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180-093
~~ • - ~ ,_ • Date: 08-27-2009 Transmitta! Number:93091 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. ~)~yS~~~ ..l !. \.? ~>.9 ~. , ~~~~<rar T r . -~ L If vou have anv auestions, please contact Joe Lastufka at (907)564-4091 Delivery Contents Bottom SW Name Date Com an Run To De th De th Descri tion BAKER CARBON/OXYGEN LOG 12-09 09-06-2008 HUGHES 1 8840 9079 GAMMA RAY RESERVOIR PERFORMANCE BAKER MONITO CARBON OXYGEN 12-09 03-03-2009 HUGHES 1 8926 8952 ANALYSIS BAKER RESERVOIR PERFORMANCE 12-09 09-07-2008 HUGHES 1 8840 9079 MONITOR RESERVOIR PERFORMANCE BAKER MONITOR GASVIEW 12-09 02-09-2009 HUGHES 1 8926 8952 SATURATION ANALYSIS BAKER INTERPRETATION OF RPM 12-09 09-07-2008 HUGHES DATA CD-ROM - RPS/GSA PRM RPM/COA CARBON/OXYGEN BAKER LOG/GR META, LAS, PDF 12-09 08-19-2009 HUGHES FORMAT BAKER RESERVOIR PERFORMANCE 11-17A 08-17-2008 HUGHES 1 9850 10370 MONITOR RESERVOIR PERFORMANCE BAKER MONITOR GASVIEW 11-17A 01-30-2009 HUGHES 1 10107 10362 SAT~JRATION ANALYSIS BAKER INTERPRETATION OF RPM 11-17A 08-17-2008 HUGHES DATA CD-ROM - RPM/GSA PRM BAKER META, LAS, AND PDF 11-17A 08-19-2009 HUGHES FORMAT BAKER RESERVOIR PERFORMANCE 14-18B 08-24-2008 HUGHES 1 10580 11043 MONITOR RESERVOIR PERFORMANCE BAKER MONITOR GASVIEW 14-18B 01-29-2009 HUGHES 1 10700 11018 SATURATION ANALYSIS BAKER INTERPRETATION OF RPM 14-18B 08-24-2008 HUGHES DATA CD-ROM - RPM/GSA PRM BAKER META, LAS, AND PDF 14-18B 08-19-2009 HUGHES FORMAT BAKER RESERVOIR PERFORMANCE M-04 08-25-2008 HUGNES 1 11100 11370 MONITOR M-04 01-29-2009 BAKER 1 11212 11374 RESERVOIR PERFORMANCE . Petrotechnical Data Center LR2-t 900 E. Benson Blvd. PO Sox 196612 Anchorage, AK 99~ t9-66t2 ~ ~ . ~ BP Alaska Interpretation of RPM Data Well: 12-09 Field: Prudhoe Bay Report Status: Authors: Reviewed: Logged Date: Report Date: Final Report Yonghwee Kim and Rafay Ansari David Chace 7th Se t er 2008 30t h J u ly 2009 ri.~ ~ Nuc~Es Baker Atlas ;~~~. ~ ~~~~~~~~ ,. _~~. . t, ~ , a ~ <~ , f ,~~~ .~~~* ~ ~.: ~ £ ~; ~~.ri~~ ~~, ~~ ~~ ~r: ~. vst ~ ~~ ~ ~ ~ ~,~ ~, `"~~;~~~iu' .. .fi:•~ d~~~;.: ?~.,.f"~M~;,~` z`~`= N~~ ~ i~ > •~YtY ~~.~~ k'~~. . '~;;~';z~ ~" ,~"y~.'~~:3~i . . ~ 3.»~~:: xx~ ~~G .a ~~ x ;~r. ~ ~~ ~=4~'~ ,~~.~Y~ .. $)i x•. xTM ' ~ ~~ : ; ~ttp://www. bake rhu g h es.com/bake ratlas :, ~~zw ~ ~~~, {~ ~~ r~~ , ~~~~~ ~ h"~~~° ~;~ ..A:a~ ~ ~~ ; ~} ~ ~~ ~ ~ ~~ ~~r~ ~ ~ '~:. i '", ~y~~. . . ~ ~n~£e~~''n;. . =V~ : ,x%3, . ~~§ 5~'"n° ~ . ~..~~~~'~' x~#`tY` . ~.o.. ,~f~.. ., t~„~. ~~; °4~ ~ ~ 1~60-C~3 r-, u r-, u ~ ~ • IN MAKING INTERPRETATIONS OF LOGS OUR EMPLOYEES WILL GIVE THE CUSTOMER THE BENEFIT OF THEIR BEST JUDGEMENT, BUT SINCE ALL INTERPRETATIONS ARE OPINIONS BASED ON INFERENCES FROM ELECTRICAL OR OTHER MEASUREMENTS WE CANNOT AND DO NOT GUARANTEE THE ACCURACY OR THE CORRECTNESS OF ANY INTERPRETATION. WE SHALL NOT BE LIABLE OR RESPONSIBLE FOR ANY LOSS, COST, DAMAGES, OR EXPENSES WHATSOEVER INCURRED OR SUSTAINED BY THE CUSTOMER RESULTING FROM ANY INTERPRETATION MADE BY ANY OF OUR EMPLOYEES. ~ ~ BP Alaska - Prudhoe - Well 12-09- RPM Satu on Analysis Page i CONTENTS 1 INTRODUCTION 1.1 Objectives 1.2 Results 1.3 Data Set 1.4 Sequence of Events 2 ANALYSIS AND INTERPRETATION 2.1 RPM Overview 2.2 GasView Analysis Methodology ~ 2.2 C/O Analysis Methodology 3 DAT A DISCUSSION 3.1 GasView Analysis and Discussion 3.2 C/O Analysis and Discussion RPM REFERENCES 12 LIST OF TABLES AND FIGURES Table 2.1 Parameters Used for Input to GasView Modelling Figure 2.1 GasView Response Chart Figure 2.2 Example of GasView Results Figure 2.3 C/O Response Chart Figure 3.1 Processed GasView Results of Sag Interval Figure 3.2 Processed GasView Results of Ivishak Interva! Figure 3.3 Processed C/O Results of Sag Intenral Figure 3.4 Processed C/O Results of Ivishak Interval r. u ~ Baker Hughes Inc. ~ BP Alaska - Prudhoe - Weli 12-09- RPM Satu on Analysis Page 1 INTRODUCTION (Source: BP Logging Program) 12-09 is a gas lifted producer in the Waterflood area. This well is currently on-line producing ~400 BOPD; the SI time required to obtain the log will result in a small production impact. • Current Status: Producer • Last test: 7/19/08: 8651 BFPD, 424 BOPD, 4882 GOR, 95% WC • Max Deviation: 30° ~ 8100' MD • Min. ID: 3.813" through 4-1/2" DB-6 n+pple ~ 8524' MD • Last TD tag: 3/6/06: Drift w/ 3-3/8" dummy gun to 9069' MD • Last Downhole Ops: 6/23/07: C/O GLVs. • Latest H2S Level: 175 ppm 3/24/08 • Tie-in Log: BHCS on 5/1/81, SLB PPROF with DEFT on 8/6/98 1.1 Objectives ~ This RPM surveillance will provide a quantitative estimate of gas saturation, oil saturation and define the GOC, OWC in the Ivishak and Sag production intervals. Through comparison with the historical log data of the well, we will have a better understanding of the capacity and limitation of this improved pulsed neutron log tool. The combination of a GasView analysis and C/O log interpretation will render better understanding of the 12-09 well. 1.2 Results • The RPM data was of very good quality and repeatability. Very limited volumetric data was available for both SAG (26 ft) and Ivishak (34 ft) which posed a problem in application of solution constraints. As a result, the uncertainty in saturation analysis is higher. • By utilizing GasView methodology, a gas saturation curve (Sg) has been calculated while two water saturation curves (Sw and Sw_HT) provided by BP have been displayed for comparison. • The GasView results indicate that the well was mostly filled with liquid. C/O analysis results in the Ivishak suggest higher oil saturation at the bottom of the open perf interval. C/O analysis results are qualitative in the SAG interval because of the movement of oil/water contact in borehole while logging of all passes. 1.3 Data Set ~ This well was logged on 7th Sep 2008. The RPM data has been recorded through 7inch casing and 8.5inch borehole section. Three passes were recorded at 10 ft/min. The GasView passes were recorded with a source output of 800,000 cps (counts per second). Five C/O passes were recorded at 2 fUmin with C/O mode. 1.4 Sequence of Events • Log was correlated to SWS/PROD-PROFILE-DEFT (reference log) DATE 8th Jun 2008. • Log started at 09:30 on 7th Sep 2008 and finished at 20:30 on the same day. • The top logged interval was 8,840 ft and the bottom logged interval was 9,079 ft. • 15:01 75 BBLS AWAY 5 BPM 1000 PSI • 1526 200 BBLS AWAY 5 BPM WELL ON VAC 110 • 15:36 240 BBLS AWAY REDUCE RATE TO 0.5 BPM • 15:44 250 BBLS AWAY 0.5 BPM 0 PSI • 15:59 FIRST PASS Baker Hughes Inc. ~~ BP Alaska - Prudhoe - Well 12-09- RPM Satu on Analysis Page 2 • 16:23 272 BBLS AWAY 0.5 BPM 0 PSI • 17:15 300 BBLS AWAY 0.5 BPM 0 PSI • 1725 THIRD PASS • 18:04 325 BBLS AWAY 0.5 BPM O PSI • 18:06 325 BBLS AWAY 0.5 BPM 0 PSI • 18:50 THROUGH LOGGING PUMP 60 BBL CRUDE & 5 BBLS METH • DUE TO SCALE IN CSG CORRELATED TO GAS LIFT MANDRAL @ 6,060 FT r-, u r~ u • Baker Hughes Inc. ~ BP Alaska - Prudhoe - Well 12-09- RPM Satu , on Analysis Page 3 2 ANALYSIS AND INTERPRETATION 2.1 RPM Overview The Baker Atlas RPM is a pulsed neutron instrument capable of acquiring data in several modes. PNC (Pulsed Neutron Capture) data is used to evaluate the formation saturation in known high salinity formations and to identify gas, while C/O (Carbon/Oxygen) is used to evaluate the formation saturation in low- or unknown-salinity formations. Further to the water saturation calculation modes the tool can also be operated in AFL (Annular Flow Log) mode to quantify water velocity in both continuous passes and stations. Also, borehole holdup can be calculated utilizing the PNHI (Pulsed Neutron Holdup Indicator) mode; this is particularly useful in horizontal or highly deviated welis where the accuracy of conventional production logging instruments is greatly reduced. More recently, the modified RPM-C tool has allowed us to carry out gas saturation analysis ( GasViews"' ) analysis from three detector PNC data. ~ 2.2 GasView Analysis Methodology Baker Atlas has enhanced the Reservoir Performance Monitor (RPM) service by introducing three features: improved instrumentation, a new characterization, and advanced interpretive techniques. The GasView service utilizes the improved resolution of the RPM-C tool, a new gas response characterisation, and a new petrophysical algorithm to deliver a better method for identifying gas and measuring gas saturation. The three detector RPM-C instrument allows gas detection ratios to be taken over longer spacing than conventional instruments. These new measurements are substantially more sensitive to the change in neutron-gamma distribution that indicates a change from liquid to gas-filled porosity. This improved sensitivity allows the instrument to resolve the presence of gas where conventional instruments cannot, and it provides better resolution in the gas saturation calculation. Characterization of tool response allows more accurate quantification of saturation. A global tool response characterization database has been constructed for standard open hole and cased hole completions. This includes varying combinations of mineralogy, fluid density, and gas pressure/density. The following table states the parameters which have been used in the modelling of the predicted curve response for Prudhoe well 12-09. Table 2.1 Parameters used in GasView modellinq of well 12-09 ~ Parameter Value Borehole Size 8.5 inch Casin Size 7.0 inch Borehole Fluid Water Matrix T e Sandstone Gas Densit 0.26 /cc Oil Densit 0.8 /cc Water Densit 1.00 /cc A GasView job planner is available to design optimal logging programs. The following chart shows the expected response of the RIN13 curve (this chart is an example only and not relevant to this specific case of well 12-09). Baker Hughes Inc. i• I • ~• BP Alaska - Prudhoe - Well 12-09- RPM Satu on Analysis Page 4 ~~~~?;=.: . ~1=1? Delta Siqma vs Fromation Porosily I Deke Sigma vs Famelian WMei Safnity I Gas CocfficieM Fde Irpt Gm Chnt I Ratio: PIU Datectw degme af fk ~~ ~ BAKEII -~ gas chails ~ 1- 3 ~ I° ] Nl7~iHES Baker Atlas Borehda fLid dansYiy: FormNion tMid density Fnmalan gas denti~y 0.10 0.69 0.69 Sd"8E~10" Pm1/E~oA CaeNiaeraa ~ RIN wet gas Porosity 0.00 0.05 0.10 0.15 0.20 0.25 0.30 0.35 0.40 OK Cancel ~ Figure 2.1 GasView Response Chart The Dynamic Gas Envelope (DGE) interpretation explicitly accounts for variations in porosity and shale volume in the saturation result. While these effects must be removed from the saturation solution, they are included in the visual DGE representation for greater insight into the processing. See example GasView results below. For results of well 12-09, see section 3.1. I ~ Baker Hughes Inc. • BP Alaska - Prudhoe - Well 12-09- RPM Satu on Analysis Page 5 EXAMPLE • 2.2 C/O Analysis Methodology When formation waters are fresh, of mixed or unknown salinity, the RPM-C/O acquisition mode is used to detect hydrocarbons. In this mode, direct measurement of the oxygen and carbon content of the reservoir are made, allowing differentiation of hydrocarbon zones from water-bearing zones. Since chlorine has virtually no inelastic reaction cross section, the C/O measurement can be used to determine formation water saturation independent of salinity. The C/O analysis creates both the minimum and maximum C/O ratios which are calculated from the characterization database level-by-level from the porosity, mineralogy, hole size, and borehole fluid content. The recorded C/O is adjusted by a parameter to account for calibration differences and Baker Hughes Inc. Figure 2.2 Example of GasView Results ~ BP Alaska - Prudhoe - Well 12-09- RPM Satu on Analysis Page 6 temperature effects. The calibrated C/O is then used directly in the following interpretation model to determine formation saturation: S =1- C~~ - COmin W OCO where; SW = Water saturation CO~ = Calibrated C/O ratio COm;,, = Minimum (water) C/O ratio 4C0 = Difference between the oil and water C/O ratios A C/O job planner is available to design optimal logging programs, view the predicted C/O response, and • determine expected resolution and statistical error. The following chart shows the expected response of the C/O curve (this chart is example only and not relevant to this specific well 12-09). It shows the difference in the formation value of oil and the value of water against porosity with oil in the borehole. In cleanest sands of the example well the porosity is approximately 13%, the planner below shows that there is an expected C/O difference of 0.0316 between this porosity being 100% oil filled and 100% water filled. This value 0.0316 is known as the DCO (Delta C/O). The planner also predicts a water saturation uncertainty of around 16%. 4~:~.J' 3 . ~ . ~1 Boiehole/Foimation Inp~6 Fan ~~ I WMIN Cha~t I Baehole Diarn~er (nJ: 8~5 Casnq Diameter (in~: ~ famationMineralogy: ~ • 2.5 2.0 15 DeteUa: INear _ ~«J9~~9 SPeed (k/minl I' Number d Loggrg Paues: ~- esponse Chart SUSW 04 CO Max 0 3 1 7230 DCO ~ 2 0 0316 CO Min 1.6913 01 SUSW 0.1581 0.1300 0.1 300 1.0 Porosiry 0 0 -~~--- Porosiry 0 00 0.05 0 10 0.15 0.20 0.25 0.30 0.35 0 40 0 00 0.05 0.10 0 15 0.20 0.25 0.30 0.35 OA~ _ _ _ Ca1CWation5 at Specified Holdup= ~0 r ~;_CalcWateNurt~bei Desired SUSW: 0.00 ~--'--......_......_.._.._..._..._..._._..._..._, ~ W Aehieve Desired SUSW+ at Paosity (0.00-1.00); 0.2 Calculated SUSW @ Paosity: 0.103704 Figure 2.3 C/O Response Chart Standatd Deviatwn SS 0.02 WMIN 0.746905 LS QOt ~ Baker Hughes Inc. Fractional SYatistical UncertainN in Sw (SU51M at Soec~ed Holtlup BP Alaska - Prudhoe - Well 12-09- RPM Sat on Analysis Page 7 3 DATA DISCUSSION 3.1 GasView Analysis and Discussion A GasView analysis has been carried out by averaging three passes logged on the 9th Sep 2008. All passes were recorded at 10 ft/min with a source output of 800,000 cps. All the passes have been shifted on depth using open hole GR provided by BP. All data looks to be of good quality and repeatability. The pre-modelling software for GasView uses a number of lab test calibration points, these lab tests are carried out using pure quartzite for a sandstone environment and tombstone marble for limestone environment. It is very unlikely that this type of matrix would be present down hole therefore a single value calibration is made to the RIN13 curve to correct for material differences in the matrix. This parameter should be used to normalize the RIN13 curve in a zone of known saturation. The provided volumetrics of Sag and Ivishak formation were limited to very short sections with no shale intervals making the shale calibration difficult. The length of supplied volumetrics were 24 ft for Sag and ~ 34 ft for Ivishak. However, both these intervals are completely perforated and borehole fluid is the injected water. Therefore, wet normalization and shale calibration were performed such that the gas saturation approached 0% at some spots in these perforated intervals. For GasView analysis, RIN13 normalization value was used as 24 and the shale calibration value was 95. Also, note that the pick up depth is 9,040 ft based on the BKS change (BKS-short spaced background countrate). Moreover, GasView model is based on sandstone lithology; however, dolomite is present in Sag interval. The RIN13 matrix point is higher for dolomite compared to sandstone. Therefore, the presence of dolomite has been corrected by adjusting the RIN13 curve. The results of this analysis can be observed in Figures 3.1 and 3.2 for Sag and Ivishak respectively. The presented results are analyzed with formation gas density of 0.26 g/cc and volumetrics provided by BP. The results show the Dynamic Gas Envelope (DGE explained in section 2.2) overlaid with the normalized RIN13 curve. The position of the RIN13 curve between the Gas line (red) and the Liquid line (blue) of the DGE determines the gas saturation. The figure shows how the measured curve moves between the liquid and gas lines and the resulting gas saturation curve (Sg). GasView results show that porosity is dominantly filled with liquid throughout the logged section. Since the well was under water injection while logging this may have been a result of injected water displacing the in-situ fluids. Baker Hughes Inc. BP Alaska - Prudhoe - Well 12-09- RPM Sat~ on Analysis Page 9 FLUID H'E7-GAS ETlvELOPE FLUID rn G~A.S ~ i ~ti: I~JDI~;~+71~ih! ° GaS ~ i'~] R t,~ C BUt' .............................................. ; SAND ; ............................................... < CONG '•.; SID G~;~4h~~,~, F.~v I'F.FA4-C'} ~ ` ,c~~~ CCL Cae 5aturation ~~~~~ UNE EN'~rELiiPE - Fii'. - VSH EFFEC?IVE POROSITY ~ GAIAMA RAY (0/H; , Swe: BP 'NET LJNE ENVELOPE TOTAL POROSffY (G~,PI} EFFFCR~f PDf~9fY p S',ve H': BF - - PJORA44LJZED =r rs (cps} __ , = i -- ,~, Figure 32 Processed GasView Results of Ivishak Interval 3.2 C/O Analysis and Discussion A C/O analysis has been performed by averaging four passes. Five C/O passes were recorded at 2 ft/min on the 7th Sep 2008, but the fifth pass was excluded due to possible oil slug passing by the tool. Four passes have been shifted on depth using open hole GR provided by BP. All data looks to be of good quality and repeatability. The C/O interpretation log display is a five track plot. The water saturation calculated from the C/O measurement is presented in track one along with two water saturation curves provided by BP. Track two displays the depth in feet. Track three contains C/Omin and C/Om~ curves calculated from the characterisation database along with the calibrated average of the actual recorded C/O curves (red curve). Track four shows the porosity and fluid volume based on the final water saturation from the C/O log. Track five contains porosity and mineral volume data used in the processing. For Sag interval, normalization value was used as 0 and the shale calibration value was 0.03. For Ivishak interval, normalization values was 0.01 and shale calibration value was 0.03. Also, note that the pick up depth is 9,040 ft based on the BKS change (BKS-short spaced background countrate). The result in Sag can be used for qualitative purpose only because of fluid contact movement across it. In Ivishak interval, the results show higher oil saturation towards the bottom of logged interval. A good correlation can be observed between the final C/O curve (red) and the Min/Max C/O curves calculated from the characterisation database which results in a water saturation of good confidence. The results of the C/O saturation analysis can be seen in Figures 3.3 and 3.4. Baker Hughes Inc. • BP Alaska - Prudhoe - Well 12-09- RPM Satu ion Analysis Page 10 ~ ~~ Baker Hughes Inc. Figure 3.3 Processed C/O Results of Sag Interval BP Alaska - Prudhoe - Well 12-09- RPM Satu on Analysis Page 11 Figure 3.4 Processed C/O Results of Ivishak Interval Baker Hughes Inc. '~ BP Alaska - Prudhoe - Well 12-09- RPM Satw on Analysis Page 12 RPM References Chace, D.M., Trcka, D.E., and Dawe, B.A., "Application and interpretation of continuous oxygen activation logs for measuring complex water flow profiles in injection wells," SPE 69th Annual Technical Conference and Exhibition, New Orleans, Louisiana, Paper 28412, 1994. Trcka, D., van den Berg, F., Manan, W.A., Peeters, M., and Mickael, M., "Measuring three-phase holdups in horizontal wellbores using pulsed neutron instruments," SPE Annual Technical Conference and Exhibition, Denver, Colorado, Paper 36561, 1996. Gilchrist, W.A. Jr., Prati, E., Pemeper, R., Mickael, M.W., and Trcka, D., "Introduction of a New Through- Tubing Multifunction Pulsed Neutron Instrument," SPE paper 56803, Annual SPE Technical Conference and Exhibition, Houston, Texas, Oct. 1999. Trcka, D.E., and Chace, D.M., "Improved method for measuring annular water flow in injection wells using continuous oxygen activation logging," SPE 68th Annual Technical Conference and Exhibition, ` Houston, Texas, Paper 26450, 1993. Chace, D.M., Trcka, D.E., Wang, J., Bousche, O., van der Spek, A., al Nasser, H., "A new production logging service for horizontal wells," SPWLA 39th Annual Symposium, Keystone, CO, 1998, Paper H. Mickael, M.W., Trcka, D.E., Pemper, R., "Dynamic Multi-Parameter Interpretation of Dual-Detector Carbon/Oxygen Measurements", SPE Annual Technical Conference and Exhibition, Houston, Texas, Oct. 1999. Chace, D., Trcka, D., Georgi, D., Wang, J., Bousche, O., van der Spek, A., al Nasser, H., "New instrumentation and methods for production logging in multiphase horizontal wells," SPE MEOS, Bahrain, Paper 53220, 1999. David Chace, Jianrong Wang, Roman Mirzwinski, Jorge Maxit, and Darryl Trcka, "Applications of a New Multiple Sensor Production Logging System for Horizontal and Highly-Deviated Multiphase Producers", SPE paper 63141, Annual SPE Technical Conference and Exhibition, Dallas, Texas, October, 2000. Trcka, D., Oliver, D., Mickael M., Chace, D., Georgi, D., and Wang, J., "Reservoir performance monitoring in the new millennium", Proceedings of the Tunisian Oil Conference, April, 2000. Riley, S., Guivarch, B., Chace, D.M., Trcka, D.E., Clark, J., "Production logging in horizontal gravel- packed highly viscous oil producers in the North Sea", SPE Annual Technical Conference and Exhibition held in Denver, Colorado, Oct. 2003. ~ Baker Hughes Inc. 5~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # !~/ .a JUN 1 g~ 2OG9 al~sk~ qil ~ Gas Cons. Commission At1t~lOP~e Log Description N0.5279 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD .06/16/09 14-23A AYKP-00016 USIT 04/10/09 1 1 A-44 AP3 36 SCMT - 04/26J09 1 1 14-23A AYKP-00016 USIT _ 04/10/09 1 1 07-10A B1JJ-00022 MEM CN STP - p5/26/Og ~ 1 07-14B 12-09 AYOO-00029 AYTU-00038 LDL - L PRODUCTION PROFILE" .~ 05/26/09 05/31/09 1 1 1 1 V-218 AVYS-00048 INJECTION PROFILEIWFL i) •-- 05/29/09 1 1 15-34A AWJI-00020 MCNL _ Oq/Zp/Og ~ 1 A-44 AWLS-00017 CH EDIT DCL-GR (SCMT) - 05/25/Og 1 DI FACC ACICNAWI Crlf!C eC nc~or ov cln_w un w..n s~TUnuu,e. w..~ ww.....-..... _-______-____ _ -_ __~______.___.._. _...-...~.-..~..... r.-.v.. .v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ,~}~ yy ~~ n Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • • osi2sios "~Ch~l~tlb~l'~~1' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # r r* r, ~ nn rlncrrintinn N0.4908 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n..a., n~ 17-12 11978484 PRODUCTION PROFILE - 09/19/08 1 1 P2-27 12017505 PRODUCTION PROFILE ~ _ 09/08/08 1 1 18-05A 11999048 FREE POINT INDICATOR LOG 09/16/08 1 1 E-36 12034922 SCMT - --a 09/13/08 1 1 06-13A 12066547 MEM PROD PROFILE b(p- ((~ 09/05/08 1 1 12-09 12083409 MEM DENSITY LOG ( 09/06/08 1 1 13-14 11978482 PROD PROFILE ~ _ ~ 09/13/08 1 1 L-214A 11970843 INJECTION PROFILE C~'3~ 09/05/08 1 1 L-210 12031511 INJECTION PROFILE 09/02/08 1 1 L-216 11970842 INJECTION PROFILE ~ 09/04/08 1 1 V-221 12034920 INJECTION PROFILE ? 09/09/08 1 1 L-205L4 40016965 OH MWD/LWD EDIT 06/26/08 (2 PRINTS & 1 CD HAND DELIVERED SEPARATELY) n~ ~wo~ wnvu~uu ~- • --- ^-•••-.-•••-•-.. •w~,•rv , v, v.M.~,~~aa e~~~v nGIVn1~I1~V VIYG VVr'i CNlil'1 IV: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ ~(~ ( Alaska Data & Consulting Services 2525 Gambell Street, Sui 400 Anchorage, AK 9777ggq~~~~~~03-2 8 ATTN: Beth ~ _ Received by. • • '~ ~~_~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervis°r''''~' .