulus with diesel. Grade and sand rig road. Rig up to displace brine with diesel. Open sliding sleeve valve. Pump 6500 gal diesel (reverse circulate). Close sliding sleeve. Allow diesel in tubing to migrate to surface. Close subsurface valve. Install back pressure valve. Inject brine returns. Clean pits and Inject excess fluid. Released rig at 2400 hrs 2/26/91. Final Report. --~,~L~ v LL/ Weather: +33°F. Clear, calm. Visibility unlimited. MAY, OF, 799 Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Dally Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and EngineeriL~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. ft/hr Bit No. Bit No. Drilling Setup: 5459 ('i'D) 322 ClRI West Fork 1-21 West Fork 0600 Hrs. 2/24/91 KB, Total Drilling Days: 67.75 KB, TVD 5459 Weight on Bit 1,000/lb 16 RR SEC. M4NJ size make & type in T , B feet rotating hrs to Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed open 5357 jet sizes in Notes: size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Report No. 68 February 25, 1991 Grace Rig 211 Hrs. 2/25/91 100.5 -5137 SS. RPM. out out Formation(s): Cased Hole Last Casing: 7" 26#, N-80 @ 5447 ft size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit~ Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid: 8.6 (PPG), weight yield point % sand Detail: Milpark 3% KCl Brine mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. 6 % pH filter cake solids % 28,000 ppm % 0.447 psi/ft oil chlorides water mud gradient Drop ball and set packer. Test annulus to 1000 psi. Blow ball seat and reverse out 1-1/2 tubing volume. Pump 5 bbl gel pre-pad, followed by 5 bbl with 14 cu. fi. 20-40 sand slurry. Sand out with 11 cu. fi. Reverse out 1 bbl of slurry (3 cu. fi.). Sand out pressure at 1500 psi. Test pack at 1700 psi. P.O.D.H. laving down drill pipe as directed by E. Opstad. Change BOP ram to 2-7/8" and test BOP stack. Rig up Schlumberger and run photon log. Run sinker bar on slickline and break isolation disc. Rig up Joe's Oilfield Service. Begin running production tubing string. Weather: +25°F. Clear. Winds calm. Visibility unlimited. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineerir .. Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr Bit No. Bit No. Drilling Setup: 5459 (TD) 322 CIRI West Fork 1-21 West Fork 0600 Hrs. 2/23/91 KB, Total Drilling Days: 66.75 KB, TVD 5459 Weight on Bit 1,000/lb 16 RI:{ SEC. M4NJ size make & type in T , B feet rotating hrs size make & type in T , B feet rotating hrs to Date: Contractor: 06O0 Report No. 67 February 24, 1991 Grace Rig 211 Total Rotating Hours: KB, Depth -5137 Rotary Speed open 5357 jet sizes in , , Notes: Hrs. 2/24/91 100.5 SS. RPM. out jet sizes in , G , Notes: out Formation(s): Cased Hole Last Casing: Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. 7" 26#, N-80 @ 5447 fi size & grade depth SPM Pump Output: (GPM)(BPM) FPM Annular Velocity (collars): FPM or % Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: 8.6 (PPG), weight yield point % sand Detail: Milpark 3% KCI Brine mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. 6 % pH filter cake solids % 28,000 ppm % 0.447 psi/ft oil chlorides water mud gradient Rig up Schlumberger. Perforate 5146-5153' (12 SPF) and 4982-4992' (6 SPF). Pick up casing scraper assembly and run in hole to bottom. No interference through perforated zones. Reverse circulate and D.E. filter brine through two hole volumes. Final NTU reading of returns was 28.6 NTU. Trip out of hole. Rig up Schlumberger with setting tool and pick up and run in hole with Baker sump packer. Set packer element at 5000'. Rig down Schlumberger. Pick up and run the gravel pack assembly in the hole. Snap latch seal assembly into sump packer. Rig up and test surface lines. Pump 4 BPM for 5 minutes to ensure ball seat and tubing are clear prior to dropping ball. Weather: +32°F. High overcast, winds calm. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineen,,~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT EN,'R Well Number: CIRI West Fork 1-21 Date: Field: West Fork Contractor: Report Period: 0600 Hrs. 2/22/91 to 0600 Depth: 5459 (TD) KB, Total Drilling Days: 65.75 Total Rotating Hours: Elevation 322 KB, TVD 5459 KB, Depth Avg. fi/hr Weight on Bit 1,000/lb Rotary Speed Bit No. 16 RR SEC. M4NJ open 5357 size make & type jet sizes in in T , B , , Notes: feet rotating hrs Bit No. Report No. 66 February 23, 1991 Grace Rig 211 Hrs. 2/23/91 100.5 -5137 SS. RPM. out size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Drilling Setup: 6" bit, casing scraper, bit sub, 4-4-3/4" drill collars, 3-1/2" drill pipe. Formation(s): Cased Hole Last Casing: 7" 26#, N-80 @ 5447 fi Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. lb size & grade SPM Pump Output: FPM Annular Velocity (collars): or % Bit Hydraulic Horsepower: HP Pump Hydraulic Horsepower: depth (GPM)(BPM) FPM HP Drilling Fluid: Milpark 3% KCI Brine mud company type 8.6 (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 fi2 , in. 6 % yield point pH filter cake solids % % 28,000 ppm % 0.447 psi/fi sand oil chlorides water mud gradient Detail: Ordered all cross overs to be cut for tubing run. Baker Sand equipment arrived late evening. This material to be inventoried and tested prior to delivery to the rig site. Trip out of hole. Strapping out. Building 100 bbl additional brine volume. Awaiting arrival of Schlumberger to conduct perforations. Weather: +26°F. Low overcast, light snow, calm. Visibility 5 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineerin~ Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT EN,'R Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 (TD) KB, Elevation 322 KB, Avg. fi/hr Weight on Bit Bit No. 6" size in 'feet Bit No. Drilling Setup: Hrs. Total Drilling Days: TVD Date: Contractor: 2/21/91 to 0600 64.75 Total Rotating Hours: 5459 KB, Depth 1,000/lb Rotary Speed SEC. M4NJ open make & type jet sizes in T , B , , Notes: rotating hrs size make & type in T , B feet rotating hrs 6" bit, casing scraper, bit sub, 4-4-3/4" drill collars. Report No. 65 February 22, 1991 Grace Rig 211 Hrs. 2/22/91 100.5 -5137 SS. RPM. out jet sizes in , G , Notes: out Formation(s): Cased Hole Last Casing: 7" 26#, N-80 @ 5447 ft size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid: 8.6 (PPG), weight yield point % sand Detail: Milpark 3% KCI Brine mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. 6 % pH filter cake solids 28,000 ppm % 0.447 psi/ft oil chlorides water mud gradient Filter system with Baker D.E. filtration equipment. Await arrival of Baker San Control material and equipment. Slow circulate hole during the waiting period. Weather: -8°F. Clear skies, winds calm. Visibility unlimited. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineer..~ Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: ClRI West Fork 1-21 Date: Field: West Fork Contractor: Report Period: 0600 Hrs. 2/20/91 to 0600 Depth: 5459 ('rD) KB, Total Drilling Days: 63.75 Total Rotating Hours: Elevation 322 KB, TVD 5459 KB, Depth Avg. fi/hr Weight on Bit 1,000/lb Rotary Speed Bit No. 6" SEC. M4NJ open 5357 size make & type jet sizes in in T , B , , Notes: feet rotating hrs Bit No. Report No. 64 February 21, 1991 Grace Rig 211 Hrs. 2/21/91 100.5 -5137 SS. RPM. 5129 out size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Drilling Setup: 6" bit, casing scraper, bit sub, 4-4-3/4" drill collars. Formation(s): Cased Hole Last Casing: 7" 26#, N-80 @ 5447 ft Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark 3% KCI Brine mud company type 8.6 (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 ft~ , in. 6 % yield point pH filter cake solids ~ % % 28,000 ppm % 0.447 psi/ft sand oil chlorides water mud gradient Detail: Install and test 2-7/8" rams in B.O.P. stack. Pick up 2-7/8" tubing and stand back in the derrick. Pick up casing scraper. Run in hole to bottom. Circulate. Rig up Baker filtration D.E. unit and begin system filtration. Received a call from Bill White at 0100 hrs 2/21/91 (Baker Sand - Kenai office) informing me that the enroute location of the screen assembly was not between Anchorage and Kenai but was last identified as being in the Yukon Territories, Canada. Weather: +8°F. Overcast, winds light and variable. Visibility 10 miles. Cumulative Mud Cost $' N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Enginee, Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. ft/hr Bit No. 18 Bit No. 19 Drilling Setup: 0600 Hrs. 2/19/91 KB, Total Drilling Days: 62.75 KB, 'I'VD 5459 Weight on Bit 16 1,000/lb 6" SEC. M44NF size make & type 168 in 19 T 8 , B feet rotating hrs 6" SEC. M4NJ size make & type 232 in T , B feet rotating hrs 6" bit, 2-junk subs, bit sub, 4-4-3/4" drill collars. to Date: Contractor: 0600 Report No. 63 February 20, 1991 Grace Rig 211 Total Rotating Hours: KB, Depth -5137 Rotary Speed 70 open 4961 jet sizes in I , I , Notes: Hrs. 2/20/91 100.5 SS. RPM. 5129 out open 5129 5361 jet sizes in , G , Notes: out Formation(s): Cased Hole Last Casing: Pump Pressure: 1450 Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ 110 361 psi, fi/sec. 7" 26#, N-80 @ 5447 ft size & grade depth SPM Pump Output: 347/8.25 (GPM)(BPM) FPM Annular Velocity (collars): 509 FPM or % Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: 8.6 (PPG), weight yield point % sand Detail: Milpark 3% KCI Brine mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ~ , in. 6 % pH filter cake solids % 28,000 ppm % 0.447 psi/ft oil chlorides water mud gradient Drill retainer at 5000'. Trip for bit #17 RIH drill on retainer at 5139'. Run in hole and tag junk at 5350. Mill on junk from 5350 to 5361. Circulate bottoms up. Pull out of hole. Safety cross over 3-1/2" of box to 2-7/8" AB-DS pin picked up from HOMCO. Conducted a conference with Baker Sand Control at their shop and reviewed gravel pack procedure. Instructed tuboscope to load all excess 3-1/2" uninspected tubing for return to ARCO/Swanson River pipe yard and to store inspected 3-1/2" tubing string for CPC's future use as per instructions of Kevin Brown. Weather: +8°F. Low overcast, winds calm. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineen~,~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 (TD) KB, Elevation 322 KB, Avg. fi/hr Weight on Bit Bit No. 18 6" size in feet Bit No. Drilling Setup: Hrs. Total Drilling Days: TVD 2/18/91 61.75 5459 6/15 1,000/lb SEC. M44NF make & type T rotating hrs size make & type in T , feet rotating hrs 6" bit, 2-junk subs, bit sub, 4-4-3/4" drill collars. , B to Date: Contractor: 0600 Report No. 62 February 19, 1991 Grace Rig 211 Total Rotating Hours: KB, Depth -5137 Rotary Speed 70/80 open 4961 jet sizes in , , Notes: Hrs. 2/19/91 100.5 SS. RPM. INC. out jet sizes in , G , Notes: INC. out Formation(s)' Cased Hole Last Casing: Pump Pressure: 1450 Annular Velocity (drill string)' Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ 110 361 psi, fi/sec. 7" 26#, N-80 @ 5447 ft size & grade depth SPM Pump Output: 347/8.25 (GPM)(BPM) FPM Annular Velocity (collars): 509 FPM or % Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: 8.6 (PPG), weight yield point % sand Detail: Milpark 3% KCI Brine mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. 6 % pH filter cake solids % 28,000 ppm % 0.447 psi/ft oil chlorides water mud gradient Run in hole and drill junk and retainer from 4964 to 4972'. Drill on retainer at 5000 ft. Remove 3-1/2" tubing from pipe rack and begin staging 2-7/8" tubing on pipe rack. Notify Schlumberger of pending wireline perforations to be conducted after retainer drill out and casing scraper run. Weather: + 15°F. Snowing, winds calm. Visibility 1/2 mile. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Enginee~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr Bit No. Bit No. Drilling Setup: CIRI West Fork 1-21 West Fork 5459 (TD) 322 0600 Hrs. 2/17/91 KB, Total Drilling Days: 60.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs Report No. 61 February 18, 1991 size make & type in T feet rotating hrs Date: Contractor: to 0600 Hrs. 2/18/91 Total Rotating Hours: 100.5 KB, Depth -5137 SS. Rotary Speed RPM. jet sizes in , B , , Notes: jet sizes in , B , G , Notes: Grace Rig 211 out INC. out Formation(s): Cased Hole Last Casing: Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. SPM FPM or 5447 7" 26#, N-80 @ size & grade Pump Output: Annular Velocity (collars): % Bit Hydraulic Horsepower: lb Pump Hydraulic Horsepower: HP depth (GPM)(BPM) FPM HP Drilling Fluid: 8.6 (PPG), weight yield point % sand Detail: Milpark 3% KCI Brine mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. 6 % pH filter cake solids % 28,000 ppm % 0.447 psi/fi oil chlorides water mud gradient Awaiting arrival of Baker Sand Control equipment. 3-1/2" tubing inspection complete. Clean up location in preparation for move-in of Baker equipment. Weather: + 12°F. Low overcast. Light snow, winds calm. Visibility 5 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Enginee, .~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr Bit No. ClRI West Fork 1-21 West Fork 5459 ('rD) 322 Date: Contractor: 0600 Hrs. 2/16/91 to 0600 KB, Total Drilling Days: 59.75 Total Rotating Hours: KB, TVD 5459 KB, Depth Weight on Bit 1,000/lb Rotary Speed size make & type jet sizes in in T , B , , Notes: feet rotating hrs Report No. 60 February 17, 1991 Grace Rig 211 Hrs. 2/17/91 100.5 -5137 SS. RPM. out Bit No. INC. size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Drilling Setup: Formation(s): Cased Hole Last Casing: 7" 26#, N-80 @ 5447 ft out size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark 3% KCI Brine mud company type 8.6 (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 ft2 , in. 6 % yield point pH filter cake solids % % 28,000 ppm % 0.447 psi/ff sand oil chlorides water mud gradient Detail: Awaiting arrival of Baker Sand Control equipment. Received one truck load of inspected 3-1/2" tubing. Tally tubing received. Remainder of 3-1/2" tubing still in process of inspection. Expect balance of 5500' tubing string Sunday p.m. Approximately 20 joints of tubing needed to be recut (pin end). Continued to lower level of effluent in reserve pit to take advantage of warm weather. Weather: +30°F. High overcast. Winds calm. Visibility 20 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri~._ Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. ft/hr Bit No. ClRI West Fork 1-21 West Fork 5459 ('rD) 322 Date: Contractor: 0600 Hrs. 2/15/91 to 0600 KB, Total Drilling Days: 58.75 Total Rotating Hours: KB, TVD 5459 KB, Depth Weight on Bit 1,000/lb Rotary Speed size make & type jet sizes in in T , B , , Notes: feet rotating hrs Report No. 59 February 16, 1991 Grace Rig 211 Hrs. 2/16/91 100.5 -5137 SS. RPM. out Bit No. INC. size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Drilling Setup: Formation(s): Cased Hole Last Casing: 7" 26#, N-80 @ 5447 fi out size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark 3% KCI Brine mud company type 8.6 (PPG), sec. weight funnel vis. plastic vis. water loss #100 ft2 , in. 6 % cps. cc Detail: yield point pH filter cake solids ~ % % 28,000 ppm % 0.447 sand oil chlorides water mud gradient Awaiting Baker Sand Equipment and 3-1/2" tubing inspection. psi/ft Continuing to inject reserve pit effluent. Clean up around location. Weather: +22°F. High overcast. Winds calm. Visibility 20 miles. Cumulative Mud Cost $ N/^ Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineering, Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. ft/hr Bit No. Bit No. Drilling Setup: ClRI West Fork 1-21 West Fork 5459 (TD) 322 0600 Hrs. 2/14/91 KB, Total Drilling Days: 57.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs size make & type in T feet rotating hrs tO Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed Report No. 58 February 15, 1991 Grace Rig 211 Hrs. 2/15/91 100.5 -5137 SS. RPM. jet sizes in , , Notes: out jet sizes in , G , Notes: INC. out Formation(s): Cased Hole Last Casing: Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, ft/sec. SPM FPM or lb 7" 26#, N-80 @ size & grade Pump Output: Annular Velocity (collars): % Bit Hydraulic Horsepower: Pump Hydraulic Horsepower: 5447 fl: depth (GPM)(BPM) FPM HP HP Drilling Fluid: 8.6 (PPG), weight yield point % sand Detail: #100 ft2 Milpark mud company sec. funnel vis. plastic vis. pH filter cake % 28,000 ppm % oil chlorides water Awaiting Baker Sand Equipment and 3-1/2" tubing inspection. 3% KCl Brine cps. in. type CC water loss 6 solids 0.447 psi/ft mud gradient Injecting reserve pit effluent. Warmer weather helps recovery of fluids from pit. Weather: +25°F. High overcast. Winds calm. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Enginee: Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. fi/hr Bit No. Date: Contractor: 0600 Hrs. 2/13/91 to 0600 KB, Total Drilling Days: 55.75 Total Rotating Hours: KB, TVD 5459 KB, Depth Weight on Bit 1,000/lb Rotary Speed size make & type jet sizes in in T , B , I , Notes: feet rotating hrs Report No. 57 February 14, 1991 Grace Rig 211 Hrs. 2/14/91 100.5 -5137 SS. RPM. out Bit No. INC. size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Drilling Setup: Formation(s): Cased Hole Last Casing: 7" 26#, N-80 @ 5447 ft out Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark 3% KCl Brine mud company type yield point % sand Detail; 8.6 (PPG), sec. weight funnel vis. plastic vis. # 100 fi2 9.0 , pH % 28,000 ppm oil chlorides Awaiting Baker sand equipment and 3-1/2" tubing inspection. cps. cc water loss in. 6 % filter cake solids % 0.447 psi/ff water mud gradient Due to the visually poor condition of the ClRI acquired 3-1/2" tubing, it was determined that a batch of 50 Joints will be put through the complete inspection cycle to give us an idea of the percentage of inspection failures. This information should be available approximately 2 p.m. on 2/14/91 at Tuboscope. Weather: +22°F. Scattered clouds, winds calm. Visibility 20 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineer' Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr Bit No. CIRI West Fork 1-21 West Fork 5459 ('I'D) 322 Date: Contractor: 0600 Hrs. 2/12/91 to 0600 KB, Total Drilling Days: 55.75 Total Rotating Hours: KB, TVD 5459 KB, Depth Weight on Bit 1,000/lb Rotary Speed size make & type jet sizes in in T , B , I , Notes: feet rotating hrs Report No. 56 February 13, 1991 Grace Rig 211 Hrs. 2/13/91 100.5 -5137 SS. RPM. out Bit No. INC. size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Drilling Setup: Formation(s): Retainers/Cased Hole Last Casing: 7" 26#, N-80 @ 5447 fi out size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark 3% KCI Brine mud company type 8.8 (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 ft2 9.0 , in. 6 % pH filter cake solids % 28,000 ppm % 0.447 psi/ft yield point % sand Detail: oil chlorides water mud gradient Rig up Joe's Oilfield Service. Run in hole with 2-7/8" tubing and lay down the same. Finish building brine volume. Rlease mud engineer. Awaiting Baker sand material and tubing inspection. Weather: +32°F. High overcast, winds calm. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 ('rD) KB, Elevation 322 KB, Avg. fi/hr Weight on Bit Bit No. 6" size in feet Bit No. Drilling Setup: Hrs. Total Drilling Days: TVD 2/11/91 54.75 5459 1,000/~b SEC. M4NJ make & type T rotating hrs size make & type in T , feet rotating hrs 6" bit; 2 junk subs; bit sub; 4-4-3/4" drill collars. , B to Date: Contractor: 0600 Report No. 55 February 11';' 1991 Grace Rig 211 Total Rotating Hours: KB, Depth -5137 Rotary Speed open 4961 jet sizes in , I , Notes: Hrs. 2/12/91 100.5 SS. RPM. out jet sizes in , G , Notes: INC. out Formation(s): Cement and Retainer Last Casing: Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. SPM FPM or 7" 26#, N-80 @ size & grade Pump Output: Annular Velocity (collars): % Bit Hydraulic Horsepower: lb Pump Hydraulic Horsepower: HP 5447 depth (GPM)(BPM) FPM HP Drilling Fluid: 8.6 (PPG), weight yield point % sand Detail: Milpark 3% KCI Brine mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 9.0 , in. 5/6 % pH filter cake solids % 28,000 ppm % 0.447 psi/ft oil chlorides water mud gradient Inject all brine from pits. Clean pits. Inject reserve pit fluids down annulus. Mix fresh 3% KCI brine weighted to 8.6#/gal with NaCI. Displace hole with fresh brine by reverse circulation method. Inject displaced fluids down annulus. Trip out of hole and begin rigging up Joe's Oilfield Service to begin laying down 2-7/8" tubing. Weather: +34°F. High overcast, winds calm. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Enginee~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: CIRI West Fork 1-21 West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. ft/hr Bit No. 16 Bit No. Drilling Setup: 0600 Hrs. 2/10/91 KB, Total Drilling Days: 53.75 KB, TVD 5459 Weight on Bit 10/15 1,000/lb 6" SEC. M4NJ size make & type 1523 in 19 T 8 , B feet rotating hrs 6" SEC. M4NJ size make & type in T , B feet rotating hrs 6" bit; 2 junk subs; bit sub; 4-4-3/4" drill collars. Report No. 54 Date: February 11, 1991 Contractor: Grace Rig 211 to 0600 Hrs. 2/11/91 Total Rotating Hours: 100.5 KB, Depth -5137 SS. Rotary Speed 60 RPM. open 3432 4955 jet sizes in out 8 , G I , Notes: open 4955 INC. jet sizes in out , G , Notes: Formation(s): Cement and Retainer Last Casing: Pump Pressure: 1200 Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ 110 361 psi, fi/sec. 7" 26#, N-80 @ 5447 fi size & grade depth SPM Pump Output: 347/8.25 (GPM)(BPM) FPM Annular Velocity (collars): 500 FPM or % Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: Milpark KCI Brine 8.6 (PPG), weight yield point % sand Detail: mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 13.0 , in. 6 % pH filter cake solids % 30,000 ppm % 0.447 psi/ft oil chlorides water mud gradient Drill out retainer at 3525'. Run in hole. Tag cement and junk from retainer at 4545'. Drill junk and cement to 4790'. Retainer set at 4711 did not show at designated spot. Run in hole and tag junk at 4955'. Attempt to pressure test casing. Air in the brine affected the first two casing tests with the following results: 1st test 1500 psi bled to 1200 psi in 10 minutes, 2nd test 1500 psi bled to 1350 psi in 10 minutes, 3rd test 1500 psi held for 25 minutes. Test good. Trip out of hole for bit #17. Weather: +36°F. High overcast, winds calm. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A ,, Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 (TD) KB, Elevation 322 KB, Avg. fi/hr Weight on Bit Bit No. 16 6" size in feet Bit No. Drilling Setup: Hrs. Total Drilling Days: TVD Report No. 53 February 10, 1991 Date: Contractor: 2/9/91 to 0600 Hrs. 2/10/91 52.75 Total Rotating Hours: 100.5 5459 KB, Depth -5137 SS. 1,000/lb Rotary Speed RPM. SEC. M4NJ open 3432 INC. make & type jet sizes in out T , B , G , Notes: rotating hrs size make & type jet sizes in T , B , G feet rotating hrs 6" bit; 2 junk subs; bit sub; 4-4-3/4" drill collars, 3-1/2" drill pipe. Grace Rig 211 Jn Notes: out Formation(s): Pump Pressure: 1200 Annular Velocity (drill string): Pressure Loss at Bit:' Jet Velocity: Bit Hydraulic Impact Force Surveys: Cement and Retainer Last Casing: 7" 26#, N-80 @ 5447 fi size & grade depth psi @ 110 SPM Pump Output: 347 (GPM)(BPM) 361 FPM Annular Velocity (collars): 500 FPM psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: Milpark KCI Brine 8.6 (PPG), weight yield point % sand Detail: mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 12.5 , in. 7 % pH filter cake solids % 30,000 ppm % 0.447 psi/ft oil chlorides water mud gradient Wait on cement 12 hours. Unseat Champ packer. Tdp out of hole. Lay down Champ packer assembly. Conduct B.O.P. test. Pick up 6" bit, junk subs and run in the hole. Tag soft cement at 3432'. Attempted to put weight on cement without success. Determined matrix cement should be allowed to cure until it could support 4 to 6,000 W.O.B. Begin drilling matrix cement to top of retainer. Circulate hole clean. Pressure test casing to 1500 psi for 10 minutes. Test ok. Begin drilling retainer at 3525. Weather: +25°F. High overcast, winds calm. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineer. Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. fi/hr Bit No. Bit No. Drilling Setup: 0600 Hrs. 2/8/91 KB, Total Drilling Days: 51.75 KB, TVD 5459 Weight on Bit 1,000/lb to Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed size make & type jet sizes in T , B , G feet rotating hrs size make & type jet sizes in T , B , G , feet rotating hrs Tail pipe, Champ packer assembly, 4-4-3/4 drill collars, 3-1/2" drill pipe. Report No. 52 February 9, 1991 Grace Rig 211 Hrs. 2/9/91 100.5 -5137 SS. RPM. in Notes: out in Notes: out Formation(s): Cased Hole Last Casing: Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. SPM FPM or 7" 26#, N-80 @ size & grade Pump Output: Annular Velocity (collars): % Bit Hydraulic Horsepower: lb Pump Hydraulic Horsepower: 5447 depth (GPM)(BPM) FPM HP HP Drilling Fluid: Milpark KCI Brine 8.7 (PPG), weight yield point % sand Detail: mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 12.5 , in. 7 % pH filter cake solids % 30,000 ppm % 0.452 psi/ft oil chlorides water mud gradient Lay down RTrS. Pick up Champ packer and run in the hole to 3509'. Set Champ packer. Pressure test to 1500 psi for 15 minutes on annular side. Test ok. Reset Champ packer at 3519'. Attempt annular test. Casing began to bleed off fluid at 1100 psi and would bleed off to 750 psi during shut in. Unseat Champ packer. Trip out of hole. Set EZSV at 3525'. Trip out of hole. Pick up Champ packer assembly with tail pipe and run in the hole. Pump 10 bbls water followed by 4 bbls 12.4# matrix cement slurry. Chase slurry with 2 bbls water and 23 bbls brine to achieve a balanced plug. Pull three stands and reverse circulate two ddll pipe volumes. Set Champ packer and down squeeze cement. Stage cement 1-1/2 bbls pressure up to 1400 psi - bled to 900 psi in 5 minutes, 1/2 bbl pressure up to 1400 psi - bled to 950 psi in 5 minutes, pressure up to 1400 psi and shut well in at surface. Wait on cement. Weather: 10°F. Partly cloudy, winds 10-15 knots NE. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Enginee~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: ClRI West Fork 1-21 West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. fi/hr Bit No. Bit No. 0600 Hrs. 2/7/91 KB, Total Drilling Days: 50.75 KB, 'I'VD 5459 Weight on Bit 1,000/lb to Date: Contractor: 06O0 Total Rotating Hours: KB, Depth Rotary Speed size make & type jet sizes in T , B , G feet rotating hrs size make & type jet sizes in T , B , G , feet rotating hrs Tail pipe (1 joint), R'I-I'S assembly, 4-4-3/4 drill collars, 3-1/2" drill pipe. Drilling Setup: Formation(s)' Cased Hole Report No. 51 February 8, 1991 Grace Rig 211 Hrs. 2/8/91 100.5 -5137 SS. RPM. in Notes: out in Notes: out Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ Last Casing: 7" 26#, N-80 @ 5447 ft size & grade depth SPM Pump Output: (GPM)(BPM) FPM Annular Velocity (collars): FPM psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: Milpark KCI Brine mud company type 8.6+ (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 ft2 12.5 , in. 7 % pH filter cake solids % 30,000 ppm % 0,447 psi/ft oil chlorides water mud gradient yield point % sand Detail: Mix 7 bbls of matrix cement with .5% CFR. Pumped 10 bbl water, 7 bbls of cement slurry, followed by 2 bbl of water and 31 bbls of brine to establish a balanced plug. Pull 5 stands and reverse circulate two pipe volumes. Set champ packer and down squeeze 1/2 bbl cement which pressured up to 1400 psi and bled off to 1100 psi in 5 minutes. An additional 1/2 barrel was squeezed and pressured up to 1600 psi and bled off to 1400 psi in 5 minutes. A final 1/2 bbl was squeezed which pressured up to 1700 psi and bled off to 1550 psi after 5 minutes. The drill pipe was shut in at surface for 12 hours monitoring shut in pressure. (Matrix cement data: slurry weight 12.4#/gal, yield .74, 0.5% CFRa, 39 cu ft.) Unseat champ packer and trip out of the hole. Pick up RTTS with 1 joint of tail pipe. Run in hole and tag cement at 4548'. Pull up one stand. Break circulation. Set R'I-rS rig up and pressure test annulus side of casing from 4529' to surface. Could not achieve a 1500 psi shut in pressure. 1300 psi bled down to 700 psi and stabilized within 2-1/2 minutes. Unseat R'I-rS and pull assembly up to 3428. Set RTTS and test annulus side of casing to 1500 psi for 10 minutes. Test ok. Unseat RTTS. Attempt to set RTI'S @ 3408 ft. Bypass valve would not close. Three more attempts to reset R'I-rS with the same results. Begin tdp out. ; Weather: -5°F. High overcast. Winds, calm. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Enginee Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: Depth: 5459 ('rD) Elevation 322 Avg. fi/hr Bit No. Bit No. Drilling Setup: 0600 Hrs. 2/6/91 KB, Total Drilling Days: 49.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs tO Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed jet sizes in , B , G , Notes: size make & type in T , B feet rotating hrs Tail pipe, Champ packer assembly. 3-1/2" drill pipe. Report No. 50 February 7, 1991 Grace Rig 211 Hrs. 2/7/91 100.5 -5137 SS. RPM. out jet sizes in , G , Notes: out Formation(s): Cased Hole Last Casing: Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. SPM FPM or lb 7" 26#, N-80 @ size & grade Pump Output: Annular Velocity (collars): % Bit Hydraulic Horsepower: Pump Hydraulic Horsepower: 5447 ft depth (GPM)(BPM) FPM HP HP Drilling Fluid: 8.6 (PPG), weight yield point % sand Milpark mud company sec. cps. funnel vis. plastic vis. #100 ft2 12.5 , in. pH filter cake % 29,000 ppm % Detail: oil chlorides water KCl Bdne type CC water loss 6 % solids 0.447 psi/ff mud gradient Pick up Halliburton RTTS. Run in the hole. Set R'I'TS at 4935'. Pressure test casing to 1500 psi for 10 minutes. Test good. Reset RTTS at 4555'. Break down at 1300 psi. Shut in for 10 minutes. Pressure bled back to 800 psi. Repeat test with same results. Reset R'I-rS at 4711'. Pressure test casing to 1500 psi for 10 minutes. Test good. Reset R'I-rS at 4555' to recOnfirm above results. Pressure to 1300 psi and bled down to 800 psi. Test fail. Trip out of hole. Lay down R'I-i'S. Pick up EZSV. Run in hole. Set EZSV at 4710'. Trip out of hole. Pick up Champ packer assembly with tail pipe and run in hole. Circulate and condition brine. Awaiting Halliburton equipment mechanic. Weather: -20°F. Skies clear. Winds calm. Visibility unlimited. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Dally Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Enginee. · Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 (TD) KB, Elevation 322 KB, Avg. fi/hr Weight on Bit Bit No. 13 6" size 312 in feet Bit No. Drilling Setup: Hrs. Total Drilling Days: TVD 2/5/91 48.75 5459 1,000/lb SEC. M4NJ make & type 5-1/2 T 8 rotating hrs size make & type in T feet rotating hrs EZSV setting tool, 3-1/2" drill pipe. , B tO Date: Contractor: 0600 Report No. 49 February 6, 1991 Grace Rig 211 Hrs. 2/6/91 Total Rotating Hours: 100.5 KB, Depth -5137 SS. Rotary Speed RPM. open 4700 5012 jet sizes in out 2 , G I , Notes: jet sizes in , B , G , Notes: out Formation(s): Cased Hole Last Casing: Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. SPM FPM or 7" 26#, N-80 @ size & grade Pump Output: Annular Velocity (collars): % Bit Hydraulic Horsepower: lb Pump Hydraulic Horsepower: HP 5447 depth (GPM)(BPM) FPM HP Drilling Fluid: Milpark KCl Brine 8.7 (PPG), weight yield point % sand Detail: mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 13 , in. 7 % pH filter cake solids % 30,000 ppm % 0.452 psi/ft oil chlorides water mud gradient Drill out cement to top of retainer. Tag retainer at 5012' approximately 40' below setting point of 4972'. Circulate bottoms up. Trip out of hole. Pick up casing scraper. Trip to 5012'. Circulate bottoms up. Trip out. Pick up Halliburton R'l-rS. SLM of drill pipe indicates EZSV is below open perfs at 4982'-92'. First R'l-rS run to verify if perfs are actually open. Set RTTS at 4965'. Pressure up to 700 psi. Bled back to 400 psi. Verify EZSV originally set at 4972' has failed and slipped down the hole exposing open perfs at 4982'-92'. Release RTTS and trip out of hole. Pick up EZSV on drill pipe. Strap in the hole. Set EZSV at 4972'. Trip out of hole. Weather: 5°F. Partially cloudy. Winds calm, light snow. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: CIRI West Fork 1-21 West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. fi/hr Bit No. 13 Bit No. 14 Drilling Setup: 0600 Hrs. 2/4/91 KB, Total Drilling Days: 47.75 KB, TVD 5459 Weight on Bit 8/12 1,000/lb 6" SEC. M4NJ size make & type 1440 in 19-1/2 T 8 , feet rotating hrs 6" SEC. M4NJ size make & type 360 in 12-1/2 T 2 , feet rotating hrs 6" Bit; 2-junk subs; bit sub; 4-4-3/4" D.C.; 3-1/2" DP. tO Date: Contractor: O6O0 Report No. 48 February 5, 1991 Grace Rig 211 Total Rotating Hours: KB, Depth -5137 Rotary Speed 100 open 2900 jet sizes in 8 , G I , Notes: Hrs. 2/5/91 100.5 SS. RPM. 434O out open 4340 4700 jet sizes in 2 , G I , Notes: out Formation(s): Pump Pressure: 1300 Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: Cement and Retainer Last Casing: 7' 26#, N-80 @ 5447 ft size & grade depth psi @ 110 SPM Pump Output: 8.25 (GPM)(BPM) FPM Annular Velocity (collars): FPM psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: Milpark KCI Brine mud company type 8.7 (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 fi2 12.5 , in. 7 % yield point pH filter cake solids % % 30,000 ppm % 0.452 psi/ft sand oil chlorides water mud gradient Detail: Trip for Bit #14. Run in the hole and drill cement from 4340' to top of EZSV at 4700'. Tdp for Bit #15. Drilling on retainer at 4700 at report time. Plan is to drill out retainer and cement to top of EZSV at 4972' conduct a casing scraper run. Rig up RTTS and begin zone testing casing to isolate and squeeze as necessary any zone not meeting the 1500 psi casing pressure criteria. Weather: -5°F. Clear and calm. Visibility unlimited. