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Home My WebLink About189-072RE: Ivan River Unit Disposal Subject: RE: Ivan River Unit Disposal _ Date: Mon, 4 Aug 2003 10:47:25 -0800 From: "Greenstein, Larry P" <greensteinlp@unocal.com> To: "Tom Maunder" <tom_maunder@admin.state.ak.us> CC: "Jim Regg" <jim_regg@admin.state.ak.us> You bet Tom. That is exactly what was going on last October. The reserve pit clean up (grind & inject) shut down then. The normal water production from all the wells at Ivan River is collected in a plastic tank on the pad. Once a week, or every other week, a water truck offioads what it can carry and delivers it to the plastic tanks at Lewis River D-1 disposal pad. After enough volume collects at Lewis River D-1 pad, the operator starts up the pumps and pushes the water into the D-1 disposal well. The D-1 well also handles the water, if any, from Pretty Creek CfA as well as the other Lewis River wells. Hope this is what you were looking for Tom. Larry ..... Original Message ..... From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, August 04, 2003 7:54 AM To: Larry Greenstein Cc: Jim Regg Subject: Ivan River Unit Disposal Hi Larry, I was looking at the DNR letter approving the Unit Operations Plan (dated July 24) and pulled up the production/disposal information. According to the information I was able to pull up, the last time there was any disposal into 14-31 was October of last year. I believe there was some reserve pit cleanup going on. Although the reported monthly water production is Iow, I am curious how that volume is being handled. Would you check into this and get back to me. Thanks. Tom Maunder, PE AOGCC SCANNEB' AIJG 0 4.__ 2003 8/4/200311:00 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor ~'\ DATE: Chair SUBJECT: THRU: Tom Maunder ~,.~ P.I. Supervisor 0,3 FROM: Jeff Jones Petroleum Inspector NON- CONFIDENTIAL August 26, '2002 Mechanical Integrity Tests Unocal D Pad D-01WD LRU Lewis River Field Packer Depth Pretest Initial 15 Min. 30 Min, We, J D-01WD J Type Inj. P.T.D.I 189-072 IType test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details AugUst 26, 2002: ] traveled to Unocal's Lewis River Field to witness an MIT on water injection well D-01WD. Bob St John was the Unocal representative today and he performed the test in a safe and proficient manner. The pretest pressures were monitored and observed to be stable. The standard annulus pressure test was then performed. The annulus was pressured up to 1600' PSI and this pressure dropped 70 PSI in a non-linear fashion during the 30 minute test and stabilized at 1530 PSI, passing the MIT. ·: I witnessed a successful MIT on Unocal's water injection well D-01WD in the Lewis River Field. M.I.T.'s performed: 1_ Attachments: Number of Failures: 0 -- Total Time during tests: 4 'hrs. CC: SCANNED OCT n. zJ: MIT report form 5/12/00 L.G. MIT LRU D-01WD 8-26-02 JJ.xls gl10/2002 DEPT. OF ENVIRONMENTAL CONSERVATION / TONY KNOWLE$, GOVERNOR DIVISION OF ENVIRONMENTAL HEALTH SOLID WASTE PROGRAM 410 WILLOUGHBY AVE JUNEAU, ALASKA 99687 http://www.state.ak.us/dec/deh Telephone: (907) 465-5162 Fax: (907) 465-5362 October 23,2001 Harry A. Eaton HES Manager Unocal Al~ka X~X~ 4 260 Cavi~ Street ?~ ~ I~-~X /°~koO//~ u Kenai, Alaska 99611 -- -- x~ ~.~ Reference: Issuance of Permanent Closur~Approval for Inactive Reserve Pi~ Iocatedat Lewis River A-l, B-l, C-l, D-rand Pretty Creek ~ 2 located onthe west side of Cook Inl~ t %t~-o~ ~ ~, Thc Alaska Dcp~ment of Environment~ Conservation (ADEC) has completed review and public notice for pc~anent closure approv~ for the above reference rese~e pits located in the Susitna ~ats State Game Refuge. The closure applications provided the required i.nfo~ation describing the histo~ of the rese~e pit(s), the present condition of the mse~e pits(s), results of any required water sampling and an assessment of thc potential risks posed by the drilling waste to human health and the environment. At these locations, the reserve pits are back~]]ed and them is no exposed dH]ling waste. ADEC coordinated scver~ field inspections of the sites with the Alaska Dep~ment of Fish and Game and the Alaska Dep~tment of Natural Resources. Public notice requesting comments on the closure requests was published September 20 and 21, 2001 in the Anchorage Daily News and posted on the state web site September 21, 2001. No public comments objecting to closure approval were received in response to this public notice. ADEC has determined that the reserve pit at this site meets the closure requirements of 18 AAC 60.440. Closure Approval Under authority of 18 AAC 60.440 (.j), ADEC grants permanent closure approval to Unocal Alaska for the inactive reserve pits at the following sites: Unocal Alaska Mr. Harry A. Eaton Well Name Lewis River I (A- 1) Lewis River B-1 Lewis River C-1 Lewis River D-1 '~' Pretty Creek #2 ~ Terms and Conditions API Number 50-283-20047-00 50-283-20052-00 50-283-20061-00 50-283-20068-00 50-283-20022-90 MTRS Sec. 02, T14N, R9W, SM Sec. ! 0, T 14N, R9W, SM ' Sec. 35, T I5N, R9W, SM Sec. 35, T 15N, R9W, SM Sec. 33, TI4N, R9W, SM October 23, 2001 Page 2 of 2 Landowner ADF&G/ADNR ADF&G/ADNR ADF&G/ADNR ADF&G/ADNR ADF&G/ADNR This permanent closure approval is subject to the following terms and conditions: 1) In accOrdance with 18 AAC 60.440(I), the Department will require additional investigation, assessment, monitoring or remediation if n6w information regarding conditions at the reserve pit facilities indicates that's further ~ctions .are necessary to protect human health or the environment. ~ ~ ~ 2) The approval granted by this letter is for the inactive drilling waste reserve pit(s) only. Closure for the pad as a whole (if required) must be coordinated between the owner/operator and the appropriat0, land owner/manager. ~ ~ .. .. Any person who disagrees with any portion of this decision may .request an adjudicatory hearing in accordance with 18 AAC 15.200z310. The reqffest should be mailed to.the Commissioner of the Department of Environmental Conservation, 555 Cordova Ave. Anchorage, AK 99501. If a hearing is not requested within thirty (30) days of the date of this letter, the right of appeal is waived. If an adjudicatory hearing is requested and .granted, this decision remains in full effect during the adjudicatory process. Sincerely, Heather Stockard Solid Waste Program Manager Heather S tockard @ envircon.state, ak.us cc: .~:.Tom..:Maunder~.AOGCC, Deborah Heebner, ADNR, Anchorage Wayne Dolezal, ADF&G, Anchorage John Hammelman, Unocal ¥,UI LEWIS RIVER D-1 DISPOSAL WELL 11/28198 1400 - Rigged up to empty storage tanks of water and perform MIT. 1500 - Began water disposal, Spent 1,5 hrs working ice plugs in lines and vibrations in pump through system. 1630 - Pumped casing pressure from 0 to 600# as tubing pressure ramped up from 1200# to 1500# as injection began. Let system stabilize. 11129198 0730 - System stable with pressures in casing at 400# and tubing at 2100#. 0800 - Final pressures had casing at 400# and tubing at 2100#, 0830 - Increased the annulus pressure from 400# to 1100# as tubing pressure remained stable at 2100#, 1030 - System stable with pressures in casing at 1100# and tubing at 2100#. 1100 - Final pressures had casing at 1 I00# and tubing at 2100#. Continued pumping until all water put away. Work performed by Dave Jaques DEC - 4 1998 uu eas Con, . Commis bn Post-it~ Fax Note ,7671 K, U~' /., / ,/'/ i ' t ., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: Dave Jaques FIELD ! UNIT / PAD: Lewis River DATE: 11/29/98 .. .............. PRETEST START 15 MIN" 30 'MIN ........ TBG. TYPE' PACKER! REQ . TBG. TIME TIME TIME WELL INJ TEST ANN. · 'FVD CASING TBG TEST CSG TaG TBG TBG START P F NAME FLUID= 'TYP. FLUID MD SIZE i WT I GRADE SIZE PRESS PRESS CSG CSG CSG TIME ................... PRESS, ~ ?RESS PRESS TVD ~1',200 2,100 2,100 ~, 100 730 - D. 1 PW M SW 2,295 9 5/8" 47# N-80 4 fl'2" . 0 400 40Q 400 29-Nov P co M N -S: ............................ D-f PW M SW 212~5I 95/8" 47# N-80 .4..1./2" - 400' 1, i'O0 f;lO0 l. l"~O01''1030 .......... . .... .29-Nov . . P . i'coMMENfS: ......... Increased cas!ng pressure te demonstrate integrity and monitored for 1/2 hour. COMMENTS: COMMENTS: c : I .__G. INJ. FLUID CODES FRESH WATER INJ. GAS INJ. SALT WATER INJ. NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST · R = INTERNAL PAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST Distribution: artg - Well File c - Operator c - Database c - Trip Rpl File c - Inspector OPERATOR REP SIGNATURE: Dave Jaques by Larry P. Greenstein Lr_dlmit,xls ANNULAR FLUID: P.P.G. Grad. WELL TEST: DIESEL i 0.00 Initial GLYCOL I 0.00 4- Year X SALT WATER i 0.'4'~i' .... Workover DRILLING MUD 0.00 Other OTHER 0.00 AOGCC REP SIGNATURE: in CONCURRENCE: (Rev 9t17196) STATE OF ALASKA ALASKA G,- AND GAS CONSERVATION ,uMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: x Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X GR 100'/115' KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Lewis River Unit 4. Location of well at surface 8. Well number 2086' FWL, 3168' FSL, Sec. 35, T15N, R9W, SM D-1 At top of productive interval 9. Permit number/approval number 89-72 At effective depth 10. APl number ~"~ :~.~ ~ ~' ~ i~~~,~ ,i.~,! .~ ~.,f" ~i 50- 283-20068-90 At total depth ~ J i~~ i' ~ ~ ~ ,~% L~ 11. Field/Pool Lewis River/Unnamed 12. Present well condition summary Total depth: measured 8025' feet Plugs (measured) N/A true vertical 8025' feet Effective depth: measured 3945' feet Junk (measured) N/A true vertical 3945' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 33' 30" Driven 33' 33' Intermediate 359' 20" 496 sxs 359' 359' Production 2395' 13-3/8" 850 sxs 2395' 2395' Liner 5135' 9-5/8" 1361 sxs 5135' 5135' Perforation depth: measured 2562-2596; 2850-2900; 2950-2960; 3020-3046; 3714-3768; 3873-3893; 3904-3918 true vertical Same Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 (internally coated) to 3584' Packers and SSSV (type and measured depth) "VST" Packer @ 2302', "BWD" Packer @ 3503' RECEIVED 13. Stimulation or cement squeeze summary [') E C 0 ~' '~996 Intervals treated (measured) Reperf'd 4 intervals on 7/2/96 - see attachment for details. Alaska 0il & Gas Cons. Commission Treatment description including volumes used and final pressure Anchorage 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 6/96 0 0 12 0 0 Subsequent to operation 7/96 0 0 39 0 1746 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Dale Haines /_.~, ~'. ~li ~{"-~' Title: Drilling Manager Date: November 26, 1996 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Lorn kews Ever D I APl No.'. 50-2S5 20065 90 0.0 -- 35.0' 4.650cm ()D 15L55#/ft !/'2" Wall 0% 0.0 - 559.0' 5.100cm OB 94.00#/fi H-aO 0% 2.~9,;,J 2595.0' SHOE 0.© - 2595P 2.075cm OB 6&O©#/ft K-55 SURF CSG 2595.0 -- 2397.0' SQUEEZE PERES Sqz'd 8/11,/89 - o/10/89 2868.0 2972.0' SQUEEZE PE[<iS Sqz'd ~ ' '" 2967/J - 2972.0' SQUEEZE PERFS Sqz'd a/17,/79 5070.0 - 507z.0 .4}UE~ZE PERES Sqz'd, 9/10/'8/ 545i.0 5464,0 SQUEEZE PERES Sq/d 8,/10/89 5679.u 568&. SOdEExE PERIS Sqz'd 8/10/89 5876.0 5945.0' llLL 5/96 Tog Soft Fill 5882,0 - 5897,0' SOUEEZ[ PF. RFS Sqfd 9/18/81 5904.0 -- 5916.0' SQUEEZE PEIRFS Sqz'd 9/ag,/sa 5956.0 - 5970,0' SQUEEZE PERES SqYd 8/7/8} 5945.0 3947.0' CEMENT PLUG 59470 - 5948.0' REIAINER EZSV 5948,0 5970,0' CEMENT PLU6 i kB ELEV: 1.,.°4' PBTD: so ~*, TB: 80:~ Dis :x.)sa I~elow -,r, 20:~ MU. 5',z' ( Ft MD. '30( Ft. MD 16.2 5.,,,~? 0.698< OD 12.60= fi N 80 TB6 8/29/89 16,2 - 2290.5 - 229!.8' _OCA~OR OINi 2291 S-- 2502,9 SLALS 2295.7 -- !509 IC/RV. &El<ER Dis VS~ = 2502 9 - 25051 MUtESHOk 2509,6 25i0.10ROSSOVEP~ /2' 25~}8. i 25123 SLEFVL svs }0(}o6 '}005 ( 2562.0 2596.6 ~nx.~ 2562.0 - 25961 ZERFS 2850.0 7900i ~ERF! 2850.0 2900i ~ERFS 29500 - 2960.0' SERFS Z950,0 29601 SFRF'S 5026.0 ~046i SERFS 5020.0 - YJ4b,O' ,C~05,6 ~ 552J,9~ d 3714.0 t708.0' ~[RF! 590/.0 ',91s.0' PERFS 38750 %6950' PLRFS 26 55044 - 5505.7' OCATOR 5505.7 B*7.E 551/.0- ~'s~ 5583,7 -- 3584.3 REENTRY JO NT uns. 90 hs Re-En[r Ou/de 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 November 3, 1992 Janet Bounds Unocal P O Box 190247 Anchorage, AK 99519-0247 Dear Ms Bounds: As we discussed on the phone October 28, AOGCC will be reassigning APl numbers for the wells listed below. In order to accommodate the revision of Unocal's records, we will not announce these changes to the public until the first week of December, or until you advise me that all the necessary changes are made. Give me a call if you would like to discuss this matter further. Well Name Permit # Old APl Number New APl Number Granite Pt St 17587 #3 66-52 · 50-883-10031 50-733-20437 Granite Pt St 17587 ~4 89-30 50-883-10032 50-733-20438-90 Granite Pt St 17587 ~ 89-103 50-883-10034 50-733-20439 Granite Pt St 18742 #8 67-36 50-883-20008 50-733-20440 Granite Pt St 17586 #4 67-54 50-883-20009 50-733-20441 Granite Pt St 18742 #34 79-17 50-883-20009-01 50-733-20441-01 Granite Pt St 17586 #41 91-45 50-883-20009-02 50-733-20441-02 Granite Pt St 18742 #14 79-33 50-883-20010 50-733-20442 Granite Pt St 18742 #20 68-16 50-883-20012 50-733-20443 Granite Pt St 18742 #20RD 91-20 50-883-20012-01 50-733-20443-01 Granite Pt St 17587 #5 68-24 50-883-20013 50-733-20444 Pretty Creek Unit #2 79-9 50-283-20022 50-283-20022-90 Nicolai Creek Unit #4 91-100 50-283-20033 50-283-20033-90 Lewis River D-1 89-72 50-283-20068 50-283-20068-90 Trading Bay Unit G-18DPN 83-135 50-733-20160 50-733-20160-90 Yours truly, Robed P Crandall Sr Petr Geologist /jo Alaska Region Unocal North Americ;~, Oil & Gas Division ~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL October 26, 1990 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchora~ Attentio~~Mains .