~i~-'13 \ DATE: May 7, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit Drill Site 12 Monday, May 7, 2001: I traveled to BPXs Drill Site 12 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test RepOrt indicates I witnessed the testing of 21 wells and 42 components with 1 failure. The surface safety valve on well 12-12 had a slow leak when pressure tested. This valve was serviced and retested by the operator on this date. Bill Preston (lead DS operator) performed the testing today; he demonstrated good test procedures and was a pleasure to WOrk with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at BPXs Drill Site 12. PBU DS 12, 21 wells, 42 components, 1 failure 2.3% failure rate 29 wellhouse inspections Attachment: SVS PBU DS 12 5-7-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU DS 12 5-7-01 CS Alas2 Oil and Gas Conservation Commiss)n Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Pmdhoe / PBU / DS 12 Separator psi: LPS 160 HPS 5/7/01 Well Pemit Separ Set L~ Test Test Test Date ~1, Number Number PSI PSI Trip Code Code Code Passed GAS orCYCLE 12-01 1790230 ~2-02 ~790320 12-03 17'90410 160 i 50 150 P P .... OIL ,, ~ , ~ ~ 12-04A 1811870 160, 150 150 P P OIL 12,05 1790550 , , i , ,,, 12-06A 1920540 160~ 150 150 P P OIL , , , , , , 12-07A 1811750 160 '150 140 P P OIL ,I ,, 12-08B 1811670 160 150~ 140 P P OIL ~~~ 1800930 ' 160 ...... 150~ 125 ' P P OIL , , 12-10A 1920890 160 150 150 P P OIL 12-11 1810730 ,, , 12'12 1810830 160 150 90 P 4 OIL i , ,,i , i , 12-13B 1960170 '160 150 150 P P OIL , 12-14A, 1981460 160 150 150 ,P P i, ,, OIL 12-15 1830320 , ,160 , 150150 P P OIL 12-16A 1931480 160 150 150 P P OIL .. , , ~2-~7 ~830040 ~60 ~0 ~so~ e e om '~2-~8 "i822060~ ~60 ~50 ~50 P P ' ' om ~-i9 ' ~2~980 ' ' ' , 12-20 1821910 ,,, , , , , ,. , 12-21 1840480 12-22 ' 1840600 160 150 125 P P ' OIL 12-23 1840580 12-25 1831660 12-26 1840140 160 150 125 P P OIL 12-27A 1990390 , 12-28A 1990330 160 150, 170 P P OIL i , , ~2-29 ~840320 ~2-30 ~88'~420 ' ' ' 12-31 1890010 12-32 1890110 160 150 150 P P 0IL , , , ~2-33 ~89o~oo 12-34 'i941370, 'i60 150 150 ' P' P ' OIL 12-35 1951300 160 150 100~ , 12-36 1951580 160 150 150 P P OIL RJF 1/16/01 Page 1 of 2 SVS PBU DS12 5-7-p4~C~S Well Number Wells: Permit Separ Set L/P Test Date Number PSI PSI Trip Code Passed 21 Components: 42 Failures: 1 Failure Rate: Oil, WAG, GINJ, GAS or CYCLE 2.38% r-'l 9o Day Remarks: Surface Safety Valve on well 12-12 had slow leak when pressure.tested. RJF 1/16/01 Page 2 of 2 SVS PBU DS12 5-7-01 CS Drill Site: 12 Well: 9 Sat Jan 22 11:37:23 1994 K-VAL¥-E DES i GN DOI: SET ESSORE: 350 @ 60 DEG FTP @ CLOSE (PSIG): 300' PSiG - K-V~ CLASS (A,B,C): A COMF~ENTS: Redesigned to allow testin9 of k-valve in well. This will require the well be choked back %o keep (or a~,p c~'~) from dumping. To aid in dumping, the LGR can be raised up, and if ok, open the drain system also. CC: ENGiNEERiNG FILE / COORDINATOR PRB 24 (WITH ATTAC~.~NTS) j ~ .~. S~IART /~.~'. G. SHOEMAKE PRB 20 (WITHOUT ATTACH~'~NTS) Tom Brassfield / Joe Ralph PRB 15 (COVER ONLY) ... Meianie Wilson ATO 15 (WITNOUT ATTACHMENTS ) STATE OF ALASKA (CO'~-ER ONLY) DESIGNED BY: ~MM ·., Drill Site: '12 Well: 9 WELL TEST DATA Sat Jan 22 11:37:26 1994 CK~ LGR FTP OiL %WTR GOR GLR LIQ P~ PI SEPARATOR DATE SEL TEMP PRES 89 1979 301 510 92.7 3564 537 7058 2184 5.69 174 276 01/23/94 Y 89 2049 304 ' 470 93.6 3678 '507 7446 0 0.00 175 275 01/22/94 88 2005 311 89 2023 89 2020 29i 89 2040 310 89 .2024 319 89'~ 2023 300 90 2014 298 90 2014 302 89 1998 289 794 88.1 2298. 570 6716 2111 0.00 173 288 01/17/94 4.45 93,8 4124 536 7196 0 0.00 175 283 01/14/94. 727 89.5 2737 714 89.1 2786 900 87.1 4284 747 88.4 4259 874 87.6 3822 865 87.7 3717 791 88.5 3783 575 6974 0 0.00 171' 263 01/09/94 614 6557 2017 0.00 170 288 12/30/93 841 6984 0 0.00 169 286 11/30/93 801 6494 0 0.00 169 273 11/04/93 756 7083 0 0.00 171 264 i0/30/93 743 7034 0 0.00 171 269 10/30/93 719 6935 0 0.00 170 258 10/27/93 ESC=EXIT; Fi=HELP; F3=DESiGN; F4=DISTRIBUTION LIST; F5~SENSITIVITY TABLE; F6=CHECKLIST; Fi0=ACCEPT; SFS=RESTORE WELL TEST; CFg=CYCLE DATA; SSSV DEPTH (MEAS): 2105 FTP @ CLOSE '~-~ t=o~;: 300 PRESS ADJUST~.~NT: I TE~.~ CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP ~, PI PROF USES BH T~P AND WELL PI ~S C= ..69702e-3 N= 1.000000 NEW C= ..02163e-2 ENTERED N= 1.000000 ARCO Alaska, Inc. Date: Feb 11, 1994 P.O. Box 100360, ~chorage, AK Transmittal #: 94021 99510j ~ Subject: From/Location: BHP Report John Degrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Well Log Date TooJ Type Run, Scale Contractdr Number (M-D-Y) i , 1-9 12-17'92 BHP Camco 1-14 i 8-11-92 BHP Camco 1-14 8-11-92 BHP - Camco 2-2 1-10-93 BHP .. - t Camco 2-13 2-12-93 BHP Camco 2-35 5-21-92 BHP - Camco , 3-15A 3-20-93 BHP - Camco 3-20 12-18-92~ 'BHP "" -" Camco '"4'-'7ST" 5-17-92' "BHP - Camco 4-14 1-9-93 BHP - Camco 4-29 12-28-92 BH P - Camco 4-42 4-27-92' ' 'BHP ' - Camco 5-9 2-21-93 BHP ' ' Cam(~o i 5-16 2-21-93 BHP - Camco 5-25 2-21-93 BHP - " ' 'Camco i ,i 5-31 2-21-93 BHP - Camco i 5'33 1-29-93 BHP - Camco i 5-35 1-29-93 BHP - Camco 5-36 1-29-93 BHP - Camco 9-24 2-15-93' .... BHP - ' Camco ii 9-40 1-25-93 BHP - Camco 9-51 3-20:93. BHP -' ....... temco 12-7A 12-6-92 BH P - Camco i 12-7A 12-10-92 BHP - Camco iii 12-9 12-10-92 BHP - Carnco i 12-29 12-14-92 BHP - Camco 13-15 7-3-92 BHP - Ca'mo 13-20 7-4-92 BHP - ' ......Camco 13-23A 7-4-92 BHP - Camco 13-32 7-3-92 BHP "" ............... ~,amco i 14-11 11-23-92 BHP - Camco 16-19 10-19-92 BHP - Camco 16-21 10-19-92 BHP - Camco 16-30 9-28-92 BHP - Camco 17-3 12-12-92 BHP - ~,amco 17-10 11-8-~2 BHP - Camco i i 17-11 2-8-93 BHP - Camco 17-20 12-21-92 BHP - "' Camco 17-21 12-21-92 BHP" - Camco 18'~5 6-14-92 ' BHP" - Camco RECEIVED FEB i ~ 1994 Alaska 0i/,t Gas Cons. Anchorage C°rm~i~lon Drill Site: 12 Well: 9 Mon Mar 15 21:13:01 1993 K-VALVE DESIGN DOME SET PRESSURE: 230 PSIG @ 60 DEG.F FTP @ CLOSE (PSIG): 175 PSIG K-VALVE CLASS (A,B,C): C COMMENTS: New K-valve well. Designed in low pressure co commonline (C), but may be moved to CL "B" oCcassionally. LP commonline currently, runs about 180-185 psi. CC: ENGINEERING FILE / COORDINATO~"~RE 24 (WITH ATTACHMENTS ) J.C. SMART / M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS ) E.E. VAUGHN / E.A. CAMPBELL PRB 15 (COVER ONLY) K.L. HUDSON ATO 1566 (WITHOUT ATTACHMENTS ) STATE OF ~KA (COVER ONLY) DESIGNED BY: RTB ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-2-92 REFERENCE: 2-9 2-13 ARCO CASED HOLE FINALS Prod Profile Prod Proffie Leak Detect (Flexstak) Prod Profile Prod Profile GR/Colln- Run 1, 5" Run Rzln L ~' Run Run Run 1, 5' RunL~ Run LS" Run 1,5" -~'"~ 7-25____.. 9-7-92 PITS Run L 5" 9-24-92 Collar/Baker IBP Run 1, 5" 9-1-92 Prof PrOfile Run 1, 9-1-92 Prod Proffie Run 1, ~ 9-244~ Perf Breakdown l~m 1, Please sign and return~ atta?/~_ co.receipt of data. RECEIVED BY 8onya Wallace OCT 0 § 1992 APPROVED_ ATO-1529 Alaeka 0il & Gas Cons. ~0mmi~# 9221~ ' ~chorage # CENTRAL FLIES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON # MOBIL # PI~.T~n,S PB WEI~ FILES R&D # BPX # STATE OF ALASKA Cnmc~ Camco Camco Camco Camco Camco Camco C~mco C~__mco C~mco Cnmco Cmneo C~mco C*~_mco * This is not a field print for 1-11. ~ ~ STATE OF ALASKA ~ ALASKA r~.AND GAS CONSERVATION CC ~'IlSSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X,. Plugging ,, Perforate , ,,, Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 648' FNL, 725' FWL, Sec. 18, T10N, R15E, UM At top of productive interval 1142' FNL, 1284' FWL, Sec. 18, T10N, R15E, UM At effective depth At total depth 1410' FNL, 1499' FWL, Sec. 18, T10N, R15E, UM 5. Type of Well Development X~ Exploratory Stratigraphic Service 6, Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-9 9. Permit number/approval number 8O-93 10. APl number 50 - 029-20505 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth' measured true vertical 9782 feet 9527 feet Plugs(measured) FILL @ 9070' MD (7/24/92) Effective depth: measured 9070 feet true vertical 8888 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 300 sx Permafrost 80' 80' Surface 2538' 13-3/8" 2500 sx Fondu & 400 sx PF II 2609' 2609' Production 8757' 9-5/8" 500 sx Cl G 8828' 8785' Liner 1261' 7" 325 sx Cl G 9785' 9219' Perforation depth: measured 8926-8951'; 9008-9020'; 9020-9048'; 9048-9050'; 9050-9070' true vertical 8760-8782'; 8833-8844'; 8844-8869'; 8868-8870'; 8870-8888' Tubing (size, grade, and measured depth) 5-1/2", 17#, PCT @ 8426' MD; 4-1/2", 12.6~, N-80, PC tail @ 8526' MD Packers and SSSV (type and measured depth) Baker SAB 13. Stimulation or cement squeeze summary 14. Pa~J~~l'~:~2" Camco Bal-0 SSSV @2105' MD Intervalstreated(measured) See attached. AU~, '1 Treatment description including volumes used and final pr~ .0i| & GaS C0fls. ~Ancfioragel · Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1245 4831 6044 -- Subsequent to operation 1406 'j 3698 6213 Tubing Pressure 260 329 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ... Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DI 868/10 DTK cc: SW, JWP ~ 12-09 DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF SAG RIVER 6/30/92: RIH w/Inflatable Bridge Plug & set plug at 8980' MD (middle of element), to isolate the lower perforation intervals at: 9008 - 9020' MD (Z4) 9020 - 9048' MD (Z4) 9048 - 9050' MD (Z4) 9050 - 9070' MD (Z4) Ref. Log: BHCS 5/1/81. 7/1/92: RIH w/bailer & dumped a CaCO3 cap on top of Bridge Plug to 8962' MD. 7/2/92: Reperforated: 8926 - 8951' MD (Sag) Ref. Log: BHCS 5/1/81. 7~4~92: MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment, using 16/20 mesh proppant, through the Sag River perforations above the Bridge Plug (listed above). Pumped: a) 450 bbls Pre Pad @ 40 bpm, followed by b) Shutdown. ISIP @ 1890. Resumed pumping: c) 250 bbls Crosslinked Pad @ 20 bpm, followed by d) 427 bbls Crosslinked Slurry with proppant stages @ 1 - 12 ppg, followed by e) 200 bbls Flush, followed by f) Shutdown, Placed a total of 85,686 lbs of proppant into the formation. Rigged down. 7/5/92: Performed a proppant fill cleanout down to top of Bridge Plug (above). 7/21/92: Rill & retrieved the Inflatable Bridge Plug. Tagged PBTD at 9070' MD. Returned well to production with gaslift & obtained a valid production test. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-10-92 REFERENCE: ARco CASED HOLE FINALS ~e '"~ 6-12 7-1-92 CCL/Chemical Cutter ~e-14A 7-1-92 C~T CEr c6-1~ g 7-1-92 C~ ~ y~-~ 7-~ CCL/Ped ~ ~-~ ~/-/~ ~~ C~/Ped ~9 ~o~ 7-~-~ C~/Ped 1~~./~ 7-~92 ~ent~ ~nd Please sign and return the attached copy as. receipt of data. .EC,iV Have A Nice Day! R E C E IV E ~ Sonya W_~!l~ce JUL 1 5 ]992. ATO-1529 Alaska Oil & Gas Cons. Commission Anchorage # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL APPROVED~ .... Trans# 92151 # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO Atlas Sch Sch Sch Atlas Atlas Atlas Atlas STATE OF ALASKA 0 I{ I G IN/ ALASKA '~ AND GAS CONSERVATION C(~ ~IlSSlON REPORT SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator ARCO Alaska~ Inc. 3. Address Operation shutdown Pull tubing ,, Stimulate X,, Plugging --..- Perforate X Alter casing Repair well Other ,, X 5. Type of Well 6. Datum of elevation(DF or KB) Development X 71 RKB Exploratory , , Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 648' FNL, 725' FWL, Sec. 18, T10N, R15E, UM At top of productive interval 1142' FNL, 1284' FWL, Sec. 18, T10N, R15E, UM At effective depth At total depth 1410 FNL, 1499' FWL, Sec. 18, T10N, R15E, UM Service Prudhoe Bay Unit 8. Well number 12-9 9. Permit number/approval number 80-93 10. APl number 50 - 029-20505 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present Well condition summary Total depth: measured true vertical 9782 feet 9527 feet Plugs(measured) 9150' MD (5/1/92) Effective depth: measured 9752 feet true vertical 9561 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 300 sx Permafrost 80' 80' Surface 2538' 13-3/8" 2500 sx Fondu & 400 sx PF II 2609' 2609' Production 8757' 9-5/8" 500 sx Cl 'G' 8828' 8785' Liner 1261' 7" 325 sx CI 'G' 9785' 9219' Perforation depth: measured 9008-9020'; 9020-9048'; 9048-9050'; 9050-9070' true Vertical 8833-8844'; 8844-8868'; 8868-8870'; 8870-8888' Tubing (size, grade, and measured depth) 5-1/2", 17#, PCT @ 8426' MD; 4-1/2", 12.64t, N-80, PC tail @ 8526' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 8441' MD; 5-1/2" Camco Bal-0 SSSV @ 2105' MD 13. Stimulation or cement squeeze summary ~ I~l..~.,LI V I..!./ 14. Intervals treated(measured) See attached. J U N 2 4 1992 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Commission Reoreseqtetive Dai!v Ayemge productiQn or In!ection Data Anchorage OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 486 2002 3847 -- 501 Subsequent to operation 1023 5225 5860 -- 479 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X...~_ Gas Suspended_._ Service i 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 842/9 LW/JCA cc: SW, JWP SUBMIT IN DUPLICATE 12-09 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE & ZONE 4 FRACTURE TREATMENT 3/13/92: Performed a fill cleanout down to 9258' MD. 3/18/92: MiRU CT & PT equipment to 4100 psi. RIH w/CT & fluid packed wellbore w/1% KCI water, then pumped an acid wash, treating the perforations at: 8926 - 8951' MD (Sag) 9008 - 9020' MD (Z4) 9020 - 9048' MD (Z4) 9050 - 9070' MD (Z4) 9086 - 9106' MD (Z4) 9122 - 9162' MD (Z4) 9184 - 9202' MD (Z4) Ref. Log: BHCS 5/1/81. Pumped 90 bbls 15% HCI - 10% Xylene, followed by 95 bbls 13% HCl - 1.5% HF, followed by 100 bbls 3% NH4Cl Flush. Displaced acid w/1% KCI water, then pumped 87 bbls of Latex Acid Resistive Cement w/Aggregate, squeezing the perforations (listed above). Placed 35 bbls of cement behind pipe at 3050 psi max squeeze pressure, held for 1 hour. Hesitated to maximum squeeze pressure, due to pressure breakbacks during the squeeze. Contaminated cement & cleaned out cement from wellbore. Left cement plug in the well below 9118' MD, over the lower squeezed perforation intervals. POOH. Rigged down. 3~28/92: Reperforated: 9008 - 9020' MD (Z4) 9020 - 9048' MD (Z4) 9050- 9070' MD (Z4) Ref. Log: BHCS 5/1/81. Added perforations: 9048 - 9050' MD (Z4) Ref. Log: BHCS 5/1/81. 4/8/92: Pumped slurry containing 850 lbs 20/40 mesh sand, to place a sand plug to 9070' MD. RD. 4/10/92: MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment, using 12/18 mesh & resin coated proppants, through the perforations (listed above). Pumped 295 bbls Pre Pad @ 50 bpm, followed by Shutdown. ISIP @ 1350. Resumed pumping 833 bbls Pad @ 50 bpm, followed by 840 bbls Cross Linked Slurry in 2-10 ppg proppant stages, followed by 214 bbls Flush, followed by Shutdown. Placed a total of 199,500 lbs of proppant into formation. Rigged down. 4/12/92: Performed a proppant/sand fill cleanout to 9075' MD. 5/1/92: Performed a fill cleanout to 9150' MD. REEEIVED Returned well to production and obtained a valid welltest. JUN 2 4 1992 Alaska Oil & Gas Cons. Comrnissio~ Anchorage AR~ Ahska, Inc. P.O.Boz 100360 Anchorage. Alaska 9~510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS * 3-34 ~F-~? 4-3-92 4-30 ~--g~ 4.12-92 ?~)r- 7-7A ~ff-/~ 4-10.92 9-3 4-18-92 ~-~t l? ~/** 9-308T 3-30-92 ~'ffY 1'2-9 3-28-92 ~_&~ ~ 12-19 4-19-92 12-19 4.19.92 ~g-~'f 14-2 4-9.92 Sptnner/Temp/Press Run 1,--- VeFtflog Run 1, 5" Turfing~[~ Cutter Run 1.5" Pe ',.0~ Run 1, 5" Collsa~'/Pel-f Run 1, 5" IFC/GR Run 1, 5" Perf ~c.,[. Run 1, 5" Collar fie.in to Jewelry Run 1, 5" Collar/Perf Run 1' 5" Perf (Post-Squeeze) Run 1, 5" Please sign and return the attached copy as receipt of data. RECEIVE D B Y_~~~..__~ Have A Nice Day! R [ C £ IV £ D ~onya Wallace ~ ~ ~ APPROVED__ ATO-1529 M ~s~ ~~5 ~ ,Alaska Oil & ~as Cons. Commissio~ Anchorage # CI:I~ON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL #~ PB~~ R&D # BPX # STATE OF ALASKA TEXACO Sch Aths Aths Sch Aths Atlas Sch Atlas Aths Sch * The correct well name is 3~34. ** The correct APl# for 9-308T is 50-029-21411. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-31-92 REFERENCE: ! o~ 5-24 1-11-92 Prod Profile Run 1, 5" Camco 1-11-92 Prod Profile Run 1' 5" Camco 1-10-92 Prod Profile Run 1, 5" Camco 1-10-92 Prod Proffie Run 1, 5" Camco 1-15-92 CNL Run 1, 5" Sch 1-18,92 Collar Log Run 1, 5" Atlas 12-27-91 Prod Profile Run 1, 5" Camco 1-12-92 Jewelry Run 1, 5" Camco 1-20-92 Tubing Cutter Run 1, 5" Atlas 1-13-92 Leak Detect Run 1, 1" C_~mco 1-12-92 Prod Profile Run 1, 5" Camco 1-17-92 CNL-GR Run 1, 2"&5" Atlas 1-9-92 Prod Profile Run 1, 5" Camco 1-19-92 CCL/Perf Run 1, 5' Atlas Please sign and return the at~,ached copy as receipt of RECEIVED By___~_~_._~ Have A Nice Dayt · Sonya Wallace APPROVED .~ ATO-1529 Trans# 9202~-' { # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # p'FrrTX,T'PS PB~~ R&D # BPX # STATE OF ALASKA TEXACO * The correct APl# for 13-2A is 50-029-20324-01. FEB 03 1992 Alaska Oil & (3as Cons. Commi~ion Anchorage TO: THRU: FROM: MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION '. Lonnie C Sm DATE: Nov. 29, 1991 C°mmiSsi°ne~ - FILE NO: LG1129- 5. DOC Blair Wondzell Sr Petr Eng TELEPHONE NO: SUBJECT: Rig/BOPE Inspection Arco DS12-9 Prudhoe Bay Unit Louis R Grimaldi/~A Petr Inspector Saturday. November 2~, 1991 I made a rig/BOrE inspection on Nabor's Rig 3S performing a workover on Arco's Well DS12-9. I found all equipment on the rig to be operating satisfactorily with the only noncompliance being a 4" x 2 1/2" swedge on the end of the blowdown line. This was removed at my request. The surrounding area was being kept neat and orderly and no other noncompliances were discovered. In summary, I made a rig/BOPE inspection on Nabor's Rig 3S finding one noncompliance, a restriction in the blooey line. Attachment 02-00lA (Rev. 6/89) 20/llfMEMO1.PM3 J ALAS KA OIL AND GAS CONSERVATION COMMI S S ION TO: Lonnie C. Smith ............... Commissioner FROM: Louis R.Grimaldi Petroleum Inspector DATE: FILE NO: SUBJECT: OPERATION: Drlg Compl__ Wkvr~ UIC Operator, ,m, O Permit # Location: Sec ! ~ T tO~t/ R 1~ M Drlg contr ~ ~0~ Rig~ Location (gen'l) ~~ ~ Well sign -) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ....... Rig/BOPE Inspection Report ? / Representative ~ ~_~ Well name ~),..~' /~2.'"'~ Representative ~/C~ ~ IN COMPLIANCE; IN COMPLIANCE; yes n_~o n/a A. DIVERTER yes n_~o n/a 1. ( ) ( ) ( ) line sz & length 33.~ ( ) ( 2. ( ) ( ) ( ) line conn& anchored 34. ~. ( ) ( 3. ( ) ( ) ( ) bifurcated & dwn wind 35.~ ( ) ( 4. ( ) ( ) ( ) 90° targeted turns 5. ( ) ( ) ( ) vlvs: auto & simultaneous 36. ~ ( ) ( 6. ( ) ( ) ( ) annular pack-off 37. ~X~ ( ) ( 7. ( ) ( ) ) condition 38. ()(~ ( ) ( B. BOP STACK 39.~ ( ) ( 8. ~) ( ) ( ) wellhead flg wkg press 40. () ( ) 9.'~) ( ) ( ) stack wkg press 41. (~ ( ) ( 10. (~ ( ) ( ) annular preventer 42. ~ ( ) ( 11. (~ ( ) ( ) pipe rams 43. ~)~ ( ) ( 12. (~%) ( ) ( ) blind rams 13, ~ ( ) ( ) stack anchored 44, ~<~ ( ) ( 14. ~J ( ) ( ) chke/kill line sz 45. ~ ( ) ( 15. ~ ( ) ( ) 90° turns targeted (chke & kill ln) 46. ~ ( ) ( 16. ~ ( ) ( ) HCR vlvs (chk_~e & kil._~l) 47. {~ ( ) ( 17, ~ ( ) ( ) manual vlvs (chke & kill) 18. ~) ( ) ( ) connections (flgd, whd, clmpd) 19. (~ ( ) ( ) drl spool 48. ( ) ( ) 20, !~) ( ) ( ) flow nipple 49, (~ ( ) 21.()~) ( ) ( ) fl ow monitor 22, (~ ( ) ( ) control lines fire protected 50. J~. ( ) C. CLOSING UNITS 51, j~ ( ) 23. (~) ( ) ( ) wkg press 24. ~ ( ) ( ) fluid level 52. ( ) 25, ~0.? ( ) ( ) .oprtg press 53, ~ ( ) 26,~) ( ) ( ) press gauges 27.~ ( ) ( ) sufficient vlvs 54. ( ) ( ) 28. (~ ( ) ( ) regulator bypass 55. (~, ( ) 29. ~ ( ) ( ) 4-way vlvs (actuators) 56. ~ ( ) 30. (~ ( ) ( ) blind handle cover 31. ( ) ( ) driller control panel 57. ( ) 32. ' ( ) (~)~ remote control panel 58. ( ) REMARKS: firewall nitrogen power source (back-up condition {leaks, hoses, etc} D. MUD SYSTEM pit level floats installed flow rate sensors mud gas separator degasser separator bypass gas sensor chke In corm trip.tank E. RIG FLOOR kelly cocks (upper,lOwer, IBOP) floor vlvs {dart vlv, ball vlv) kelly & floor vlv wrenches driller's console (flow monitor flow rate indicator, pit leve indicators, gauges) kill sheet up-to-date gas ~etection monitors (H-S &'methane) hydr chke panel chke manifold F. MISC EQUIPMENT flare/vent line 90 ° turns targeted (dwn strm choke Ins) reserve pit tankage personnel protective equip avai all drl site suprvs trained for procedures H2S probes rig housekeeping RECORDS: Date of last BOP inspection: Date of last BOP test: Resulting non-compliance:, HC~ -)''' .~'~J~,~'b (a~lo/../~C~"'b ~.,ct'~> -r'~_~l"~'~"~ Non-compliances not corrected & why: Date corrections will be completed: ~ BOP test & results properly entered on daily record? C.0013 (rev 07/08/91 ) STATE OF ALASKA ALASKA ~_AND GAS CONSERVATION C¢ ~'~ISSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing ~ Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic 4. Location of well at surface 648 ' N & 725' W of SE cr, Sec. 18, T10N, R15E, UM At top of productive interval 1142' N & 1284' W of SE cr, Sec. 18, T10N, R15E, UM At effective depth At total depth ~ ~ ~0~~~~0~$$~' 1410' N & 1499' W of SE cr, Sec. 18, T10N, R15E, U~~ n~ 12. Present well condition summary Total depth: 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit i 8. Well number 12-9 9. Permit number/approval number 80-93 10. APl number 50 - 029-20505 11. Field/Pool Prudhoe Bay Oil Pool measured 9782 feet true vertical 9527 feet Plugs(measured) 9114' MD; 8928' TVD feet Effective depth: measured 9114 feet true vertical 8928 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 300 sx Permafrost 80' 80' Surface 2538' 13-3/8" 2500 sx Fondu & 400 sx PF II 2609' 2609' Production 8757' 9-5/8" 500 sx Cl 'G' 8828' 8785' Liner 1261' 7" 325 sx Cl 'G' 9785' 9219' Perforation depth: measured 8926-8951 '; 9008-9020'; 9020-9048'; 9050-9070'; 9086-9106' [Isolated below bridge plug: 9122-9162'; 9184-9202'] true vertical 8760-8783'; 8833-8844'; 8844-8868'; 8870-8888'; 8903-8921' [Isolated below bridge plug: 8935-8971'; 8991-9007'] Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8426' MD; 4-1/2", 12.64t, N-80, PC tail @ 8526' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8441' MD; 5-1/2" Camco Bal-0 $SSV @ 2105' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Dailv Averaae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 555 3121 4194 -- 688 1545 1857 Tubing Pressure 291 284 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations .__ 16. Status of well classification as: Oil X_.~_ Gas ~ Suspended Sewice 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ....... Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 710 REK c: D. Warner, ATO-1479 SW JWP SUBMIT IN DUPLICATE DS 12-9 DESCRIPTION OF WORK COMPLETED BRIDGE PLUG W/SAND CAP INSTALLATION FOR WATER SHUT-OFF 4/1/91: MIRU CT & PT equipment. isolate open perforations at: RIH w/CT mounted inflatable Bridge Plug & set plug at 9118' MD (top), to 9122 - 9162' MD (Z4) Ref. Log: BHCS 5/1/81. 9184 - 9202' MD (Z4) 4/3/91 -' RIH & tagged top of bridge plug at 9118' MD, then made runs w/dump bailer to dump four feet of sand on top of bridge plug. POOH. Rigged down. Returned well to production & obtained a valid welltest. Alask~ Oil & G~s Cons. ARCO Alaska, Inc. '~~'' Prudhoe Bay ~---d~neering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager )ORIGINA October 19, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-9, Approval No. 9-693 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/RAC/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 12-9) W1-3 RECEIVED OCT 2 6 ] 89 Oil & ~as Co~s, Commisslot~ .,Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA '3,. AND GAS CONSERVATION C( ~'~vllSSlON 0 ~ REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging ...- Perforate .~ Pull tubing Alter casing Repair well ..... Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic 4. Location of well at surface 648' N & 725' WofSEcr, Sec.18, T10N, R15E, UM At top of productive interval 1142' N & 1284' WofSEcr, Sec. 18, T10N, R15E, UM At effective depth At total depth 1410' N & 1499' W of SE cr, Sec. 18, T10N, R15E, UM 6, Datum of elevation(DF or KB) 71' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 12-9 9. Permit number/approval number 80 - 93 / 9-693 10. APl number 50 - 029 - 20505 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2538' Production 8757' Liner 786' 9782 feet Plugs(measured) 9527 feet 9752 feet 9561 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 300 SX Permafrost 80' 80' 13-3/8" 2500 sx Fondu & 400 sx PF II 2609' 2609' 9-5/8" 500 sx Cl 'G' 9088' 8785' 7" 325 sx Cl 'G' cmt 9570' 9219' Perforation depth: measured 8926 - 8951'; 9008 - 9020'; 9020 - 9048'; 9050 - 9070'; 9086 - 9106'; 9122 - 9162'; 9184 - 9202' true vertical 8760 - 8783'; 8833 - 8844'; 8844 - 8868'; 8870 - 8888'; 8903 - 8921 '; 8935 - 8971 '; 8991 - 9007' Tubing (size, grade, and measured depth) 5-1/2",17#, L-80, PCT @ 8426' MD; 4-1/2",12.6#, N-80, PC Tail @ 8502' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 8421' MD; 5-1/2" Camco BaI-O SSSV @ 2105' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) SEE ATTACHED Treatment description including volumes used and final pressure OCT 2 6 AJaska 0il & (~as Cons. Coml~,i~.