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineer Anchorage, Alaska (907) 276-4302 DAILY DRILUNG REPORT Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 0'D) KB, Elevation 322 KB, Avg. ft/hr Weight on Bit Bit No. 13 6' size in feet Bit No. Hrs. Total Drilling Days: 'i'VD 2/3/91 43.75 5459 1,0oo/ b SEC. M4NJ make & type T , B rotating hrs size make & type in T feet rotating hrs ,! Drilling Setup: 6' Bit; 2-junk subs; bit sub; 4-4-3/4" D.C.; 3-1/2" DP. to Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed open jet sizes in , G , Notes: Report No. 47 February 4, 1991 Grace Rig 211 Hrs. 2/4/91 100.5 -5137 SS. RPM. 2900 (cmt) INC. OUt jet sizes in , G , Notes: out Formation(s): Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. Last Casing: SPM FPM or 7" 26#, N-80 @ size & grade Pump Output: Annular Velocity (collars): % Bit Hydraulic Horsepower: lb Pump Hydraulic Horsepower: HP 5447 ft depth (GPM)(BPM) FPM HP Drilling Fluid: Milpark KCI Brine 8.7 (PPG), weight yield point % sand mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. % pH filter cake solids % 32,000 ppm % 0.452 pSi/ft oil chlorides water mud gradient Detail: Tagged cement at 2900 ft. Drilled out firm cement to top of retainer at 3030 ft. Tested perforations to 1500 psi for 30 minutes. Held ok. Drilled out cement retainer at 3030 ft and chased retainer junk down hole to 4256 ft. Closed rams and tested perfs from earlier squeeze job at 3500 ft and casing to 4256 ft with 1500 psi. Pressure slowly bled off to 900 psi. No way to tell if leak is through perfs or through hole in casing. Will drill out to top of retainer at 4792 ft and test casing with R'i-rs to find problem. Drilled on retainer junk and drilled on cement to 4360 ft at report time. Prep to make trip for new bit. · ,. .. --.'~,,~.. · -~.. Weather: -IO°F. Sky partly obscured, fog (ground). Wind < 5 knots from north. Visibility est. 1 mile. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Robert C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri~,~, Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 (TD) KB, Elevation 322 KB, Avg. fi/hr Weight on Bit Bit No. 13 6" size in feet Bit No. Drilling Setup: Hrs. Total Drilling Days: TVD 2/2/91 43.75 5459 1,000/lb SEC. M4NJ make & type T rotating hrs size make & type in T , B feet rotating hrs 6" Bit; 2-junk subs; bit sub; 4-4-3/4" D.C.; 3-1/2" DP. to Date: Contractor: 06O0 Total Rotating Hours: KB, Depth Rotary Speed open jet sizes in , G , Notes: Report No. 46 February 3, 1991 Grace Rig 211 Hrs. 2/3/91 100.5 -5137 SS. RPM. 2900 (cmt) INC. out jet sizes in , G , Notes: out Formation(s): Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. Last Casing: SPM FPM or 7" 26#, N-80 @ size & grade Pump Output: Annular Velocity (collars): % Bit Hydraulic Horsepower: lb Pump Hydraulic Horsepower: HP 5447 ft depth (GPM)(BPM) FPM HP Drilling Fluid: Milpark KCI Brine 8.6 (PPG), weight yield point % sand Detail: mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. % pH filter cake solids % 30,000 ppm % 0.447 psi/ft oil chlorides water mud gradient Correlated guns with Schlumberger. Set HRS packer. Rigged up PTS test manifold and tested lines with nitrogen to 3000 psi. Pumped 910 psi nitrogen cushion on top of 124 fi water cushion. Dropped bar and fired guns at 0842 hrs, 2/2/91. Perforations 3007.5 to 3017.5 ft at 12 HPF. Opened well 5 minutes with no pressure response. Shut in well 1 hour for pressure buildup. No buildup recorded at surface after 1 hour, and no fluid to surface. Terminated test. Killed well. Reversed circulated two tubing volumes. Released packer and circulated long way. No gas on bottoms up. POH and broke down complete test assembly. Advised by Kevin Brown of CPC that no further testing will be done at this time. Rigged down PTS, BJ, and Epoch and prep equipment for demob off location. Rigged up Schlumberger and set cement retainer at 3030 feet. RIH with open end dp to 3028 fi. Rigged up Halliburton and tested lines to 2000 psi. Laid 25 ft3 balanced plug on top of retainer. Pulled 4 stands and reversed out. Closed pipe rams and Bradenhead squeezed 2.5 bbls. Max. squeeze pressure 1250 psi. Shut in dp and held 105.0 psi on dp. WOC and preparing to drill out cement at report time. ' h I' :¢ i Weather: 10°F. Overcast. Wind estimated .5 knots from north. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Robert C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineen,.~ Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: Field: Report Period: Depth: 5459 ('rD) Elevation 322 Avg. fi/hr Bit No. Bit No. CIRI West Fork 1-21 West Fork 0600 Hrs. 2/1/91 KB, Total Drilling Days: 43.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs size make & type in T feet rotating hrs ! , , to Date: Contractor: 06O0 Total Rotating Hours: KB, Depth Rotary Speed Report No. 45 February 2, 1991 Grace Rig 211 Hrs. 2/2/91 100.5 -5137 jet sizes in B , G , Notes: jet sizes in B , G , Notes: SS. RPM. Drilling Setup: DST assembly: Vann System guns, HRS recorders and packer assembly, 4-3/4" drill collars, 3-1/2" DP. Formation(s): Last Casing: 7" 26#, N-80 @ 5447 ft out size & grade SPM Pump Output: FPM Annular Velocity (collars): or % Bit Hydraulic Horsepower: out Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM psi, fi/sec. HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: Milpark KCI Brine mud company type '8.6 (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 ft2 9.5 , in. % pH filter cake solids % 28,000 ppm % 0.447 psi/ft oil chlorides water mud gradient yield point % sand Detail: Completed TIH with gauge ring and junk basket. RIH with EZSV on wire line and set with top @ 4700 ft. Rigged down Schlumberger. RIH with champ packer and 16 jts (- 500 fi) 3-1/2" dp tail. Tagged EZSV and picked up 2 fi. Circulated two casing volumes. Rigged up Halliburton and set 83 cubic foot (.72 sxs) balanced plug. Pulled 8 stands (16 jts) dp and reversed out. No cement returns as 7 ppg differential was sufficient to allow cement to drop out of dp. Top of plug after pulling 8 stands calculated at 440 ft. Set packer and squeezed through dp. Got returns up annulus at 400 psi. 'Shut down pump and reset packer 2 fi higher. Resumed squeeze. Squeezed away total of 8.5 bbls with final pressure of 1850 psi. Toward end of job, noted slight return from annulus. Closed hydril and held pressure on drill pipe 2 hrs. Pressure bled back to 100 psi during this period. Unseated packer and pulled out of hole slow. Laid down packer. Packer showed external signs of leakage, but had some small pieces of junk on body. Changed valve on choke manifold and tested all BOPE to 5,000 psi except hydril which was ~ested to 2500 psi. Picked up Vann guns and HRS tools for DST #4. RIH and rabbit dp on trip in hole. Rigged up Schlumberger correlating guns with Schlumberger wireline at report time. ... Weather: IO°F. Overcast, light snow. Wind less than 5 mph from north. Visibility approximately 2 mi. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Robert C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri~.~ Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. ft/hr Bit No. Bit No. 0600 Hrs. 1/31/91 KB, Total Drilling Days: 43.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs , B to Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed Report No. 43 February 1, 1991 Grace Rig 211 Hrs. 2/1/91 100.5 -5137 SS. jet sizes in , G , Notes: RPM. out size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Drilling Setup: None (in hole with wireline to set cement retainer). Formation(s): Last Casing: 7" 26#, N-80 @ 5447 ft Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark KCI Brine mud company type 8.6 (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 ft2 10 , in. % pH filter cake solids % 30,000 ppm % .447 psi/ft oil chlorides water mud gradient Well shut in for pressure buildup analysis until 1430 hrs, 1/31/91. Rerouted steam line to BOP stack and yield point % sand Detail: changed methanol injection point in attempt to minimize chances of hydrate formation and freeze-up during test. Started modified 4-point test at 1430 hours 1/31 on 8/64 choke. Incrementally increased choke sizes to 18/64 at time of termination of test. Final stabilized flow on 18/64 choke was 4.67 MMCF @ 1350 psi, at which time flow rate became erratic and dropped rapidly due to hydrate formation. Terminated test @ 2115 hours on 1/31. Reversed out two tubing volumes and then pulled packer free and changed over to circulate long way. Max gas on bottoms up after changing to long way circulation = 880 units. Continued circulating until gas levels stable @ 5-10 units. POH and laid down test tools. Rigged up Schlumberger to set cement retainer in preparation to squeeze perfs. Running in hole with gauge ring and junk basket at report time. Weather: +15°F. Overcast, light snow. Wind estimated at 5-10 from NE. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Robert C. Gardner 0,7 ~ (?m~- ~..~>,... 'llO/i/:.rp~/~ ~ ~ *'; ¢~,,~'ilS.~i~.' Daily Total Well Oost $ N/A Gurnkoy) Rig Phone: 262-2048 ENSR Consulting and Engineeri, ~ Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. fi/hr Bit No. Bit No. Drilling Setup: 3-1/2" drill pipe. Date: Contractor: 0600 Hrs. 1/30/91 to 0600 KB, Total Drilling Days: 42.75 Total Rotating Hours: KB, TVD 5459 KB, Depth Weight on Bit 1,000/lb Rotary Speed size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Report No. 43 January 31, 1991 Grace Rig 211 Hrs. 1/31/91 100.5 -5137 SS. RPM. out size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs D.S.T. assembly. Vann Systems guns. H.R.S. record and packer assembly. 4-3/4" drill collars, Formation(s): Pump Pressure: Annular Velocity (drill string): Pressure Loss at Biti Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ Last Casing: 7" 26#, N-80 @ 5447 ft size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP depth (GPM)(BPM) FPM Drilling Fluid: Milpark KCI Brine 8.6 (PPG), weight yield point % sand mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 10 , in. % pH filter cake solids % 29,000 ppm % .447 psi/ft oil chlorides water mud gradient Continued to flow well on test at different choke settings. Shut in well for pressure buildup analysis at 1350 Detail: hrs 1/30. F.F. on 14/64 choke = 2.82 MMCF/D @ 1620 psi. Well is shut in at report time. Expect to resume testing at 1350 hrs today. Weather: -20°F. Wind calm. Visibility unlimited. Cumulative Mud Cost $ N/A Drilling Foreman: Cumulative Total Well Cost $ Virgil Thrapp N/A Dally Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri~,~ Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. fi/hr Bit No. Bit No. Drilling Setup: Report No. 42 January 30, 1991 Date: Contractor: 0600 Hrs. 1/29/91 to 0600 Hrs. 1/30/91 KB, Total Drilling Days: 41.75 Total Rotating Hours: 100.5 KB, 'rVD 5459 KB, Depth -5137 SS. Weight on Bit 1,000/lb Rotary Speed RPM. size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Grace Rig 211 out size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs D.S.T. assembly. Vann Systems guns. H.R.S. record and packer assembly. 4-3/4" drill collars, 3-1/2" drill pipe. Formation(s): Last Casing: Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. lb SPM FPM or @ 5447 ft size & grade depth Pump Output: (GPM)(BPM) Annular Velocity (collars): FPM % Bit Hydraulic Horsepower: HP Pump Hydraulic Horsepower: HP Drilling Fluid: Milpark KCI Brine 8.6 (PPG), weight yield point % sand Detail: mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 10 , in. % pH filter cake solids 29,000 ppm % .447 psi/ft oil chlorides water mud gradient Finish trip out of hole. Lay down D.S.T. assembly and retrieve H.R.S. Down hole recorders. Rig up Schlumberger and run gauge ring and junk basket. Feed back from H.R.S. tools and wireline work indicate only "some" sanding developed along with some water. Contacted fill at 5103' (36' of fill to top of EZSV retainer). Differences between down hole reservoir sensors (H.R.S.) and surface records (P.T.S.) would indicate that after the well's dramatic increase in flow rate (6+ MCFD to 10 MCFD), an environment was created for hydrate buildup which eventually diminished surface rates and pressure. H.R.S. records indicated no changes in down hole pressures during the same time frame. Set retainer at 2972'. Begin pickup up D.S.T. #3 assembly and run in hole. Correlate perf zone to guns with Schlumberger. Set packer. Test lines to 3000 psi drop bar. Fire guns. Flow well 10 minutes. Shut well in for two hours. Shut in pressure 1630 psi. Open well to test @ 10/64 choke. Weather: -10°F. Clear and calm. Visibility unlimited. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineers, Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. ft/hr Bit No. Bit No. 0600 Hrs. 1/28/91 KB, Total Drilling Days: 40.75 KB, TVD 5459 Weight on Bit 1,000/lb to Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed size make & type jet sizes in T , B , G feet rotating hrs Report No. 41 January 29, 1991 Grace Rig 211 Hrs. 1/29/91 100.5 -5137 SS. RPM. in Notes: out size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Drilling Setup: D.S.T. assembly. Vann Systems guns. H.R.S. record and packer assembly. 4 4-3/4" drill collars, 3-1/2" drill pipe. Formation(s): Cased Hole Last Casing: 7" 26#, N-80 @ 5447 ft Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark KCI Brine mud company type 8.6 (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 ~ 10 , in. % pH filter cake solids % 29,000 ppm % .447 psi/ft oil chlorides water mud gradient yield point % sand Detail: Finish picking up D.S.T. and run in hole. Correlate perf zone 4982'-4992' with Schlumberger. Set H.T.S. packer. Rig up P.T.S. test manifold and test lines to 3000 psi with nitrogen. Pump nitrogen cushion. Drop firing bar. Flow well for 5 minutes, shut in well for two hours. Begin flaring well through a 16/64 choke. Initial shut in pressure prior to flaring was 1648 psi. Increase choke to 24/64 after 2 hours of flaring. At 2200 hr pressure dropped 100 psi and flow dropped from 9.4 MCFD to 9.0 MCFD. Hole acting as if were loading up with either sand or water. No confirmation at surface reduced choke back to 16/64 to see if flow will stabilize. Flow reduced to 2.9 MCFD at 980 psi at 2300 hrs. As per instructions from CIRI representatives, K. Brown and M. Zhange, HR well was shut in and instructions to kill the well were given. Kill well reversing through P.T.S. manifold and circulating long way until gas shows at a minimum. Begin trip out of hole. Weather: 16°F. Scattered clouds, winds light and variable. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineer,, ,u Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. fi/hr Bit No. Bit No. Drilling Setup: Date: Contractor: 0600 Hrs. 1/27/91 to 0600 KB, Total Drilling Days: 39.75 Total Rotating Hours: KB, TVD 5459 KB, Depth Weight on Bit 1,000/lb Rotary Speed size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Report No. 40 January 28, 1991 Grace Rig 211 Hrs. 1/28/91 100.5 -5137 SS. RPM. out size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs D.S.T. assembly. Vann Systems guns. H.R.S. assembly. 4 4-3/4" drill collars, 3-1/2" drill pipe. Formation(s): Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, ft/sec. Last Casing: 7" 26#, N-80 @ 5447 ft size & grade depth SPM Pump Output: (GPM)(BPM) FPM Annular Velocity (collars): FPM or % Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: Milpark KCI Brine 8.6# (PPG), weight yield point % sand mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. % pH filter cake solids % 26,000 ppm % .447 psi/ft oil chlorides water mud gradient Continue with shut in well monitoring. Shut in dead weight psi at 1828 psi after 24 hrs. Begin killing well at Detail: 1300 hrs. Reverse circulate through packer valve flaring gas. Change over reverse circulating through rig choke and gas buster. Unseat packer and circulate the long way until gas detection at minimum (< 10 units). Trip out of hole slowly and monitor well. Lay down D.S.T. assembly and recover H.R.S. pres/temp recorder. Rig up Schlumberger. Run junk basket and gauge ring. Wireline EZSV to 5139' set retainer. Rig down Schlumberger. Begin picking up drill stem test assembly (Vann Systems guns, H.R.S. recorder and packer assembly). Run in hole on 3-1/2" drill pipe. Weather: 16°F. Winds calm, clear sky. Visibility unlimited. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineerl, ~, Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. fi/hr Bit No. Bit No. Drilling Setup: Date: Contractor: 0600 Hrs. 1/26/91 to 0600 KB, Total Drilling Days: 38.75 Total Rotating Hours: KB, TVD 5459 KB, Depth Weight on Bit 1,000/lb Rotary Speed size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Report No. 39 January 27, 1991 Grace Rig 211 Hrs. 1/27/91 100.5 -5137 SS. RPM. out size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs D.S.T. assembly. Vann Systems guns. H.R.S. assembly. 4 4-3/4" drill collars, 3-1/2" drill pipe. Formation(s): Pump Pressure: N/A Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ Last Casing: 7" 26#, N-80 @ 5447 fi size & grade Pump Output: Annular Velocity (collars): % Bit Hydraulic Horsepower: Pump Hydraulic Horsepower: psi, fi/sec. SPM FPM or depth (GPM)(BPM) FPM HP lb HP Drilling Fluid: Milpark KCI Brine 8.6# (PPG), weight yield point % sand mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. % pH filter cake solids % 26,000 ppm % .447 psi/fi oil chlorides water mud gradient After 4 hours of stable flow of 4.8 MCFD, the well was shut in at 0950 hrs. Initial indications show zone Detail: produced dry gas with small amounts of mud filtrate and minor amounts of water. There were no problems with sanding during flow period. Initial shut in pressure after flow period was 1800 psi. Well shut in and monitored for 24 hours. Weather: 18°F. Winds calm, patchy fog. Visibility 1/4 mile. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri:.~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: ClRi West Fork 1-21 Field: West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. fi/hr Bit No. Bit No. 0600 Hrs. 1/25/91 KB, Total Drilling Days: 37.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs tO Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed Report No. 38 January 26, 1991 Grace Rig 211 Hrs. 1/26/91 100.5 -5137 , B SS. RPM. jet sizes , G in Notes: out Size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Drilling Setup: D.S.T. assembly. Vann Systems guns. H.R.S. assembly. 4 4-3/4" drill collars, 3-1/2" drill pipe. Formation(s): Cased Hole Last Casing: 7" 26#, N-80 @ 5447 ft Pump Pressure: N/A Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark KCI Brine 8.6# (PPG), weight N/A # 100 ft2 yield point N/A % N/A % sand oil Detail: mud company type N/A sec. N/A cps. N/A cc funnel vis. plastic vis. water loss N/A , N/A in. N/A % pH filter cake solids N/A ppm N/A % .447 psi/ft chlorides water mud gradient Ran in hole with test assembly. Correlate guns to perf zone with Schlumberger. Set H.R.S. packer assembly. Rig up manifold and pressure test all lines to 3000 psi with nitrogen. Set nitrogen cushion at 1460 psi. Drop Vann gun bar and shoot perf zone at 1745 hrs. Daylight test criteria was recinded by CIRI representatives, Kevin Brown and Mengghi Zhang, after being informed that the testing would extend into night time which was contrary to original testing plans. Well was shut in after 5 minutes. After 1 hour 20 minutes, well pressure had stabilized at 1750 psi and was then opened to separator and flare line. Flow well with 1600 psi rack pressure on manifold. Gas producing 3.1 MMLFD after 2-hr flow. Peak flow was 4.9 MCFD. Well stabilized at 4.8 MCFD. Flow at stable rate with heater choke at 34/64, 1661 psi and 4.8 MCFD. ;'~"'~' ' %,?/, ' *ozoO. Weather: 27°F. Low overcast, winds calm. Visibility 2 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineen,,~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 (TD) KB, Elevation 322 KB, Avg. fi/hr Weight on Bit Bit No. 12 6" size N/A in feet Bit No. Drilling Setup: Hrs. Total Drilling Days: TVD Report No. 37 January 25, 1991 Date: Contractor: 1/24/91 to 0600 Hrs. 1/25/91 36.75 Total Rotating Hours: 100.5 5459 KB, Depth -5137 SS. 1,000/lb Rotary Speed RPM. Security M4NJ open 5354 5354 make & type jet sizes in out N/A T , B , G , Notes: rotating hrs Grace Rig 211 size make & type jet sizes in in T , B , G , Notes: feet rotating hrs 6" bit, junk sub, bit sub, 4 4-3/4" drill collars. Vann Systems gun, H.R.S. tools and packer out assembly, drill collar 3-1/2" drill pipe. Formation(s): Cased Hole Last Casing: 7" 26#, N-80 @ 5447 ft Pump Pressure: N/A Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % E/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark KCI Brine 8.6# (PPG), weight N/A #100 ft2 yield point N/A % N/A % sand oil Detail: mud company type N/A sec. N/A cps. N/A cc funnel vis. plastic vis. water loss N/A , N/A in. N/A % pH filter cake solids N/A ppm N/A % .447 psi/E chlorides water mud gradient Displace hole with water. Close Hydril and monitor casing pressure. Mix up 8.6# KCl brine. Displace hole with brine. Mix remaining pit volume to 8.6#/gallon. Circulate hole. Trip out of hole breaking each joint. Cleaning both box and pin. Redoping tool joint and torquing to specifications. Pick up Vann System guns and H.R.S. assembly and begin trip in the hole. Weather: 24°F. Winds calm, patchy fog. Visibility 1/4 mile. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri,,u Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: Field: Report Period: Depth: 5459 (TD) Elevation 322 Avg. fi/hr N/A Bit No. 12 Bit No. ClRI West Fork 1-21 West Fork 0600 KB, KB, Weight on Bit 6" size in feet Hrs. Total Drilling Days: TVD 1/23/91 35.75 5459 N/A 1,000/lb Security M4NJ make & type T , B rotating hrs size feet make & type in T rotating hrs to Date: Contractor: 06O0 Report No. 36 January 24, 1991 Grace Rig 211 Total Rotating Hours: KB, Depth -5137 Rotary Speed N/A open 5354 jet sizes in , G , Notes: jet sizes in B , G , Notes: Hrs. 1/24/91 100.5 Drilling Setup: 6" bit, junk sub, bit sub, 4 4-3/4" drill collars 3-1/2" D.P. 3-1/2" B.P. Formation(s): In Casing Last Casing: 7" 26#, N-80 @ 5447 ft SS. RPM. INC out out size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark KCI Brine E Pits mptying (PPG), weight mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. % pH filter cake solids % ppm % psi/ft oil chlorides water mud gradient yield point % sand Detail: Ran in hole with casing scraper assembly. Circulated and conditioned mud. Trip out of hole. Rig up Schlumberger. Run C.E.T. through squeeze zone. Indications that squeeze isolated section desired. Pick up junk sub BHA and run in hole. Inject mud and clean pits. Epoch, Milpark representatives on location. Vann systems P.T.S., H.R.S., BJ Nitrogen Service, Schlumberger have been contacted and are informed of pending operations. Weather: Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineer.,,.~ Anchorage, Alaska (907) 276-4302 DALLY DRILUNG REPORT Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 (TD) KB, Elevation 322 KB, Avg. fi/hr 25 Weight on Bit Bit No. 12 6' size 354 in feet Bit No. 6' size feet Hrs. Total Drilling Days: TVD in 1/22/91 34.75 5459 5/15 1,000/lb Security M4NJ make & type 14 T 8 ,,, rotating hrs Security M4NJ make & type T rotating hrs to Date: Contractor: 06O0 Report No. January ~., 1991 Grace Rig 211 Total Rotating Hours: KB, Depth -5137 Rotary Speed open 5009 jet sizes in 6 , G I , Notes: 35 Hrs. 1/23/91 100.5 SS. RPM. 5636 OUt open 56O9 jet sizes in , G , Notes: inc out Drilling Setup: 6" bit, junk sub, bit sub, 4 4-3/4" drill collars 3-1/2" D.P./6" bit casing scraper, 4 4-3/4" drill collars, 3-1/2" D.P. Formation(s): Cement and Retainers Last Casing: 7' 26#, N-80 @ 5447 ft size & grade psi @ 110 SPM Pump Output: 347/8.25 361 FPM Annular Velocity (collars): psi, or N/A fi/sec. Bit Hydraulic Horsepower: N/A HP lb Pump Hydraulic Horsepower: N/A HP Pump Pressure: 1200 Annular Velocity (drill string): Pressure Loss at Bit: N/A Jet Velocity: N/A open jets Bit Hydraulic Impact Force N/A Surveys: depth (GPM)(BPM) 509 FPM Drilling Fluid: Milpark 9.4 (PPG), weight yield point % sand Detail: No further mud. j'eport until down hole opera[~ons resume. mud company type 34 sec. cps. CC funnel vis. plastic vis. water loss #100 ft2 , in. % pH filter cake solids % ppm % .489 psi/fi oil chlorides water mud gradient Test perf zone to equivalent mud weight of 14.5 ppg. Pressured up to 1300 psi 3 times. Each. time pressure bled back to 1000 psi over a period of 4 to 6 minutes. Decision was to go ahead and perform the squeeze. Perform squeeze by Stab-In method. 15 cu ft. of matrix cement blended with 5% CFR-3 slurry weight = 12.6 ppg. Initial induction rate and pressure was 0.25 bpm/1450 psi. Final injection rate and pressure was .25 bpm/1900 psi. 2 minute shut in pressure stabilized at 1650 psi. Shut down injection after 8 cu. ft. displaced into formation as pressure indicator showed psi starting to break back. Reverse circulated after unstinging. Trip out of hole. Pick up bit and junk sub and ran into hole. Drill on retainer at 5010 and 5021. Run to bottom. Circulate bottoms up. Trip out of hole. Pick up casing scraper BHA. Run in hole. Weather: 30°F. High overcast. Winds calm. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri~,u Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr Bit No. Bit No. Drilling Setup: CIRI West Fork 1-21 West Fork 5459 (TD) 322 0600 Hrs. 1/21/91 KB, Total Drilling Days: 33.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs size make & type in T feet rotating hrs 3-1/2' D.P. slick with EZSV stinger. Report No. 34 January 22, 1991 Date: Contractor: to 0600 Hrs. 1/22/91 Total Rotating Hours: 100.5 KB, Depth -5137 SS. Rotary Speed RPM. Grace Rig 211 jet sizes in , G , Notes: out jet sizes in , G , Notes: out Formation(s): Cased Hole Last Casing: Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, ft/sec. 7" 26#, N-80 @ 5447 ft size & grade depth SPM Pump Output: (GPM)(BPM) FPM Annular Velocity (collars): FPM or % Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: 9.4 (PPG), weight yield point % sand Milpark No further mud. j'eport until down hole opera[~ons resume. mud company type 42 sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. % Detail: pH filter cake solids % ppm % .489 psi/ft oil chlorides water mud gradient Awaiting CIRI representatives. Further analysis on C.E.T. has been considered and further cement squeezes will be performed. Prior to squeezing, the perf zone shall be circulated with EZSVs and a P.I.T. will be conducted to the equipment mud weight of 14.5 ppg. If perfed zone breaks down prior to 14.5 E.M.W., then a squeeze will be conducted. Rig up Schlumberger. Pick up EZSV and run in hole on wireline. Set EZSV and retrieve wireline. Pick up perforation guns. Run in hole and perforate zone 5015'-5017. Retrieve wireline. Pick up EZSV #2. Run in hole and set EZSV above perforations. Retrieve wireline. Rig down Schlumberger. Run in hole to top of EZSV. Rig up Halliburton pumper. l'~ ;-. Weather: 34°F. Cloudy, light rain. Visibility 2 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Dally Total Well Cost $ N/A (Tumkey) Rig Phone: 262-2048 ENSR Consulting and Engineer.. ~ Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Report No. 33 Well Number: ClRI West Fork 1-21 Date: January 21, 1991 Field: West Fork Contractor: Grace Rig 211 Report Period: 0600 Hrs. 1/20/91 to 0600 Hrs. 1/21/91 Depth: 5459 (TD) KB, Total Drilling Days: 32.75 Total Rotating Hours: 100.5 Elevation 322 KB, 'I'VD 5459 KB, Depth -5137 SS. Avg. fi/hr Weight on Bit 1,000/lb Rotary Speed RPM. Bit No. 11 6" Security M4NJ open jets 5031 5363 size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Bit No. size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Drilling Setup: Formation(s)' Cased Hole Last Casing: 7" 26#, N-80 @ 5447 ft out size & grade psi @ 110 SPM Pump Output: 347/8.25 361 FPM Annular Velocity (collars): psi, or N/A % fi/sec. Bit Hydraulic Horsepower: N/A HP lb Pump Hydraulic Horsepower: N/A HP Pump Pressure: 1200 Annular Velocity (drill string): Pressure Loss at Bit: N/A Jet Velocity: N/A (open jets) Bit Hydraulic Impact Force N/A Surveys: depth (GPM)(BPM) 509 FPM Drilling Fluid: Milpark No further mud3eport until down hole operauons resume. mud company type 9.4 (PPG), 36 sec. cps. weight funnel vis. plastic vis. water loss CC #100 ft2 , in. % yield point pH filter cake solids % % ppm % .489 sand oil chlorides water mud gradient psi/ft Detail: Pick up casing scraper assembly. Run in hole to top~! of float collar. Circulate and condition mud for C.E.T. and testing. Trip out of hole. Rig up Schlumberger and run C.E.T. Contact all service companies involved in the well testing program. (P.T.S., Vann Systems, H.R.S. Joe's Oilfield Service, Epoch, and Milpark). Begin general rig up. Discovered tubing has Atlas Bradford D.S.S. threads. Neither Vann Systems nor HRS has compatible crossover subs. Contacted Tristate and ordered subs to be fabricated since they had none in stock. Tristate's machinist called back and said they would be unable to fabricate the required subs. Contacted Homeco (old Land and Sea) they did not have the requested crossovers. They informed me that they are a licensed Atlas Bradford representative and in order to make the crossovers, A.B. must send prints and gauge to authorize the cuts. Prints could be in Monday PM and crossovers completed possibly Tuesday. Pick up tubing and rack in d~lri~. Weather: 30°F. High overcast. Winds light and variable. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey)' Rig Phone: 262-2048 ENSR Consulting and Engineering Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT EN,'R Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 (TD) KB, Elevation 322 KB, Avg. ft/hr Weight on Bit Bit No. 10 6" size 2023 in feet Bit No. 11 6" size Drilling Setup: Hrs. Total Drilling Days: TVD 1/19/91 31.75 5459 5/15 1,000/lb Security M4NJ make & type 16.5 T rotating hrs Security M4NJ tO Date; Contractor: 0600 Report No. 32 January 20, 1991 Grace Rig 211 Total Rotating Hours: KB, Depth -5137 Rotary Speed 70/110 open jets 3008 jet sizes in , G , Notes: open jets 5031 make & type jet sizes in in T , B , G , Notes: Hrs. 1/20/91 100.5 SS. RPM. 5031 out feet rotating hrs out Bit, junk sub, bit sub. 4 4-3/4" drill collars. Drill pipe. 117.82' (5500#). Formation(s): Cement and Retainers Last Casing: Pump Pressure: 1600 Annular Velocity (dri!l string): Pressure Loss at Bit: N/A Jet Velocity: N/A (open jets) Bit Hydraulic Impact Force N/A Surveys: psi @ 110 361 7" 26#, N-80 @ size & grade SPM Pump Output: 347/8.25 FPM Annular Velocity (collars): psi, or N/A % ft/sec. Bit Hydraulic Horsepower: N/A HP Pump Hydraulic Horsepower: 5447 ft depth (GPM)(BPM) 509 FPM lb N/A HP Drilling Fluid: 9.4 (PPG), weight yield point % sand Detail: Milpark No further mud. j'eport until down hole operauons resume. mud company type 38 sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. % pH filter cake solids % ppm % .489 psi/ft oil chlorides water mud gradient Drill retainer and cement from 3008' to 3024. Trip in hole to top of EZSV retainer at 5029'. Drill cement and retainer. Trip for Bit #11 at 5031'. Drill retainer and cement. Run in hole to top of EZSV retainer. Drill retainer and cement. Run in hole to top of float collar. Circulate hole clean. Trip out of hole. Weather: 30°F. Sky overcast. Cumulative Mud Cost $ Drilling Foreman: N/A Cumulative Total Well Cost $ N/A Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri~,~l Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Report Period: Depth: 5459 (TD) Elevation 322 Avg. fi/hr Bit No. 10 Bit No. Date: Contractor: 0600 Hrs. 1/18/91 to 0600 KB, Total Drilling Days: 30.75 Total Rotating Hours: KB, TVD 5459 KB, Depth Weight on Bit 5/10 1,000/lb Rotary Speed 6" Security M4NJ open jets 3008 size make & type jet sizes in T , B , G , feet rotating hrs Drilling Setup: Formation(s): Cement and Retainers Last Casing: size make & type jet sizes in T , B , G , feet rotating hrs Bit, junk sub, bit sub. 4 4-3/4" drill collars. Drill pipe. 117.82' (5500#). Report No. 31 January 19, 1991 Grace Rig 211 Hrs. 1/19/91 100.5 -5137 SS. 70/110 RPM. in Notes: out in Notes: out Pump Pressure: 1200 psi @ 110 SPM Annular Velocity (drill string): 361 FPM Pressure Loss at Bit: N/A psi, or Jet Velocity: N/A (open jets) fi/sec. Bit Hydraulic Impact Force N/A lb Surveys: 7" 26#, N-80 @ size & grade Pump Output: 347/8.25 Annular Velocity (collars): N/A % Bit Hydraulic Horsepower: Pump Hydraulic Horsepower: 5447 fi depth (GPM)(BPM) 509 FPM N/A HP N/A HP Drilling Fluid: Milpark 9.4 (PPG), weight yield point % sand Detail: No further mud. j'eport until down hole opera[~ons resume. mud company type 44 sec. cps. cc funnel vis. plastic vis. water loss #100 ft2 , in. % pH filter cake solids % ppm % .489 psi/fi oil chlorides water mud gradient Run second EZSV retainer and set at 5029'. squeeze by STAB method, 13 cu fi. of 15.6# premium class G blended with 0.2% CFR3, 0.4% Halad 344, and 0.1% HR-7. Shut in pressure stabilized at 1400 psi. Unsting drill pipe. Reverse circulate prior to unsting out of the hole. Run third EZSV retainer and set at 3008'. Breakdown injection was 700 psi. This indicated very poor cement in perf zone area. It was decided to increase slurry size. Squeeze by STAB method, 30 cu. ft. of 15.6# premium Class G cement blended with 0.2% CFR3, 0.4% Halad 344 and 0.1% HR-7. Shut in pressure stabilized at 750 psi. Unsting drill pipe, reverse circulate prior to tripping out of the hole. Pick up bit #10 and run in hole to top of retainer. Drill retainer and cement from 3008'. Weather: 32°F. High overcast. Winds calm. Visibility 10 miles. Cumulative Mud Cost $ Drilling Foreman: N/A Cumulative Total Well Cost $ Virgil Thrapp N/A Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineering Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT EN,'R Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr Bit No. Bit No. Drilling Setup: CIRI West Fork 1-21 West Fork 5459 (TD) 322 0600 Hrs. 1/17/91 KB, Total Drilling Days: 29.