~ Dear Steve: As we discussed on October 26, 1990, there was an error in the 10-407 form submitted for Lewis River D-1, Permit Number 89-72. The error was the perforations reported from 2662'-3666' 0.6" 4 SPF. These perforations do not exist, please mark through that line on the official copy. Thank you. Sincerely, George R. Buck Drilling Engineer STATE OF ALASKA ALASKA OIL A_ND GAS CO.~SERVATION CO~ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: P~E: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCR I PT I ON Copy sent to sender YES, _~ _ NO ~ STATE OF ALASKA . ALASKA~,~,:~_ AND GAS CONSERVATION CO,..,, ¢IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of. Well _ Classification of Service Well OIL [] GAS [] SUSPENDED [] ~ ABANDONED [] SERVICEJ~ ., 2. Name of Operator 7, Permit Number Union Oil Company of California (UNOCAL) 89-72 3, Address 8. APl Number P.O. Bo× 190247. Ankh. AK.. 99519-0247 50-- 2B3-2006~ 4. Location of well at surface 9, Unit or Lease Name 2086' FWL, 3168· FSi, Sec. 35, T15N, R9W, S.Mo Lewis River Unit At Top Producing Interval 10. Well Number Straight Hole D-1 At Total Depth 1 1. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ~ lOn~/!23' KBI AnT. r-,R'7qR 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 7-20-81 R-qfl-R1 R-Rr~-RQ_ _I N/A feet MSL 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD)19. DirectionalSurveL/I 20. Depth where SSSV set I 21. Thickness of Permafrost 80?5 ' Rn~"fm~ YES [] NO L_~ N/A feet MD N/A 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTIF~G' RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED .. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2562'-2596' 0.6" 4 SPF ' 2850'-2900' 0.6" 4 SPF . 3-1/2" 6576' ~529' 2950 ' -2960 ' 0.6" 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 3020' -3046' 0o 6" 4 SPF 3714' -3768' 0.6" 4 SPF '3873'-3893, 0.6,, 4 SPF ~ , 9 ' ~ 6 4 SPF -o OD N 27. PR UCTIO TEST Date First Production ~ t Method of Operation (Flowing, gas lift, etc.) . , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO ' . . TEST PERIOD I~ .... . . Flow Tubing . Casing Pressure CALCULATED OI.L-BBL GAS-MCF WATER-BBL OILGRAVITY-API (cor'r) Press.: . 24_HOUR BATE I~ ' _ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . .. 29554-95 - 'sandstOne, very fine to med.., grained; POR=26% SW=70% 3971-76 - Conglomerate, sandy and clayey, POP = 15%, SW = 73% '3977-78 - Sandstone, very fine .to'fin'e grained, POP = 13%, SW = 86% 3979-84 - Claystone, POR= 17%, SW = 87% .,. '' : ' 3985-89 - Sandstone, POP = 15%, SW 75% Form 10-407 Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Beluga Formation 2096' 2095' See Attachment "E" Tyonek Formation 6210' 6206' 3_1 LIST DF AT/AC A%~acnmen~s ~N~rough "E" 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Environmental Signed~O'~;)~~I1~ (~Titlerj Engineer Date 11/2/89 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 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 LOGS RUN ON LEWIS RIVER D#i ATTACHMENT "A" · · · Ran Dual Induction w/Gamma Ray for 2395' to 6345'. Ran Dual Induction - SFL with Linear Correlation Log 2395' to 8024'. Ran Dual Spacing Thermal Neutron Decay Time w/Gamma Ray from 2100' to 5050'. · Ran Borehole Compensated Sonic Log w/Gamma Ray from 2395' to 8021' . · · Ran Cement Bond Log from 1350' to 5050'. Ran Dipmeter Log from 2395' to 8024'. Ran Cement Bond Log from 90' to 3912'. Date Attachment "B" LEWIS ~IVER D-1 Description of Abandonment Work Performed Depth Description of Work Amount Cement Used 9/3/81 7235-7135 cement plug 9/4/81 6280-6180 cement plug 9/4/8i 9/4/81 9/5/si 9/i0/si 9/13/81 5975-5875 5475-5575 5053-5135 3070-3072 4889 4593 9/15/81 cement plug cement plug cement plug @ bottom of 9-5/8" float shoe @ 5135' squeeze perfs set EZSV squeeze cement below EZSV set EZSV squeeze cement below EzSV 7I sx class G 15.8~ 71 sx class G 71 sx class G 15.8# 71 sx class G 15.8~ 30 sx class G 15.8~ 100 sx class G neat 15.8~ 95 sx class G neat 15.8~ 75 sx class G 15.8# 9/16/8~ 9/17/81 9/18/81 9/29/81 lO/i/si 4376 4220 3904-3916 3882-3897 3849 TOC 3792 3374 TOC 3317 set EZSV squeeze cement below EZSV set EZSV squeeze cement below EZSV squeeze perfs set EZSV 57' balanced plug on top set EZSV 57' balanced plug on top 95 sx class G 15.8# 75 sx class G 16.0~ 75 sx class G 15.8# 21 sx cla~ G neat 15.0~ 21 sx class G neat 13.2~ Page two Att,~chment '~" %- Date Depth Description of Work Amount Cement Used · 10/3/81 2805 TOC 2745 set EZSV set 60' cement plug on top 10/3/81 0-50 set surface plug 21 sx class neat 15.5~ class G neat 13.5~ circulated to surface *Operation witnessed by B. Foster of AOGCC. DATE 8/07/89 08/10/89 08/10/89 08/10/89 o8/11/89 DEPTH 3956-4126 3679-3683 3451-3464 2868-2972 2395-2397 DESCRIPTION OF WORK Set RTTS and Squeeze Perfs Set RTTS and Squeeze Perfs Set RTTS and Squeeze Perfs Set RTTS and Squeeze Perfs Squeeze Perfs AMOUNT CEMENT USED 250 sx Class "G" 15.8# 150 sx Class "G" 15.8# 450 sx Class "G" 15.8# 200 sx Class "G" 15.8# 300 SX Class "G" 15.8# 30" DRIVEN 33' 20" 94# @ 359' @ 2395' ' 9-5/s" 5135' TUBING DETAIL 4- 1/2", 12.6#, N-80 TBG. 1) X - Nipple G 287' 2) '¥ST" Pocket @ 2302' - :3) XA- Sliding Sleeve ~ 2512' 4) XA- Sliding Sleeve ~ 3000' 5) "BWD" Packer ~ 3503' 6) × - Nipple ~ 5554' 7) Wireline Re-enb'y guide G 3584' 2395'- 2397' Sqz'd w/ 300 sx 2562'- 2596' 2850'- 2900' 2950' - 2960' 2967'- 2972' Sqz'd ! 3020' - 5046' 3070'- 3072' Sqz'd w/ 100 sx 5451' - 3464' Sqz'd w/ 450 sx 3714' - 3768' .3662'- 3666' Sqz'd w/ 150 sx 3873' - 3893' 3894' - 3897' Sqz'd 3904'- 3907' 3907' - 3918' Top of cement @ 3945' EZSV @ 3947' 3956'- 3970' Sqz'd w/ 100 sx EZSV @ 4020' 4054'- 4054' } 4062' - 4068' Sqz'd w/ 200 sx 4077'- 4094' 4122' - 4125' Junk EZSV @ 4144' Top of cement ~ 4154' EZSV @ 422O' LEWIS RIVER D- 1 INJECTOR CURRENT COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: GRB SCALE: NONE DATE: 8-31-89 Acid Job Lewis River D~i Attachment "D" Perf's: 3956'-3970', 8 SPF 4034'-4054', 8 SPF 4062'-4068', 8 SPF 4077'-4094', 8 SPF 4122'-4126', 8 SPF Acidized perforations with 2,000 gallons of 75% HCL w/MSR-100, .4% A-200, .2% W52, and 1% L53. Followed by 6,000 gallons of 7½% HCL and 15% HF w/MSR-123, .4% A-200, .2% W52, and 1% L53. Followed by 2,000 gallons of 7½% HCL w/MSK-100, .4% A-200, .2% W-52, and 1% L53. Attachment .. Well Name: Lewis River D-1 Date of Test: 9/12/81 DST~ la Perfs @: 4970'-4980' Type of guns used: 2-1/16" thru tbg. Tool set @: 4900' · Type of tool used: RTTS: Hydro Spring Tool run on: Drill pipe Water cushion: # of feet: type fluid: 4130' Fresh water Time tool was opened: Gas to surface: No Fluid to surface: No SPF: 8 Surface pressure: o psi Flare: No Chlorides: N/A Chlorides of comp. fluid: N/A Time tool was closed: Initial hydrostatic pressure: Initial flowing pressure: ~ Final flowing pressure: Final closed in pressure: Second initial flowing pressure: Final hydrostatic pressure: Clocks did not work Conmments: -1- Page Well Name: Lewis River D-1 Date of Test: 9/13/81 DST~ lb Perfs @: 4970'-4980' Type of guns used: 2-1/16" thru tbg. Tool set @: 4894' · Type of tool used: RTTS: Hydro Spring Tool run on: Drill pipe Water cushion: # of feet: 700' type fluid: Fresh water Time tool was opened:il:29 a.m. Gas to surface: No Fluid to surface: No SPF: 8 Surface pressure: 0 psi Flare: No Chlorides: N/A Chlorides of comp. fluid: N/A Time tool was closed: 1:30 p.m. Initial hydrostatic pressure: 2696.2 Initial flowing pressure: 323.3 Final flowing pressure: 431.1 Final closed in pressure: --- Second initial flowing pressure: --- Final hydrostatic pressure: 2656.2 Co~ents: Page 3 well Name: Lewis River D-1 Date of Test: 9/14/81 DST~ 2 Perfs @: 4675'-4704' Type of guns used: 2-1/16" thru tbg. Tool set @: 4579' Type of tool used: RTTS: Hydro Sprin~ Tool run on: Drill pipe Water cushion: ~ of feet: 1000' type fluid: fresh water Time tool was opened: 5:00 p.m. Gas to surface: yes Fluid to surface: very little SPF: 8 Surface pressure: 0 psi Flare: 6' (1'2' max)5:15 pm flare lit Chlorides: N/A ' Chlorides of comp. fluid: N/A Time tool was closed: 3:45 a.m. Initial hydrostatic pressure: 2502,.2 Initial flowing pressure: 456.6 Final flowing, pressure: 500.0 Final closed in pressure: 781.4 Second initial flowing pressure: 478.3. Final hydrostatic pressure: 2373.4 Con~nents: Build up: 1:20 a.m. 0 psi 1:30 a.m. 17 psi 1:45 a.mi-~42 psi 2:00 a.m. 67 psi 2:15 a.m. 94 psi 2:30 a.m. 120 psi 2:45 a.m. 155 psi 3:00 a.m. 180 psi 3:15 a.m. 205 psi 3:30 a.m. 230 psi 3:45 a.m. 260 psi .. Page 4 Well Name: Lewis River D-1 Date of Test: 9/15/81 DST# 3 Perfs @: 4444'-4476' Type of guns used: 4" csg. Tool set @: 3666' Type of tool used: RTTS: Hydro spring Tool run on: Drill pipe Water cushion: # of feet: type fluid: NO. Time tool was opened: 5:30 a.m. Gas to surface: No Fluid to surface: No SPF: 4 Surface pressure: 0 psi Flare: None Chlorides: N/A Chlorides of comp. fluid: N/A Time tool was closed: Initial.hydrostatic pressure: 2036.4 Initial flowing pressure: 64.7 Final flowing pressure: 99.2 Final closed in pressure: 194.2 Second initial flowing pressure: Final hydrostatic pressure: 2027.8 Con~nents: Build Up test: · SI @ 8:30 a.m. 0 psl 9:30 a.m. 3 psi Page 5 Well Name: Lewis River D-1 Date of Test: 9/16/81 DST~ Perfs @: 4327'-4347'; 4290'-4300'; 4315'-4327' SPF: '4 Type of guns used: 4" csg. Tool set @: 4229' · Type of tool used: RTTS: Hydro spring Tool run on: Drill pipe Water cushion: # of feet: type fluid: No Time tool was opened: 5:10 a.m. Gas to surface: Very small Fluid to surface: None Surface pressure: 0 psi Flare: None Chlorides: N/A Chlorides of comp. fluid: N/A Time tool was closed: Initial hydrostatic pressure: 2160.3 Initial flowing pressure: 64.7 Final flowing pressure: 86.3 'Final closed in pressure: 215.6 Second initial flowing pressure: --- Final hydrostatic pressure: 2160.3 Comments: Build up test: 8:15 a.m. 9:15 a.m. 0 psi 2 psi Page 6 Well Name: Lewis River D-1 Date of Test: 9/17/81 DST~ 5 Perfs @:3904'-3916'; 3892'-3897' Type of guns used: 4" csg. Tool set @: 3820' Type of tool used: RTTS: Hydro spring Tool run on: Drill pipe Water cushion: No # of feet: type fluid: Time tool was opened: 2:35 a.m. Gas to surface: No Fluid to surface: No SPF: 4 Surface pressure: 0 psi* Flare: No Chlorides: N/A Chlorides of comp. fluid: N/A Time, tool was closed: Initial hydrostatic pressure: 2091.9 Initial flowing pressure: 43.2 Final flowing pressure: 43.2 Final closed in pressure: 64.7 Second initial flowing pressure: --- Final hydrostatic pressure: 2079.1 Co~ents: Build~up: . 5:15 a.m. 0 psi 6:15 a.m. 2 psi Page 7 Well Name: Lewis River D-1 Date of Test: 9/19/81 DST~ 6a 4122'-4126'; 4077'-4094'; 4062'-4068' Perfs @: 4034'-4054'; ~956'-3970' Type of guns usea: 4" csg. Tool set @: 3855' Type of tool used: RTTS: Hydro sprin~ Tool run on: DrilI pipe Water cushion: # of feet: type fluid: 500' fresh water Time tool was opened: 8:30 a.m. Gas to surface: yes Fluid to surface: no SPF: 8 Surface pressure: 0 psi Flare: very small(2')' 10:15 a.m. Chlorides: N/A Chlorides of comp. fluid: N/A Time tool was closed: 10:45 a.m. Initial hydrostatic pressure: 2073.0 Initial flowing pressure: 304.4 Final flowing pressure: 326.1 Final closed in pressure: 738.1 Second initial .flowing pressure: --- Final hydrostatic pressure: 2073.0 Comments: Page B Well Name: Lewis River D-1 Date of Test: 9/20/81 DST~ 6b Perfs @: Same as 6a Type of guns used: SPF: 8 Tool set @: 3855' Type of tool used: RTTS: Hydro sprin~ Tool run on: Drill pipe Water cushion: ~ of feet: type fluid: No Time tool was opened: 8:00 p.m. Gas to surface: yes Fluid t° surface: yes/see attached Surface pressure: 0 psi Flare:. see attachments Chlorides: see attachments Chlorides of comp. fluid: 277,000 Time tool was closed: 10:05 p.m. Initial hydrostatic pressure: 2079.1 Initial flowing pressure: 86.3 Final flowing pressure: 258.7 Final closed in pressure: 495.7 Second initial flowing pressure: 280.2 Final hydrostatic pressure: clock expired Final flow pressure: 388 Comments: :: .. Page 9 Test #6.B .Tool open 8:00 p.m. - 0 psi 10:45 p.m. - small flare (1 to 2 feet) 4:00 a.m. - 6' flare'(0 psi) Shut in well 4:00 a.m. - Build up 4:00 a.m.- 0 psi 4:10 a.m.- 16 psi 4:20 a.m.- 35 psi 4:30 a.m.- 47 psi 6:00 a.m.- 180 psi' Open tool 6:00 a.m. - 40' flare 6:05 a.m. - 8 psi FTP-15' flare 6:30 a.m. - 0 psi FTP 4:30 p.m. - 0 psi FTP Well kicked fluid - built to 10 psi at 6:00 p.m. 6:10 p.m. - 0 psi FTP Well kicked fluid - built to 30 psi at 7:52 p.m. 8:05 p.m. - 2 psi 8:30 p.m. to 2:00 a.m. - 0 psi FTP 2:00 a.m. - pressure buil'ding 2:30 a.m. - 20 psi FTP 4:00 a.m. - 2 psi FTP Well shut in - 4:00 a.m. - build up 4:36 a.m. - 165 psi 5:00 a.m. - 300 psi 6:00 a.m. - 580 psi 7:00 a.m. - 830 psi Open well 7:25 a.m. w/920 psi - large flare 8:00 a.m. - 5 psi set 16/64" CHK 8:10 a.m. 8:30 a.m. - 46 psi FTP flow rate #1 8:45 a.m. - 54 psi 9:00 a.m. - 62 MCF/D - 55 psi · 9:55 a.m. - 350 MCF/D - 65 psi 10:45 a.m. - 221MCF/D - 57 psi Shut in well 11:00 a.m. - build up !1:00 a.m. - 56 psi 12:00 p.m. - 450 psi !:00 p.m. - 720 psi 2:00 p.m. - 950 psi Open well 2:00 p.m. w/950 psi (@ 700 psi well began to unload water - 15 BB1 9.8 pp$ Set 16/64" chk 2:15 p.m. - 45 psi 3:00 p.m. - 265 MCF/D ' Shut well in 3:30 p.m. - build up 4:00 p.m. - 305 psi 5:00 p.m. - 665 psi. . 