~r~ 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae Production or Iniection Data .Anchorage OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 2081 4221 3633 .... 288 2131 4018 4014 .... 320 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby_certify that the foregoing is true and correct to the best of my knowledge. Signed ~//,~'/~.,~f~/~/'/~ j T'~le Operations Engineering Manager Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE RICHARD A. CLAUSEN DS '~)9 Hydraulic Fracture Treatment Su, ~)ary Stimulation Sequence of Events Perf Sag 1. Perforate Sag River interval, 4 spf at 8926'-8951' MD (referenced to BHCS log dated 5/1/81) on 7/15/89. Changeout Gas lift Valves 1. MIRU slickline on 9/19/89 and changeout gas lift valves with dummy valves. Load annulus with diesel and seawater. Ivishak Isolation I , RIH on 9/21/89 with 3 3/8" inflatable bridge plug on coil tubing (CT). Set BP at 8993' MD. Released from BP. Opened circulating valve in CT string and pumped sand slurry to place 10' of fill on top of BP. Propped Frac 1. MIRU Halliburton on 9/23/89. Pressure annulus to 2500 psig. 2. Pump 100 bbl of 10#/1000 HPG slickwater at 20 bpm and 2600 psig to Sag River formation perfs 8926'-8951' MD (referenced to BHCS log dated 5/1/81). Shutdown. 3. Pump 40 bbl of slickwater at 20 bpm and 2700 psig. Shutdown. 4. Pump 250 bbl pad of HyBor 1400 at 20 bpm. Treating pressures ranged from 2740 to 3000 psig. 5. Pumped total of 188 bbl of 16/20 mesh proppant slurry with treating pressures ranging from 3000 to 2500 psig. Total of 39700 lb of proppant pumped. Proppant concentrations of 1-14 ppg. 6, Switch to slickwater flush and pumped 206 bbl before well screened out 5 bbl short, Maximum pressure observed was 6099 psig. Cleanout 1. MIRU slickline on 9/24/89 and pulled SSSV protector. Tag fill at 8786' MD, 2. MIRU slickline on 9/25/89 and changeout dummy valves for gas lift valves. 3. MIRU CTU on 9/27/89 and cleanout proppant, latched bridge plug and retrieved. ARCO Alaska, Inc. Prudhoe Bay ~' ineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 9, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-9, Permit No. 80-93 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/RAC/jp Attachment J. S. Dietz, BP J. Gruber, ATO-1478 PI(DS 12-9)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C 1. Type of"'Request: STATE OF ALASKA ALASK/~ IL AND GAS CONSERVATION C(' ~ISSION APPLICA (ION FOR SUNDRY AF ROVALS Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Variance ~ Perforate Other 5. Type of Well Development X Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 648' N & 725' W of SE cr, Sec. 18, T10N, R15E, UM At top of productive interval 1142' N & 1284' Wof SEcr, Sec. 18, T10N, R15E, UM At effective depth At total depth 1410' N & 1499' Wof SE cr, Sec. 18, T10N, R15E, UM 6. Datum of elevation(DF or KB) 71 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-9 9. Permit number 80-93 10. APl number 50 - 029-20505 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth' measured true vertical 9782 feet 9527 feet Plugs(measured) }~ i~ C '~ IV' E D Effective depth: measured 9752 feet ~,~tj~ i ii!.. t0f~Q true vertical 9561 feet Junk(measur'~,~,$k~ .0ii & Gas Cons, C01Ttr~iSSJ0~ Casing Length Size Cemented ~ ~ Ar[C'~3a~red depth True vertical depth Conductor 80" 20" 300 sx Permafrost 80' 80' Sudace 2538' 13-3/8" 2500 sx Fondu & 400 sx PF II 2609' 2609' Production 8757' 9-5/8" 500 sx Cl 'G' 8828' 8673' Liner 1261' 7" 400 sx Cl 'G' 9785' 9532' Perforation depth: measured 9008-9020'; 9020-9048'; 9050-9070'; 9086-9106'; 9122-9162'; 9184-9202'; 8926-8951' true vertical 8833-8844'; 8844'-8869'; 8871-8889'; 8903-8921'; 8935-8971'; 8991-9007'; 8760'-8782' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8426' MD; 4-1/2", 12.6~, N-80, PCT tail @ 8502' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8421' MD; 5-1/2" Camco Bal-0 SSSV nipple @ 2105' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation August 1989 16. If proposal was verbally approved Oil x~ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~:~'~'~ ~~ Tit,e Operations Engineering Manager Date 15. Status of well classification as: Gas Suspended I ^,,row, 73 C,o~)~ Co--Date FOR COMMI~.~ION U~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10--~O ~ Original Signed By David W. Johnston Approved by order of the Commissioner Form 10-403 Rev 06/15/88 136 R. A. Clausen, 263-4538 SUBMIT IN TRIPLICATE Drill Site 12-9 Sag River Formation Preliminary Hydraulic Fracture Treatment Procedure ARCO Alaska Inc. proposes the following hydraulic fracture procedure: 1. Remove gas lift valves and replace with dummy valves. Load 5 1/2" X 9 5/8" annulus with seawater. 2 Set inflatable bridge plug at 8993' MD. 3. MIRU fracturing service company 4. Pressure annulus to 3000 psig. 5. Pump propped fracture treatment for Sag River zone using gelled water and Carbolite proppant at 20 bpm. a. 100 bbl Formation breakdown and shutdown for ISIP. b. 250 bbl Pad c. 180 bbl Slurry at 2-14 PPG d. ,209 bbl Flush 6. RDMO fracturing service company. 7. MIRU slickline unit and tag fill. 8. Cleanout excess proppant to 8993' MD with CTU and retrieve bridge plug. 9. Place well on production. Run spinner log to determine post frac production split between the Ivishak and the Sag River intervals. 6 5 4 2 C0IL£D TUBINg UNIT BOP EOU l PMENi 1. 5000 PSi 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAHS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS $. 5000 PSI 4 1/6" BLIND RAHS 6. 5000 PSI 4 1/16" STUFFING BOX i i 2 BOP EOU ] PHENT 1. 5000 PSI 7" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WIRELINE RAtaS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF F'. 0. ~:.', 0 X i (!:, ({:,'..'~; 6,:..::, ANCHORAGE, AI_A~,'KA 995'i ,3 DAT,:.':: · , 7-i 9-89 REFERENCE· ARCO CASED HOLE FINALZ i'? 6-'''~'' " '"- ,~.,"-89 MI: INJECTIOi':! F'ROF'ILE SURVEY RUN '~, 5" '-~-':;' 7- ~ 5-89 "' ..... "' '" '"' UULL~'-~N,-'F Eh..F RUN ~ 5" i5'-28 7"-2-?'-89 F'F.'.ODiiCTION PROFILE .~:URVF'Y RUN 1 """&_~.:." ~-4-4 6-,:':-o',' F'F.'.ODUCTIFIN~ · F'F:riFiLE_ ,.,~:'UI:;.'.¥EY RUN ~, ~.,. 4'-5 6'-..'5':']'-89 F'IT,S' RLtN ~ , 5" 4-",25 7'- i -89 F' :I:'TS F:IJN ~., '5" 4-.SS 7'"2-8':? i::'PODLICTION PROFILE RUN J , '-5" , :.::., 6-28-89 !:'I;:ODUC]':[ON F'I;~OI::ILE SURVEY F:UN ~.. ":*.'" 4-.59 7"'i -89 F't~'.ODUC'I'ION PROFIi_E RUN i ,. 5" 5--i 6-29-89 LEAK .C, ETEC-[iON RUN i, ~ ~ 5-iS 6-28-89 LEAK DETECTION F:UN i, i "' ..,'~' -':" (),_ 6--2'8.-89 LEAK DF'¥EC'T'ION RUN ~ , 5" 8-i('3 '7--:;-89 GR/CCL RUN i , 5" f3-'".2~ 7-S-89 6R/CCL F'.UN ~ , 5" I-I_E.A,.,E £'IGN AND RE!TIJRN THE ATTACHED COPY AS' RECEIPT OF DATA, RECE!VED BY HAVE A NICE DAY! SALLY HOFFECKER AT0'-1529 '¥RAN$:~ 89S~4 CA:-iCO Ai'I_A;~;' CAMt.:O CAMCO C A M C 0 CA,MCO C A M C ti CAMCO CAHCU CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILEZ CHE '"' D &M EXTENSION: EXPLORATION EXXON MARATHON MOBIL I:,HILLIF, 5~ F'B ~ELL FILE~' BF'X ,*2TAI'E OF ALASKA TEXACO ARC(: AI_ASKA, INC, F',, 0 ,, BOX i 88,56(.~ ANCHORAGE., ALA~,"KA 995~ 8 DATE- 2-t 5-89 REFERENCE' ARCO F'RE$~URE DATA 2-2 ~-~t-89 BHP--F'LOWING GRADIENT CAMCO 2-i ;5 t2-i8-88 BHP--FI_OWING GRADIENT CAMCO 4-~8 ~2-~8-88 BHP--$TATIC GRADIENT OTIS 4-24 ~2-'2t-88 BHF'--$TATIC GRADIENT OTIS 7-.38 ~2--~7-88 BHP--FLOWING GRADIENT CAMCO 9-t 'i~-24-88 BHP--FLOWING GRADIENT CAMCO 9-i ~-tS-89 BHP--$TATIC GRADIENT CAMCO .. · -- "~...-,. · ~..,.... 0-4 i 2-3(-) 88 BIqF'--F'LOWING GRADIENT u~i'~..,u 9-4 i -i 5-89 BHP--5'TATIC GRADIEN-f OTI'$ 9--.3~ i 2-,'58-88 BHP--FLOWING GRADIENT CAMCO 9-32 i~-24-88 BHP--STATIC GRADIENT CAMCO tt-~5 t-~-89 BHF'--,S'TATIC GRADIENI" CAMCO '12-9 i -7-89 BHF'--FLOWiNG GRADIEN'I' CAMCO ~2-~ t2-i7-88 BHP--FI_OWING GRADIEN'I" CAMCD t.3-5 2-t -89 BHF'--STATIC GRADIENT OTIS' i4-.57 t-St-89 BHP--$'I'ATIC GRADIENT OTIS i4-.58 ~-St-89 BHF'--~'TATIC GRADIENT OTIS ~4-48 t-2S-89 BHP--$TATIC GRADIENT OTIS 't 8-i 3 t 2-S-88 BHF'--STATIC .GRADIENT CAMCO 'i 8-t 5 t 2-t -88 BHP--$'I"A'[IC GRADIENT CAMCO F'WDW2--i i-'t9-89 BHP--gTAI'IC GRADIENT CAMCO PLEA;~E SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY___ HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 TRAN$ ~8907~. APPROVED FEB 1 6 lS89, Alaska "" ,, Gas Cons. Commission Anohorago iI}~.~.TR I B U T I 0 N CENTRAL FIL£~.:- i'~. ¢ PHILLIP&' CHEVRON:~. .~ '¢'.~. PB WELL FILE~ D & M ~ R & D EXTENSION EXPLORATION ~ ~ ~PC EXXON $ ETATE OF ~LR~'K~ M~R~THON ~ ~ TEX~CO MOBIL , THE CORRECTED API$ FOR THIS BHP REPORT I~' 58-829-21588. ARCO AL.A~:KA, INC. F',,O. BOX 188368 ANCHORAGE, ALA,YI< A 995: i. _ DATE' t-23-89 REFERENCE' ARCO -' ~-'~ '-' UACED HOLE fINALS t-3 t-4-89 PRODUCTION PROFILE t-6 t-5-89 PRODUCTION PROFILE t -t4 t-9-89 F'IT$ t-2t t-7-89 PRODUCTION PROFILE t- .'D- ''~ t-8-89 PRODUCTION F'ROFI L.E 3-1 t2-29-88 F'RODUCTION PROFILE 3-t0 t2-29-88 INJECTION F'ROFILE 3-25 t2-3t-88 PRODUCTION PROFILE 5-3 t -5-89 PITS; 5-i2 t-2.-89 PRODUCTION F'ROFiLE 9-4 12-38-88 F'RODtJCTION PROFILE 9-3t i2-38-88 F'RODUCTION F'ROFILE ti-i5 i2-28-88 LEAK DETECTION ti-t5 t-t-89 LEAK DETECTION t2-9. i-7-'89 F'RODtJCTION F'ROFILE t2-2~ t-8-89 INJECTION PROFILE t3-6 1-6-89 INJECTION F'ROFILE t 3-3,'-3 ~ '-t t -89 PRODUCTION F'LEA£E SIGN AND RETURN THE ATTACHED COF'Y RUN i, 5" RUN i, 5' RUN t , 5' 'RtJN t, 5' RUN t ..5" RtJN ! , 5' RUN t, ._.-~" k.JN t , :~" RUN i, 5:" RtJN I, 5" RUN t, D" RUN I , 5' RUN i , .,_o" &..,.' .'.~. RUN t, 5" RUN 2, 5" RUN t , 5' RUN i, 5" RUN i, '::;.,' AS RECEIPT OF' DATA,, CAMCO CAMCO CAMCO CAMCO C A M C 0 C A M C 0 CAMCO C A H C 0 CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO ~'CI4 RECEIVED BY___ HAVE A NICE DAY! SALLY HOFFEC3, KER ATO-t 529 TRAN$ ~898~i- AF'PROVED _ __ DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXF'LORATION EXXON MARATHON MOBIL ~ PHILLIPS PB WEL. L FILES R & D '-.,.SAF'C ~ $'l'A'l'E OF ALASKA "".,.TEXACO ARC() AL. ASKA., ]:NC, F'.O. BOX i"::"::)S60 ANCFIORA(;E, ALASKA DATE' it-4-88 REFERENCE: '"'S-iT., ~S-i ? .S-i9 **'"~ 7--,: .'.~; ~ 7-7,4 "'" 9--5 "" 9-20 "-' 9-,3.5 8 .OA 9 ARCO CASED HOLE FINALS i0/i-2/88 FLUID DENSITY RUN '-2, i ~-..'--,-o,., CNL-GAMMA RUN i , _, · } 0-i9-88 VERTiLOG RUN i, 5 -,~/8~ TEMP SURVEY RUN i, 5' iO/t ..... " ~ c)-24.-88 COLLAR RUN ~, 5 "' f" ' ! " '=" i0-27-88 L;..,L-PLUt, SETTZNG RLIN i, i0-27-88 CET RUN i, 5 --,,..:,:.,-~8 UUI_L~aR/PEF,'F RtJN t 5" 9'-t6/~"?-88 COt. LAR/F'E'RF RUN t, 9-t 6-88 COLI_AI;,'/PFRF . RUN ~ , =.,' i,.~::_='_ooj..,.,,., F'ROI)UCTION F'ROF']:LE RUN i , 5" i 0-:5'-88 I NdE:CT I ON F'ROF I L.E RUN i, o-",~.-p.F~ IN,JECTION F'ROF'ILE RUN i , 5 9-26-88 PRODUCTION PROFILE RtJN 3, 5' i(')-i-88 PRODUCTION PROf:ILE RUN i, 5" i ~-23""88 CNL-GAMMA RUN i , 9-i 9-88 COL_LAR/PERF RUN i , i0-7-88 GAMMA-COI_LAR RUN t, 5' i(9-9'-88 GAMMA-CCL. RUN i , 5' i0-8-88 COLLAR RtJN t, 5' 9-.30-88 PRODUCTION PROFILE RUN t, 5' 9-~ 4'-88 COLLAR/F'ERF RUN ~ , 5 i0--2-88 PITS RUN 1, 5" i 0-2'?-88 COLI_AR/'k:'~RF ' RtJN I , 5" GN AN[) RETURN 'f'i~E-A'f'T~CHEI) COF'Y A,S' REC~:.iPT 01::' DATA,, RECEIVED BY HAVE A NICE DAY! ,'.-,I_L '¢ HOI- FE .,K ER ATO- i 529 TF,.AN~ ~8~J6~59 APPROVED DISTRIBUTION CENTRAL FILES UHEYRO~. EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'8 WELL FILES SAF'C STATE OF ALASKA TEXACO CAMCO AFl_AS ATLAS C A M C l.] A"I-L. AS SCH SCH g E A R G E A F.'. GEAR C A M C 0 CAMCO C A Pi C: (ii CAMCO CAMCO A'i'I_A:~ GEAR CAMCO CAMCO CAMCO CAMCO C A M C 0 A'[LAS THESE LOGS HAVE THE WRONG AP1 NOS T-SS 50-029-'2 i 809 i 5-i ¢,A ~"~_,-)-,:-')79--?05,'-~ '..... ~.__,.,, 1 -Oi ON THEM,, THE CORRECi NOS ARE' W~.~:~l~,ka, Inc. ) Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 13~ 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-9 Approval No. 8-188 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, DFS/JMH/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 P 1 (DS 12-9)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany AR3B--6132-C STATE OF ALASKA ALt, IA OIL AND GAS CONSERVATION COMMIL REPORT OF SUNDRY WELL OPERATIONS !1. Operations performed: Operation shutdown__ Stimulate._. Plugging._. Pedorate Pull tubing .__ Alter casing __ Name of Operator ARCO Alaska, Inc. , Address P. O. Box 100360, Anchorage, AK 99510 Location of well at sudace 648' N & 725' W of SE cr, Sec. 18, T10N, At top of productive interval 1142' N & 1284' W of SE cr, Sec. 18, TiON, At effective depth At total depth 1410' N & 1499' W of SE 12. P'~ese~t ~ell condition summary Total depth: measured true vertical Effective depth: measured true vertical cr, Sec. 18, T10N, Casing 9782 feet 9527 feet 9752 feet feet 9561 Length Size Repair well ~ Pull tubing ~ Other ~ 5, Type'of Well: 6. Da'turn elevation (DF or KB) Development ~ 71 ' R~B Exploratory ~ Stratigraphic .__ Service __ R15E, UM R15E, UM R15E, UM Plugs (measured) Junk (measured) 7. Uniter Property [tame ~ruanoe ~ay Unit 8. Well number 12-9 9, Permit number/approval number 8-188 i0. APl number 50-- 029-20505 11. Field/Pool Prudhoe Bay Oil Pool feet Cemented Measured depth · True vertical depth 13. Conductor Surface Production Liner Pedor~iondepth: measured 80' 20" 300 sx Permafrost 80' 2538' 13-3/8" 2500 sx Fondu & 2609' 400 sx PF II 8757' 9-5/8" 500 sx Cl 'G' 8828' 1261' 7" 400 sx Cl 'G' 8524-9785' 80' 2609' 8673' 8316-9532' 9008-9048'; 9050-9070'; 9086-9106'; truevertical 8833-8869'; 8871-8889'; 8903-8921'; ~bing(siz~gmde, andmeasumdde~h) 5½", 17#, L-80, PCT @ 8426' MD;4½", 12.6#, N-80, PCT an~SSSV (~pe ~%~~¢t~amco Bal-0 SSSV nipple aKer -SA~ pacKer e Stimulationorcementsqueezesummary Attached 9122,9162'; 9184-9202' 8935-8971'; 8991-9007' Intervals treated (measured) tail @ 8526' MD @ 2105' MD Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation ..... i5. Attachments Copies of Logs and Surveys run Daily Report of Well Operations ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 909 3O7O -- Tubing Pressure 505 891 1646 1027 -- 16. Status of well classification as: Oil __ Gas __ Suspended __ 430 Signed Form 10-404 Rev 06/15/88 WELLS3/44 J. M. Y~e Operations Heusser, 263-4266 Engineering Manager Date SUBMIT IN DUPLICATE Objective: 8/29/88 8/31/88 9/3/88 9/4/88 9/19/88 Drill Site 12-9 COILED TUBING CEMENT SQUEEZF~ WATER SHUT OFF To repair a cement channel and perform a water shut off on water producing intervals. RU slickline unit. Install surge tool and surge well. Perform coiled tubing acid acid wash across the following intervals: 9008 -9235' MD. The following treatment was pumped: 1) 72 bbls 12% HC1 dispersed with xylene 2) 72 bbls 12-3% HC1- HF 3) 65 bbls 12% HC1 RU coiled tubing. Fluid pack wellbore. Cement squeeze the following intervals: Reference: BHCS 5-1-81 9008 9050 9086 9122 9184 9215 -9048'MD -9070'MD -9106'MD' -9162'MD -9202'MD -9235'MD Contaminate cement. Wait on cement overnight. Reverse out contaminated cement. Reperforated the following intervals: Reference: BHCS 5/1/81 9008 - 9048' MD Reperf 1 spf 9050 - 9070' MD Reperf 4 spf 9086 - 9106' MD Reperf 4 spf 9122- 9162' MD Reperf 4 spf 9184 - 9202' MD Reperf 4 spf Returned the well to production and obtained new well test. JMH 10/6/88 I~'FFF'I.';~FNF:F'- ARt:ri f':.A.~'I:'I) t..Ifil !::' 4 ..0-9 7 47-.qR PRfiDllETTf'INI Inn ri:liN ~ . %" -l?--i ~ "7-47-~R PR'nI~IlRT'rF1N t fir I~tlt',J 't . .:.r,. P! FA.qF .&~TI';N ANT')'bFl'llR'i,J TNI-':'- ~.'ITTAF:I--IFD F:FIF'Y AX' I:;'I::'F:F'I'f.:'T FIF 1'4:F t"t F T V FD RY._ " ' t:'F'R~Y RI--bJNIFTT ~t~J~[(a 0il & Gas Cons. '1"!::.' ~ KI, ,,.q 4 9 4 f.~ , D. T .', ~ T R'. '[ 1~ ! 1T T f'i · '~ {E:I:'!' i~J'f' F-;,' A ! I:: T !. ~ ,.~ ... f't 1-41, ,,; :~: I'.-'. v~ T F N.? T f'IN E%F'I. fqR' AT T f'lt',J 4~ F :.',.; Y, i't N 41: H f!R 1'! . ARCO Alaska, Inc ~jl~ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 15, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-9 Permit No. 80-93 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TAB/jp At t a chment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 12-9)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ,~ Suspend ~ Operation Shutdown [] Re-enter suspended well ~ Alter casing L~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator .. ARCO .Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 648' N & 725' W of SE cr, Sec. 18, T10N, R15E, UM At top of productive interval 1142' N & 1284' W of SE cr, Sec. 18, T10N, R15E, UM At effective depth At total depth 1410' N & 1499' W of SE cr, Sec. 18, T10N, Ri5E, UM 5. Datum elevation (DF or KB) 71' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 12-9 8. Permit number 80-93 9. APl number , 50-- 029-20505 10. Pool feet Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 9782 feet true vertical 9527 feet Plugs (measured) Effective depth: measured 9752 feet Junk (measured) true vertical 9561 feet Casing Length Size Cemented Measured depth Conductor 80' 20" 300 sx 80' Surface 2609' 13-3/8" 2500 sx & 400 sx 2609' Production 8828' 9-5/8" 500 sx 8828' Liner 1261 ' 7" 400 sx 8524-9785' True Vertical depth 80' 2609' 8673' 8316-9532' Perforation depth: measured 9008-9048', 9050-9070', 9086-9106', 9122-9162', 9184-9202', 9215-9235' true vertical ECEIYED 8833-9036' ~i/::-¢ ' 6, Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) [;:~'~'::;a~9 Baker SAB Packer ~ 8441' ~; Camco RQY SSSV nipple ~ 2105' ~ 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation 4/1/88 14. proposal was verbally approved SuI%cquent Work t]epo~:ted.~on Name of approver Form >:o. J~: ~O~,_ Dat~q ...... ,/ ....... /__ Date approved 15. I hereby,certify that the foregoing is true and correct to the best of my knowledge Signed 2~:P~~2~ Title Operations Engineering Manager _ Commission Use Only Conditions of approval ORIGINAL SIGNED BY ! n. flNIE C: SMITH Approved by Notify commission so representative may witness [] Plug integrity .~ BOP Test ~ Location clearance Approved Copy Returned IApproval No. Commissioner Date ~//..(-/¢'~/' by order of the commission Date Form 10-403 Rev 12-1-85 WELLS2/68 T. A. Billingley, 265-6871 Submit in triplicate¢ DS 12-9 PRELIMINARY PROCEDURE CTU SQUEEZE FOR LOWER CHANNEL SHUTOFF 1. Acid wash current completion interval. 5 e 0 Run production spinner. Perform coiled tubing unit cement squeeze on existing perfs: 9008-9048' 9050-9070' 9086-9106' 9122-9162' 9184-9202' 9215-9235' Ref: BHCS 5/1/81 Contaminate cement in wellbore. 5. WOC 12 hours. Jet out contaminated cement. 6, After at least 2 weeks, reperforate as follows: 9008-9048' 9050-9070' 9086-9106' 9122-9162' 9184-9202' 9215-9225' Ref: BHCS 5/1/81 Do not reperforate 9225-9235. 7. Return well to production. TAB2/156 6 5 4 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS .3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) .~. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF H ! REL ! NE BOP EOU ! PMENT ARC[! ALASKA, INC F'. O. BOX ANCHORAGE, ALASKA DATE: t 2-24-8'7 REFERENCE: ARCO CA.~ED HOLE FINAl... 9-f8 t.,,.-7-87 LEAK DET./SP.T.N/TEMP RUN t, 2" & 5' i 2-t t 2-5-87 F'I.JMF'--IN/TEMF' R.!JN i, 5' t 2-6-87 F'I..IHF'-IN/TEHF' RIIN t, ~" i6-'l i2-44-.87 CAI...IF'ER RI. JN i, 5' HAVE A NICE DAY! PEGGY BENNETT ATO-t ..").,:. 9 F'L. EA,~E,~IGN AN]) REI'I..IRN THE ATTACHE]) COPY A,.~ RECEIFT OF DATA., E I.VEi) ^nehorago TRAN$ ~877~5 APPROVE!) DI£TRIBIJTION CAMCO CAMCO CAMCO CAMCO CENTRAl... FILES CHEVRON D & M EXTENSION EXF'LORATION EXXON MARATHON MOBIl... .,.'"PHI I...I... I F',~ F'B WELl... FII..E,~' R & D '"' SAF'C '"'.,,. ,.~TATE, ElF AI...ASK A ,,~ TEXACO ARCO Akaska, Inc P~O. Box ! Anchorage: 995 i ,::;, DATE' Ap,ri REFERENCE ' DS 7-7A I 2-27-86 D:'.7 7-o'" ! '-7-28-86 D.':: /-'7' i 2-29-86 DY 7--i ~' 1 2-3(':'-'-":.-.~,::, i 2-! 6-..'.-B5 ......... S-S"J -8,3. ,_,_,:-,,-,, V:,"L/,;::..:.-. i..,.,, ACBL/V?:,L/'.? T 5 F,' U iq i '"_::" Pun a 5-~ Run i f,. "-._.' :_.'. i'--i fDA · :.":, ::.: .:.?A I.:A $ch C 8 ~,i C 0 '-'-ce i ved '"'..s :.,-' HAYE A,-<~"I~'~,...,_ DAY: TRAN:'--: ¢862-_.-.. .... ARCO Alaska, Inc. ~ Prudhoe Bay E )eering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 13, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 12-3 Permit No. 79-41 DS 12-4A Permit No. 81-187 DS 12-5 Permit No. 79-55 DS 12-7A ~ Permit No. 81-175 DS 12-9 Permit No. 80-93 DS 12-10 Permit No. 81-53 DS 12-14 Permit No. 81-138 DS 12-16 Permit No. 83-11 DS 12-17 Permit No. 83-4 DS 12-21 Permit No. 84-48 DS 12-28 Permit No. 84-31 Enclosed are the "Subsequent" Sundry Notices and Completion reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TAB/vh RECEIVED JAN 2 4 Alaska Oil & 6as Cons. Commiss/ol~ Anchorage Enclosure CC: SOHIO Alaska Petroleum Co. File PI(DS 12-3)W1'3 Pi(DS 12-4A) Wl-3 Pi(DS 12-5) Wl-3 PI(DS 12-7A) Wl-3 PI(DS 12-9) Wl-3 PI(DS 12-10) Wl-3 P1 (DS 12-14)W1-3 Pi(DS 12-16)W1-3 PI(DS 12;17)W1-3 Pl (DS 12-21)W1-3 Pl (DS 12-28)Wl-3 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany -. ~ STATE OF ALASKA ALASKA C.-~ AND GAS CONSERVATION CO, ~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc.r ' 80-93 3. Address 8. APl Number Post Office Box 100360, Anchorage, AK 99510 ' 50- ' 029-20505 4. Location of well at surface 9. Unit or Lease Name 648'N & 725'W of SE cr Sec.18, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1142'N & 1284'W of SE Sec.18, T10N, R15E, UM DS 12-9 At Total Depth 11. Field and Pool 1410'N & 1499'W of SE Sec.18~ T10N~ R15E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 71' RKBJ ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of.Completions 3/28/81 5/2/81 5/8/81I N/A feet MSLI '1 ,7. Total Depth (MD+TVD) ,B. PIugBackDepth(MD+TVD) 19. OirectionalSurvey I 20. Depth where SSSV set i 21. Thickness of Permafrost 9782'MD,9527'TVD 9752,MD,9561,TVD YES [~ NO [] 2105 feet MD ~900' (approg,) 22. Type Electric or Other Logs Run DIL/SP/GR. ILD/ILM/SFL/BHCS/GR. FDC/CNL/GR/CAL/CCL 23. CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED .. 13-M/R" 72~A T.-RO R111~F..qt~ ?k~qE 17½" 9_500 _~× Fond- ~ 400 sX P.~rm..afro. st II 9-5/8. aT~ T.-RO/ R,,r~m~¢ R878' 12k" 500 "~ ~.~°"~ "G" S00-95 7" 29# L-80 852~' 97R~' R~" ~.n~ ~ C.i~ "n- 24. Perforations open t° ProdUction (MD+TVD of ToP and MOt'tom ~ind 25. - : ~ ' ' -T'-0~ING'RECORD ' ' interval, size and number) SIZE DEPTH SET (MD) PACKER SET' (MD) 9050-9070'MD 8799-8817'SS @ 8 spf 5%" 8526' 81,/,1' 9086-9106'MD 8832-8850'SS @ 8 spf 9122-9162'MI) 8864-8900'SS @ 8 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED '9008-9048'MD 8762-8798'SS @ 4 spf N/A '9184-9202'MD 8919-8936'SS @ 2 spf '9215-9235'MD 8947-8965'SS @ 2 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 1/23/82 Flowi~ Date of Test Hours Tested PRODUCTION FOR OI L-BBL GA$-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4/17/82 12.4 TEST PERIOD ~ 2578 1 ~ 74 5': Flow Tubing Casing Pressure CALCULATED OI L-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 822 _. 24-HOUR RATE I1~ 4299 3035 lb'~ 26_1 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ~/A , Ah! 2 4 1986 Alaska Oil & 6as Cons.Oomm.~,~,, Anchorage, Form 10'407 ~ '2~,D---~,fT/ Submit in duplicate Rev. 7-1-~0 CONTINUED ON REVERSE SIDE _ . 29. ' 30. ~r..-:(~!.(.'~(~C r,? ,*' F.: i( r' ~.: ¢ -.. ,.,~ ~z '- ~', ,.:" ~ :''r''~ ~:;~ ~ Include ,nterval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . , Top Sadlerochit 9004, 8829' N/A Base Sadlerochit 9284' 9080' · · , · · 31. L~ST OF ATTACHMENTS None · 32. ~ hereb~~ certify that the foregoing is true and correct to the best of my know~ed§e Signed_ ,~~/~.