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs size make & type in T feet rotating hrs EZSV Retainer, 3-1/2' drill pipe. Report No. 30 January 18, 1991 Date: Contractor: to 0600 Hrs. 1/18/91 Total Rotating Hours: 100.5 KB, Depth -5137 SS. Rotary Speed RPM. Grace Rig 211 jet sizes in , G , Notes: out open 5095 na jet sizes in , G , Notes: out Formation(s): Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. Last Casing: 7" 26#, N-80 @ 5447 ft size & grade depth SPM Pump Output: (GPM)(BPM) FPM Annular Velocity (collars): FPM or % Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: (PPG), weight yield point % sand Milpark No further mud. j'eport until down hole operauons resume. mud company type sec. cps. cc funnel vis. plastic vis. water loss #100 fi2 , in. % Detail: pH filter cake solids % ppm % .489 psi/ft oil chlorides water mud gradient Circulate and condition mud. Trip out of hole. Test and begin running tubing on location. Prepare pad to accommodate P.T.S., Schlumberger, and Vann systems. After a meeting with ENSR and CIRI representatives in Anchorage, it was determined that three more squeezes will be conducted. Rig up Schlumberger. Wireline into hole. Perforate line S1'89'. Retrieve guns. Rig up for second perforation. Wireline into hole. Perforate zone 5038' 5040'. Retrieve guns. Rig up for third perforation. Wireline into hole. Perforate zone 2098' 3000'. Retrieve gun. Rig Schlumberger. Pick up EZSV retainer on drill pipe. SLM into hole. Detained at 51~9'. Rig up Halliburton. Squeeze, 100 fi of 15.6# premium Class G blended with 0.2% CFR3, 0.4% H~lad 344, and 0.1% HR-7. Shot in pressure STAB at 1300 psi. Unsting drill pipe, reverse circulate and trip out of the h~e:~I' .Pick up EZSV retainer on drill pipe and trip in the hole. Weather: 12°F. Overcast. Light and variable winds. Visibility 5 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineering Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT EN 'R Report No. 29 Well Number: CIRI West Fork 1-21 Date: January 17, 1991 Field: West Fork Contractor: Grace Rig 211 Report Period: 0600 Hrs. 1/16/91 to 0600 Hrs. 1/17/91 Depth: 5459 ('rD) KB, Total Drilling Days: 28.75 Total Rotating Hours: 100.5 Elevation 322 KB, TVD 5459 KB, Depth -5137 SS. Avg. fi/hr Weight on Bit 5/15 1,000/lb Rotary Speed 70/110 RPM. Bit No. 6" Security M4NJ open 5095 5363 size make & type jet sizes in out in T , B , G , Notes: feet rotating hfs Bit No. 6" Security M4NJ open 5095 na size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Drilling Setup: 6" bit, casing scraper. Bit sub 4 4-3/4" drill collars. BHA wt. approx. 5500# Formation(s): Cement Last Casing: 7" 26#, N-80 @ 5447 ft out Pump Pressure: 1500 psi @ 110 Annular Velocity (drill string): 361 Pressure Loss at Bit: N/A psi, Jet Velocity: N/A open jets fi/sec. Bit Hydraulic Impact Force N/A lb Surveys: size & grade SPM Pump Output: 347/8.25 FPM Annular Velocity (collars): or N/A % Bit Hydraulic Horsepower: N/A HP Pump Hydraulic Horsepower: N/A HP depth (GPM)(BPM) 5O9 FPM Drilling Fluid: Milpark 9.4 (PPG), weight No further mud. j'eport until down hole opera[~ons resume. mud company type 40 sec. cps. CC funnel vis. plastic vis. water loss #100 ft2 , in. % pH filter cake solids % ppm % .489 psi/ft oil chlorides water mud gradient yield point % sand Detail: Drill through bottom retainer at 5128. Run in hole to top of collar. Pump high viscosity sweep and circulate out. Trip out of hole. Lay down junk bucket. Pick up casing scraper and run in the hole. Circulate and condition mud. Trip out of hole. Rig up Schlumberger to run and squeeze C.E.T. Conduct a C.E.T. Conference call to ENSR, Anchorage discussing the effective isolation of all the zones of interest was conducted. In call interim, station indicates effective isolation complete and that tests can proceed, Vann systems and P.T.S. have been contacted regarding testing of West Work 1-21. Run in hole. Circulate and condition. · -/ Weather: 2°F. N.E. winds 5 to 10 mph. High overcast, light snow. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Enginee~,,,~l Anchorage, Alaska (907) 276-4302 DALLY DRILMNG REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 (TD) KB, Elevation 322 KB, Avg. fi/hr Weight on Bit Bit No. 6' size 375 in feet Bit No. 6" size Hrs. Total Drilling Days: TVD 1/15/91 27.75 5459 1015 1,000/lb Security M4NJ make & type 16.5 T 8 rotating hrs Security M4NJ to Date: Contractor: Report No. 28 January 16, 1991 Grace Rig 211 Total Rotating Hours: KB, Depth 5137 Rotary Speed 70-110 open 4720 jet sizes in 6 , G I , Notes: Hrs. 1/16/91 100.5 open 5095 na make & type jet sizes in in T , B , G , Notes: SS. RPM. 5095 out feet rotating hrs out Drilling Setup: 6' bit, junk basket. Bit sub 4 4-3/4' drill collars. BHA 117.32', approx, wt. 5500#, 3-1/2-Inch drill pipe. Formation(s): Cement and Retainers Last Casing: 7' 26#, N-80 @ 5447 ft size & grade psi @ 110 SPM Pump Output: 347/8.25 361 FPM Annular Velocity (collars): psi, or N/A fi/sec. Bit Hydraulic Horsepower: N/A HP lb Pump Hydraulic Horsepower: N/A HP Pump Pressure: 1500 Annular Velocity (drill string): Pressure Loss at Bit: N/A Jet Velocity: N/A open jets Bit Hydraulic Impact Force N/A Surveys: depth (GPM)(BPM) 509 FPM Drilling Fluid: Mill~ark/Nq further .mud report until aownno~e opera[~ons resume. mud company 9.4 (PPG), 45 sec. weight funnel vis. plastic vis. yield point % sand type cps. cc Detail: #100 ft2 , in. water loss pH filter cake solids % ppm % .489 oil chlorides water mud gradient Set on retainer at 4740'. Drill cement to set on cement stringers to 4840'. Run in hole to 5024'. psi/ft Drill hard cement to top of retainer at 5071'. Drill through retainer and pump a high viscosity sweep. Circulate bottoms up trip out of the hole for bit No. 9. Run the hole to 5095'. Drill cement to top of retainer at 5128, drill out retainer. Weather: 10°F. Winds calm, high overcast, visibility 10 miles i i i i Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineer,, ,9- Anchorage, Alaska (907) 276-4302 DALLY DRILUNG REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 (TD) KB, Elevation 322 KB, Avg. fi/hr Weight on Bit Bit No. 6" size 1284 in feet Bit No. 6" size Drilling Setup: Hrs. Total Drilling Days: TVD 1/14/91 26.75 5459 1015 1,0(X)/Ib Security M4NJ make & type 16 T 8 rotating hrs Security M4NJ to Date: Contractor: 06O0 Report No. 27 January 15, 1991 Grace Rig 211 Total Rotating Hours: KB, Depth 5137 Rotary Speed open 3436 jet sizes in 6 , G I , Notes: Hrs. 1/15/91 100.5 SS. 110-120 RPM. 4720 out open 4720 na make & type jet sizes in in T , B , G , Notes: feet rotating hrs out 6" bit, junk basket. Bit sub 4 4-3/4" drill collars. BHA 117.32', approx, wt. 5500#. Formation(s): Cement and Retainers Last Casing: Pump Pressure: 1500 Annular Velocity (drill string): Pressure Loss at Bit: N/A Jet Velocity: N/A open jets Bit Hydraulic Impact Force N/A Surveys: psi @ 113 361 7' 26#, N-80 @ size & grade SPM Pump Output: 347/8.25 FPM Annular Velocity (collars): psi, or N/A fi/sec. Bit Hydraulic Horsepower: N/A HP Pump Hydraulic Horsepower: 5447 ft depth (GPM)(BPM) 509 FPM lb N/A HP Drilling Fluid: Milpark oNoO f(/rtber mud.report until wnno~e opera[~ons resume mud company type 9.4 (PPG), 36 sec. cps. weight funnel vis. plastic vis. water loss cc #100 ft2 , in. % yield point pH filter cake solids % % ppm % .489 psi/ft sand oil chlorides water mud gradient Detail: Drill through cement at 3560'. Run in hole to 4618'. Hard cement to top of retainer at 4629'. Drill on retainer from 4629'. Drill cement and junk to 4720. Trip for bit. Run in hole. Drill cement from 4720 to top of retainer. Drilling on retainer at 4740 at report time. Weather: -15°F. Scattered Clouds, Winds light and variable, visibility OK Cumulative Mud Cost $ N/A Cumulative Total Well-Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineerh,~- Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Date: Contractor: Report Period: 0600 Hrs. 1/13/91 to 0600 Depth: 5459 ('rD) KB, Total Drilling Days: 25.75 Total Rotating Hours: Elevation 322 KB, 'I'VD 5459 KB, Depth Avg. fi/hr Weight on Bit 10/15 1,000/lb Rotary Speed Bit No. 6" Security M4NJ open size make & type jet sizes 743 in 12-1/4 T , B , G , feet rotating hrs Bit No. Report No. 26 January 14, 1991 Grace Rig 211 Hrs. 1/14/91 100.5 -5137 SS. 110-120 RPM. 2693 in Notes: 3436 out size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Drilling Setup: 6" bit, junk basket. Bit sub 4 4-3/4" drill collars. BHA 117.32', approx, wt. 5500#. Formation(s): Cement and Retainers Last Casing: 7" 26#, N-80 @ 5447 fi size & grade psi @ 110 SPM Pump Output: 347/8.25 361 FPM Annular Velocity (collars): psi, or N/A % E/sec. Bit Hydraulic Horsepower: N/A HP lb Pump Hydraulic Horsepower: N/A HP Pump Pressure: 1000 Annular Velocity (drill string): Pressure Loss at Bit: N/A Jet Velocity: N/A open jets Bit Hydraulic Impact Force N/A Surveys: depth (GPM)(BPM) 509 FPM Drilling Fluid: Milpark mud company 9.4 (PPG), 38 sec. weight funnel vis. plastic vis. oo further mud.report until wnno~e operauons resume type cps. cc water loss #100 E'2 , in. % pH filter cake solids % ppm % .489 psi/ft oil chlorides water mud gradient yield point % sand Detail: Rig up new 6" bit. Run in the hole· Resume drilling cement and retainers from 2693' to 2779'. Pump high viscosity sweep. Drill cement to 3014'. Run in hole to tope of retainer at 3436'. Mill on retainer. Trip out of hole for new bit and junk basket. Run in hole. Drill out of retainer at 3436'. Drilling on junk and cement at 3466' (0600 hrs). Weather: 0°F. Skys clear· Wind light and variable. Visibility 50 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineering Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT EN 'R Report No. 25 Well Number: ClRI West Fork 1-21 Date: January 13, 1991 Field: West Fork Contractor: Grace Rig 211 Report Period: 0600 Hrs. 1/12/91 to 0600 Hrs. 1/13/91 Depth: 5459 (TD) KB, Total Drilling Days: 24.75 Total Rotating Hours: 100.5 Elevation 322 KB, TVD 5459 KB, Depth -5137 SS. Avg. fi/hr Weight on Bit 5/15 1,000/lb Rotary Speed 110 RPM. Bit No. 6" Security M4NJ open 2674 2693 size make & type jet sizes in out 19 in 9 T , B , G , Notes: feet rotating hrs Bit No. size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Drilling Setup: 6" bit, junk basket. Bll sub 4 4-3/4" drill collars 117.32' BHA at approximately 5500# Formation(s): Cement and Retainers Last Casing: 7" 26#, N-80 @ 5447 ft size & grade psi @ 110 SPM Pump Output: 347/8.25 361 FPM Annular Velocity (collars): psi, or N/A % ft/sec. Bit Hydraulic Horsepower: N/A HP lb Pump Hydraulic Horsepower: N/A HP Pump Pressure: 1000 Annular Velocity (drill string): Pressure Loss at Bit: N/A Jet Velocity: N/A open jets Bit Hydraulic Impact Force N/A Surveys: depth (GPM)(BPM) 5O4 FPM Drilling Fluid: Milpark oNoO further mud.report until wnnole opera[~ons resume mud company type 9.4 (PPG), 39 sec. cps. cc weight funnel vis. plastic vis. water loss #100 ft2 , in. % pH ' filter cake solids % ppm % .489 psi/ft oil chlorides water mud gradient yield point % sand Detail: Rig up Schlumberger. Run in hole and perforate from 2888 to 2890 (4 shots per foot). Retrieve gun and rig down. Pick up Halliburton EZ ddll. Run in hole and set retainer at 2686. Squeeze 100 ct. ft. (85 sacks) of premium Class .G blended with 0.2% CFR-3, 0.4% Halad 344, and 0.1% HR-7 utilizing back pressure. Sting in method to minimize mud loss to formation. Final displacement shot in pressure 450 psi. Unsting and reverse out clearing drill hole. Trip out of hole. Wait on cement. Continue minor rig repairs while waiting on cement. Assemble bottom hole with 6" bit (open jets) junk sub, bit sub and collars. Run in hole. Tag green cement at 2674'. Drill green cement to TOH retainer at 2688'. Begin milling on retainer. Milling at 2688' to 2693'. Trip out of hole for new bit. Weather: Clear. Light and variable winds. Visibility unlimited. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri~,~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr Bit No. Bit No. ClRI West Fork 1-21 West Fork 5459 (TD) 322 0600 Hrs. 1/11/91 KB, Total Drilling Days: 23.75 KB, 'I'VD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs , B size make & type in T feet rotating hrs , B to Date: Contractor: 060O Total Rotating Hours: KB, Depth Rotary Speed Report No. 24 January 12, 1991 Grace Rig 211 Hrs, 1/12/91 100.5 -5137 jet sizes in , G , Notes: jet sizes in , G , Notes: SS. RPM. out Drilling Setup: N/A Formation(s): Last Casing: 7" 26#, N-80 @ 5447 ft out size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % E/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark aNoO further mud.report until wnno~e opera[~ons resume mud company type (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 E2 , in. % yield point pH filter cake solids % % ppm % psi/fi sand oil chlorides water mud gradient Detail: Reverse circulate pipe clean. Trip out of hole. Rig up Schlumberger. Run in hole and perforate from 5670 to 5672 (4 shots per foot). Retrieve gun and rig down. Pick up Halliburton EZ Drill. Run in hole and set retainer at 5630. Sting in holding pressure on 3-1/2 diameter 7' casing. Pump and displace 41.3 cu. ft. (35 sacks) of premium Class G blended with 0.2% CFR-3, 0.4% Halad 344, and 0.1% HR-7. Final displacement pressure 1350 psi. Pull out of retainer and reverse circulate pipe clean. Trip out of hole. Rig Schlumberger. Run in hole and perforate from 3498 to 3500 (4 shots per foot). Retrieve gun and rig down. Pick up Halliburton EZ drill. Run in hole and set retainer at 3436. Rig up pressure returns on 9-5/8 annulus. Attempt to establish circulati~r~ through perforations to surface. No success. Conduct stab in squeeze 88.5 cu. ft. (75 sacks) of premium CI~..~-blended with 0.2% CFR-3, 0.4% Halad 344, and 0.1% HR-7. Final displacement pressure 1200 psi. Pull out of~ret;i~'e,i~d~reverse circulate hole. Clean pull out of hole. .: -f;::i:~? ~, _~' ,~'-/~ Weather: 18°F, overcast. Light and variable winds. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri,~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. E/hr Bit No. Bit No. 5459 (TD) 322 ClRI West Fork 1-21 West Fork Drilling Setup: N/A 0600 Hrs. 1/10/91 KB, Total Drilling Days: 22.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs to size make & type in T feet rotating hrs Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed jet sizes in , B , G , Notes: jet sizes in , B , G , Notes: Report No. 23 January 11, 1991 Grace Rig 211 Hrs. 1/11/91 100.5 -5137 SS. RPM. out out Formation(s): Last Casing: Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, E/sec. SPM FPM or 7" 26#, N-80 @ size & grade Pump Output: Annular Velocity (collars): % Bit Hydraulic Horsepower: lb Pump Hydraulic Horsepower: 5447 depth (GPM)(BPM) FPM HP HP Drilling Fluid' Milpark jNoO ft/rtber mud.report until wnno~e opera[~ons resume mud company type (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 ft2 , in. % Detail: yield point pH filter cake solids % % ppm % psi/ft sand oil chlorides water mud gradient Set retainer at 5130. Pull out of hole. Rig up Schlumberger to run 1 perf gun (2' @ 4 shots per ft). Squeezed section from 5108 to 5110. Run in hole with Halliburton's E.S.V. retainer set 5078. Rig up line from annulus 9-5/8" x 7" to flowline. Open annulus valve. Sting drill pipe into E.S.V. Attempted to pump annular side and establish circulation with 20 bbls water. No return established. Closed annular valve and conducted standard squeeze procedure pumping (300 sacks) 350 cu. ft of premium Class G blended with 0.2% CFR 3, 0.4% Halad 344, and 0.1% HR-7. Slurry Wt. - 15.6 ppg. Injection rate 5 bbl/min. Final displacement pressure - 1050 psi. Unsting from E.S.V. Reverse circulation to clear drill pipe of cement. Trip out of hole. Rig up Schlumberger to run one perf gun (2' @ 4 shots per ft). Ordered 300 more sacks cement for squeeze jobs over next couple days. Shoot interval 4773-4775. Rig down Schlumberger. Down hole with Halliburton's E.S.V. retainer to 4740. Break circulation with tool at 4740. Squeezed (25 sacks) 88.5 cu. ft of premium Class G blended with 0.2% C~RB, 0.4% Halad 344, and 0.1% HR-7. Slurry wt. 15.6 ppg. Final displacement pressure = 1080 psi. Weather: 15°F, overcast, light winds NE, 5 mph. Visibility 10 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consultingand Engineeri~t Anchorage,Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr Bit No. Bit No. Drilling Setup: ClRI West Fork 1-21 West Fork 5459 (TD) 322 Date: Contractor: 0600 Hrs. 1/9/91 to 0600 KB, Total Drilling Days: 21.75 Total Rotating Hours: KB, TVD 5459 KB, Depth Weight on Bit 1,000/lb Rotary Speed size make & type jet sizes in in T , B , G , Notes: feet rotating hrs size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Report No. 22 January 10, 1991 Grace Rig 211 Hrs. 1/10/91 100.5 -5137 SS. RPM. out out N/A Last Casing: 7" 26#, N-80 @ 5447 ft size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % ft/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Formation(s)' Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid' Milpark aHoO f[jrtber mud.report until wnno~e opera[ions resume mud company type (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 ft2 , in. Detail: yield point pH filter cake solids % % ppm % psi/ft sand oil chlorides water mud gradient Slip 70: Set wear ring. Run lock in screens in laydown setting tool. Strap pipe in rack. Test accumulator. Change lower Kelly valve. Make 6' Bll and casing scraper. Run in hole (SLM). Tag cement at 5300. Drill out soft cement to top of float collar at 5300. Circulate hole clean. Pressure test casing for 10 minutes at 1500 psi. Test ok. Trip out of hole. Rig up Schlumberger. Run two C.E.T. passes throughout interval 5000' to 5350'. Interpret C.E.T. Conference with R.C. Gardner on squeeze program. Contact Dan Saunders with Halliburton and order crew out. Rig up Halliburton's setting tool and retainer. Run in hole slowly with retainer. Call out Schlumberger to prepare to perforate casing for squeeze. · Weather: I°F, overcast, freezing rain. Visibility 2 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: Virgil Thrapp Dally Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineerir,u Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. ft/hr Bit No. Bit No. CIRI West Fork 1-21 West Fork 5459 (TD) 322 0600 Hrs. 1/8/91 KB, Total Drilling Days: 19.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs , B size make & type in T feet rotating hrs , B to Date: Contractor: Total Rotating Hours: KB, Depth Rotary Speed Report No. 21 January 9, 1991 Grace Rig 211 Hrs. 1/9/91 100.5 -5137 jet sizes in , G , Notes: jet sizes in , G , Notes: SS. RPM. out Drilling Setup: Formation(s): Last Casing: 7" 26#, N-80 @ 5447 ft out size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % ft/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark oNoO further mud report until wnhole operatlohs resume mud company type (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 ft2 , in. % Detail: yield point pH filter cake solids ~ % % ppm % psi/ft sand oil chlorides water mud gradient Layed down 11 6-1/4' drill collars, 6 joints MW drill pipe, and 1 set 6-1/4' jars. Nipple up BOPE system and tested. Test went ok with minor leak on the Koomey line. Picked up 4 4-3/4" drill collars. Ought Too Trucking hauled MWD and other drilling equipment that is no longer needed to Anchorage. Surplus mud supplies were also removed by Ought Too Trucking. Preparing to make 7" casing scraper trip at time of report. Weather: 0°F, patchy fog, light mist/snow. Wind calm. Visibility - 5 miles. Cumulative Mud Cost $ Drilling Foreman: N/A Cumulative Total Well Cost $ N/A R. C. Gardner Daily Total Well Cost $ N/A (l'umkey) Rig Phone: 262-2048 ENSR Consulting and Engineerin~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. ft/hr Bit No. Bit No. Drilling Setup: CIRI West Fork 1-21 West Fork 5459 (TD) 322 0600 Hrs. 1/7/91 KB, Total Drilling Days: 19.75 KB, 'I'VD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs Report No. 20 January 8, 1991 size make & type in T feet rotating hrs Date: Contractor: to 0600 Hrs. 1/8/91 Total Rotating Hours: 100.5 KB, Depth -5137 SS. Rotary Speed RPM. jet sizes in , B , G , Notes: jet sizes in , B , G , Notes: Grace Rig 211 out out Formation(s): Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. Last Casing: 7" 26#, N-80 @ 5447 ft size & grade depth SPM Pump Output: (GPM)(BPM) FPM Annular Velocity (collars): FPM or % Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: Milpark aNoO further mud report until wnl~ole operatlohs resume mud company type (PPG), sec. cps. cc weight funnel vis. plastic vis. water loss #100 ft2 , in. % Detail: yield point pH filter cake solids ~ % % ppm % psi/ft sand oil chlorides water mud gradient Continued to reciprocate 7" csg while circulating in an attempt to improve returns. Returns never got better than 50 percent. Rigged up Halliburton and cemented casing with 350 cu. ft of premium Class G Mended with 0.2% CFR-3, 0.4% Halod 344, and 0.1% HR-7. Slurry wt = 15.3 ppg. Mixing and pumping rate = 5.5 bbls/min. Final displacement pressure = 1050 psi. Bumped plug with 1200 psi. Floats held ok. C.P. at 0950 hrs. Considering partial loss of returns while circulating, ran only enough cmt to cover primary zone of interest + 200 ft. Did not want to risk pumping cmt into pay zone, if that is the zone taking mud. Felt this was the best approach to protect pay zone under circumstances. Squeeze program will be developed from bond log. Got poor returns throughout cmt job (20-50%), but returns were continuous. Rigged down Halliburton and nippled down to lift stack. Rigged down trip tank and choke and kill lines. Picked up stack and set 7" csg slips under/1~i)~# tension. Set stack down and continued to nipple down single gate. Made rough cut on 7" and set out singi~J ~ .~. ,~Made_~.,/final cut on 7" and Installed tubing bend. Tested tubing head to 3000 psi, ok. ~'~'~'~'~ ~/' '//½' 0-~ / '/~'I~'~"D/ Weather: -18°F, clear. Wind calm. Visibility unlimited. Cumulative Mud Cost $ Drilling Foreman: N/A Cumulative Total Well Cost $ N/A R. C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineerin~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr Bit No. Bit No. ClRI West Fork 1-21 West Fork 5459 (TD) 322 0600 Hrs. 1/6/91 KB, Total Drilling Days: 18.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs to size make & type in T feet rotating hrs Date: Contractor: 06O0 Total Rotating Hours: KB, Depth Rotary Speed jet sizes in , B , G , Notes: jet sizes in , B , G , Notes: Report No. 19 January 7, 1991 Grace Rig 211 Hrs. 1/7/91 100.5 -5137 Drilling Setup: N/A Formation(s): Last Casing: 7" 26#, N-80 @ 5447 ft SS. RPM. out out size & grade SPM Pump Output: FPM Annular Velocity (collars): or % Bit Hydraulic Horsepower: HP Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: 5418 ft - 0° psi @ psi, fi/sec. lb Pump Hydraulic Horsepower: depth (GPM)(BPM) FPM HP Drilling Fluid: Milpark Polymer/3% KCl mud company type 9.4 (PPG), 44 sec. 17 cps. 8.4 weight funnel vis. plastic vis. water loss 9 #100 ft2 8.5 , 2/32 in. 4 yield point pH filter cake solids TR % % 1800 ppm 96 % 0.489 sand oil chlorides water mud gradient Detail: cc psi/ff Completed TIH and reamed 22 ft of fill on bottom (probably caused worn bowspring on CNL tool, plus hole deterioration). Circulated hole clean, pumped sweep around and POH (no tight spots). Pulled wear bushing and rigged up Joe's Oilfield Services to run 7" casing. Ran 146 of 7", 27#, N-80, LT&C casing equipped with F.C. and 18 centralizers. Shoe at 5446 ft. Casing ran in hole smoothly, but noticed a reduction of returns at approximately 3500 ft. Casing running rate = 30-40 sec/joint. Circulated casing prior to cementing but only have 20 to 50 percent returns. Working casing trying to improve returns at report time. Casing acts like to wants to pack off. Weather: -20°F, clear with patchy ground fog. Wind calm. Visibility = 5 miles (fog). Cumulative Mud Cost $ Drilling Foreman: N/A Cumulative Total Well Cost $ N/A R. C. Gardner ' Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Enginee,,,lg Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr Bit No. Bit No. 5459 (TD) 322 ClRI West Fork 1-21 West Fork Drilling Setup: N/A 0600 Hrs. 1/5/91 KB, Total Drilling Days: 17.75 KB, TVD 5459 Weight on Bit 1,000/lb size make & type in T feet rotating hrs , B size make & type in T feet rotating hrs to Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed Report No. 18 January 6, 1991 Grace Rig 211 Hrs. 1/6/91 100.5 -513 7' SS. RPM. jet sizes in , G , Notes: out jet sizes in , G , Notes: out Formation(s): Last Casing: Pump Pressure: psi @ Annular Velocity (drill string): Pressure Loss at Bit: psi, Jet Velocity: fi/sec. Bit Hydraulic Impact Force lb Surveys: None - Will drop final survey on last T©H. SPM FPM or size & grade Pump Output: Annular Velocity (collars): % Bit Hydraulic Horsepower: Pump Hydraulic Horsepower: ft depth (GPM)(BPM) FPM HP HP Drilling Fluid' Milpark 9.7 (PPG), weight 16 #100 ft2 yield point % o % sand oil Detail: New Drill Polymer/KCL mud company type 48 sec. 20 cps. funnel vis. plastic vis. water loss 9.0 , 2/32 in. 14 pH filter cake solids 16,000 ppm 86 % 0.504 chlorides water mud gradient cc psi/ft Completed rigging up Schlumberger. RIH with DIL/GR/SP and bit bridge @ 4927 ft (coal on mud Icg). Spudded on bridge to no avail. POH and rigged down Schlumberger. Ran in hole with BHA. Went smoothly to bottom and did not see bridge on TIH. Circulated sweep around and POH. Re-rigged up Schlumberger. Logs went to bottom ok this time. Made two logging runs: DIL/GR/SP and LDT/GR/CNT/MRT. No problems in logging program. Rigged down Schlumber and are making clean out run with BHA at report time. Prep to run 7" casing. Weather: -5°F, clear, patchy ground fog, winds calm. Visibility unlimited. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineer,,,g Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Report Period: 0600 Depth: 5459 (TD) KB, Elevation 322 KB, Avg. ft/hr Weight on Bit Bit No. 4 8-1/2 size 1057 in feet Bit No. Drilling Setup: N/A Hrs. Total Drilling Days: TVD size in feet 1/4/91 16.75 5459 1,000/lb SEC.S33F make & type 22 T rotating hrs 5 , B make & type T rotating hrs Report No. 17 January 5, 1991 Date: Contractor: to 0600 Hrs. 1/5/91 Total Rotating Hours: 100.5 KB, Depth -5137' SS. Rotary Speed RPM. 12-12-12 4402 5459 jet sizes in out 2 , G 3/16 , Notes: Grace Rig 211 jet sizes in , G , Notes: out Formation(s): Last Casing: Pump Pressure: psi @ Annular Velocity (drill string): Pressure Loss at Bit: psi, Jet Velocity: ft/sec. Bit Hydraulic Impact Force lb Surveys: None - Will drop final survey on last TOH. SPM FPM or @ ft size & grade depth Pump Output: (GPM)(BPM) Annular Velocity (collars): FPM % Bit Hydraulic Horsepower: HP Pump Hydraulic Horsepower: HP Drilling Fluid: Milpark mud company 9.6 (PPG), 48 weight funnel vis. 25 #100 ft2 9.5 yield point pH % 6,ooo sand New Drill Polymer/KCL type sec. 19 cps. 10.4 cc plastic vis. water loss , 2/32 in. 13 % Detail: filter cake solids 0 % ppm 87 % 0.499 psi/ft oil chlorides water mud gradient Repaired PZ-9 pump. Continued TOH to shoe. Last 15 stands pulled free. RIH to 4070. Picked up singles and washed and reamed back to TD @ 5459 ft through several tight spots and bridges. Bridges are opposite coal seams. Logged again with MWD tool from 4957 ft to 5459 ft while reaming. Slowed reaming rate on orders from CIRI and loggers to facilitate MWD Icg. Additional time expended - 1 hr. At TD pumped high as sweep and continued circulating until shakers cleaned up. POH with only two tight spots this time. Dumped data from MWD tool. Good data recovery. Laid down MWD tool. Rigging up Schlumberger at report time. Weather: 0°F, clear with patchy ground fog, wind light and variable. Visibility -20 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Enginee~,~g Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: ClRI West Fork 1-21 Field: West Fork Report Period: 0600 Hrs. 1/3/91 Depth: 5459 KB, Total Drilling Days: 15.75 Elevation 322 KB, TVD 5459 Avg. ft/hr - 45 Weight on Bit 20/25 1,000/lb Bit No. 4 8-1/2 SEC.S33F size make & type 1057 in 22 T , feet rotating hrs Bit No. to Date: Contractor: 0600 Report No. 16 January 4, 1991 Grace Rig 211 Total Rotating Hours: KB, Depth -5137' Rotary Speed 9-100 12-12-12 4402 jet sizes in , G , Notes: Hrs. 1/4/91 100.5 size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Drilling Setup: 8-1/2" BIT-BS-XO-MWD-XO-2 ea 6-1/4" DC-8-1/2" STAB-9 ea 6-1/4" DC-XO-JARS-6 JTS HWDP BHA Length = 585.67 fi BHA WT. = - 45,900# Formation(s): Sand, Coal, Mudstone Last Casing: 9-5/8" 40#, N-80 @ 2143 ft size & grade psi @ 110 SPM Pump Output: 347/8.25 141 FPM Annular Velocity (collars): 972 psi, or. 35 % fi/sec. Bit Hydraulic Horsepower: 197 HP 578 lb Pump Hydraulic Horsepower: 567 HP SS. RPM. 5459 out Pump Pressure: 2800 Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: 336 Bit Hydraulic Impact Force Surveys: 1/2° @ 5028 ft depth (GPM)(BPM) 256 FPM Drilling Fluid: Milpark mud company 9.5 (PPG), 55 weight funnel vis. 24 #100 ft2 10.5 yield point pH olt/~ % 0 % 16,000 sand oil chlorides Detail: New Drill Polymer/KCL type sec. 12 cps. 13 cc plastic vis. water loss 2/32 in. 12 filter cake solids ppm 88 % 0.494 psi/ft water mud gradient Drilled to TD @ 5459 ft as per instructions from ClRI geologist, Eric Opstead. Ran survey on wireline @ 5020 ft. Circulated bottoms up for loggers and circulated an additional 15 minutes to clean up hole. Started short trip to shoe. Pulled one stand and got stuck in coal on second stand. Worked pipe and pumped singles out of hole to - 4400 ft. May overpull - 100,000 lbs. Had to jar through several areas. Large pieces of coal and dense siltstone recovered from shaker. Letting mud weight come back to 9.5 from 9.7 may have contributed to problem. Bit is in previously wiped hole section of report time and pipe becoming easier to pump out. Still acts like we are pulling a large mass of coal and other formation ahead of stabilizer in spite of high vis sweeps we have periodically run. PZ-9 pump down (swab) and are circulating and pumping out with duplex pump. SPR (PZ-9) 700 psi @ 54 spm. Weather: + 7°F, high thin overcast. Winds light and variable. Visibility 20 miles. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineerir,9 Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr 35/55 Bit No. 2 Bit No. Drilling Setup: CIRI West Fork 1-21 West Fork 4910 322 Date: Contractor: 0600 Hrs. 1/2/91 to 0600 KB, Total Drilling Days: 14.75 Total Rotating Hours: KB, TVD 4910 KB, Depth Weight on Bit 20/25 1,000/lb Rotary Speed 8-1/2 S EC.S33F 12-12-12 size make & type jet sizes in T , B , G , feet rotating hfs Report No. 15 January 3,1991 Grace Rig 211 Hrs. 1/3/91 88.0 -4588' SS. 100/120 RPM. 4402 in out Notes: size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs 8-1/2" BIT-BS-XO-MWD-XO-2 ea 6-1/4" DC-8-1/2" STAB-9 ea 6-1/4" DC-XO-JARS-6 JTS HWDP BHA Length = 585.67 ft BHA WT = - 45,900# Formation(s): Sand, Mudstone, Coal Last Casing: 9-5/8" 40#, N-80 @ 2143 ft size & grade depth psi @ 110 SPM Pump Output: 347/8.25 (GPM)(BPM) 141 FPM Annular Velocity (collars): 256 FPM psi, or 35 % fi/sec. Bit Hydraulic Horsepower: 197 HP lb Pump Hydraulic Horsepower: 567 HP 972 Pump Pressure: 2800 Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: 336 Bit Hydraulic Impact Force 578 Surveys: 24 @ 4446 ft (may be a mis-run) Drilling Fluid: Milpark 9.6 (PPG), weight funnel vis. 47 #100 ft2 9.0 yield point pH % o % ,ooo sand oil chlorides Detail: New Drill Polymer/KCL mud company type 80 sec. 13 cps. 16.0 plastic vis. water loss 2/32 in. 12 CC filter cake solids ppm 88 % 0.499 psi/ft water mud gradient Note on Mud: Higher viscosity and higher fluid loss due to addition of KCI. Mud being conditioned at report time. RIH to 2525 ft. Picked up singles laid down when pumping out of hole and washed and reamed to 4402 ft. Reamed through few tight spots and bridges. Resumed drilling. Circulated bottoms up for loggers at ,, 4600 ft. Drilled to 4910 ft at report time. Took survey at 4446 ft. ~- -':' ¢- Weather: + 15°F, clear. Wind 15 knots from east, visibility 20 mi + N/A Cumulative Mud Cost $ Drilling Foreman: Cumulative Total Well Cost $ N/A R. C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineering Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. ft/hr 4462 322 ClRI West Fork 1-21 Date: West Fork Contractor: 0600 Hrs. 1/1 to 0600 KB, Total Drilling Days: 13.75 KB, 'rVD 4402 Weight on Bit 20/30 1,000/lb Report No. 14 January 2, 1991 Grace Rig 211 Total Rotating Hours: KB, Depth 4080 Rotary Speed 100 Hrs. 1/2 79.0 SS. RPM. Bit No. 3 8-1/2 SEC.S33SF 12-12-12 2933 4402 size make & type jet sizes in 1469 in 21.5 T 2 3 , G 1/8 , Notes: feet rotating hrs size make & type jet sizes in in T , B , G , Notes: Bit No. feet rotating hrs out out Drilling Setup: 8-1/2" BIT-BS-2 ea 6-1/4" DC-8-1/2" STAB-9 ea 6-1/4" DC-XO-JARS-6 JTS HWDP BHA Length: 562.87' BHA WT - 43,800# Formation(s): Sand, Clay, Silt Last Casing: 9-5/8" 40#, N-80 @ 2143 ft size & grade psi @ 110 SPM Pump Output: 347/8.25 141 FPM Annular Velocity (collars): 962 psi, or 42 % fi/sec. Bit Hydraulic Horsepower: 195 HP 572 lb Pump Hydraulic Horsepower: 466 HP Pump Pressure: 2300 Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: 336 Bit Hydraulic Impact Force Surveys: None this report period. depth (GPM)(BPM) 256 FPM Drilling Fluid: Milpark mud company 9.7 (PPG), 50 weight funnel vis. 18 #100 ft2 8.0 yield point pH % o % sand oil chlorides Detail: New Drill Polymer/KC type sec. 16 cps. 6.2 cc plastic vis. water loss 2/32 in. 10 filter cake solids ppm 90 % 0.504 psi/ft water mud gradient Drilled to 4402 ft. Circulated bottoms up for loggers and started TIH to pick up MWD tool. Pulled 15 stands with intermittent tight spots. Got stuck on 16th stand. Picked up kelly and pumped out singles 3364 ft to 2385 ft. Got stuck several times but able to work pipe free. Got packed off once but able to restore circulation after working pipe 20 minutes. Raised MW to 9.7 + and added KCI to system to 3% concentration while pumping out of the hole. Pipe started pulling free 3 stands below 9-5/8" casing shoe. Problems appear to be caused by swelling clays and siltstones. Finally out of the hole at 0400 hrs 1/2/91. Changed bits and picked up MWD tool. Checking functions of MWD tool @ 0600 hrs 1/2/91. Weather: Cumulative Mud Cost $ + 10°F, overcast. Winds 10 knots from north. V~s~bd~ty ¥5 N/A Cumulative Total Well Cost $ N/A Daily Total Well Cost $ N/A (Turnkey) Drilling Foreman: R.C. Gardner Rig Phone: 262-2048 ENSR Consulting and Enginee,.