6:00 p.m. - 940 psi Open well - set 5/8" chk 6:15 p.m. (@ 500 psi well began to unload water) 6:25 p.m. - 50 psi FTP Set 16/64" chk 6:30 p.m. - 62 psi 10:00 p.m. - 315 MCF/D 86 psi FTP Page 10 ~ . " Test #6.B cont. Shut well in 10:30 p.m. '- build up 10:30 p.m. - 86 psi 11:30 p.m. - 500 psi 12:00 a.m. - 650 psi 12:30 a.m. - 800 psi Open well 12:30 a.m. w/ 5/8" chk (@ 500 psi well began to unload water) Set 16/64" chk 12:45 a.m. - 99 psi - 338 MCF/D (Note: fluid 176,000 ppm) Shut in well 3:00 a.m. - build up 4:00 a.m. - 545 psi Open well 4:15 a.m. w/ 5/8" chk - 620 psi Set 16/64" chk 4:20 a.m. - 100 psi 5:30 a.m. - 3'20 MCF/D - 98 psi Shut in well in 6:30 a.m~ - build up 7:00 a.m. - 345 psi 8:00 a.m. - 695 psi 9:00 a.m. - 950 psi Open well 9:15 a.m. w/ 5/8" chk - 997 psi (@ 520 psi well began to discharge water - 10 BB1 9.6 ppg-147,000 ppm) 11:00 a.m. - 368 MCF/D - 116 psi Shut in well 12:00 p.m. - build up 1:00 p.m. - 550 psi 2:00 p.m. - 870 psi 3:00 p.m. -1067 psi 4:00 p.m. -1200 psi 5:00 p.m. -1277 psi Open well 5:07 p.m. w/ one 5/8" chk + one 1" chk. 5:10 p.m. - discharge fluid (5 BB1-9.3 ppg 136,000 ppm) Set 16/64" chk 5:15 p.m. 9:00 p.m. CF/D - 179 ps Closed tool 10:05 p.m. _ ..... Page 11 Well Name: Lewis River D-1 Date of Test: 9/25/81 DST~ 6c Perfs @:Same as 6a Type of guns used: Tool set @: 3941 · Type of tool used: RTTS: Hydro spring Tool run on: 2-7/8" tbg. Water cushion: No # of feet: type fluid: Time tool was opened: 3:40 a.m. Gas to surface: Yes Fluid to surface: Yes SPF: 8 Surface pressure: Flare: 3:50 a.m. (very small) Chlorides: N/A Chlorides of comp. fluid: N/A Time tool was closed: Initial hydrostatic pressure: 2164.6 Initial flowing pressure: 258.7 Final flowing pressure: 474.2 Final closed in pressure: 1630.4 Second initial flowing pressure: 495.7 Final hydrostatic pressure: 2143.2 Final flow: 603.1 ' 2nd closed in: 1801.3 Comments: Leak in tool - very short test Page 12 Well Name: Lewis River D-1 Date of Test: 9/28/81 DST~ 6D. Perfs @: same as #6A Type of guns used: Tool set @: 3860' Type of tool used: Tool run on: Drill pipe Water cushion: No # of feet: type fluid: Time tool was opened: 8:22 p.m. Gas to surface: yes Fluid to surface: no SPF: 8 Surface pressure: Flare: yes (FTP-2 psi) 10:38 p.m. Chlorides: N/A Chlorides of comp. fluid: N/A Time tool was closed: Initial hydrostatic pressure: 2030.1 Initial flowing pressure: 43.5 Final flowing pressure: 651.6 Final closed in pressure: 651.6 Second initial flowing pressure: --- Final hydrostatic pressure: 2137.4 Con~nents: Build up. ... · · 3:35 a.m. - SI 4:30 a.m. - 21 psi 4:35 a.m. - 24 psi Page 13 %~ ~ Well Name: Lewis River D-1 Date of Test: 9/30/81 DST~ 7 Perfs @: 3451'-3464' Type of guns used: 2-1/16" thru tbg. ?ooi set @: 3356' Type of tool used: RTTS: Hydro spring Tool run on: 2-7/8" tbg. Water cushion: ~ of feet: 500' type fluid: fresh water Time tool Was opened 7:30 a.m. Gas to Surface: No Fluid to surface: No SPF: 8 Surface pressure: 0 psi Flare: ~wabed fluid-9.8 ppg Chlorides: 2I~,000 mmm Chlorides of comp. fIuld: 390,000 ppr Time tool was closed: initial hydrostatic pressure: 1814 initial flowing pressure: 478 Final flowing pressure: 651 Final closed in pressure: 347 Second initial flowing pressure: --- Final hydrostatic pressure: 1793 Con~nents: Swabed - final fluid level 2690' Page 14 Well Name: Date of Test: Lewis River D-1 10/2/81 DST~ 8 Perfs @:2868'-2900'; 2955'-2959'; 2967'-72' Type of guns used: 4" csg. Tool. set @: 2825' Type of tool used: RTTS: Hydro sprfng Tool run on: 2-7/8" tbg Water cushion: No # of feet: type fluid: Time tool was open~d: 4:40 a.m. Gas to surface: No Fluid to surface: swabbed 10.3 ppg SPF: 8 Surface pressure: 0 psi Flare: No Chlorides: 370,000 Chlorides of comp. fluid:370,000 Time tool was closed: Initial hydrostatic pressure: 1513 Initial flowing pressure: 217 Final flowing pressure: 434 Final closed in pressure: --- Second initial flowing pressure: Final hydrostatic pressure: 1513 Comments: Swabed - final fluid level 2518' Pumped 10 barrel of diesel into formation, swabbed well. Well remained dead. Page 15 Repeat Formation Tests Formation Tested 7240 6545 6542 6302 6310 4045 4049 4088 Fluid Recovery None None None None None None None None Pressure Buildup (psi) 4002 105 283 118 5O 65 240 96 Navin Sharma August 29, 1989 STEP RATE TEST #1 LEWIS RIVER UNIT D-1 A step rate test was conducted on the following perforations in Lewis River Unit D-i: 3,714' - 3,768' 3,873' - 3,893' 3,907' - 3,918' Fluid used was filtered 2% KCL with Nacl, weighted up to 70.5 pcf (0.49 psi/ft). Initial pumping rate was 0.25 BPM and final pumping rate was 3.5 BPM. Formation fracture occurred at 2,825 psi at 3 BPM. After the step rate test the well was shut-in and the tubing pressure stabilized at 2,250 psi. Data gathered, from the test is tabulated below. representation of this data is attached. Graphical INJECTION RATE SURFACE INJ COMM VOLUME BPM PSI BBLS 0.25 1,975 2 (Unstable) 0.50 2,000 5-1/2 0.50 2,300 7-1/2 0.50 2,325 9 0.50 2,350 10-1/2 0.50 2,350 11-1/2 0.50 2,350 12-1/2 0.75 2,400 13 0.75 2,400 13-1/2 0.75 2,425 14 0.75 2,425 14-1/2 0.75... 2,425 15 0.75' ' 2,425 16 1.0 2,475 16-1/2 1.0 2,475 17-1/2 1.0 2,475 18-1/2 1.25 2,500 19 1.25 2,500 19-1/2 1.25 2,500 22 1.25 2,500 23 1.5 2,550 24 1.5 2,550 25 1.5 2,550 28 1.5 2,550 29 1.5 2,550 31 1.75 2,675 33 1.75 2,675 40 STEP RATE TEST #1 LEWIS RIVER UNIT D-1 Continued INJECTION RATE BPM 1.75 1.75 2.0 2.0 2.0 2.0 · 2.0 2.25 2.5 2.5 2.5 2.5 3.0 3.0 3.25 3.5 3.5 SURFACE INJ PSI 2,675 2,675 2,720 2,725 2,725 2,725 2,725 2,750 2,800 2,800 2,800 2,800 2,825 2,825 2,825 2,825 2,825 END OF TEST COMM VOLUME BBLS 42 44 52 55 56 58 60 62 63 68 70 78 82 94 96 98 112 (Frac Pressure) NKS: trf 0372r-53/54 .! LEWIS RIVER WELL D STEP ~714' RATE TEST #1 , ~7~' 5000 2900 2800 2700 2600 2500 2400 2500 2200 2100 2000 i 900 1800 1700 1600 1 500 SURFACE PSI FRAgTUR£ PR~URE ~ 28,25 P$1G 500. 0.5 1 1.5 2 2.5 3 - 450 - 400 - ,350 - 5OO 25O - 200 - 150 - lO0 5O INJECllON l~l'F_.. BPNI 3.5 4 PS1 CUM INJ., BBLS Navin Sharma August 29, 1989 STEP RATE TEST #2 LEWIS RIVER UNIT D-1 A second step rate test was performed on the following sands using the same fluid as in Test #1. 2,562' - 2,596' 2,850' - 2,900' 2,950' - 2,960' 3,020' - 3,046' Fracture pressure equipment at hand. at 8'BPM. was unattainable due to limits of pumping Final injection pressure achieved was 2,500 psig Data below represents this step rate test. plotted and the graph attached for review. Information is also INJECTION RATE SURFACE INJ COFIM VOLUME BPM PSI BBLS 0.25 950 1 0.25 1,200 2 0.25 1,200 3 0.25 1,200 4 0.5 1,250 5 0.5 1,250 6 0.5 1,250 7 0.75 1,250 8 0.75 1,250 9 0.75 1,250 10 1.00 1,300 11 1.00 1,300 12 1.00 1,300 13 1.125 ' · 1,350 14 1. 125 i, 350 15 1.25 1,350 16 1.25 1,350 17 1.25 1,350 18 1.5 1,400 19 1.5 1,400 20 1.5 1,400 21 1.5 1,350 22 1.5 1,350 23 2.0 1,400 25 2.0 1,400 27 2 . 0 1,400 29 2.25 1,450 31 2.25 1,450 33 2.25 1,450 35 STEP RATE TEST #2 LEWIS RIVER UNIT D-1 Continued INJECTION RATE BPM SURFACE INJ PSI COMM VOLUME BBLS 2.50 1,450 2.50 1,450 2.50 1,450 2.50 1,450 2.50 1,450 2.50 1,450 3.00 1,500 3.00 · 1,500 3.00 1,550 3.00 1,550 3.00 1,550 3.25 1,600 3.25 1,600 3.25 1,600 3.50 1,650 3.50 1,650 3.50 1,650 4.0 1,700 4.0 1,700 4.0 1,700 4.0 1,700 4.0 1,700 4.25 1,750 4.25 1,750 4.25 1,750 4.25 1,750 5.0 1,950 5.0 1,950 5.0 1,950 6.0 2,000 6.0 . 2,000 6.0 2,000 6.0 2,000 6.25 2 , 050 6.25 2,050 6.25 2,050 6.25 2,050 6.25 2,050 6.25 2,050 37 39 41 43 45 47 49 51 55 57 59 61 63 65 69 71 73 75 77 79 83 85 89 91 93 100 108 110 124 133 140 148 162 170 188 194 205 210 218 Shut-down to increase pump intake capacity. B.J. Suction maxed out due to intake line size. Resumed test within 10 minutes. STEP RATE TEST LEWIS RIVER UNIT D-1 Continued INJECTION RATE SURFACE INJ COMM VOLUME BPM PSI BBLS 6.5 6.5 7.0 7.0 8.0 8.0 8.0 8.0 8.0 Shut-down. Test BJ) terminated. 1,250 Shut-Down 2,200 240 2,200 250 2,300 260 2,300 270 2,500 280 2,500 290 2,500 300 2,500 310 2,500 320 Maxed out on pump strokes (@ 8 BPM Frac Pressure Unreachable NKS:trf 0372r-55/57 LEWIS RIVER WELL D STEP RATE TEST #2 25sZ ' ,, ,zo~¢~' SURFACE: PSi 3000 --- .... 900 2500 2000 150O 1000 0 RNAt RATE- 8 bprn O 2500 PUt, fPS ldAX~ OUT: FRACTURE PRESSURE UNATTAINABLe. 1 2 3 4. 5 6 INJECTION RAT~ BPM 7 8 9 0 10 80O 7OO 600 500 4OO 300 200 lO0 PSI , ,u- CUM INJ., BBLS 30" DRIVEN .I 33' 5135' _F TUBING DETAIL 4-1/2", 12.6#, N-SO TBG. 1) X - Nipple O 287' 2) 'MST" Packer 1~ 2302' 3) XA - Sliding Sleeve ~ 2512' 4) XA- Sliding Sleeve ~ 3000' 5) "BWD" Pecker ~ 3503' 6) X- Nipple ~ 3554' 7) Wircline Re-entry guide ~ 3584' 2395' - 2397' Sqz'd. w/ 300 sx 2562' - 2596' 2850' - 2900' 2950' - 2950' 2967'- 2972' Sqz'd 3020'.- 3046' 3070'- 3072' Sqz'd w/ 100 2× 345i' - 3464' Sqz'd w/ 450 s× 376~' - 3683' Sqz'd w/ 150 s× 3873'- 3893' 3894' - 3897' Sq~d 3907' - 3918'- Top of cement ~ 3945' EZSV ~ 5947' ,3956'- 5970' Sq~'d w/ 100 s× EZSV ~ 4020' 4054' - 4054' 4062' - 4068' . Sez'd w/ 200 sx 4077' - 4094' ' 4122' - 4126' Junk EZSV ~ 4144' Top of cement ~ 4154' EZSV ~ 4220' LEWIS RIVER D-1 INJECTOR CURRENT COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: GRB SCALE: NONE DATE' 8-3 1-89 LEWIS RIVER WELL D 1 STEP 571¥' RATE TEST #1 ~ zs~,~'/VD/VD SURFACE Pg; 3000 2900 2800 2700 2600 2500 2400 2300 2200 2100 20O0 1900 1800 1700 1600 1500. 0 0.5 1 3.5 4 1.5 2 2.5 3 INJECTION RATE, BPM 500 450 400 350 300 250 200 150 100 5O ! .N J C T E D PSI CUM INJ., BBLS STATE OF ALASKA ALASKA OIL AN D GAS CONSERVATION CUM MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator Union Oil Comoanv of Ca1 i fnrn~ -- -- 3. Address P.O. Box 190247~ Anch~ 4. Location of well at sudace 2086' FWL, 3168' FSL, At top of productive interval At effective depth At total depth Perforate __ 5. Type of Welh Development ! f;NC~AL ) Exploratory · ! Stratigraphic Ak. ~ 9 9 519 - 0 2J~ 7 Service Sec. 35, T15N, R9W S.M. Straight hole Other 6. Datumelevation(DForKB) Z UnitorPrope~yname Lewis River Unit 8. Well number D-1 9. Permit number/approval number 89-72 10. APl number 50-- 283-20068 11. Field/Pool Lewis River/Unnamed 12. Present well condition summary Total depth: measured . true vertical 8,025' feet 8,025 ' feet Plugs (measured) Effec.tive depth: measured true vertical Surface feet Surface feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length measured Size Cemented 33' 30" Driven 359' 20" 496sxs 2395' 13-3/8" 850sxs 5135' 9-5/8" 1361sxs See Attachment No. 1 Measured depth 33' 359' 2395' 5135' True vertical depth 33' 359 ' 2395 ' 5135 ' true vertical Tubing (size, grade, and measured depth) 4-1/2", Packers and SSSV (type and measured depth) "VST" 13. Stimulation or cement squeeze summary 12.6", N-80 (internally coated) Packer @ 2302', "BWD" Packer ¢ 3503' I ntervalstreated (measured) See Attachment No. Treatment description including volumes used and final pressure RECEivED OCT 1 41aska Oil & Gas Cons. Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 0 0 0 0 0 0 feet Tubing Pressure 0 15. Attachments X Copies of Logs and Surveys run Daily Report of Well Operations ~ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ Roy D. Roberts~,~ Environmental Engineer Signed /~"~¢.,&//3 ,/~~~ ~(~"' Title Form 10-404 Re~ 06/15/88 8OO Date 10/18/89 SUBMIT IN DUPLICATE LEASE LEWIS RIVER UNOCAL ~ILLING RECORD -~. ALASKA REGION PAGE NO. ! of 5 WELL NO~ D-1 FIELD WEST SIDE DATE E.T.D. 7/30/89 0' 7/31/89 0' 8/01/89 0' 8/02/89 500' 8/03/89 3285' 8/04/89 3348' 8/05/89 38O5' 8/06/89 4154' DETAILS OF. OPERATION,. DESCRIPTIONS & RESULTS Nippled up the BOPE. Were unable to fit the original BOP stack under the rig, so a variance was received from Mike Minder to run the stack as follows: Bag, CS0 rams, pipe rams, mud cross and wellhead. Repaired mud pump. Installed pipe rack, rotary table & floor plates. Hung windwalls, set V-door and stairs. Pressure tested and repaired leaks on the BOPE. Received permission to draw water from a depression in the wetlands near the Lewis River. Continued testing stand pipe and pump liner. Testing BOPE stack to 3000 psi. Derating was approved by Mike Minder AOGCC. Valves at pump end of line would not test to 3000 psi. Waited on parts. Rig on down time from 1500 to 2400 hrs. Waited on parts to 0600 hrs. Pressure tested all surface equipment to 3000 psi, OK. RIH and cleaned out to 500' with an 8-1/2" bit and 3-1/2' D.P. Picked up 3-1/2 DP & RIH to 1300'. Circulated at 1300'. Picked up DP to 2714' Washed from 2714' to 2692'. 10' of soft fil~. Circulated and treated H20, weighted up to 66 PCF. Cleaned out cement from 2692' to 2785'. No pressure but some flow. Weighted up to 70 PCF. Drilled retainer and washed from 2797 to 2832. Circulated bottoms up. Mud was frothy. Picked up 3-1/2" DP and washed to 3246'. Drilled cement from 3246' to 3261'. ~' Bit #1 torqued up. Circulated bottoms up. POOH and layed down Bit #1. Broken teeth and one cone was locked up. RIH with BHA #2 including junk basket. Drilled cement from 3261' to 3328'. POOH and layed down bit #2, loss of teeth. RIH w/mill #1 and tandem junk baskets. Drilled junk and milled cement from 3328' to 3348'. Continued to mill junk and cement from 3339' to 3348'. POOH w/mill and junk baskets RIH with bit #3 and drilled from 3348, to 3~52' which was the bottom of the plug. No flow but the mud was out of balance. Weighted mud up to 70 PCF. RIH and tagged cement at 3728'. Drilled junk and cement from 3728' to 3734' POOH and RIH with bit #4. Drilled cement and junk from 3734' to 3805'. Continued to drill junk and cement from 3805' to the bottom of the retainer at 3827'. Tagged next plug at 4154'. Began drilling and took a gas kick. Maximum pressure on csg was 200 psi. Circulated out kick and weighted up to 71 PCF. Well dead. Made a bit and scraper run to 4154'. OCT 1 Alaska Oil & Gas Cons. Cornmissior~ Anchorage LEASE LEWIS RIVER UNO~,L DRILLING RECORD ~ ALASKA REGION PAGE NO. 2 of 5 WELL NO. D-1 FIELD WEST SIDE DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 8/07/89 3827' Reverse circulated to clean the perforations. Stripped out of the hole. RIH with a Howco EZ drill and set it at 3840'. Rigged up surface lines and tested to 5000 psi. Tested D.~. to 1000 psi. Established circulation and · achieved formation breakdown at 1550 psi. Pumped 1/2 BPM @ 1650 psi and 2 BPM @ 2300 psi. Mixed 250 sacks of class "G" cement with 6% F/10, .75% A7, and 1 gal/sk FPGL to 15.8 PPG. Pump plugged up. Reverse circulated. Repaired cement pump. Batch mixed 250 sack of O~ new cement. Squeezed same with a final rate @ 2250 psi, and 1-1/8 BPM. Formation held 2250 psi. Reversed out. POOH with stinger. 