~_~~ Title Or~or.En~t'.l~¢r. Date.. 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 inte~r, val (multiple completion),, so state in item 16)"and in item 24 show the eroducing 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 -') STATE OF ALASKA .... ) ALASKA OiLAND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL I-1 COMPLETED WE L~:~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. LocationofWell Surface: 648' N 725' W' of SE cr Sec. 18, T10N, R15E, UM At Top Producing Interval: 1142' N & 1284' W of SE cr Sec. 18, T10N, R15E, UM At Total Depth: 1410' N & 1499' W of SE cr Sec. 18, T10N, R15E, UM 5. Elevationinfeet(indicateKB, DF, etc.)71, RKB I 6. LeaseDesignationandSeriaINO.ADA 28330 12. 7. Permit No. 80-93 8. APl Number 50- 029-20505 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 12-9 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations i]{JX Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operations 12-15-85. RU perforating unit and pressure test surface equipment. RIH w/gun #1. Shot 9215-9235 2 spf. 12-16-85. RIH w/gun 92. Shot 9184-9202 2 spf. RIH w/gun 93. Shot 9028-9048 4 spf. RIH w/gun 94. Shot 9008-9028 4 spf. Flowed well to clean up. RD 12-16-85. Ran SSSV 12-28-85. Ref: BHCS 5-1-81 14. I hereby,certify that the foregoing is true and correct to the best of my knowledge. a~/~~~~[/' ~'~ ~/;' ~'//i~"~ Operations Engineering Mgr. Signed _ .. _.... _ .... ~ Title The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 --~'/~ Rev. 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay I.]neering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 6, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 12-3 DS 12-4A DS 12-5 DS 12-7A DS 12-9 DS 12-10 DS 12-11 DS 12-14 DS 12-16 DS 12-17 DS 12-21 DS 12-28 Permit No. 79-41 Permit No. 81-187 Permit No. 79-55 Permit No. 81-175 Permit No. 80-93 Permit No. 81-53 Permit No. 81-73 Permit No. 81-138 Permit No. 83-11 Permit No. 83-4 Permit No. 84-48 Permit No. 84-31 Attached are the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS:JEB:vh Attachment cc: SOHIO Alaska Petroleum Co. File PI(DS 12-3)Wl-3 PI(DS 12-4A)Wl-3 Pi(DS 12-5)Wl-3 PI(DS 12-7A)Wl-3 Pi(DS 12-9)Wl-3 Pi(DS 12-10)Wl-3 PI(DS 12-11)W1-3 P1 (DS 12-14)Wl-3 P1 (DS 12-16)Wl-3 P1 (DS 12-17)Wl-3 Pi(DS 12-21)W1-3 P1 (DS 12-28)W1-3 ARCO Alaska, Inc. is a Subsidiary o! AtlanticRIchfleldCompany STATE Of ALASKA '~) ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L~::~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-93 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. LocationofWell Surface: 648' N 725' W' of SE cr Sec. 18, T10N, R15E, UM At Top Producing Interval: 1142' N & 1284' W of SE cr Sec. 18, T10N, R15E, UM At Total Depth: 1410' N & 1499' W of SE cr Sec. 18, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 71' RKB 6. Lease Designation and Serial No. ADL 28330 8. APl Number 50-- 029-20505 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 12-9 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [~X Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate well 12-9 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator tested to 1.5 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 9008-9048' MD 9184-9202' MD 9215,9235' MD Ref: BHCS 5-1-81 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~6~7~j/~,~ Operations Engineering Mgr. Signed . . _ Title The space below for Commission use Date Conditions of Approval, if any: Approved by. ORIG!HAL SIGN[D BY H~IRY W. i~UGLER Approved Co~y By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Ala.s'k~, Inc· DA'T'Iii]' Oc:1:ol::,er 4, t984. R IE F:' E R IE N C:liE · A R C 0 I::' r e ;~:.s' u r e D a t.. a R e F' o r !' S 't' a .I. i c .;-.,' u r v e v · · ·o .. D,.$, i4 ....i2.-?' 9 .... t3....84 ;};:1:at:it Survey S't'at:ic Survey D~'/~ i6 ....t6 f 9 ....i2..--84 · ~i"' i. eaz,'e ...:7 i g'n a'nd ret u'rn $ t: e r.:' R a i: e i) a !: a 1:he at.'t:ac:hecl (::or.:,y a2' 'rec:eip'l.' R e c e i v e d B'..,' ............. ~,~:. .... :~_ ...... HAVE: A NICE DAY! ..... ' · KeL i.y McF'ar Land A!aska D~I ,;:, ~:~ Cons. Commissi0rt ATO-i '1291::' Anchorsge · · TR~i'i$ ,. ~-~'78' C a m c:: o C a rll ('- o Ca mc o DA C ,.':i ft'l c c) 6 0 t]a hie 0 Ca mc o C a hi C: 0 Ca htC C) C;O o f d a t: a, D I S T R I B U T I 0 N Chert on D &M Expi. or~+ion ~ · ...er v ices Exte'n.sion ExpLoration "E x' Getty M a r a 'f h o n Lt fi Le~ ARCO Alaska, In,.. "~~ Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 July 13, 1984 Reference: ARCO Pressure Data D.S. 7-19: 6-15-84 PBU 6-15-84 Common D.S. 12-8B/6-18-84 Static D.S. 12-9 ~/6-18-84 Static D.S. 13-4 .... 6-17-84 Static D.S. 13-12, 6-17-84 Static D.S. 13-13 '-/ 5-31-84 PBU ~, 5-31-84 Common D.S. 13-14~ 6-20-84 Static D.S. 13-27 ..... 6-2-84 PBU 6-4-84 Common D.S. 13-28,~ ~6-3-84 PBU 6-4-84 Common D.S. 13-29 ' 6-1-84 PBU 6-2-84 Common D.S. 14-12 6-16-84 Static D.S. 18-2 .... "~' 4-25-84 PBU ~/' 4-25-84 Common Data Base Report Survey Survey Survey Survey Data Base Report Gradient Data Base Report Data Base Report Data Base Report Data Base Report Otis GO GO GO GO GO GO Camco GO GO GO GO Camco ~n and return the attached copy as receipt of data. Friday the 13th is back again, have a safe one! Kelly McFarland ATO-1429F Trans. f~266 DISTRIBUTION Chevron D & M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mobil Mobil Phillips Prudhoe Bay Well Files R&D Carolyn Smith Sohio SCace-of Alaska ALASKA OIL AND ~AS CONSERVATION'COMMISsION / 3OOl PORCUPINE DRIVE / A~NCHORAGE,ALASI<A 9950'~3192 June 5, 1984 TELEPHONE(907) 279--1433 Ms. Kelly McFarland ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Transmittal #196. Transmitted via Mail are the following: 0uantity Description of Item DS 1-9, 05/10/84, CPL/TDT-M listing DS 1-10, 05/8/84, CPL/TDT-M listing DS 12-9, 04/22/84, CPL/TDT-M listing DS 12-16, 04/22/84, CPL/TDT-M listing DS 13-5, 04/21/84, CPL/TDT-M listing. Kelly, These listings that accompanied the CPL's sent with the captioned transmittal are neither required nor of value and a accordingly returned herewith. William Van Alen Please acknowledge receipt by signing and returning one copy of DATED: Yours ~ve.r~ tru~y,~_ Alaska Oil and Gas Conservation Commission ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 24, 1984 ~~ Refe..rencll- Arco Ca~~Finals~~ ..-~.s. ~-~' . ~-~-~ /c~,/~-~\ ~ ~- sc~ ~ ~ 5-10-84 / C~T~list~ng ~ 5" Sch D.S. 1-10~" 5-8-84 / CPL/TDT-M ~/~sting ~ 5" Sch /D'S. 12-9~ 4-22-84 / TDT ~. ~.. . ~ Run 2 '~'~' 5-9-84 / CPL/TDT-M ~listinq % 5" Cch D.S.' 12-16~'5-11-84/ CP~/TDT-M w~listin~ ~ 5" Sch D.S. 12-~7,~ 4-22-841 TDT ; / Run 1 D.S. 13-5 / 4-21-84~ TDT_ ~_ _ . / Run 2 ~. ~-s-s~ ~c~/~o~-. ~/~st~n~ / ~" scn i~n and return the attached copy as receipt of data. 5" Sch 5" Cch 5" Sch HAVE A NICE MEMORIAL DAY WEEKEND! Kelly McFar!and ATO-1429F Trans. % 196 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon ~etty ~ Mara'thon · '-~ ~-, ' o. i.~ "SS/on Mob i 1 Mobil E & P Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 16, 1984 Reference: ARCO Magnetic Tapes w/listings D.,S. 1-9 _(~___'" 4-20-84 TDT-~ #69158 Sch ~' ' ~t~on Answer : f~69161 Run' 2 Sch /D,S., 12-9~. 4~22-84 TDT/5 .passes of TDT-M #69160 Run 2 Sch #69163 Run 2 Sch 4.s.. 12-1~fi' 4-22-84 TDT/5oasses af TDT-M #69162 Run 2 Sch ~..~~. ~ .; 4 _ OH ~281~~ ..... GO I ~.S.:~)=~ [ _]5')~ . '3 Ramses CN~MSN w/CN Average #1964 DA '/, ~D. S~.~-4~=~ 84~~p~'~ ~ S-' C~:W/CN--~Pa--rage-{} t 96 8~D~ ~ ~~~~'~~- m~'era ~e-- ~ 1-9-6-~A D. S: o=~''' 5-11-8a CH cN~2~i99~ ..... ~ Please si~n and re~urn ~he ~hed ~opy ~s receipt of data. Kelly McFarland ATO-1429F Trans. #173 Chevron D&M Have a Nice Day! DISTRIBUTION "4ias~ra Oil · Mob i 1 . Mob il E & P ':mCh°r~e Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Phillips Prudhoe Bay Well Files R & D /~ '~ 6\~ Carolyn Smith ~o,~5 Sohio State of Alaska C~.O ~ b~x'~ ARCO Alaska, Inc. Post Office P %360 Anchorage,,~(a 99510 Telephone 907 277 5637 January 14, 1983 Reference: Arco Magnetic Tapes · D.S. 13-98 1-1-83 D.S. 12-9 7-30-82 Open Hole Tape 9 66242 Run 1 Sch 5 pass DNLL w/Sigma Average 9 1392 DA Pl~~ease sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 044 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBILE GETTY D&M DALLAS .. I? E £ E V E D Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldComl~any ARCO Alaska, Inc. ! Post Offic~ )x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 11, 1983 Reference: Arco Cased Hole Finals D.S. 1-18~ 11-13/14-82 D.S. 13-6~ 12-4-82 D.S. 9-4/' 12-8-82 D.S. 13-13 ~'~11-12-82 D.S. 11-3~- 12-16-82 D.S. 11-6/ 11-6-82 °D.S. 12-9% 12-2-82 D.S. 13-6-- 12-3-82 D.S. 14-15'~12-21-82 D.S. 14-2i~/ 11-7-82 D.S. 15-11f12-30-82 D.S. 15-15~/11-28-82 Spinner 5" Diff Temp Log Run 1 5" CH CNL Run 6 5" Collar Log Run 4 5" Spinner 5" CCL & Perf Log -Run 1-3 CNL/GR/CCL (CH) Run 3 5" CBL/VD Run 1 5" Spinner 5" CCL & Perf Log Run 1-4 Spinner 5" CFS/Spinner Run 1 5" camco GO Sch GO C amc o 5" GO Sch Sch Camco 2" & 5"( Camco GO · ase sign and return the attached copy as receipt of data. Kelly McFarland AFA-4 03 Trans. 9 035 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldComl3anv EXXON. MOBILE GETTY D&M STATE OF ALASKA DALLAS ARCO Alaska, Inc.' Post Office E~"'~360 ' Anchorage,. ~ka 99510 Telephone 907 277 5637 November 6, 1982 Reference' ARCO Cased Hole Finals D.S. 1-21 10-18-82 CBL/VD Run D.S. 12-9. 10-8-82 GST Inelastic & Stations Run 10-8-82 GST Capture & Activation Run 9-23-82 TDT-M Run 10-10-82 Gradi omanometer/GR/CCL Run D.S. 13-6 10-10-82 Cement Evaluation Log Run D.S. 14-12 10-10-82 Spinner Run D.S. 14-16 10-15-82 Spinner Run 11 1! 5" 5" 5" 11 5" 5" SCH SCH SCH SCH SCH SCH Gearhar Gearhar Please sign and return the attached copy as receipt of data. · Becky Benedi ct AFA- 403 Trans. #601 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA~.- ~.. '" DALLAS NOV /'d:~'~a O:,l e, C:'~ ARCO AlaSka, inc. Post Office Box 360 Anchorage..~ '~ka 99510 Telephone 90, 2'77 5637 October 4, 1982 Reference: Arco Magnetic tapes D.S. 6-22 9-27-82 D.S. 12~9 9-23-82 9~-23-g%- ...... OH tape and list (ACC 65635) Run 1 Sch TDT LIS and list (ACC 65624) Run 1 Sch Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 513 " DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON · CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA DALLAS ARCO Alaska, Inc. Post Office B'~360 Anchorage, , ,,Ika 99510 Telephone 907 277 5637 October 4, 1982 Reference: Arco Cased Hole Final D.S. 12-9 9-23-82 CPL/TDT-M w/listing Sch e sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 522 NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ~-r,~ ~ ,'il', ~... ;..~ GEOLOGY D~S ARCO Alaska, Inc. Post Office Box_360 Anchorage. A )a 99510 Telephone 907 ~77 5637 September 29, 1982 Reference: Arco Cased Hole Finals D.S. 6-4 -?- Epilog - C/O log D.S. 12-9 7-30-82 Epilog - C/O log D.S. 12-9 7-30-82 Epilog - Overlay ..~.._ ~-.-:-=: -- , TDT-M. ~ D.S. 14-16 7-24-82 Epilog - C/O log Run 1 5" DA Run 1 5" DA Run 1 5" DA _----Ra~ 3c~ Run 1 5" DA ~~Pl~ase sign and return the attached copy as receipt of data. Kelly McFarland .AFA-403 Trans. # 506 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA CHEVRON ARCO Alaska, Inc. Post Office Box 360 Anchorage. ~"~ka 99510 Telel3hone 9C ~/'7 5637 September 15, 1982' Reference: Arco Magnetic Tape D.S. 12-9 7-29-82 C/O (6 passes) Magnetic tape ECC 1392 DA Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 ,- Transo # 476 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY · PHILLIPS D&M SOHIO GEOLOGY MARATHON S.TATI[ OF ~SKA CHEVRON DALLAS Post Office Box 360 Anchorage. ,~'.q~ka 99510 Telephone c_, ~1~77 5637 September 15, 1982 Reference: Arco Cased Hole Finals D.S. 2'23 8-19-82 D.S. 12-8B 8-21-82 ~ 7-29-82 D.S. 12-9 7-30-82 ACBL/VDL / Signature/GR PLS/CCL-Spinner Carbon/Oxygen DDT/NLL/GR Run 1 5" Run 1 5" Run 1 5" Run 1 5" .DA DA DA DA e sign and return the attached copy as receipt of data, Kelly McFarland AFA-403 Trans. # 474 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY OF ALaSr · ,. ,, ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 September 7, 1982 Reference: Arco Pressure Data D.S. 12-9 7-6-82 Pressure Buildup Survey Otis gn and return the attached copy as receipt of data. Kelly McFarland AFA-403 ' Trans. # 443 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO. MARATHON CHEVRON D&M Alaska Oil &~a~ Cons. Commission anchorage GEOLOGY DALLAS ARCO Alaska, Inc. ' Post Office E 360 Anchorage. Alask~ 99510 August 26, 1982 Reference: Arco Cased Hole Finals DoS. 12-9 7-30-82 Fluid Density D.So 13-33 8-3-82 ~,. ACBL/VDL/Signature/GR D.So West Bay St. #1. ~!,,/ 7-31-82 Diff Temp Log Run 1 5" Run 1 5" Run 1 5" : DA¸ Please sign and return the attached copy as receipt of data. Kelly McFariand Trans~ 420 DISTRIBUTION NORTH GEOLOGY. R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ARCO Alaska, Inc. Post Office R~x 360 Anchorage, )ska' 99510 Telephone 907 277 5637 July 23, 1982 Reference: ARCO CASED HOLE FINAL LOGS ~ D.S.12-9 7/6/82 D.S,13-21 5/31/82 D.Sol5-11 6/28/82 DOS.15-14 6/27/82 D.S.i-13 7/5/82 D.S.1-9 6/3/82 Spinner Run 1 5" CNL Run 1 5" Collar & Perf Log Run 1 5" Collar & Perf Log Run 1 5" Collar & Perf Log Run 1 5" EPL Run 1 5" Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 301 DI STRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON CHEVRON I ECEIVED JUL 2 8 ' 982 Alaska Oil & ~a$ Cons. Commission ,nch0ra~e · - .k ARCO Alaska, Inc. Post Office~~'- ~x 360 ' Anchorage", aska 99 ~?~'0 Telephone 907 277 July 13, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: Do S. 4-14 D.S. 11-1 D~S. 11-2 D~S. 11-5 D.S. 12-7A D.S. 12-8B ~D.~ S, 12-9 D.S. 12-13 D.S. 14-5 D.S. 14-19 D.S. 14-20 Permit No. 78-36 Permit No. 81-123 Permit No. 81-128 Permit No. 81-155 Permit No. 81-175 Permit No. 81-167 Permit No. 80-93 Permit N°. 81-87 Permit No. 78-64 Permit No. 81-45 Permit No. 81-70 Enclosed are Completion Reports for work done on the above-mentioned wells. Very truly yours, Regional Engineer DF S: TKKW Enclosures Distribution: Sohio Petroleum Co. ARCO Alaska. Inc. ~s a Subsidiary of AllanlicRichlieldComj:an¥ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ... 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc. 80-93 3. Address 8. 'AMI Number P.O. Box 360 AnchoraKe, Alaska 99510 s0-029-20505 _ 4. Location of well at surface 9. Unit or Lease Name 648'N & 725'W of SE cr Sec 18, T10N, R15E, UM .. Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1142'N & 1284'W of SE cr Sec 18, T10N, R15E, UM D.S. 12-9 At Total Depth 11. Field and Pool 1410'N & 1499'W of SE cr Sec 18, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool 71' RKBI ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 3/28/81 5/2/81 5/8/81I ------ feet MSL )782'MD 9527'TVD 9752'MD 9561'TVD YES []. NO [] 2105 feetMD 1900' (approx) __ 22. Type Electric or Other Logs Run DIL/SP/OR, ILD/ILM/SFL/BHCS/GR, FDC/CNL/OR/CAL/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf 80' 32" 300ex Permafrost 13-3/8" 72# L-80 Surf 2609' 17~" 2500ex Fondu & 400ex Permafrost II 9'5/8" 47# L-80 & Surf 8828' 12¼" 500sx Class G S00-95 7" 29# L-80 8524' 9785' 8½" 400ex Class G 24. Perforations open to PrOduction (MD+TVD of Top and Bottom and 25. ' ' '-~U~i"NG R'ECORD' interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5½" 8526 ' 8441' 8 shots per foot 9050' - 9070'MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9086' - 9106'ZD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9122' - 9162 'MD 8869 ' TVD - 8971 ' TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 1-23-82 Flowing Date c~f Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 4-17-82 12.4 TESTPERIOD ~ 2578 1238 74 54I 706 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 822 NA 24-HOUR RATE ~ 4299 3035 143 26.1 28. CUR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. I ECEIVED J U L 1 9 i 82 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9004' 8829' Oil/Water Contac1 9284' 9080' -- 31. /~$T OF A]-TACHMENT$ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~_ ~/~.~4d~_~..- Tit,eRejional Engineer Date 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 fcr. this well should show the details of any multiple stage cement~ lng 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 10-40'7 ARCO Alaska, Inc, Post Office ~ 360 Anchorage, Alaska 99510 July 13, 1982 Mr. C.V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. ~hatterton: RE: D.S. 4-14 D.S. 12-7A D.S. 12-8B ~ D.S. 12~9'I' · D.S. 12-13" D.S. 14-5 D.S. 14-19 D.S. 14-20 Permit NO. 78-36 Permit No. 81-175 Permit No. 81-167 Permit No. 80-93 Permit No. 81-87 Permit No. 78-64 Permit No. 81-45 Permit No. 81-70 ..Enclosed are Subsequent Sundry Notices detailing the work done on the.above-mentio~ed wells. Very truly yours, D. F. Scheve Regional Engineer DF S: TKKW Enclosures Distribution: Sohio Petroleum Co. ARCO Alaska. Inc ~.,-. ~ St bSid~R~y Of AllanticRichfiel~lCo,~p~n¥ SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 360 Anchorage, AK 99510' 4. Location of Well 648'N & 725'W of SE er Sec 18, T10N, R15E, UM (surface) 1142'N & 1284'W of SE cr Sec 18, T10N, R15E, UM (tOp producing) 1410'N & 1499'W of SE cr Sec 18, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 71' RKB 12. ADL 28330 I 6. Lease Designation and Serial No. 7. Permit No. 80-93 8. APl Number 50-- 029-20505 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D. S. 12-9 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimu late [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operations on 1/2/82. Pressure tested tree and wireline per- forating equipment. Perforated 9122' - 9162'MD with four shots per foot. Well cleaned up to a tank. Suspended perforating to monitor well performance. The well was left shut-in until some facility tie-in problems could be corrected. Ran static pressure survey. Ran, set and tested SSSV. Resumed perforating activities on' 4/3/82. Pulled SSSV. Pressure tested tree and wireline perforating equipment. Reperforated 9122' - 9162'MD with additional four shots per foot and perforated'9050' - 9070'MD and 9086' - 9106'MD with eight shots per foot (to.tal of eight shots per foot across all intervals). Well was flowed to the test spearator during reperforating. Ran, set and tested SSSV. Returned well to Production Department on 4/5/82. JUL 0il & Gas Cons. C0mmissi0~ ,~,.~../orag,.. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate %TATE ()F ^LASE^ Anchorage, Alaska 99501 279-14'33 QUANTITY RE. which was transmitted via is hereby acknowledged ., ,. DESCRI PT ION Ck,'j~ S ' Copy sent YES ~ to sender NO ARCO Alaska, Inc. :ii" Post ©fficF..'-~---'o, x 260 · Anchorag[ ~aska 99510 Tel.e, phone ~07 277 .?~37 Reference: ARCO CASED HOLE FINALS D.So7-14 ~'12/31/81 Casing Collar Log Run 1 D.S.7-14 -.~1/1/82 Collar Log-Tubing Cutter/Depth Determ D.S.7-14 12/19/81 Collar Log for Tubing Puncher Run'l D.S.12-7A~'l/2/82 CNL Run 1 D.S.12-7A~'i/2/82' C~L Tie-In Log For Gyro Run 1 D.S.12-7A~'%/2/82 CmL Run 1 ~D-S.l~2-9L/1/3/82 CCL & Perf Record Run 1~ D.S.12-11U~l/1/82 Collar Locator Run 1 D.S.12-14z 1/21/82 CCL & Perf Record Run 1 D.S.12-14'"' 1/16/82 CCL & Perf Record Run 1 D.So12-14'~ 1/13/82 CCL & Perf Record Run 1 D.S.12-14' 1/12/82 CBL/VD Run 1 D.S.12-1~ 1/19/82 CBL/VD Run 2 D.S.13-3~ 1/9/82 CCL Run 1 D.S.i3-3' 1/8/82 CCL Run 1 D.S.13-3'~ 1/6/82 Pipe Analysis Log Run 1 D.S.13-3~ 1/6/82 Electromagnetic Thickness Tool Run 1 D.S.15-14 12/20/81 CBL/VD Run ! ase sign and return the attached~copy~ as receipt ~of data. 1! · Run 1 5" 2~ 5~, 5~ ~ 2"/5" 2~ 5" 5~' 5" 5~ 5~' 5~ 5~ 5'~ 5~ 5~ 1! Mary F. Kellis North Engineering Transmittal # 995 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS DCM SOHIO GEOLOGY MA~\THON STATE OF ALASKA CHEVRON ARCO Alaska, Inc. ~' Post Office Br.,,, 360 October 22, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: ~<~:~:!~!!iS:~::'::,:'I2'-.9 Permit No. 80-93 D.S. 12-10 Permit No. 81-53 D.S. 12-11 Permit No. 81-73 D.S. 12-12 Permit No. 81-83 Enclosed are our sundry Notices detailing the work to be done on the above mentioned wells, Very truly, yours, ~,/' A. Rochon District Operations Engineer JAR/TKKW/kam Enclosures RECEIVED OCT 2 .q i::. Alaska Oil & 6as Cons. Commissiori Anchorage STATE OF ALASKA ALASKA IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-93 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50-029-20505 4. Location of Well 648'N & 725'W of SE cr. Sec. 18, T10N, R15E, UM - Surface 1142'N & 1284'W of SE ct. Sec. 18, T10N, R15E, UM - Top of Interval 1410'N & 1499'W of SE cr. Sec. 18", T10N, R15E, UM - TD 5. Elevation in feet (indicate KB, DF, etc.) 71' RKB 6. Lease Designation and Serial No. ADZ. 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 12-9 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate E~c Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO proposes to perforate selected intervals within the Sadlerochit for production. The perforated intervals will be reported on a subsequent report. A 5000 PSI WP BOP/ lubricator, tested to working pressure, will be used on all wireline work. The downhole safety valve will be installed and tested upon conclusion of the job. The well will be flowed to the Flow Station for clean up. RECEIVED OCT 2 8 198] Naska Oil & Gas Cons. commission Anchorage 14' ' hereby ce~ t~.°r_eg°Ztrue and c°rrect t° the best °f mY kn°wledge. Signed /' ~"//'~~ Title District Operations Engineer Conditions of Approval, if any: Approved Copy Refined ORIGINAL SIGNED /. ~/;~/~/ BY LONHIE C. SMITH By o:~-_~o~ Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARC'O O!!' and Ga.~"-~ompany derry A. Rochon District Operations Engineer July 21, 1981 ~,~ ~7.~ 2~.e__r ~_n ~_. ARC Q M_ ~Lp. e s & Listings !~'i!'~~~.S.'12-2 ~~'/5/81 ~-T~ape #61764 dj.~ .3.6 ~/~. 6/26/81 Tape #61763 /D.S.i-i~ 7/7/81 TaPe #62003 ~;..~~ 6/11/81 · Tape #61640 Schlumberger se sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #446 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO 0,I and Gas Company ,$ a O,v,$~on ol AllanhcR,chheldCompany EXXON MOB I L GETTY PHILLIPS SOHIO CHEVRON ARCO Oil and Gas ........ 'mpang Jerry A, Rochon District Operations Engineer July 16, 1981 Reference: Arco Magnetic Tapes & Lists 5/1/81 DOS.17-8 6/22/81 D. S. 16-14~-z 7/3/8! Tape #62000 Run 1 & 2 Tape#61740 Run 1 & 2 Tape#61757 Run 1 Schlumberger Schlumberger Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #443 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLI ~.Cu././//,./~(.__~S /'2',,'2 so, o ' ~ARAIHGN A!aska Oil & Gas Cons. Commissio~ CHEVRON Anchorage ARCO OH and Gas Comp,thy is ,1 Divas,on o! AtlanhcRichlieldCompany Oil and ARCO .2'.. :": ,.:. ~'~ ~':. ~ ~i~ Jerry A. Rochon District Operations Engineer July 6, 1981 Reference: ARCO Cased Hole Finals 12-11 J6/24/81 DOS.12-11 t~ 6/25/81 D.S.14-20;'~ 6/23/81 D.S.16-13 5/10/81 CNL Run 1 Cement Volume Log R~un 1 CNL Run 1 CNL Run 1 CBL/VDL Run 1 5I! 5" 5 i! 5" ~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal ~1409 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and G~$ Company is a Oiv,$ion o! AtlanticRichlielclCompan¥ ARCO Oil and Gas.,Company North Alas!." 'istrict Serry A~ ~ochon District Operations Engineer June 23, 1981 Reference: ARCO DIRECTIONAL SUP~EYS 1/~ o 14~1'8*': 5/10/81 / D.So16-6 5/19/81 ~. 16-'1'3 6/17/81 x. 12-10 6/2/81 o16-6 6/16/81 Gyroscopic Job#4771 GyrOScopic Job#Boss-16803 Single-Shot Job A481D0291 Single-Shot Job# AL 5-81-D12 Single-Shot .JOb# A481D0324 Gyroscopic Job#4772 I GEOL . I 2 GEOL __1.3 GEOL I STAT TEC ._ EEC,._ _ .................. CONFER: ................ ~ FILF: Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #3?0 6 DISTRIBUTION NORTH GEOLOGY R & D DRILLING ENG. MANAGER D & M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company ,,~ a Olvls:on O! AIl,lnlicR~chlieldCompan¥ ARCO Alaska, Inc, , " ' · Posl Otlice B,,:.