~.g Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT ClRI West Fork 1-21 West Fork 0600 Date: Contractor: 0600 Well Number: Field: Report Period: Hrs. 12/31 Depth: 4027 KB, Total Drilling Days: 12.75 Total Rotating Hours: Elevation 322 KB, TVD 4027 KB, Depth Avg. ft/hr - 96 Weight on Bit 20/25 1,000/lb Rotary Speed Bit No. 2 8-1/2 S33SF(SEC) 12-12-12 2105 size make & type jet sizes in 828 in 17.5 T 2 , B 2 , G 1/16, Notes: feet rotating hrs Bit No. 3 8-1/2 SEC. S33FS 12-12-12 2933 size make & type jet sizes in in T , G Notes: to feet rotating hrs Report No. 13 January 1, 1991 Grace Rig 211 Hrs. 1/1 73.5 3705 SS. 100-120 RPM. 2933 out p.r~ aCnmc~ out Drilling Setup: 8-1/2" BIT-BS-2 ea 6-1/4" DC-8-1/2" STAB-9 ea 6-1/4" DC-XO-JARS-6 JTS HWDP BHA Length = 562.87' BHA WT = ,, 43,800# Formation(s): Sand, Silt, Clay, Coal LaSt Casing: 9-5/8" 40#, N-80 @ 2143 ft size & grade psi @ 110 SPM Pump Output: 347/8.25 141 FPM Annular Velocity (collars): 962 psi, or 42 % fi/sec. Bit Hydraulic Horsepower: 195 HP lb Pump Hydraulic Horsepower: 466 HP Pump Pressure: 2300 Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: 336 Bit Hydraulic Impact Force 572 Surveys: 1/2° @ 3432 ft; 1/4° @ 3995 ft depth (GPM)(BPM) 256 FPM Drilling Fluid: Milpark New Drill Polymer mud company type 9.5 (PPG), 45 sec. 22 cps. 6.0 weight funnel vis. plastic vis. water loss 9 #100 ft2 ~ 9.0 , 2/32 in. 10 pH filter cake solids yield point sand cc 0 % 2200 ppm 90 % 0.494 psi/ft oil chlorides water mud gradient Detail: Completed TOH and picked up new bit. Bit and stabilizer not as badly fouled with clay as expected. RIH and picked up singles laid down when pumping out of hole. Washed and reamed 15 its to bottom as precautionary measure. Resumed drilling and drilled to 4027 ft at report time. Took surveys @ 3432 ft and 3995 ft. Replaced slickline on survey unit--no lost time. Started dumping a couple of handfuls of SAPP down drillpipe on each connection. Seems to be helping with clay problem, however lithologic change has helped as well. Drilling @ 0600 hrs, 1/1/91. Weather: + 5°F, clear. Wind from NE @ - 10 knots, visibility 20 mi + Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily-Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineerinu Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. ft/hr - 50 Bit No. 2 Bit No. Drilling Setup: CIRI West Fork 1-21 West Fork 2933 322 Date: Contractor: 0600 Hrs. 12/30 to 0600 KB, Total Drilling Days: 11.75 Total Rotating Hours: KB, TVD 2933 KB, Depth Weight on Bit 15/20 1,000/lb Rotary Speed 8-1/2 SEC.S33SF 12-12-12 size make & type jet sizes in T , B , G , feet rotating hrs Report No. 12 December 31, 1990 Grace Rig 211 Hrs. 12/31 57.5 -2611' SS. 90/100 RPM. 2105 in out Notes: size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs 8-1/2" BIT-BS-2 ea 6-1/4" DC-8-1/2" STAB - 9 ea 6-1/4" DC-XO-JARS-6 JTS 5" HWDP-XO to 3-1/2" DP. BHA Length = 562.87' BHA WT. = - 43,800# Formation(s): Clay Last Casing: 9-5/8" 40# N-80 @ 2143 ft Pump Pressure: 2000 (w/pluggbd jet) Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: 2469 ft; 0° 2933 ft; 0° size & grade psi @ SPM Pump Output: 110 347/8.25 179 FPM Annular Velocity (collars): 256 FPM psi, or % ft/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP depth (GPM)(BPM) Drilling Fluid: Milpark mud company 9.4 (PPG), 50 weight funnel vis. 15 #100 ft2 9.0 yield point pH TR % 0 % 2200 sand oil chlorides Detail: New Drill Polymer type sec. 25 cps. 5.8 cc plastic vis. water loss 2/32 in. 10 filter cake solids ppm 90 % 0.489 psi/ft water mud gradient Drilled 8-1/2" hole to 2933 ft. Took suweys @ 2469 ft and 2933 ft. Started 10 stand short trip but had so much trouble pulling through clays that decided to make round trip for new bit and to inspect BHA. Had to pump 14 singles out of hole on trip. Decided not to run MWD on this bit run as tool has greater OD than DCs and until we are out of clay, the chance of sticking the tool is too great. Tripping BHA @ 0600 hrs 12/31/90. Slow pump rate: Pump No. 1:500 psi @ 55 spm. Weather: .15°F, clear. Wind ,5 knots from north, visibility unlimited. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri~,= Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT EN 'R Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: 0600 Hrs. 12/29 Depth: 2220 KB, Total Drilling Days: 10.75 Elevation 322 KB, TVD 2220 Avg. ft/hr 63 Weight on Bit 10/15 1,000/lb Bit No. 2 8-1/2 SEC. S33SF size make & type in T , B feet rotating hrs Bit No. to Date: Contractor: 0600 Report No. 11 December 30, 1990 Grace Rig 211 Total Rotating Hours: KB, Depth -1898' Rotary Speed 80-90 12-12-12 2105 jet sizes in , G , Notes: Hrs. 12/30 42.5 size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Drilling Setup: 8-1/2" BIT-B.S.-2-6-1/4' D.C. - 8-1/2" Stab - 9-6-1/4" D.C. - XO-JARS-6 JTS HWDP- XO to 3-1/2" DP. BHA Length = 562.87' BHA WT = - 43,800# (incl. HWDP) Formation(s): Clay, Coal Last Casing: 9-5/8" 40# No80 @ 2143 ft size & grade psi @ 100 SPM Pump Output: 315/7.5 163 FPM Annular Velocity (collars): 768 psi, or 51 % fi/sec. Bit Hydraulic Horsepower: 141 HP 457 lb Pump Hydraulic Horsepower: 276 HP SS. RPM. out Pump Pressure: 1500 Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: 305 Bit Hydraulic Impact Force Surveys: None depth (GPM)(BPM) 232 FPM Drilling Fluid: Milpark 9.1 + (PPG), weight 5 #10o yield point TR % 0 % sand oil Detail: New Drill Polymer mud company type 42 sec. 15 cps. 10.0 funnel vis. plastic vis. water loss 9.5 , 1/32 in. 8 cc pH filter cake solids 800 ppm 92 % 0.476 psi/ft chlorides Liquids mud gradient Tested BOPE as follows: Upper and lower pipe rams, blind rams, choke and kill line valves, HCR valve, choke manifold, kelly, upper and lower kelly valves, kelly hose, standpipe and floor valves to 5000 psi. Tested Hydril to 2500 psi. All tests finally ok and witnessed by Lou Grimaldi of AOGCC. Tests complete @ 1030 hrs 12/29/90. Pulled test plug and set wear bushing, picked up BHA, cut and slipped 100' of drilling line. Resumed TIH and tagged F.C. at 2105 ft. Closed hydril and tested 8-5/8" csg to 1700 psi for 15 minutes--ok. Rig put on downtime for 2 hrs to repair pump pressure gauges on floor-all needed repair. Drilled out F.C., shoe joint and F.S. Cleaned out to old TD @ 2157 ft. Drilled new hole to 2162 ft. Pulled up to shoe and ran formation competency test to 1116 EMW. Put rig on downtime another 2 hrs to repair leaking union on standpipe. Circulated at shoe and broke mud to New Drill Polymer system. Resumed drilling @ 0500 hrs 12/30. Drilling @ 0600 hrs 12/30/90. Weather: 10°F, clear. Wind from north @ estimated 5 knots, visibility 40 miles +. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineerir,~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. ft/hr N/A Bit No. Bit No. 2157 322 CIRI West Fork 1-21 West Fork Drilling Setup: None 0600 Hrs. 12/28 KB, Total Drilling Days: 9.75 KB, TVD 2157 Weight on Bit 1,000/lb size make & type in T feet rotating hrs to size make & type in T feet rotating hrs Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed jet sizes in , B , G , Notes: jet sizes in , B , G , Notes: Report No. 10 December 29, 1990 Grace Rig 211 Hrs. 12/29 41.5 -1835' SS. RPM. out out Formation(s): Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ psi, fi/sec. Last Casing: 9-5/8" 40# N-80 @ 2143 ft size & grade depth SPM Pump Output: (GPM)(BPM) FPM Annular Velocity (collars): FPM or % Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Drilling Fluid: 9.2 (PPG), weight 12 #100 ft2 yield point TR % sand Milpark Spud Mud -Treated (Not Circulating) mud company type 47 sec. 19 cps. 8.0 cc funnel vis. plastic vis. water loss 8.5 , 2/32 in. 9 % pH filter cake solids 0 % 700 ppm 91 % 0.478 psi/ft Detail' oil chlorides water mud gradient Continued down for repair and/or replacement of components of BOPE. Replaced HCR valve and valve in choke manifold. Repaired check valve in kill line. Repaired several leaks on flanked connections. These leaks due mainly to dirty ring grooves. Preparing to test BOPE again @ 0000 hrs 12/29/00. Entire report period on Grace Drilling downtime. '.!~..j,~ f ..~... '.. , Weather: 20°F, fog, V!sibility < 1/4 mile, wind - 5 knot,s from north, Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri~.o Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr N/A Bit No. Bit No. Drilling Setup: ClRI West Fork 1-21 West Fork 2157 322 Date: Contractor: 0600 Hrs. 12/27 to 0600 KB, Total Drilling Days: 8.75 Total Rotating Hours: KB, 'I'VD 2157 KB, Depth Weight on Bit 1,000/lb Rotary Speed size make & type jet sizes in in T , B , G , Notes: feet rotating hrs size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Report No. 9 December 28, 1990 Grace Rig 211 Hrs. 12/28 41.5 -1835' SS. RPM. out out None Last Casing: 9-5/8" 40# N-80 @ 2143 ft size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Formation(s): Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid: 9.2 (PPG), weight 12 yield point TR % sand Milpark Spud Mud -Treated (Not Circulating) mud company type 49 sec. 19 cps. 8.0 CC funnel vis. plastic vis. water loss #100 ft2 8.0 , 2/32 in. 9 % Detail: pH filter cake solids 0 % 700 ppm 91 % 0.478 psi/ft oil chlorides water mud gradient Stack down for BOPE repair. Repaired leaks in stack flanges and choke line connections. HCR valve leaks badly. Grace trying to repair old valve and locate replacement simultaneously. Entire report period on Grace downtime. Weather: 30°F, light snow. Visibility - 5 miles, wind light and variable. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineer,, Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT ENCR Well Number: Field: Report Period: Depth: Elevation Avg. ft/hr N/A Bit No. Bit No. CIRI West Fork 1-21 West Fork 2157 322 0600 Hrs. 12/26 KB, Total Drilling Days: 7.75 KB, TVD 2157 Weight on Bit 1,000/lb size make & type in T feet rotating hrs , B size make & type in T feet rotating hrs , B to Date: Contractor: 06O0 Total Rotating Hours: KB, Depth Rotary Speed Report No. 8 December 27, 1990 Grace Rig 211 Hrs. 12/27 41.5 -1835' jet sizes in , G , Notes: SS. jet sizes in , G , Notes: RPM. out Drilling Setup: None Formation(s): Last Casing: 9-5/8" 40# N-80 @ 2143 fi out size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark Spud Mud -Treated (Not Circulating) mud company type 9.3 (PPG), 44 sec. 11 cps. 8.0 weight funnel vis. plastic vis. water loss 10 #100 ft2 8.5 , 2/32 in. 9 yield point pH filter cake solids TR % 0 % 800 ppm 91 % 0.484 sand oil chlorides water mud gradient Detail: CC psi/ft Initial BOP test failed. Numerous leaks, and upper kelly valve frozen. Replaced upper kelly valve, but several leaks in choke manifold. Some valves are very hard to turn and may not seal when tested. Put rig on downtime effective 1200 hrs 12/26/00. Repairing BOPE leaks @ 0600 hrs 12/27. Rough estimate for completion of repairs is approximately 24-36 hrs. . ~ · . '/ Weather: 10°F, clear. Wind <5 knots from north, Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineen,_~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr N/A Bit No. Bit No. ClRI West Fork 1-21 West Fork 2157 322 0600 Hrs. 12/25 KB, Total Drilling Days: 6.75 KB, TVD 2157 Weight on Bit N/A 1,000/lb size make & type in T feet rotating hrs , B size make & type in T feet rotating hrs , B to Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed Report No. 7 December 26, 1990 Grace Rig 211 Hrs. 12/26 41.5 -1835' jet sizes in , G , Notes: SS. jet sizes in , G , Notes: RPM. out Drilling Setup: None Formation(s): Last Casing: 9-5/8" 40# N-80 @ 2143 fi out size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark Spud Mud (Pit Sample - Not Circulating) mud company type 9.3 (PPG), 43 sec. 11 cps. 8.0 weight funnel vis. plastic vis. water loss 10 #100 ft2 8.5 , 2/32 in. 9 yield point pH filter cake solids TR % 0 % 91 ppm 91 % 0.484 sand oil chlorides water mud gradient cc psi/ft Detail: Continued with nipple up of BOPE. Function tested blowout preventers. Rigged up trip tank. Rigged up hydraulic choke. Laying down 8" D.C. at 0600 hrs 12/26. W.O. State man for BOP test. Weather: Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineeri,... Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr N/A Bit No. Bit No. ClRI West Fork 1-21 West Fork 2157 322 0600 Hrs. 12/24 KB, Total Drilling Days: 5.75 KB, TVD 2157 Weight on Bit N/A 1,000/lb size make & type in T feet rotating hrs , B size make & type in T , , feet rotating hrs to Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed Report No. 6 December 25, 1990 Grace Rig 211 Hrs. 12/25 41.5 -1835' N/A SS. jet sizes in , G , Notes: jet sizes in , G , Notes: RPM. out Drilling Setup: None Formation(s): Last Casing: 9-5/8" 40# N-80 @ 2143 ft out size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark 9.4 (PPG), weight 13 #100 ft2 yield point TR % 0 % sand oil Detail: Spud Mud (Pit Sample - Not Circulating) mud company type 47 sec. 19 cps. 8 cc funnel vis. plastic vis. water loss 8.0 , 1/32 in. 10 % pH filter cake solids 800 ppm 90 % 0.478 psi/ft chlorides water mud gradient Cemented 9-5/8" csg. as follows: Flushed with 50 bbls H20 ahead. Cemented using two plug method. Lead Slurry: 660 SX Class G blended with 4% gel, 0.5% CFR-3, and 2% CaCl2. Tail Slurry: 200 SX Class G blended with 2% CaCl2. Avg lead slurry wt = 14.7 ppg. Avg tail slurry wt = 15.8 ppg. Pumping rate during cementing was 8-9 bbls/min. Displaced cement with 159.8 bbls mud at approximately 6.5 bbls/min. Lower rate due to mud delivery limitations from rig. Final displacement pressure = 700 psi. Bumped plug with 1200 psi. Floats held ok. CIP @ 0700 hrs 12/24. Good returns throughout job until 10 minutes before end of displacement period when circulation lost for 5 minutes. Returns resumed and got cmt contaminated pre-flush to surface, but column in annulus dropped during WOC time. Will make decision on top job after nipple up. WOC time = 7 hrs. Nippled down diverter lines and valves and took bolts out of diverter while WOC. After WOC, removed diverter and flowline. Made cut on conductor and removed 13-3/4" Bradenhead. Made cut on 9-5/8" csg and installed 9-5/8" Bradenhead. Set in BOP stack and started welds on choke and kill lines. Continuing with nipple up @ 0600 hrs.! 2/25. Location and access roads becoming dangerous due to thaw: ~c~ghll s~'~ad ~r~,6.), but probably will not help much. Weather: 35°F, rain, fog. Visibility - 1/2 mile· Wind light and variable (ma~e this is Puget Sound?) · __ Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineel...= Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Report No. 5 December 24, 1990 Well Number: CIRI West Fork 1-21 Field: West Fork Date: Contractor: Report Period: 0600 Hrs. 12/23 to 0600 Hrs. 12/24 Depth: 2157 KB, Total Drilling Days: 4.75 Total Rotating Hours: 41.5 Elevation 322 KB, TVD 2157 KB, Depth -1835' SS. Avg. fi/hr 35 Weight on Bit 10/25 1,000/lb Rotary Speed 70/80 RPM. Bit No. 1 12-1/4 SEC. SS33GJ4 14-14-14 140 2122 size make & type jet sizes in out 1982 in 39.5 T 3 , B 2 , G I , Notes: Good Shape feet rotating hrs Bit No. RR 12-1/4 SEC. SS33GJ4 14-14-14 2122 2157 size make & type jet sizes in out 2017 in 41.5 T 4 , B 3 , G I , Notes: feet rotating hrs Grace Rig 211 Drilling Setup: BIT-B.S.-8" D.C.-12-1/4" STAB-6-8" D.C.s-XO-JARS-11 JTS 5" HNDP. Total Length: 624.96' BHA WT - 57.500 lbs Formation(s): Clay, Sand, Boulder Last Casing: 13-3/8" @ 140 ft Pump Pressure: Not Circulating Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: None size & grade SPM Pump Output: FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP psi @ depth (GPM)(BPM) FPM Drilling Fluid: Milpark Spud Mud (Pit Sample - Not Circulating) mud company type 9.4 (PPG), 46 sec. 15 cps. 8 weight funnel vis. plastic vis. water loss 12 #100 ft2 8.5 , 2/32 in. 10 yield point pH filter cake solids 0.25 % 0 % 900 ppm 90 % 0.49 sand oil chlorides water mud gradient CC psi/ft Detail: Picked up laid down singles and ran back in hole with RR Bit No. 1. Went to bottom with no problems. Conditioned mud and drilled to 2157 ft. Circ. bottoms up and POH with no problems this time. Clay zones appear to require multiple passes of BHA to wipe swelled areas. Rigged up Schlumberger and ran DIL/SP/GR combination tool from 2154 ft to 140 ft. No problems with legs. Rigged down Schlumberger and rigged up Joe's Oilfield Services to run 9-5/8" csg. Ran 55 JTS of 9-5/8" 40# N-80 LTC casing with F.S., F.C., and 17 centralizers. Shoe at 2143.28 ft. Casing ran smoothly, with only the initial problem of overcoming centralizer friction in conductor pipe. Filled casing on every other connection. Rigged down Joe's and dgged up Halliburton to cement casing. Circulated and reciprocated casing 40 mins--return cleaned up well. Cementing @ 0600 hrs 12/24. Cementing details on next report. Weather: - 30°F, snow and rain mixed, wind - 15 knots from north, visibility -'f' mile, road very bad! Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineer,. Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: Report No. ClRI West Fork 1-21 Date: 12/23/90 West Fork Contractor: Grace Rig 211 0600 Hrs. 12/22 to 0600 Hrs. 12/23 2122 KB, Total Drilling Days: 3.75 Total Rotating Hours: 40.5 322 KB, TVD 2122 KB, Depth -1800 SS. Weight on Bit 10/25 1,000/lb Rotary Speed 75-80 RPM. 12-1/4 SEC. SS33GJ4 14-14-14 140 size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Field: Report Period: Depth: Elevation Avg. fi/hr 60 Bit No. 1 Bit No. size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Drilling Setup: BIT-B.S.-DC-DC-STAB-DC-DC-DC-DC-DC-DC (all 8")-XO-JARS-11 JTS HWDP Total Length: 624.96' BHA WT - 57.500 lbs Formation(s): Clay, Sand, Coal Last Casing: 13-3/8" @ 140 ft Pump Pressure: 2100 Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: 197 ft - <3/4° size & grade psi @ 110 SPM Pump Output: 347/8.26 61 FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP depth (GPM)(BPM) 100 FPM Drilling Fluid: Milpark mud company 9.7 (PPG), 57 weight funnel vis. 20 # 100 ft2 8.5 yield point pH 0.5 % 0 % 800 sand oil chlorides Detail: Spud Mud - Pit Sample - Not Circulating type sec. 18 cps. NC cc plastic vis. water loss 2/32 in. 12 % filter cake solids ppm 87.5 % 0.5 psi/ft water mud gradient Drilled 12-1/4" hole to 1971 ft. Ran survey (<3/4°). Continued drilling to 2122 ft when bit appeared to lock up. Circulated bottoms up to 30 min and TOH. Pulled two stands and had to pump out singles thereafter until bit @ 907 ft. Major problems were swelling clays and buildup of clay solids in mud. Completed TOH but lost 3 hrs due to Grace 8" D.C. lifting subs were not all 6-5/8" req. (two were H-90) and had to use a mixture of cross-overs to pull last two stands of collars. Rigged up Schlumberger to run logs, but could not get sonde below 1025 ft due to clay. Rigged down Schlumberger and started clean-out run. Temperature above freezing all day. Pad is thawing and covered with standing water (looks like breakupl). Weather: 0500 hrs 12(/23: 32°F, Visibility ~ 1/4 mile, fog. Wind <5 knots from north. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineerh.~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: CIRI West Fork 1-21 Date: Field: West Fork Contractor: Report Period: 0600 Hrs. 12/21 to 0600 Depth: 1700' KB, Total Drilling Days: 2.75 Total Rotating Hours: Elevation 322 KB, TVD 1700' KB, Depth -1378' Avg. fi/hr 60-200 Weight on Bit 10/20 1,000/lb Rotary Speed 75-80 Bit No. 1 12-1/4' SEC.SS33GJ4 14-14-14 140 size make & type jet sizes in in T , B , G , Notes: feet rotating hrs Bit No. Report No. 3 December 22, 1990 Grace Rig 211 Hrs. 12/22 33.5 size make & type jet sizes in out in T , B , G , Notes: feet rotating hrs Drilling Setup: BIT-B.S.-DC-DC-STAB.-DC-DC-DC-DC-DC-DC-XO-JARS-11 JTS HWDP Total Length: 624.96' BHA WT: - 57.500 lbs Formation (s): Clay, Sand, Coal Last Casing: 13-3/8" @ 140 ft SS. RPM. out Pump Pressure: 1200 Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: 97 ft - 0°, 1476 ft - 1/2° size & grade psi @ 110 SPM Pump Output: 347/8.26 61 FPM Annular Velocity (collars): psi, or % fi/sec. Bit Hydraulic Horsepower: HP lb Pump Hydraulic Horsepower: HP depth (GPM)(BPM) 100 FPM Drilling Fluid: Milpark , spud mud 9.3 (PPG), weight 30 #1oo yield point 1 % 0 % sand oil Detail: mud company type 87 sec. 23 cps. NC cc funnel vis. plastic vis. water loss 9.0 , 2/32 in. 9.0 % Ph filter cake solids 800 ppm 90 % 0.484 psi/ft chlorides water mud gradient Drilled 12-1/4" hole from 573' to 1700' KB. Ran surveys at 971' and 1476'. Made 5 stand short trip at each survey point. Got caught up on water. Added second water truck for night runs to Swanson River, which kept up ok. Will go back to one truck as soon as surface pipe cemented. Pump down 1 hour between 0300 and 0400 hrs on 12/22 due to rock in valve. Reducing mud level in pits to accommodate returns from cement job. 9-5/8", 40#, N-80, LTC casing on location. Held environmental training for both crews on 12/21. Extra OT - 2 hrs for each crew. Weather: 29°F, Visibility 10 miles, patchy fog, wind light and variable. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (Turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineer,.., Anchorage, Alaska (907) 276-4302 DALLY DRILLING REPORT EN 'R Well Number: Field: Report Period: Depth: Elevation Avg. fi/hr ~ 100 Bit No. 1 Bit No. ClRI West Fork 1-21 West Fork 0600 573' 322 KB, KB, Weight on Bit 12-1/4 size in feet Hrs. Total Drilling Days: 'rVD 12/20 1.75 573' 10 1,000/lb Sec SS33GJ4 make & type T , B rotating hrs Drilling Setup: -11JTS HWDP Total Length: 625.24. BHA WT: - 57.500 to Date: Contractor: 0600 Report No. 2 December 21, 1990 Grace Rig 211 Total Rotating Hours: KB, Depth -251 Rotary Speed 70-80 14-14-14 140 jet sizes in , G , Notes: Hrs. 12/21 12 SS. RPM. out size make & type jet sizes in T , B , G feet rotating hrs Bit-B.S.-D.C-D.C.-STAB-DC-DC-DC-DC-DC-DC-XO-JARS- in Notes: out Formation(s)- Sand, Gravel, Coal Last Casing: Pump Pressure: 800 Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: 500 ft - 1/2° psi @ 110 psi, fi/sec. SPM FPM or lb 13-3/8" @ size & grade Pump Output: 346/8.25 Annular Velocity (collars): % Bit Hydraulic Horsepower: Pump Hydraulic Horsepower: 140 ft KB depth (GPM)(BPM) 100 FPM HP HP Drilling Fluid: Milpark , spud mud mud company 9.2 (PPG), 185 weight funnel vis. 31 #100 fi2 8.5 yield point Ph 1.0 % 0 % 700 sand oil chlorides Detail: type sec. 21 cps. NC cc plastic vis. water loss 4/32 in. 7 filter cake solids ppm 92 % 0.478 psi/ft water mud gradient (Note: Mud dehydrated due to running Iow on water--will correct as soon as water truck arrives.) Continued final rig-up. Repaired slick line unit for surveys. Hooked up cellar pump. Fabricated chute for mud cleaner discharge. Picked up BHA. Tagged fill in conductor @ 112 ft. Started washing to bottom @ 1400 hrs. Picking up 8" D.C.s slow because collars will not fit in mousehole. Started drilling new hole @ 1600 hrs. Formation poorly to unconsolidated. Hard to handle volume of solids in mud. Had electrical problems with mud cleaner, but repairs made by 2000 hrs 12/20. Ran survey @ 500' KB: 1/2°. Ran Iow on water @ 0530 hrs 12/21 and slowed penetration rate while waiting on water truck. Warm weather thawing location and melting snow, making location sloppy. ,. ~ Weather: 31°, Fog. Visibility 0.5-1.0 mile. Wind light and variable. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (turnkey) Rig Phone: 262-2048 ENSR Consulting and Engineerin~ Anchorage, Alaska (907) 276-4302 DAILY DRILLING REPORT Well Number: CIRI West Fork 1-21 Field: West Fork Report Period: Depth: Elevation Avg. ft/hr Bit No. 140 322 Bit No. Drilling Setup: None 0600 Hrs. 12/19 KB, Total Drilling Days: 0.75 KB, TVD 140 Weight on Bit 1,000/lb size make & type in T feet rotating hrs size make & type in T feet rotating hrs to Date: Contractor: 0600 Total Rotating Hours: KB, Depth Rotary Speed jet sizes , G Report No. 1 12/20/90 Grace Rig 211 Hrs. 12/20 0 SS. RPM. jet sizes , B , G in Notes: out in , Notes: out Formation(s): Sand Last Casing: Pump Pressure: Annular Velocity (drill string): Pressure Loss at Bit: Jet Velocity: Bit Hydraulic Impact Force Surveys: None psi @ psi, ft/sec. SPM FPM or lb 13-3/8" size & grade Pump Output: Annular Velocity (collars): % Bit Hydraulic Horsepower: Pump Hydraulic Horsepower: 140 depth (GPM)(BPM) FPM HP HP Drilling Fluid: > 10 (PPG), weight 129 #100 fi2 yield point 0 % sand Milpark , spud mud mud company type 160 sec. 18 cps. NC funnel vis. plastic vis. water loss 8.5 , 2/32 in. 8 pH filter cake solids 0 % 800 ppm 92 % approx. 0.49 oil chlorides water mud gradient Detail: cc psi/ft Rig accepted effective 1200 12/19. Continued with rig up. Completed diverter installation. Had some problems with frozen 10" ball valves. Thawed valves. Function tested diverter. Test witnessed by Doug Amos of AOGCC. Fabricated and installed flow nipple. Mixed mud. Installed screens on shaker and mud cleaner. Changed kelly bushings. Still quite a bit to do. Expect to spud between 1000 hrs and 1200 hrs this date. · . Weather: 31°, light freezing rain. Visibility estimated at 10 miles plus, wind >5 mph from north. Cumulative Mud Cost $ N/A Cumulative Total Well Cost $ N/A Drilling Foreman: R.C. Gardner Daily Total Well Cost $ N/A (turnkey) Rig Phone: 262-2048 PERMIT # q COMPLETION AOGCC GEOLOGICAL MATERIALS iNVENTORY LiST // ~~:~/ CO. CONTACT 0~/ i" ct~'eck off or lis{ data a~ ii is rcceived.*list re'eib/ed date for 407. if no{~rca, u'ircd list as NR ,4~7 ] * ~/~/ ~J ddllina. ~. history. ,i ~, su~'cv,,~l.~ 'Well.tests, i;~'corcd intc~als t~o.. ~,.~iy~i~!¢~d~.ditch intc~ais t digital data ! , .,I,, , , I. I ,,, i,,. i,,, ! ., , ! ...... !,. !, ii 3] -5] | fli 1311 Bilk, IAITCn~'~'* I 0 i SCALEi r'q.l~lNI I1~1 I lrlLlill.l'4,lq.]I NO. {to thenearest faot} {inchl100'1 I ., ,, . i. ~, i~;~- 7Y~ '~ .. 5.2 ~ /( , ill i i , , 11 i , ' i i i ii iii i COOK INLET REGION, INC. March 12, 1991 Larry J. Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Larry: I have checked the cementing evaluation logs. All the cementing evaluation logs were sent to you last week. The well was logged with four runs of cement evaluation logs. The confusion was caused by the wrong run numbers appearing on the log headings. The first log (dated January 9. 1991) is a combination of two runs, one on January 9 and one on January 16; the second log is run #3 which was run on January 20; the third log is run #4, dated January 23, 1991. Please ignore the run numbers appearing on each log heading. Enclosed are the following additional logs for CIRI West Fork 1-21 well: . One sepia copy of MWD Log One sepia copy and one blue line for the packer setting record log, completion record log, and gravel pack log When you find all items present, please acknowledge receipt and return to me at the address below. Please give me a call if you have any questions. Sincerely, COOK INLET REGION, INC. Menggui Zhang ~/ Operations [ngineer MZ:klp:029 CIRI BUILDING 2525 "C" STREET P.O. BOX 93330 ANCHORAGE, ALASKA 99509-3330 (907) 274-8638 TELECOPIER (907) 279-8836 TELEX 090-26-465 MAR ? 1991 Alaska Oil & Gas Cons. March 7, 7 99 7 _ Mr. Larry j. Grant CO0/< INI_ET REGION, /NC. Alaska Oil and Gas Conservation CommisSion 3007 POrcupine Drive Anchorage, AK 99507 Dear Mr. Grant: In accordance with Regulation 20 AAC 25. CIRI West Fork 1-21 W~II. Enclosed please f~7ndl' I am sending you the well logs the following items: run in 1. One COpy of sepia and one COpy of blue line for ~)ual Induction, SFL (2" and 5") the ~C°mpensated Neutron · . following logs: ~yberlook_ Fi~l,~ -._ 'L!th.oDenstt ~ement ""~ Cumputation Y Evaluation Logs (3 runs) Mud Log " J~\/~ 2..<Two blueline copies of MWD Icg .~3: One copy of magnetic tape LIS format and a verification listing of open hole Icg data in Please acknowledge receipt attention. Thank you. with your signature below. Sincerely, COOK INLET REGION, INC. uperations Engineer abov__.__..__e named reports. Alaska Oil a d Gas Conservation Commissi Dat~ Enclosures ' on nam:226 Return one original to my CIRI BUiLDiNG 2525 "C" STREET P.O. (90;) 274-863,9 TELECOp/£~B~Xn~9o3_,33,O- ANOHoRA BIAKER SAND CONTROL A Baker Hughes company 4792 BUSINESS PARK BLVD. BUILDING F, SUITE 3 ANCHORAGE, ALASKA 99503 TELEPHONE (907) 563-0825 FAX NO.(907) 563-0385 February 26, 1991 CIRI Production Company 2525 C Street Anchorage, Alaska ATTN: Erik Opstad RE: Completed Gravel Pack Summary for CIRI West Fork Well 1-21 Dear Sirs, Baker Sand Control is pleased to submit this summary of the completed gravel packing of CIRI West Fork Well 1-21. GRAVEL PACK SUMMARY: PERFORATIONS GRAVEL PACKED: 10', 4982' - 4992' GUNS: Schlumberger 5" OD 12 SPF 90° phased "DP" PBTD: 5459' SUMP PACKER SETTING DEPTH: 5000' GRAVEL PACK SCREEN: 26' 3-1/2" base pipe with 4.13" OD, 0.012 gage Bakerweld Stainless Steel Screen GRAVEL PACK PACKER: Baker SC-1L 70B2-40 set at 4837' THEORETICAL GRAVEL VOLUME: 13 cubic feet 20-40 Baker Low Fine ACTUAL GRAVEL VOLUME PLACED: 11 cubic feet 20-40 Baker Low Fine FLUID FILTRATION: D.E. Filter Press to 2 micron absolute POLYMERS: A HEC Baker Clean Gel was mixed to yield a 350 cp viscosity. The gel was then cycled through a hydraulic hydrator to remove micro-fisheyes. SLURRY DENSITY: 10 pounds per gallon PUMP RATE: 2 barrels per minute CONCLUSION: A Photon Gravel Pack Log reveals total coverage of gravel pack sand across all screen and 75% of reservoir blank pipe. The theoretical gravel volume (13 cu. ft.) was derived assuming 1/4 cubic foot of gravel pack sand would be placed in each foot of perforations. Eleven cubic feet, or 84% of the theoretical amount, was successfully and effectively placed. Baker Sand Control would like to thank you for your business and we look forward to providing you with quality service and products in your upcoming gravel packing and perforating completions. Sincerely, BAKER SAND CONTROL, a Division of ~er Hughes Production Tools, Inc. Darr¥1 S~w Alaska SaSes Representative DS:RR CIRI.., WEe''?~~,,~ FORI.(.-, ~ ., 1-,..Ol FILTFt, AT~ON REPORT 2/21/9t 20 0 150 100 50 0 0700 NTH"S 0 900 1100 1300 1500 i70 0 1900 TIME IN HOURS WELL OF{ ?!1' RETURNS DE PRESS DISCHARGE FILTER REPORT NO. I CIRI WEST FOF~K --,21 F!L'f'RA~"IOI',~ REPORT 2/,:23/91 NTL!'$ 6O 5O 4(') 3O 2O 10 0 1100 ................. 3% I<CL 86;~ SODIUM E~.ROMIBE ................................................................... :'""':-..i,i...,.. ' ................... ,,,.,?" .................................. '--":-~ ....... -: CLEANUPAFTERPERFORATING J I t I J t 1200 1300 1400 1500 1600 1700 1800 TIME IN HOURS WELL OR PiT RETURNS DE PRESS DISCHARGE FILTER REPORT NO. 2 CORE LABORATORi a Compa~ :CIXI[ INLET R:EGIO#AL CIXlP. ~eL L :gl: 1-21 Field : FiLe ~o,:57112-C[l&lO~E Formation : Date :l~-Feb-91 Locacion:COl~ lgLET $~mp[e Xo.: 2 AnaLysts:PUl State :AI.A.~ Depth : 4~50.0 - 4~1~1.0 ft Hethod :Sie~e Description: PARTICLE SIZE ANALYSIS , Aril~letic Ptot Ueight Sand _- Statistics , . · -- He~ian: 1.1105 ~ -0.1512 0,~0 ~e~: 0.~127 ~ 0,1319 --Std. D~iaC~: 1.~5 0.~ { ~ ~ ~ ~ { { { I 0.50 i 'r ~ ,, 0.40 ~ ' I o.~o,,/' ' ~i .... I I '' ' , , I ' I { I I ' r ~ I - ' - ~ " 1 [ i i , ,. { '- -1 0 1 2 3 4 5 6 7 8 9 10 2.~ 1.~0 0.5~ O.~O 0.1~ O.~ 0.031 0.016 0.0~ 0.0~ 0.0~ 0.001 i , Sieve analysis. ~.S.si~el PebbLes 4 4.757 6 3.344 Granu{es 8 12 { .~ ~.q~ Coarse ~ 20 0.841 30 0.595 M~:lium semi ~ 0.420 50 0.297 70 0.210 Fir~ ser~l 100 0,149. 