8/08/89 3834' Finished RIH w/Howco stinger to retainer at 3840'. Established circulation. Tested lines, drill pipe and tested perfs from 3956' to 4126'. Broke perfs down @ 1550 psi. Formation held 1300 psi with pumps off for 10 ~minutes. Pumped 250 SX Class "G" cement at 1-1/8 BPM and 2250~-~. --L-~tt 1 BBL of cement on retainer. Perforated from 3663' to 3665'. Set a Howco EZ drill retainer at 3671' Attempted to break formation w/o success. Drilled and chased Howco retainer to 3834'. 8/09/89 3619' Re-perforated from 3662' to 3666'. RIH and tagged ETD @ 3893' (a 38' difference between the wireline and drill pipe measurements caused this error, All the depths in the history have been corrected to DIL measurements). RIH w/Howco RTTS set @ 3650' DPM. Attempted to break down w/o success. Picked up and set RTTS @ 3661'. Formation broke down at 1600 psi. POH. 8/10/89 2830' RIH and set an EZSV retainer at 3620'. POOH, rigged up Schlumberger and tagged retainer at 3619'. RIH and stabbed into retainer. Obtained a breakdown at 1950 psi. Pumped 2 BPM @ 2750 psi. Squeezed 50~q_~_~'G" cmt into perfs from 3662' - 3666'. Reversed out and set RTTS packer at 3430'. Broke formation down at 900 psi. Pumped 1/2 BPM at 950 psi. Formation held 200 psi after 10 minutes. POH. RIH and set EZ drill retainer at 2420'. Squeezed 445 sacks of cement into perfs from 3451' - 3464,. RIH and set EZ drill retainer @ 2830". Broke down formation @ 1050 psi. Pumped 2 BPM at 1500 psi. Formation held 900 psi with pump off for 10 minutes. 8/11/89 2360' Squeezed perfs from 2868' - 2972' with 200. ~~'~c~c~.,~_of cement at 1800 psi. Perforated from 2395' - 2397'. Rigged down wireline. Set Howco EZ drill retainer at 2370'. Rigged up B.J. Titan. Established breakdown. Squeezed perforations from 2395' - 2397' with 3~0_,0_~s. of cement. Reversed out. Waited on cement and cleaned pits. Tested BOPE. LEASE LEWIS RIVER UN~..AL DRILLING RECORD ALASKA REGION PACE NO. 3 WELL NO. D-1 FIELD of 5 WEST SIDE DATE E.T.D. 8/12/89 2767' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS WOC 18 hrs. Ran in hole and tagged cement at 2360'. Drilled cement from 2360' - 2366', green cement. WOC 19-1/2 hrs. Drilled cement from 2366' - 2370'. Drilled retainer at 2370', void from 2374' - 2395'. Drilled cement from 2395'-2400'. Pressure tested perfs from 2395' - 2397' for 15 minutes w/1450 psi surface pressure-OK. RIH and tag cement at 2681. Drilled cement stringer from 2681' - 2687'. RIH. Tagged cement at 2767'. 8/13/89 3430' 8/14/89 3580, 8/15/89 3481' 8/16/89 4152' 8/17/89 3454' Drilled cement from 2767'-2883' with EZ drill retainer at 2830'. Pressure tested perfs from 2868' - 3072' for 15 minutes with 1450 psi surface pressure-OK. RIH to cement at 3403'. Drilled cement from 3403' to retainer at 3430'. Drilled on retainer. Poor progress, 2' of junk on retainer. POOH to empty junk baskets. Drilled on junk and retainer at 3430'. POOH. Emptied junk baskets. RIH with mill. Milled on junk. Mixed 90 BBL's of hole sweep. Pumped 15 BBL's of same. POOH. Emptied junk baskets. RIH with bit #8 and drilled the remainder of the retainer at 3430'. Drilled cement from 3464' - 3466'. Washed stringers to 3496'. Tested perforations from 3451' - 3464' with 1500 psi surface Pressure of 15 minutes, OK. RIH and tagged cement at 3580'. Drilled hard cement from 3580' to retainer at 3689'. Drilled retainer and cement to 3840'. Pulled out of the hole and emptied the junk baskets. RIH with bit #7RR and drilled hard cement to 3841'. Drilled retainer and hard cement from 3841' - 3864'. POOH and emptied junk baskets layed down bit #7RR and picked up bit #9. Drilled hard cement from 3864' - 3906'. Drilled soft cement from 3906' - 4039'.' Washed stringers from 4039' - 4152'. Tested perforations from 3882' - 4126' w/o success. POOH. Made a bit and scraper run. Tagged bottom at 4146'. POOH. RIH with an RTTS · packer and set at 4136'. Tested blank pipe from 4136' - 4072'-OK. Tested perfs above 4136' w/1440 psi, lost 125 psi in 5 minutes. Tested perfs to final leak. Found same. LEASE LEWIS RIVER UNOCAL XILLING RECORD ALASKA REGION PAGE NO. 4 WELL NO. D-1 FIELD of 5 , WEST SIDE DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 8/17/89 3454'Cont. Found leaking perfs 2868'-2900'. Pipe and perfs above 2809' test OK. 8/18/89 27' 8/19/89 4144' RIH w/EZSV. Set prematurely at 27'. Drilled on EZSV @ 27'. c~ Drilled and pushed junk EZSV to 4144'. Circulated bottoms up. Tested BOPE to 3000 psi, OK. Ran scraper through area where retainer was drilled. Set an EZSV @ 4020'. Squeezed below EZSV w_~_213...cu ft cement. 8/20/89 3945' RIH with scraper and bit. Tagged cement at 4011'. RIH with RTTS and tested perfs from 3956'-3970' negative. RIH and set RTTS at 3947' DIL. Established breakdown at 2100 psi' and 1 bbl/min. POH w/RTTS. RIH and set an EZSV at 3947' DIL. Stabbed into EZSV and ~queez~perfs from 3956'-3970' with 100 sacks ~of Class G cement with 0.750 CaCl and .6° fluid loss control and 1 gal/100 sx FPGL. POH. 8/21/89 3945' 8/22/89 3945' RIH with RTTS/Bridge plug combination. Attempted to set bridge plug at 3696' and RTTS at 3686' DIL. Pressure tested perfs from 3882'-3916' (The bridge plug was not set) to 1500 psi, OK. Set RTTS at 3668', and pressure tested the perfs from 3679'-3916' to 1450 psi and lost 100 psi over a 15 minute period. POOH with damaged bridge plug and found that the bridge plug had never been set. Installed Schlumberger lubricator and ran CBT & Digital CET logs from 3945' to surface. Filtered fluid and cleaned pits. Changed over to clean fluid. 8/23/89 3945' Continued to filter fluid. Wireline perforated intervals from 3714'-3768', 3873'-3893' and 3907'-3918' with 5" Hyper jet II RDX 22.7 gm charges set at 4 SPF and 120° phasing. All shots were correlated to the DIL. 8/24/89 3945' RIH with an RTTS and tagged bottom at 3945'. Circulated bottoms up. Set RTTS at 3923' and tested to 2500 psi, OK. Set RTTS at 3690'. Performed a step rate injection test injecting a total of 110 bbls of fluid. Found frac pressure at 2825' psi and 3 BPM. POOH with RTTS and rigged up Schlumberger. Perforated intervals from 2562'-2596', 2850'-2900', 2950'-2960' and 3020'-3046' with 5" Hyperjet --~I ~Dx-22.7 gm ~h~a~~t at 4 SPF. All shots were correlated to the DIL. Made an 8-1/2" bit and casing scraper run. LEASE LEWIS RIVER UNOCAL _~,ILLING RECORD ALASKA REGION PAGE NO. 5 of 5 WELL NO. D-1 FIELD WEST SIDE DATE E.T.D. 8/25/89 3945' 8/26/89 3945' 8/27/89 3945' 8/28/89 3945' 8/29/89 3945' 8/30/89 3945' DETAILS OF OPERATION,.DESCRIPTIONS & RESULTS POOH with bit and scraper. RIH and set a retrievable bridge plug at 3416'. Set the RTTS at 3373', blank tested to 2500 psi, OK. Set the RTTS at 2496' and performed an injection step rate test. Did not find frac. pressure and stopped the test at 8 BPM and 2500 psi. Released the RTTS and saw returns from the formation. Retrieved the bridge plug. The well continued to flow back out of the perforations just injected into. Circulated and monitored well for 3 hrs. The flow stopped. POOH with RTTS/Bridge plug. Attempted to set Otis permanent packer w/o success. POOH and found that the packer had 'disengaged and fallen to bottom. RIH and recovered packer. POOH with fish. Set permanent packer with tail at 3501' Pulled out of the packer and circulated adding 20 gal of Nalco 3900 chemical inhibitor. Attempted to make up running tool to Otis "VST" packer, w/o success. Made up the new "VST" packer, RIH on drill pipe and stabbed into the lower packer an set the "VST" packer at 2296'. Released the packer and blew out the ball. Stabbed back into the "VST" packer and tested the annulus to 1500 psi, OK. POOH and layed down the drill pipe. Continued laying down drill pipe. Installed and function tested 4-1/2" tubing rams. RIH with 4-1/2" 12.6# MMS, N-80 tubing. Stabbed into packer at 2296' and spaced out the hanger. Stabbed back into the packer and landed the hanger. Pressure tested the annulus to 1500 psi for 30 min, OK. Removed the BOPE and Installed the tree. Released the rig at 2400 hrs. 30" DRIVEN 33' 20" 94# e 359' / 6s#Z @ 2395' 5135' TUBING DETAIL 4-1/2", 12.6#, N-80 TBG. 1) ×- Nipple ~ 287' 2) '¥ST" Packer ~ 2302' 3) ×A- Sliding Sleeve li~ 2512' 4) XA- Sliding Sleeve ~ 3000' 5) "BWD" Packer ~ 3503' 6) X - Nipple @ 3554' 7) Wireline Re-ent~ guide ~ 3584' 2395'- 2397' Sqz'd w/ 300 sx 2562'- 2596' 2850' - 2900' 2950' - 2960' 2967'- 2972' Sqz'd 3020'- 3046' 3070'- 3072' Sqz'd w/ 100 sx 3451'- 3464' Sqz'd w/ 450 sx 5714' - 5768' 3662'- 5666' Sqz'd w/ 150 s× 3873' - 3893' 3894' - 3897' Sqz'd 3904' - 3907' 3907' - 3918' Top of cement@ 3945' EZSV @ 3947' 3956'- 3970' Sqz'd w/ 100 sx EZSV ~ 4O20' 4034'- 4054' } 4062' - 4068' Sqz'd w/ 200 sx 4077'- 4094' 4122' - 4126' Junk EZSV @ 4144' Top of cement: @ 4154' EZSV @ 4220' LEWIS RIVER D-1 INJECTOR CURRENT COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: ORB SCALE: NONE DATE: 8-31-89 ST^T. O.^'^S.^ 0 ALASKA OIL AND GAS CONSERVATION COMMIbSION APPLICATION FOR SUNDRY APPROVALS 16 IN AL 1. Type of Request: Abandon m Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well m Plugging __ Time extension __ Stimulate __ Change approved program ~ Pull tubing m Variance __ Perforate ~ Other 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 190247, Anch' Ak., 99519-0247 4. Location of well at surface 2086' FWL, 3168' FSL, At top of productive interval At effective depth At total depth Sec. 35, T15N, Straight Hole 5. Type of Well: Development ~ Exploratory __ Stratigraphic __ Service _~ R9W, SM 6. Datumelevation(DForKB) GR 100'/115' KB Z UnitorPropertyname Lewis River Unit 8. Well number D-1 9. Permit number 89-72 10. APl number 50-- 283-20068 11. Field/Pool Lewis River/Unnamed feet 12. Present well condition summary Total depth: meas'ured true vertical 8,025' 8,025 ' Effective depth: . measured Surface true vertical Surface feet Plugs (measured) feet feet Junk (measured) feet Casing Length Structural Conductor Surface 359' Intermediate 2,395' Production 5,135 ' Liner Perforation depth: measured Size Cemented 30" Driven 20" 496 SXS 13-3/8" 850 sxs 9-5/8" 1,361 sxs true vertical See Attachment No. 2 Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Measureddepth ~ueverticaldepth 33' 33' 359' 359' 2,395' 2,395' 5,135' 5,135' 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Service Gas __ Suspended In iector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tit, ' R~v F)- Rnhc. z'f.s FOR COMMISSION USE ONLY Conditions of ~,pproval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Date ~0/~ ~,,,~ JApprovalNo. Approved Copy Returned Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment No. 1 DESCRIPTION o[MMAR? OF PROPOSAL NOTICE OF INJECTION LEWIS RIVER UNIT WELL D-I Unocal proposes to begin injection of non-hazardous waste fluids into Well D-I upon approval by the Commission of 'the attached 10-402 ~ Authority for th injection Order No. 6, issued May 11, 1989. Injection will Occur in the followingZ~"on~.~'_.,~ Zone Zone 3,714" - 2,918' 2,562' -- owl 9/22 Attachment No. 2 30" DRIVEN I 33' '[ 5-5/8" 68#X @ 23,95' 9-5/8" 5135' I T UBIN(~ DETAIL 4-1/2", 12.6t~, N-80 'lBO. 1) X- Nipple O 287' 2) '~/ST" Packer O 2302' 3) XA- Sliding Sleeve ~ 2512' 4) XA- Sliding Sleeve ~ 3000' 5) "BWD" Packer ~ 3503' 6) X - Nipple ~ 3554' 7) Wireline Re-entry guide O 3584' 2395' - 2397' Sqz'd w/ 300 sx 2562' - 2596' 2850' - 2900' 2950' - 2960' 2967'- 2972' Sqz'd 3020'- 3046' 3070'- 3072' Sqz'd w/ 100 sx 3451' - 3464' Sqz'd w/ 450 sx 3714' - 3768' 3662' - 3666' Sqz'd w/ 150 sx 3873' - 3893' 3894' - 3897' Sqz'd 3904' - 3907' 3907' - 3918' Top of cement ~ 3945' EZSV ~ 3947' 3956' - 3970' Sqz'd w/ 100 sx EZSV ~ 4020' 4034'- 4054' 4062'- 4068' Sqz'd w/ 200 sx 4077' - 4094' 4122' - 4126' Junk EZSV ~ 4144' Top of cement @ 4154' EZSV ~ 4220' LEWIS RIVER D- 1 INJECTOR CURRENT COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: GRB SCALE: NONE DATE: 8-31-89 Alaska District Unocal Oil & Gas Di,~'~-,~..n Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL September 19, 1989 Mr. Blair Wondzell Sr. Petroleum Engineer AK. Oil & Gas Conserv. Comm. 3001 Porcupine Drive Anchorage, AK. 99501 RE: LEWIS RIVER UNIT D-1 STEP RATE TESTS Dear Blair: Step rate tests were conducted in each of the two approved injection zones on August 24th and 25th. Zone 1 included three sands between 3,714' and 3,918' and zone 2 included four sands between 2,562' and 3,046'. Zone 1 fractured at 2,825 psig at 3 bpm. Zone 2 could not be fractured as maximum operating limits of the pumps were reached. A maximum rate of 8 bpm at 2,500 psig was established for this zone. Unocal proposes to inject at different surface injection pressures, for each zone, instead of one based on the lower pressure of 2,500 psig. This is because at 2,500 psig the lower zone 1 is capable of taking fluid at only 1.25 bpm. At 2,725 psig, 100 psig lower than the fracture pressure, this zone's injection rate is 2 bpm, a 63% increase from the 1.25 bpm rate at the lower pressure. Injection will not be commingled in the two zones. When injecting into zone 1 at the higher pressure, the sleeve across zone 2 will be closed thereby isolating it from the injection pressure of the lower zone 1. Based on the step rate tests, Unocal intends to limit surface injection pressure as follows: Zone 1: Zone 2: 3,714' - 3,913' = 2,725 psig 2,562' - 3,046' = 2,400 psig RECEIVED SEP 2 ! 1989 Alasl(a oil &,' ~s Cons. Comm/ssl'oi/ Mr. Blair Wondzell AK. Oil & Gas Conserv. Comm. September 19, 1989 Page -2- Related test data and plots are attached for review. Also attached is a completed Application for Sundry Approvals to begin injection as outlined above. Should you have any questions please feel free to contact me at the phone number and/or address listed above. Sincerely, Navin K. Sharma Petroleum Engineer cc: Anton Chaplin Ed O'Donnell Faye Sullivan File NKS:trf 0372r-66 RECEIVED SEP 2 1 1989 Alaska Oit .?