-~ 360 Anchorage. :~],,a 99510 June 22, 1981 Mr. Hoyl.e Hamilton State of Alaska Alas'ka Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 4-13 DS 5-1 DS 12-t0 DS 13-12 DS' 14-18 DS 14-19 DS 16-6 DS 16-13 DS 17-7 .A-1 B-2 B-3 C-8 · Dear Sir: Enclosed please fi nd: ' 1.) The subsecluent sundries for DS',4-13 & DS 5-1. /'" 2.) The monthly reports for DS 12:10, DS !4=19, DS 16' 13, DS ~7-7, "A- 1 '& B- ~,," 3.) The complet, ion reports for DS 12L9, DS 13'Z12, DS 14'J'18, u~ 16-6,.. 4 )~:Thm~yros~o~'Su==e~s'~or DS -~, DS ~ 8, DS Z~' C~ ~zSincerely' /~- P.A. VanDusen District Drilling Engineer PAV/KJG: sr Enclosure ..- mS-)/' ' STATE OF ALASKA ~ ~"~ 0RI~I "A ~ ' ALASKA,;'...~AND GAS CONSERVATION C~ , ~IISSlON ." WELL COMPLETION OR RECOMPLETIONREpORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. permit Number ARCO Alaska, :[nc. 80-93 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 995]0 50-029-20505 4. Location of well at surface 9. Unit or Lease Name 648'N & 725'W of SE cr Sec 18, TIOIt, RI5E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number l142'N & 1284'W of SE. cr Sec 18, TION, R15E, UM DS 12-9 At Total Depth 11. Field and Pool 14IO'N & 1499'W~of SE cr Sec 18, TION, RI5E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe 0i 1 Pool 71' RKBI ADL 28330 12. Date Spudded3/28/81 13. Date T.D. Reached5/2/81 14' Dat' C°mp" Susp' °r ~Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns5/8/81 --- feet MSL 1 17. Total Depth(MD+TVD) 18. Plug Back Depth (MD+TVD)19. DirectionalSurvey [ 20. DepthmhereSSSVset I 21. Thickness of Permafro~t 9782'MD 9527'TVD 9752'MD 9561 'TVD YESC~] NO[] 2105 feetMD 1900 (approx) 22. Type Electric or Oth'er Logs Run DIL/SP/GR, ILD/ILM/SFL/BHCS/GR, FDC/CNL/GR/CAL/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SiZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 surf 80' 32" ' 300 sx Permafrost 13-3/8" 72# L-80 surf 2609' 17~" 2500 sx Fondu & 400 sx Permafrost II 9-5/8" 47# L-80 & surf 8828' 12~". 500 sx Class G S00-95 7" 29# L-80 8524' 9785' 8~Il 400 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. ~- ~I'UBING RECORD, ~nterval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5~" 8526' R441 I -- n/a .. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED , · n/a ,' , . · . 27." ~ PRODUCTION TEST Date First Pr, oduction Method of Operation (F, Iowing, gas lift, etcJ , Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I1~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE. ,._ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . To be sumitted by ARCO GeolOgy Department und'er separate cover. ~ .... o .. ' Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ' i~,:~,M~. Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ..... T. Sadl erochit 9004' 8829' 0i 1/Water 9284' 9080'. n/a · ,,. · 31. LIST OF ATTACHMENTS DRILLING 'HISTORY, GYROSCOPIC SURVEY .......... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S ig,ed .~..__/~. J~ T it,e Dist. Dr lq. En.q. D a,e ~//"/~'/ 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 ,!6 and 24: If this well is compleX;ed for separate production from more than one interval (rnultiple 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 derails of any multiple stage cement- lng 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". DS 12-9 DRILLING HISTORY NU 20" riser. Spudded well @ 1930 hrs, 3/28/81. Drld 17½" hole to 2620'. Ran 64 its 13-3/8" 72#/ft L-80 csg w/shoe @ 2609'. Cmtd 13-3/8" csg w/ 2500 sx Fondu & 400 sx Permafrost II. ND 20" riser. Instld 13-3/8" pack- off & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi -pk. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to .l_2.59_p_g E~W - ok. Drld 12¼" hole to 8839'. Ran multishot. Ran DIL/Sp/G~' Ran 215 jts 9-5/8" 47#/ft L-80 & S00-95 csg w/shoe @ 8828'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" pack-off & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FS & 10' new ,form to 885,0,'. Tstd form, to 12.5 ppg EMW - ok. ~s f/8850- 9369 . Drld 8½ hole to 9782 TD. Ran ILD/ILM/FSL/BHCS/GR, FDC/CNL/GR/ CAL/CCL. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H~O, 53 bbls Permafrost C & 132 bbls Arctic paCk. Ran 43 jts 7" 29#/ft L-80 AB MOD liner fr/8524-9785' Cmtd 7" liner w/400 sx Class G. Drld cmt to 9752' PBTD. Displaced weli to NaC1. Tstd lnr to 3000 psi - ok. Ran CBL. Ran 5½" comPletion assy w/tail @ 8526' & pkr @ 8441'. Tstd tbg hanger & pack-off to 5000 psi - ok.. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Dropped ba~et pkr. Tstd tbg to 3500 psi & ann to 200 psi - ok. Tstd tbg t<200 ps~ & ann to 3500 psi - ok. Pulled dummy valve. Closed SSSV. Instl~-t-we~ cap & tstd to 5000 psi - ok. Secured well & released rig @ 2400 hrs,' 5/8/81. I, P~RT OF SUB-$U~FACF 9{RECT~ONAL SUPVEY ARCO ALASKA, INC. C.,9~PA~Y DR! LLSI, ~ 12 W,zL.L 9 NORTH SLOPE, ALASKA AL 381 D6 LOCATION Sindle Sh_g~ nTCK t' r ,-,- TYPE SURVEY ENG. I.N£ER NAMr. TITLE 1000 DATE ~NA. URE 85O9 DEPTH INTERNAL FROM TO 3-30-8! 4-18-8! DATES S' ~,~'~.r WAS TAKEN FROM · TO THiS !S A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We :'.ave retained a copy of your survey report in our files for your convenience; however, should you so desire, aH copies of the survey report w;i~ be forwarded to you on written request. A!I surveys are kept in a locked file ~nd are held in strictest conf;dence. Additional copies of your survey report can be made from the original by any b!uepr[nt company, RECEIVED Alaska Oil & Gas Co.s, Co~r~[Ss[oD Anchorage ~il;:.:;'" '" ":'~:'; ' ' ..................... ' ........ '" "-" ...... ' ....... :" ................. ~!'~ ~RCO ALASKA INC. ~ sITE 12 WELL 9 ZOHPUTER METHOD(RADiUS OF CURVATURE) COMPUTER DATEI4=20-81) ~:~ =IELD METHODIAVERAGE) SURVEY. DAT~(~-j-S1 THRU ~-9-8j~ ...... .... ... ~j~,~ ~ECO~D OF SUrVeY . . ~'~A"S'; .... DRIFT VERTICAL .... ~ ................ ~'IFT TOTAL COORD]NATE~ C L 0 ~ U R E ~ · $~V~RITY S~CT]ON )EPTH ANGLE DEPTH SEA DIREC DISTANCE ANGLE DEG/IOOFT DISTANCE 1485 0 15 1484.99 1413.99 N56.00E 3.58 N 2.05 E 4.12 N 29 49 19 E 0.021 0.53 - ~:~,~ ~:' 2620 0 45 2619.94 2548.94 S65.00E 4.32 N 11.49 E 12.28 N 69 2~ 5 E 0.044 -6.52. i~i!/' 3137 1 0 3136.88 3065.88 579.00E ........ 1.89 N 18.98 E 19.08 N 84 18 43 82 '.':.!!-;";".:S 7:4 .*' 0('" :~:::~:;~:':~::~:~?'~::i:.:~¥ - ~:~,~::'.:. 36~0 0 45 3629,82 ~558, ...- .... ~:~f'~:<:~ ;..: ............. . ............... :-.,:~5,,:.:.. 0 ~ ~.T8 f':'.:.::'N ~:," O0 '::~.'~ ::.::~ o... ~?~. ~' ~o~,.?z?~:.;~'B'6~:~oO' ~::~;-~::~:~ 0~::. 5189 0 45 5188.66 5117.66 N65,00E 3.46 N 48,4~ E 48,5T N 85 54 ~5 E 0,048 -36,4~ ~: 5710 0 0 5709,64 5638.64 N. O.OOE 6,18 N 50,18 E 50,56 N 82 58 6229 0 0 6228.64 6157.6~ N O.OOE 6.1B_N 50.18 E 50,55 N 82 58 10 E 0.000 -~6.~( . ~:~:~ 6858 ~ 0 6857,59 6786 59 N78,00W 7,57 N 47,41 E 48.01 N 80 55 :~'6952':"!:4 ~5 , 6951,:36 "::698 5.,..:':' 5 15 6984.24 ::.691 .... :.. ' .'.:... ~~~?~~~~ .-...:: ~-..:.:.,-,.:..-~:.?.:.-~..:~.:.o >.7462 15, 0 7208 8 0 7205.75 71:34.75 N75.OOW 7368 1:3 0 7363,02 7292,02 N74,00W 7400 13 0 7394_%_20 7323,20 N74.00W 7454., :36 ,~.....:.....:...: ::.: 0.54 N 13,97 E 13,98 N 87 45 17 E 1,678-,- -10,78 8.33 N 14,11 W .!6.39 N 59 25 40 W 3.125 16,27 ,0.32 N,' .:21.03 W i' 23,42 N 63 51 '41 W 0.000 22.98 ARCO DS 12 WELL 9 TRUE DOG LEG ~:u MEAS. DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L O S U R E S SEVERITY SECTION )EPTH ANGL~E __PEPTH SEA DIREC DISTANCE ANGLE DEGJ[OOFT DjSTANCE D M '7631 7682 ~: ~o5~ IOTTOM HOLE CLOSURE 477.88 FEET AT N 52 41 46 W I~RCO ............................................... DS 12 WELL. 9 MAGNETIC'.'SlNGL£ SHOT"SURvEY'" :' .'.' .:, .'' ::8 : :: '":;'. :':~ii::: HEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF ..SUB SEA DEPTH, ~ii- TRUE ' DEPTId S._EA MEASURED DEPTH __ .1.7_1 · o,00 E 1_7_1 271 371 47! . 571 671 571, 500 0 0 0,69 N 0,11 E 671. 600 0 0 0,95 N 0,18 E i 711 871 "' 971 1171 1271 7 ]_1._~ 7.QO 0 0 ._1,25___N 0i27 E .... 1171, 1100 0 0 2,67 N 1,0~ E 1271. 1200 0 0 2,99 N 1771 1771. 1700 0 0 ~.27 N 3,~ E : 1871 1871. 1800 0 O ~,~9 N ~.io',E ' I !8.!1 . ~ 1971, _ _ ~900 0 :":..:: : '.' .2071 20-~1. :.:' :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :?::'>"-:?.'::: 2 z 71 2171 · .': :' 2 z ::::::::::::::::::::::::::: :::::::::::::::::::::::::::: 1211 · 2~1!.,..'?'- 12o0'-'::ii"'::::'::.::.:::.......;..: :......:.:..::. 2371 2371, 2300 0 2~71 2471- 2400 0 0 0 0 4.67 N :~;~;.~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 4,85 N- 8,.63 E 4,71 N ~:i?:: ::::::::..,' .. 2 6 71 .. .. '. 2 6 7 ~ .":...:'/: ~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ======================================= ~i:~: :-~:~:O~i:.:-:::'~ i:iZ:':~:-i::l:::i:iei:?::i~:~i:!~i:~:i:!" 2971 2971, 2900 0 0 ' 2,5~ N 16,28 3071 3071, 3000 0 0 2-13 N 17.88 3171 3571 3171. 3100 0 ' 0 1.77'N 19.56-E 327 ~; .. : ~ 0.0 :~::.!~:::~:!.~:.::/:~:~.::i::~:?~:i~i:~:~:i~!!:::~i.~i:i::~i???ii:!i::i:!.::.~?~.:i!:!i~::~i~i~!~iii?::.i~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 3571, 3560 0 J'" '' 0 ..... .-.'. ........ 0 '. 3~ N ...... 25, ~m ''E " '' ~RCO DS 12 WELL 9 ~EASURED DEPTH AND OTHER DATA FOR EVERY EVEN i00 FEET OF SUB SEA DEPTH, MEASURED DEPTH 3671 '.:- 3771 3971 4071 4171 4071, 4000 0 0 0.12 $ _32,01 4171, 4100 0 0 0,18 N 33,29 '+0.82 E 49,30 E ' · _ 5371 5371, 5300 0 0 4,62 N 50,OZ,E 5471 5471, 5qO0 0 0 . :..,:.,- ..... s sv i 557 ~. ~.. ~ 500 :~::.?~:~:~:~?~:~:~<.o:~?<~?~ ] 587t 587x. 5soo 0 0 :. 6.ts N 50.Z8 E '- . ~'~ J 5971 5971, 5900 0 0 J 6071 6071, 6000m j 657X 6571e 6500 .0 '.,' 0 ' - . -' ' - N 50 XS'. ' ' .' ' . )~"~ { 6671 667~, 6600 0 4671 4671 · 4600 0 0 1,49 N 4771 4771, 4700 0 0 1,67 N 4871 4871, 4800 0 .... 0 1,96 N 507 ~ · 5o7 ~.--~:::?:.~:~::,:sooo..?:~.~o~ ~: 5271 5271e 5200 0 0 3e96 N .''. m" .... ' .:.~'': . .:'j:':~ .' ".': ' ' . ' . /m ':,~ "..S':. ...... ........ ",~, ~ :',:'~"-'-' /S' ..' "::":."%.~::'.'.:''~.~ .': .'-'''.'':. q~'~SURED D£~"AND OTHER DATA FOR EVERY EVEN 1OO FEET OF SUB ,SEA DEPTH, - TRUE .' .?~ ~ '"~. :.:.~)(:.'"~. ~?~:.:': ';::/ ~'.'~ )."":'.::-¢:~- ~ :"..;?.?.:~:.~:'/.~-:?f~.::~:?'." MEASURED VERT J CA~ SUB ' ' D:':"~':~F"-?/~?~'~:~'~:- '"': :""~'"'":: ;''/';''~'''':~'~':'L~''?''~ '.;.r-...::~..:? MD TV -...:.:.: ....... -:::.--::- VERT I CA~-'..:. :. :.....:..:- · . :. :-:: ...... :-:..: :: .-:: ...... ".....::..::-.. ' :;) ..::~ .....:..:;? -.' · · .:;':--: :: '.:-." . . -...' · .-. '-: '.. · , ~pT~ ~TH SEA 7173 7171. 7100 .1 0 0,03 5 7274 72710 7376 7371, 7479 7471, 7583 7689 77~.5 7904 8015 8D_O 8245 8361 I8.65 E iiii:!?:3:, 9"7 ~:!iI'' 7571, 7500 12 4 25,21 N 67,41 7671. 7600 17 5 41,36 N 95,60 _7_7_7_1_~ 7 ~g_O. 24 ' 7 (,4,49 N 124,20 .... i~ _ ~1~ . _i':' S_o. o.o. .:'"?~:iL:~i:::/5 8.:i?':~:'i::?:: ~ii:;!:!i~!~.!~,;! ~!!;?~!.:-X~:~:,~-:ii::;O~.?:N?j~~.i3~::~.,::; 8171, 8100 74 16 198,78 N 278,17 8271, 8200 90 i6 238.07 N 322,5X .5 - kRCO DS 12 WELL 9 MAGNETIC SINGLE SHOT .suRVEy ... . 20 APR 81 ~ .> . '- ~ : - . '-' ' ' '' " '..~ ..~ i.. '. ;NTERPOLATED VALUES FOR EVEN lO00 FEET OF MEASURED DEPTH, TRUE ~. ~ MEASURED VERTICAL SUB ~ DEPTH DEPTH SEA 1000 200Q_ 300O 4000 . ~_~.0 0 6000 7000 999, 928- 2*07 N 0,59 5999. 5928, 6,18 N 50.18 E 6999. 6928. 5.34 N 37.13 E 19_5_7_, 78B6, ! 19. 91 N 18 7 ,_9_7 W 400 800- 1200- 1600 : - _ --~ 2000. · 2400 ........ . . - 2800 ..... _ . . 3200- $600' '' . 4400 . . 5200- 5600- .... 6000- . 6400' 6800- 7200- · . ; ' _ .................................................... VERTICAL. SECTION ' ARCO ALASKA INC. ' DRILL SITE'I:) WELL 9 ' · i ' RADIUS OF CURVATURE ..... i MAGNETIC' SINGLE-' SHOT · . - ....... ! ~ SCALE~ : I000' : i . . . i -. - APRIL ~-I, 1981 , . . _ ................ .' ........... :_ .J ................. ~ - . , --- ARE TVD · , ! , , . . . T '' ~ , : - i ; .... : - i ............. f ; t J ~ ' . . ~, . ,~ ....... .I. .... ._ . : . . . : ...... ,'.. [ - . .......................................................... _J ............................................................... t .......... i · ~ ~ - ; - . . ............................................................................... ..... ..... ~--'760i'~ eooo-~ ............ TVD: 8397' . -. TMD = 8509' · I ...... ~ ...... ARCO ALASKA INC, - ~ !- ~:.-~, -~ J DRILL SITE 12, .WELL 9_~_ ....... ~ ........ I ......... : ............. RADIUS OF CURVATURE ....... '" MAGNETIC SINGLE- SHOT .......... SCALE I" '- IOO0' .............. ~ ........... ~ .......................... APRIL'- 21, 1981 . ...................................... ~ ......... ' .j ; ......................... , ~. ~ ....... ~ .... ~, ,~ ._,~~_.CLOSURE~ N 52° 42' W - 478' ..................... -'. ......... ~ ............ ......................... TMD:8509'~[ o ' ~ ' ................. t ...... :, ....... ~ .................... ~ ................. - ~ ALL DEPTHS. SHOWN -.: ...... ' ............ ', ARE TVD ~ ....... : · 4- - ' ' ; ....... ................ : ........ ~ ~ ~ .......... ..... ~ .......... : ........... 1 .... ~ :-;'-i'.';ii'_~.'_'..'.'... ;'; ;;'. ~ ..... ; ............. : :, ............ ~ - ........... : ..... ~ ...... . ..... ~ ' . , ' ' ' ~ ........ ~ ....... t .......... ................................. ; ... ; . { ' . . .............. ; ..... '. ~ ' , ~ ~ : - - ~ I ....... " ' ..... ' t ..... ....... ~ · : - - - ~ ~ - ......... ~ - I t ,' .......... i ; , { . . ~ _ World Leader in Service to the Oil Industry 1111 East 80th Anchorage, Alaska 99502 'Phone 349-3541 - ... . ~ . ' . :.;.? .. .' May ll, 1981 Job #4772 North Slope Drilling: Enclosed please find our Gyro Survey on Drillsite 12-9 along with our Vertical Section and Horizontal View maps. - , ';. - '- ' . , Also enclosed you will find the Gyro Film, Field Sheet and Calculations. If any other information is needed please call 349-3541. Thank you for using Scientific Drilling International and please call again. Sincerely Manager TRUE MEAS. DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D ,N DEG. 0 0 0 0.00 -71,00 N O,OOE 100 0 0 100,00 29,00 N52.35W 200 0 0 200.00 129,00 N52.31W 300 0 0 300.00 229.00 N52.31W 400 0 0 400.00 329.00 N52.31W 500 0 0 500.00 429.00 N52.31W 600 0 0 600.00 529.00 N52.30W 700 0 0 700.00 629.00 N52.30W 800 0 0 800.00 729,00 N52.30W 900 0 0 900.00 829.00 N52.30W 1000 0 0 1000.00 929.00 N52,30W 1100 0 0 1100.00 1029.00 N52.33W 1200 0 0 1200.00 1129,00 N52.41W 1300 0 ~ 1300.00 1229,00 N52.48W ' 1400 0 0 1400.00 1329.00 N52.56W 1500 0 0 1500,00 1429.00 N52o65W 1600- 0 0 1600,00 1529,00. N52,?3W 1700 0 30 1699.99 1628.99 S72.81E ' 1800 0 30 1799,99 1728.99 S22,88E 1900 0 0 1899.99 1828.99 N52,96W' 2000 1 0 1999,98 1928.98 N86.95E 2100 0 45 2099,97. 2028,97.~ N76,86E 2200 0 45 2199.96 2128.96 S78.76E 2300 0 30 2299,96 2228,96 S48.85E 2400 0 30 2399.95 2328.95 S58.93E ' TOTAL COORDINATES O.O0"S 0.00 S 0.00 S 0,00 S 0.00 S' 0.00 S 0.00 S 0.00 S 0.00 S 0.27 N 0.29 S 0.49 S 0.15 N 0.36 N 0.38 N 0,O8 S 0,60 S 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.14 E 0,76 E 0,51 E 0.70 g 2.21 E 3.51 E 4,48 E 5.19 E C L 0 S DISTANCE U R E S ANGLE O M S DOG LEG SEVERITY DEG/IOOFT 0.00 'S 0 0 0 W 0.00 S 0 0 0 W 0.00 $ 0 0 0 W 0.00 $ 0 0 0 W 0.00 $ 0 0 0 W 0.00 $ 0 0 0 W 0.00 S 0 0 0 w 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 w 0.00 $ 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W- 0.00 S 0 0 0 W 0.00 S. 0 0 0 W SECTION DISTANCE 0.00 S 0 0 0 W 0.30 N 27 13 30 E 0.82 S 69 4 29 E 0.71 S 46 '15 17 E 0.72 N 78 . 0 53 E 2.24 N 80 39 12 E 3,53- N 83 43 31 E 4.48 S 88 51 42 E 5.22 S 83 22 33 E 0,000 0.0-0 0.000 0.00 0.000 0.00 0-000 0.00 0.000 0.00 0.000 0.00 0.000 O. o.ooo 0.000 0.00 0.000 0.00 0.000 0,00 0,000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0-000 0.00 0.000 0.00 0.500 0.09 0.422 -0.75 0.500 -0.71 1.001 -0.39 0,250 -1.32 0,317 -2.~ 0.250 -3......,,~ 0.088 -4.11 ARCO DS ~2-9 GYROSCOPIC SURVEY RECORD OF SURVEY JOB NO 4772 11 :;JUNE ,81 MEAS, DRIFT DEPTH ANGLE D M 2500 0 45 2600 1 0 2700 0 0 2800 1 0 2900 1 15 3000 0 30 3100 1 0 3200 1 15 3300 1 30 3400 0 30 3500 0 30 3600 1 15 3700 0 45 3800 0 0 3900 0 0 4000 0 0 4100 0 0 4200 0 %5 4300 0 15 4400 1 0 4500 1 '0 4600 1 30 47O0 1 0 4800 0 30 4900 1 0 5000 0 30 5100 1 0 5200 0'0 5300 .0 0 TRUE VERTICAL DEPTH 2499.95 2599.94 2699.93 2799.93 2899.91 2999.89 3099.88 3199,87 3299.84 3399.82 3499.82 3599.80 3699.79 3799,79 3899.79 3999,79 4099,79 4199,79 4299.78 4399,78 4499,76 4599,74 4699,71 4799,71 4899.70 4999,69 5099.68 5199,67 5299,67 SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES CLOSURES DI STANCE ANGLE O M 2428.95 524.00E 2528.94 S39.08E 2628,93 N54.16W 2728.93 S49.25E 2828.91 549.315 2928.89 . S61,31E 3028.88 556.31E 3128.87 564.31E 3228.84 S73.31E 3328.82 564.30E 3428.82 N85.70E 3528.80 S74.30E 3628.79 N75.70E 3728.79 .... N54.30W 3828.79 3928.79 4028.79 4128.79 4228,78 4328.78 4428.76 4528.74 4628.71 4728,71 N54.26W N54,26W N54.26W S74.26E S84,25E 589.255 S84,25E '580,25E' S74.25E S84.23E 1.40 S 2.70 S 3.14 S 3.59 S 4.87 S 5.73 S 6~41 s 7 38 s 8~25 s 5.90 E 6.69 E 6.28 E 5.93 E 7.41E 8.67 E 9.79 E 11.49 E 13.73 E 8.70 8.70 8.70 8,56 8.64 8,70 8.80 9.09 9.58 9.82 19.53 E 19.53 E 19,53 E 19.60 E 20,03 E 21.12 E 22.86 E 25.02 E 27.i5 E 28.43 E 4828.70 584.23E ' ,..';,,9-95 4928.69 ..S84':23Ei': 10.08 5028.68 ~-.'::~89 23E'~i? 10-16 5128,67"; N54.21W ' 9-53 5228.67 N54.21W 9.53 -. .. 29.73 E 31.04 E 32.34 E 32.55 E 32.55 E 6,06 S 76 35 7 7.22 S 68 0 25 7,02 S 63 26 17 6.93 S 58 48 58 8,87 S 56 43 0 10,39 S 56 30 41 11.70 S 56 46 9 13.66 S 57 16 41 16.02 S 58 59 35 17.74 $ 59 57 10 18.55 $ 60 50 7 19.96 S 62 34 19 21,51 S 64 38 20 21.38 S 65 59 38 21.38 S 65 59 38 21.38 S 65 59 38 21,38 S 65 59 38 21.39 S 66 24 21 21.82 S 66 39 38 22.84 S 67 35 59 24.50 S 68 56 18 26,62 S 70 '1 8 28.79 S 70 33 54 30.08 S 70 56 26 31.36 S 71 29 25 32.64 S 71 59 50 33.90 S 72 33'35 33.92 S 73 40 14 33,92 S 73 40 14 DOG LEG SEVERITY DEG/iOOFT E E E E E. E E E E E E 0.250 0.250 1.000 1.001 0.250 0.750 0.500 0.250 0.250 1.O00 0.259 0.750 E 0.500 E 0.750 E 0.000 E 0.000 E 0,000 E 0.250 E 0,044 E 0.750 E . 0.087 E ,' 0.500 E 0.500 E 0.500 E ~ 0.500 E: 0.500 E '"'~'".0.500 '. E 1.000 E 0.000 ,..;. i~..:-~ . ,~,~. :.;- ,.. , . , SECTION- DISTANCE -5.1~,- -6.66 -6.67 -6.74 -8.70 -10.20 -11.47 -13.36 -15,56 -17,16 --17.88 -19.06 -20.30 -20+01 -20.01 -20.~ -19-96 -20.32 -21-14 -22-45 -24.19 -26,04 -27.13 -28.14 -29.16 -30.15 -29,85 ~29.85 ARCO DS 12-9 GYROSCOPIC SURVEY JOB NO 4772 11-JUNE 81 RECORD OF SURVEY MEAS, DRIFT DEPTH ANGLE D M 54O0 '0 0 5500 0 0 56OO 0 0 57O0 0 0 5800 0 0 5900 0 0 6000 0 0 6100 0 0 6200 0 0 6300 0 0 6400 0 0 65OO 0 3O 6600 0 0 6700 1 30 6800 4 0 6900 6 0 7000 7 0 7100 8 0 7200 11 15 7300 13 30 7400 16 0 7500 19 30 7600 19 0 7700 20 30 7800 23 30 7900 26 15 8000 28 30 8100 30 0 82O0 29 0 TRUE VERTICAL DEPTH 5399,67 5499,67 5599,67 5699-67 5799,67 5899,67 5999.67 6099,67 6199,67 6299.67 6399.67 6499,67 6599.67 6699,66 6799,54 6899,15 6998.51 7097.65 7196,23 7293,90 7390,60 7485,82 7580.23 7674,34 7767,05 7857,77 7946,56 8033,81 8120,84 SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M 5328,67 N54,21W 5428,67 N54.21W 5528.67 N54,21W 5628.67 N54.20W 5728.67 N54,20W 5828'.67 N54,18W 5928.67 N54.18W 6028,67 N54,16W 6128.67 N54,16W 6228.67. N54.16W 6328,67 N54,16W 6428,67 579,165 6528,67 N54,1OW 6628,66"'N78.00W 6728.54 N83.83W 9,53 S 32,55 E 9.53 S 32,55 E 9.53 S 32.55 E 9.53 S 32,55 E 9,53 S 32,55 E 9,53 S 32,55 E 9~53 S 32.55 E 9~53 S 32.55 E 9'53 S 32,55 E 8 · 9 5:~-'5'~..'?? ~.32., 80~;.. E~ 8 · 43'*:*:5¢ '~'31;'`61 ~ E ?"~:~ .7.67 S 26.88 E 6828,15 -S64.33W '..." 9.13 6927,51 -S71.50W ?' 13.38 7026.65 N78.38W 14.15 7125,23 N74,13W 10,18 7222.90 N72,88W 4.10 7319,60 N73,03W. 3,35 N 7414,82 "N63,06W ]]:~. 14.73 N 7509,23 N49,75W 32,93 N 7603,34 N47.80W 55,20 N 7696,05. N47,80W · 80,36 N 7786,77 N47.,80W :.:':':: '108,61 N 7875.56,:':.,.:'~47.78W-? 139,50 N 7962.81-N45.O1W ' 172.88 N 8049.84 N45,93W 207,10 N 18.40 E 7,91 E 4.95 W 21.19 W 41.74 W 66.08 W 94.31 W- 121.72 W 147.13 W 174.88 W 206,04 W 240,09 W 275.77 W 311,17 W 33,92 S 73 40 33,92 S 73 40 33,92 S 73 40 33.92 S 73 40 33,92 S 73 40 33,92 S 73 40 33.92 S 73 40 33,92 S 73 40 33.92 S 73 ~0 33.92 S 73 $0 33,92 S 73 $0 33.96 S 74 11 34,00.5 74 43 32,72 S 75 4 27,95 $ 74 3 20,54 $ 63 36 15,55 S 30 36 15.00 S 19 18 23.51 S 64 19 41.94 S 84 22 66.16 N 87 5 95.46 N 81 7 126,09 N 74 51 157.14 N 69 26 192.46 N 65 19 232,.91 N 62 12 277.68 N 325,48 N 373.79 N DOG LEG SEVERITY DEG/iOOFT DISTANCE 14 E 14 E 14 E 14 E 14 E 14 E 14 E 14 E 14 E 14 E 14 E 53 E 27 E 2 E 56 E 29 E 42 E 16 W 30 W 56 W 37 W 15 W 35 W 5 W 12 W 14 W . 59 50 31 W . 57 54 55 W 56 21 13 W 0,000 0.000 0,000 0.000 0,000 0,000 0.000 o.Ooo 0.000 0,000 0,000 0.500 0.5O0 1,500 2,500 2,030 1.006 1.158 3.254 2.251 2,500 3,672 1,497 1,519 3,000 2.750 2.250 1.564 1.OOO -29.b~ -29.85 -29.85 -29.85 -29.85 -29.85 -29.85 -29.85 -29.85 -29.85 -29.85 -29,74 -29.62 -28.41 -24.51 -19,=0 -6,42 7,91 26,80 49,35 77,43 109.71 143,44 180.86 222,89 268,82 317,66 366,90 ARCO DS 12-9 GYROSCOPIC SURVEY RECORD OF SURVEY JOB NO 4772' 11 JUNE 81 MEAS. DRIFT DEPTH ANGLE D M 8300 29 0 8400 30 0 8500 29 0 8600 2~ 30 8700 27 0 8800 27 0 8900 27 0 9000 27 0 9100 26 30 9200 26 30 9300 26 30 9400 26 0 9500 25 30 9600 24 45 9700 25 0 BOTTOM HOLE TRUE VERTICAL DEPTH 8208.31 8295.34 8382.37 8470.05 8558,54 '8647.64 8736.74 8825.85 8915.14 9004.64 9094.13 9183.82 9273.89 9364.42 9455.15 CLOSURE SUB SEA DRIFT DIREC DEG. 8137.31 8224.34 8311.37 8399.05 8487.54 8576.64 8665.74 8754.85 8844,14 8933,64. 9023,13 9112,82 9202,89 9293.42 9384.15 1046,74 FEET AT N43,30W N43.38W N41,53W N41.46W N39,51W N37,71W N36,81W N37.70W N36.71W N37.61W N37.61W N38,48W N37,48W N38.08W N36.03W N3~.O3W N TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M DOG LEG SEVERITY DEG/iOOFT 241,61 N 345,22 W 421.37 N 55 0 45 W 277,42 N 379,02 W 469,70 N 53 47 51W 313.75 N 412.26 W 518.07 N 52 43 36 W 349,77 N 444,13 W 565,33 N 51 46 39 W 385.18 N 474,36 W 611.05 N 50 55 23 W · ' 420.65 N 502.69 W 655.48 N 50 4 38 W 456~78 N 530.18 W 699.82 N 49 15 11W 492Q92~ N 557.67 W 744.29 N 48 31 37 W 528~76 N 584.89 W 788.47 N 47 53 6 W 599.66j~N~%'% 6'3~9'¢;f08~i~:~!':~;' 876.37 N 46 49 20 W 634. ~:~ 920.10 N 46 24 8 668 · 73~'N:'~' 69 B ...O~7.~.W,~ ~ 963.10 N 46 1 26 W 702.29"N 719,09 'W ' 1005.14 N 45 40 37 W ' 735.86 N 744,43 W 1046,74 N 45 19 55 W .7'&3, 3ff ~ 7~5,2/ 19 55 W 1.277 1.000 1.090 0.500 1.553 0.817 0.409 0.401- 0.537 0.402 O.OOO 0,527 0,533 0,757 0,443 SECTION DISTANCE 464.58 513,76 561.75 ~08,15 653.23 698,18 743,13 787,69 831.85 876.07 919,94 963.03 1005.12 1046.74 ARCO DS 12-9 GYROSCOPIC SURVEY JOB NO 4772 · INTERPOLATED TRUE VERTICAL DEPTHS~ COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL NAME DEPTH DEPTH TOTAL COORDINATES CLOSURE DISTANCE ANGLE D H S JUNE 81 SUB SEA TOP SAD 9004 8829.41 OIL/WATER 9284 9079.81 PBTD 9752 9501.21 TD 9782 9526.74 494,37 N 558.76 W 594,25 N 634.40 W 753,18 N 761.05 W 762,16 N 773.96 W 746.06 N 48 29 56 W 8758,41 869.25 N 46 52 17 W 9008.81 1070,74 N 45 17 51W 9430.21 1086.23 N 45 26 24 W 9455,74 .. · . · . i ARCO DS 12-9 MEA$'URED DEPTH AND OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB NO 4772 FEET OF SUB SEA DEPTH, 11 ._. JUNE · m TRUE MEASURED VERTICAL DEPTH DEPTH 171 271 371 471 571 671 771 871 971 1071 1171 1271 1371 1471 1571 1671 1771 1871 1~71 2071 2171 2271 2371 2471 2571 2671 2771 2871 2971 3071 3171 3271 3371. 3471 3571 171, 271. 371, 471. 571, 671, 771. 871, 971, 1071, 1171, 1271. 1371. 1471, 1571, 1671. 1771, 1871. 1971. 2071, 2171, 2271. 2371, 2471, 2571, 2671, 2771. 2871, 2971, 3071, 3171, 3271. 