140 0,105 Very fine s~nd 200 O. 07'4 271) 0.053 SiLt & clay 600 O.ITS? Retained: t/eight tgi [fmc] _ cts. [fr~cl 5.89 0.04~ 0.04~ 11.03 0.082 0.12~ 16.7& 0.1E& 0.249 14.56 0.108 16,81 0,124 15.4Z~ 0.116 0.5~ 13.01 0:096 , 0.6¢2 9.1~ 0.0~ 0.76O 7.77' 0.058 0.817 4,70 0.035 0.852 3.98 0.029 0,881 2.55 0.019 0.900 2.16 0.016 0.916 2.0~ 0.015 0.931 4;50 0.0~3 0/.~5 130.35 O. ,965 , 0.9.65 CORE: LABORATORIE Caq3any :COO[ IELE'r WeLL :S~F 1-21 Locat t on=COl:l: INLET State Description-- Fietd : ;ormat ~ ~ : Samp(e No.: Depth : 5130.0 - 5160.0 ft Fire ~o.:57112-C11&lOSE Date :O~-Feb-91 AnaLysts:PL8 Method :Sieve PARTICLE SIZE ANALYSIS Aritheet(c P(ot t Sand 3-~ )lean: 0.6303 fa= 0.6659 -. Std. Deviation: 1.8~03 - Skewneaa: -0,0 )- Kurtosis: 1.~ - Tra~k*s sorting: ( ) i :/ .E L l ) , ,I ,~ Weight [frac] 1.00 0.~ 0.~ 0.70 0.~ 0.~ 0.30, 0.20 0.10 0.00 ~ -1 0 1 2 3 4 5 6 7 8 m 2.000 1.000 0.:500 0.250 0.12S 0.063 0.031 0,016 0.008 0.004 Sieve analysis [U.S..sieve~ ~ ,., 6 GranuLea 1Z I Vary coarse sated16 1,189 Coarse sand 20 0.~1 ,L _ 30 o.5~ Medltm sand 40 0.420 50 0.297 713 0.,210 Fine sand 100 0.1&9. 14,0 0,1~ Ver~ f~ne sand 200 O.07& : . , 270 0.053 SiLt & clay 400 Retained: 7,39 0.050 O. 196 8.2¢ 0.055 0.~1 19.40 0.130 0,381 17.20 0,11~ 0,~ 17.~ 0,1~0 0,616 ~.A,~ 0,1~ 0,'/'8~. 2.85 0.019 0.9~2 2.00 0,013 0.9S5 142.52 O.g~5 0.955 9 10 0.002 0.001 Oistributim Diameter 16' ~.14~ -1,100 125 1.1~ -0.~0 50 0,5~1 0.~ ~ 0.3191 1.~ ~ ;0.Z031 2.3~ ~ ~.~27 4.550 * Statist(cs caLcutated on extension of data CORE LABORATORY, _S : ;orlTmti on : Depth : FiLe Date :04-Feb-91 5010.0 - $040.0 ft Hethod :Sieve PARTICLE SIZE ANALYSIS Artttmattc PLot _ _ $~a~is~ics - Hedia~: 0.3<~7 ~ 1.,.T5'39 ~ i ,~- ~ '" ~ ~ ~ ) ; ' ~' ~ ' ' ~ " -- Std. - Tr~'s sortie: 1.6 i ~ I I I . ' ' ~ ] : I I J f f I i . .I . i I ,, ~ i '-' ' ~ . ~ ...... . ,. .~. ~ · = ~r ; ,. ~ ,, ~ , '1 .. , _ ~ ~ ' ~k ~ i r , .. ~i ' ~ight Cfrac 1. 0.90 0.~ 0.~ 0.50 0.30 0.20 0.00 e -1 0 I 2 3 & 5 6 7 8 9 10 an 2.000 1.000 0.500 0.250 0~,.1~ 0.06] ,.'..0.0]1 0.016 O,OOB 0.004 0.1102 0.1301 i ii TU.S.aieve] imm] ~=ebete~ /* ~.~7 Or~t~ 6 8 12 1.~ i i c~ ~ ~ 0.~1 , 30 ~t~ ~ ~ 0.4~ 50 0.~ Fine sand 140 0.105 Very ftne sand 200, O.07&. 270 SiLt G clay 400 0.0~ i Weight 5.17 0.037 .-' 0.~7 3.~ o.~ ~ o.~ 5.~ 0.~ 0.q~ 5.3q 11 17.~ ~.08 0,038 O, 140 0.038 0.178 0.087 0.265 0.082 0 °346 0.122 0°306 0.775 70 0.210 0.33 0.002 0.777 100 O. 140 1/,.59 O. 104 0.881 3.43 O.O?A 0.906 2.78 0.020 0,925 1.59 0.011 0.937 0,84 O.OM 0.943 132.5~, 0.943 0.9~3 Olstrfbutt~. _ X Oimter 16 1.320-0.400 2.5 0.8712 O. 50 0.~967 7~ 0.3O92 1 ~ 0.16531 2.5~7 ~1o. ,o1~1 s.~o Statistics caLcuLated on exter~ion of data 3'5 CORE __ LABORATOR] Compeny :I:I:X:IC IMLET ilf. gl~llAL II:JP. Locatio~:~ IIILET State :ALASr~ Description: PARTICLE Field : FiLe No. :57112-CX 14,10<J~ Format:ton : Date :l~-Feb-91 SampLe No.: & Analysts:PUl Oepth : 5160.0 - 5190.0 ft Method :Sieve SIZE ANALYSIS Aritll~-tic Plot Weight [frac] 1.00 0.90 0.80 0.70 0.60 0.40 0.30 0.20 0.10 0.00 e -1 0 1 2 3 4 5 6 7 faa 2. O(X) 1.000 0.500 0.250 0.12S 0.063 0.0~1 0.016 0.008 _ _ sieve anaj. y~i8, geiaht .. Ill] [frec] c,-.. 2.40 0.018 0.018 GranuLes 6 3.364 8 2.378 12 1.6,8~ Very coarse sand 16 1.189 Coarse sand ZO 0.841 zo )tediu,~ sand 40 0.420 50 0.297 Fine sired 70 0.210 100 0,149 i 140 0.105 Very fine sand 200 0.074 270 0.053 Silt & cle~ 400 0.05'7 .~:.-.,:...-.'~-.¢-~. ,~.~;..,..~. ~; Retai ,ned: 0.~8 0.007 0.024 2.80 3.80 0.0~6 0,074 6.89 ,. 0.051 , 0.125 9.6~ 0.072 O. 197 22.20 ,.. 0.165 0.~ 18.65 0.139 0.501 25 · 70 O. 191 , .0.693 11 .~6 0.085 0.777 6.76 0.050.., 0.828 . 6.52 0.0~9 0.a76 3,08 ,, 0~023. , 0.S~, , 0.49 O.OO~ 0.90~ 8.07 O.06a 0.96~ . '~.m,.:,~... o..,~ o.,w~.., 9 10 0.002 0.001 4-5 CORE LABORATOR: .~ Compe~ ~eL t Local ion:QXIl( State Oescril~ion: PARTICLE FieLd : Ff Le No. :5711Z-CI1410SE Format J on : Date : 04`- Feb-91 SampLe ~io.: 5 AnaLysts:PUl Depth : 5044).0 - 5070.0 ft Method :Sfe~e SIZE ANALYSIS Arithmetic PLot Sand ~ian: 0.3589 Std. D~iaC~: 1.1507 [ur~is: 3.~/ : ~ ~ ~ ~r , , , ~ , l I' ~ i m ' f _t~ ~f ~ei~t [fracl: 1 0.90 0.~) O. 70 0.60 0.50 0.40 0 0.20 0.10 0.00 J -1 0 1 2 :3 4, 5 6 7 8 9 m 2.~0 1.1:X)O 0.500 0.?.50 0.125 0.06~ 0.0~1 0.016 0.008 0.00~ 0.00~ 0.001 Sieve [U.S.sieve] Grmmies 6 3.~ Ve~ c~ a.]~ 1. C~ s~ 20 0.~1 ~0 0.~ ~t~ ~ ~ 0.4~ 50 0.~ , FiM ~ ~ 0.Z10 .. , 1~, O. 1~ Ve~ ft~ ~ 1~ 0.105 . . , 2~ o.~ SiLt & clay , Retai~; [g] [frae] cra. [frac] 3.52 0.026 o.o26 1.09 0.005 0.0~ 1,58 ,0,011 1.~ O.01S 2-1~, 0.016, 3.~ 0.~ 0.1~ ,.~6-IS , 0.~5 18.~ o.1~ 0.~ ~.~ o.~ 1~.11 0.1~ 0.~2 S.~ 0.~ 0.~.. ~.~ 0.0~ 0.~ s.~ o.~ ~.~ o.o~ o.~ 3.52 0.0~ 0.~ 133.01 0.9~ I 5-5 / k SAND CONTROL A Bsker Hughe. company 9 IO SIZE WEIGHT GRADE THREAD cruz CASING 7' , COMPANY REP. ERIK FIPSTAD / BOB GARDNER / VIRGIL THRAPP LINER nE~ WELL 'NO'. ' ' VEST FnRK 1-21 TUBING 8 7/.' ~I'ATE LEA*3~E ALASKA KENA[ BO~UUOH WEST FORK WKSTRG 3 L/e' ~3,3. lOADING DO, i( '" PI.~ Pi, Kl'~llOl~$ ' ' SEE BELOW I~lO NAME PH~ ' ' DOWP. FtiJID " INHIBitOR DATE SUBI~rTTED .... JOB E ' ' $C~E£N SiZE ' ' SAHb ~lZ£ 8/;34/91 3 1/;3' ,01;3 GAGE 20-40 BAKEE LI]W FINE DARRYL SNOW 563-0825 . NO. DEPTH LENGTH O. D. I. D. DESCRIPTION I 4937,70 4.17 5,96 4.00 BAKER HODEL '$C-1L' GRAVEL PACK PACKER SIZE 70BFq-40 ;3 4841,87 4,81 5.50 5,00 UPPER £XTEN$IDN 3 4846.68 t,64 5.75 4,75 HODEL *S' SLIDING SLEEVE 4 4848,3~ 1,49 5,50 4.00 SEAL BnRE 5 4849,81 81.85 5,00 4,31 LOWER EXTENSION 6 4871.66 ,~5 5,00 8.99 CROSSOVER SUB 7 4871,91 31,51 3.50 ';3,99 3 1/;3' NU 10 RD BLANK PIPE W/ CENTRALIZERS 4903.4~ 31,55 3,50 ~,99 4934,97 31,50 3.50 ;3,99 · 4cJ66,47 5,29 3.50 2,99 · 8 497[.76 ;3:>6.30 4,13 2,99 BAKERWELD 3 1/2° ,01~ GAGE WIRE ~RAPPED SCREEN 9 4998,06 1.07 4,50 3.00 BAKER [SOLATIOH DISC 10 4999,13 ,97/3,41 4,63 ;3,44 BAKER HODEL 'S-82' SNAP LATCH SEAL ASSY SIZE 80-3;3 [1 5000,00 .70/2.75 5,86 3.~5 BAI<ER MODEL 'D' SUMP PACKER SIZE 84-3~ [E 5003,4I 3047 2.875 ~,44 I JOINT ~ 7/8' 6,5# N80 TUBING W/SPECIAL CLEARANCE 13 5033.59 15,06 2,875 2,44 2 7/8' NU lO RD TUB]NO JOINT W/SPECIAL CLEARANCE [4 5048,64 ,98 3,10 2.~5 BAKER MODEL 'F' SEATING NIPPLE ~5 5049,68 I0,06 8,875 B,44 8 7/8' NU 10 RD TUBING JOINT W/SPECIAL CLEARANCE [6 5059.68 ,81 3,18 8.18 BAKER MODEL 'R' SEATING NIPPLE SIZE 8.85 ~/8,197' NO-GO i7 5060,49 8.55 8,875 8,44 8 7/8' NU 10 RD TUBING .JOINT W/SPEC[AL CLEARANCE [8 5063.04 .68 3,18 8.18 WIRELINE INTRY GUIDE ~,,~;~,n T.~,[L ~nt~Ou ~-r ALL LISTED DEPTHS ARE TOOL TOPS ....... 12 15 17 INFO RlvtATION: PERFORATIONS 4982-499~ \CIRI\I-2L ANCHORAGE, ALASKA 99519 Geoscience and Engineering 907/345-6346 TO: Mr. Larry Grant DATE: Alaska Oil & Gas Conservation Commission TRANS.#: 3001 Porcupine Drive Anchorage, Alaska 99501 February 9, 1991 OAA-9.0291001 REFERENCE: CIRI West Fork 1-21 Ditch Samples q 0- t/~ The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to this office, attention Mr. Erik A. Opstacl~~g9 One Set Dry Ditch Samples (3 Boxes) Box#l: 120' - 2100' MD ~...~ / 4~ 7 ~'~'/ Box #2: 2100'- 3900' MD Box #3: 3900' - 5459' MD Well: CIRI West Fork API#' 50-133-20424 1-21 R ¢EIVED Alaska 0il .& Gas Cons. ,. I-II=iII_L_ING SEFIUII-E S WELL LOG TRANSMITTAL TO: AK Oil & Gas Conservation Commission ATTN: John Boyle 3001 Porcupine Drive Anchorage, Alaska 99501 January 14, 1991 RE: HWD Formation Evaluation Logs - CIRI West Fork 1-21 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the address listed below attention of Mr. Erik A. Opstad. 2" & 5" Presentations: 1 Blueline Print 1 Folded Sepia Digital Data: 1 LIS Format Tapes @ 1600 BPI 1 Tape Verification Listings Received : Alaska Oil & Gas~ Conservation Commission RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 5631 SilveradoWay, Suite G · Anchorage, Alaska99518 · (907) 563-3256 · Fax (907) 563-7252 A Baroid Company TO: THRU: FROM: i : MEMORANOUM St ,te of Alaska ALASKA OIL A~ND GASCONSERVATION COi-~4ISSION Lonnie . Sm~~ · Co~issioner ~'-' ~: DA~E: oanuary 18, 1991 ~ILE NO: JT. LG. i~ ~ g 91 TELEPHONE NO: Louis R. Grimaidi//~'~ Petroleum Inspector SUBJECT: RIG/BOPE inspection C~_,! W Fork #04 Permit No. 90-143 Sec 21T6N R9W Exploratory Wednesday 12/26/90: I performed a RiG/BOPE inspection on Grace ~/211 ~ng we%~ #24 t,~.~¥. Fork for CiRI. The rig had been stacked for 2 years and much of the equipment showed evidence of needed maintenance which was being taken care of. The major discrepancies I found were: (1) The choke line entering the manifold was on a 45© turn and not targeted. I had them change this to where the fie× hose entered straight in. (2) There were ha~maer up unions and threaded connection on the choke manifold. These were ~either removed or welded. Also, there was no biowdo~ line to the pits. This was fabr~ ' ' _catec at my request. (3) The flare line coming from the buster ended next to the rig. The pi.oe_ was ordered and ! was as surad that this would be remedied by adding more vipe and. e×tending the e~_d out past nne mud pits. . ~ ' BOP Friday 12/28/90: i wit~ess~c a test on Grace Rig ,~/211. The test was not compl-e-~ed because of kelly and BOP stack problems. S~~ ~_ -,_~[29/90: I returned to location to retest the Grace Rig ~z-l-i~~? ~I.-~.~.- For~.~zq ~ ~ ~ for CIR! Production. There was a problem with the bottom pipe rams hitting the crossover from the dri%lpipe to the test plug We tested the ~ ~ ~ . ~. oot~om rams against the casing to 3000 psi then engaged the test plug and tested the rest of the stack to 5000 psi. The test went w~ll and the only failures noted were the trip tank gauge was inoperative and 3 of the 4 nitrogen back-up bottles were discharged'. It should also be noted that the test pump was in very poor shape and rig air had a hard time keeping up with the demands of the test. The tool pusher assured me that this would be rememdied. All. orobl, ems. were -,=~-'~a~.~._~.-.. by 12/3/89 as per telecon with Bob Gar~...er'.~ 1/4/91. Attachment. (Rev, 6/89) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COHMISSION BOPE Inspection Report DATE OPERATION: Dr1g ~/' Wkvr~ Well Location, Sec ~ J T, d~v~ R c7 t~1 M Location (general) ~ Well sign Housekeeping (general) /~/~/!'t. Rig Reserve pit .::- MUD SYSTEMS: Visual Audio Trip tank ~ I Pit gauge ~ I ...... Flow monitor ~""~' ~ gas detectors ~'~k J ..... Rig#, BOPE STACK= Annular preventer Pipe rams Blind rams ~ Choke Itne valves HCR valve Ktll line valves Check valve Test Pressure TEST: Intttal~ ...,,'~,." Weekly~ Other Representative A~?? i:~ .... ~) (i':"? r/'7 fi, : . :. ,z .i .: i, ACcuHU~ToR SYST~4 J Full charge pressure ~ ~~ pstg Press after closure /~:P~ pstg Pump tncr clos press 200 pstg Full charge press attained Controls: Master Remote KELLY AND FLOOR SAFETY VALVES= ~ mtn . ~ mtn ~C~ sec Upper Kelly - Lower Kelly Ball type Inside BOP Choke manifold Number valves Number fl anges . I? r~ Adjustable chokes / Hydraulically operated choke (~/~(' Test pressure ~:~/~' Test pressure ~~-~ ¢~ ~ Test pressure ~-~ Test pressure TEST RESULTS: o /' Failures ~ Test time ,~.~v /~q- hrs · 'Repair or replacement of failed equipment to be made wtthtn ~ days. No,try the Inspector, and follow with wrttten/FAXed verification to Commission office. Remarks= Oistributton~ ortg - AOGCC c - Operator c - Supervisor C.OOq (rev 05/10/90) WITNESS TO: THRU: FROM: MEMORANuUM St ,' e of Alaska A~_SKA OIL AND GAS CONSERVATION COmmISSION DATE: Lonnie C. Smi~~ December 27, 1990 Con~nissione~:~~ FILENO: ~/ JT.DA.1127 TELEPHONE NO: SUBJECT: Doug Amos ~/' Petroleum Inspector Diverter Test CIRI W. Fork 1-21 Permit No. 90-143 West Fork Unit Wednesday Dec. i9,_..!99.0~: i traveled this date from Anchorage to Kenai and on to CiRi W. Fork 1-21 well to inspect the diverter system and witness the function test at Grace Rig No. 211. The diverter system consisted of a 13 5/8" annular, two i0" hydraulically controlled, full-opening ball valves and one 10" hydraulically controlled full-opening knife valve. There was one straight t0" line from the diverter to a targeted 4-way cross. lu~ediateiy downstream of the cross, there was one hydraulically controlled full-opening knife valve. The two valves were connected to the pipe ram master valve on the accumulator and were piped so that one valve was always in the open position. The master valve was labeled so that the driller is able to determine which valve is open and which is closed and is able to select the direction o~ flow through the bifucaned vent lines. The function test was successlul and all valves actuated properly with the annular. In sun, nary: I inspected the diverter system and witnessed the successful function test at CIRI W. Fork 1-21 well on Grace Rig No 21i. · 02-001A (Rev. 6/89) 20/11]MEMOl.PM3 Formerly ERT November 28, 1990 ENSR Consulting and Engineering 750 \Vest .qcc¢~d :\venue Suite 100 .-\~c}~oragc. :\K 99501 (907) 276-1.302 Commissioner Lonnie C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Survey Plat, GIRl Production Company, GIRl West Fork 1-21 Permit No. 90-143 Dear Mr. Smith: Please find attached two (2) copies of the above survey plat as per 20 AAC 25.005(j). The as- built location lies approximately 73 feet north of the location described in the Application for Permit to Drill. The original location was on a specific shot point which was later determined to lie in the middle of Sunken Island Lake Road. The final location was moved to the north to accommodate the footprint of the drilling rig and be off the road. In addition, the section line offsets given in the APD were approximate, since the section had not been surveyed. After establishing control in the area by a CPS survey, the section line offsets were corrected from a protraction diagram. The attached plats correctly reflect these offsets. I have also attached three (3) copies of an Application for Sundry Approvals that reflect these minor changes in both the surface and bottom hole location. R~--'~rt C. Gardner Regional Director, Technical Services RCG/rm Attachments CC: Kevin Brown, CIRI Production Company RECEIVED DE0 - 6 1990 Alaska Oil & Gas Cons. Commission Anchorage . . ~" "-- STATE OF ALASKA ,~ 5KAOILANDGASCONSEF::IVATIONCO, :L ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Aba~ __ S~s~-~l __ Alter ceang __ Ref3air ~ __ Operalion s~utdown __ Re-enter suspended welt __ Plugging __ Time exten=on __ Stimulate __ Pull tubing __ Variance __ Perforate __ Othe~ XX 2. Name of Operator I 5. Type of Well: CTRT Production Company I Oevel°ome~ XX Exploratory __ ~ Address 2525 "C" St reet Stratigraphic __ Anchorage, AK 9950.5 Service__ Datum elevation (DF or KB) .522 ft. KB 7. Unit or Property name West Fork Gas Field 4. Location of weil at sudace 1984 ft. FNL, 1707 ft. Sec 21, T§N, RgW. SM At top of productive interval 1984 Ft FNL, 1707Ft. FEL, Sec.21, T6N, EgW, SM At effective depth 1984 ft FNL, 1707 ft. FEL, sec. 21, T6N, Rgw. SM ~ total depth 1984 ft. FNL, 1707 ft. FEL, Sec.21, T6N, Rgw, SM. 8, Well number CIRT West Fork 1-21 9. Permit number 90-14.5 10. APl number 50-- 133-20424 11. Field/Pool West Fork/Sterling feet 12. Present well condition summary Total depth: measured 118 feet BGL Plugs (measured) true verticaJ 118 feet BGL Effective depth: measured 118 feet BGLJunk (measured) true vertical 118 feet BGL Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: Length Size 120 ' 1.5 3/8" measured true vertical Tubing (size, grade, and measured depth) Cemented Drilled and D riven Measured depth 118 ft. BGL True vertical depth 118 ft. BGL RECEIVED DEC - 6 199 Alaska Oil & Gas Cons. Commission Anchorage -. Packers and SSSV (type and measured depth) 13. A~tacl"~nents Description summary of proposalS_. (Letter) De{ailed'operations program __ BOP ske*,r.,h __ 14. Estimated date for commencing operation Spud -. December 10, 1990 16. If Proposal was verbally approved Name of approver Date approved 15. Status of we~l cla$~fication as: Oil __ Gas __~ Suspended __ Service 17, I hereby certify that the f?.,~omg is~ correct to the best of my knowledge, R. C. Ga rdne~~~ Signed ~,.~ ~,~e Agent ..... FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrib/__ BOP Test __ bacatJon clearance __ ,~;,:c~ ~ Mechanical Integrity Test __ Subsequent form required 10- . ORIGINAL SIGNED BY Approved by order of the ~i~h SMITH Form 10-403 Rev 06/15/88 Approved Copy Ret, urne/d Date 11/28/90 Commissioner I^pproval NO,~ _ ~// ' SEC. 21, T6N,R9W, S.M. Scale: 1' = 1/4 mile 1. Location of well site was accomplished by using GPS equipment from USGS stations Drab and Killey. 2. All dimensions and coordinates are in feet. ALASKA STATE PLANE CCORDI~TES ZONE 4, IN FEET. RF_F~~~ TO NAD27. Y = 2,411,643 DEC - 6 1990 x = 345,347 0ii & Gas Oons. 0ommissioISEODETIC POSITION Anchorage Lat. 60° 35' 54.08" N. Long. 150° 51' 37.53" W. Elev. of Conductor 300 feet hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me and all dimensions and other detai~t.~, ,~~ ~'~D~te~O Lawrence M' Whiting' LS 7618 Center of the conductor is located 1,707 feet west of the east line and 1,984 feet south of the north line of protracted section 21, T6N, R9W, SM. Dec. 3,1990 added Elevation Location Survey For CIRI West Fork 1-21 Section 21, T6N, R9W, SM KENAI, ALASKA ENSR CONSULTING AND ENGINEERING Surveyed By LCMF Limited 723 W. 6th Ave. Anchorage, Alaska SEC. 21, T6N,R9W, S.M. Anchorage Scale: 1' = 1/4 mile 1. Location of well site was accomplished by using GPS equipment from USGS stations Drab and Kiiley. 2. All dimensions and coordinates are in feet. ALASKA STATE PLANE COORDINATES ZONE 4, IN FEET. REFERENCED TO NAD27. Y = 2,411,643 X = 345,347 GEODETIC POSITION Lat. 60° 35' 54.08" N. Long. 150° 51' 37.53" W. Elev. of Conductor 300 feet I hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me and all dimensions land other detai~t,~, ,~.,~~ /?D~t¢O Lawrence M. Whiting, LS 7618 Center of the conductor is located 1,707 feet west of the east line and 1,984 feet south of the north line of protracted section 21, T6N, R9W, SM. Dec. 3,1990 added Elevation Location Survey For CIRI West Fork 1-21 Section 21, T6N, R9W, SM KENAI, ALASKA ENSR CONSULTING AND ENGINEERING Surveyed By LCMF Limited 723 W. 6th Ave. Anchorage, Alaska COOK INLET REGION, INC. November 14, 1990 Lonnie C. Smith Commissioner c,~ of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' Please be informed hereby that Robert C. Gardner is authorized to act in the capacity of an agent for Cook Inlet Region, Inc. (CIRI) and CIRI Production Company (CPC) for the purposes of obtaining any and all permits and filing any and all reports in connection with the CIRI West Fork 1-21 well. Sincerely, COOK INLET REGION, INC. Kevin A. Brown Manager, Engineering and Operations kab:vv:017 061,300.003 RECEIVED 1 4 ]990 CIRI BUILDING 2525 "C" STREET P.O. BOX 93330 ANCHORAGE, ALASKA 99509-3330 (907) 274-8638 FAX (907) 279-8836 TELEX 090-26-465 Te!ecopy No. (907) 276-7542 November !4, 1990 Robert C Gardner, Agent ENSR Consulting and Engineering 750 I~est Second Avenue Suite Anchorage, AK 99501 Re: CIRI West Fork 1-21 CIRI Production Company Permit # 90-143 Surf Loc 2!58'FNL, !725'FEL, Sec 21, T6N, R9W, SM Btu%hole Loc 2!58'FNL, 1725'FEL, Sec 21, T6N, R9W, SM Dear Mr Gardner: Enclosed is the approved application for permit to drill the above referenced well. The perrait to drill does not exempt you from obtaining additional, permits required by la~ from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Sufficient notice must be given to allow for a representative of the commission to witness the BOPE installed on the surface casing and a test of same prior to drilling out the surface casing shoe. BY ORDER OF ~HE CO~?-~ISSIO~ jo eric! Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl Formerly ERT November 7, 1990 Commissioner Lonnie C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENSR (],,nsulting and Engineering 750 \\'c.~t ,%c,:c¢~(1 .-Xventm Suite 100 .-kuci~oragc..-XK 99501 (007) 2TO-.N02 Re: Statewide Drilling Bond, Cook Inlet Region Inc. Dear Lonnie: Please find attached the above-referenced statewide bond. Also attached are the Notice of Change of Ownership Forms (Form 10-417) covering the following three wells in the Tyonek area: Simpco Moquawkie No. 1 Simpco Moquawkie No. 2 Simpco Koloa No. 1 It is understood that the statewide bond will satisfy the AOGCC requirement for bond coverage for these properties as well as for the CIRI West Fork 1-21 development well. You presently hold a single well bond for the West Fork 1-21 well and the drilling permit for that well is presently before the commission. It is also understood that the AC)GCC will release the single well bond upon receipt of the statewide bond. Please contact the undersigned at 276-4302 or Margie Brown at Cook Inlet Region Inc. (274-8638) if you have any questions. Thanks for your help on this, Lonnie. RECEIVED NOV 0 9 1990 Robert C. Gardner &!as Qil & 6as Cons. Regional Director, Technical Services ', '_Anch0ra~ RCG/rm Attachments cc: Margie Brown, Cook Inlet Region Inc. Formerly ERT October 15, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENSI/Consulting and Engineering Suit(-100 :~n(:I~()rage, AK 99501 (907) 276-4302 Re: Application for Permit to Drill CIRI Production Company, CIRI West Fork 1-21 Gentlemen: CIRI Production Company (CPC), a wholly owned subsidiary of Cook Inlet Region, Inc. (CIRI) submits herewith three (3) copies of their Application for Permit to Drill the CIRI West Fork 1-21 development gas well in the West Fork Gas Field, Kenai Peninsula. The required $100 filing fee is enclosed. Bond information is included in the Application booklets. The actual bond has been previously submitted to your office. Thank you for your timely consideration of this application. If you have any questions, please contact the undersigned or Curtis King at 276-4302; or Kevin Brown, Manager of Engineering and Operations for CPC, at 274-8638. Sincerely~ Robert C. Gardner Regional Director, Technical Services RCG/rm Enclosures CC: Curtis King, ENSR Kevin Brown, CPC STATE OF ALASKA ALASKA ,_ ,_ AND GAS CONSERVATION CL,.,iMISSION PERMIT TO DRILL 20 AAC 25.005 Drill ~ Redrill []1 lb. Type of well. Exploratory [] Re-Entry ~ Deepen la. Type of work Stratigraphic Test L~ Development Oil Service ~, Developement Gas ~ Single Zone ~ Multiple Zone 2. Name of Operator CIRI Production Company 3. Address 2525 "C" Street Anchorage, Alaska 99503 4. Location of well at surface 2158 FNL, 1725 FEL, Sectlon 21, TCN, Rgb, S~4. At top of productive interval 2158 FNL, 1725 FEL, Section 21, TCN, Rgw, SI~. At total depth -2158 FNL, 1725 FEL, Section 21, TCN, ~9~, SI~I. 12. Distance to nearest property line (SE1/4 sectionllne 482 feet 13. Distance to nearest well Soldotna- Creek No, 21A- 16 37,000 feet 16. To be completed for deviated wells Kickoff depth n/a feet Maximum hole angle 18. Casing program size Hole Casing 17-1/2 12-1/2 8-1/2 5. Datum Elevation (DF or KB) KB feet 6. Property Designation Kenai Native Asso. - Surfa¢ Co~k [nlet Region - Subsurf 7. Unit or property Name West Fork Gas Field 8. Well nu ,mber CZR[ West Fork 1-21 9. Approximate spud date,~/f~, ~, 1990 14. Number of acre~ in property 640 10. Field and Pool West Fork Gas Field =~c~ 13-3/8 9-5/8 7 Specifications WeightIGrade Coupling 54.5 I N-80 BR 43.5 I N-80 i BTC 26/29 IN-gO BTC 11. Type Bond (see 20 AAC 25.025) Single Well Number Amount $100,000 15. Proposed depth (MD and TVD) 5,500 ft. f4.D. 5,500 ft. TVD feet psig 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) ~ Maximum surface 2074 psig At total depth (TVD) 2706 Quantity of cement TVD (include stage data) 120 ~150 ft3 c.irc, cmt. to surf 2150 ~1600 ft3 circ. cmt. to surf 5500 ~ 800 ft3 cmt. to 1000 ft. Setting Depth Top Bottom 0 I 0 I 120 I o / o 15500 I above top producing zone. / ~:,~3500 ft) cmt. ¥ol. fm calip, 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet log + 20~ excess. Effective depth: measured feet Junk (measured) true vertical feet Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 20 true vertical . Attachments Size Cemented Measured depth True Vertical depth RECEIVED OCT -.:, i9.9.0 & Gas C0, s. Pressure based on 0.492 psi/ft. gradient (normal gradient plus 0.027 psi/ft, safety factor), and assumed gas gradient of 0.115 psi/ft. Filing fee ,~ Property plat ~ BOP Sketch ~ DiverterSketch ~ Drilling program Drilling fluid program ~ Time vs dep~,h plot ~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements ~ ~,~.lhereby certif~,.t, he~~~ _f~isTd correct tothe best of my knowledge Signedi~~n~"~r ~,.,~,-~~~~¢'~'"''''~'?~''~'''¢r~'¢'''''~-'' Title Agent for CZRI Production Corp. Date 10/16/90. ENSR Consulting & EngJ. neering Commission Use Only -.Permit Number APl number ISee cover letter for other requirements Conditions of approval Samples required ~ Yes ~No Mud Icg required L~ Y.~s ? No Hydrogen sulfide measures r~ Yes ~¢'No Directional survey required I~, Yes N Required working pressure forCBOPE ,~2M; 73M; [] 5M; [] 10M; [] 15M Other: .... ,./ /'~?/-"'].i\ ' . ; by order of / " L' /" ~- ', Approved by~ .,~.__._,._~,~: '/~-'~i ¥ ..... t.~'~-~'., Commissioner the commission Form 10-401 Rev. ~-1-8/5" :~ ~'-) Date i' /~ l Zf-. '[ ~' Submit in triplicate SEC 17 ISLAND LAKE SEC 29 SEC 16 SURFACE LOCATION SEC 28 SEC 22 SEC 27 PROPOSED SURFACE LOCATION FOR VERTICAL WELL ClRI PRODUCTION COMPANY, WEST FORK 1-21 T.6No, R.9W., S.M. 0.5 I SCALE IN MILES 1.0 I EN 'R FILLUP LINE ,I 5,000 PSI WP ANNULAR PREVENTER i I FLOWLINE 3' KILL LINE 'l,l~ll~, ~ Ii 3' CHOKE LINE DRILLING SPOOL CHECK GATE GATE ,:,;~, VALVE' VALVE VALVE III~1~ ,11~1~ , VALVE VALVE ¢, TO 5000 PSI WP CHOKE MANIFOLD RING GASKE'I WELLHEAD SECTION 5,000 PS! FLANGE RING GASKET 5,000 PSI FLANGE B.O.P. STACK CONFIGURATION, 11" THREE RAM STACK WITH ANNULAR PREVENTER CIRI PRODUCTION COMPANY CIRI WEST FORK 1-21 13 5/8' 5000 PSI ANNULAR PREVENTER FILLUP LINE RING GASKET 3" GATE VALVE 3' KILL LINE --- -- \\\\ \ \ I I / / / / /// WELD-ON FLANGE /10' HYDRAULIC VALVE (OPENS AUTOMATICALLY WHEN ANNULAR PREVENTER CLOSES;) NOTE DIVERTER LINES HAVE DOWNWIND DIRECTIONAL OISCHARGE CAPABILITY. 3/8' 54.5 lb. CONDUCTOR 13 5/8" DIVERTER SYSTEM CIRI PRODUCTION COMPANY CIRI WEST FORK 1-21 TO DISCHARGE POINT 10' DIAMETER DISCHARGE LINE NOTE FLUIDS TO BE DIVERTED DOWNWIND, AWAY FROM RIG 8Y CLOSING APPROPRIATE 10' HYDRAULIC VALVE 10' HYDRAULIC VALVES (NORMALL"¢ '.~PE';;. .~~ VALVES LINKED THROUGH CO,NT~OL 'j"~IT SO ONE VALVE MUST BE OPEN ,AT AL,_ .":',,LIE5 TO DISCHARGE POI~'- 10" DIAMETER DISCHARGE LINE 10' DIVERTER DISCHARGE LINE ~ 10' HYDRAULIC VALVE, NORMALLY CLOSED ~'~"~/(OPENS AUTOMATICALLY WHEN DIVERTER IS CLOSED~ WELLHEAD FLANGE AND 13 ~~..~,,.~ ANNULAR PREVENTER DIVERTER DISCHARGE LINE AND VALVE LAYOUT CIRI PROOUCTION COMPANY CIRI WEST FORK 1-21 Choke Manifold · 3"x 5,000 psi choke manifold system on control and diverter side. Hydraulically-operated choke and manual choke manifold through an 8" expansion chamber to the gas buster or reserve pit. BOP Stack (1) 1 l"x 5,000 psi wp single ram type preventer. (1) 11" x 5,000 psi wp double ram type preventer. (1) 11" x 5,000 psi wp annular preventer. (1) 11" x 5,000 psi wp drilling spool with 2 ea 3" side outlets (choke and kill), HCR and manual valves on choke line, manual valves on kill line. (1) SWACO hydraulic choke - 10,000 psi wp with choke control panel (rental item). BOP Closing Unit One Koomey 120 gal. 3,000 psi working system with twelve lO-gal, accumulator bottles and nitrogen backup system: five station control with five station air-operated remote control. DIVERTER DESCRIPTION (1) 13-5/8 "x 5,000 psi wp diverter. (1 10t) 10" hydraulic valves and diverter lines. (1) actuating unit- (see BOP Accumulator) RECEIVED ,~!$~fa Oi/& Gas Cons. Commiss!g.l~ Anchorag~ CIRI PRODUCTION COMPANY Casing and Cementing Program Summary ., Hole Casing Casing Depth, Depth, Float Cement Slurry Size Size Description Shoe (KB) Top Length Equipment Class Weight Notes 17-1/2" 13-3/8" Conductor 54.5 lb 120' MD 0 120' Plug G 15.5-16.0 If not driven: or larger (may Conductor installed N-80 (120' 1'VD) Cement to surface be augered as part of drillsite 8R with Class G (top job.) or driven) construction Approximately 150 ft" operations required for job. Fill casing with water. 12-1/4" 9-5/8" Surface 43.5 lb 2,150' MD 0 2,150' F.C. G 13.5-14.0 Cement to surface N-80 (2,150' F.S. using Class G BTC TVD) blended with prehydrated gel. f~proximately 1500 required for job. , 8-1/2' 7" Production 26 and 29 5,550' MD 2,050' 3,450' F.C. G 16.0 Cement to 1,000' lb (est.) F.S. above top of highest N-80 (5,500' producing horizon. BTC TVD) Top of cement about 3,500'. Use Class G with friction reducing and fluid loss additives. CIRI PRODUCTION COMPANY West Fork 1-21 Fluids Summary Depth Casing Density Viscosity Fluid Loss HT/HP (**) Problems Mud Additives O-2150 9-5/8' 8.8-10 +150 sec/qu N.C. No Control Hole Cleaning Milgel Hole Sloughing Soda Ash Shallow Gas Benex Milbar 2150-5500 7" 8.8-9.4 40-46 sec/qu 10-12 cc/30mm Less than 25 cc's Hole Cleaning Milgel Hole Sloughing Soda Ash Gas Kicks Mil-Bar Rotary Torque Drispac Caustic Soda Bicarb of Soda New Thin D Ligco New-Drill HP Shave-Bond LD-8 ** Run @ 200°F/500 psi/30 mins. OPERATOR: CIRI PR~_JCTION COMPANY LEASE: WEST FORK 1-21 SEC. 21 TWP. 6N RNG. 9W COUNTY: DATE: 22-OCT-90 FIELD: WEST FORK GAS FIELD SEWARD MERIDIAN STATE: SURFACE CASING ALASKA CASING DESIGN DATA DESIGN CODE: 1 CASING STRING DESIGN CODE ............................ = ***************************** DESIGN FACTORS: 2 BURST DESIGN FACTOR .................................. = 1.100 3 COLLAPSE DESIGN FACTOR ............................... = 1.100 4 TENSION DESIGN FACTOR ................................ = 1.600 50VERPULL IN EXCESS OF THE STRING WEIGHT ......... (LBS) = 100000.000 CASING BURST DESIGN DATA: 7 FRACTURE GRADIENT AT THE CASING SHOE + YOUR SAFETY FACTOR .............................. (PPG) 8 GAS GRADIENT ................................. (PSI/FT) 10 WEIGHT OF BACKUP FLUID ........... - .............. (PPG) = 13.000 = .115 = 9.000 CASING COLLAPSE DESIGN DATA: 11 MUD WEIGHT CASING IS SET IN ..................... (PPG) = 12 TOP OF CEMENT .................................... (FT) = 13 WEIGHT OF CEMENT ................................ (PPG) = 14 WEIGHT OF COLLAPSE BACKUP FLUID ................. (PPG) = 9.500 3500.000 15.500 9.400 CASING DESIGN DATA: 15 CASING SIZE, O.D ................................. (IN) = 16 CASING (MIN. ACCEPTABLE) DRIFT DIAMETER .......... (IN) = 17 SETTING DEPTH .................................... (FT) = 18 MINIMUM SECTION LENGTH ........................... (FT) = 7.000 6.100 5500.O00 .000 CALCULATION CONTROL DATA: 24 UPGRADE BURST FOR TENSION ............... (0=YES;i=NO) = 25 UPGRADE COLLAPSE FOR COMPRESSION ........ (0=YES;i=NO) = 26 CONSIDER EFFECT OF BOUYANCY ON TENSION...(0=YES,i=NO) = 27 MAXIMUM LOAD;MAXIMUM STRAIN ENERGY..(0=LOAD;i=STRAIN) = CASING TABLE NAME: 28 CURRENTLY SELECTED CASING TABLE ............ (CAS.BIN) = C:CAS.BIN OPERATOR: CIRI PRe ~TION COMPANY LEASE: WEST FORK 1-21 SEC. 21 TWP.'6N RNG. 9W t~TE: 22-OCT-90 FIELD: WEST FORK GAS FIELD COUNTY: SEWARD MERIDIAN STATE: ALASKA SURFACE CASING CASING DESIGN -- 7.000 DEPTH LENGTH WEIGHT GRADE JOINT PRICE (FT) (FT) (LB/FT) ($/FT) .0 5500.0 26.00 N-80 BTC 16.59 STRING COST = $ 91'245. STRING WEIGHT = ** INTERNAL YIELD UPGRADED FOR TENSION ** ** COLLAPSE LOAD UPGRADED FOR COMPRESSION ** ** FORMULA USED: MAXIMUM LOAD THEORY ** 143000. LBS BURST PIPE IN TENSION NOT IN TENSION PIPE DEPTH WEIGHT/GRADE/JOINT (FT) .0 26.00/N-80 /BTC 5500.0 26.00/N-80 /BTC BURST PIPE DESIGN PIPE DESIGN LOAD BURST FACTOR BURST FACTOR (PSI) (PSI) (PSI) 3081. 7786. 2.53 7240. 2.35 1143. 7102. 6.22 7240. 6.34 PIPE DEPTH WEIGHT/GRADE/JOINT (FT) .0 26.00/N-80 /BTC 5500.0 26.00/N-80 /BTC COLLAPSE PIPE IN TENSION NOT IN TENSION COLLAPSE PIPE DESIGN PIPE DESIGN LOAD COLLAPSE FACTOR COLLAPSE FACTOR (PSI) (PSI) (PSI) 0. 4880. 5410. 652. 5508. 8.45 5410. 8.30 TENSION PIPE DEPTH WEIGHT/GRADE/JOINT (FT) .0 26.00/N-80 /BTC 5500.0 26.00/N-80 /BTC TENSION JOINT/BODY TENSION LOAD STRENGTH DESIGN FACTOR (1000 LBS) (1000 LBS) 117.8 603.9 5.13 -25.2 603.9 -23.97 OPERATOR: CIRI PRe CTION COMPANY LEASE: WEST FORK 1-21 SEC. 21 TWP. 6N RNG. 9W uATE: 22-OCT-90 FIELD: WEST FORK GAS FIELD COUNTY: SEWARD MERIDIAN STATE: ALASKA SURFACE CASING BURST PRESSURE VS. DEPTH 0 + .... + .... + ....+ ....+ .... + .... +--*-+ .... + .... + .... + .... + .... ~ ..... + .... + ! * + ! * + ! * + ! * + 1000 + * + ! * + ! * + ! * + ! * + 2000 + * + ! * + ! * + ! * + ! * + 3000 + * + ! * + ! * + ! * + ! * + 4000 + * + ! * + ! * + J * + ! * + 5000 + * + ! * + ! * + 6000 + + ! ! ! , 7000 + + ! ! 8000 + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + 0 1000 2000 3000 4000 5000 6000 7000 BURST DESIGN LINE (PSI) * PIPE BURST (PSI) + OPERATOR: CIRI PRL ~TION COMPANY ATE: 22 -OCT- 90 LEASE: WEST FORK 1-21 SEC. 21 TWP.'6N RNG. 9W FIELD: WEST FORK GAS FIELD COUNTY: SEWARD MERIDIAN STATE: ALASKA SURFACE CASING COLLAPSE PRESSURE VS. DEPTH 0 * .... + .... + .... + .... + .... + .... + .... + .... + .... +--+-+ .... + .... + .... + ..... · - + · + ! · + · + ! 1000 * + + · + · + ! · + · + 2000 * + + · + I · + ! · + ! · + i 3000 * + + · + ! · + ! · + ! !* + ! 4000 +* + + ! * + ! ! * + ! * + ! ! * + ! 5000 + * + + ! * + ! ! * + ! ! ! ! 6000 + + ! , ! , ! ! ! , 7000 + + ! , 8000 + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + 0 1000 2000 3000 4000 5000 6000 7000 COLLAPSE DESIGN LINE (PSI) * PIPE COLLAPSE (PSI) + OPERATOR: CIRI PRU_~CTION COMPANY uATE: 22-OCT-90 LEASE: WEST FORK 1-21 SEC. 21 TWP. 6N RNG. 9W FIELD: WEST FORK GAS FIELD COUNTY: SEWARD MERIDIAN STATE: ALASKA SURFACE CASING TENSION VS. DEPTH 0 + .... + .... + .... +--*-+ .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + ! * + ! ! * + ! ! * + ! ! * + ! 1000 + * + + ! * + ! * + ! ! * + ! ! * + ! 2000 + * + + ! * + ! * + ! ! * + ! ! * + ! 3000 + * + + ! * + ! * + ! * + ! ! * + ! 