~ ,~,~.~ Cnn~. Comrn~ss~on Navin Sharma August 29, 1989 STEP RATE TEST #1 LEWIS RIVER UNIT D-1 A step rate test was conducted on the following perforations in Lewis River Unit D-i: 3,714' - 3,768' 3,873' - 3,893' 3,907' - 3,918' Fluid used was filtered 2% KCL with Nacl, weighted up to 70.5 pcf (0.49 psi/ft). Initial pumping rate was 0.25 BPM and final pumping rate was 3.5 BPM. Formation fracture occurred at 2,825 psi at 3 BPM. After the step rate test the well was shut-in and the tubing pressure stabilized at 2,250 psi. Data gathered from the test is tabulated below. representation of this data is attached. Graphical INJECTION RATE SURFACE INJ COMM VOLUME BPM PSI BBLS 0.25 1,975 2 (Unstable) 0.50 2,000 5-1/2 0.50 2,300 7-1/2 0.50 2,325 9 0.50 2,350 10-1/2 0.50 2,350 11-1/2 0.50 2,350 12-1/2 0.75 2,400 13 0.75 2,400 13-1/2 0.75 2,425 14 0.75 2,425 14-1/2 0.75 2,425 15 0.75 2,425 16 1.0 2,475 16-1/2 1.0 2,475 17-1/2 1.0 2,475 18-1/2 1.25 2,500 19 1.25 2,500 19-1/2 1.25 2,500 22 1.25 2,500 23 1.5 2,550 24 1.5 2,550 25 1.5 2,550 28 1.5 2,550 29 1.5 2,550 31 1.75 2,675 33 1.75 2,675 40 STEP RATE TEST #1 LEWIS RIVER UNIT D-1 Continued INJECTION RATE BPM 1.75 1.75 2.0 2.0 2.0 2.0 2.0 2.25 2.5 2.5 2.5 2.5 3.0 3.0 3.25 3.5 3.5 SURFACE INJ PSI 2,675 2,675 2,720 2,725 2,725 2,725 2,725 2,750 2,800 2,800 2,800 2,800 2,825 2,825 2,825 2,825 2,825 END OF TEST COMMVOLUME BBLS 42 44 52 55 56 58 60 62 63 68 70 78 82 94 96 98 112 (Frac Pressure) NKS:trf 0372r-53/54 LEWIS RIVER WELL TEST 1 Q//,. -- D-I U R~A~S~ PSI 3000! 2900 }- 2800i- 2700 ~ 2600 ~ 2500 t 2400 2500 ~ 2200 k 2100 ~ 2000 ? 1900} 1800 '1700 ~ t600¢- 1500 0 5O0 4-50 4-00 55O ,500 0.5 1 1.5 2 2.5 3 3,5 INJECTION t;~TE, EIPM 2OO 'I50 100 50 ~0 C U M PSi CUM INJ., BBLS Navin Sharma August 29, 1989 STEP RATE TEST #2 LEWIS RIVER UNIT D-1 A second step rate test was performed on the following sands using the same fluid as in Test #1. Fracture equipment at 8 BPM. pressure at hand. 2,562' - 2,596' 2,850' - 2,900' 2,950' - 2,960' 3,020' - 3,046' was unattainable due to limits of pumping Final injection pressure achieved was 2,500 psig Data below represents this step rate test. plotted and the graph attached for review. Information is also INJECTION RATE SURFACE INJ COMM VOLUME BPM PSI BBLS 0.25 950 1 0.25 1,200 2 0.25 1,200 3 0.25 1,200 4 0.5 1,250 5 0.5 1,250 6 0.5 1,250 7 0.75 1,250 8 0.75 1,250 9 0.75 1,250 10 1.00 1,300 11 1.00 1,300 12 1.00 1,300 13 1.125 1,350 14 1.125 1,350 15 1.25 1,350 16 1.25 1,350 17 1.25 1,350 18 1.5 1,400 19 1.5 1,400 20 1.5 1,400 21 1.5 1,350 22 1.5 1,350 23 2.0 1,400 25 2.0 1,400 27 2.0 1,400 29 2.25 1,450 31 2.25 1,450 33 2.25 1,450 35 STEP PATE TEST #2 LEWIS RIVER UNIT D-1 Continued INJECTION RATE SURFACE INJ COMM VOLUME BPM PSI BBLS 2.50 1,450 37 2.50 1,450 39 2.50 1,450 41 2.50 1,450 43 2.50 1,450 45 2.50 1,450 47 3.00 1,500 49 3.00 1,500 51 3.00 1,550 55 3.00 1,550 57 3.00 1,550 59 3.25 1,600 61 3.25 1,600 63 3.25 1,600 65 3.50 1,650 69 3.50 1,650 71 3.50 1,650 73 4.0 1,700 75 4.0 1,700 77 4.0 1,700 79 4.0 1,700 83 4.0 1,700 85 4.25 1,750 89 4.25 1,750 91 4.25 1,750 93 4.25 1,750 100 5.0 1,950 108 5.0 1,950 110 5.0 1,950 124 6.0 2,000 133 6.0 2,000 140 6.0 2,000 148 6.0 2,000 162 6.25 2,050 170 6.25 2,050 188 6.25 2,050 194 6.25 2,050 205 6.25 2,050 210 6.25 2,050 218 Shut-down to increase pump intake capacity. B.J. Suction maxed out due to intake line size. Resumed test within 10 minutes. STEP RATE TEST #2 LEWIS RIVER UNIT D-1 Continued INJECTION RATE SURFACE INJ COMM VOLUME BPM PSI BBLS 6.5 6.5 7.0 7.0 8.0 8.0 8.0 8.0 8.0 Shut-down. Test BJ) terminated. 1,250 Shut-Down 2,200 240 2,200 250 2,300 260 2,300 270 2,500 280 2,500 290 2,500 300 2,500 310 2,500 320 Maxed out on pump strokes (@ 8 BPM Frac Pressure Unreachable NKS:trf 0372r-55/57 LEWIS RIVER WELL D-1 $000 25OO 2OOO 1500 SURFACE PSt 900 - 800 700 6OO 500 400 300 2OO 1 O0 IOO0 0 I 2 3 4 5 6 INJECTION RATE, BPM 0 7 8 9 10 PSI -~ CUM IN J,, BBLS 30" DRIVEN 33' 13-3/8" @ 2395' 9-5/8"@ 5155' LTUBING DETAIL 4-1/2", 12.6#, N-80 TBG. 1) X- Nipple O 287' 2) '~/ST" Pecker O 2302' 3) XA- Sliding Sleeve ~ 2512' 4) XA- Sliding Sleeve ~ 3000' 5) "BWD" Pocket ~ ;3503' 6) × - Nipple ~ 3554' 7) Wireline Re-entry guide O 3584' 2395'- 2397' Sqz'd w/ 300 sx 2562' - 2596' 2850' - 2900' 2950'- 2960' 2967' - 2972' Sqz'd 3020'- 5046' 3070'- 3072' Sqz'd w/ 100 sx 345I' - 3464' Sqz'd w/ 450 sx 3769'- 3685' Sqz'd w/ 150 sx 3873'- 3893' 3894'- 3897' Sqz'd 3907' - 3918'- Top of cement ~) 3945' EZSV ~ 3947' 5956'- 3970' Sqz'd w/ 100 sx EZSV ~ 4020' 4054'- 4054' 4062' - 4068' Sqz'd w/ 200 sx 4077' - 4094' 4122' - 4126' Junk EZSV ~ 4144' Top of cemenf. O 4154' EZSV ~ 4220' LEWIS' RIVER D- 1 INJECTOR CURRENT COMPLETION UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN: GRB SCALE: NONE DATE: 8-31-89 LEWIS RIVER STEP RATE WELL D-I 5000 2900 2800 2700 2600 2500 2400 2500 2200 2100 2000 1900 1800 1700 1600 1500 SUR~CE PSi i i] 500 ~ ~ 14oo 35O ~i 300 0 0.5 t t .5 2 2.5 5 3.5 250 2O0 ] 150 -J 1 O0 -t 50 to 4 INJECTION RATE, BPM C U M B B L S N J E C T E D PSi -¢_.-. CUM INJ., BBLS 30" DRIVEN 33' 68#Z @ 2395' 9-s/8" 5135' LTUBING DETAIL 4-1/2", 12.6#, N-80 TBG. 1) X - Nipple @ 287' 2) '¥ST" Packer O 2302' 3) XA- Sliding Sleeve @ 2512' 4) XA- Sliding Sleeve @ 3000' 5) "BWD" Packer ~ 3503' 6) X - Nipple @ 3554' 7) Wireline Re-entry guide @ 3584' 2395'- 2397' Sqz'd w/ 300 sx 2562' - 2596' 2850' - 2900' 2950' - 2960' 2967' - 2972' Sqz'd 5020' - 3046' 3070' - 3072' Sqz'd w/ 100 sx 3451'- 3464' Sqz'd w/ 450 sx 3714' - 3768' 3662'- 3666' Sqz'd w/ 150 sx 3873' - 3893' 3894' - 3897' Sqz'd 3904' - 39O7' 3907' - 3918' Top of cement @ 3945' EZS'V @ 3947' 3956'- 3970' Sqz'd w/ 100 sx EZSV @ 4O2O' 4034'- 4054' } 4062' - 4068' Sqz'd w/ 200 sx 4077' - 4094' 4122' - 4126' Junk EZSV @ 4144' Top of cement @ 4154' EZSV @ 4220' LEWIS RIVER D- 1 INJECTOR CURRENT COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' GRB SCALE: NONE DATE' 8-3 1-89 / ! / 0% Lewis River D-1 Mechanical Integrity Test Water Injection Well API % 50-283-20068 Date: 8-30-89 Time: 1500 hfs Procedure: Pumped into the 9-5/8" casing - 4-1/2" tubing annulus with 6% KCl brine until a pressure of 1500 psi was reached. The pumps were then shut off and the pressure was observed resulting in the above chart. Note: Witness of this initial test was waived by Blair Wondzell of the AOGCC. Another test will be run with a witness from the AOGCC preseut in the near future. STATE OF ALASKA '* 0 Il ALASKA OIL AN D GAS CONSERVATION CO M M ISSI ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter Casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program _~ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator Union 0il Company of' Oa'lif'ornia (UNOCAL) ~ A~dreAs .u. ~OX 190247, Anch, Ak., 99519-0247 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2086' FWL, 3168' FSL, At top of productive interval Sec. 35, T15N, RgW, SM 6. Datum elevation (DF or KB) GR 100'/115' KB 7. Unit or Property name Lewis River Unit 8. Welt number D-1 9. Permit number feet At effective depth At total depth Straight Hole 89-72 lO. APInumber 50-- 283-20098 11. Field/Pool Lewis River/Unname¢ 12. Present well condition summary Total depth: meaS'ured 8,025 ' true vertical 8,025 ' Effective depth: measured Surf'ace true vertical Surf'ace feet feet feet feet Plugs (measured) Junk (measured) See Attachment No. 3 Casing Length Structural Size Cemented Measured depth True vertical depth Conductor Surface 359' Intermediate 2,395 ' Production 5,135 ' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 30" 20" 13-3/8" 9-5/8" See Driven 33' 33' 496 sxs 359' 359' 850 sxs 2,395' 2,395' 1,361 SXS 5,135' 5,135' Attachment No. 1 None Packers and SSSV (type and measured depth) None 13, Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Nike Ninder 7/28/89 Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service In ieetor 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~/'~ ),, :: :/' Title Environmental Engineer Ro¢¢ D· Rbberts FOR COMMISSION USE ONLY Conditions of-approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ,~ ¢ ~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By I'b~vid W. John£tc2, Commissioner Date 08/15/89 IApp, r0valN°.p_ Date Approved Copy Returned 5 _ - SUBMIT IN TRIPLICATE LEWIS RIVER WELL D-1 CHANGE IN BOP EQUIPMENT Due to spacing difficulties at the D-1 site, Unocal is unable to run the full stack of BOP equipment specified in Unocal's permit to drill dated 7/14/89. Therefore, we are requesting that the 13-5/8" x 5000# sharer single gate BOP fitted with blind rams be left out of the stack. This change affects the D-1 well only. As the proposed work does not require removal of the EZSV cement retainer at 4220' wellhead pressures of more than 2000 psi are not anticipated ATTACHMENT NO. I Lewis River Unit Well D-1 Perforations 4,122' - 4,126' 4,077' - 4,094' 4,062' - 4,068' 4,034' - 4,054' 3,956' - 3,970' 3,451' - 3,464' 2,868' - 2,900' 2,955' - 2,959' 2,967' - 2,972' 3,070' - 3,072' 4,970' - 4,980' 4,675' - 4,704' 4,444' - 4,476' 4,327' - 4,347' 4,290' - 4,300' 4,315' - 4,327' 3,904' - 3,916' 3,882' - 3,897' Comments Appear to be open with Ret @ 3,849' w/ Cmt plug on top to 3,792' (21 sxs) Appear to be open with Ret @ 3,374' w/ Cmt Plug on top to 3,317' (21 sxs) Appear to be open with Ret. @ 2,805' w/ Cmt Plug on top to 2,745' (21 sxs) Squeezed off - 95 sxs Squeezed off - 75 sxs Squeezed off - 95 sxs Squeezed off - 75 sxs Squeezed off - 75 sxs Squeezed off - 75 sxs 0062n/5 ATTAC~T NO, 3 PRESENT LEWIS RIVER FIELD WELL D-1 PROPOSED ~ PluJ 50" 302D.-304~ _-L. 3714-,.3761~ ~. CmL Plugs 51:35--72.35 I LEWIS RIVER D-1 13 5/8" x 5000# Shaffer 13 5/8" x 5000# Shaffer Double Gate !~ 5OOO# Mud Cross Grace Drilling Company Rig #158 Proposed B.O.P. Stack UNOCAL Memo from Candace Lockwood NT ding 6~29/89 6/30/89 7~09~89 ,? :'~ ....,:,,-~:>. 7/10/89 ( .f'~_L...-s/~.~'''~' /~ 7/14/89 (2) (1) (1) (1) s~s ~- ~.v~,o-- u,uc~-,',uoK---=-ro~Fy-l~'~Sle - spreaders - forklift stinger Sections tructure Trailer w/2 rig mats/BOP's - swivel - stairs - misc. Mud pit ~'"" ":' i :: '" Skid electrical equipment ~! ['-(... C ~/' ~'... Drilling equipme~nt barged ,~eluga cont'd Page 2 BARGE # 6 7/16/89 (2) Mud pit (2) Sections shop (1) Trailer w/kelly - mouse hole - rat hole - cat walk - kelly hose - stairs - misc. (1) Trailer w/bbls of oil - oxy & ace bottles - misc. (1) Junk basket BARGE # 7 7/17/89 (1) 500 bbl watertank (rental) (2) Top sections mud pit (1) Shale shaker house (1) Trailer w/rig mats - centrifuge - walkway - stairs - ramp - misc. (1) 966 forklift BARGE # 8 (1) Boiler house (2) Trailer w/drill pipe- drill collars (1) Trailer w/drill pipe- steel -Quadco tools (1) Trailer w/misc, supplies ,J '. L .~ · o . , 0 Environmental Department Alaska District Unocal Oil & Gas Divis Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL( August 3, 1989 C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Lewis River Well D-1 Change in BOP Equipment Permit to Drill #89-72 API No. 50-283-20068 Dear Mr. Chatterton' Due to spacing difficulties at the D-1 site, Unocal is unable to run the full stack of BOP equipment originally specified in our Permit to Drill (approved 7/14/89). For this well only, we are requesting that the 13-5/8" x 5000# sharer single gate BOP fitted with blind rams be left out of the stack. As the proposed work does not require removal of the EZSV cement retainer at 4220' wellhead pressures of more than 2000 psi are not anticipated. Verbal approval was given by Mike Hinder on July 28, 1989 for this change. Attached is a schematic of the proposed BOP stack for Well D-1. Very truly yours, Candace Lockwood] Environmental AnalYst Attachment CC: Gary Bush George Buck CWL:klb 0013n/70 LEWIS RIVER D-1 13 5/8" x 5000# Shaffer 13 5/8" x 5000# Shaffer Double Gate 13 5/8" x 5000# Mud Cross i Grace Drilling Company Rig #158 Proposed B.O.P. Stack Telecopy No. (907) 276-7542 July 14, 1989 Roy 0 Roberts Environmental ~gineer UNOCAL P O Box 190247 Anchorage, AK 99519-0247 Lewis River D-1 Union Oil Company of California Permit ~ 89-72 Surf Loc 2086'F1.~, 3168'FSL, Sec 35, T15N, RgW, SM Bt~ole Loc Straight Hole Dear Mr Roberts: Enclosed is an approved Permit to Drill authorizing re-eL~try of uhe above referenced abandoned well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment. truly/y~u~s, C V Chatterto~ Chairman Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO.fiSSION ~closure C~ Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl ---- STATE OF ALASKA ..... ": ....... ALASKA '~. _ AND GAS CONSERVATION C(. ....MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill D Redril, F-Ii lb. Type of well. Exploratory E] Stratigraphic Test [] Development Oil [] -~' Re-Entry ~ Deepen~I Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of operator _ ' 5. Datum Elevation (DF or I~B) 1'0. ~:ieid and Pool " uni.o.n Oil Company of..Ca, lifornia (UNOCAL.).. GR .100,J115' KB feet Lewis River/Unnamed 3, Address 6.~P ~p2rty. ~_~.~.¢~in tion P.O. Box 190247, Anch, Ak., 99519-0247 .... 4. Location ~)f 'weii at surface" 7. Unit or property Name 11. TyPe Bond (,ce ~0,,Ac 25.025) ' United Pacific 2086' FWL 3168' FSL, Sec. 35, TI5N, R9W, LeW;,,~s River' At top of productive interval SM 8. Well nurpber ~~ance Company D-1 0629269 At total depth 91 ApprOximate spud date Amount Straight Hole July ~ 1989 $200,000 , 12. Distance to nearest 13. Distance to nearest well 14. Number bf acres in property 15. Proposed depth(MO anu TVD) property line 33'68' FSL feet 3520+ feet 1280 acres 4220' ETD feet '16. To be comPleted for deviated wells 17. Anticipated pressure {see 2o ^^c 25.035 (e)(2)) Kickoff depth feet Maximum hole angle " Maximum surtace psig At total depth (TVD) psig '18. casi'6g program Setting Depth size Specifications Top Bottom Quantity of cement ......... i~. ;i'.'