3371, 3471, 3571, SUB MD-TVD SEA DIFFERENCE 100 0 20O 0 300 0 400 0 50O 0 600 0 700 0 800 0 9O0 0 1000 0 1100 .0 1200 0 1300 0 1400 0 1500 0 1600 0 1700" 0 1800 0 1900 0 2000 0 2100 0 2200 0 2300 0 2400 0 2500- 0 2600 .: 0 2700 O' 2800 , 0 2900 .... ,,,.'0 3000 0 3100 0 3200 0 3300 0 3400 0 350O 0 VERT I CAL CORRECTION TOTAL -0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 -0 0 0 0 0 0 0 0 0 0 0 - 0 COORDINATES · 00 5 · 00 S · 00 S · 00 S · 00 S · 00 5 .00 .00 · 00 $ · 00 $ · 00 $ · 00 S · 00 S · 00 S · 00 S · 18 N · 08 S · 58 S · 10 S · 29 N ,44 N · 07 N · 47 $ .10 · 31 S .33-S · 30 S · 47 S · 59 S · 16 S · 11 S · 02 S · 74 S · 04 S · 08 S 0.00 W 0,00 W 0.00 W 0,00 W 0,00 W 0.00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0.00 w 0,00 W 0,00 W 0,01 E 0.63 E 0,58 E 0,49 E 1.82 E 3.14 E 4.27 E 4.97 E 5,71 E 6,41 6.47 E 5.96 E 6.95 E 8.39 E 9,39 E 10.94 13.02 E 15.06 E 15,95 E 17,15.E ARCO DS 12-9 MEAS'URED DEPTH AND OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB NO 4772 FEET OF SUB SEA DEPTH, JUNE 81 MEASURED DEPTH TRUE VERTICAL DEPTH ,. SUB MD-TVD SEA DIFFERENCE VERT I CAL CORRECTION TOTAL COORDINATES 3671 3771 3871 3971 4071 4171 4~71 4371 4471 4571 4671 4771 4871 4971 5071 5171 5271 5371 5471 5571 5671 5771 5871 5971 6071 6171 6271 6371 6471 6571 6671 6771 6872 6972 7073 3671. 3771. 3871. 3971. 4071. 4171, 4271. 4371. 4471, 4571. 4671. 4771, 4871, 4971, 5071, 5171, 5271. 5371. 5471. 5571, 5671. 5771. 5871. 5971. 6071. 6171, 6271, 6371, 6471, 6571. 6671, 6771. 6871, 6971, 7071, 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200" 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ' 0 0 0 0 0 0- 1 2 0 9.30 0 9.49 0 8.70 0 8.70 0 8.70 0 8.60 0 8.63 0 8.69 0 8.76 0 8.99 0 9,44 0 9.79 0 9.53 0 9.53 0 9.53 0 9.53 0 9,53 0 9,53 0 9.53 O- 9,53 0 9,53 0 9,53 O- 9.53 0 9.34 0 9.55 0 8.65 0 7,90 0 8.16 1 . 12.30 1 '"' 14,62 S S S S S S S S S $ S S S S S S S S S $ S S S S S S S S S $ $ $ S S S 19,03 E 19,90 E 19.53 E 19.53 E 19,53 E 19.54 E 19,90 E 20.67 E 22.36 E~ 24,31 E 26,62 E 28,14 E 29.27'E 30.75 E 31.88 E 32,76 E 32,55 E 32,55 E 32.55 E 32,55 E 32,55 E 32,55 E 32,55 E 32.55 E 32,55 E- 32.55 E 32.55 E 32.55 E 32,55 E 32,8i E 32,21 E 28.70 E 21.04 E 11,08 E 1,29 W MEASURED DEPTH AND OTHER DATA FOR EVERY TRUE MEASURED VERTICAL SUB - MD-TVD DEPTH DEPTH SEA DIFFERENCE 7174 7171. 7100 3 7276 7271. 7200 5 7380 7371. 7300 8 . 7484 7471. 7400 13 7590 7571. 7500 19 7696 7671. 7600 25 7804 7771, 7700 33 7915 7871, 7800 43 8028 7971. 7900 56 8143 8071. 8000 72 8257 8171. 8100 86 8372 8271. 8200 100 8487 8371. 8300 116 8601 8471. 8400 130 8714 8571. 8500 143 8826 8671. 8600 155 8938 8771, 8700 167 9051 8871. 8800 180 9162 8971. 8900 191 9274 9071, 9000 203 9386 9171. 9100 215 9497 9271. 9200 226 9607 9371. 9300 236 EVEN 100 FEET OF SUB SEA VERT I CAL -.. CORRECTION TOTAL 1 11 2 5 3 1 5 12 6 31 6 54 8 -81 10 113 13 148 16 187 14 226 14 267 16 309 ~.*~.~-14 ~ 3 430 1'3 ~11 11 551 12 5,90 I2 629 ii 657 10 70~ DEPTH, COORDINATES · 39 S · 58 S · 92 N · 47 N · 01 N · 59 N · 45 N · 09 N · 70 N · 72 N. · 84 N .43 N · 25 N · 13 N · 12 N · 10 N .70 N · 25 N · 05 N ,69 · 81 N · 86 N · 60 N 16.47 W 36,46 W 60,74 W 89.57 W 119.09 W 145.80 W 176.05 W 210,84 W 249,91 W 291.02 W 330,52 W' 369,30 W 407,81 W 444.44 W 478,34 W 509,78 W 540.37 W 571.36 W 601.27 W 631.71 W 662.15 W 691,95 W 720,89 W ... ARCO DS 12-9 INTERPOLATED VALUES FOR EVEN MEASURED DEPTH TRUE VERTICAL DEPTH IO00 2000 3000 40OO 5000 6000 7000 8000 9OO0 1000. 1999. 2999. 3999. 4999. 5999. 6998. 7946, 8825'. GYROSCOPIC SURVEY JOB. NO 4,772 1000 FEET OF MEASURED DEPT~, SUB SEA TOTAL COORDINATES 929. 0.00 S 0.00 W 1928- 0.15 N 0.71 E 2928. 5.74 S 8.66 E 3928, 8.70 S 19.53 E 4928. 10.09 S 31.04 E 5928. 9.53 S 32.55 E 6927. 13.46 S 7.95 E 7875, 139.97 N 239,66 W 8754, 493.28 N 557,19 W ll JUNE 81 .... ; ' 4--[.~--: ..... ;_'..~,..+. ~L~.-'-':-_L~--z-L _:._ :2~ ~ ";' :_' ._" ~-~-~.;-:: ...... GYROSCOPIC SURVEY .... SCALE I I000 .. ' *:" ' i · ' :: ' ·' : ......... i ...... ~.--: .... : ............... :-: .... ;--.: ........ ' ........ : ..... L ................ ~..=-.;-'~:,-VERTICAL ..:PROJECTIO ~ ...... :':Ti :T .... ~--~"*:':Y ......... ::"T::-='T:T:T~'-SURFACE LOCATION IS .SEC 18 ,'. ............ ~:--~~~ARCO _:ALASKA INC. ~ ~ .... r-~ ..... ~-.~ ....... ~ ................... ~ ......... =.-6~8 NSL~ TZ5 WEL~ T I0 N, R 15 E,U.M. ,:~--~...~=~WELL 1~-9 ., ............. ~ ...... ~-:---:-~ ..... ............ +'-~ ............... : ..... ~ .......... ~- ..... ~ ..... ~': ..... ~ ...... ~ ......... :-:*'i ...... ~ ....... ~ .... f ...... :-~':'.*'GYROSCOPIC sURVEY · : ........ : ................ ~.~ ....... ~ ~-:*. ~--; ....... ~: .... ',..~ .-*..~ ..... ...... ~.~?; ...... :---~--=~ ...... :*~ .......... ~ ....~-..~..RADIUS OF CURVATURE ............. · ~:*,~ ......... ; ........... ~--4 ....... ,...~ .... ~-~- ...... : ....... ~ ......... ' ....... ~--~.---:--~-.~'-.-~ ......... :.~:,~,~ .... ~ ~ -. ~vv .~ ...... ~.~ .... .*-~ Check Form for timely compliance with our regulations. Operator, We-i 1 Name and Number Reports and Materials to be received by: Completion Report Required Date Received Wel 1 History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data Yes Yes 7--- Remarks 6 ARCO Alaska, Inc. ~ Post Office~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 MaY 29, 1981 Mr. Hoyle Hamilton State of Alaska Oil & Gas Conservation Commission 300 Porcupine Drive Anchorage, Alaska 99501 Re: Core Summary - ARCO Drill Site i2-9 Dear Mr. Hamilton: Enclosed please find the Core Summary for ARCO Drill Site 12-9 core 1-9 (8905.0'-9369.0'), submitted as Item #36 on Form P'7 for the above mentioned well. Please sign and return one copy of the enclosed transmittal. Very truly yours, District Explorationist RWC :JBM:dvh Enclosures ARCO Alaska, inc, is a subsidiary of AtlanticRichfietdCompany RECEIVED JUN .. 1 1981 Alaska Oil & Gas COns. C°rn~ission AnChorage CORE # 1 7 8 8905°0'-8929.0" 8929.0'-8989.0' 8989.0'-9049.0' 9049.0'-9109.0' 9109.0'-9169.0' 9169.0'-9228.0' 9228.0'-9265°0' 9265.0'-9309.0' 9309.0'-9369o0' ARCo Drill Site 12-9 CORE SUMMARY · CUT/RECOVEnY 24'/24' 60'/60' 60'/60' 60'/60' 60'/60' 59'/59' 37'/37' 44'/41' 60'/60' 100% loo% loo% lOO% loo% lOO% lOO% 93% lOO% LITHOLOGY SHAt,F, SANDSTN/SH~ r ,~./LIMF_STN SANDST~/L~TN/SH~r,~. S~~ S~S~ S~S~ S~S~/P~BLY S~S~ PEBBLY S~/CONG~S~S~ S~S~/P~BLY S~/CONG~M POROSITY POOR FAIR-POOR GOOD-VERY GOOD VERY GOOD GOOD-VERY GOOD GOOD-FAIR 0 VERY GOOD VERY GOO~C~D ARCO Alaska, Inc. Post Office ~ 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 13, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 5-1 DS 5-10 DS 9-18 DS 12-9 DS 14-18 DS 16-5 DS 16-6 Dear Sir: Enclosed please find' · · · · Sincerely, P. A. VanDusen District Drilling Engineer PAV/KJG:sp Enclosures DS 16,13 B-2 C-7 C-8 T-3C CONFIDENTIAL W. Sak #18 CONFIDENTIAL The Completion Report for DS 16-5. The Completion Reports and Gyroscopic Surveys for C-7, W. Sak#18& T-3C. (Please note that W. Sak #18 & T-3C are to be considered confidential). The Monthly Reports of Drilling & Workover Operations for DS 5-1, DS 14-18, DS 12-9, DS 16-6, DS 16-13, B-2 & C-8. The Subsequent Sundry Notices for DS 5-10 and DS 9-18. ~~ STATE Or: ALASKA ' ALASK/ ~LAND GAS CONSERVATION C ~!tMISSION MONTHLY' REPORT DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, ]:nc. 80-93 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 995]0 50029-20505 4. Location of Well at surface 9. Unit or Lease Name Prudhoe Bay Unit 648'N & 725'W of SE cr Sec 18, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. 71' RKB I ADL 28330 10. Well No. DS 12-9 11. Field and Pool Prudhoe Bay Field Prudhoe 0il Pool For the Month of April ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded we]]@ ]930 hfs, 3/28/81. Cut core #9 to 9369', as of 4/30/81. (See attached Drilling History). 13. Casing or liner run and quantities of cement, results of pressure tests 20" conductor to 80'. Cmtd w/300 sx Permafrost. 13-3/8" csg w/shoe e 2609'. Cmtd w/2500 sx Fondu & 400 sx Permafrost II. 9-5/8" csg w/shoe @ 8828'. Cmtd w/500 sx Class G. (See attached Drilling tiistory). 14. Coring resume and brief description Cut 9 cores f/8850'-9369'. 15. Logs run and depth where run None to date. 1 6. DST data, perforating data, shows of H2S, miscellaneous data n/a 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED_. ,~~' ~~ TITLE Dist. Drilling Engineer NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 DS 12-9 Drilling History Spudded well @ 1930 hrs, 3/28/81. Ran 64 its 13-3/8" 72# L-80 csg w/shoe @ 2609'. Cmtd csg w/2500 sx Fondu and 400 sx Permafrost II. Instld 13-3/8" pkoff & tstd to 2000 psi.- ok. NU BOPE & tstd to 5000 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 12.5 ppg EMW. Drld 12¼" hole to 8839'. Ran multishot. Ran SP/DIL/GR. Ran 215 jts 9-5/8" 47# L-80 & S00-95 csg w/shoe @ 8828'. Cmtd csg w/500 sx Class G. ~Instld 9-5/8" pkoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi f/15 min - ok. Ran Gyro. Changed over to oil base mud. Drld FC, cmt, FS & 10' new form to 8850'. Tstd form to 12.5 ppg EMW - ok. Cut 9 cores fr/8850- 9369', as of 4/30/81. ARCO Oil and Gas r'~.7[mpany North Alask ~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer April 30, 1981 Reference: ARCO Directional Surveys D. S. 12'g,/" 4/22/81 D.S. 16-4/ 3/19/81 D.S. 16-.~/ 4/12/81 D.S. 16_12/ , 3/30/81 D.S.12-2V~ 3/7/81 4/9/81 D.S.16-8J Z~/27/81 D.S.13-12J 2/21/81 D.S. 13-3~ 3-8,9,10-81 D.S.16-9~/ 3/17/81 D.S. 16-1{ 4/11/81 .... Single-Shot .. Single-Shot _- Single-Shot Single-Shot Gyroscopic Multi-Shot Gyroscopic Gyroscopic Gyroscopic Gyroscopic Gyroscopic Job No. AL 381 D6 Job No. A381D0262 - . Job No. A381D0285 Job No. A381D0273 Boss-16759 Run #1 Job No. MS-16781 Boss-16752 Boss-16751 Run #3 Job No. A381G0278 Boss-16767 Run #1 Job No. A481G0309 ~~Pl~se sign and return the attached copy as receipt of data. Mary F.. Kellis North Engineering Transmittal #237 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG, MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETT~ ~" -. IV SOHIO MAY- 1981 MARATHON '._Alaska 0ii & Gas Cons. Commission A~(~horage CHEVRON ARCO Oil and Gas Company is a Division of AtlanlicRichfieldCompany ARCO Alaska, In '~ Post Office:, ~fox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 30, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUbject: DS 4-13 DS 16-4 DS 4-15 DS 16-5 DS 12-6 DS 16-12 DS 9-18 / West Sak 18 'Confidential DS 12-9 ~a~¢~ West Sak 20 COnfidential T-3C Confi denti al Dear Sir' Enclosed please find' 1. The Sundry Notices of intent for DS 4-13 & DS 4-15. 2. The subsequent Sundry Notice for DS 12-6. 3. The monthly reports of Drilling Operations for DS 9-18, DS 12-9, DS .16-4, DS 16-5, DS 16-12, West Sak 18, West Sak 20 and T-3C. Please note that West Sak 18, West Sak 20 and T-3C are considered CONFIDENTIAL. Sincerely, P. A. VanDusen District Drilling Engineer PAV/KJG:sp RECEIVED Attachments MAY - 1 1981 Alaska Oil & Gas Cons. Commission Anchorage ARCO A~aska. h'~¢: ~¢ ~ ~'Jt~bs~diar¥ 'if /',tJ;lnti(:Ri,'hfi¢.fdC(?r'~pr~ny STATE rot': ALASKA ALASK/ ])IL AND GAS CONSERVATION C .~,IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 80-93 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of Well at surface 648'N & 725'W of SE cr Sec 18, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 71' RKB 6. Lease Designation and Serial No. ADL 28330 For the Month of March ,19 81 8. APl Number so-029-20505 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. DS 12-9 11. Field and Pool Prudhoe Bay Unit Prudhoe 0Il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1930 hrs, 3/28/81. Drld 17½" hole to 2620', as of 3/31/81. (See attached Drilling History). 13. Casing or liner run and quantities of cement, results of pressure tests 20", 94#, H-40 conductor to 110' Cmtd w/300 sx Arctic Set. 13-3/8", 72#, L-80 csg w/shoe @ ~609'. Cmtd w/2500 sx Fondu & 400 sx Permafrost II. (See attaChed Drilling History). 14. Coring resume and brief description None 15. Logs run and depth where run None to date .16. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1 -~0 ....... DS 12-9 DRILLING HISTORY Spudded well @ 1930 h+~-s, 3/28/81. Drld 17½" hole to 2620'. Ran 64 jts 13-3/8", 72#' L-80 csg w/shoe @ 2609'. Cmtd csg w/2500 sx Fondu & 400 sx permafrost II, as of 3/31/81. ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle ~. Hamilton Chairman Thru: Lonnie C. Smith ~]J~ Commissioner Bobby Foster '~'"'~'~' Petroleum Inspector April 6, 1981 Witness BOPE Test on ARCO'$ D.S. 12-9 Sec. 18, T10N, R15E, UPM Permit #80-93. Wednesday~.Apri!_!,~ ~.198_$: After witnessing the meter proving at ARCO'S C.O.T. plant I went to ARCO'S D.S. 12-9 to witness the upcoming BOPE test. The test began at 11:15 am and was concluded at 3{45 pm. As the attached BOPE report shows there were 3 failures. The door gasket on the upper pipe rams and a flange on the choke line leaked. Both were repaired and retested The other failure .was the BOPE control unit on the rig floor. This is being repa~ed and A.O.G.C.C. will be notified. The choke line on this rig has treaded connections in it. I informed Kelly' ~ff, ARCO drilling foreman and Pete Raypold, Parker tool pusher that this did not meet API standards and must be corrected before the next BOPE test witnessed by a A.O.G.C.C. inspector. In summary, I witnessed the BOPE test on ARCO'S D.S. 12-9. Attachment: Tuesday April 7, 1981: I contacted Pete Raypold this am and he ~nf°rmed ~ .... ~hat t~-' accumulator control panel on the rig floor ha~d. been repaired and was operating properly. BF .mm 4/~o STATE OF' q' ' A!,A. kA ALASKA OIL, & GAS CO?,JSI.']RVATIO?,: COt'lt'l~_o ION B.O.P.E. Tnspection Report Location: Sec /8 Drilling Contractor Location, General --~--~ , General Housekeepzng Rig ~L BOPE Stack Annular Preventer ig Test Pres sure / Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: }Full Charge Pressure~C)C) psig Pressure After Closure/~.~_ ? ~.~ psig 200 psig Above Precharge Attained: -- rain// Full Charge Pressure Attained:. Z min f> ., . ~"~ 0 ps ig Controls: Master~~ .... -._?.f?,_P=~k~-. B.,_.~inds switch cove~ KellZ and Floor Safety Valves Upper Kelly / Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure ide ~D o. o 0 't~hoke ~aO0 ~ NO. Valves / ~OO ~ NO. flanges ~ ~Adjustable Chokes Failures ~ .. BOP / Test Pressure Manifold ~ Test Pressure~OrOO / Test-Time ~/~ hrs.. R&pai'r or Replacement of failed equipment to be made within x_~ days and Inspector/Commission office notified. ". , / ~ ' . t~1~ orig - AO&~C ' February 18~ 1981 Mr. Po A. VanDusen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit DS 12-9 Atlantic Richfield Company Permit No. 80-93 Sur. Loc.: 648'N, 725'W of SE cr Sec 18, T10Nv R15E, UM. Bottomhole Loc.: 1537'N, 1818'W of SE cr Sec 18, T10N, R15E, UM. Dear Mr. VanDusen: Enclosed is the approved revised application for ~rmit to drill the above referenced well. The provisions of the cover letter, dated November 24, 1980, accompanying the original approved permit are in effect for this revi sion. Since the well has not been spudded an additional fee of $100.00 is not required. We will hold this check (No. 203030) for the new "12" pad as per your phone conversation with John Levorsen on February 13, 1981. Very truly yours, Hoyl~ H. ~amilton Chairman of ~'~ ~%E~2~ ~ ~L~ CC2~i~.~C~©N Alaska 0il & Gas Conservation Commission Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. }!I~H: be ARCO Oil and Gas C yany North Slope D ~'ict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 2, 1981 Mr. Hoyle Hamil ton State of Alaska Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Drill Site 12-9, Permit to Drill Dear Sir: Enclosed is an Application for a Permit to Drill the subject well. This well was previously permitted under Permit No. 80-93 to a different bottomhole location. A plat of the proposed well path and a drawing and description of the sur- face hole diverter system and BOP equipment are enclosed. There are no other wells within 200' of the proposed well. If you have any questions regarding this application, please contact Mr. Michael Morris at 263-4273. Sincerely, P. A. VanDusen District Drilling Engineer PAV/MAM:sp Enclosures ARCO Oil and Gas Company is a Division of AtlantlcRichlieldCompany REEEIYED FEB 1 0 198I Alaska Oil & .Gas Cotts. Cotg~l~jort ~chorage PERMIT TO DRILL 2O AAC 25.005 la. TYpe of work. DRILL ~] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC []. REDRILL [] DEVELOPMENT OILI-X SINGLE ZONE [~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator At]antic Richfield Company RECEIVED 3. Address - P.O. Box 360, Anchorage, Alaska 99510 c~m. ^ 4. Location C;'f well at surface ! L 1.7 J. U l~Ol 9. Unit or lease name 648'N & 725'W of SE cr Sec 18, T10N, R15E,A~a~0il&GasC0ns. C01,,,~J2~udhoe Bay Unit ... At top of proposed producing intervalA~ch0rage "I~0Y~Ie~Illl number - . 1165'N & 1361'W of SE cr Sec 18, TION, R15E, UM Drill Site 12-9 . At total depth 11 Field and pool 1537'N & 1818'W of SE cr Sec 18, T10N, R15E, UM Prudhoe:Bay Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation' and serial no. Prudhoe 0i 1 Pool 71' RKBI ADL 28330 12. Bond information (see 20 AAC 25.025) Federal Insurance Co. Type Statewide Surety and/or number#8011-38-40 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling Or'completed Approx 1 mi NE of Deadhow~,A~ .3919 feet 'well 247.8 ,, feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 9543'TVD, 9863'MD feet 2512 March 1, 1981 19. If deviated (see 20 AA• 25.050) 120. Anticipated pressures ~l~l psig@ Surface .. KICK OFF POINT6800feet. MAXIMUM HOLE ANGLE31°l (see 20 AAC 25.035 (c) (2)465'opsig@ .95Z[3 ft. TD (TVD) r . 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITy OF CEMENT ' ' Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 32 20" 94# H-40 I{elded 80' 0 10 80 ~180 300sx Permafrost. 17~ 13-3/8': 72# N-80 ~uttress 2700' 0 i0 2700 12700 2300sx Fondu, ~OOsX P.e 12¼ 9-5/8" 47# L-80 luttress 8853 0 ,~0 8853 18677 Class G 500sx 1st st~ S00-95 ' ~ ] 2nd stage 8½ 7" 29# . L'-80 ~uttress 1310 8553 ~,8420 9863 'lI 9543 250 sx Class G, 22. Descri'be proposed program: . Atlantic Richfield Co. proposes to directionally drill this well to 9863'MD (9543'TVD). The Sadlerochit will be cored to the oil-water contact with oil-based mud. Logs will' -66 run across S-~l-~e--EF-i-6~6rvals. A 20" diverter will 66' used ~h-~'T~-"-~-~i-ling the sur- face hole. A 13-5/8" 5000 psi RSRRA BOP stack will be used after setting 13-3/8" casing. It will be operationally tested each trip and pressure tested weekly. A string of 5½" 17# L-80 tubing with packer and provisions for subsurface safety equipment will be run. A non-freezing liquid will be left in all uncemented annuli within the permafrost interval. .. 23. I here6¥ certify that t~~rect to the best of my knowledge The space I~elow fo~ C~omm}ssion use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required ! APl number DYES ~NO DYES ~'NO J~YES •NO[ 50-- O ;~?- ~..0 Permit number Approval date ~0- ~-~ //b/o~, ~/ / ~ ~0 I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY. ,COMMISSIONER DATE ]~lPJmmmr!z' liB.. 1981 ___ by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 ! i ! i SECTION 7'10 N, RI6E, U.M. 19 I HFPrRY FrpTIFY THAT I PPQPEF'I !' r~rGI~TEP, EP A,NF, L IFFNSFn TO PP,'"Tlrr I_A*~D SL~PwFYING THE S, IATE pr ALASKA A,,~ THAT THI~ PLAT ~FP~r¢FHTq ~*t R!'ILT StI~wrv ~.,Anr ov ,.~r AND THA3 ALI nlt, FNSIO~n A~,r) ~T~FP DETAIL5 Apr ~pr~: AS hATE. ::11 17 20 AtlanticRiChfieldCompany {) "' : NORTH AMERICAN PRODUCING DIVISION ~0 ALASKA DISTRICT -- PRUDHOE BAY ,, i ii W£/L5 ~t, I0 & II. CONDUCTOR Y = 5,gB,.Q, .~60.93 ' / .... O:-, . t, -- 6~p) , / .'~. LAT 7nc'1 '~':,6 1 '~'' LO~ - 148('2L, ' 1,2.-''' ~: '.~1 o8o x = 696, 867.7n LAT -- 70(')12 '57. '~0 LONG = 148°2/4' 42.q~(," Y = 5 931 iqq c)o ~ ~ ~ ,../ · . × = 696,855.96 LA1' = /0°12'58.481'' LONG = 148°24'43.237'' RECEIVED FEB 1 0 1981 Alaska Oil & Gas Cons. CommisSion Anchorage 4s-gU/L7:s' DRAWING No: RNNULRR PREVENTER BLIND:'RRMS PIPE RRMS SPOOL 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulatOr pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultan- eously and record the time and pressure re- maining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure.) PIPE RRMS . 6. RECEIVED 13-5/8" BOP Stack Test FEB 1 0 1981 0ii & Gas Crow,. ~ Fill BOP stack and manifold with a non- freezing liquid. Check that all hold down screws are fully re- tracted. Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws in head. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a 250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. 5. Increase pressure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. O~en annular preventer and close top set of pipe.rams. ~'.' ~. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pressure to zero. 8. Close valves directly upstream of chokes, open top set of pipe rams and chokes, then close bottom set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open .bottom set of pipe rams. ll. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold & lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. . · 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of De Gasser. 16. Record test information on Blowout preventer test form. Sign and send to Drilling Super. 17. Perform complete BOPE test once a week and functional operate BOPE daily. SURFACE DIVERTER SYSTEM !' . Note: Valves on diverter lines open automatically when the annular preventer is closed. L 1. 20" BRADENHEAD 2. 20" 2000 PSI DRILLING SPOOL 3. 20" 2000 PSI ANNULAR PREVENTER 4. 10" BUTTERFLY VALVES 5, RIG DRILLING RISER 6. 10" LIt'lES TO SUMP November 24, 1980 Mr. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Re= Prudhoe Bay Unit DS 12-9 Atlantic Richfield Company Permit No. 80-93 Sur. Loc... 629~N, 724~W of SE cr Sec 1.8, T10N, R15E, UM. BOttomhole ~.= 1320'S, 1345*E of NW cr Sec 20, TION, R15E, UM. Dear Mr. VanDusen= Enclosed is the approved application for permit to drill the above reference~ well. well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50'870 and the regulations promulgated thereunder (Title Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any Waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative.Code, Chapter 70) an~ by the Federat Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Prudhoe Bay Unit DS 12-9 -2- November 24, 1980 co~encing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in schedu!ing field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notifie~ so that a repre- sentative of the commission ma}, be present to wiriness testing of blowout preventer equipment before surface casing shoe is .drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly 'yours, Ho~ H. Hamilton Chairman of BY ORDER OF THE CO~AI$SION Alaska Oil & Gas Conservat£on Commission Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl.~ Department of Labor~ Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and Gas j''~ npany Alaska Region. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 20, 1980 Mr. Hoyle Hamilton Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 Subject: Drill Site 12-9 Permit to Drill Dear Sir: Enclosed is a plat showing the surface location of the subject well and a plat showing the relationship of the proposed wellbore with the wellbores of DS 12-8 and DS 12-8A. These plats did not ac- company the original Application for a Permit to Drill. Please note that the least distance between the subject well and either DS 12-8 or 12-8A is 500 feet. Sincerely, P. A. VanDusen District Drilling Engineer PAV:MAM:cs Enclosures Oil & ~as Cons. Commissio. A~chor~o ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany i ~® eoeeeedeeoeeeeeeeoeeoeetee~oo u, ~. ~! //. ,/j~. ~ GARY A. CRENSHAW ~ ~ PpOPFr't ,' prql .TFPEF: ANr, f_ IFFNKF" T': P,".'r Tl"r l.;.';D %l. lP~FVlf, ic: 'rtq~ c~'A. TF r,r A[AqKA A TH/,'" T c D ~ T D F I~' t- c F I~P c ~ ~ , c .HI.~ , I/' ~ P . ,T ...... THA'f ALt nlP-'F';sIr'~!C /,~,r~ ' DATE: ' lT. I = r. ",'.?~1. 0P, O. x --- .696, 867.7 ~ ,, ~. ..~ L..q7 = 7n°12'57.~,0r'' ' ..:]] Y = 5,931,199.90 } = 696 855. LAT = ?0°12'58.481" I q,. LONB = 1 ~8°2L~' ~7,. ...__..__. ,18 117 T/O N, RISE U.M. 19 20 & ,~,:~ boris. Commission I I I IIII -0.5.12 WELLS q, lfl ll, CON PUCTOR AS-£LIILT5 IIII ilJl i! AtlanticRiChfieldCompany {) DATE: DRAWING No: NORTH AMERICAN PRODUCING DIVISION t~oq..