4000 + * + + ! * + ! * + ! ! * + ! ! * + ! 5000 + * + + ! * + ! * + ! ! , 6000 + + ! , 7000 + + 8000 + .... + ....+ .... + .... + .... + ....+ .... + .... + .... + ....+ .... + ....+ .... + .... + 0 100 200 300 400 500 600 700 TENSION DESIGN LINE (1000 LBS) * JOINT/BODY STRENGTH (1000 LBS) + OPERATOR: CIRI PRe ;TION COMPANY ~TE: 22-OCT-90 LEASE: WEST FORK 1-21 SEC. 21 TWP..6N RNG. 9W COUNTY: FIELD: WEST FORK GAS FIELD SEWARD MERIDIAN STATE: ALASKA SURFACE CASING CASING DESIGN DATA DESIGN CODE: 1 CASING STRING DESIGN CODE ............................ = ***************************** DESIGN FACTORS: 2 BURST DESIGN FACTOR .................................. = 1.100 3 COLLAPSE DESIGN FACTOR ............................... = 1.100 4 TENSION DESIGN FACTOR ................................ = 1.600 50VERPULL IN EXCESS OF THE STRING WEIGHT ......... (LBS) = 100000.000 CASING BURST DESIGN DATA: 7 FRACTURE GRADIENT AT THE CASING SHOE + YOUR SAFETY FACTOR .............................. (PPG) = 8 GAS GRADIENT ................................. (PSI/FT) = 10 WEIGHT OF BACKUP FLUID .......................... (PPG) = 13.000 .115 9.000 CASING COLLAPSE DESIGN DATA: 11 MUD WEIGHT CASING IS SET IN ..................... (PPG) = 12 TOP OF CEMENT .................................... (FT) = 13 WEIGHT OF CEMENT ................................ (PPG) = 14 WEIGHT OF COLLAPSE BACKUP FLUID ................. (PPG) = 9.400 .000 13.500 9.400 CASING DESIGN DATA: 15 CASING SIZE, O.D ................................. (IN) = 16 CASING (MIN. ACCEPTABLE) DRIFT DIAMETER .......... (IN) = 17 SETTING DEPTH .................................... (FT) = 18 MINIMUM SECTION LENGTH ........................... (FT) = 9.625 8.500 2150.000 .000 CALCULATION CONTROL DATA: 24 UPGRADE BURST FOR TENSION ............... (0=YES;i=NO) = 25 UPGRADE COLLAPSE FOR COMPRESSION ........ (0=YES;i=NO) = 26 CONSIDER EFFECT OF BOUYANCY ON TENSION...(0=YES,i=NO) = 27 MAXIMUM LOAD;MAXIMUM STRAIN ENERGY..(0=LOAD;i=STRAIN) = CASING TABLE NAME: 28 CURRENTLY SELECTED CASING TABLE ............ (CAS.BIN) = C:CAS.BIN OPERATOR: CIRI PR(._ ~CTION COMPANY LEASE: WEST FORK 1-21 SEC. 21 TWP. 6N RNG. 9W ~ATE: 22-OCT-90 FIELD: WEST FORK GAS FIELD COUNTY: SEWARD MERIDIAN STATE: ALASKA SURFACE CASING CASING DESIGN -- 9.625 DEPTH LENGTH WEIGHT GRADE JOINT PRICE (FT) (FT) (LB/FT) ($/FT) .0 2150.0 43.50 N-80 BTC 27.80 STRING COST = $ 59770. STRING WEIGHT = ** INTERNAL YIELD UPGRADED FOR TENSION ** ** COLLAPSE LOAD UPGRADED FOR COMPRESSION ** ** FORMULA USED: MAXIMUM LOAD THEORY ** BURST 93525. LBS PIPE DEPTH WEIGHT/GRADE/JOINT (FT) .0 43.50/N-80 /BTC 2150.0 43.50/N-80 /BTC PIPE IN TENSION NOT IN TENSION BURST PIPE DESIGN PIPE DESIGN LOAD BURST FACTOR BURST FACTOR (PSI) (PSI) (PSI) 1204. 6529. 5.42 6330. 5.26 447. 6276. 14.05 6330. 14.17 COLLAPSE PIPE DEPTH WEIGHT/GRADE/JOINT (FT) .0 43.50/N-80 /BTC 2150.0 43.50/N-80 /BTC PIPE IN TENSION NOT IN TENSION COLLAPSE PIPE DESIGN PIPE DESIGN LOAD COLLAPSE FACTOR COLLAPSE FACTOR (PSI) (PSI) (PSI) 0. 3678. 3810. 458. 3842. 8.39 3810. 8.32 TENSION DEPTH (FT) PIPE WEIGHT/GRADE/JOINT .0 43.50/N-80 /BTC 2150.0 43.50/N-80 /BTC TENSION JOINT/BODY TENSION LOAD STRENGTH DESIGN FACTOR (1000 LBS) (1000 LBS) 74.6 1004.7 13.47 -18.9 1004.7 -53.07 OPERATOR: CIRI PRe .CTION COMPANY ~ATE: 22 -OCT- 90 LEASE: WEST FORK 1-21 SEC. 21 TWP. 6N RNG. 9W FIELD: WEST FORK GAS FIELD COUNTY: SEWARD MERIDIAN STATE: ALASKA SURFACE CASING BURST PRESSURE VS. DEPTH 0 + .... + .... +--*-+ .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + ! * + ~ ! * + ! ! * + ~ ! * + , 500 + * + + ! * + t ! * + ! ! * + t ! * + ! 1000 + * + + ! * + ~ ! * + ~ ! * + I ! * + ~ 1500 + * + + ! * + ! ! * + ! ! * + I ! * + ! 2000 + * + + ! * + ! 2500 + + 3000 + + ! , 3500 + + 4000 + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + 0 1000 2000 3000 4000 5000 6000 7000 BURST DESIGN LINE (PSI) * PIPE BURST (PSI) + OPERATOR: CIRI PRO~JCTION COMPANY LEASE: WEST FORK 1-21 SEC. 21 TWP. 6N RNG. 9W DATE: 22 -OCT- 90 FIELD: WEST FORK GAS FIELD COUNTY: SEWARD MERIDIAN STATE: ALASKA SURFACE CASING COLLAPSE PRESSURE VS. DEPTH 0 * .... + .... + .... + .... + .... + .... + .... ++---+ .... + .... + .... + .... + .... + ..... . + * * * 500 +* !* !* !* ! * 1000 + * ! * ! * ! * ! * 1500 + * ! * ! * ! * ! * 2000 + * ! * 2500 + 3000 + 3500 + !. + + + + + + + + + + + + + + + + + + + + + ! ! ! ! ! ! ! ! ! ! ! ! ! · 4000 + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + 0 1000 2000 3000 4000 5000 6000 7000 COLLAPSE DESIGN LINE (PSI) * PIPE COLLAPSE (PSI) + OPERATOR: CIRI PRO~CTION COMPANY LEASE: WEST FORK 1-21 SEC. 21 TWP. 6N RNG. 9W ~ATE: 22-OCT-90 FIELD: WEST FORK GAS FIELD COUNTY: SEWARD MERIDIAN STATE: ALASKA SURFACE CASING TENSION VS. DEPTH 0 + .... * .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + ! * + ! ! * + ! ! * + ! ! * + ! 500 + * + + I * + ! ! * + ! ! * + ! I * + ! 1000 + * + + ! * + ! * + ! ! * + ! ! * + ! 1500 + * + + ! * + ! ! * + ! I * + ! ! * + 1 2000 + * + + ! * + ! ! ! ! ! 2500 + + ! ! ! ! ! ! ! , 3000 + + ! ! ! ! ! ! 3500 + + ! ! ! ! ! ! ! ! 4000 + .... + .... + .... + .... + .... + ....+ .... + .... + .... + .... + .... + .... + .... + .... + 0 200 400 600 800 1000 1200 1400 TENSION DESIGN LINE (1000 LBS) * JOINT/BODY STRENGTH (1000 LBS) + MILPAkX W DRI£LING FLUIDS A Baker Hughe~.cx~rn~y ENSR TeL_,nical Information Ddlling Fluids Recommendations STERLING TEST INTERVAL: HOLE SIZE: CASING SIZE: MUD TYPE: 0 - 2000' 12-1/4" 9-5/8" Spud Mud MUD PARAMETERS WEIGHT: 8.8 - 10.0 VISCOSITY: ±150 Sec/Qt pH: 9.0 - 9.5 PV: 10 - 14 YIELD POINT: 20 - 30 FLUID LOSS: N.C. For the purposes of this program a 600 barrel active system will be used in all calculations. Prior to spud, strap pits and trace guns, discharge and suction lines, etc. Fill the pits with fresh water and check both the chloride and calcium levels. Treat out excessive calcium with small additions of Soda Ash (1/2 - 3/4 ppb) until -+40 mg/L. Page I MILPAJ. X TM DRILLING FLUIDS A Baker Hughes.company I ENSR: Sterling Test Interval: 0 - 2,000' TeL nicai Information Drilling Fluids Recommendations For the first bit run mix the surface system to maximum capacity adding Milgel of sufficient quantity (25 - 30 ppb) to yield a viscosity of _+200 sec/qt. The 150+ vis needed for in-field drilling should be adequate here due to the decreased size and amounts of gravel. Prior to spud, run this surface system briefly through the solids control equipment checking for leaks, etc. Drill ahead maintaining volume and sufficient yield point for good hole cleaning. Viscosity and yield point may be dropped back depending on hole conditions as surface gravel subsides. A viscosity of 100 sec/qt should suffice once it's determined that nothing extraordinary is occurring. Gravel of 10- 15 mm should be present to about 400' - 500', then dropping to 2 - 6 mm until TD. A yield point of 20 will be adequate after initial gravel is encountered. Keep mud weight at necessary levels with barite additions. There is the possibility that abnormal surface pressures may exist. Run all solids control equipment as necessary to keep sand content : 1% to improve the quality of the mud and reduce wear on pumps. Ben Ex may be used at a 5'1 ratio with Milgel as a bentonite extender and supplementary viscosifier after the first bit run. Page 2 MILPAJ~KTM DRILLING FLUIDS A Bak~ Hughes' company TeLnnical Information Drilling Fluids Recommendations ENSR' Sterling Test Interval' 0 - 2,000' Run and cement 9-5/8" casing. ANTICIPATED PRODUCT USAGE FOR 12-1/4" HOLE PRODUCT GENERIC NAME UNIT SIZE AMOUNT Milgel Soda Ash Ben Ex Mil-Bar Benton i te Soda Ash Acrylic Polymer Barite (For 10.0 ppg) 100# SX 100# SX 2# SX 100# SX 250 SX 8 SX 25 SX 800 SX Page 3 MILPAkKTM DRILLING FLUIDS A Baker_Hughes'company Tec, nical Information Recommendations ENSR: Sterling Test INTERVAL: HOLE SIZE: CASING SIZE: MUD TYPE: 2O00' - 6,000' 8-1/2" 7" New Drill (Co-Polymer) MUD PARAMETERS WEIGHT: VISCOSITY: pH: PV: YIELD POINT: FLUID LOSS: 8.8 - 9.4 40 - 46 Sec/Qt 8.0 - 8.5 3- 10 10- 15 10 - 12 CC/30 MIN API, Reduced to : 6 CC/30 MIN API Before drilling out the cement the spud mud should be evaluated for percent low gravity solids and active bentonitic clays. If the mud is found to be clean, and it should be if proper solids control techniques are followed, the New-Drill may be added directly to the old mud. This should save both time and money, eliminating the necessity of building a new system from scratch. We are trying to avoid drilling out with the polymer system as a matter of principle although the calcium and pH generated by drilling cement will produce significantly less adverse rheological effects than expected when using a low-solids mud. The viscosity increases should be polymer viscosity. Page 4 MItPAkKTM DRILLING FLUIDS A Baker Hughes company ENSR: Sterling Test Interval' 2,000' - 6,000 Te . nical Information Drilling Fluids Recommendations Supplement Drispac and Ligco (lignite) at 2 - 3 ppb for fluid loss and rheological control. Add Caustic Soda as necessary to bump the pH to 9.0 - 9.5. The Soda Ash alone should do this so little Caustic will be necessary. Some may be added simultaneously with the Ligco. Add Mil-Bar (barite) to bring up the weight to desired specifications. Prior to drilling out the 9-5/8" casing shoe, pretreat the surface system with i ppb Bicarb. Dump any heavily contaminated returns and treat out residual calcium while drilling ahead. Drill ahead maintaining your polymer concentration. To help decide on the amount of New-Drill HP addition, inspect the drilled cuttings regularly. Cuttings that are sticky or visibly hydrated are indicative of low polymer concentration. If the amount of cuttings has visibly decreased for a given ROP, then further additions are advisable. The most fundamental method to ensure polymer concentration is to keep track of water additions. If no water meter is available then manually check flow rate and record in this manner. Page 5 MILPARKTM DRI&tlNG FLUIDS A I~k~ hughe~ company ENSR: Sterling Test Interval: 2,000' - 6000' Tec. nicai Information Drilling Fluids Recommendations To use a cross-reference, run the ammonium degeneration test procedure for polymer content. If it is desired to smooth out rheological properties, New Thin can be added. New-Thin is a low molecular weight polyacrylate thinner that works well in this system. New-Thin can be used for the same purpose but does not have the dispersing effects of lignosulfonates and comparable products. A principle benefit of New-Thin is that it does not require Caustic (NaOH) to solubilize or activate it. Increased hydroxyl (OH-) ion content exerts a highly dispersive effect on reactive formations. Maximum use of solids control equipment and techniques are fundamental to operating this system to its optimum efficiency. Running the finest shaker screen possible will act as a front-line defense against solids build-up. Any drilled solids eliminated in the first pass cannot recirculate, be broken down and lead to future rheological difficulties. If maintaining volume and/or weight does become a problem, switch the unit to the mud-cleaning mode if possible. Page 6 MILPA&KTM DRILLING FLUIDS A IBsk~'_Hugh~ ~:~np~y Tec, nical Information Recommendations ENSR- Sterling Test Interval: 2,000' - 6'000 Run all solids control equipment to their maximum efficiency. Add all water below the shakers to avoid washing in unwanted drilled solids. Run only 200 mesh screens on the mud cleaners to give the maximum cut and run desilters as much as possible. Run the centrifuge as often as necessary to keep mud weight and solids in line. Slow the feed to achieve maximum cut. Desilter should be operated so they are processing 120% - 140% of returns. Be sure that there is not excessive mud loss from the desilting units to minimize subsequent wet discharge. If losses occur, switch units to mud-cleaning mode. If the initial mud weight is set higher that 9.8 ppg, then you will likely have to start directly on the mud cleaners or barite usage will be high. Add all water below the shakers and not through the spray bars so as not to wash in any unwanted drilled solids. Any intentional increase in weight should be done with barite. Incorporation of native sol ids to use as a foundation for this system runs contrary to established technology. Page 7 MILPAL.¢TM DRILLING FLUIDS A Baker Hughes.company nical information Recommendations ENSR' .Sterling Test Interval' 2,000' - 6,000 With recirculation and the particulate breakdown that ensues, rheological control becomes increasingly difficult. This problems can be compounded if there are relatively high penetration rates or by the lack of dispersing agents. If native solids are incorporated and high yield points and progressive gels develop, this may lead to an increase in E.C.D. (Equivalent Circulating Density) and result in loss of circulation in the event of encountering a sensitive formation. Any money saved through the use of native solids can be quickly lost. Loss of circulation has not been a significant problem in this area but this should be addressed. Solids laden muds have also proved to be damaging to pay zones via pore throat plugging, etc. Depending on the formation's exhibited sensitivity, the yield point and circulation rates will have to be manipulated in order to control the E.C.D. The E.C.D. can be adjusted through the manipulation of yield points, circulation rates, mud weights, etc. These will necessarily be adjusted on location depending on hole conditions. After logging run and cement 7" casing. Page 8 DRItLING FLUIDS A E~k~ Hughes company Te _ nical Information Drilling Fluids Recommendations ENSR' Sterling Test Interval' 2,000' - 6,000' ANTICIPATED PRODUCT USAGE FOR 8-1/2" HOLE PRODUCT GENERIC NAME UNIT SIZE AMOUNT Milgel Soda Ash Mil-Bar Drispac Caustic Soda Bicarb of Soda New Thin D Ligco New-Drill HP Bentonite Soda Ash Barite (For 10.0 ppg) 100# SX 100# SX 100# SX Polyanionic Cellulosic Polymer 50# SX Sodium Hydroxide Sod i um B i ca rbona te Sodium Polyacrylate Lignite Polyacryl ami de - Polyacrylate Co-Polymer 50# SX 100# SX 55# SX 50# SX 50# SX 100 SX 6 SX 500 SX 80 SX 20 SX 15 SX 15 SX 50 SX 30 SX CONTINGENCY PRODUCTS Sha 1 e-Bond LD-8 Gilsonite Resin Aluminum Stearate in a Propoxylated Oleylalcohol 50# SX 5 Gal Can 80 SX 6 CN Page 9 ClRI PRODUCTION COMPANY WEST FORK 1-21 DEVELOPMENT WELL Program Basis . , , , . Hole Sizes, Casing and Casing Points Hole Size Casing Description Programmed Casinq Points 17-1/2" (or driven) 12-1/4" 8-1/2" 13-3/8", 54.5 lb, N-80, BTC 9-5/8, 43.5 lb and 53.5 lb, N-80, BTC 7", 26 lb and 29 lb, N-80, BTC 120ft KB 2,150 ft KB 5,500 ft KB (liner) Drilling Rig' Grace Drilling Company Rig 211 (Kremco K7501) will be used to drill the well. Rig description is attached. The maximum anticipated mud weight is 10.0 ppg at the Sterling interval. No overpressured zones are anticipated in this well. Maximum anticipated pressure at TD (5,500 ft M.D. - 5,500 ft TVD) is 2706 psi based on normal gradient of 0.465 psi/ft plus a 0.027 psi/ft safety factor. Maximum anticipated surface pressure - 2074 psi based on column of gas to surface from TD and a gas gradient of 0.115 psi/ft. This well will test the Sterling formation. Estimated formation tops and key depths: o Measured Depth TVD Sterling A 4,500 4,500 Sterling B 5,000 5,000 Downhole Disposal of Drillinq Fluids CIRI Production Company plans to dispose of waste drilling fluids by subsurface injection down the 9-5/8" annulus. A General Wastewater Disposal Permit has been requested from ADEC covering this activity. Prior to any actual injection of drilling fluids, the operator will meet all requirements of 20 AAC 25.252. . Shallow Gas Considerations This well lies between the surface locations of the abandonded SOCAL West Fork 233-16 (1962) and Halbouty #1-B (1960) wells. No shallow gas was encountered in these wells or in the Halbouty West Fork 42-20, Union Sterling Unit 43-28, and AMAREX S.W. Fork 13-29 wells which were also drilled in the West Fork area. Since the CIRI West Fork, 1-21 well will penetrate the same stratigraphic section as was encountered in these surrounding wells, it is proposed that the well logs and histories from these wells satisfy the requirements of 20 AAC 25.061 pertaining to the identification of shallow gas. , The attached Plan of Operations describes the key elements of the overall project and gives a proposed schedule of activities. DRILLING RIG DESCRIPTION Grace Drilling Company Rig 211 will be used to drill the CIRI West Fork 1-21 development well. Rig specifications and other equipment are described in the following sections. Drilling Equipment Drawworks Kremco, K7501,860 HP with 1-1/8" drilling line, 17-7/8" x 35-1/2" grooved drum with enclosed cooling system, 6 forward and 1 reverse positions, sandline drum for 17,000-foot 9/16 sandline. Power: Two 3408 Caterpillars with Allison TC580 torque converters. Hydromatic: 22' T.R.I. with air over water controls. Mast Kremco 116 foot x 350,000 gross rated capacity. Racking Board: 10,000 foot 4-1/2" tubing or 20,000 foot 2-1/8" tubing capacity. Traveling Block: 150 ton McKissick Model 764 four sheave block. Substructure Kremco slingshot, 280,000 stand back, 350,000 APl gross, 18-1/2 ft R.T. to G.L. Rotary Table: 17-1/2" IDECO driven through a deep case to the drawworks, split square drive master bushing with a 350,000 APl gross load capacity. Mud Pumps No. 1 Mud Pump: PZ9 Gardner Denver with a K20 pulsation dampener, 3"x 5,000 psi shear release valve and a 4" x 4,000 psi gates bumper hose powered by a 398 TA Cat. No. 2 Mud Pump: 214P Oilwell powered by twin 671 Detroit diesel engines. Suction System: Pressurized by a 4" x 6" 50 HP Galigher pump. Mud Pit 500 bbl active system with 20 bbl sand trap, 50 bbl pill pit and three 140 bbl active pits. Shale Shaker: (1) Brandt dual, tandem 800 GPM. Mud Hopper: Pioneer Model S-800. Submarine Guns: Three Medearis 3" revolving guns. Degasser: Drilco See-FIo Note: Additional solids control equipment will be added to facilitate maintenance of the drilling fluid system that will be used on this well. Choke Manifold 3"x 5,000 psi choke manifold system on control and diverter side. Has space for a hydraulically-operated choke and has a manual choke and manifold through an 8" expansion chamber to the gas buster or reserve pit. BOP Stack (1) 11" x 5,000# Double Gate. (1) 11" x 5,000# Annular. (1) 13-5/8" x 5,000# Annular - Diverter (1) Lot 10-3/4" Diverter lines. BOP Closing Unit One Koomey 120 gal. 3,000 psi working system with twelve 10-gal. accumulator bottles and nitrogen backup system: five station control with five station air-operated remote control. Generators Two 3408 Caterpillar (1) 275 kW prime with (1) 275 kW standby, wired through a synchronizer and a master control panel. Water Tank 350 bbl insulated tank with 2" steam coil and raw steam connector house in one end for accumulator. Boiler One 100 HP Lister Boiler. Air Heater One four million BTU/hr Lister air heater with ductwork to cellar motor room, mud pump room, and mud pit. Drill String 100 Jts 3-1/2" drill pipe grade "E" with 3-1/2" IF connections. 18 Jts 6-1/4" x 23/4 drill collars with 4-1/2" H-90 connections. (1) lot bit sub and xo sub drill collars to drill pipe. Swivel TSM 150 ton swivel with 6-5/8" upper Kelly Cock. Kelly: 4-1/2" x 42' with lower Kelly Cock and Varco square bushings. Kelly Spinner: Foster Model 77 hydraulic Kelly Spinner with forward and reverse. Rotary Tools Tongs: J.J. Type "B" short lever tongs c/w 3-1/2" to 10-3/4" lug jaws. Slips: Varco SDML c/2 3-1/2" inserts, Varco DCS-L 5-1/2" to 7" DC slips. Rotary Bushings: Varco 17-1/2" solid drive bushing with 9-5/8" x 10-3/4". Mud Bushings: B.J. mud bucket with 3-1/2" and 4-1/2" seals. Rotary Tools (Cont'd) E-Z Torque: Two E-Z torque rated at 15,000 f. lbs with enough speed to accommodate a spinning chain, if necessary. Hillman Kelly: 5500H power tongs. Monitoring Equipment Torque Indicator: FA9-21 Hydromech. Mud Pressure: Martin Decker GM4-502. Tong Torque: Martin Decker H63-28. Weight Indicator: Martin Decker Clipper AA15. Mud Pit Totalizer: Seven Pin Recorder: Dog House Two 6' x 20' dog houses on rig floor. One 9.5' x 40' crew change/parts dog house with toilet. Two 8' x 40' dog houses with generator, boiler, and shop. Rig Mats Twenty 20' x 8' x 6' steel reinforced rig mats. Winterization Norseman canvas shelter over motors, drawworks, and mud pits. Hydraulic Tuggers Two Kremco tuggers rated at 6,500 lbs with 1/2" cable. Catline Two catlines, with one being rigged up through a 12-foot boom located above the monkey board. Wireline Survey Unit Kremco hydraulic with a 20,000-foot wireline drum. Fuel Tank 8,000-gal. tank with transfer pump. The following figure shows the typical layout of Grace Rig 211. 47' ,i JNIT i WATER ! GENERATOR'S [ 7'-~' 1 ! ! CHANGE HOUSE ! EiOILER'S SHOP 64' .--- HYDRAULIC JACK I P2-9 MUD PUMP I ! i,i,/l' " SUBSTRUCTURE CAT WAI. K 57' 55' 178' N.T.$. Typical on-site layout of Grace Drilling Company Rig 2 1 1 PLAN OF OPERATIONS ClRI PRODUCTION COMPANY CIRI WEST FORK 1-21 Operator CIRI Production Company Anchorage, Alaska Prepared by ENSR Consulting and Engineering Anchorage, Alaska August 1990 1.0 STATEMENT OF PURPOSE The project covered by this Plan of Operations consists of drilling one and possibly two development wells from a surface location on Kenai Native Association (KNA) lands to evaluate the gas potential of the Sterling formation in the area of the West Fork Gas Field, Kenai Peninsula, Alaska. The initial well will be either a straight hole or slightly deviated, as final geologic interpretations dictate. Total vertical depth will be approximately 5,500 feet. In the event of a discovery, the well will be produced into an existing Enstar Natural Gas Company pipeline which traverses the project area. Production facilities would be situated on the same gravel drilling pad as the well and no additional land would be required. It is estimated that these production facilities would be utilized for an estimated field life of between 15 and 20 years. If a second well is necessary to fully develop the field or to pursue a different geological objective, it would be directionally drilled from the same pad and would therefore have negligible additional impact on the surrounding area. The project will be operated by ClRI Production Company (CPC) of Anchorage, Alaska, acting for themselves as working interest owner. ARCO Alaska, Inc. has an overriding royalty interest in the project. CPC will be the permittee of record. CPC has contracted ENSR Consulting and Engineering of Anchorage, Alaska to manage the project and provide the required engineering, regulatory, and supervisory services. The activities described in this Plan of Operations will be conducted in a manner consistent with the Alaska Coastal Zone Management Program, the refuge management practices of the Kenai National Wildlife Refuge and requirements of KNA. 2.0 SITE LOCATION The wellsite is approximately 50 air miles south of Anchorage and 15 miles east of Kenai, Alaska. -The surface location will be on a 200 by 200 foot gravel pad which will be constructed adjoining the present gravel road, which runs between the Swanson River Road and the Sunken Island Lake Campground. The surface estate is owned by the KNA. The oil and gas rights under all of Section 21, except the SW 1/4 (160 acres), as well as under surrounding sections are owned by Cook Inlet Region, Inc. The surface use in the area is generally managed in a manner consistent with the objectives of KNA and the Kenai National Wildlife Refuge, within whose boundaries the entire prospect lies. The regional setting of this location is shown in Figure 2-1. The subject well, CIRI West Fork 1-21, will be drilled from a surface location in the SW 1/4, NE 1/4, Section 21, T6N, R9W, SM. The bottomhole location will be the same as the surface location. Preliminary coordinates of the initial test well are shown below. Surface and Bottomhole Location (Straight Hole Option) Geodetic Position Section Line Reference ASPC Zone 4 (NAD 1927) 2,158 ft FNL Sec 21 X = 345,340.64 Longitude 150051'37.64'. 482 ft FEL Sec 21 Y = 2,411,569.54 Latitude 60035'53.36.' If final geological and geophysical interpretations indicate the bottomhole location should be deviated from the surface location shown above, the revised bottomhole coordinates will be provided to the Alaska Oil and Gas Conservation Commission as part of the Application for Permit to Drill. '~ENAI ~iSTERLING z'c=_ x.. C4"IISAK :ISLAND FIGURE 2-1' Regional Setting, CIRI Production Company 'CIRI WEST FORK 1-21' N.T.S. 17' 2O 15 ALF LAKE FORK 1-21" KENAI L A£ V OO K NATIONAL WILDLIFE -I-- AVKA LAKE + + REFUGE 29 28 27 26 + -t- + SCALE IN MILES //~ ~V~LGAGARA '~ ,~4 , , 3,5 GATE _....4 TO 24 25 I T6N I FIGURE 2-2: LOCATION MAP, CIRI PRODUCTION COMPANY "CIRI WEST FORK 1-21" 3.0 SITE DESCRIPTION The proposed drillsite is located in a well-drained area at an elevation of approximately 280 feet. The area is covered by a dense growth of spruce, birch, alders, and other vegetation. While some areas of obvious wetlands designation occur in the project vicinity, the drillsite area itself does not qualify as a wetland. Application for exemption from Department of the Army Section 404 permitting requirements will be made. The area exhibits well drained glacial topography with native grasses and brush covering the glacial soil beneath and between trees. The area was not affected by the 1969 burn, and consequently, some isolated mature timber is present. The drillsite location was chosen so as to minimize damage to seed trees and other mature vegetation. Access to the drillsite can be controlled by a gate on the Sunken Island Lake road near the junction with the Swanson River road (see Figure 2-1). Controlled access will be maintained during drilling operations if required by the surface landowner (KNA). The drillsite is easily accessible by car over the previously described dirt road system. These roads will require some grading maintenance during the construction and mobilization/ demobilization phases of the program. Such road upgrades will be done in conjunction with the site operations by ENSR Consulting and Engineering as CIRI Production Company's contract operator. 4.0 PROJECT SCHEDULE The proposed project schedule is shown in the following figure. Non-objection to the project has been obtained from the landowner (Kenai Natives Association) and the U.S. Fish and Wildlife service. It is anticipated that all permit applications can be completed by October 20, 1990. Site construction will begin at the end of October 1990, and mobilization of the drilling rig will follow as soon as the drilling pad is completed. Drilling is scheduled to be at total depth by the last week in November 1990, with subsequent activities dependent on the analysis of data from the first well. The project recognizes a 20-day drilling and evaluation (not including testing) window for the first well. This time frame includes a modest contingency for unforeseen downhole or mechanical events which sometimes characterize development drilling. Testing and completion activities are estimated to add from 10 to 15 days. Subsequent activities (i.e., second well) are dependent on the outcome of the first well. Activity July 1990 August 1990 September 1990 October 1990 November 1990 December 1990 January 1991 Permitting, Surface Use Agreement, etc. j~jj~ jj~jjj~jjjj~ ~jjjjJjj~jjj~ jjjjjjjjjj~ Engineering, Planning, and Contracting for ~ ~~jjjjjjj~ ~ JJJJ~ Services .... , ,, Moose Season (no on-site activity) jjjjjj~j~Jj~ Site Construction- includes mobilization/ JJJ~ demobilization of construction equipment Mobilize Drilling Rig and Third-Party Equipment ~ Drilling CIRI West Fork 1-21 ~ Possible Testing of CIRI West Fork 1-21 ~ Hydrotest and Upgrade West Fork Pipeline ~ P&A Comfier PSd~ P&A or Completion 1 Earliest Startup for Drilling Second Well ~ ~ (skid ri~l-same pad) Proposed Schedule of Activities for CIRI Production Company, CIRI West Fork 1-21. DRILLING PROGNOSIS The drilling program for the CIRI West Fork 1-21 well is covered in detail in the Application for Permit to Drill, filed with the Alaska Oil and Gas Conservation Commission. In this application, the drilling mud program, casing design, formation evaluation program, cementing programs, hydraulics programs, and other engineering material is presented in detail. Much of this information is of a proprietary nature. The following sections cover the drilling program within the limits of public information. 1.0 Geological The CIRI West Fork 1-21 well will be drilled from a surface location in the SW 1/4, NE 1/4, Section 21, T6N, R9W, SM. The well is programmed as a straight hole or slightly deviated hole to the east. The total depth will be 5,500 ft (true vertical depth) or -5,220 ft subsea. The Sterling A and B sands are the principal exploration target. These sands are channel deposits with good porosity and permeability. They are known to be gas productive when favorable structural position is combined with the development of good reservoir characteristics. The well is expected to bottom approximately 500 ft below the top of the Sterling B sand. 1.1 Mud Logging and Collection of Samples A qualified contractor will pedorm the mud logging service. A computerized mud logging unit will be employed, which will supply drilling engineering data, formation gas and hydrocarbon monitoring, and lithologic information on a continuous basis. The mud logging contractor will also collect, wash, and prepare cuttings samples as directed by the on-site geologist. A comPlete mud log and lithologic log will be prepared consisting of a detailed record and description of the sequence of strata penetrated, all shows of hydrocarbons, drilling penetration rate, and other salient information. Drill cuttings will be collected every 30 ft from spud to the 9-5/8" casing point and every 10 ft thereafter. Both washed and unwashed samples will be collected in sufficient quantities to supply all parties designated by the operator. In addition, cuttings samples may be collected for both geochemical and paleontological analysis if required by the operator. A mud sample will be collected at each casing point and at each significant change in the mud system. A complete set of. washed cuttings will be supplied to the State of Alaska in accordance with AOGCC regulations [20 AAC, 25.071(b)(2)]. 1.2 Wireline Logging The wireline logging program will be kept flexible to accommodate the specific formation evaluation objectives of the operator. The following logging program is representative of the wireline log data desired. · Conductor Hole: No logs · Surface Hole: 9-5/8" casing point (approximately 2,150 ft RKB to shoe of conductor casing Dual Induction/Gamma Ray/SP · Total Depth: TD back to 9-5/8" casing point Dual Induction-SFL/Gamma Ray/SP/ Borehole Compensated Sonic Lithodensity/Gamma Ray/Compensated Neutron Micro Resistivity Log Sidewall Cores (optional) FMS/Dipmeter (optional) A cement evaluation log will be run following the cementing of the 7" casing string. 1.3 Sidewall Cores Sidewall cores may be obtained in specific zones for reservoir and lithological analysis at the discretion of the operation. If sidewall cores are taken, an excess will be planned in order to ensure full coverage. A preliminary lithologic description of any sidewall cores will be made at the wellsite and distributed as directed by the operator. No conventional cores are anticipated to be cut during the drilling of this well. 2.0 Hole Sizes, Casing and Cementing Programs The casing and cementing programs for the CIRI West Fork 1-21 well are described in detail in the Application for Permit to Drill. The design is consistent with good oilfield practice and all casing weights and grades are sufficient to resist anticipated downhole pressure differentials and mechanical loading. Hole and casing sizes are described below: Hole Size Depth (MD) Casing Description 17-1/2" or larger ~ 120 ft Conductor 13-3/8", 54.5 lb, N-80 8R, or (or driven) other suitable weight and grade for conductor. Conductor will be set during site construction phase. 12-1/4" ~ 2,150 ft Surface 9-5/8", 43.5 lb, N-80 BTC 8-1/2" ~ 5,500 ft Production 7", 26/29 lb, N-80 BTC The cementing programs for each of these casing strings are summarized below. Casing Cementing Program Conductor No cement, if driven. If augered, cement to surface with Class G (from top). 