.~(incl~cle ~tage data)' Hole casin~ Weight Grade Coupling Length MD TVD MD TVD~;, ~ ~' .,~ 19. 'To"'be completed for Redrill, Re-entry, and Deepen OperatiOns. ,v~,, ....... Present well condition summary Total depth: measured feet Plugs (measured) true vertical 8025' feet See Attachment #3 8025' Effective depth: measured Surface feet Junk (measured) true vertical SurCace feet Casing Length Size Cemented Measured depth True Vertical depth -7-.?-:. StruCtural Conductor 33 · 30" Driven 33 ' 33 ' Surface 359 · 20" 496 sxs 359 · 359 ' Intermediate 2395 · 13-3/8" 850 sxs 2395 ' 2395 ' Production 5135 ' 9-5/8" 1361 sxs 5135 ' 5135 ' Liner Perforation depth: measured - See Attachment No. 1 true vertical "20~ Attachments Filing fee [] Property plat [] BOp Sketch [] Diverter Sketch [] "~rilling program ~ Drilling fluid program [] Time vs depth plot r-I Refraction analysis E3 Seabed report r"t 20 AAC 25.050 requirements [] '2':1".' i hereby certify that the foregoing is true and co'rrect' t~) ~he best of my knowledge Signed /~¢_..¢./;'~. ,M~~ . Title Enviro..nmental Engineer ..... Date6/27/89., R~)v~:). Rob~:rt~i CommiSsion Use Only Permit Number APl number l'""ApProval date I See cover letter ~c/- 7 ~ 50--2 8",.~ - 2. oO¢¢'! 0 7 / 1.4/..8.9.! for other requirements Conditions of approval Samples required [] Yes '~1~ No Mud tog' required [] Yes' ~' No ' Hydrogen sulfide measures [] Yes '~ No Direcd'on'al survey required [] Yes '~ No Required workingj;w,e~sure for BD, PLL'/~_.~2M; [] 3M; [] 5M; [] 10M; [] 15M -- Other:._ ~/~' 602'6n/6 /'~/~/~//~// .... by order of Approv~d"by L.,, ..~,, L ~'~-~~. .c0mmissioner.. the commission Date Form 10-401 Rev. 12-1-85 Submit in'triplicate PRETTY CRK 1 LEWIS RIVER FIELD LEWIS R C-1 LEWIS R A-1 LEWIS R D'-I LEWIS R 13-2 LEWIS R 1 PRETTY CREEK FIELD ~c~ IVAN R 14-31 . .,.'.-:: IVAN R 44-1 X 3 3-1 2 · :~!~;';'"";" · " ." ,';'. IVAN R 23-12 BR W D' 1 '::',~.,, . ,.:;.. · '"""" IVAN RIVER FIELD BRU 212-36 LUGA~ RIVER FIELD .:.: ':j · · .:ISLA GRANDE U'I , STUMP LK U 41-33 STUMP LAKE FIELD Goo~ ATTACHMENT NO. 1 Lewis River Unit Well D-1 Perforations 4,122' - 4,126' 4,077' - 4,094' 4,062' - 4,068' 4,034' - 4,054' 3,956' - 3,970' 3,451' - 3,464' 2,868' - 2,900' 2,955' - 2,959' 2,967' - 2,972' 3,070' - 3,072' 4,970' - 4,980' 4,675' - 4,704' 4,444' - 4,476' 4,327' - 4,347' 4,290' - 4,300' 4,315' - 4,327' 3,904' - 3,916' 3,882' - 3,897' Comment s Appear to be open with Ret @ 3,849' w/ Cmt plug on top to 3,792' (21 sxs) Appear to be open with Ret @ 3,374' w/ Cmt Plug on top to 3,317' (21 sxs) Appear to be open with Ret. @ 2,805' w/ Cmt Plug on top to 2,745' (21 sxs) Squeezed off - 95 sxs Squeezed off - 75 sxs Squeezed off - 95 sxs Squeezed off - 75 sxs Squeezed off - 75 sxs Squeezed off - 75 sxs 0062n/5 LEWIS RIVER D-1 9bjective: To convert abandoned well Lewis River D-1 into an injection well. This conversion work will include the clean-out of the existing wellbore and integrity tests to ensure the safe operation of the well. Workover fluid will be 3% KCL. t.. WORKOVER PROCEDURE 1. MIRU. Well is currently abandoned. 2. NU and test BOPE. Notify AOGCC 24 hours prior to test as this'willbe the first BOPE check on the West Side. . Clean out wellbore of cement and retainers to + 4220'. a. Neat class "G" cement plug (0-50'). be EZSV @ 2805' with 60 linear feet of cement on top (TOC @ ~ 2745'). C. EZSV @ 3374' with 57 linear feet of cement on top (TOC @ ~ 3317'). de EZSV @ 3849' with 57 linear feet of cement on top (TOC @ ± 3792'). Se Cement squeezed perf: 3882'-3897' & 3904' - 3916'. Squeezed with 75 sxs class "G". f. EZSV @ 4220'. Do not clean out. No cement on top of this EZSV. . Make bit and 9-5/8" casing scraper run to 4220' ETD. Circ and cond fluid. . Evaluate 9-5/8" casing using caliper and cement evaluation logs. NOTE: Casing should be in good shape. Was installed in August 1981 and abandoned in early Oct. 1981. . Perform cement squeezes as necessary for zone isolation and/or zone abandonment. Known zones to be squeezed: 2967'-2972', 3451'-3464' and 3956'-4126'. . Clean out cement and retainers to 3940' ETD. Make bit and scraper run. Clean up fluid in wellbore. . Perforate injection zones using tubing conveyed guns. Seven tentative zones between 2562' and 3918'. 9. Injection test through RTTS as necessary. 10. Run 4-1/2" completion: Packer at ~2540' and ~ 2990'. 4-1/2" 12.6# N-80 coated tubing. 11. ND BOPE. NU and test 4-1/2" 5K valve tree. 12. Release Rig. 0062n/6 ATTACHMENT NO. 3 PRESENT i Cmt Plug 5D" LEWIS RIVER FIELD WELL D- 1 3D" Driven to ~0" g4~ H-4.0 0eming ~ 359' =: 3451-3464 38~9' - ' 39~'-391 $' Cmt Plugs 51 PROPOSED 302D-3D4-6 3714--3768 3873--3B93 - '- 3907-3g 1B -- EZSV ~ 479D' ~ .-9--5/8" 47~ N-BD Csg ~ 5135' J NOTE.' For octcrrtional 'peff 'info Below 422D' see i-fietoty A%~/,~. OP~ & gas C;ons. uom,m,~,,,,~'~ Chk~ ~. NKS ATTACHMENT NO. 4 13 5/8" X 5000# SHAFFER 13 5/8'" X 5000# ~_~ SHAFFER DOUBLE GATE [ ~~ 42" 36" 13 5/8" X 5000# MUD CROSS 13 5/8 X 5000# k..._ 1 32I' 11.50 GRACE DRILLING COMPANY RIG #158 PROPOSED B.O.P. STACK I I' ATTACHMENT NO. 5 GRACE DRILLING COMPANY RIG #158' CHOKE MANIFOLD TELECOPY NO.' (907) 276-7542 March 28, 1989 Randall M weiner Executive Director Trustees for Alaska 725 Christensen Drive, Suite 4 Anchorage, AK 99501 Re; ./ Application for Disposal In'jection Order Unocal Lewis River Well D-1 Dear Mr. Wetnar: Today, March 28, 1989, we are advis~by Mr. Robert S. Burd, Direc~ Water Division, Region 10~' U. S. Environmental Pro- tec~ion ~ency (EPA) of his acceptance of the Commission's February 16, 1989 recommendation and EPA's approval for the exemption of freshwater aquifers below a depth of 2300 feet and within an area circumscribed by a one-quarter mile radius around Unocal's Lewis River Well D-1. You w~!l recall from the January~~.I989 hearing record covering Uno~'~'S application for a disp~aI~njection order for Lewis River Well D-I, that~the hearing record will close 10 working dayS-following notification of EPA's action with respect to a freshwater acquifer e~emption. Accordingly the hearing record for Unocal's application for issuance of a disposal order for Lewis River Well No. D-1 will close at 4~30 pm, April 11, 1989. Advise should you have questions. Sincerely, c. v. Chairman ce: Dan Steimborn - EPA 01-A35LH _. OFFICE OF THE GOVERNOR DI VISION OF GO VERNMEN TA L COORDINATION STEVE COWPER, GOVERNOR CENTRAL OFFICE ~ ~,, P.O. BOX AW JUNEAU, ALASKA 99811-0165 PHONE: (907) 465-3562 SOUTHEAST REGIONAL OFFICE SOUTHCENTRAL REGIONAL OFFICE Mr. Robert S. Burd Director, Water Division U. S. Environmental Protection Agency Region 10 1200 Sixth Avenue Seattle, WA 98101 NORTHERN REGIONAL OFFICE 431 NORTH FRANKLIN 2600 DENALI STREET 675 SEVENTH A VENUE P.O. BOX AW, SUITE 101 SUITE 700 STATION H JUNEAU, ALASKA 99811-0165 ANCHORAGE, ALASKA 99503-2798 FAIRBANKS, ALASKA 99701-4596 PHONE: (907) 4653562 PHONE: (907) 274-1581 PHONE: (907) 456-3084 April 5, 1989 Dear Mr. Burd= The Division of Gover~ental Coordination (DGC) has received the info~ation you submitted for our project consistency review of Unocal's Freshwater A~ifer Exemption application for Lewis River Unit - Well D-1. Included in that packet was your consistency dete~ination submitted for our agre~ent under Section 307(c)(1) of the Federal Coastal Zone Management Act as per 15 CFR 930, Subpart C. The enclosed project info~ation sheet includes a State I.D. N~er ~890405-03A. Please refer to this n~ber in any future reference to the project. Appropriate materials have been distributed to participants in the Alaska Coastal Management Program for their review and comments. Reviewer milestones and the associated permits are also indicated on the enclosed sheet. · Note to Reviewers: A full review packet has been sent only to DEC. If you want to review the packet, please call me at 274-1581 and I will send one to you. Thank you for your cooperation in this review process. EnclOsure su3/7 Z~erely, ~ Pro]ect Coordinator RECEIVED APR u A/aska Oil & (]as Cons. Anchorage ~r. Robert S. Burd 2 ~nocal's Freshwater Aquifer Exemption ~tate I. D. No. AK890405-03A Julie ~owe Department of Environmental Conservation Bill Ashton Department of Environmental Conservation Dave Johnston Alaska Oil & Gas Conservatin Commission April 5, 1989 ~u3/7 RECEIVED A~aska Oil & Gas Cons. CommissJoB Anchorage DISTRIBUTION LIST April 5 ~ 1989 [~501 Mr. [~2~1 Mr. [1.2201 Ms. [91 Ms. [28ol [10721 [7121 The [3o31 Mr. [37].1 Mr. Judith Bittner, Department of Natural Resources Division of Parks, Anchorage T~ Brooks, Manaser, Civil En$ineerin$ Alaska Railroad Corporations Anchorage James Eason, Department of Natural Resources, Anchorase Bob Flint, Department of Environmental Conservation, Anchorage Veronica Gilberts Department of Natural Resources, Anchorage Nan~ Hol~uin~ Division of Governmental Coordtnati~n, Juneau Ro~ ~uhndorf, Anchorage Neil Johaunsen, Department of Natural Resources Division of Parks, Anchorage Honorable Doroth~ Jones, Palmer Michael O'Brien, Depar=ment of Transportation and ]~blfc Facilities, AnchoraEe Claude Oxfords PaLmer Lance TTask7~ Department of Fish and C.~me, Anchora§e ol- TELECOPY NO: (907) 276-7542 March 28,-1989 G A Grai~am District Operations Mgr. Unocal P. O. Box 190247 Anchorage, AK 99519-0247 Re: Application for Disposal Injection Order Unocal Lewis River Well D-1 Dear Mr. Graham: Today,~ Ma~Ch 28, 1989, we are advised by Mr. Robert S. Burd, Director, Water Division, Region 10, U. S. Environmental Pro- tection Agency(EPA) of his acceptance of the Commission's February 16, 1~9 recommendation and EPA's approval for the exemption of freshwater aquifers below a depth of 2300 feet and within an area circumscribed by a one-quarter mile radius around Unocal's Lewis River Well D-1. You will recall from the January 13, 1989 hearing record covering Unocal's appllcatzon for a disposal injection order for Lewis River Well D-is that the hearing.record will close 10 working days following notification of EPA's action with respect to a freshwater acquifer exemption. Accordingly the hearing record for Unoca!'s application for issuance of a disposal order for ~Lewis River Well No. D-1 will close at 4:30 pm, April !1, 1989. Advise should you have questions. Sincerely, CC~' . - 2600 DENAI. J STREET SUITE 700 ANC)')ORAGE. ,41...45KA 99503-2~ PROJECT INFORMATION SHEET PROJECT TITLE: STATE I.D. NUMBER/REVIEWING OFFICE: AK89 P~-- -- 6)~ cco. : L APPLICANT CONDUCTING ACTIVITY: ~ ~ DI~CT FEDE~ ACTION: ~ES~ NO ~VIEW TYPE: CONSISTENCY /ANILCA OCS~ ,.. NEPA OTHER ACTIVITY TYPE: ARMED FORCES ACTIVITIES COMMERCIAL/TYPE LAND MGMT. PLAN MINING: HARDROdK' MINING PLACER MINING OFFSHORE' MINING OIL AND GAS OTHER PUBLIC UTILITIES/FACILITIES PRIVATE RESIDENTIAL TIMBER FISHERIES PRODUCTION: GENERAL HATCHERY REMOTE RELEASE FISHERIES FARMS: FINFISH SHELLFISH SEA VEGETABL~.s FISHERIES ENHANCEMENT FISHERIES PROCESSING PROJECT LOCATION: -- NEAREST COASTAL DISTRICT: -- PROJECT INSIDE THE DISTRICT BOUNDARY: YES ~-/ NO , DISTRICT PLAN APPROVED: YES ~--'NO PENDING , REVIEW SCHEDULE: 15-Day 30-Day ~ 50-Day OTHER ~vz~w~ ~Qu~s~ ~o~ ~ooz~zo~ z~o~zo~ ~: COMMENTS DUE TO DGC BY: NOTIFICATION TO APPLICANT BY: DECISION DEADLINE: PROJECT PREVIOUSLY REVIEWED UNDER STATE ID NO._ ,, ! STATE APPROVALS (LIST AGENCY/APPROVAL TYPE/I.D. NUMBER) : FEDERAL APPROVALS (LIST AGENCY/APPROVAL TYPE/I.D. NUMBER) : EXTENSION GRANTED FOR: FORMAL INFORMATION REQUEST PROJECT IN U.O.B. FIELD REVIEW MISCELLANEOUS APPLICANT REQUEST ELEVATION TO DIRECTORS: YES NO ELEVATION TO COMMISSIONERS: YES CLOCK STOPPED ON ,,, ..., , . WAS STOPPED FOR DAYS PUBLIC HEARING HELD DNR DISPOSAL SMCRA ~ _ UNUSUALLY COMPLEX PROJECT IF YES, BY: NO IF YES, BY: · CLOCK RESTARTED ON ACTION AT CLOSEOUT: CLOSE-OUT DATE ACTUAL NUMBER OF DAYS IN REVIEW DISTRICT COMMENTS RECEIVED: YES NO ,, FOR CONCLUSIVE CONSISTENCY DETERMINATIONS: CONSISTENT ,. CONSISTENT WITH STIPULATIONS INCONSISTENT WITHDRAWN FOR OTHER REVIEWS: COMMENTS SUBMITTED OTHER pis/prinfo ... OFFICE OF THE GOVERNOR DIVISION OF GOVERNMENTAL COORDINATION STEVE COWPER, GOVERNOR CENTRAL OFFICE P.O. BOX AW JUNEAU, ALASKA 99811-0165 PHONE: (907) 465-3562 01-A35LH SOUTHEAST REGIONAL OFFICE 431 NORTH FRANKLIN P.O. BOX AW, SUITE 101 JUNEAU, ALASKA 99811-0165 PHONE: (907) 465-3562 REGISTERED MAIL RETURN RECEIPT REQUESTED Ms. Faye Sullivan UNOCAL P.O. Box 19027 Anchorage, AK 99519 Dear Ms. Sullivan: SUBJECT: SOUTHCENTRAL REGIONAL OFFICE 2600 DENALI STREET SUITE 700 ANCHORAGE, ALASKA 99503-2798 PHONE: (907) 274-1581 March 22, 1989 NORTHERN REGIONAL OFFICE 675 SEVENTH A VENUE STATION H FAIRBANKS, ALASKA 99701-4596 PHONE: (907) 456-3084 NORTHERN SUSITNA FLATS SURFACE FACILITIES LEWIS RIVER AND PRETTY CREEK FIELDS STATE I.D. NO. AK890206-05A CONCLUSIVE CONSISTENCY DETERMINATION The Division of Governmental Coordination (DGC) has completed coordinating the state's review of your project for consistency with the Alaska Coastal Management Program (ACMP). On March 15, 1989 you were issued a proposed consistency finding for your project. The project is to construct surface facilities at Lewis River in the Susitna Flats State Game Refuge (T. 15 N., R. 9 W., S.M.). Gas well reworking and testing will be carried out at both the Lewis River and Pretty Creek fields. New surface facilities at the three existing drill pads A, C, and D at the Lewis River Field include: Drill Pad A · A tank building approximately 32 feet by 32 feet which will contain the produced water tank, heat string surge tanks and the heat string pumps; and · a utility building, approximately 20 feet by 20 feet which will contain a heat string heater and electrical generator. Drill Pad C A tank building approximately 32 feet by 32 feet which will contain the produced water tank, he~,~,t~i~,~.u~ge tanks and the heat string pumps; and KkLI:/V[:D · , .Oil & Gas Cons. Commissio[t ":~.'