~O ALASKA DISTRICT- PRUDHOE BAY II ARCO Oil and Gas ~tpany Alaska Distr,' , Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 29, 1980 Hoyl e Hami 1 ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501' Subject: DS 12-9 Permit to Drill Dear Sir' Enclosed please find the Application for Permit to Drill DS 12-9 and the required $100.00 filing fee. Attached to the application are' A drawing 'of the proposed well path, a drawing and description of the surface hole diverter system, and a drawing and description of the BOP equipment including anticipated pressures. There are no other wells within 200' of the proposed well. Please note that the given surface location is approximate. Once the conductor has been set, a certified survey plat will be sent showing the as-built surface location. Very truly yours, P.A. VanDusen District Drilling Engineer PAV/DEB:mtb Enclosures A~qCO Oil and Gas Cornp.~r~y is Form 10-~01: REV. 1-1-71 SUBMIT IN ~. ~,ICATE ~i (Other ~itructions on STATE OF ALASKA OIL AND GAS CONSERVATION CO~:i~~ !~, PERMIT TO DRILL OI:k~EEEEN ~i~ ,~, ~u~,,:ni~sic,, ._ DEEPEN ["-] la. TYPE OF WORK DRILL ~r~ b. TYPE OF WELL WELL ['--I 2. NAME OF OPERATOR SINGLE MULTIPLE OTHER ZONE [~ ZONE Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4.LOCATIONAtsuffaceOF(surfacewELL location approx.-to be corrected later.) 629'N & 724'W of S5 cr Sec 18, T10N, ~R15E, UM At proposed prod. zone (@8800'SS) 1320'S & 1345'E of NW cr Sec 20,TION~ R15E~UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE*. . Approximately 1 mile' NE of Deadhorse, Alask~ 14. BOND INFORMATION: aPI #50-029-20505 6. LEASE DESIGNATION AND SERIAL NO. ADL 28330 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 12-9 (xx-20-10-15) 10. FIELD AND POOL, OR WILDCAT prUdhoe Bay Field/Prudhoe.Oi ii. SEC., T., R., M., (BOTTOM Pool .OrE OBJECTIVE) Sec 20~ TION~ R15E~ UM 12. ~ WE Statewide Surety and/or No. Federal Insurance Co. #8011-38-40 ~u-nount $100,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 3935' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2429' 16. No. OF ACRES IN LEASE 2512' 19. PROPOSED DEPTH ' 9629'TVD 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 74' RKB, 40' Pad Elevation (Gravel) 23. PROPOSED CASING AND CEMENTING PROGRAM 17.. NO,ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START September 24~ 1980 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SE'I'rING DEPTH ~ , · Quantity of cement 32" 20" 94# ~ H-40 llO'MD ~ 300 sx Permafrost to surface 17-1/2" 13-3/8" 72# L-80 2700'MD 2300 sx Fondu & 400sx Permafrost !_~-!/4" 9-5/R" 47# Rflgq.~ 10fi??'MD 5fl0'.gx on l~t ~tage & 300 gx on 2nd st age Atlantic Richfield Co. proposes to directionaily drill this well to +iUbZZ'MU (_+~6Z~')vU) to produce the Sadlerochit zone. Logs will be run across selected i-6tervals. A 13-5/8" 5000 psi RSRRA BOP stack will be used. It will be pressure tested each week and operationally tested each trip. A string of 5-1/2" 17# L-80 tubing, packer & necessary provisions for subsurface safety equipment will be run. A non-freezing liqu.,id will be left in all un~emented annul i within the permafrost interval. Selected intervals within the Sadlerochit zone will be perforated. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized on all wireline work. Well will be flowed to production facilities during perforatin~ and testing. The downhole safety valve will be installed a,n,d tested upon conclusion of job. A 20" diverter will be used during drilling of the 17-1/2 hole. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionaUy, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I here~ that DATE,Je"Pr' $., ~O (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED DIRECTIONAL SURVEY REQUIRED [] NO CONDITIONS OF APPROVAL, IF ANY: IMUD LOC, [] YES ~o OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE 3'0 .... o ~?- ~ o3-o3- PERMIT NO. FO ._ ~i'.,~ APPROVAL DATE APPOVED BY ~~~ ,TITLE Chairman BY .ORDER O~THE cOMMISSION *See Instruction On Reverse Side November 2~, 1980 DATE 11/24/80 -1-- .. RNNULRR PREVENTOR .. 13-5/8' BOP STACK DIAGRAM Accumulator Cap..acity Test ~;[nmiS~eck and fill accumulator reservoir to proper level with hydraulic fluid. , Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. BLIND RRHS , Observe time,then close all units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. - 4. Record on IADC report. {The acceptable lower limit is 45 seconds closing-time and 1100 psi remaining pressure.) P'I PE RRHS 13-5/8" BOP STACK TEST Fill BOP stack and manifold with Arctic Diesel or Calcium Chloride Solution, SPOOL e Check that all hold down screws are fully retracted. Predetermine depth plug.will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws in head. PIPE RRHS me Close annular preventer and chokes and bypass valves on manifold. Test all components to 250 psi and. hold for 10 minutes. Bt Increase pressure to 3000 p'si and hold for 10 minutes. Bleed pressure to 500 psi. ,~;/O./~.~-Maximum anticipated bottom hole pressure. _.~O~£-Maximum preesure' to which BOP's could be subjected. Calculated by allowing a gas bubble at reservoir pressure to rise without expanding but cooling to 80°F. 6~ . t Close top set of pipe rams and open annular preventer. Increase. pressure to 5000 psi and hold for 10 minutes. Bleed pressure to 500 psi. Close bottom set of pipe rams and valves directly upstream of chokes, then open top set of pipe rams and'chokes. Increase pressure to 5000 psi and hold for 10 minutes. Test' remaining un'tested manifold valves(if any) with 5000 psi upstream of 'valve and zero pressure downstream. 10. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for 10 min. 11. Bleed pressure off all equipment open bottom- preventer. Make sure manifold & lines are full of Arctic Diesel and all valves are set in drilling position. 12. Test standpipe valves to 5000 psi. 13. Test Kelly cocks .and inside BOP to 5000 psi with Koomey pump. .14. ~ Check operation of De Gasser. 15. Record test information on Blowout preventer test form. Sign and send to Drilling SuPervisor. 16. Perform complete BOPE test once a week and functional operate BOPE daily. SURFACE DIVERTER SYSTEM ,® .® Note' Valves on diverter lines open automatically when the annular preventer is closed. 1. 20" BRADENHEAD 2. 20" 2000 PSI DRILLING SPOOL 3. 20" 2000 PSi ANNULAR PREVENTER 4. 10" BUTTERFLY VALVES 5.. RIG DRILLING RISER 6. 10'! LINES TO SUMP rrl CHECK LIST FOR NEW ~LL PERMITS Item App,. ove (1) Fee / / (3) /~lmin. Date Yes No 7..-!o~'.t 1. Is the permit fee attached .......................................... ~ -- ~ Is well to be located in a defined pool ......... / , 3. Is a registered survey plat attached ................................ ~/~ 4. Is well located proper distance frcm property line .................. ~. Is well located proper distance frc]n other wells .................... / 6. Is sufficient undedicated acrea~ axrailable in this pool ........... 7. Is mll to be dev±atecl .............................................. 8. Is operator the only affected party ................................. ~/~ O. Can permit be approved Before ten-day .wait .......................... .................................. 11. Is a conservation order needed ................ (4) Casg. ~ ~,/,,!~I ~k.' 12. Is administrative approval needed ......................... ~ ....... ~ 13. Is conductor string provided ........................................ ~ 14. Is enough cement used to circulate on conductor and surface ......... 15. Will cement tie in surfaCe and intermediate or production strings 16. Will cement cover all known productive horizons ...... , .............. 17. Will surface casing protect fresh water zones ....................... ~ Additional Requirements: 18. Will all casing give adequate safety in collapse, tension and burst. 19. Does BOPE have sufficient pressure rating - Test to ~-o~ .. psig . Approval Reccmmanded: Lease & ~ii ~. ?~ U~ Remarks Geology: Engine~_ring: HWK '~-"'---- LCs ~_~ BEW / rev: 03/05/80 (1) Fee CHECK LIST FOR NEW WELL PERMITS Approve / (2) Loc./~/.--- (3) kimin. ~ / (4) Casg.~ Date '~" ~ Yes No ~-~_<~ 1. Is the permit fee attached .......................................... 7~__. -- 2. Is well to be located in a defined pool ............................ 3. Is a registered survey plat attached ................................ 4. Is well located proper distance frcm property line ................ .~/ 5. Is well located proper distance frcm other wells .................. ( 5 ) BOPE ~_,~ 6. Is sufficient undedicated acreage available: ~i.~ po~l 'i"i ...... 7. Is well to be deviated ................................. 8. Is operator the only affected party ......... 9. Can permit be approv~ befOre ten-day wait ......................... 4-~" 10 Does operator have a bond in force ........ ~' 11. Is a conservation order needed ...................................... Additional Requirements: 12. Is administrative approval needed ................................... 13. Is conductor string provided ................................ 14 Is enough cement used to circulate on c~nductor and'L~e 15. Will cement tie in surface and intermediate or production strings ... ~_ 16. Will cement cover all known productive horizons ..................... 17. Will surface casing protect fresh water zones ....................... ~ 18. Will all casing give adequate safety in collapSe, tension and burst~ __ 19. Does BOPE have sufficient pressure rating- Test to ~6)~ · Approval Reccmmended: psig . .~ ' Lease & Well No. Remarks Geology: Engine,?rin9: . rev: ~3105/80 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. .o LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Alaska, Inc. Well DS 12-9 Field Prudhoe Bay County, State North Slope, Alaska Date 7/30/82 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale GR4 Gamma Ray Pass 4 DDNLL 0-100 MON4 Monitor Pass 4 DDNLL 0-120 Gl4 Gate One Pass 4 DDNLL 0-7.5 G24 Gate Two Pass 4 DDNLL 0-12.5 NL4 Sigma Pass 4 DDNLL 60-0 RAT4 Ratio Pass 4 DDNLL 11-1 GR5 Gamma Ray . Pass 5 .DDNLL . 0-100 MON5 Monitor Pass 5 DDNLL 0-120 Gl5 Gate One Pass 5 DDNLL 0-7.5 ! G25 Gate Two Pass 5 DDNLL 0-12.5 . NL5 Sigma Pass 5 DDNLL 60-0 , , , RAT5 Ratio PaSs 5 DDNLL 11-1 ,, , NLAV Sigma Average 60-0 ! , LIBILARY TAPE · CURVE SPECIFICATIONS C Oll~p arAy Arco Alask___a, inq,: ~%'ell DS 12-9 Field Prudhoe Bay gounty,State North Slope, Alaska Date 7/30/82 Curve Name (Abbreviated) Standard Curve Name 1 GR1 tGamma Ray Pass MON1 IMonitor Pass 1 Gll /Gate One Pass G21 Gate 2 Pass 1 NLI Sigma Pass I k~7l Ratio Pass l GR2 Gamma Ray Pass 2 MO×2 Monitor Pass 2 Gl2 Gate One Pass 2 G~2 ×L2 RAT2 GR5 Gate Two Pass 2 Si,gma Pass 2 Ratio Pass 2 Gamma Ray Pass MON3 Monitor Pass 3 · Gl3 Gate One Pass G25 Gate Two Pass NL5 KAT3 Sigma Pass Ratio Pass 3 Logs. Used DDNLL DDNLL DDNLL DDNLL' DD×LL DDNLL DDNLL DDNLL DDNLL. DDNLL DDNLL DDNLL DDNLL DDNLL DDNLL DDNLL DDNLL DDNLL : Scale 0-100 0-120 0-7.5 0-10 60-0 31-1 0-100 0-120 · 0-7.5 ,, 0-10 60-0 11-1 · . 0-100 0-120 0-7 5 0-10 60-0 11-1 Company Well LIBRARY TAPE CURVE SPECIFICATIONS ARCO ALASKA, INC. D. S. 12-9 Field PRUDHOE BAY County, State N. SLOPE, ALASKA Date 7-29-82 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale · . MON1 Monitor Curve Pass 1 C/O 0 - 1 MON2 " " " 2 " " MON3 " " " 3 " " MON4 " " " 4 " " ., MON5 " " " 5 " " MON6 " " " 6 " " ,,, SI1 Silicon Curve Pass 1 " " SI2 " " " 2 " " SI3 " " " 3 " " , ,, SI4 " " " 4 " " SI5 " " " 5 " " SI6 " " "6 " " , , CO1 Carbon Oxygen Ratio Pass i " i - 2 ., C02 " " " " 2 " " C03 " " " " 3 " " C04 " " " " 4 " " C05 " " " " 5 " " CO6 " " " " 6 " " , Company Well LIBRARY TAPE CURVE SPECIFICATIONS ARCO ALASKA, INC. D. S. 12-9 Field PRUDHOE BAY County, State N. SLOPE, ALASKA Date 7-29-82 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale SIC1 · Silicon-Calcium Inelastic Pass 1 C/O .9 - 1.9 SIC2 " " " " 2 " " SIC3 " " " " 3 " " SIC4 " " " " 4 " " SIC5 · . " " " " 5 " " SIC6 " " " " 6 " " CASl Calcium Silicon CaPture Pass 1 " .5 - 1 CAS2 " " " " 2 " " , , CAS3 " " " " 3 " " CAS4 " " " " 4 " " CAS5 " " " " 5 " " CAS6 " " " "' 6 " " , , , CI1 Capture/Inelastic Ratio Pass 1 " .125 - .375 CI2 " " " " 2 " " CI3 " " " " 3 " " CI4 " " " " 4 " " CI5 " " " " 5 " " ,, CI6 " " " " 6 " " SWCO Water Saturation From C/O " 100 - 0 PAGE ARCO ALASKA INC. L__._DEP_TH ............ ~.G_~t ........... NI.1 ................ NL2 ..... ;......NL3 ...... L...._NL.~._ ............. NL5 .......... NLAV......NLLQ_NLEII--.H.ILD-D_)FL ..... F_T ......... AP ! ...... _P_/~__P_ASS2_~_.~_ P AsS~._P_ASS5 N, 5 ]. ;58 8795, ~7 7 8797 8799 8801 8803 8805 8807 ~ 5 8817 6~ ~ 38 5 36 95 3 8829. 105.8 ~5~ 0 PAGE 6 4,6 PAGE ARCO ALASKA INC, D_,_S_,__12 ~_Q £ ........................... D_.A_T_E__..L_.G~.G.F~D;__ZZ..3..O_XS.a ............. DATE_..COMP.UIED ......... DEPI H ......... GS1 ............. NL1 ..................... NL~ ........... N.L3 ........... NL.~ NL5 ..... NI.A V._ Nt L 0.. NLHI. _. H ILO..._..O..I_~L ...... EI ....................... APl_ ......... PAS_S1 .... P.ASS2_PA.S$_.3~__PASSa __PASS5 8887. 96 7 ~ 7 ~ 889 92, 3 ~, 8893, 95 5 ~5 8895 8 g6 7 g6 ~897 8899, 97 8901, 100,2 8903 8905, 9~ 8907, 103 6 ~5 7 ~5 1 ~fi 0 ~2 8909 102 7 ~5 6 ~ 9 ~ 2 ~3 8911 7 ~6 2 ~6 6 ~3 2 ~ ~ ~4 8913. 102,9 ~,9 q3,3 ~6 7 ~5 M ~ 891~ 6 ~ 8917 10~ 5 ~5 6 ~3 7 ~2 8 8923 0 27 6 32. 927. 139 9 25 6 20 ARCO ALASKA INC, D__,_$ ...... _D_A_I E___kO_~.~EL D___:_.T~/_ 30.Z 82 ..... ...... D.£RTH ................ G. B1 ............ NL1 ................ NL2 ....... ~_T .................. A_P__I ....... P_ASS~___PA,SS2._,.RAS .......... B.~.~_.O.,,._ .............. 6_~_..~ ............ ~.0_._,1 ........... ................ B..~_,~l,_, .......... 5.._7__.5. ............ 21....0 ............. 19..9 .................. a9..~..2,. ............... 5.,~.,.8 .............. 21,1 ................ :~.Q,._O 8 21 8<967 PAGE ARCO ALASKA INC. D__.$_. .... DE_P....TH ............... ._G__R1 ............... Nkl .................. NL2 .......... N.L_~_ ........... NL.~ .............. NL5 ........... NLAV___ NLL0...._NLHI_ .... ET_ ..................... AP_I_ ....... PA~S1....P.A~S2_PAS~__PA~S~__P-A$S _; ............ 8..P8.._0._,_!..~..!._.,..~ .............. D_D..,,.7 ..... .3_2...~ ...... 3.1..,...._3.. ........... _.3...!_.....6: ........ Di,~2,_. ............ ~_._9_..8.L,. ........ e_2_A.._-..!. ........... .~..6,__7 ........... _e_.8_,_.8 .......... 2_~_.,_.~ ............ 2.5.._._.~ ............. 25.,..0__.2.6. .... L ........... .~..~82..,_...g..5.~_,.8.._2D_,.....Q ............. 8...3.....,...~. ................ e..~.,1 ............. ~..,..~ ............. e;~....6... 898 eq. 8 8 22,;5 22 8985, 8987, 13~ 8 23 2 22 8 2~ 167 993 131 9 31 8995, 121 3 32 1 32 1 31 8997, 105 8999 9001, i22,5 2 9003 9005 9007 9009 2 14 9011 1 15 3 15 1 1~ 9013 PAGE 6 ARCO ALASKA INC. .ID_, S_,_ 12--9_ D_A_T E ..LO_G._GE D_:_7_ ./~.0.Z_62 ....... DAT_E__ C O~_~P ......... DEPTH .............. G~i ............... NL1 .............. NL2 .................. NL-3 ............. ....... .F._T_ .............. A_P_I ..... ~_~ A S $ 2-.-P-XLS-SS-P-A~-.--PA$S5 .............. 90..D.O_, .............. ~..~_,1 ............ .1..6.~7. ............. 16.o..,9_ ......... 1.~.,_q,........ ........ _1._6 ................. .gO.~l,. ......... 2,_7.._,_0 ........... 1.5_,.._5.. ........... 16,.0_ ............ l_7_,.D .......... _: .................. 9..0_3_2., ............. 2_D..,J_ ............... 15_,_6 ................. 15.,...~ ................. 15.,9 ............... 15..,..~. 9055, 9057 905 9061 9063 7 17 9 16 ~ 15 6 17 2 17 I 21 9067. 29 0 17 5 16, 8 18 0 18 . 1 17 5 17 9075. 30 1 16 ~ 16 9077 ~ 16 9079. 3%.1 19 2 19 ~ 18 9 18 PAGE ? ARCO ALASKA INC. ......... O E.P,.TH ........... G_B1 .......... NL1 .............. N L2 ........... NL 5 ............. N.L~ .......... N.L5 .... NLAV... NLLO_ ..._ NLHI._.. H I LO._. D-I-FL ..... F~ .................. AP_I_ ....... PASS1._._.PASS2_.._P_AS~S3_PASS_~.._PASS5 ............. ~.0.8_0_, ............ .~.~_.,._7~ ............. 1...9...,...~ ............ 2..Q..,._~ ......... 2. 0..,..8 ............ 2.0.., ~ ............. 20..,~5...2..0_o6.....1.9 ,.5_.. 20..o..9 ............ 1..o...~ ............. 1.,..1 ................. 9_...0_...~.!..., .............. A_8....,...6 .......... !.Z.,..~ .............. .1_8... ,...6 ............. !.9_.,..0. ................ .1.8...,_.~ ............ 17_,.7 .......... 1.~._,,._3....,,..17..,.._.7.....1~.....0 ............. 1,..3 ............... o_,_7. : ....................... 9..~..8..2.., ............... 3.~.,...8 ................ 1.6_,.~ .............. .1.6,..3 ............. 16 ,..~ ............. 16..,..9 .......... 15.o..9 ... 16..,..3_....1.5._.9....._..1.6.., 9_ 1.o .0 ............ 0 °6 4 16, : 25 9099 9103 9105 9107 9109 9111 9113 31 3 17 2 17 6 20 61 6 22 8 2~ 5 23 6 22 2 19 6 19 4 15: 25 9 6 ~ 16 2 PAGE ~RCO ALASKA INC. ]__.A._T.E..__._L_Q~_.G_..C_D___,'...~/_~_.~_ZS.2 ............ QA.T__[...._C.O_M.P~UIED..L9 Z_7_ZB_2 ...... .OEP_TH .................. 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D.E~_TH ............ 6.~.1 ................. NL1 ................... N L2 ............ NL. ~. ............. NL_~ ........... NL_5 ......... NLAV,_ ,NLLO..., NLH I_ .. IdlLO_.DI.~L ............... !.~.8...2_:,_ ........... .2__6_,._.~ ............. !.5._,..~ ......... ...1...5...,..5 ....... 15 ,. 1 ............ 1..~..,...1 .............. 1.5..,.~3. 15..,_ t..1 ~.,..Z....15..,.5 ................. 0.,...~ .............. 0,.6 9282. 27, 2 15 ~+ 15 9287. 30 0 15.8 15, 9 15 5 16 3 15,6 15 929q 9299. 26 9301. 27.6 1 9303. 28.8 9305. 28.9 1~ 9507 5 16 0 15~1 1~ 2 15 9309, 27.0 15.8 15 6 15 8 15, 9311, 27 0 15 6 16 0 15 5 1~ 9 15 9313, aG 8 16,2 15 8 15 9 1~ 9315 7 159 15 9 17 28.1 15.3 15 5.2 15 5 16~ 29 29 6 15 PAGE ARCO ALASKA INC. Q,_ S_,_._..__12 ~.9 ....... DEP_.T.H ............ GB.1 ......... NL.1 ........... NL2 ............ NL3 ........... NL.~ .......... NL-5 ......... [~AV.... NL.LO.--NLHI -..H-ILQ , ............ 9..~..~_0., .............. 8.$.,. ~. ............ 1.6..,...~ ............. 1.6 ,..N ........... 16, .~ ........... 16.,...0 .............. 16,.2..__. 16_,_.3__.16,Q... 16,..~ ........... 0,5 .............. 0-,--3 .................... .~_~..~_1., .............. .~.8...,...~. ............ _16,.6 ........... l_6..,..g. .............. 1..~.,.1 ............ 16_,..~ .............. 16.,6.._16,.6_..16.,.A_._1_7..,1 ................ 1,.0 .............. O~ ................. 9.~.D:2., .................. ~..9_,...1 .................. 16,...~. .............. 16,..~ ................ 16, .~ ........ 16.,...A ............ 15., ..B.-..-16..,.~.....-....15 ..,..8........~6...,.-~- ................ 0..,:.8 .............. 0-,6 ......................................................................... 9367. 26 ! 16 0 16,8 17 ii, 17, 1 15 9 17 9~79. 27 0 19 ,RCO ALASKA INC. ~AT AP 9381 '7 17 2 17 9 3O 0 ~mmmmmmmmmmmmmmmmmmmm~ ~15 TAPE VERIFICATION LISTING ~mmmmmmmmmmmmmmmmmmmm~ ~----$CH~U~BEROER----~ ~mmmmmmmmmmmmmmmmmmmm~ ~Z$ ~APE VERZF~CA?~ON LISTIN~ LVP 009,H03 VERIFICATION LISTING ** REEL HEADER SERVICE NAME DATE ~81! 7/11 ORIGIN ~ REEL NAME CONTINUATION # ~01 PREVIOUS REEL COMMENTS ~ LIS FORMAT CUSTOMER TAPE ** TAPE HEADER ** SERVICE NAME IEDIT DATE ~81/ 7/11 ORIGIN ~ TAPE NAME t62000 CONTINUATION # ~01 PREVIOUS TAPE ~ COMMENTS ~ ** COMMENTS ** TAPE COMMENTS DIL RUN # i, LOGGED 16-APR-81 CASING DRILLER = 13,37 IN. ) 8839 FT. CASING LOGGER = 8707 FT. BIT SIZE = 12.25 IN. FLUID IN THE HOLE = LIGNOSULFATE DENS = 10.10 VISC = 42,00 PH = 10.40 FLUID LOSS = 3.600 ML RM ~ MEAS TEMP. = 1.54 9 65 F. RMF " " m 1 15 9 65 F. RM 9 BHT = '~3 9 147 F. PAGE ~¥P 009.H03 VERIFICATION LISTING PAGE RUN # 2, bOGGED X-MAY-81 CASING DRILLER = 9,625 IN, P 8828X F?, CASING LOGGER = 8827 BIT SIZE 8,50 IN. FbUID ZN THE HOLE = OIL BASE DENS = 9,8 VISC = 56.00 PH = NA FLUID LOSS = 2.4 Nb RM P MEAS TEMP, = NA P NA F. RMF " " ' NA ' NA F' RMC " " = NA ~ NAF' RM ~ BHT = NA ~ NA F. POROSITY MATRIX = SANDSTONE ** FILE HEADER aY FILE NAME IEDZT ,00! SERVICE NAME I VERSION # I DATE I MAXIMUM LENGTH I 1024 FILE TYPE I LVP 009,H03 VERIFICATION LISTING PAGE 3 PREVIOUS FILE { ** INFORMATION RECORDS MNEM CONTENTS CN : ATLANTIC RICHFIELD WN { D,$, 12-9 FN { PRUDHOE BAY RANGI 1SE TOWN{ SECT{ 18 COUN{ ALASKA STATI ALASKA DENS{ 800. ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE 0 DATUM SP MNEM SER DEPT SP IbM SFbU GR GR CALf DRHO NPH! RHOB NRAT NCNb FCNL GR CC). SIZE 1 ECIFICATION BLOCKS VICE SERVICE UNIT AP1 D ORDER # bOG TYPE FT 0 0 DIL / MV 7 1 DILf OHMM 7 12 DIb / OHMM 7 12 DIb/ OHMM 7 22 OIL GAPI 7 31 CNL/''' GAPI 42 31 CNL / IN 42 28 CNL/ G/C3 42 44 CNb J PU 42 68 CNL*'*~ G/C3 42 35 CNb* C/C 42 42 CNL' CPS 42 34 CNL* CPS 42 34 BHC GAP! 60 31 BHC ~ US/F 60 52 APl DATA DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb 9790.000 SP 2.~03'''~ GR O. 37 NPHI 2796.000 FCNL 0~ 8P -0.005 NPHI 3496.000 FCNL REPR CODE 66 API API FILE CLASS MOD N~. 0 0 0 0 0 46 0 0 44 0 0 ! 0 0 32 0 0 32 0 0 1 0 0 0 0 0 3 0 0 t 0 0 1 0 0 92 0 0 93 0 0 32 0 0 32 0 0 -26.250 -111.250 31,738 984.500 '26,250 93.938 29,053 1275.000 ILD GR RHOB GR GR RHOB GR UNIT TYPE CATE SIZE ..m. .m.m .... CODE 000 000 O22 O65 000 000 009 065 000 000 01! 065 000 000 003 065 000 000 003 065 000 000 002 065 000 000 006 065 000 000 006 065 000 000 004 065 ENTRY 0 SIZE PROCESS SAMPLE LEVEL 4 0 I 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 I 3,355 IbM 126,688 CALf 2.459 NRAT -1tl,250 DT 4,684 IbM 117,312 CALI NRAT REPR CODE 68 68 68 68 68 68 3.422 '285 '770 79.563 4.602 B.711 , 695 7 ,000 bVP O09,HO~ VERIFICATION LISTING PAGE 4 DEFT 9600.000 SP -26.25~ SFLU 2,703 GR 51,000 GR DRHO 0,006 NPHI 26.465 RHOB NCNb 4008,000 FCNL 1484.000 GR DEFT 9500,000 SF '26.250' SFbU 2.703 GR 31,000 GR NCNb 373 . FUNk 1449.000 GR DEFT 9400,000 SP =26,25~ SFLU 2,703 OR 14,586 GR DRHO =0.005 NPHI 28,662 RHOB NCNb 3520,000 FCNb 1314,000 GR DEFT 9300,000 SP -26.250 $FbU 2,703 i'GR 14023 GR DRHO -0,002 NPHI 22:949 RHOB NCNb 4012,000 FCNG 1667,000 OR DEFT 920~,000 SP -26.250~' $FbU .703" GR 24.~i~ GR DRHO 0,00gl NPHI 25. RHOB NCNb 3828. 0 FCNb 1476.0 GR DEFT 9100,000 $F -26,250/ ILD $FLU 2,7003~ GR ~,281 O .R DRHO O. 19 NPHI ,617 RHOB NCNb 3572.000 FCNL 1190. 000 GR SFLU 2. / GR 103' R DRHO =0,011 NFHI 30,957 RHOB NCNb 3056,000 FCNb i145.000 GR DEFT 8900,000 $P -26.250' $FbU 2,7003< GR 1090.500 OR DRHO 0, 09 NPHI 3 .697 RHOB NCNb 23~2,000 FCNb 667. 000 GR ........... ?00'.000 ILO - , 50 NPHZ 250 RHOB NCNb -999. 250 FCNL -999. 250 GR DEFT 8600,000 SP -23,500 ILD SFLU 2,205 GR 131,. 005 GR DRHD =999.250 NPHI -999.250 RHOB NCNb -999,250 FCNL -999,250 GE 3 68 2.449 51.000 2,568 37,938 2,365 31,000 1~ '510 ,766 2.236 14,586 2,443 18.250 2.3il 14,023 t7,031 26,672 2.283 24,813 19.969 34,906 2,314 26,281 15.961 117.750 2.469 103,813 1.555 110.500 2,572 100,500 23,484 46,438 2,109 40,000 -999:2250 ,975 -995.250 5O CALI NRAT DT IbM CALI NRAT DT IbM CALI NRAT DT CALZ NRAT DT IbM CALI NRAT DT IbM CALI NRAT DT CALI NRAT DT IbM CALI NRAT DT IbM CALl N~AT D ~AT DT CALI NRAT DT Bi617 2 514 81 000 2.830 8,594 2,490 86,750 7 8 2 652 94;750 2,939 B 594 2'279 83!375 18 172 8i742 490 892,563 21.312 ,805 .941 93.750 16.328 9.148 2 59 1,635 9 898 3:404 105,563 2O0O 00 56 =°o -999 50 -999,250 LVP DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb 009.H03 VERIFICATION LISTING 8500,000 SP 2,393 GR 29 .250 FCNL -19.828 276.250 -999.250 '999.250 8400,000 SP 3,180 GR -999.250 NPHI -999,250 FCNL -19.03! 