9-5/8" Surface Cement to surface using Class G blend with prehydrated gel. 7" Production Cement to at least 1,000 ft above top of highest potentially productive horizon. Use Class G blend with friction reducing and fluid loss additives. The following wellhead components and associated BOP equipment will be utilized during the drilling of CIRI West Fork 1-21: Csg Size Wellhead Section BOPE Description 13-3/8" Conductor 13-5/8 x 5,000 psi wp weld-on 13-5/8" 5,000 psi wp flange diverter 9-5/8" Surface 9-5/8" SOW Csg head 5,000 psi 11" 5,000 psi wp BOP wp RSRRA 7" Production 7" x 9-5/8" 5,000 psi wp tubing 11" 5,000 psi wp BOP head RSRRA 3.0 Drilling Fluid Program In general, an undispersed bentonite spud mud will be used through the 9-5/8" casing point (2,150 ft RKB). Drilling the next hole section to the approximate 5,500 ft TD will use a Iow-solids non-dispersed mud system with additions of polyanionic polymer. Additions of dispersants, if required, will be minimized. A 3 percent KCI addition will be made from approximately 4,500 ft to TD to enhance clay inhibition and minimize formation damage through the target horizons. This drilling fluid system containing polymers and co-polymers of cellulose, acrylamide-AMPS and specialty additives including surfactants is a freshwater-based system and has the properties necessary to stabilize the hole through coal and other ragged sections. Desired mud properties will be maintained under the direction of the on-site drilling foreman and qualified mud engineer. Optimum solids control and fluid loss will be maintained, which is critical to successfully drill the anticipated stratigraphic section. The drilling fluid program is summarized below: Weight Viscosity Fluid Loss Depth Type Mud lbs/gal (secs) (cc) 0 - 2,150 Spud Mud 8.8 - 9.5 + 150 N.C. 2,150 - 5,500 Co-Polymer 8.8 - 9.4 40 - 46 6 - 12 Quantities of basic mud materials maintained on location will be patterned after previous Cook Inlet basin experience and as dictated by good oilfield practice. Contingency planning requires that significant inventories of barite and lost circulation material be on location at all times. The following table lists the anticipated drilling mud and components for the CIRI West Fork 1-21 well. Name Functions BAS04 Density Bentonite Filtrate control and viscosity Bentonite Extender Filtrate control and viscosity NaOH pH control NaCO3 Remove cations Lignosuifonate Thinner and dispersant Lignite Filtrate control and thinner Polyanionic Polymer Filtrate control and thinner NaHC03 Cement contamination CaOH Flocculation and alkalinity control Aluminum Stearate Defoamer Fibers Lost circulation material Mica flakes Lost circulation material Walnut hulls Lost circulation material Triglycerides Anionic surfactants KCI Lubricant Drilling soap Clay inhibition 4.0 Blowout Prevention Program and Equipment All operating procedures on the rig, whether automated or controlled by Contractor personnel, are specifically designed to prevent a loss of well control. The primary method of well control utilizes hydrostatic pressure exerted by a column of drilling mud of sufficient density to prevent an undesired flow of formation fluid into the well bore. In the unlikely event primary control is lost, the following surface blowout prevention equipment would be used for secondary control: Diverter System: A 13-5/8" 5,000 psi W.P. annular diverter system will be nippled up on a 13-5/8" weld-on flange on the conductor casing prior to drilling the 12-1/4" surface hole. The 10' diverter lines will run to discharge points downwind from the drilling rig. The diverter lines will be equipped with hydraulically actuated valves which will open the downwind diverter line concurrently with the closing of the annular preventer. In the unlikely event that high pressure, Iow volume surface gas is encountered, the wellbore fluids can be diverted downwind and gas vented to the atmosphere. BOP Stack: After drilling the 12-1/4" surface hole to approximately 2,150 ft, running and cementing the 9-5/8" casing, a 9-5/8 x 5,000 psi W.P. SOW casing head will be installed. The blowout preventer stack for the remainder of the program will then be as follows: 11" APl 5,000 psi W.P. BOP stack with two sets of pipe rams, a drilling spool, one set of blind rams, and an 11" APl 5,000 psi W.P. annular preventer. This BOP stack will be hooked up to a 5,000 psi W.P. two- choke manifold. This BOP stack is activated by a 120-gallon, 3,000 psi accumulator unit with a 400-gallon fluid reservoir. Both hydraulic and nitrogen backup systems are provided. All blowout prevention equipment and testing procedures will meet APl Recommended Practice No. 53 and Alaska Oil and Gas Conservation Commission specifications. All blowout prevention equipment tests will be conducted with a non-freezing fluid when the ambient temperature around the BOP stack is below 32°F. Tests of all blowout prevention equipment will be conducted at least weekly and before drilling out the shoe of each casing string. Function tests and crew drills will be conducted daily. Primary well control will be maintained by over-balancing formation pressure with drilling fluid. Automatic and manual monitoring equipment will be installed to detect any abnormal variations in the mud system and drilling parameters. A mud logging unit, manned by experienced personnel, will be in continuous use throughout the drilling operations and will monitor formation pressure, hydrocarbon shows, and loss or gain in mud pits. In the event that the well kicks, the blowout preventers will be used to shut in the well immediately and confine the pressure within a closed system. The casing program is designed so that any anticipated formation pressure can be shut in at the surface. The ENSR representative assigned to the drill site will have extensive training including MMS-approved blowout prevention training school, together with actual experience in controlling and killing kicks. Such training is an ongoing program of ENSR Consulting and Engineering. These personnel will be further supported by well-trained rig crews. Pressure resulting from a kick will be circulated out using industry approved methods, and the well will be restored to its normal operating condition. Leakoff tests or formation competency tests will be made after running each string of casing below the conductor pipe, both for well information and as an indicator of the depth at which the next string of casing will be required. 5.0 Testing Program If a decision is made to flow test the well, a testing program will be written at that time based on the known downhole conditions. Pressure activated test tools will be employed. Recovered liquids will be stored in portable tanks brought to the site for that purpose and gas will be flared from flare booms on the rig. All required permits will be obtained in advance of flaring. 'Produced fluids (i.e., formation water) will be reinjected (bullheaded) back into the formation from which they originated or they may be disposed of by injection down the 9-5/8" x 7" casing annulus. All permit restrictions and stipulations will be observed during any of these operations. EMERGENCY SITUATIONS AND CRITICAL OPERATIONS The most probable factors that could result in the curtailment of operations while drilling at the West Fork location will be extreme wind and storm conditions. Conditions of a magnitude to curtail oprations would be considered a 100-year event. As a general rule, no critical operations will commence when the wind velocity approaches the design limits of the drilling mast. Operations sensitive to extreme storm conditions are drilling, tripping pipe, running casing, wireline logging and drill stem testing. No drilling operations will commence or be continued when any of the following conditions exist: . Drilling will not begin until the ENSR Drilling Supervisor is satisfied that the rig is properly rigged up to begin operations and all required materials and third-party equipment are on location. . When there is an insufficient supply of drilling fluid materials on location required for pressure control, in the event the well kicks. . When sufficient emergency containment and cleanup equipment is not on location or inoperative. . When the manpower required to safely conduct the drilling operation is not available. . When any critical equipment needed to assure a normally safe operation is not operative. Relief Well Plan In the unlikely event that primary and secondary well control were lost and a blowout occurred which could not be contained, the rig may have to be abandoned to prevent loss of life. This is an extremely remote possibility, due to the extensive precautions taken to prevent such an occurrence. Fundamental to these precautions is the training required for all personnel involved in development drilling operations and the safety equipment on the rig itself. All supervisory personnel will be trained in accordance with Subpart O of "Oil and Gas and Sulfur Operations in the Outer Continental Shelf (Final Rule)" and MMS Training Standard MMS-OCS-T1, "Training and Qualifications of Personnel in Well Control Equipment and Techniques for Drilling Offshore Locations (Second Edition)." A list of personnel and training received will be available on the rig. If subsequent efforts to control the well failed, a relief well would be required. This relief well would be drilled from another land rig currently available in the Cook Inlet Basin (i.e., Grace Drilling Rig 150 or 160). The relief well would be directionally drilled to intersect the wild well. Sufficient wellhead assemblies, tubulars, and materials (i.e., mud, cement, bits, fuel, etc.) are available in the Cook Inlet area to rapidly mobilize for a relief well program. The Relief Well Plan is discussed further in the SPCC Plan. QUALIFICATIONS OF KEY PERSONNEL All wellsite operations will be under the direct supervision of the on-site drilling foreman or engineer. A wellsite geologist will also be on-site to supervise mud logging, sample collection, and sidewall core recovery. Both the engineer and the geologist will assure quality control in wireline logging operations. Additional operations personnel will be at the wellsite as specific specialized activities dictate. Daily reports will be transmitted to the offices of the CIRI Production Company and frequent telephone and data fax communications will monitor activities at the wellsite. Training and Drills Contractor personnel involved directly in drilling operations (including rotary helpers and derrickmen) will be trained in well control methods and in detection of abnormal pressures. Such training will be completed in approved company or industry schools before drilling is commenced. Blowout prevention drills will also be conducted as required by the Alaska Oil and Gas Conservation Commission. A list of personnel and their completed training will be maintained on the drilling rig and will be available on request. All supervisory drilling personnel will be MMS certified as operator's representatives both in surface and subsea applications. All supervisory personnel engaged on the project will have received Oil Spill Containment and Cleanup training. Fire Drills: Procedures for emergencies such as fires will be posted on the rig and in the crew change house. Specific emergency responsibilities for crew members will also be posted at appropriate and conspicuous places on the drilling rig. Fire, kick, and H2S drills will be conducted periodically for all crew members. Safety Meetings: Safety meetings will be conducted periodically to make crews aware of safety procedures and to review potential sources of accidents and the means of preventing them. Accident causes and corrective measures to be taken in the event of accidents will be discussed. An EMT/Environmental Monitor person will be on the rig at all times and will coordinate the safety program with supervisory personnel. Fuel Transfers: Fuel quantities will be monitored daily. Fuel transfers from trucks to the rig are estimated to occur weekly. A fuel transfer plan has been developed which addresses fuel flow diagrams, valving sequences, safety precautions, and transfer procedures. One person will have the responsibility for all fuel transfers and he will be thoroughly trained in the above procedures. No fuel transfers will be made without this responsible party in attendance. Persons in Charge The person in charge of the overall operation, including on-site operations, is: R. C. Gardner Regional Director of Technical Services ENSR Consulting and Engineering 750 West Second Avenue, Suite 100 Anchorage, Alaska 99501 (907) 276-4302 (office) (907) 243-7554 (home) Operator's contact (CIRI Production Company)is: Kevin A. Brown Manager, Engineering and Operations CIRI Production Company 2525 "C" Street Anchorage, Alaska 99503 (907) 274-8638 (office) (907) 346-1596 (home) SUMMARY DRILLING PROGNOSIS . Construct location as per construction specifications. Set 12 ft diameter, 10 ft deep corrugated steel cellar. Drill 17-1/2" or larger hole or drive 13-3/8" conductor to 120' RKB. 2. Move in and rig up Grace Drilling Company Rig 211. ! Install, weld-on flange on 13-3/8" conductor, and nipple up 13-3/8" 5000 psi diverter system as per diagram in Operating Procedures manual. Notify Alaska Oil and Gas conservation Commission (AOGCC) sufficiently in advance of anticipated spud so AOGCC representative can witness functional test of diverter system. 4. Rig up mud loggers prior to spud. 5. Drill 12-1/4" hole to 2150 M.D. as per drilling program. a) Run all solids control equipment. Control drilling rate so as to not exceed capacity of solids control equipment to handle drilled solids. b) Maintain lowest practicable mud weight as per mud program. c) Maintain optimum hydraulics. 6. Condition hole and run openhole wireline logs as directed. , Run 9-5/8" 43.5 lb N-80 BTC casing to 2150 ft as per detailed program in Operating Procedures manual. Cement casing to surface. a) Use top and bottom wiper plugs, float collar, and float shoe. b) Use slurry volumes calculated from caliper log plus 50 percent excess. Circulate cement to surface. If no surface returns, do top job as directed. Adjust slurry properties to provide 4-hour thickening time. Use 6 percent gel and friction reducing agents as per detailed program. Maintain slurry weights in the 13.6 - 13.7 ppg range. . . 10. 11. 12. 13. WOC as directed. Nipple down diverter system. Cut off 13-3/8" conductor at base of cellar. Install 9-5/8" 5000 psi wp casing head. Nipple up RSRRA 11" BOP stack in accordance with Operating Procedures Manual. AOGCC representative must witness test of BOPE prior to drill out of 9-5/8" shoe. Run in hole with 8-1/2" bit. Pressure test casing to 3500 psi before drilling out float collar. Drill out float collar and float shoe. Clean out any rathole and drill 10 ft of new hole. Perform formation competency test to 11.5 EMW. Drill 8-1/2" hole to 5500 ft as per drilling program. a) Run all solids control equipment. Control drilling rate so as not to exceed capacity of solids control equipment. b) Maintain optimum drilling fluid properties and lowest practicable mud weight in accordance with mud program. c) Maintain optimum hydraulics. d) Beware of drilling breaks in coal stringers. Do not advance more than 1 ft on a drilling break without picking up and reaming. Upon reaching 5500 ft, make wiper trip to shoe of 9-5/8" casing. mud for open hole logs. Log as directed. Condition hole and A decision as to running a 7" production string and testing will be made after an analysis of log and sidewall core data. If production casing is run, it will be 26 lb N-80 BTC. Casing to be run and cemented as per detailed program in Operating Procedures Manual. a) b) c) Use top and bottom wiper plugs, float collar and float shoe. Use slurry volumes calculated from caliper logs. Place sufficient cement slurry for an annular fill-up to 1,000 ft above highest potential producing horizon. Use friction reducing, fluid loss, and retarding agents as per cementing program in Operation Procedures Manual. 14. A testing p~ogram will be issued based on an analysis of the geological data. a) If the well is to be abandoned, a supplementary program will be issued covering this procedure. This drilling prognosis is in summary form. A detailed Wellsite Operating Manual and Operational Plan will be issued prior to the startup of drilling operations. WIREUNE LOGGING PROGRAM Run 1' (9-5/8" casing point) Dual Induction - Gamma Ray - SP Run 2: (TD) Dual Induction - Gamma Ray - SP Lithodensity - Gamma Ray - Compensated Neutron Micro Resistivity Log Cement Evaluation Log This wireline program is subject to modification to fit geological conditions encountered while drilling. ~iAl::ll'lO 9NI"I'IIIdCI CI::I.LYdlOI.LN¥ I.~-I. NIdO:l J.S~IM IldlO ,] SA¥O O~ O~ OC OZ O[ / l~ --LM__ A2PROVE DATE YES,, ,NO J R_=U. ARKS - ¢!) zs :he per= : fee == ched ........................................... ,, (2) Loc 2,2 ) (5) BOPE ~.;r.f.~,.,,.~. ,, (23 :~2rt~ 28) (29 :hr= 31) --: 01/30/89 Z. Is well :o' be locaued in a defined pool ............................... 3. Is well locaned proper disuauce from property line .................. _,~. 4. Is well loca:ad proper diszauca from o:her ~;e!!s ........ ~ ........... ~,,, 5. Is suffix, iai: undedica:ed acreage available in :his pool ............ ~ 6. Is ~eL! =o be deviauad and is ~e!!bore pla: included ................ ?. Is oDera:or :he o~y affac=ad pa~ ................................. ~ 8. Can permi: be approved before fir=men-day wai= ...................... T 9. Does operator have a bond Lu force .................................. 10. is a conserve:ion order needed ...................................... I!. Is aa~scracive approva~ needed ................................... 12.' Is :he lease number appropria:a ..................................... 13. Does uhe we!! have a un/qua ~ame and number ..... 14. IS a6nduc~or s~:riug provided ........................................ 15. ~i3.1 surface casi~§ pro,ac= a3_l zones reaso~ab!y expec=ad sez-Te as a~ u~derground source of drinkin~ ~a=ar ..................... ./~F .... 16. Is anouEh cemaen= used =o ¢ir=ula=a on ¢onduc-.or a~d su~aca ......... 17. W'~.!! caman: cie in surface and incarmadiace or produc=ion 18. Will cemen= cover ~ known 9roduc=ive horizons ..................... 19. W'~LL1 ail cas~u~ give adaqua=a safe~y in collapse, =e~sion and burs:.. /~/ ,,, 20. Is :his ~ell :o be kicked off from an ~4suing wel!bor~ ............. , , ///~,,,, 2! ............. Is old wellbora abando~me~: procedure included o~ i0-403 /~,~ 22. Is adequate wellbore separz:io~ proposed ..................... ' ...... ~/~ -- 23. Is a ~iver:ar system required ................................... ~ ~ ~ ,, , 24 Is the dr/!!ing fluid program schemaui: lis: oz'equipmen: adequaue,~...,~. .... Zb. Are necessary dlagr~ and descrip=ions of ~iver~ar and BOPE a==ached. 26. Does BOPE have suffiaiau: pressure ra=iug - Tee: ~:o ~Oc30 psig .. ~ .............. 27. Does =he choke man_tfoid comply ~/API EP-53 (~ay 84) .................. : , 28. IS :he presence of H25 gas probable ............................. ~... ,, For exTlora=ory and Scra:igraphic we!!sr 29. Are da:a presenued on pouau:ial overpressure zones? ................. 30. Are seismic analysis daua presented on shallow gas zones .............. ,,,, 31. If an offshore loc., are survey results of seabed condluions presenuad _ 3Z. Addi=ional requiremen:s ............................................. Add!ziona~ R~aarks: ' , / POOL CLASS STATUS A/LEA NO. , SNORE , i11,1 i ii ii _ · ,, il , __ -- , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. ** FILE HEADER ** FILE SEQUENCE FILE NAME: WF121. DAT SERVICE NAME: RLL VERSION #: V 3.26 DATE: 91/01/19 MAX. RECORD LENGTH: FILE TYPE: EO PREVIOUS FILE NAME: 1024 RECEIVED ** COMMENTS ** JAN 2 1991 GRC: GAAMARAY API AlaskaOil&GasCons. Commission ROP: RATE-OF-PENETRATION Anchor~e EWR: ELECTROMAGNETIC WAVE RESISTIVITY EWC: ELECTROMAGNETIC WAVE CONDUCTIVITY *-RPT: REPEAT OF INDICATED LOG MADE AFTER DRILLING (MAD) ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS i ' IClIOFILMED TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 EWR REPEAT OHMM 0 0 0 0 1 4 0 1 68 ROP MWD FT/H 0 0 0 0 1 4 0 1 68 FXE MWD HOUR 0 0 0 0 1 4 0 1 68 DDE MWD PPF 0 0 0 0 1 4 0 1 68 EWR MWD OHMM 0 0 0 0 1 4 0 1 68 FXE REPEAT HOUR 0 0 0 0 1 4 0 1 68 DDE REPEAT PPF 0 0 0 0 1 4 0 1 68 GRC MWD API 0 0 0 0 1 4 0 1 68 EWC MWD MMHO 0 0 0 0 1 4 0 1 68 EWC REPEAT MMHO 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 EWR REPEAT OHMM 0 0 0 0 1 4 0 1 68 ROP MWD FT/H 0 0 0 0 1 4 0 1 68 FXE DDE EWR FXE DDE GRC EWC EWC MWD MWD MWD REPEAT REPEAT MWD MWD REPEAT HOUR PPF OHMM HOUR PPF API MMHO MMHO 68 68 68 68 68 68 68' 68 ** DATA VERIFICATION (every 100 FT) ** DEPT EWR ROP FXE DDE GRC EWC EWC 4400.000 -999.250 -999.250 -999.250 .683 53.774 -999.250 -999.250 4500.000 2.992 52.658 .140 .575 74.771 279.818 334.251 4600.000 9.841 93.636 .161 .226 53.157 97.230 101.615 4700.000 5.203 51.818 .188 1.362 70.785 201.774 192.202 4800.000 9.857 150.158 .238 .556 68.895 94.702 101.454 4900.000 12.432 130.957 .234 .299 64.239 82.032 80.435 5000.000 13.723 84.200 .161 .721 55.177 68.630 72.872 5100.000 8.004 80.469 .123 1.266 55.195 112.965 124.932 5200.000 8.072 83.312 .127 -999.250 61.784 118.796 123.879 5300.000 12.337 24.000 .359 2.439 67.810 82.977 81.060 5400.000 9.165 23.377 .364 1.010 76.626 110.560 109.110 5500.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 96 DATA RECORDS ** FROM ** FILE TRAILER** FILE NAME: WF121.DAT SERVICE NAME: RLL VERSION #: V 3.26 DATE: 91/01/19 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ********** END OF FILE (EOF # DDE EWR FXE 4.167 -999.250 -999.250 · 12.500 3.574 40.893 8.333 10.285 38.481 6.250 4.956 36.563 9.091 10.559 36.059 12.500 12.190 35.303 11.111 14.571 33.858 5.263 8.852 31.784 3.030 8.418 30.750 · 16.667 12.051 28.842 14.286 9.045 26.916 -999.250 -999.250 -999.250 4400.00 TO 5500.00 FT ** TAPE TRAILER** SERVICE NAME: RLL DATE: 91/01/19 ORIGIN OF DATA: 1-21 TAPE NAME: W. FORK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 91/01/19 · ORIGIN OF DATA: RLL REEL NAME: CIRI CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER ********** * ALASKA COMPUTING CENTER * ****************************** ****************************** COMPANY NAME ~ CIRI PRODUCTION cOMPANY WELL NAME : CIRI WEST FORK 1-2! FIELD NAME : WEST FORK BOROUGH ~ KENAI STATE ~ ALASKA API NUMBER : 50'133-20424 REFERENCE NO : 7427 I ICROFILHED 1991 IS Tame Ver1fication [,isting chlumberger Alaska Com~utino Center 8-JAN-1991 01:56 **** REEL HEADER SERVICE NA~E : EDIT DATE : 9i/01/ ORICIN : FLIC REEL NAME : 74273 CONTINUATION # PREVIOUS REEL COMMENT : CIRI PRODUCTION COMPANY,CIRI WEST FORK 1-21,50-133-20424 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 91/01/ 8 ORIGIN : FLIC TA~ NAME : 74273 CONTINUATION # : 1 PREVIOUS TAPE : CO~ENT : CIRI PRODUCTION COMPANY,CIRI WEST FORK 1-21,50-133-20424 **** FILE MEADER **** FXL~ NA~E : EDIT ,001 SERVICE : FLIC VERSION : O01A06 DATE : 91/01/ 8 ~AX REC SIZE : 1024 FIL~ TYPE ~ LO LAST FILE : PAGE~ ** SCHlUmBERGER WEb5 SERVICES ** ** ******************************************************************************* ******************************************************************************* COMPANY NAME: CIRI PRODUCTION COMPANY WELL: CIRI WEST FORK 1-21 FIELD: WEST FORK BOROUGH: KENAI STATE: ALASKA AP1 NUMBE~: 50-133-20424 LOCATION: 1984' FNL & 1707' FEL SECTION: 2l TOWNSHIP: 6N RANGE: 9w PERMANENT DATUm: G.L. ELEVATION: 302' 5OC MEASURED FRO~ K,B. 20' ABOVE PERMANENT DATUM IS Tare verification b~stinq cblumberqer Alaska ComDutinq Center B-jAN-1991 01:56 PAGE~ ELEVATIONS KB: 322' OF: 321 ' 302 ' RUN NUMBER: t DATE LOGGED: 23-DEC-90 TD DRILLER: 2157 C~S!.NG 1: 13 3/8" ~ DRILLER DEPTH OF 0' TO 140' BIT SIZE 1: 12,25 " 8 2157' TYPE FLUID IN HOLE: GEL CHEM DENSITY: 9,7 VISCOSITY: 60 S PH: 8,5 FLUID LOSS: 8 C3 MUD RESISTIVITY: FILTRATE RESISTIVITY: ~UD CAKE RESISTIVITY: 4,t4 ~ 68 DEGF 3,77 $ 64 DEGF 3,2~ ~ 57 DEGF TIME CIRCULATION ENDED: 23:30 22-DEC'90 TI~E LOGGER ON BOTTOM: 18:10 23-DEC'90 MAXIMUM TEMP RECORDED: 102 DEGF LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: KENAI MCCROSSAN R, C. GARDNER TOOL NUMBERS: IEM-BD 1205 SGC'JAA 151 DIC'DB 1353 DIS C 1474 FIELD RE~ARKS: TOOL RUN WITH NO FIN STANDOFF$~ AT CLIENT'S REQUEST, DUE TO RAPID SWELLING OF CLAY FORMATIONS . RAPID SHIFTS IN SP CURVE AT 1.590', AND 1980' DUE TO UNGROUNDED RIG POWER SUPPLY, RUN NUMBER: DATE LOGGED: TD DRILLER: TWO 03-JAN-1991 5459' C~SING 1: 9 5/8" B DRILLER DEPTH OF 2145' BIT SIZE 1: 8 1/2" TYPE FLUID IN HOLE: POLYMER/KCL DENSITY: 9,7 VISCOSITY: 48 S PH: 9.5 FLUID LOSS: 10,4 C] ~UD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 0.3~3 M 70 DEGF 0,291 0 70 DEGF 0,549 ~ 70 DEGF Tape Verification Listlng cblumberger AlasKa Computing CeDter 8-JAN-1991 0i:56 M~XIMU~ TEMP RECORDED: ESTIMATED 136 DEGF LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: TOOL NUMBERS: D!S-EC 1474 SGC-JC NLM-BC 1024 N$C-E 789 GSR-J 7200 NSR-F 2513 TCC-B TCM 537 FIELD REMARKS~ BAILEY ERIK OPSTAD DIC-DB 1353 IEM-BD 1223 DRS-C ~824 PGD 37 2 CNC-HA 108 SGC-SA MTL-A TOOLS RUN WITHOUT CENTRALIZERS AT CUSTOMER REOUEST, BOTTOm HOLE TEMPERATURE IS ESTIMATED, DATE JOB STARTED~ 7-JAN-91 JOB REFERENCE NO: 74273 LDP/~NA: R, KRUWELL FILE - EDIT,00! CIRI PRODUCTION COMPANY WEST FORK CIRI WEST FORK I-2! 50-133-20424 "MAIN PASS LOG DATA" DATA SAMPLED EVERY -,5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME DIT-D ,OIL LOT ,LOT CNT-A/D/H ,CNL ~LT ,MLT R0 ,CSU DUAL INDUCTION SFL LITHO DENSITY COMPENSATED NEUTRON MICROLOG ~ATER FILLED RESISTIVITY FROm CYBERLOOK IS Tape Verification Llstlnq chlumberqer AlasKa Com~%]ting Center B-jAN-1991 01:56 PAGE= 4 TABLE TYPE : CONS TUNI VALU DEF! CN CIRI PRODUCTION COMPANY FN WEST FORK WN CIRI WEST FORK 1-2t APIN 50-133-20424 FI, 1984 FNL & 1707 FEb SECT 21 TOWN 6N RANG 9W COUN KENAI STAT ALASKA NATI USA WIT~ GARDNER/OPSTAD PDAT GL_ EPD FT 302, L~F KB ADD FT EGL FT 02 TDD FT 545~. BLI FT 5460, TLI FT 140 DFT POLgMER/KCL DFD G/C3 ~.~0000! DFPH DFV CP DFL F3 ~0'4 R~S OH~ 0.383 MST DEGF 70 ~MFS o~ o.~9~ MFST DEGF 70 Ri~CS OHMM 0.~49 MCST PEGF 70. BHT DEGF Company Name Field Name Well Name AP[ Serial Number Field Location Section Township Range County State or Prov~nce ~atlon itness' Name Permanent datum Elevation of Perm, Datum Log Measured From ABOVE PERMANENT DATUN ~ Elevation o~ Kelt¥ Bushing EleVation of Derrxc~ Floor Elevation o~ Ground bevel Total Depth - Driller Bottom bog Interval Top bog Interval Dr~llifig Fluid TYPe~ Drilling Fluid Density Drilling Fluid P~ : Drilling Fluid ViSCOSity Drllllng~.FlUid LoSS . Resistivity of Mud. Sample Mud-Sample Temperature~ Resistivity of mud filtrate s ~ud~,~Flltrate Sample Tempe~atu Resistivity o,f Mgd Ca~e~'Sempl Mud Ca~e Sample ~empera~ure Bottom H. ol· Temperature ...... TABLE TYPE = CURV DEPT ILD CILD IL~ SFLU SFLa SP G~ TENS DPHI Depth Channel Name Deep Induction Standard Processed Resistivity Deed Induction Standard Processed Conductivity ~edi' um Induction Standard Processed Resistivity SFL Resistiv! unaverag d) SrL ~esistivl [~ I e avera~eo) Spontaneous Potential Gamma Ray Tension Density Porosity IS Tape Verification Listing cblumberqer ~las~a Computing Center 8-J~-199! 01:56 DEFI '''''''''''''''''Z'''''''''''''R~OB iK Den ty ..... ''''''''''''''''''''''' DRHO Delta RHO PEF P~otoelectric Factor OLS Duality control of long spacing fPr GDT QSS Quality control on short Spat. 6g~ zor LDT LS Bona SPacing Computed Count R.ate (BL+LU/2) LU Long UPper ~-2 Window Count Rate (LUI+LU2) Long Lower Wlndow Count Rate LIT~ Lltholog Window Count Rate SSi Short SPacing 1 Window Count Rate SS2 Short SPacln6 2 Window Count Rate LSHV Long Spacing'N~gh Voltage Output SSHV ShOrt Spacing High voltage Loop Output $1RH Short SPacln~ ! Density LSRM Long Spacing~RHOB (UncOrrected) LUR~ Long Upper R~OB CAbI Caliper GR Gamma Ray TE~S Tension 0 Resistivit~ 100% Water Bearing ~PHI Neutron Po osit¥ RTNg Raw T~ermal Neutron Ratio TNP~ Thermal Neutron Porosit~ TNRA Calibrated Thermal Meut~on Ratio NPOR Neutron Porosity Output From an Application Program RCNT RCNT RCFT RCFT C~TC C~TC CFTC CFTC GR Gamma Ray CAb! Caliper TENS Tension GR Gamma Ray TENS Tension B~NO B,NO -MNOR ~CAL MCAL --........m~mmmmmmmmmmmmmmmm..m~mmmmmmmmMm~.~.mmmmm~mmmm~. ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ..mmmmmmmMmm..m.mmm........... 1 66 0 2 66 O 3 73 4 66 1 5 66 PAGE{ Tape verification Listing chlumDerqer AlasKa Computing Center 8-jAN-199] 01:56 PAGE{ 6 73 7 65 8 68 0 5 11 66 5 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API ID ORDER ~ LOG TYPE DEPT FT O0 000 ILO OIL O~MM O0 000 CILD OIL MMHO O0 000 iLM DIL OHM~ O0 000 SFLU OIL OH~ O0 000 SFLA DIL OHMM O0 000 SP DIL MV O0 000 GR DIL GAPI O0 000 TENS OIL LB 00 000 DPHI LDT PU O0 000 RHOB LDT G/C3 O0 000 DRHO LOT G/C3 O0 000 P£F LOT O0 000 QLS LDT O0 000 OSS LOT O0 000 LS LDT CPS O0 000 LU LOT CPS 00 000 LL LOT CPS O0 000 LIT~ LOT CPS O0 000 SSI LDT CPS O0 000 SS2 LDT CPS O0 000 LSHV LOT V O0 000 $SHV DDT V O0 000 S1RH LDT G/C3 O0 000 LSRH LDT G/C3 O0 000 LUR~ bDT G/C3 O0 000 C~LI LOT IN O0 000 GR LDT GAP! O0 000 TENS bDT LB O0 000 RO CSU OH~M O0 000 NPHI CNL Pt! O0 000 RTN~ CNL 00 000 TNP~ CNb PU O0 000 T~R~ CNL O0 000 AP1 API FIbE NUMB NUMB SIZE REPR PROCESS CLASS ~OD NUMB SAMP EDEM CODE (HEX) O0 0 I 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 I 1 4 68 0000000000 O0 0 I 1 1 4 68 0000000000 O0 0 ! 1 1 4 68 0000000000 O0 0 1 ! 1 4 6'8 0000000000 O0 0 I I I 4 68 0000000000 O0 0 1 I 1 4 68 0000000000 O0 0 ~ 1 1 4 68 0000000000 O0 0 I 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 i t 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 i 1 I 4 68 0000000000 O0 0 I 1 1 4 68 0000000000 O0 0 1 i 1 4 68 0000000000 O0 0 1 1 ! 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 I 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 ! 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 ! 1 I 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 ! 1 t 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 ! 1 4 68 0000000000 O0 0 1 1 I 4 68 0000000000 O0 0 1 1 ! 4 68 0000000000 O0 0 I 1 1 4 68 0000000000 O0 0 1 I 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 IS Tape verification bistimQ cblumberQer Alaska Computing Cent. er B-jAN-199! 01:56 NAMe: SERV UNIT SERVICE API APi API API 'FIbE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS ROD NUMB SA~P ELEM CODE (HEX) NPOR CNL PU O0 000 O0 0 i 1 I 4 68 RCNT CNL CPS O0 000 O0 0 I 1 1 4 68 RCFT CNL CPS O0 000 O0 0 1 1 ~ 4 68 CNTC CNL CPS O0 000 O0 0 1 I I 4 68 CFTC CNL CPS O0 000 O0 0 I I 1 4 68 GR CNL GAPI O0 000 O0 0 1 I 1 4 68 CALI CML IN O0 000 O0 0 1 1 ! 4 68 TENS CNL LB O0 000 O0 0 I 1 t 4 68 GR ~LT GAPI O0 000 O0 0 1 1 I 4 68 TENS MLT LB O0 000 O0 0 1 I 1 4 6 BMIN ~LT OHMM O0 000 O0 0 1 I I 4 68 BMNO MLT OH~M O0 000 O0 0 1 t 1 4 68 MCAL MbT IN O0 000 O0 0 i 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 PAGE{ DATA DEPT. SFLU.DIL TEN$.DIL P~F.LDT LU.LDT SSI.LDT LSRH.LDT TENS.bDT TNP~.CNL RCFT.CNL CALI.CNL BMIN.MLT DEPT. SFLU.DIL TENS.DIL PEF,LDT LU LDT $S2~LDT LSR~.LDT TENS.LDT TNPH CNL RCFT:CNL CALI.C~L B~I~.~LT DEPT. SFI. U.DIL TEN$.DIL PEF.LDT LI{.LDT SS2.LDT LSR~.LDT 5475.000 11.294 1290 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 5400,000 8.449 1655 000 5~531 450 750 347:750 2.078 1970.000 46 959 397:844 11.430 0.911 5300.000 16.515 !640.000 3.904 368.750 323.750 2.184 IbD.DIL SFLA DIL DPHI LDT O[.S bDT LL bDT LSHV bDT LURH:LDT RO,CSU TNRA.CN5 CNTC.CNL TEN$.CN5 BMNO,MLT ILD.DIL SFLA.DIL DPHI.bDT OL$,LDT Lb~LDT bSHV,LDT LURH bDT RO:CSU TNRA.CNL CNTC.CNL TENS.CNL B~NO.MLT ILD.DIb SFLA DIL DPHI:LDT OLS.LDT LL.LDT LSHV.DDT LURH.LDT I! .4 -999 250 -999 ~50 '999 50 '999 ~50 '999 50 '99~ ~50 '99 50 '999 0 -99 250 10 726 2~ 213 945 -0 012 263 500 1209 000 1!, 3 4.~28 1580, 22 1970,000 1.223 15 284 14:322 27.579 0.006 217.000 1210.000 2.205 CILD.DI5 SP.DIL RHOB,LDT kITH.bDT SSHV,LDT CALI'LDT NPHI CNL NPOR CNL CFTC CNL OR MbT MCA5 MbT CILD,DIb SP.Dib RHOB,bDT LITH.LDT SSHV,hDT CAbI,hDT NPHI.CNL NPOR CNL CFTC:CNL GR.MLT MCAL.MLT CILD.DIL SP.DIL RHOB.bDT OSS.LDT 5ITH.LDT SSHV.LDT CALI.LDT 95226 -999. -999 -999 -999 -999 -999 -999 -999 -999 -999 625 OR.DIS 250 DRHO.LDT ~50 SSi,LDT 250 SlRH,LDT 250 OR'bDT 250 RTNR.CNL 250 RCNT.CNL 250 GR,CNL 250 TENS,MbT 25O 93 -8 2 0 1~ 19 O4 49 48 4O8 66 GR,DIb ~ DRHO.bDT bS,LDT SlRH,bDT 430 OR,bDT 226 RTNR,CNb 8 9 RCNTeCNb o½8 GR.CNb 84.188 TENS,MbT 9,891 65 427 '51129 2 195 0 008 89 625 131~ 000 414 IbM GR DRHO LDT LS bDT SS1LDT GR DT 9':973 ,. 62,844 999,, 250 '999. 250 "999,250 999'250 -999,250 .,999,250 .,999.250 0 0 8 , 188 ,367 17~,~,499 .188 1970.000 7 7 15, ~5 64, 5OO 214,500 75,3i3 IS Tame verification blstinq chlumberger AlasKa Computinq Center TE $.LDT 1965.000 R0.CSU CNL 34 816 TNRA.CNL TNPH, '1 , RCFT,CN~ 709,385 C{<TCiCNL C'AL~ .CML 9,414 TENS,C~L B~I~, ~LT I · 138 BMNO, ELT DE'-,,Pr, 5200,000 ILO,bib SFLU,DIL 6,884 SFLA.DIL TENS.bib i610,000 DPMI,LDT LU.LCT 400 50 LB.LDT SS~.~OT 3o~:~oo ~S~V.b~T LSR~,LDT 2 50 bURH.LDT TE~$.LDT 1935,000 R0,CSU TNPH.CNL 36,791 TNRA,CN5 ~c~.c~ ~,~o~ c~:c~ C~L~.C~ ~ ~8o T~ C~ DEPT. SFLU,DIL TENS.DIL PEF.LDT LU bDT DSRH.LDT TENS.bDT TNPH.CNL RCFT,CNL CAbI,CNL B~I~.NLT 5100,000 7,566 1595,000 2.990 384750 308:000 189~'170000 35 125 747980 8 523 1257 ILO.DIL SFLA,DIL DPM~ bDT GL bDT 55 bDT 5SHV bDT LURH bDT R0 CSU TNRA CN5 CNTC CNb TENS CNL BMNO MbT DEPT. SFLU.DIL TENS,bib PEF bDT LUiLDT SS2 bDT LSRM,LDT TENS.bDT TNPN,CNL RCFT,CNL CALI,CNL BNIN.~LT ooo: oo 12 02 1560. O0 450 O0 319.250 2,084 1935,~00 31, 57 821,101 8.508 1,471 ILD.DIL SFLA,DIL DPHI.LDT OLS,LDT Lb,bDT bSHV.LDT LURH,LDT RO,CSU TNRA,CNL TEN CNL BMNO,MLT DEPT. SFLU,DIL TENS.bib PEF.LDT LU.LDT SS~.LDT LSRH.LDT TEMS.LDT TNP~.CNL ~CFT.CNL 4900,000 9.467 1530,000 3,066 407,250 312,500 2,137 1885.000 38.037 658.549 ILD bib SFLA:DIL DPHI,LDT OLS,LDT Lb bDT LSHV:LDT LURH.LDT RO.CSU CNL CNTC.CML 8-JAN-1991 01:56 9.883 NPHI,CNb 8 CFTC, CNL ! 965 ~0 GR, ~LT 1,826 MCAL,~LT 9,547 6,879 30.880 oos 625 1208 000 :158 ~ 754 3 184 19 000 I 577 9.899 7,231 29,588 -0 5 8 ~6o 1895 000 1 436 018 ~951 34'966 -0.009 262,500 1208'000 ,094 .934 ,722 235 .036 193~'000 1,613 13,835 9.632 31,830 0 002 240i875 1208 000 2.148 7.266 3,299 2067,850 CILD,DIL SP.DIL RHOB,bDT OSS LITM bDT SSHV bDT CALI bDT NPHI,CNL NPOR,CNb CFTC,CNb GR,MLT MCAL,MLT CIbD,OIL SP,DIL RHOB.LDT O$S;LDT L~TH,LDT $.~HV.