~. ' Anchorage ' Ms. Faye Sillivan 2 Northern Susitna Flats Surface Facilities Lewis River and Pretty Creek Fields State I.D. No. AK890206-05A March 22, 1989 · A utility building approximately 20 feet by 20 feet which will contain a heat string heater and electrical generator. Drill Pad D · A wellhead building, approximately 12 feet by 12 feet to enclose the well and related valves. A buried pipeline will be run across the location to the tank and pump building· · A tank and pump building, approximately 40 feet by 40 feet which will contain two 250 barrel tanks, one 100 barrel tank, one 10 barrel tank, filters and three pumps; and · A utility building, approximately 10 feet by 20 feet, which will contain an electrical generator. In addition, a 2 3/8 inch diameter, 1 mile long pipeline will be buried along the existing road from the D-1 well site to the Lewis River C-1 well site. The work will begin around April 15, 1989, and be completed by September 1, 1989. Crew sizes will range from 15 to 30 people and they will be boarded at a construction camp o6tside the refuge. A portable lavatory will be on location and the contents will be disposed of at a Department of Environmental Conservation approved site. The construction at the D-1 site consists of pile driving with a backhoe and pile driver. A prefabricated module equipped with drain pans with tanks, pumps, boiler and generator already installed will be placed on pilings by an all-terrain crane. Piping will be run between the tanks, pumps and well requiring 2 welding machines, the crane and backhoe. A pipeline from the D-1 site to the C-1 site will be run and buried in the existing road. Excavation of approximately 625 cubic yards will occur with the material being used as backfill. The C-1 and A-1 construction will be .carried out in a manner similar to that at D-1. Excavation at the sites is expected to be less than 75 cubic yards and the material will be used for backfill. No excavations or facilities are planned for Pretty Creek: only well reworking will take place. Approximately 2000 barrels of water per well will be used. Wells will be drilled for water extraction at site A and C. There is an existing water well at Pretty Creek which will provide 2000 barrels of water for the well work at that site. R~~IV~D co11/56 Llaska Oil & Gas Cons. CommJs$io~t Anchorage Ms. Faye Sillivan 3 ' Northern Susitna Flats Surface Facilities Lewis River and Pretty Creek Fields State I.D. No. AK890206-05A · March 22, 1989 Access to all locations will be via existing roadways. This conclusive consistency finding applies to the following state authorizations as per 6 AAC 50. · Alaska Department of Natural Resources, Division of Land and Water Management (DNR/DLWM) - Right-of-Way Permit. Alaska Department of Natural Resources (DLWM) - Temporary Water Rights (4 locations). · Alaska Department of Natural Resources, Division of Oil and Gas (DNR/DOG) - Lease Operations Plan. · Alaska Department of Fish and Game (DFG) - Special Areas Permit. Based on the review of your project by the Alaska Departments of Natural Resources, Environmental Conservation and Fish and Game, and the Matanuska Susitna Borough, the state concurs with your certification that the project is consistent with the ACMP provided the following conditions are met. The following stipulations will appear as conditions on the Right-of-Way permit issued by DNR/DLWM: I · Ail waste generated during operation, maintenance and termination activities under this permit shall be removed or otherwise disposed of as required by state and federal law. Waste in this sub-paragraph means all discarded matter, including, but not limited to human waste, trash, garbage, refuse, oil drums, petroleum products, ashes and discarded equipment. · Use of petroleum products or by-products for dust suppression is not permitted. These stipulations are necessary to prevent pollution and illegal waste disposal in the vicinity of the drill pads and connecting roads in the Susitna Flats State Game Refuge as per the Air, Land and Water Quality Standards of the ACMP (6 AAC 80.140). A copy of this ACMP standard is enclosed. The following stipulations will appear as conditions on the Special Area Permit issued by DFG: · Ail activities shall be confined to existing well pad surfaces and roads unless otherwise KI:EI:iV ED co11/56 ~":k.!,,;!.~a Oil & Gas COllS. Anchorage Ms. Faye Sillivan 4 ~ Northern Susitna Flats Surface Facilities Lewis River and Pretty Creek Fields State I.D. No. AK890206-05A March 22, 1989 2. Public use of and recreation on the refuge shall not be restricted. 3. No waste material shall be d~.sposed of on the refuge. These stipulations are necessary to prevent intrusion into the State Game Refuge outside of the permitted activities and to prevent the limitation of access to the refuge as per the Habitat and Recreation Standards of the ACMP (6 AAC 80.130 and 6 AAC 80.060 respectively). Copies of these ACMP standards are enclosed. This conclusive consistency determination represents a consensus reached between you as the project applicant and the reviewing agencies listed above, as provided for under 6 AAC 50.070(k), regarding the conditions necessary to insure the consistency of the proposed project with the ACMP. If changes to the approved project are proposed prior to or during its siting, construction, or operation, you are required to contact this office immediately to determine if further review and approval of the revised project is necessary. The state reserves the right to enforce compliance with this conclusive consistency determination if the project is changed in any significant way, or if the actual use differs from the approved use contained in the project description. If appropri- ate, the state may amend the state approvals listed in this conclusive consistency determination. Should cultural or paleontological resources be discovered as a result of this activity, we request that work which would disturb such resources be stopped, and that the State Historic Preserva- tion Office be contacted immediately (762-2626). If you have any questions regarding this determination, please contact me at 274-1581. Sincerely, Project Review Coordinator Enclosures co11/56 Ms. Faye Silliva .... 5 Northern Susitna Flats Surface Facilities Lewis River and Pretty Creek Fields State I.D. No. AK890206-05A March 22, 1989 Janetta Pritchard Department of Natural Resources John Wharam Department of Natural Resources Phil Brna Department of Fish and Game Bob Flint Department of Environmental Conservation Claud Oxford Matanuska-Susitna Borough Dave Johnston Alaska Oil and Gas Conservation Commission co11/56 RECE IVED Oil & ~s Cons. Commission fincl~olatle CHECK LEST FOR NEW ~q~LL PERMITS ITEM APPROVE DATE (~' thru 8) (8) ( 3 ) Adm in A~/O~ 7/~ ~ 9. -~/(9 -thru 13-)' ' 10. (10 ~and 13) 12. 13. (4) Casg (14 thru 22) (5) (23 thru 28) Company Lease&YES Well NO NO. Is the permit fee attached .......................................... ~ 2. Is well to be located in a defined pool ............................. ~( 3. Is well located proper distance from property line .................. .~ 4. Is well located proper distance from other wells .................... ~ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ '~ 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve., as an underground source of drinking water ..................... Is enough cement used t'o circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~O~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. / (29 thru (6) Add: GeologyL Engi;neering: rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. _/- Additional Remarks 0 ~Z 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. i ICi OFILMED Oate-- =__~, ,,,/ * * * ALASKA COMPUTING CENTER * * * ****************************** * ............................ * * ....... SCHLb'~BERGER ....... * * ............................ * ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 11-28 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292195800 REFERENCE NO : 98013 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/01/15 ORIGIN : FLIC REEL NAME : 98013 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, PRUDHOE BAY, DS 11-28, API #50-029-21958-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/01/15 ORIGIN : FLIC TAPE NAME : 98013 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, PRUDHOE BAY, DS 11-28, API #50-029-21958-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 11-28 API NUMBER: 500292195800 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 14-JAN-98 JOB NUMBER: 98013 LOGGING ENGINEER: BAILEY OPERATOR WITNESS: K NEUPERT SURFACE LOCATION SECTION: 28 TOWNSHIP: 1 IN RANGE: 1SE FNL : FSL: 745 FEL: 291 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 63. O0 GROUND LEVEL: 28. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 675 11602.0 47. O0 2ND STRING 7. 000 11284.0 26. O0 3RD STRING 7. 000 12470.0 29. O0 PRODUCTION STRING 3.500 11400.0 9.30 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 17-JUL-89 LOGGING COMPANY: WESTERN ATLAS BASELINE DEPTH .............. 88888.0 12323.0 12316.5 12312.5 12307.0 12300.0 12294.0 12289.0 12265.5 12265.0 12258.5 12257.5 12251.5 12246.5 12244.5 12243.0 12239.5 12234.5 12233.5 12231.5 12218.5 12218.0 12210.5 12206.0 12205.0 12198.0 12197.5 12192.0 12181.0 12177.0 12171.0 12170.5 12154.5 12143.0 12135.0 12130.0 12129.0 12125.0 12124.5 12120.5 12120.0 12114.0 12113.5 12102.0 12098.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTD 88887.5 88887.5 12306.5 12299.0 12293.5 12289.5 12264.0 12258.0 12251.5 12247.0 12244.5 12243.0 12239.5 12234.5 12231.5 12218.0 12210.0 12206.0 12197.0 12192.0 12180.5 12176.5 12170.5 12155.5 12144.5 12135.0 12132.0 12123.5 12119.0 12113.5 12106.5 12099.5 12322.5 12316.5 12311.0 12306.5 12299.0 12293.5 12289.5 12264.5 12258.5 12251.5 12247.0 12244.5 12243.0 12239.5 12234.5 12218.0 12210.5 12205.5 12197.0 12192.0 12181.5 12176.5 12170.5 12155.5 12144.5 12135.0 12132.0 12123.5 12119.0 12113.5 12106.0 12099.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 12095.0 12094.0 12094.0 12093.0 12091.0 12092.5 12091.0 12086.0 12085.0 12085.5 12085.0 12081.5 12080.5 12081.0 12081.0 12079.5 12078.0 12078.0 12077.0 12076.5 12076.5 12071.0 12069.0 12069.0 12068.5 12067.0 12067.0 12066.0 12065.0 12065.5 12065.0 12064.0 12063.0 12063.0 12062.5 12059.5 12062.0 12059.5 12049.5 12049.0 12049.0 12046.5 12045.5 12045.5 12044.5 12043.0 12044.0 12043.0 100.0 99.0 98.5 $ REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTD DATA AQUIRED ON ARCOALASKA'S DS 11-28 WELL. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BCS GAM~ARAY, ALSO NPHI PASS #1 AND THE BCS GAM~A~Y, CARRYING ALL CNTD CURVES WITH THE NPHI SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12309.5 12039.0 CNTD 12331.5 12038.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD REMARKS: THIS FILE CONTAINS CASED HOLE CNTD PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE ARE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 48 66 1 66 0.5 FT 21 0 FT 68 1 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELm CODE (HEX) DEPT FT 1066322 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTD PU-S 1066322 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTD 1066322 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTD 1066322 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTD CPS 1066322 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) FCNT CNTD CPS 1066322 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTD CPS 1066322 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTD CPS 1066322 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTD GAPI 1066322 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTD LB 1066322 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTD V 1066322 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1066322 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12450.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD -999.250 CCL.CNTD -999.250 GR.BCS DEPT. 12000.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD -999.250 CCL. CNTD -999.250 GR.BCS -999.250 -999.250 115.243 -999.250 -999.250 21.906 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMFiARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12309.5 11981.5 CNTD 12329.0 11978.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH 88888.0 88887.5 12328.5 12326.0 12320.5 12316.5 12313.0 12307.5 12307.0 12304.5 12301.0 12299.5 12299.0 12298.~ 12294.5 12293.5 12288.5 12288.5 12284.5 12282.5 12281.0 12280.5 12278.5 12277.5 12275.5 12274.5 12275.0 12273 . 5 12273 . 0 12269.5 12268.5 12268.0 12267.0 12266.0 12264.5 12264.5 12262.5 12258.0 12258.0 12257.0 12254.5 12253.0 12252.0 12250.0 12250.0 12248.5 12246.0 12244.5 12244.5 12243.5 12239.5 12239.0 12236.0 CNTD 88885.0 12325.5 12322 5 12319 5 12317 0 12311 0 12307 5 12303 5 12299 5 12296.5 12285.0 12282.5 12274.0 12269.0 12266.0 12264.5 12261.5 12258.0 12254.5 12248.5 12245.5 12243.5 12234.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 12232.5 12230.5 12227.0 12223.5 12220.5 12215.5 12214.5 12211.5 12210.5 12207.0 12202.5 12201.5 12193.0 12191.0 12188.5 12186.0 12181.0 12180.0 12178.0 12173.0 12171.5 12169.5 12167.5 12166.0 12163.0 12161.5 12159.0 12158.0 12155.0 12154.5 12151.5 12147.0 12144.5 12142.0 12139.5 12137.5 12135.5 12135.0 12133 5 12133 0 12129 5 12127 0 12125 5 12122 0 12120 5 12117 0 12116 0 12113 0 12110 0 12107 0 12105 5 12104 0 12102 5 12099 5 12098 0 12232.0 12226.0 12219.0 12214.0 12210.5 12201.5 12194.0 12190.0 12186.5 12180.0 12179.0 12170.5 12165.0 12163.5 12159.5 12155.5 12148.0 12144.0 12139.5 12135.5 12130.5 12126.0 12124.0 12121.5 12114.0 12111.0 12109.5 12106.0 12103.0 12098.5 12229.5 12223.0 12216.0 12211.5 12205.5 12201.0 12190.0 12181.5 12177.5 12173.0 12169.0 12165.0 12162.0 12159.0 12154.5 12152.5 12146.0 12140.0 12138.0 12135.0 12134.0 12132.0 12124.0 12120.5 12116.0 12113.0 12105.0 12099.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 12095.0 12093.5 12088.5 12087.5 12084.5 12083.0 12082.5 12080.5 12079.0 12076.5 12074.5 12072.0 12070.0 12065.0 12064.5 12062.5 12062.0 12059.0 12058.5 12053.5 12050.0 12048.5 12046.0 12045.5 12041.5 12039.5 12037.5 12034.0 12032.5 12032.0 12026.0 12023 5 12022 0 12014 0 12009 5 12005 0 12001 0 100.0 $ 12094.5 12091.0 12087.0 12083.0 12080.5 12063.0 12059.5 12057.0 12053.0 12049.0 12045.5 12041.0 12036.0 12030.0 12028.5 12024.5 12021.5 12016.0 12007.5 12002.5 101.5 12092.0 12086.0 12083.5 12082.0 12078.5 12076.5 12074.0 12069.5 12068.0 12063.0 12060.0 12056.5 12047.5 12044.0 12038.5 12030.0 12021.5 12008.0 98.5 R~L~RKS: THIS FILE CONTAINS LDWG CASED HOLE CNTD PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CNTD CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1066322 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 1066322 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTD 1066322 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTD 1066322 O0 000 O0 0 2 1 1 4 68 0000000000 NCNTCNTD CPS 1066322 O0 000 O0 0 2 1 I 4 68 0000000000 FCNT CNTD CPS 1066322 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 1066322 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 1066322 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 1066322 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 1066322 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 1066322 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12329. 000 NPHI. CNTD 28. 361 NRAT. CNTD 4. 630 CRAT. CNTD NCNT. CNTD 4056. 830 FCNT. CNTD 910. 432 CFTC. CNTD 769.191 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1160.000 CCL. CNTD 0.000 DEPT. 11978.500 NPHI. CNTD 12.375 NRAT. CNTD 2.643 CRAT. CNTD NCNT. CNTD 6504.918 FCNT. CNTD 2497.816 CFTC. CNTD 2189.695 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1095.000 CCL. CNTD 0.000 4.843 3850.491 2. 719 6057. 282 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 10 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : OOICO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12309.0 12028.0 CNTD 12330.0 12024.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTD 88888.0 88887.0 88886.5 12330.5 12329.0 12329.0 12328.0 12326.5 12325.5 12323.0 12322.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 12320.0 12316 5 12313 5 12308 5 12307 5 12305 5 12303 0 12301.0 12299.5 12298.0 12290.0 12286.5 12284.5 12281.5 12281.0 12279.5 12278.5 12276.5 12275.0 12274.5 12268.5 12266.0 12264.5 12262.5 12257.5 12257.0 12254.5 12250.0 12248.5 12246.5 12243.5 12240.0 12239.5 12238.0 12234.0 12233.0 12231.5 12230.5 12225.0 12224.0 12223.5 12220.5 12218.5 12216.0 12211.5 12210.0 12208.0 12205.5 12204.5 12202.0 12199.0 12198.0 12193.0 12190.5 12188.0 12306.5 12299.0 12286.5 12284.5 12280.5 12279.5 12275.5 12274.5 12268.0 12264.0 12257.0 12250.0 12244.0 12239.5 12237.5 12234.0 12232.0 12226.0 12222.0 12219.0 12217.5 12209.0 12206.0 12201.0 12197.0 12192.5 12186.5 12319.5 12314.5 12311.0 12307.5 12303.5 12301.5 12299.5 12296.5 12292.5 12287.5 12282.0 12278.0 12274.0 12264.5 12261.5 12258.0 12254.5 12249.0 12245.5 12243.5 12239.0 12234.5 12229.0 12223.0 12216.0 12211.5 12207.5 12204.0 12197.0 12190.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 12 12181.0 12179.0 12175.5 12171.0 12169.0 12167.0 12164.5 12162.5 12160.5 12158.0 12157.0 12155.0 12151.5 12147.5 12144.5 12142.0 12139.0 12137.0 12135.5 12134.0 12133.0 12129.0 12127.0 12124.5 12122.0 12119.5 12116 5 12114 0 12110 5 12105 0 12104 5 12100 0 12098 5 12095 5 12095 0 12093 0 12088 5 12087 5 12084.5 12082.5 12080.0 12077.0 12075.0 12074.0 12073.0 12070.0 12069.0 12064.0 12062.5 12061.5 12059.5 12054.5 12051.5 12048.0 12046.0 12180.0 12170.5 12165.0 12163.5 12160.0 12157.5 12148.0 12144.0 12139.5 12138.0 12135.0 12130.5 12123.5 12120.5 12113.5 12106.5 12099.5 12094.5 12091.0 12087.0 12080.5 12076.0 12069.0 12067.0 12063.0 12059.5 12057.5 12049.5 12179.5 12174.0 12168.5 12167.0 12162.0 12159.5 12154.5 12153.0 12146.0 12139.0 12134.0 12132.0 12127.0 12123.5 12120.5 12116.0 12114.5 12110.5 12105.5 12099.0 12094.5 12091.0 12086.0 12083.5 12078.5 12074.0 12072.0 12068.0 12065.5 12063.0 12059.5 12053.0 12047.5 12043.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 13 12044.5 12043.5 12044.0 12041.0 12039.0 12041.0 100.0 102.0 $ 12041.0 12039.0 98.0 REMARKS: THIS FILE CONTAINS LDWG CASED HOLE CNTD PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GI~CH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYING ALL CNTD CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 66 66 73 66 66 73 65 0 0 44 1 0.5 FT 23 1 2 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1066322 O0 000 O0 0 3 1 i 4 68 0000000000 NPHI CNTD PU-S 1066322 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTD 1066322 O0 000 O0 0 3 1 I 4 68 0000000000 CRAT CNTD 1066322 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTD CPS 1066322 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTD CPS 1066322 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTD CPS 1066322 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 14 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) CNTC CNTD CPS 1066322 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTD GAPI 1066322 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 1066322 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTD V 1066322 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12330.500 NPHI.CNTD 29.400 NRAT. CNTD 4.577 CRAT. CNTD NCNT. CNTD 4046.365 FCNT. CNTD 892.704 CFTC. CNTD 739.417 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1145.000 CCL. CNTD 0.000 DEPT. 12024.000 NPHI. CNTD 13.816 NRAT. CNTD 2.784 CRAT. CNTD NCNT. CNTD 6120.219 FCNT. CNTD 2185.792 CFTC. CNTD 1871.503 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1110.000 CCL. CNTD 0.000 4. 971 3753. 771 2.916 5678. 935 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 15 LDWG TOOL CODE PASS NUMBERS CNTD 1, 2, 3, $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FT 1066322 O0 000 O0 0 4 1 1 4 68 0000000000 DEPT NPHI CNAV PU-S 1066322 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1066322 ~00 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1066322 O0 000 O0 0 4 1 1 4 68 0000000000 NCNTCNAV CPS 1066322 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1066322 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1066322 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1066322 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 1066322 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 1066322 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 16 ** DATA ** DEPT. 12331.500 NPHI.CNAV -999.250 NRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV GRCH. CNTD -999.250 TENS. CNTD 1180.000 DEPT. 12038.500 NPHI.CNAV 13.949 NRAT. CNAV NCNT. CNAV 6241.996 FCNT. CNAV 2265.251 CFTC. CNAV GRCH. CNTD -999.250 TENS. CNTD 1120.000 -999.250 -999.250 2. 774 1929.268 CRAT. CNAV CNTC. CNA V CRA T . CNA V CNTC. CNA V -999.25O -999.250 2. 934 5801. 683 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Cdrves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... CNTD 12348.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): STOP DEPTH 12038.0 01-0CT-97 CP 44.2 1010 01-0CT-97 12326.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-i998 09:20 PAGE: 17 TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 12335.0 12050.0 12330.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTD COMPENSATED NUETRON $ TOOL NUMBER CGRS-A CNC-DA-146 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12470.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE 7.00 25.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 18000 TOOL STANDOFF (IN): REMARKS: TIED IN TO WA BHC DATED 7/17/89. THE PURPOSE OF THIS WAS WAS TO DETERMINE IF THE SAND AT 12220' WAS GAS FILLED. THE GOC APPEARS TO BE AT 12210' WITH A GAS UNDERRUN FROM 12222' TO 12225', FROM 12249' TO 12254', AND FROM 12259 ' TO 12263 '. THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 18 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1066322 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1066322 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1066322 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1066322 O0 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 1066322 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1066322 O0 000 O0 0 5 I 1 4 68 0000000000 CNTC PS1 CPS 1066322 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1066322 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1066322 O0 000 O0 0 $ 1 1 4 68 0000000000 TENS PS1 LB 1066322 O0 000 O0 0 5 1 1 4 68 0000000000 CCLD PS1 V 1066322 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12347. 500 NPHI. PS1 27. 262 RTNR. PS1 4. 511 TNRA. PS1 RCNT. PSI 4156. 862 RCFT. PS1 921. 569 CNTC. PS1 3874. 916 CFTC. PS1 GR. PS1 40. 031 TENS. PS1 760. 000 CCLD. PS1 0. 021 4.706 793.878 LIS Tape Verification Listing Schlumberger Alaska Compu ting Center 15-JAN-1998 09:20 PAGE: 19 DEPT. 12038.000 NPHI.PS1 14.027 RTNR.PS1 RCNT. PS1 6180.257 RCFT. PS1 ' 2231.759 CNTC. PS1 GR.PS1 33.469 TENS.PSi 1110.000 CCLD.PS1 2.800 TNRA.PS1 5803.819 CFTC. PSi 0.000 2.945 1907.760 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... CNTD 12358.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 11978.0 01-0CT-97 CP 44.2 1010 01-0CT-97 12326.0 12335.0 12050.0 12330.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 2O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAFIFIA RAY CNTD COMPENSATED NUETRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : TOOL NUMBER CGRS-A CNC-DA-146 12470.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE 7.00 25.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNTRATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 18000 TOOL STANDOFF (IN): REMARKS: TIED IN TO WA BHC DATED 7/17/89. THE PURPOSE OF THIS WAS WAS TO DETERMINE IF THE SAND AT 12220' WAS GAS FILLED. THE GOC APPEARS TO BE AT 12210' WITH A GAS UNDERRUN FROM 12222' TO 12225', FROM 12249' TO 12254', AND FROM 12259' TO 12263'. THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 1066322 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1066322 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1066322 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1066322 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1066322 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1066322 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1066322 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC. PS2 CPS 1066322 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1066322 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1066322 O0 000 O0 0 6 1 1 4 68 0000000000 CCLDPS2 V 1066322 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 12357.500 NPHI.PS2 26.143 RTNR.PS2 4.375 TNRA.PS2 RCNT. PS2 4117.646 RCFT. PS2 941.176 CNTC. PS2 3838.360 CFTC. PS2 GR.PS2 34.000 TENS.PS2 730.000 CCLD.PS2 0.021 DEPT. 11978.000 NPHI.PS2 11.784 RTNR.PS2 2.556 TNRA.PS2 RCNT. PS2 6714.754 RCFT. PS2 2592.274 CNTC. PS2 6277.024 CFTC.PS2 GR.PS2 22.297 TENS.PS2 1095.000 CCLD.PS2 0.000 4.565 810.769 2.638 2275.033 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 22 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12354.0 12025.0 CNTD LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 01-0CT-97 CP 44.2 1010 01-0CT-97 12326.0 12335.0 12050.0 12330.0 1800.0 TOOL NUMBER ........... LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 23 GR CNTD $ GAMFiA RAY COMPENSATED NUETRON CGRS-A CNC-DA-146 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12470.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE 7.00 25.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 18000 TOOL STANDOFF (IN): REMARKS: TIED IN TO WA BHC DATED 7/17/89. THE PURPOSE OF THIS WAS WAS TO DETERMINE IF THE SAND AT 12220' WAS GAS FILLED. THE GOC APPEARS TO BE AT 12210' WITH A GAS UNDERRUN FROM 12222' TO 12225', FROM 12249' TO 12254', AND FROM 12259' TO 12263'. THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 24 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1066322 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1066322 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1066322 O0 000 O0 0 7 1 1 4 68 0000000000 TNRAPS3 1066322 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1066322 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1066322 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1066322 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1066322 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1066322 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1066322 O0 000 O0 0 7 1 1 4 68 0000000000 CCLDPS3 V 1066322 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 12353.500 NPHI.PS3 28.570 RTNR.PS3 4.667 TNRA.PS3 RCNT. PS3 4122.699 RCFT. PS3 883.436 CNTC. PS3 3843.070 CFTC. PS3 GR.PS3 31.844 TENS.PS3 930.000 CCLD.PS3 0.021 DEPT. 12024.500 NPHI.PS3 14.011 RTNR.PS3 2.752 TNRA.PS3 RCNT. PS3 6434.973 RCFT. PS3 2185.792 CNTC. PS3 5799.701 CFTC. PS3 GR.PS3 23.688 TENS.PS3 1105.000 CCLD.PS3 0.000 4.869 761.029 2.943 1890.056 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1998 09:20 PAGE: 25 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/01/15 ORIGIN : FLIC TAPE NAME : 98013 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, PRUDHOE BAY, DS 11-28, API #50-029-21958-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/01/15 ORIGIN : FLIC REEL NAME : 98013 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, PRUDHOE BAY, DS 11-28, API #50-029-21958-00