*.LDT CALX,bDT NPHI,CNL NPOR'CN5 CFTC,CNL GR,~LT MCAL.MLT SP IL RHOB DT O$$,LDT LITH,LDT SSHV,LDT CALI,LDT NPHI,CNL NPOR,CNL CFTC,CNb GR,MLT MCAb,MLT CILD,DIb SP,DIL RHOB,bDT QMS,bDT L!TH,LDT $$HV,LDT CALI,LDT NPHI.CNL NPO~:CNL CFT CNL 33,480 RTNR,CNb 6~5,93 GR,CNL 104 749 IL~,DIL 500 GR'DIb 2~ 140 DRHO,bDT 0 127 ~13 bM.LOT 75 SSI.bDT 3 RTNR,CNL 36.064 RCNT~CNb 5 31 TENS, ~01,016 2t'000 GR 2.162 DRHO bDT 0.008 LSLDT I19,875 SS1 bDT ' 523 GR~LDT 35,i007 RTNR CNb 34'804 RCNT~CNb 729,605 GR CNb 56,063 TENS MbT 8'156 62 431 IbM DIL 28~~ 0 DRGR 2 .~ ~0 0 4 50 bDT 1304 000 SIRH,bDT 85O8 RCNT,CNb 50 GR.C 61 TENS.M 8 086 72.283 IbM.bib 36'219 GR,DIL 2.125 DRHO,bDT 0,002 LS,-LDT 131,750 SSi,bDT 1303,000 S1RH~LDT 8,563 GR'LDT 39,434 RTNR,CNL 38,46! RC~T,CNL 644,788 GR,CNL PAGEI 1965, ~ 85!5 57 469 -002 56~'6 1895~000 58,094 -0,0 4 2761,938 1935,000 2 0 64 938 3 490 2309 6 0 64 9~8 IS Tape Verification Listing chlumberger AlasKa Computing Center CALI.Cgb 8 563 TENS,CNG B~IN.~LT i'444. 8MNO, ~LT DEPT. SFLU.DIL TENS,OIL PEF.LDT LU,LDT $S2.LDT LSRH bDT TENS' .bDT TNPH,CML RCFT,CMb CALI.CNL 8MIN,~LT 4800,000 8,488 1510 000 2 984 412 000 315 000 2 137 1840 000 35 601 680 892 8 505 1 098 ILO.DIG SFLA.DIL DPHI,GDT QLS,LDT Lb,LOT 5SHV.LDT GURH,LDT RO,CSU TNRA,CNL CNTC;CNL TENS,CNG BMNO'~LT DEPT, SFLU,DIL N DIG TE~$, PEF,LDT GU,LOT SS~.LDT LSRH.I, DT TENS,LOT TNPM,CNL RCFT,CNL CALI.CNL BMIN.~LT 4700 000 5 248 1475 000 5 875 1193000 420 750 1 563 !900 000 44 630 333 822 17 578 0 524 ILD.DIL SFLA,DIL DPHI,bDT QLS,LDT Lb.bDT LSHV.LDT LURH.LDT RO.CSU TNRA.CNL CNTC,CNL TENS.CNL BMNO,MI,,T DEPT SFLU:DIL TENS,DIL PEF.LDT LU.LDT SS2.LDT bSRH LDT TENS:LDT TNPH,CNL RCFT.CNL CALI,C~L B~I~.~LT 460~.000 .173 1455.000 2.908 31 000 129 1825.000 37.715 660.41~ 8 563 1:458 ILO DI[, DPHI.LDT Qb$~LDT GL'GDT LSHV.LDT LURH.'LDT RO,CSU TNRA.CNL CNTC~CNL TENS, CNG B~NO,MLT D~PT, SFbU DID TENS:OIL PEF.LDT LU,bDT SS2.LDT LSR~.LDT TENS.LOT TkPH CNG RCFT:CNI. CALI,C~b B~IN.MLT 4500.000 3.058 1430.000 5.238 1179,000 400.000 1,566 1770,000 56.91~ 301.789 17,609 0,578 ILO,DIG SFLA,DIL DPHI.LDT OLS LDT bL:LDT LSHV.LOT LURH.LDT RO CSU TNRA:CNL CNT~'CNL TENS.CNG 5MNO,MLT 8-JAN-1991 01:56 1885,000 1.418 bi 8 8 31 851, -0 013 000 2,143 7,254 204~ 't22 '689 I840.000 1'329 5 837 65 0 -0 031 629 500 1208 000 1 584 I 547 0 798 1~ 956 117 32 064 -0 002 243 500 1208 000 .141 ~;152 2003'178 ,561 4.174 3.401 64,680 '0.018 627,000 1207.000 1,590 1.582 4 29O 1249!247 1770 000 0.567 GR,MLT MCAL,MLT CILO,DIb SP,DIL RHOB,LDT O$S,LDT blTH,bDT SSMV.4OT CALl,bDT NPHI,CNL NPOR,CNb CFTC,CNG GR,MbT MCAb,MLT CILo,DIL SP DIG RHOB LOT OSS LOT IT 5DT CALl bDT NPHI CNG NPOR,CNL CFTC,CNG GR,MbT MCAL,MLT RHOB,bDT Q$S~GDT GITH.~DT $$HV.GDT CALl,GDT NPHI,CNL NPOR~CNL CFTC.CNG GR,MbT MCAL,MLT CILD,DIb SP,DIb RHOO,bDT OSS,LDT LITH,bDT $$HV,bDT CALI,bDT NPHI,CNL NPOR,CNL CFTC,CML GR,~LT MCAL.MLT 64.938 TENS.MbT 8.234 84 313 IbM,OIL 36 53I GR,DIb 2 ~4 DR"O.~DT -0 5 LS.LDT 134 ~5 SSi.bDT 1,304 0 SlRH,LDT 8.508 GR,bDT 36.283 RTNR.,CNL 37,176 RCNT.CNL 671;019 GR,CNL 72,438 TENS,MbT 8.156 171 334 lb~',Olb 0 000 GR,DIL 1 572 DRHO..GDT -0 ~0 .3 LDT 272 7~0 55. SSI.bDT 578 GR,bDT 50 540 RTNR.CNL 43824 RCNT, 355 507 _ GR.CNb C 13.586 GRDIL 0 b$ bDT 133:O0 SS1 bDT 1303.000 $1RH bDT 222 RTNR,CNb 36.817 RCNT 628'482 GR. Nb .375 TENS,MbT 239.582 IbM,DIG -0 997 GR,DIb i:583 DRHO.bDT 0,~16 bS.LDT 300. 0 8SI.GDT 1302.000 SlRH.GDT 17.609 GR.bDT 51,,052 RTNR,CNG 57.0BB RCNT.CNL 280.790 GR,CNL 64 750 TENS.MbT 11~234 1885,000 lO 067 64 250 -0 1840 4,363 .0,,007 1216~000 238'500 1.534 4,533 t599,690 6¸5 000 27 65 64 750 4 769 1404 680 64 750 1770 000 IS Tape Verification Listlnq ch!umberger AlasKa Computin.~ Center DEPT. 4400.000 SFLU.DIL 8,675 TENS.DIS 1400,000 PEF,LDT 3,172 LU,LDT 390,250 SS~.LDT 312,000 bSR~,bDT ~,164 TENS.bDT 178 ,000 TNpH,CNL 40,817 RCFT,CNL 568,220 CRbI CML 8,508 BNIN' ,MbT 1,138 DEPT. 4300 SFLU,D!L 5 TENS.DIL 1375 PEF,LDT 3 bU.LDT 423 SS2.LDT 317 LS~H,LDT 2 TENS,bDT 1775 TNPH,CNL 43 RCFT.CNL 531 C~LI,C~b 8 B~I~.MLT I DEPT. 4200 SFLU,DIL 6 TENS.DIL 1340 PEF,LDT 3 LU,LDT 442 SS2,LDT 316 LSRH,LDT 2 T~MS.LDT 1715 TNpH CML 38 RCFT:CNL 584 CALI,CNL 8 B~IN.MLT DEPT, 4100 SFLU,DIL 4 TENS.DIb 1320 PEF.LDT LU.bDT 574 SS2,LDT 337 LSR~.LDT TENS,bDT ~705 TNPH.CNL 47 RCFT.CML 471 C~LI,CNL 8 B~IN.NLT 02 ,000 201 25O 250 ~7 000 582 135 508 ,244 ,000 201 000 242 5OO 500 098 000 095 140 ,492 ,298 ,000 ,55] ,000 45 : oo ,000 ,95~ ,000 ,413 ,795 ,594 .244 ILD,DIb SFLA,DIL DPHI.LDT OLS,LDT Lb,bDT LSHV'.~.~DT LURH~LDT R0,CSU TNRA,CNL CNTC,CNb TENS.CNL BMNO,MLT IbD DIL SFLA DIL DPHI bDT QLS bDT Lb bDT LSHV,LDT LURH,LDT R0.CSU TNRA,CNL CNTC,CNL TENS,C~t. BMNO,~LT ILO.DIL SFLA'DIL DPHI~LDT QLS,bDT Lb,bDT LSHV,LDT LURH.bDT R0'CSU TNRA,CN~ CNTC~CNL TENS,CNb BMNO,MLT ILD,DIL SFLAeDIL DPHI,LDT OD$,LDT LL:LDT LSHV,LDT LURH,LDT R0,CSU TNRA,CNL C~TC.C~L TENS.CML B~NO.MLT 8-JAN-1991 8.684 30,324 -0.004 22'? 1208,500 ,000 ,174 ~,063 3,496 1972,094 !780.000 t.348 6,567 32, 7 8 1208:000 2 127 6 906 182~ 620 1.418 7,948 3~ 197 55O -0 019 25 120~ t75 )00 2 04 6 188 3 283 7!5 0 1 383 5.313 4,618 42,873 0 000 333~500 1207,000 1 961 3 828 818 1737 811 1705 000 1.400 0!:56 CILD.DI5 SP,DIL RHOB,LDT QSS,LDT LITH,LDT SSHV,LDT CALI,LDT NPHI~CNL NPOR,CNL CFTC,CNb GR,MbT SCAb,MbT ClLD OIL SP RHOB bDT O$S bDT LITH bDT $$HV bDT CAbI bDT NPHI CNb NPOR CNL CFTC~CNL GR MbT MCAL ~LT ClLD,DIb SP,DIL RHOB'bDT OS$,bPT blTH.'LDT SSHV~bDT CALIeLDT NPHI,CNb NPOR CNL CFTC CNb GR MCAb ~LT CILD,DIb SP,OIb RHOB,LDT Q$S,LDT LITH,LDT SSHV,bDT CALI,LDT NPHI,CNL NPOR,CNL CFTC,CML GR,MLT SCAb,MbT 82.861 35 500 2 150 -0 007 120938 1303 000 8 8 40 865 583 597 55 656 8 422 152,273 0 010 130 875 1303 000 8 5O8 45 400 44 ~00 51.4 970 58 031 8 ,234 125,819 24;984 2,096 0'027 133,.875 1305,.000 8,'492 39,246 _37,754 559,33~ 62,21_ 8,367 188.210 10,500 1.943 202. 5 1303,000 8.594 48.894 47,050 456,869 99.375 8,547 GR DIL DRHO bDT b$ bDT $S1 bDT SIRH bDT GR bDT RTNR CNL RCNT CNb GR CNb TENS MbT IbM DIL GR:DIL DRHO bDT L$ bDT SSI bDT S1RH bDT GR bDT RTNR CNL RCNT CNb GR:CNL TENS ~LT IbM GR DRHO bDT b$ bDT 881 bDT $1RH bDT GRbDT RTNRCNb RCNT,CNb GR CNL TENS ~LT OR OIL DRHO bDT bS bDT SS1 bDT S1RH bDT GR bDT RTNR CNb RCNT CNb G~:CNL TEN MbT PAGE{ 10- !,.239 ,313 '0~6 42~,,7.0 20 ,.125 ;227 1~80,000 5 988 994 8 -0 0~8 75 I775 000 476,500 21i;625 2;[09 62,219 3,586 2038,826 8t3 2{.2.9 ' $ 9 IS Tape Verification LlstlnO 8-JAM-1991 01:56 cblumberger Alaska Computlnq Center DEPT. 4000.000 SFLU.DIL 5.155 TENS.DIL 1295.0(>0 PEF,LDT 2,906 LU,LDT 439.500 SS2.LDT 319.000 LSRH.LDT 2.094 TENS.LDT 1690.000 TNPH.CNL 40.349 RCFT.CNL 566.667 CALI.CNL 8.508 B~IN.MLT 1,3~1 DEPT. SFLU.DIL TENS.DIL PEF,LDT LU.LDT SS2.LDT LSRH.LDT TENS.LDT TNPH CNL RCFT:CNL CADI.CNL BMIN.MLT DEPT. SFLU.DIL TENS.DIL PEF.bDT LU.LDT SS2.DDT LSRM.LDT TE~S LOT TNPH:CNL RCFT.CNL CADI.CNL B~IN.MLT DEPT. SFLU.DI5 TENS.DID PEF.LDT LU bDT $S2:LDT bSR~.LDT TENS.LDT TNP~.CMb RCFT.CNL CALI.CNb BMI~.MLT 3900 000 4 685 1220 000 2 875 43O 250 316 500 !3 2 1670 45 O54 480 144 8 508 I 991 3800.000 5,279 1190~000 2.955 418.250 312,750 2.:127 1640 000 371660 638 57'7 8 539 1,124 3700.000 4.829 i165.000 3.242 383.750 310.000 2,174 1620,000 40,148 616,i69 8.508 1,004 ILO.bib SFLA.DIb DPMI.LDT OLS.LDT Lb.bDT bSNV.LDT LURM.LDT RO CSU TNRA CNL CNTC CNb TENS CNL BMNO ~LT ILD,DIL SFLA.DIL DPHI.LDT OLS,LDT Lb.bDT bSMV,bDT LURH.LDT RO.CSU TNRA.CNL CNTC.CNL TENS.CNL BMNO.MLT ILD,DIL SFbA,DIb DPHI,LDT OhS,bDT Lb,bDT LSHV.LDT bURH'LDT RO CSU CNTC.CNb TENS.CNL BMNO.MLT IbD DIb SFbA:DIb DPMI bDT QbS bDT Lb LDT bSMV bDT LURH bDT RO.CSU TNRA.CNL CNTC.CML TENS.C~L BMNO.MLT 5.949 13 0.003 261,000 1208.000 2.107 6.!99 3,420 1852.851 1690,000 1,453 5 06 4 32 ~94 '0 12 250 ~50 1208 O0 o ,1 9 6 477 ~ ~20 o0 0~4 242 375 1208 000 2 135 7 000 3 295 064~ 304 000 I 365 5,515 °. -0 013 220 750 1208 000 2,184 8 641 3 328 1952 547 1620 000 ! 241 CIbD.DIb SP.DIL RHOB.LDT QMS.bDT LITH.LDT SSHV.LDT CALI.LDT NPMI.CNL NPOR.CNL CFTC'CNL GR.MbT SCAb. MbT CILD SP DIL RHOB bDT QMS bDT ITH bDT SHV bDT CALI,hDT NPHI.CN~ NPOR CNb CFTC:CN~ GR,.MLT MCAL'MLT ~$P,DZL RMOB.bDT QMS,bDT GiTH'LDT SSHV,GDT CALI.~DT N~MI CNb CFTC CNb SCAb,MbT CILD.DIb SP.DIb R~OB.bDT SS.bDT LITH.DDT MMHV.LDT CAbI.bDT NPHI.CNL NPOR.CNL CFTC.CNL GR,MLT ~CAL.~LT 168't07 14.500 2,085 · 0,005 142.750 o :ooo 41.~26 RTNR 40.285 RCNT 55~.097 GR 4:.500 TENS 8'227 ILM.DIL GR.DIb DRHO,bDT bM.bDT SSI~LDT SlRH.LDT GR.bDT CNb !Z5.:242 IbM 1,501 2,i07 DRHO 0~013 LS 142'875 1302.000 $1RH 8.508 44.779 RT~ 47!,~ GR~ ,tNb ~CNb CNb 154.397 1~'492 ,,005 13 ,000 ,539 ,0 8 638.3~4 52~344 8,'422 GR DZb DRHOLDT S1RH bDT OR bDT RTNR CNb RCNT CNb 1~ 10 03 8 40 39 585 46 8 05 GR 166 DRHO 0O3 375 000 SIRH 508 GR 040 RTNR 319 RCNT 056 GR 406 TENS 477 IbM bDT bDT bDT bDT bDT tnb CNb CNL MbT PAGE: 11 344 -0,012 480,750 206,790 :500 ,229 169~ .500 ,000 s's4o 56~666 '53*500 1909,521 53,'5~0 1670,00 45~,~ 204,0 !640~000 5,564 47,406 412,500 2,2!7 4&,406 3,564 2242.020 · 46,406 1620,000 IS Tape Verification bisting chlumber~er Alaska Computing Center DEPT. 3600,000 ILD.!)IL SFLU DIL 7.835 SFLA.DIL TENS~ ' DIL 1140.000 DPHI.LDT PEF,LDT 3.498 QLS.LDT LU.LDT 339,250 BL.LDT SS2.LDT 299,250 5SHV.LDT LSRN,LDT 2.234 DURH.LDT TENS.LDT 1605,000 R0,CSU TNPH.CNL 38,183 TNRA.CNL RCFT.CNL 607,575 CNTC,CNL CALI.CNL 8,508 TEN$.CNL BNIN.MLT 1.351 BMN'O,MLT DEPT. 3500.000 SFLU.DIL 4.881 TENS.bib J125.000 PEF.LDT 3,537 LU,LDT 445,000 SS2.LDT 322.~5.0 LSR~.LDT 2. 90 TENS.LDT 1575,000 TNPH CNL 43.227 RCFT:CN5 518.219 CALI.CNL 8,234 B~IN.~LT 1.284 ILD.DIL SFLA,DIL DPHI,LDT QLS.LDT LL bDT LSHV LDT BURH bDT R0 CSU TNRA CN5 CNTC CN5 TENS.CNL BMNO.MLT DEPT. SFLU TFNS:DIL PEF.BDT 5U,LDT SS~..LDT LSRH,LDT TENS.LDT TNPN.CNL RCFT CNL CALI:CNL BMIN.~LT 3400,000 9.228 1090 000 3 729 421 250 329 ?50 2 1560 000 49 074 405 8 719 ~ 444 ILD DIL SFnA DIS DPHI bDT QB$ bDT Bb bDT BUR bDT RO CSU TNR~ CNb CNTC,CNb TEN$,CNb BMNO.MBT DEPT SFLU:DIb TENS.DIL PEF.LDT LU LDT SS2* .DDT LSRH.LDT TENS.bDT T~P~ CNL C~L! CNL B~IN:~LT 3300,000 7.383 1065.000 3 137 373:500 304.750 2.186 15i5,000 37,715 644,589 8.508 1,338 IBD DPHI.LDT OL$ bDT LL LDT BSHV LDT LURH LDT R0 CSU TNRACN5 CNTC CNL TENS CNL BMNO MLT B-dAN-1991 01:56 ..324 26.206 0.018 200,750 1208.000 2,254 1605' 0 1,613 6~ 1208,000 157~,000 ,365 10.256 9 1208 7, 1560, 0 !,524 10 411 8 081 28 447 0 003 219 ~25 1208 000 2 197 9.250 3.256 2033.688 1515.000 1.578 ClLD.DIL SP,DI5 RHOB'LDT SSHV,LDT CALI,LDT NPHI~C~L NPOR.CNL CFTC,CNL GR.MBT MCAB.MBT CILDDI5 SP ~DI5 RHOBi~DT ~SS DT LITH BDT SSHV bDT CABi:BDT NPH! CNL NPORCNL CFTC CNL GR MBT MCAL ~BT CIBD,DIL SP,DIb R~OB~LDT QSS~LDT LITH.'LDT SSHV'LDT CALI,BDT NPHI'CNL NPOR,CN5 CFTC'CNU GR,MBT MCAL'~LT CIbP'eDIb SP,DIb RHOB'BDT QSS~BDT BITH,BDT SSHV,LDT CALI,LDT NPHI,CN5 NPOR,CNb CFTC,CNL GR,NLT MCAB.MLT ~22 114 13 2 -0 98 13082 38 38 600 64 8 ILM.DIL · 492 GR,DIL 218 DRHO.BDT 005 LSeLDT 063 SSl,LDT 000 SlRH,LDT ,508 GR,LDT 186 RTNR.CN~ 825 RCNT,CNL 307 GR.CNL 500 TENS,~bT 539 07 ~ 69~GR 2 096 DRHO 125 130 StRH 501,667 GR oI b D! LDT .bDl bDT CNb CNB 56,~38 8, 47 97~50! -0 2 0 119 1302 8 52 50 398 83 8 TENS MbT ILM,DIL 02~ GR,DIb 139 DRHO;LDT 006 BS,bDT 063 SSi.bDT 000 S1RH~LDT 719 GR,bDT 553 RTNR*CNB 400 RCNT'CNb 291 _ GR*CN 375 TENS.fib~ 6O2 930 2 181 0020 875 ooo 8 508 38 36 969 638 679 58 875 8 516 IbM,DIL GR,DIb DRHO,bDT LS,LDT SS!,BDT $1RH,bDT GR,bDT RTNR,CNB RCNT,CNB GR,CNL TENS.MBT PAGE: 12 7 344 ~0 3'210 5~0 1605 i 085 s 48 i 500 15'15 1 o' ! 2 5 0,00 446d75~ 215.31'5 406 205. 000 2.23 2333 639 000 IS Tape Verification Listing chlumberger Alaska Computing Center DEPT. 3200.00(i! ILD.Dlb SFLU.DIb 9.046 SFbA.DIL TENS.DIb !020.000 DPHI.bDT PEF,LDT 3,559 OLS,LDT LU.LDT 319.000 Lb.bDT $S2.LDT 296.750 LSMV,LDT bSRH.LDT 2,275 LURM,LDT TENS.bDT 1525,000 R0.CSU TNPH.CNL 40.056 TNRA,CNL RCFT,CNb 538,550 CNTC,CNL CALl.CML 8.508 TENS,CML B~IN.MLT 2,109 BMNO,MLT DEpT. SFLU.DIL TENS.DIb PEF.LDT LU.LDT SS2.LDT LSRH.LDT TENS.bDT TNPH.CNL RCFT.CNL CALI.CNL BMIN.MLT 3i0~.000 ,475 980,000 3.090 4!6.750 3i2,000 2,123 1455 000 42 483 526 081 8 633 I 150 ILD.DIL SFLA.)IL DPHI bDT ~LS bDT LL bDT LSHV bDT LURH bDT RO CSU TNRA.CNL CNTC CNb TENS CML B~NO~bT SFbU.DIb TEMS.DIL PEF bDT LU* .bDT SS2.bDT LSR~.LDT TENS.bDT TNPM,CML RCFT.CNL CALI.CN5 BMIN.MLT 3000.000 8,029 95O 000 428.000 336,250 2,11~ 1430,000 48.946 432.315 8.844 1,111 ILD.DIL SFLA,DIL DPHI.LDT OLS,LDT Lb,bDT LS~V,LDT bURN.bDT R0 CSU TNRA CNb CNTC CNb TENS CNL BMNO MbT DFPT. SFLU.DIL TEMS.DIb PEF.LDT LU bDT SSg:LDT LSRM.LDT TENS.bDT TMPH.CNL RCFT CML CALl:CML B~{IM.MLT 2900.000 9.532 920,000 3.133 321,500 297.250 2.271 1395.000 37,301 557,657 8.680 1.805 ILD.DIL ~FbA,DIb DPHI.bDT OLS,LDT bb. LDT LSHV.LDT LURH bDT RO:CSU TNRA.CNL CNTC.CNL TENS.CML 8'dAN-1991 01:56 11,637 0 007 184 500 1208 000 2 2 268 11,396 8,480 32~]44 2; 'oo ,875 1208,000 , 0 ]'527 1859~068 1455'000 1,400 9 639 .o 245 1208 0 3 ~'~2 1599 1430 1,117 10:1 9 2~,212 0,009 186,625 1209.000 5 3.285 1731,340 1395,000 2.109 CILD.DIL SP,DIL RHOB,LDT OSS,bDT LITH.LDT SSHV,LDT CALI,LDT NPHI,CNb NPOR.CNb CFTC,CML GR.MLT SCAb,MbT RMO8 bDT IT bDT CALI,LDT NPHI.CNb NPOR CNL CFTC CML GR SCAb MbT CILD SP RHOB bDT OSS bDT bi. TH bDT SSHV,bDT CAbI,bDT NPHI,CNb NPOR,CNL CFTC,CML .GR,MbT MCAb,MbT CILD.OIb RMOB,bDT QSS,LDT LITH,bDT SSHV,hDT CALI,LDT NPHI.CNL NPOR,CNL CFTC.CML GR.MLT MCAL.~LT 85,931 2.893 .272 g. ½o 92. 5 1303, 40,146 39. 5O8 IbM DIL GR DXL DRHO bDT LS bDT SSi bDT SiRH bDT GR bDT RTNR'CNL RCNT'CNL GR'CNb TENS,MbT 87 754 19 297 2 0 130 ~302 8 43 42 532 48 8 Ib~ DIL GR DI~ .DRHO~bD 750 SSI 000 $'IRH :813 TENS 422 bDT bDT bDT MbT 103 742 0 .499 2 ,178 0,050 !16.,813 1301.000 8~.844 50,225 50,~39 410.681 83.250 8,945 ILM.DXb GR DRHO bDT S1RH bDT GR bDT RTNR CNb RCNT CNb GR CN TENS 92 1 2 0 96 1302 8 39 37 546 64 8 938 000 $1RH 68O OR 006 RTNR 667 RCNT 890 GE 250 TENS .547 bDT ,bDT ,bDT ,tNb CNL OO6 200'I~5 1 -0;010 454,2§0 206.~,375 2~I64 48:i~13 :3,'24 2111;I77 8,6.13 1455~000 9007 50 459 !744 0 64 250 IS Tape Verification bistinq chlumberoer Alaska Computlnq Center DEPT, SFLU,DIL TENS,DIE LU.LDT $S2,LDT LSRH,LDT TENS,bDT TNPH,CNL RCFT.CNL CALI,CNL B~IN,MLT 2800,000 8.662 870,000 4,020 376,500 316,000 2 176 1380 000 47 466 451 302 8 695 1,404 ILD,DI5 SFLA.DIL DPHI.LDT OLS.LDT LLLDT 5SHY LDT LURH LDT ROCSU TNRA CNb CNTC CNb TENS CNL BMNO MLT DEPT. SFLU,DIL TENS.DIE PEF.LDT LU.LDT LSRH.LDT TENS LDT TNPH:C~{L RCFT,CNL CALI.CNL BMIN.MLT 2700,000 10.978 835,000 33 000 1385,000 518,190 8.563 1,444 ILD SFEA DIE DPHI bDT OLS bDT Lb bDT GSHV bDT LURH bDT RO CSU TNRA CNL CNTC CNL TENS CNL BMNO MLT D~PT. SFLU,DIL TENS.DIE PEF.LDT LU,bDT SS2,LDT LSRH,LDT TENS.bDT TN'PH,CNL RCFT.CNE C~LI.CNL B~IN.MbT 2600.000 8,786 805.000 3.762 354,250 308.000 2 219 1340 000 42 829 471 795 8 680 1 751 ILD,DIb SFLA,DIb DPHILDT OL$.LDT kb bDT bSHV bDT LURH bDT RO CSU TNRA CNE CMTC. CNb TEN$.CNL BMNO MbT DEPT. SFEU.DIL TENS DIE PEF:EDT LU.LDT SS2,bDT LSRH,LDT TENS.bDT TNPH.CMb RCFT.CNL CALI,CNL BMIN,~LT 250~.000 780 00 3,100 ~4.500 8.250 2.104 1310o000 41.504 519,209 8.570 1.21~ XED,DIE $FLA.DIL DPHI,LDT QL$,LDT bE,bDT LSHV.LDT bURH bDT RO CSU TNRA CNL CNTC CNb TENS,CNL BMNO'~LT '8-JAN-1991 01:56 9 905 27,619 0,006 222'000 1208.000 2.193 156~.847 138 .000 1.543 1 63 2 097 -0 004 193 125 1208 000 1~ 258 211 177~ '562 ,544 1385,000 1,755 26 3 ,'0 0 120~ 000 1,844 7.~84 25O 1207.000 2,1~3 6,~ 0 , 508 176 .667 1310.000 1,488 CILD,DIb SP.,DIL RHOB,bDT OS$,bDT bITH,LDT $SHV,LDT CALI bDT NPHI CNb NPOR CNL CFTC CNL GR MLT ~CAL,MLT CILDi~IL SP RHOBbDT OSS bDT EITH bDT SSH¥ bDT CAL~ bDT NPH! CNb NPOR~CNb CFTC CNb GR MCAL MbT CIbD DIE RHOB bDT OS$ bDT LITH bDT $SHV bDT CAL~ bDT NPHI CNL NPOR CNL CFTC CNL GR MbT MCAL MbT CIbD,DXL RHOB,bDT OSS'.LDT bITH~LDT SSHV'bDT CALI,bDT NPHI,CNb NPOR,CNL CFTC'CNL GR,MLT MCAL'MLT 10~.355 !b~ DIE ~480 OR , 194 DRHO .'039 bS 106.125 SSI 130~*,000 $.XRH ,695 GR 52,488 RTNR 49'844 RCNT 4~,059 G~ MbT ,000 TEN 8,852 bDT bDT ~DT bDT CNL 79,585 10'813 2'252 0,008 94,813 1302'000 8.563 44'244 44~427 501',340 70,000 8~477 XLM GR ~X'bXb DRHO DT LS:~DT SSl. LDT S1RH bDT GR bDT RTNR CNL RCNT CNL GR CNb TENS.MbT 86 039 .2 !3 0 95 13082 44 42 486 73, 8 ILM.DtL 58 GR,DIL 14 DRHO,LDT 003 b~,bDT 063 SS ,bDT 000 $1RH'.hDT 680 GR'LDT 0 RTNR,CNL .866 GR,CNb 1½8842 TENS.MbT 2 0 8 4~ 40 514 46 8 IbM, GR 096 DRHO 009 875 000 $1RH 570 OR 240 RTNR 50 RCNT 59 UR bDT bDT bDT bDT CNL CNL 094 TENS.MbT 602 PAGE{ 14 87.250 0,016 410,250 2i8'290 2,i15 89.000 0,003 36t,500 207,250 2.2~4 ?o;ooo 3.894 196~.i5'94 ? ,.000 1.385,000 10'.105 6'5,.375 ~0,006 +000 0~00 47i.,~50~ 2, 41 3.700 2035~02 46. 94 1310,000 IS Teoe Verification Listing ChlUmberqer Alaska CoMputing Center DEPT 2400,000 IgO.DIL SDLU° TEN$.DIL 8.018 SFLA.DIL .DIL 775,000 DPHI.LDT PEF gDT 1,461 QLS.LDT LU gDT 1115.000 Lb. LDT S82 LDT ]60.000 bSMV.LDT LSRM.LDT 1.604 LURH.LDT TENS.gDT 1295,000 RO,CSU TNPH.CNL 58.273 TNRA.CNg RCFT.CNL 274.695 CNTC,CNL CALI.CNL 8.547 TENS.CML BMIN.MLT 12.094 BMNO.MLT DMPT. MFgU.DIL TENS.LIb PEF.bDT LU.gDT SS2.LDT LSRM.LDT TENS.bDT TNPM.CNg RCFT.CNL CAgI.CNL B~IN.MLT 2300 000 4 588 760 000 3 496 323 750 295 500 2 260 ~250 000 38 870 566 667 8 08 ILL.LIb SFLA.DIL DPHI,LDT .OLq. gDT bt,bDT LSHV,LDT bURM'LDT RO,CSU TNRA. L CNTC.~N TENS'CNL BNNO.MgT DEPT. SFbU TMNS:DtL PEF.gDT gU.bDT $$2.gDT LSRM.LDT TENS.bDT TNPH.CNL RCFT.CMg CALl.CNg BMIN.MbT 2200 000 4 622 765 000 3 078 335 500 297 000 2 252 1230 000 4I 704 549 761 8 508 1 551 DPHI;~gDT ~LS,LDT LL'[,DT LSH¥~LDT bURH.LDT RO CMU TNRAiCNL CNTCCNb TENS.CML B~NO,MLT DEPT. SFLU.DIg TENS.LIt PEF.gDT bU,LDT $S2.LDT LSRH.gDT TENS.LDT TNPH.CML RCFT.CNL CaLl.CML B~IN.~LT 2100.000 11.267 2100 000 75 438 206 125 114 625 2.510 1235,000 52 291 321:30o 8,875 0,004 ILD.DIb SFbA'DIL DPHI,LDT QLS,LDT gL,bDT LSHV,LDT bURN.bDT RO.CSU TNRA CNL CNTC CML TENS CML B~NO MLT 8-JAM-1991 01:56 9,884 8,803 64,540 0,001 609,500 1207'000 1,618 1 589 5 039 1395 11 1295 00~ 16 016 4,893 4,657 24.460 oo o 4 51 0 12 469 3 552 !864 544 ~230 000 1 861 5.146 5~ '169 '476 0,~26 ,000 6 4'175 1283.657 1235,000 0.000 CILD.DIL SP.DIg RHOB.gDT OSS bDT LITH gDT SMHV bDT CALI bDT NPHi,CNL NPOR.CNL CFTC,CNL GR~MLT MCAL,M~T SP'DIL QMS,bDT L!TH,bDT SSHV~LDT CALI,LDT NPHI.CNL NPOR'CNL CFTC,'CNL ~CAL,MLT CXLD IL G$~ bDT DITH LDT SS.Hr,bDT CAbI,bDT NPHI,CNL NPOR'CN~ CFTC,CNL <GR~MLT ~CAL,MLT CILD.DIL SP~DIL RHOB,LDT GMS'bDT LITH,bDT SSHV.LDT CALI.LDT NPHI.CNL NPOR.CNL CFTC.CML GR.MLT MCAL.MLT 8 1 0 419 13028 169 101 435 GR.DIL 585 DRMO bDT 030 gS bDT 750 SS1 bDT GR LDT 594 TENS 8 602 204'394 IbM.LIb 13,~34 _ GR'DIL 2,246 DRHO.LDT 0,000 bM.bDT 95,063 SMX,LDT X302~000 S1RH,LDT GR.~DT RTNR, CNL RCNT, CNL GR, CNL TENS'MbT GR DRHO LDT S$I.~DT SXRH LDT LDT 46 39~885 571,101 240, 2,~ 93 ~7 2'241 0.007 !02.813 508 GR 44 RTNR ;154 42,226 RCNT 542~869 GR 56,344 TENS 8,555 " · 3 OR'P.Zb I ~,~69 DRHO.~DT -0~150 LS,LDT 23 297 S$1,LDT 1302,000 $1RH,LDT 8875 GR,LDT 55 000 RTNR,CNL 52 29 RCNT'CNL 313 78~ GR'CNh PAGE~ 15 49,594 1295~000 I ~00 1250,000 0.7 4 6~8 56 · -0 0'~2 360 "/ 0 198, 6 5 2~,: 99 56,~44 20 ~,u~z 56,344 12{0,000 55,3?3 9,063 -0~8~4 6ii563 4,320 41,53! 4~463 1447,485 t235,06~ IS TaLe Verification Listing chlumberger .Alaska Computing Center D~PT. SFLU.DIL TENS.LIb PEF,LDT LU.LDT SS2.LDT LSRN,LDT TEN$.LDT TNPH.CNL RCFT.CNL CALI.CNL B~IN.MLT 200O 000 6 662 2100 000 -999 250 -999 250 -999 250 -999'250 -999,250 -999,250 -999,250 -999.250 -999.250 ILD.DIL SFbA.DIL DPHI.LDT QLS.LDT LL.LDT LSHV,LDT LURH.LDT RO,CSU TNRA;CNL CNTC~CNL TENS,CN5 B~NO.MLT DEPT. SFLU.DIL TENS.DIL PEF LDT LU LDT S$~ bDT LSRH.LDT TENS.bDT TNPN,CNL RCFT.CNL CALl CNL BMIN:~LT ~900,000 8;160 100,000 999~250 999,250 999,250 '999,~50 '999, 50 "999,250 '999,250 "999,250 '999,~50 ILD.DIL SFLA DIL DPHI LDT 055 DDT 55 bDT LSHV bDT LURH,SDT RO.CSU TNRA,CN5 CNTC.CNL TENS'CNL BMNO,~LT DEPT SFbU, D I b TENS,LIb PEF.LDT LU.LDT SS~,LDT LSRH.LDT TENS,bDT TNPH,CNL RCFT CNL CALI:CNL BMIN,MbT 1800,000 7,786 21.04,000 -999 250 -999 250 -999 250 -999 250 -999,250 -999.250 -999,250 -999'250 -999~250 ILD.DIb SFLA,DI5 DPH!'LDT S,bDT B.LDT LSHV,LDT LURH.LDT TNRA, L CNTC,CNL TEN$.CNL BMNO.MLT DEPT. SFLU,DIL TENS.DIL PEF.LDT LU bDT SS?~DT LSRH,LDT TE~S.LDT TNPF.CNL RCFT.CNL CALI.CNL BNIN.~L~ 1700,000 5,490 999~250 999,250 .999,250 -999 250 -999:250 -999,250 -999,250 -999 250 -999:250 ILO,DIL SFLA,DIL DPHI,LDT OL$,LDT LL,LDT LSHV,LDT LURH.LPT RO,CSU TNRA.CNL CNTC.CNL TENS,CN5 B~NO.MLT 8-jAN-1991 01:56 5 570 761 -99~ 250 -999 250 -999 250 99 0 *999 250 -999 ~50 -99 50 '999 50 4.83] 7,929 *999,250 -999.~50 -999,250 -99' 1250 -99 250 -999 250 -999 250 -999 250 -999 250 -999 250 5. 37 -999 ~50 -99~ 50 -99 50 -999 ~50 -99 ~ 0 -999 50 -999 ~50 -999~250 6.124 5 558 -999 250 -999 250 999 250 -999 ~50 *999 50 -999 250 -999 250 -999 250 -999 250 CIbD,DIL SP,DIL RHOB.LDT QSS,bDT LITH,LDT SSHV,LDT CALI,~DT NPHI,CNb NPOR,CNL CFTC,CNL GR,MbT ~CAL,MbT ClLD,DIL RHOB'LDT QSS'LDT 5ITH'LDT SSHV,LDT CALX,bDT NPHI,CNb NPOR,CNb CFTC;CNL GR,NbT MCAb,~LT CIbD, DIL SP..DIb RHOB bDT QS$ bDT LITH bDT SSHV bDT CAbI bDT NPHZ CNL NPOR~CNL CFTC CN5 GR~NLT CILD~DIL SP,DIb RHOB,LDT OSS~LDT LITHebDT SSHV,bDT CALX'bDT NPHI'CNb NPOR,CNL CFTC,CNL GR,MLT ~CAL,~LT 179 538 ILM.DIb '29 797 GR,DIL -999 250 DRHO.LDT '999 250 kS.bDT '999 250 SSI.bDT '999 250 SIRH.LDT '999 250 GR,LDT -999:250 RTNR,CNL -999 250 RCNT,CNL -999 250 GR.,CNL -999 ~50 TENS,MbT -999 250 206,902 IbM -230,750 GR DIL :99 ;250 LS bDT 99~,250 DRHO bDT -999'250 SSi bDT -g99'250 SXRH bDT '999'r!So CNL -9 50 RCNT '9 9;2'999'2 0 TENS 9 0 -6 ~17 O0 GR -99~ 250 DRHO.bD -999,~ 50 bS ~bDT -99, ~50 SSi,bDT !50 GR,bDT -999 iO RTNR CNL -999 ~0 RCNT CNL -999 ' -999:250 163.287 -41,000 GR,D25 -999,250 DRHO,bDT -999,250 bS'bDT -999'250" SSl~bDT -999'250 SlRH,LDT :999,250 GR,bDT .999.250 RTNR,CNL .999,250 RCNT.CNL .999.250 GR.CNL ,999"~50 TENS,N~T 999.250 PAGE{ 16 5,513' -99~'290 -99 ~250 "999~,250 "999'~250 "999~50 60 "99 "'9' "999~ '999, '999 '999 69'.18 '99~d -999+250 -999 -999 ~0 '999 ~50 Tame Verificatlom Listing ~chlumberqer AlasKa Computinq Center DFPT, SFbU.DIL TENS.OIL PEF,LDT LU.LDT SS2,LDT LSRH.LDT TENS.bDT TMPH,CNL RCFT,CNL CALi,CNL BMIN.MLT 1600 DO0 9 696 2110 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ILD SFL.~,DIL DPHI,LDT OLS.LDT Lb.bDT LSHV bDT bURH bDT RO CSU TNRA CML CNTC CNL TENS CNb BMNO,MLT DEPT SFLU DIL TENS mIL PEr bDT LU.LDT S$2,LDT LS~M,LDT TENS,bDT RCFT.CML CALI CNL BMIN:MbT 1500,000 ~10 0o0 '999,250 '999~50 '999,250 '999,250 '999.250 '999.~50 '999.250 '999.~50 '999,250 ILD,DIL SFLA,DIL DPHI.LDT QLS,LDT LL bDT LSHV~LDT LURH,LDT RO,CSU TNRA.CNb CMTC.CNL TEN$~CNb DEPT. SFLU.DIL TENS.mIL PEF.bDT LU.LDT SSa.bDT LSRH.LDT TENS bDT TNPM:CNL RCFT.CNL CALI.CNL B~IN.MbT 1400 000 6 432 2110 000 -999 50 -999 ~6 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ILD SFLA DPHI bDT Ob$ LDT Lb. bDT LSHV, LDT LURH LDT ROCSU TNRA CNb CNTC,CNL TENS,CNb BMNO.MLT DEPT. SFLU.DIL TENS.DIL PEF.bDT LU,LDT SS~.LDT LSRH.bDT TENS.bDT TNP~.CML RCFT.CNb CALI,CNL B~IN.MLT 1300,000 4,894 104 000 999~250 999.250 '999.250 '999 250 '999 250 -999 25~ -999 250 -999.250 -999,250 I~D,DIL SFbA.DIb DPHI,bDT QLS.LDT Lb,bDT bSHV,bDT LURH.LDT RO,CSU TNRA:~N~ CNTC Nb TENS.CNL BMNO.~LT 8-JAN-1991 01:56 9,011 -999 0 -999 0 '999 250 "999 250 5O '999 ~5 '999 0 -999 250 '999 250 -999 250 7.018 8,881 -999,~50 -999,250 -999,250 '999,250 -999o250 -999,~50 -999.2~0 -999,2 0 -9 ; 50 5 079 539 -99 250 -999 250 "999 250 -99 50 -99g 50 -99 ~50 '999 50 '999 ~50 -999 50 3.951 4 128 -999 250 ~999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 '999 250 '999 250 CILD,DIb SP,DIL RHOB,GDT OSS,bDT 5ITH,LDT SSHV,GDT CALI,LDT NPHI.CNL NPOR,CNL CFTC,CNb GR,MLT ~CAL,MbT CILD DIL RHOB bDT Q$SbDT LITH bDT SSHV.~DT C~LI.LDT NPHI CNL NPOR CNL CFtC CN~ GR MbT MC~L MbT CI~D DI~ $ P .D I L RHDB ~DT bDT $SHV LDT CA~ bDT NPOR ,CN6 CFTC CN5 MCAL ,NLT CI.TD,DIb RHOB.bDT O$$,~DT $SHV,LDT CALI.LDT NPHI,CNL NPOR.CNb CFTC.CN5 GR.MLT MCAL.~LT 110.973 -66 000 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 250 DRHO.LDT 250 LS.LDT 250 $$1,LDT 250 S!RH~LDT ~50 GR,LDT ~50 RTNR,CNL ~50 RCNT~CN5 ~50 GR,CNL 250 TENS,~LT ~50 142,481 IL~,DIL '59,!88 GR,DIL i99925 0 DRHO,bDT 999;250 LS.;LDT 999,~50 .999,250 99'250 GR,LDT '~99,250 RTNR,CNL i 99;250 RCNT,CNL ~99..250 GR'CN.~ 999 0 60'531 GR,DI~ -999°:250 -999,250 -999~250 S$1,~DT -999,250 $1RNe~DT -999,250 GR.LDT -999,250 RTNR'CNh :999,250 .999.250 -999,:.250 TENS,~bT -999;25O 253 -53 -999 -999 -999 -999 -999 -999 -999 -999 86 DRHOLDT ~250 LS,~DT 250 SSI,~DT 250 $1RH~LDT 250 250 R~NR CNb 250 RCN? CNb 250 GR CNb 250 250 PAGEl 1,7 8,929 68'813 -999,250 '999,.250 '999,250 .999'250 .999,250 ~999,250 ,999,250 999,250 -995~ 0 '-99 ~ 0 ~999.250 "999,250 5'~',' 5 -999,250 :-999.~0 ~- 0 3:,8~5 . 68~3~3 ..999~250 .999,250 999'250 -999~,250 -999 250 -999 250 -999 2 0 -999 210 -999 250 IS TaDe Veri~icatlon Llstino chlUmberoer Alaska Computin~ Center DFPT. 1200.000 SFLU.DIL 6 099 TEN$.DIL 2100:000 PEF.LDT -999.250 L[!.LDT -999.250 SS2.LDT -999.250 LSR~{.LDT -999.250 TENS.LDT -999.250 -999.250 TNP~.CNL RCFT.CNL -999.250 CALI.CNL -999.250 BMIN.MLT -999.250 ILD.DIL SFLA.DI5 DPHI.LDT OLS.LDT LL.LDT LSHV LDT LURH LDT RO CSU TNRA CNL CNTC CNL TENS CNL BMNO,MLT DEPT. 1100,000 SFLU.DIL 60.643 TEN$.DIL !124,000 PEF.LDT .999,250 LU.LDT 999.250 SS2.LDT 999.250 LSRH.LDT :999,250 TE~S.LDT .999,.2'50 TNP~.CNL 999.250 RCF .CNL :999"250 C~LI.CNL . 999.250 B~I~.~LT -9991250 ILD DIL SFLA DIL DPHI LDT LL LDT bSHV LDT LURH.LDT RO,CSU TNRA.CNL CNTC.CNL BMN MLT DEPT 1000.000 SFLU:DIL 15,.100 TENS.DiL PEF'LDT 999'250 LU.LDT -999.250 SS2 LDT -999.250 LSR~:LDT -999.250 TEN$.SDT -999,250 TNPH.CNL -999,250 RCFT,CNL -999~250 CALI CNL -999,250 ~IN:MLT -999;250 ILD.DIL DP~ bDT L bDT bUR LDT R0 CSU TNRA~CN~ CNTC,CNL TEN$.CN5 BMNO,MLT DEPT. 900 000 ILD.DIL SFLU.DIL 76:780 SFLA.DIL TENS.DIL ~094,000 DPHIeLDT PEF.LDT 999.250 OLS,LDT LU.LDT -999,250 SS2.LDT -999.250 LSHV.LDT LSRH LDT -999,250 5URH,LDT TEN$:LDT -999.250 RO.CSU TNP~.CML -999.250 TNRA.CNL 999 250 CNTC.CNL RCFT.CML ~ C~LI.CNL ~99.250 TENS.CNL B~I~.MLT ' 99.250 BMNO.MLT 8-JAN-199~ 01:56 4.937 6 090 -999 250 -999 250 -999 250 -999 ~§0 -999 50 -999 250 -999 5O -999 2 0 -999 250 CILD.DIL SP'DIL RHOB.LDT OSS LDT LITH 5DT SSHV LDT CALI LDT NPHI CNL NPOR CNL CFTC CNL ~CAL MLT 58 58 -999 -999 -999 -99~ -999 -999 -999 -9 9 550 CILD,DIL 909 SP,DI5 250 RHOB;~DT 250 OS$;LDT 250 5ITH.'LDT 250 SSHV,LDT 250 CALI,.LDT 250 NPHi,CNL 250 NPOR,CN5 250 CFTC'CN~ 250 GR,.MLT 250 MCA~.,MLT ! 3 99~ 50 i99~ 50 999 50 -99~ 50 "9 9 ~0 -999 2 0 -999 250 -999 250 -999 250 CIbD. DIL SP~DIL RHOBbDT OSS bDT LITHbDT SSHV bDT CALI ~DT NPHt CNL NPORCNL CFTC,CN5 GR,.MLT MCAS,MLT 96 83 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 559 683 250 250 250 250 250 250 250 5O RHOB'LDT OSS,LDT LITH,LDT SSHV'~DT CALI,LDT NPHI,CNL NPOR.CNL CFTC,CNL GR,MLT NCAS.MLT 202.567 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 1 5 UR 0 DRHO i~50 LS 50 SSi 50 SIRH 50 ~50 RTNR 250 RCNT 50 GR 50 TENS 25O ILM DIL LDT LDT LDT .DT CNL 17,079 -91.,688 GR. -999~250 DRHO -999"250 -999.250 -999'250 SIRH -999..250 GR -999: RCNT -999 GR -9991~$6 TENS -999,290 i DRHO -999'.250 RTNR "999~250 RCNT -999,250 GR -999.250 TENS -999,~50 5DT LDT LDT LDT LDT .DI.L bDT I.,DT ' ,563 GR,DIL -~99,250 DRHO LDT - 99,250 L$ 5DT -999;250 SSI .~DT -999.250 $1RH ~DT :999,250 GR ~DT 999.250 RTNR..CNL :999.250 RCNT.CN~ .999,250 GR ~N~ 999,250 TENS -999.250 PAGE,' :18 4'8?8 . 57,250 :999,250 .999;;250 999,250 -999,250 -999,250 -999{250 -999~250 -999,250 -999,250 '99'9'250 '999,250 -9991250 '999{250 '999~*'250 :999.250 .999,250 '999ai w999~ '999,~ '999' '999.25 '999~250 ~999'250 IS Tape Verification Listing chlumberger Alaska Computing Center 8-JAN-1991 01:56 DEPT. 800.000 ILO.DIL SFLIf,DIL 66.209 SFLA.DiL TENS.DIL 2074.000 DPHI,LDT PEF bDT -999.250 QLS,LDT ,LDT '999,250 LL.LDT SS2.LDT -999.250 LSHV .bDT LSRH.LDT -999,250 LURH;LDT TENS.LDT -999,250 RO.CSU TNPN.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC'CNL CAbI.CN5 -999,250 TENS.CNL BMIN.MLT -999.250 BMNO.MLT DEPT SFLU.DI5 TENS.DIL PEF.LDT bU'bDT $S~,LDT LSR~,bDT TENS bDT TNP~ CNL RCFT CNL DEPT. SFLU,OIL TEMS.DIL PEF,LDT LU.LDT $S~,LDT LSRM,LDT TENS.bDT TNPM.CNb RCFT.CNL CALI.CNL BMIN.MLT DEPT. SFLU.DIL TENS.bib PEF.LDT LU.bDT SS2.LDT LSRH.LDT TENS.bDT TNP~.CNL RCFT.CNL CALI.C~5 B~IN.MbT 354 2050 0o0 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999'250 -999.~50 -999.250 600,000 179,439 2045.000 -999.250 -999,250 -999.250 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 50 000 2064,000 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999.250 -999,250 -999,250 ILD.DIL SFLA,DIb DPHI,LDT QLS,LDT Lb'bDT bSHV,LDT LURH,LDT RO.CSU TNRA CNL CNTC CNL TENS CNb BMNO MbT IbD,DIb SFLA,DIb DPMI~LDT OhS,bDT Lb,bDT LSHV,LDT bURH~LDT RO,CSU TNRA,CNb CNTC~CNb TENS,CNL BMNO,MbT IbD.DIb SFLA.DIb DPHI'bDT OhS,bDT Lb.bDT bSHV,LDT LURH,bDT RO,CSU TNRA.CNL CNTC,CND TENS,CN~ BMNO.MbT 102 657 97 216 -999 250 -999 250 -999 ~50 -999 250 -999 250 999 250 999 250 -999 250 -999 ~50 -999 250 -99 250 -9999 250 '999 ~ '99 0 "999 0 '999 ~ 0 -999 50 78 535 125 560 -999 250 25O '999 250 ~999 ~50 '999 250 -999 250 -999 250 -999 250 -999 250 6 81 5O 999 0 -999 ~50 -999 250 -999 ~50 -999 ~50 -999 250 -999 250 -999 250 -999 250 CILD,DIL SP.DIb RHOB.LDT QSS,LDT LITH'LDT SSHV,LDT CALI,bDT NPHI,CNL NPOR.CNL CFTC.CNL GR,NLT NCAL.NLT CXLD,DIU ,bDT ,LOT LI~'bDT SSH ~LDT C~L~,~DT NPM .CNL ,DIb RM~B,bDT · DT SSHV'bDT CA.~I'~DT NPMI'CNL NP~R,CNL CF~C,CNb ~R.MbT CILD,DXb SP,DX~ RHOB,bDT SSMV.bDT CAbI:~DT NPHI Nb NPOR,CN5 CFTC,CNL GR,NLT ~CAL,NLT 9 741 IL~.DIb -108 063 GR.DIL -999 250 DRHO.LDT -999 250 L$.'LDT -999 ~50 $MI,LDT -999 250 S~RH.~DT -999 250 GR,LDT -999 ~50 RTNR CNL -999 ~50 RCNT CNL -999 250 GR CNL -999.250 TENS MbT -999~50 -105 0 '99~..250 -999 ~50 50 -999 250 ~-999 !50 -999 50 -999~ 50 -999,,~250 -999,250 ~1~9'250 '999,250 .DRHO -999,250 -999.~50 -999;250 $1RH -999'.250 GR -999,) RCNT -999. 50 GR -999,)50 TENS -999, 50 GR'DIL DRHO,LDT LS:,LDT SSI~LDT SlRH,LDT GR.bDT RTNR.,CNb RCNT,CNb GR.CNb TENS,M~T DIL bDT bDT bDT LDT ,MbT 15,581 '!23.063 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 GR,DIh 250 DRHO,bDT 250 LS.LDT ~50 SSi,bDT 250 SXRH,bDT 250 GR bDT 250 RTNR CNb 250 RCNT CNL ~50 GR CNL 250 TENS MbT ~50 PAG . t9 79 786 54 969 -999 250 -999 250 -999 250 ~999 250 -999 250 -999 250 '~999 51,464 , 50,344 ..999,250 999,..250 -999~250 -999,250 -999,2~0 -999~250 -999,250 ~999,250 .99 0 9~9,,250 -999~250 -999,250 49,387 :'999,250 "999,250 9 ~2 0 -999,250 ~999'.250 ~999.250 ~999~250 '999'250 IS Ta~e Verification Listina chlumberger AlasKa ComPutin.~ Center DEPT. SFLU.DIL TENS.DIL PEF.LDT LU.LDT SS2.LDT 5SRH.LDT TENS.LDT TNPH CNL RCF!' ChbI 'CNL ,CNL B~IN.MLT 400.000 2000.000 2045.000 '999,250 '999.250 '999,250 '999.250 '999 250 '999 250 '999 250 '999 250 -999 250 ILD.DIL SFLA.DI5 DPHI LDT OLS LDT DSHV,LDT LURH,LDT RO CSU TNRA CNL CNTC CNL TENS CNL BMNO.MLT DEPT SFLU:.DIL TENS.DIL PEF.LDT LU.LDT SS2.LDT LSRM LDT TENS:LDT TNPH.CNL RCFT.CN5 CALI.CNL B~IN.~LT 30O 000 2000 000 2025 000 -9gg 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 '999,250 '999,250 SFLA DPHI ~DT QD$ LDT 5L LDT LSHV 5DT LURH LDT RO CSU TNRACNL CNTCCNL TEN$.CNL BMNO,~LT DEPT. SFLU.DIL TENS.DIb PEF.LDT 5U.LDT SS2.LDT LSR~.LDT TENS LDT RCFT,CNL CALI.CNL B~IN.MLT 200.000 56,.487 2020,000 'ggg~250 -999~250 -999,250 -999,250 -999.250 -999.250 -999.250 -999,~0 -999, 0 SFSA I5 DPHI~SDT ~QL$,LDT LL,LDT LSHV,LDT LURH.LDT R0.CSU TNRA,CN~ C~TC.C~L TENS'C~ B~NO'~LT DEPT SFLU:DIL TENS.DIL PEF.LDT LU 5DT SS~:LDT LSR~.LDT TENS.LDT TNPH.CNL RCF~.CN5 C~LI.CNL 8MIN.~LT 119,500 1,262 i995 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ILD DI5 SFSA:DIL DPHI,LDT LL.SDT 5$HV,LDT LURH'LDT RO.CSU TNRA.CNL CNTC,CN5 TENS.CN~ BMNO.~LT 01:56 ~00 000 SP,.DIL 99 250 ~SS.~DT -99 250 SSHV.LDT NPHI CN5 -999' so NPO :C L 50 '999'15 ,MLT '999. 0 MCAL 182.406 1659.,5!0 -ggg. 50 "ggg ~50 '999 '50 'ggg ~50 -999 250 '999 250 :999 250 999 250 '999 250 '999 250 233.731 91,079 ~999,250 ~999,250 999,250 '999,250 ~999,250 '999,2~0 -999'250 :999,250 999,250 2000 000 .gg~ 263 25O -999 250 -999 250 -999 250 -999 250 -999 250 2999 999 -999 2~0 -999 2~0 CILD SP.DI5 RHO~ LDT ITD SH~ b T LDT CALI LDT NPH! CNL NPOR CNL CFTCCN5 GR,MLT ~CAL;~LT CILD,DIL SP'.DIL RHOB.5DT OSSLDT LITH LDT SSHV LDT CAL! LDT NPHi CNL NPOR CNL CFTC !NL GR! LT MCA5 bT CILD, IL RHOB'LDT OSS,LDT SSH BDT CALI,LDT NPHI,CNL NPOR,CNL CFTC,CN5 GR,~ST MCAL,~LT 4 589 -999 -999 -999~ -999 -999 -999 -999 -999 -999 IL~.DIL 06~ GR..DIL 250 DRHOLDT 250 5~ LDT 250 SS bDT 250 S1RH LDT 250 GR LDT 250 RTNRCNL 250 RCNTCNL :50 GR. CNL ~50 TENS. ~LT 250 5,482 · -134,750 GR -999'250 DRHO LD? '999~250 LS LDT -999,250 SS! LDT -999,:250 SIRH LDT -999-250 GR 5DT -~99;250 RTNR CNL - 99,250 RCNT -999,250 GR CNL -999,:250 TENS.M5T -999i250 4.278 Ib~ -78.563 'GR -999'250 DRHO '999.250 LS -999.,250 SS! -999"250 S1RH -999~250 GR -999;250 RTNR :999.,250 RCNT 999~250 GR :999,250 TENS 999~.250 D!L .LDT .LDT bDT '~51','7~6 ILM,DIb . 40-563 GR,DI~ .999'.250 DRHO.LDT -999.::250 L$'LDT -999.250 SSl,~DT -999 ~250 S~RH'~DT -999 250 GR .SDT -999 250 RTNR.CN5 -999 0 GR;CN~ '999 250 TENS,M~T -999 250 PAGE{ 20 71. 972 46,~71g ,-ggg, 250 '999:250 'ggg250 -999250 :~999 250 .ggg 2SO -g99~250 62 573 . :34 406 .999250 999250 -9'99250 -999~250 ggg~: 0 -ggg~250 44,188 "ggg,..250 "999,250 '"999"2S0 "999,250 2000"000 :35,281 -999~25~ -999~25 "999,25~ -999.25 -99,'I :999,.250 .gg :2,o Tape Verification t, isting rhlumberger Alaska Computing Center 8-JAN-1991 01:56 PAGE~ **** FILE TRAILER **** FILE NAME : EDIT ,001 SFRVICE : FLIC VERSION : 001A06 DATF : 91/01/ 8 MAX REC SIZE : 1024 FILF TYPE : bAST FILE **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 91101/ 8 ORIGIN : FblC TAPE NAME : 74273 CONTINUATION ~ PREVIOUS TAPE CO~MENT I CIRI PRODUCTION COMPANY,CIRI WEST FORK 1-21,50-133-20424 **** REEL TRAILER SERVICE NAmE : EDIT DATE : 91/01/ 8 ORIGIN : FLIC REEL NAME : 74273 CONTINUATION # : PREVIOUS REEL COMgENT = CIRI PRODUCTION CONPANY,CiRI WEST FORK