233 875 '999.250 8300,000 SP 5.164 GR '999.250 NPHI '999.250 FCNL -20,500 120,000 '999.250 '999,250 8200,000 SP 3.070 GR -999,250 NPHI -999,250 FCNL -27 031 128:875 -999.250 -999,250 8100,000 SP 2,246 GR -999,250 NPH! -999,250 FCNL -29,750 162,000 -999,250 -999.250 8000,000 .99~.480 GR .250 NPHI '999,250 FCNb -24.969 98.063 -999.250-999,250 7900.000 SP 2,625 GR -999,250 NPHI -999.250 FCNb =25,234 98.688 -999.250 =999,250 7800,000 3.338 GR '999.250 NPHI '999,250 FCNb -28.984 104,625 -999,250 -999,250 770~,000 SP .999,520 OR ,250 NFHI -999,250 FCNb -29.250 88.500 -999'250-999.250 7600,000 SP 2,332 GR '999.250 NPHI '999,250 FCNL '30,250 88,375 =999.250 -999,250 7500.000 SP 2.533 GR -999,250 NPHI -999,250 FCNL .000 -999,250 -999.250 GR RHOB GR GR RHOB GR ILD RHOB GR GR RHOB OR GR RHOB GR ILD GR RHOB GR GR RHOB GR ILD GR RHOS GR ILD GR RHOB GR GR RHOB GR GR RHOB GR .9929,049 IbM ,250 CALI .250 DT 2,348 IbM -.999,250 CAbI 999,250 NRAT -999,250 DT 980 -.999,250 NRAT 999.250 DT 2,141 IbM -999,250 CALI · -999.250 NRAT -999.250 DT .99~,749 ILM · 250 CALI '999,250 NRAT '999,250 DT 2.482 IbM -999.250 CALI -999.250 NRAT -999.250 DT .582 IbM '99 ,250 CALI '999,250 NRAT '999.250 DT 3.1tl IbM -999.250 CALl -999.250 NRAT =999,250 D~ .99~.422 IbM ,250 CAb! -999.250 NRAT -999'250 DT 2,240 '999,250 CALI '999.250 NRAT '999.250 DT 250 CALl -999,2250 NRAT -999. 50 DT PAGE O7 999,250 2,422 -999.25O -999,250 -999,250 . 31102 999 250 -999 25O -999 250 25O 999 25O . 860 -99 ,250 '9 ,250 2.5~8 -999.250 -999,250 -999.250 . 2.652 999,250 -999,250 -999.250 . 3.186 .999.250 999.250 -999.250 -99 250 -99~ 25O -99 °250 . 2.291 .999.250 999.250 -999,250 ' 50 -999.250 -999"250 DEPT SFLU DRHO NCNb DEPT SFbU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFbU DRHO NCNb DEPT SFLU DRHO NCNb 8FbU DRHO NCNb DEPT SFbU DRHO NCNb DEPT DRHO NCNb DEPT SFLU DRHO NCNb DEPX SFbU DRHO NCNb DEPX SFbU DRHO NCNb 7400,000 SP 2 486 GR -999i250 NPHI -999 250 FCNb 7300,000 8P 2,199 GR -999.250 NPHI -999.250 FCNb 7200.000 SP 2.637 GR -999.250 NPHI -999.250 FCNb 7100,000 SP 2.125 GR -999,250 NPHI -999.250 FCNb 7000.000 SP 2.895 GR '999.250 NPHI '999.250 FCNb 6900.000 8P '999. NPHI '999.250 rCNb 6800.000 SP 4.316 GR '999.250 NPHI '999.250 FCNb 6700.000 SP 3.586 GR -999.250 NPHI -999.250 FCNb 6600.000 4.496 GR -999.250 NPHI -999.250 FCNb 6500.000 SP 3.975 GR -999.250 NPHI -999.250 FCNb 6400.000 SP 4.453 GR -999.250 NPHI -999.250 FCNb -33 98 -999-999 -35 9O -999-999 -33 86 -999-999 -32 132 -999 -999 -36 117 -999 -999 -38 103 -999 -999 -41 87 -999-999 -40 91 -999-999 -48 83 -999-999 -74 55 -999-999 -6O '999 '999 .719 ,875 .250 ,250 .500 .250 .500 .688 '250 .250 .031 .750 ,250 .250 .250 .625 .250 .250 .969 .250 ,250 ,250 .875 ,688 ,250 .250 .188 .625 .250 .250 .375 .125 25O .188 .688 .250 .250 ,656 ,500 25O :250 OR RHOB GR GR RHOB GR GR RHOB GR ZbD RHOB IbD GR RHOB GR GR RHOB GR GR RHOB GR GR RHOB GR GR RHOB GR GR RHOB GR IbP GR RHO5 GR 2.375 IbM -999.250 CAbI .250 NRAT 2.195 IbM -999.250 CALI '999,250 NRAX '999,250 DX 2.465 IbM '999 250 CAbI '999:250 NRAT '999.250 DX 1,601 IbM :999,250 CAb! 999,250 NRAX -999.250 DX , 584 IbM -99 .250 CALl -999.250 NRAT -999,250 DX 3.166 IbM -999.250 CAbI -999,250 NRAT -999.250 DX 3,930 IbM 999.250 CAbI -999,250 NRAT -999.250 DX 3.738 IbM -999.250 CAbI -999,250 NRAT -999'250 DX 4.250 IbM -999.250 CAEI -999,250 NRAT -999.250 DX 2,814 IbM '999,250 CAbI '999.250 NRRT '999.250 DT 3.752 IbM '999.250 CAb! -999.250 NRAX -999.250 DX 2,426 -999.250 :999 250 2.246 999.250 999.250 999.250 250 :999 250 999 250 1,681 :999,250 999.250 -999.250 . 2,600 999,250 -999,250 -999.250 3,.277 -999.~50 -999, 50 -999.250 - 250 :999.250 999.250 3,600 -999.250 -99 250 4.223 -99~.250 -99 .250 -99~.250 3 000 -999 250 -999 25O -999 250 .99~"986 ;250 -999.250 -999'250 bVP 009,H03 VERIFICATION DEPT 6300,000 SFUU 3,363 DRHO -999.250 NPHI NCNb -999.250 FCNb DEPT 6200.000 SP &FLU 5.105 GR DRHO -999.250 NPHI NCNb -999'250 FCNb DEPT 6100,000 SP SFbU 4,141 DR DRHO -999,250 NPHI NCNb -999.250 FCNb DEPT 6000.000 SFbU 3,125 GR DRHO '999.250 NPHI NCNb '999.250 FCNb DEPT 5900,000 SrbU 5.320 GR DRHO '999.250 NPH! NCNb -999,250 rCNb DEPT 5800.000 8rbU 5,566 OR DRHO '999,290 NPH! NCNb -999,250 FCNU DEP? 5700,000 SP SFbU '7 .039 GR DRHO 999,250 NPHI NCNU -999,250 FCNb DEPT 5600,000 SFbU 3.598 DRHO .-999,250 NPHI NCNb 999.250 FCNb DEPT 550~.000 SP SFbU .732 GR DRHO :999,250 NPHI NCNb 999,250 FCNb DEPT 5400.000 SP SFUU 2,770 GR DRHO ~999,250 NPHI NCNb 999,250 FCNb DEPT 5300.000 SP SrbU 3.352 GR DRHO -999,250 NPHI NCNb -999,250 rCNb LISTING -64 68 999 :999 -90 58 -999-999 -77 79 -999-999 -124 3O '999 '999 -92 56 999 :999 -104 -999 -999 -109 56 -999-999 -60 79 -999-999 =54 65 999 :999 -75 53 '999 '999 '999 '999 .188 .125 5O "2250 . .188 .344 .250 °250 .688 .063 .250 .250 .688 .906 .250 .250 .375 $0 .375 ,125 ,250 ,250 375 :844 .250 .250 .594 .875 .250 ,250 .750 .250 .250 .250 .125 .875 .250 .250 ,844 .250 .250 IUD GR RHOB GR GR RHOB GR IUD GR RHOB GR GR RHOB GE IUD GR RHOB GR GR RHOB GR IUD GR RHOB GR IUD GR RHOB GR IUD GR RHOB GR ILD GR RHOB GR IUD GR RHOB GR 953 -9929:250 2.852 .-999,250 999.250 -999.250 2.598 -999.250 -999.250 -999.250 ,851 ~99 ,250 999.250 -999.250 2.613 -999,250 2.086 '999,250 '999.250 '999.250 .4 53 -99 .250 :999.250 999.250 3.803 :999. 5o 999,250 -999,25O 2,686 -99 . 250 '250 9 . 999 ' 50 -999.250 99~} '229 ,250 ,250 CALI NRAT DT CAbI NRAT DT CALl NRAT DT IbM CAb! NRAT DT IbM CAb! NRAT DT IbM CALI NRAT DT IbM CAbI NRAT DT CALI NRAT DT IbM CALl NRAT DT CAbI NRAT DT CALl NRAT DT PAGE i TM -99 250 -99~ 250 -99 250 3,516 :999,250 999.250 -999.250 -999: 0 -9999,250 -99 . 250 1,130 -999,250 -999.250 -999.250 3,137 99 . 50 99 , 50 2 721 :999i250 999 25O '999,250 -999 250 -999 250 3 549 -999i250 -999 25O -999.250 -999, 0 -999.250 =999,250 2,670 =999,250 -999'250 -999,250 584 -99 250 -9 99: ,o DEPT 5200,000 SP SFbU 3,279 DRHO -999,250 NCNb -999,250 FCNL DEPT 5100,000 SP FLU 4,004 GR ~RHO -999,250 NPHI NCNb -999,250 FCNU DEPT 5000,000 SFGU 3,971 GR DRHO :999,250 NPHI NCNb 999,250 FCNL DEPT 4900,000 SFbU 3.875 OR DRHO '999.250 NPHI NCNb '999,250 FCNb DEPT 1800,000 SFLU 4.363 DRHO 999,250 NPHI NCNb '999,250 FCNb DEPT 4700,000 8FUU ~,047 DRHO '99 ,250 NPHI NCNb '999,250 FCNb DEPT 460~,000 SP SFbU ,621 GR DRHO -999,250 NPHI NCNb -999,250 FCNb DEPT 4500.000 SFbU ~,506 DRHO -99 .250 NPHI NCNb '999,250 FCNL DEPT 4400,000 SP 8FLU 3,348 GR NCNb ,250 srbu 5. GR DRHO -999,250 NPHI NCNb '999,250 FCNb DEPT 4200,000 SFbU 5,855 OR DRHO -999,250 NPHI NCNb -999,250 FCNb -50,844 73.875 -999.250-999.250 6 , 81 - 99. 50 -999,250 '10~,375 6 .125 :999,250 999,250 '72,375 72,250 '999.250 -999,250 -66 875 71~375 -999.250-999.250 -110.875 46,719 '999.250 -999.250 - 125 999.250 -78.063 69.000 -999,250-999,250 108,125 32,406 ,250 -72.375 66.063 -999,250-999,250 -82.500 55.219 -999,250-999,250 IUD OR RHOB GR ILD GR RHOB GR RHOB OR OR RHOB GR GR RHOB OR GR RHOB GR GR RHOB GR IbD RHOB OR OR RHOB OR GR RHOB GR GR RHOB GR 3.576 999,250 999,250 999.250 2.281 -999.~50 -999, 50 -999.250 99~'2i3 =,250 999:250 3,646 -999,250 -999,250 -999.250 3.660 -999 250 -999!250 -999 25O 1,500 ,250 -999,250 938 :999,250 999.250 3,010 :999.250 999.250 -999,250 1.798 -999.250 -9 -9~'~50. 50 99~ '129 ,250 :999,250 -999.250 , 719 -99 ,250 -99~,250 -99 .250 IbM CALZ NRAT DT IbM CALI NRAT IbM CAb! NRAT DT IbM CALl NRAT D? CAb! NRAT CAbI NRAT DT CALI NRAT CAbI NRAT NRAT CAbI NRAT D~ NRAT D~ 3 430 =9991250 25O 2 711 :9991250 999 25O -999,250 ,803 99 ,250 :999,250 -999,250 99 250 -99 250 3.916 -999'250 -999.250 -999,250 i 695 -999i250 -999 250 -999.250 -99 0 3.316 -999'250 -999,250 -999.250 -99 250 -999,250 -999,250 .172 -999,250 :999.250 999,250 LVP DEPT BFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFLU DRHO NCNb DEPT SFbU DRHO NCNb 009.H03 VERIFICATION LISTING 4100.000 SP 7.133 GR -999.250 NPHI -999.250 FCNL -65.625 64.500 .-999,250 999.25O 4000,000 SP 5,137 GR '999.250 NPHI -999.250 FCNL -95,063 50.813 -999.250-999.250 3900.000 SP 5.254 GR -999.250 NPHI -999.250 FCNL -65 813 83:188 -999.250-999.250 3800.000 SP 7,246 GR .-999,250 NPHI 999,250 FCNL '80.000 65.312 '999.250 '999.250 3700.000 SP 6.555 GR 99,250 NPHI ?CN , -82.~50 72. 75 -999.250 -999.250 3600.000 8P 99(~ GR - , NPHZ -999.250 FCNb -84.250 73.688 -999.250-999.250 3500,000 4.566 GR -999,250 NPHI '999,250 FCNL -67 063 -999.250 '99.9. 250 3400.000 SP 4.~67 GR -_999, 50 NPHZ 999,250 FCNG -56.500 51.375 -999.250-999.250 3300,000 SP 4,168 DR 999.250 NPHI ~'999,250 FCNL -33.000 76.063 999,250 -'999.250 3200'.000 3,598 GR '999,250 NPHI '999.250 FCNL -30.312 7~.750 -99 .250-999.250 310~.000 SP .123 GR -999.250 NPHI -999.250 FCNL -4~.344 6 ,188 -999.250 -999.250 IbD GR RHOB GR ILD GR RHOB GR IbD GR RHOB GR ILD GR RHOB GR GR RHOB GR GR RHOB GR IGD GR RHOB GR GR RHOB GR ILD GR RHOB GR ZED GR RHOB GR ILD GR RHOB GR 6 2 -99 0 4.277 -999.250 -999.250 -999.250 .777 -9995.250 -999.250 -999.250 7.109 -999.250 -999.250 -999.250 999.250 : 99.2so 6.512 -999.250 -999.250 -999.250 5.316 -999.250 -999.250 -999.250 2.754 '999,~50 '999, 50 '999,250 3,791 '999.250 '999.250 '999.250 3.307 -999.250 -999.250 -999.250 -9992.2254' 50 -999.250 -999.250 IbM CALI NRAT DT CALI NRAT DT IbM CALl NRAT DT CALl NRAT DT IbM CALl NRAT DT IbM CALI NRAT DT IbM CALI NRAT DT IbM CALI NRAT DT CALI NRAT DT IbM CALI NRAT DT CALI NRAT DT PAGE 6,617 -999.250 -999. 0 4 645 -999!250 -999 25O -999 250 5 06 :999 250 999;250 7.332 =999.250 =999.250 =999.250 6.379 -999.250 -999.250 -999.250 6,680 -99 0 -999;250 4.820 -999.250 '999,250 '999.250 2.895 =999.250 '999.250 -999.250 1 '999. 50 '999'2250 -999. 3 119 -99 . 250 -999.250 .9992,438 .250 -999.250 -999.250 LVP 009,H03 VERIFICATION LISTING DEPT 3000,000 SP -37,875 IbD SFLU 2,766 GR 66,375 GR DRHO ~999,250 NPHI ~999 250 RHOB NCNb 999,250 FCNb 999,'250 GR DEPT 2900,000 SP -60. 156 SFbU 2,771 GE 49.094 GE DRHO -999.250 NPHI -999' 250 RHOB NCNr, -999.250 FCNb -999.250 GR DEPT 2800.000 SP -59.281 ILD SFLU 4.453 GR 42.344 GE DRHO -999.250 NPHI -999.250 RHOB NCNb -999.250 FCNb -999.250 GR DEPT 2700,000 SP -29.891 SFLU 2,775 GR 74,563 GR DRHO ,..999,250 NPH[ -999,250 RHOB NCNb -999,250 FCNL -999,250 GR DEPT 2600.000 SP 64.000 ILD SFr. U !00~.000 GR ~2,875 GR DRHO 99 .250 NPHI ~999,250 RHOB NCNB 99 .250 FCNL 999,250 GR DEPT 2590. 000 SP 65. 000 ILD SFbU 2000,000 GE 28.875 GR DRHO .'999,250 NPHI '999,250 RHOB NCN[~ 999,250 FCNL '999,250 GR ** FILE TRAILER FILE NAME IEDIT ,OO1 SERVICE NAME : VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME ** TAPE TRAILER SERVICE NAME :EDIT DATE 581/ 7/11 ORIGIN : TAPE NAME 162000 CONTINUATION # :01 NEXT TAPE NAME COMMENTS ** REEL TRAILER ** SERVICE NAME :EDIT 2,252 -999,250 -999 50 '999:~50 1.668 '999,~50 '999, 50 '999,250 3,i15 '99g, 50 '999,250 -999.250 2,922 -999,~50 -999, 50 -999.250 2000.000 -999,250 -999 5O 2000,O00 -99 250 -999,250 CALl NRAT DT ILM CALl NEAT DT CALI NEAT DT CALl NEAT DT CALI NEAT DT ILM CALI NEAT DT PAGE . 2,500 .999,250 .999,250 999,250 1,992 -999,250 -999,250 -999,250 .99~ '428 .250 -999.250 -999,250 2.643 -999.250 -999,2.50 -999,250 ~000.000 999,250 -9991250 -999.250 2000 000 -999, 0 -999.250 10 LVP O09,HO~ VERIFfCATfON LfSTING PAGE DATE ~81/ 7/11 ORIGIN ~ REEL NAME ~P,C,A,L, CONTINUATfON # 501 NEXT REEL NAME ~ COMMENTS ~ LIS FORMAT CUSTOMER TAPE ~ REEL HEADER DATE 182/09/2'4 ....... REEb NAME 1117921 _?.: - :!i?:i:': ~-:~!~#~' :,i! PREVIOU~ REEb ~.::~ -:~:.:: :.::/:~ *~ TAPE .HEADER DATE :82/09/24 TAPE NAME PAGE: ~a FZbE HEADER ~ERV~C.E NAME DATE l ..,...bF~ E TYP~ RANGI 15E 000 000 003 Ob5 8ECTI 18 000 000 002 005 8TATI AbASKA 000 000 006 065 ,.qCHI~UMBERGER ~OM~AN~ :~ A~bAN~. AbA~KA ~N~, == PRUDHOE BAY FIELD S~A~E m. ALASKA ~ . TOP' DEPTH J.' 8900"'FT: TUBING ' r: 5,5 IN. 8526'FT,' T'O SURF, ~YPE FLUID ~. P~ODUCED 1 68 8 ! 68 ! 68 ~ 68 ! 68 I 68 ~ 68 I 68 ~ 68 ! 68 68 ! 68 65 GR GR GR ;R GR 500 NTDT 500 NTDT -999 ~99:9 0 NTDT -999 PAGg 68 68 2500 -999 2500 2500 25OO soo 250(, 25O0 0 '999,2500 GR GR GR GR 60 6875 ,3672 rDT 121 ,b875 '2676 NTDT 119~7500 c 3,263B 6797 2401 2500 2279 76§b OR GR GR "29 5 T 11 ,06 4 .56 5 9968 1406 51 2~97~4 1 8379 9668 114,0625 GR ,2266 10 ,1875 ~,2324 11~,7773 ,1530 11 ,5391 112.'/500 ,0391 ~5 NTDT NTDT 'R O645 0000 9004 0000 0801 53 7500 0244 193 1387 0195 169,7500 26~,0000 ,2500 ;4492 ,0000 ~2432 ~K NTDT 75OO K FBAC NTDT 259 5 b 623 NTDT 25~ ~0 NT{ 25 ,5000 0000 4883 2500 7500 0000 ,:5239 1~0~ 48-83 5000 ? ~"999,2500 9 9,2500 ,3242 500o 2500 999 2500 :2500 0 NTDT -999,2500 IR 2500 ..I'DT 999"2500 N"' -,2500 SERVICE 'N'A~E .... DA~ I OCT 6 1982 MAX]CRUM bENGTH : 1024 NEXT FZLE NAME { ~******** EOF ORIGIN CON?INUATION : :.. :: ::: · ::~ .:.~ :~<.. :' ; PAGE 2 2 1981 Alaska Oil & Gas Cons. Commission Anchorage REE5 MEADER ~ i~ '' PAGE mmmm mmmm CN : ATLANTIC RICHFIEbD CO. 000 000 022 ~WN. :' ~ . . : i: ..'-: ~:i'O00 00'0 0.14 004 MNE~,~ CO~,~ENTS UNIT TYPE CATE SIZE PRES: FDNOOiF ' ~' ·- . ~' ~-. -" - .'>.' '."-~:~:i."O00 :' 000 007 RECORD. TYPE 047 CODE U65 065 065 065 065 065 065 065 065 CODE 065 JOB 10707,61640 CNL RUN #1, 11'MAY'BI BTM. LOG INTERVAL TOP LOG INTERVAL CASING DRILLER TYPE FLUID IN HOLE 8IT SIZE ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE 4 8 9 0 -' 7,0 IN, -- D IESE~N 4 73 .... ...... 60 ....... '4 DATU~ SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT APE API ID ORDER ~ LOG TYPE CLASS MOD NO. LEVEL CO.DE. DEPT FT 0 0 0 NRAT 017 0 42 1 .0 O ,. 4 0 1 6.8 GR CNE GAPI 42 NCNb CNb 42 34 92 0 0.-~_ . 0 1-- 6.8 F C N 5 C N 5 42 34 9 NPHI CN~ PU 42 ' ,_ .' -~.':~:~ ~.:,, .~ -., :. . :;.. :: .-?:;~,'...;.~:-/' ':;._ ~; :.{..-,~ . ;.._ ~---- .....:. .. :: .-. '.'~ ;::~-./,--.{~..:~__.,.-;~, - ~ .::_ .. .' ... ~_..~:;~ ...- . ..- . - DATA *~.-: ' _.'/ / -- . :':i. '/'~' · DEPT 9753'500 NRAT· . '999~25·0 ·.GR· ·::?<: :-:'I'~'966' NCNb PAGE -999.250 268.240 303.863 281.974 FCNL 4491,769 NPHI 2~,D21 DEPT 9300,000: NRAT 2,731 . GR 18,315 NCNb FCNL 5022,300 NPHZ 20,181 DE~T 9100,000 NRAT 3.155 GR 25,609 NCNb 4723:~409 NPHi FCNL 3038,412 NPHI 29,142 273.391 301.288 278.112 263,519 255.794 233.476 DEPT 880-0.000 ' :' -5"2'15 G~'- :NCNb 200.858 GR 44.791 ·NCNb 207,725 DEpT ' 8_600'~0'00· : NRA? >4.'.712: GR?i'>-': 220.172 FCNL 2328.546 NPHI . 50..403 · ~ '-" ' : ..: _"- _ : < .:-!<i:_.' :':'!.i:! :'..;' ' ~ ' T 4, 44 R .5,945 NCnb 2 5 DEPr ~00,000 NRA 5 G 9 4 0 .579 FCNL ~883'946' NPHI ' '" 49.663 ' 'DEPT 8400.000 NRAT : :-'"--'4,.774' '<'GR'~.-:. 233.476 FCNb 2194.045 NPHI . 53.163 DEPT 300,000 NRAT ~ ~.38~ . ~R e2.b75 NCNb 235.~93 FCNL 2500'409: .NPHX" ~ ' ':'4~'~>t83"": ' : ': :"'":'~':' ';"::::'-'~ : DEPT 8200-000 NRAT : 4"9i3- 'GR'.:' -~"S2"784 :NCNb' · 227.039 FCNb 2145,476 NPHI 54.423 DEPT 8100,000 NRAT 223 605 . ' . . . · :~ . ~ ' . ' ~ . ~ ' . ' . LVP O09'.HO3'VERIFICATION I~ISTING ~:'- ~-::-:':<-'':~ = FCNL '999,300 NPHI '999,250 ! · ' ' : :' , i!': /' _~ ' ' 60 0 .... i ' DEP~ i 0,0. 0 NR.A~ 999,3.00 GR. 41,594. NCNb FCND -999'300 NPHi DEPT 6000..0'00 'NR'AT -.'999-3'-00'i GR i"- : 26"807 NCNb ~ ' 0 ' FCNE 999,3 0 NPH~ -999.250 DEPT 5900.000 NRAT -999,300 GR 33.601 NCNb FCNL ~999',300' NPHi' ~"999;-250 '' ' '.: DEpT 5800'000 NRAT NCNb FCNL 999,3.00 NPHi -999.250 .... . : - . . := - ... :; '.3 DEP~ 5700,000 NRAT ~999,300 .Ga 19,514 NCNU FCNL '999*300NPHI · ,'999~-250' DEPT 5500,000 NRAT -999,300 GR. 32,602 NCNb FCNL 'i~99,9'-300 NPHI' '""'~99~:'2§0' :: DEPT 5400.000 NRAT 6 -NCNb FCN5 -999,300NPH~ -999.250 D'" ' - N EP.~ 5300,0Q0 .NRAT 999.300 GR 2.1.8~12 .NC L FCNL ' .-999,'30.0 NPHI ' -'999..250 ' ~:-- .... ~'-~- DEPT 5200~000 NRAT" : ~999; 300 -' OR :---> ':! ~-~-?~316'499 'NCNb N , . - FC.L 999,300 NPHI -999,250 ' ' , . ~ '-. i ~ : . ~ . - '?'-~- ! - ~ ~ DE:PT : : 5000,000'-NRA~' : '999'.3:00' GR" -----3:7'8:97 ~ NCNb DEPT 4900,000 NRA~ -999..300 GR 22,611 NCNb FCNL '999*300NPHI' '!999.'250- DEPT 4800'000 'NRAT ''9'99.'300 ..GE: . '. ' : 2.6.4~8 :..NCNI~ FCNL -9.99.300 NPH[ . '999.250 . DE.PT 4700,000 NRAT 999.30. .GR 33,701 . NCN[~ FCN[~ .,.999~300' -NPHI' . '9.99'250 DEPT : 4600,O00NRAT FCNL -999'300 NPH~ ~999,25.0 .'. .' : '. . ~ : · .. - . ~] ~ : DEPT . .500.000. N~AT 999,300 GR .32,4 2 NCNb FCNL '99.9-'300 NPHI ·'999'250 : PAGE -999,300 -999,300 -999,300 -999.300 -999,300 -999,3OO -999.300 -999,300 -999,300 -999,300 -999,300 -999,300 -999,300 -999.300 -999.300 -999.300 -999,300 -999,300 5VP 009.H03 VERIFICATION FCNL 2093,170 NPHi DEPT 8000,000 NRAI FCNL 2100,642 NPHI DEPT 7900,000 NRAT FCNL 2395.797 NPHf DEPT 7800,000 NRAY FCNL 24i8,213 NPHI DEPT 7700,000 NRAT FCNL 2167,893 NPHI DEPT 7600.000 FCNL 1891,419 NRAT NPHI DEPT 7500,000 NRAT FCNb 1962,405 NPHI DgPT 7400,000 NRAT FCNL 1827.904 NPHI DEPT 7300,000 NRAT 1753,182 NPH! FCNL 57 NPHI DEPT 7200,000 NRAT FCN5 lb93,403 NPHI DEPT 7000 000 NRAT FCN5 1921:308 NPHI DEPT 6900,000 NRAT FCNL 2052,072 NPHI DEPT 6800 000 NRA~ FCN5 1943:725 NPHI DEPT 6700,000 NRAT FCNL 1827,904 NPHI DEPT 6.609~.,000 NRAT FCNL 9 .300 NPHI DEPT 6500,000 NRAT FCNL -999,300 NPHI DEPT ~400,000 NRAT FCNL 999,300 NPHI DEPT 6300,000 NRAT FCNL -999.300 NPHI UlSTING 3,656 .GR 44,69:1 NCNb 229,~.185 39' 482 ~ ~ ' 4,764 ~GR ~ 46.::689 NCNb 205.579 53 · 803: 4 ' 937 54,223 . ........ ....... 4.887 GR ...... ........ 32.8.02 N ~:Nb 203, ~3:~ 6 4,344 5 5,276 OR 42,993 NCNb 215,02! 58 ' 963 ~ ~- J 55.823 · ~999,30.0 -999.250 -999,300 GR 40,395 NCNb ~999,30.0 -999'250 '999 '300 GR '.i:~ 32'103 ~:~N:[, J -999.250 · L~P O09,HO~ VERIFICATION DEPT 4~00,000 NRA1i FCND =999,300 NPHI DEPT 4300,000 NRAT FCNL -999,300 NPHI DEPT .492~0,000 NRA~ FCNL 9,300 NPHI DEPT 4100,000 NRAT rCNb -999,300 NPHI DEPT ~000 000 NRAT FCNL 999~300 NPHI DEPT .3900 000 NRAT ~CNL 999~300 NPHi DEPT 3700.000 NRAT FCNB -999,300 NPHi DEPI ~00,000 NRAT FCN5 999,300 NPHI DEPT 3500.000 NRAT FCND -999,300 NPHI DEPT ~400 000 NRA~ FCNL 999~300 NPHI DEPT 3300.000 NRAT FCNL -999.300 NPHI DEPT 3200.000 NRAT FCNL -999,300 NPH! DEPT 3100,000 NRAT FCNL -999.300 NPHI DEPT 3000 000 NRA'1~ FCNL 999:300 NP~I DEPT 2900.000 NRA~ FCNL -999.300 NPHI DEPT 2800,000 NRAT FCNL -999.300 NPHI DEPT 2700,000 NRA~ FCNL -999,300 NPHI DEPT 2605,500 NRAI LISTING -999 300 ~R 34'20~ NCN:L ~999:,300 99: 25:0 '9 -999.250 250 '999'.250 -999 , 300 GR . 999,250 -999,250 ............................ :999,300 ~R ..... ..... ::29,~05 NCN:~ ~999,300 999' ~:§:0 :: '999,250 '999,300 GR 26,108 . NCNb ~999,3..00 ' -99:9 "250: : ::' ~' : i': :..: :'."':!: ] '999 , 25=0 ......... i ~:: '.. -999,300 OR ....... 37,99~ N£NL 99~ 250 ~ i '999.250 ........................... '999.250 i~ '999,300 OR ~999,.25.0NCN~ ~999.250 L~P 009.H03 'VERIFICATION L~ISTING FCNL -999.250 NPHI DATE : MAXI UM LE.~GTH · 1024 FIbETYPE~ ' NEXT FiLE NAME · ** TAPE TRAIbER' ** ~ERVICE NAMe14 :SER¥IC ATE :81/07 ORI IN :6164 COM~EN...$ .TAPE COMMENTS ** REEL.TRAILER SERVICE.NA~E .SERVIC DATE :81/07/14 ' N ORIGI. EXT': REE~ .CO~ENTS :REEn .CO~ENT$ :. -< :" d-:~; ::. ::i:' :_: ~ PAGE -999..250 EOF - EOF EOF . .:': _: ~: -.. :. - :. : . :-' .:..:: -- · /-:::-:,_ ::.::'~:: _- · ... . . . .-'. : :- .:: :.: _-'< :....:. . : .--' -..: ?:: .- . · . , · - . . ' ... . ~.' . AP 1 GAP1 S~PI GAPI ,1 137,9 · 1 I37,9 33 .37,1 137,9 123. 56:37~1 t37'9 123. 94 37,1 137 0 137 9 117 8 97 8 4,6 91,1 6 94,3 .4 1.1 14.4 58 ~ ~a -13-5 571 o4 49 .0 o6 .7 53 15,6 45 . 8 35 14i4 45.3 15.80 14,3 47,7 PAGE I PASS5 AVE, AVE, GH 6IGMA 8IGMA NEAP F~ GAPI CU 123,4 129.6 128.9 29.1b 24.44 123'4 129.6 128.9 19.16 17.08 4 I~ 6 128.9 17.35 15.71 4 :6 128.9 18,51 16,69 4 129,, 128.9 19.95 17.34 4 129,6 128.9 20,00 17.59 123,4 129,6 128,9 21,57 1~,59 123.4 129,6 128.9 93,19 90.56 116.4 116.9 120,4 24.50 22.02 107.4 103.6 116.9 21.70 19.50 101,6 102.9 113,9 20.12 18.15 101,9 101.2 110.~ 20.84 18.15 99,5 110,4 104,8 20,86 18.03 1~0.2 117,6 1.12,1 21,14 17.83 105,3 123,1 127,3 22,25 19.63 96.1 1 18.6 131.8 ~4.83 21.38 111.1 122,7 128.6 27.71 22.95 131.5 142.3 137.6 28.32 23.77 112.1 130 8 136.6 95.17 21.43 71,3 89~6 102,0 26,41 23,63 64,6 78.9 88,9 33.09 29,09 68.8 77,8 88.2 28.46 24,84 66,7 79,8 86,3 22,34 20,11 70,3 80,5 88.6 20,84 18,69 73,9 76,8 92,6 19,85 17,71 68,2 76,4 82,8 19,32 16.73 66,8 76,6 77,3 19,32 16,~3 63.I 78.3 83.1 19.07 16.97 61,4 72,8 82,8 18,56 16,77 57,5 72,8 80,8 17,23 15.52 63,9 7~,4 84,0 1},34 14.75 66,6 84,0 $1,0 17.07 14.81 64,4 77,1 81,4 17.33 15,0~ 60,5 74.8 76,7 17.92 15.53 59.8 71,7 77.9 18.33 15,41 56.1 61.8 70.9 17.71 15.11 7.5 54. 7.7 7,.4 ,8. 0 56,2 62,8 71,7 18,23 15.88 ....- OCT . $ I'& NA$ I G HA ,5 J GNA .~ IGNA. $ IGNA' StG..~.~ ~. ~,G~A .~..I..~A .~_.SIG~A,..~&I.G~A GB Nt~R NEAR NEAR NB~ N~R - ~"T ~U GU CU CU CB . · ..... ~ GAP1 9390 17.59 19,4~ 18,15 17,84-1~,08 ..... 13.7 9389 ~6.98 18.59 17.66 '~'::::~:: : 9388 17.~2 ~8.~~ 9387 17.53 18.~ 18 .38': 18.18 -:15.,, ...... t4..9.9 .... 9.38~I 17,34 18, 938'~ 18.55 18, 93~2 ~7,61 17,56 18, 93~1 17;81 17;81 18; 99~.~0§ 20'27 20 20 ~ 19,,03 19 19 ~9~8 20.39 20 19 9~77 18-42 18 18 · 9376 17.78 17 9375 17'19 17 9374 !7.!4 16 9373 16'63 16 9372 18.06 17- 9371 17.66 17 !7.,59 17,61 9369 18'05 17'97 9368 17-52 18,58 19 9367 17'72 18~67 9366 !7.75 17,86 9365 I7'28 I7'88 17' 9364 17,34 17,45 17 ,9363 18'30 18~80 18 ,' 9362 18,80 18,94 18 936I 18'56 18;94 19 9360 18,50 19,01 18, 9359 17'75 18'05 9358 17.33 9357 18'33 :9:356 18,14 9355 18'42 935419,28 9353 19.27 9352 17,36 9351 16'63 9350 17,28 934:9 16.97 ~9347 .31 9346 16,52 934517.31 9344 17.91 18.521:6, 16,55~17; ,17,28 1:8 18'513 18 19,3419, 19'39 19" 18,45 18. 18'06 17' 16,94 18, 18.06 18' 19.9{ 18,97 16.38 i6'80 16,25 16,56~1:6, 20,2~ 19 23 19.63 ....... !5~.55 .......... 1~6~.~5 ......... 3~.3 ......... ~8~.2 ........ 16.66 COMPANY F'T 9343 9342 9341 9340 9339 9338 9337 9336 9335 9334 9333 9332 331 330 9329 9328 327 326 :U CU CU CU CU-~ ~ .., - GAPI GA.P.i ?0 ~ 7, 8~ ~6,92 ~7..7-0-::15~:,:~0.:::~1.: 7 34..2 .77 18,0C 18.06 18.14 8'48 18,75 18.70 18.14 17,09 16 ,47 16 ,89 09 67 53 18 17 17 18 17 18 18 18 18 17 1-7. t7. 18.23 17.39 17.45 17.28 7.50 8.52 18.70 18.53 17.53 17.44 7.63 7.94 17.0-9 16 16,63 16 6.27 17 6.67 16 17.33 16 17.42 16 28 18, 53~19, 02.18, 95i8, 9 17'66:i:7 17,01 1.7,02::16 16.70 16;31~'-i6 16,70 .... 16,41-~-1.~ 932~ 16,86 17 14 i6 932. 16.86 16 97 17 9323 16.53 17 76 9322 17.86 17 61 9321 17.36 16.B3 17 9320 17.00 17.0'8 17 9319 17.:00 16 97 17.72- 16. 9318 16.75 17,25 17.02~I5; 9317 16.69 16,47 -16. 9316 17.00 16,66 17' 9315 16.58 17 38 16, 9314 15.98 17.00 t5 9313 16.03 16,7~ 16 9312 16.50 17 1616 9311 16,75 17,25 9310 16,78 17 44 9309 17.05 17.37 17 9308 16.80 17.30 17 9307 16.83 17,0( 9306 16.52 16.77 9305 16.53 16.95 16 9304 16.6t 17.79 17 9303 17,17 iT,l~ 9302 17.52 17.19 9301 17,36 17,66 {6 9300 17.45 16.92 17 9299 17,33 16.99 16 9298 16.84 17.58 17 9297 16.75 16.8C 17 COMPANY : ARC£ NEaR NEAR NEAR NB/R "~tAR ~ ~ ~ '~ '-: '::'"'~:~' ~:~''~ '~'-~: "~:'~[':A~:' F~:R ET CU CU CU CD CD GAPI GAPI...-.~API. GAEI,- ~GAP!:...~, 9296 16.77 16.36 16,64 9295 16.61 15.70 16,42 16. 929416 .45 16.2( 16,52 16-~ 9292 1 9291 27 17'61 17.05 I7:: 9290 17.64 17.81 17 55, ~289 16,91 17,27 1'7 66' 9288 16,2~ i5,81 16,65 9587 16.70 16,50 16.78 ~!~ 9286 16,42 15,88 16,57 ~ .1~ 30. t:6, 3 .... 14,08 t4:~{.:~.~~-.-iA,~A ~ t.~ ~ 14...5~-:-_ 30..3 4.4,0 51 ...8 5.6.9. 1. 6.33 .14.30 9284 16.94 16,5; 1.6,75.?~!6 02~3 16.7§ 16,64 16,4~ I'6 9-1~'i7~ 9282 16.42 1~.55 ~2..16,44 :!6. ~281 15.34 16,3'1 1~ 16.13 1'6; 9280 16.34 15,73 9279 16,78 16.55 9278 16,02 16,~ 9277 15.54 15,49 9276 15.28 15,17 9275 14.80 15.I0 9274 14.84 15. 67 9273 16,25 16 927~ 15,70 927 15.29 9270 15,89 14 9269 15o55'15 9268 15.02 1 9b 9267 15.34 1~ 62 9266 15,02 9265 14.65 9264 14.55 1 !5 9263 15.20 I 16 926~ 925~ ~1, 925 925 ~0. 9256 18.6~ 17 9255 17.i9 16 9254 18,~ 17,45 18.87 17. 9253 19~27 20.8~ 20.75 19 9252 25,20 26,55 24, 9251 2~.97 24,90 9250 ~6.94 20.99 19.59 19 ~O~P ~f~¥ : ~RCC DEPTH PASS1 PASS2 SIGMA SlGHA NEAR NEAR FT CU CU 924% 924{ 92~7 92~ 6 92~5 9 Z44 9243 9342 924116-36 16.76 9:240 17.09 17'72 9239 20.00 1'9.35 9238 19'28 l:B;g8 9237 ~8,38 923618'34 !!9235 17..95 17 9234 18'25 I8 923319.13 9232 19.34 i 9231 19.28:17. 923017'95 16 ,9229 17.59 ,t~ 9228 18'36 :6g 18 922719.34 9226 18'03 19.72 18.84 17,9~ 17.53 16'7=8 16'8:; 16,53 16.1g 16 8'05 lg;O1 20 23-05 21'.48:22 19'94 19'09 1'8 '23 16;64 16 '00 I8 9224 9223 ~', 9222 922 ! 1 9220 9219 92I B 9217 1 9216 1 9215: ~ 17, 17 9:214 17, :17 9213 16,08 16 9212 17'47 16 9211 9 17',99 16 :92i0 ! 3 18'09 I 9209 i~7.80 19'0:1 19 9208 : 9'36 20'43 20 920:~. i9.66 1.9. 92'0~ 20'3! 20~2~ 39 9209 22.64 22.0{ 9~04 24,05 23;38 2~1 9.203 · .. 1 18 22.75 22.20 2!.16 22..03 COMPANY £EPSD FAES1 SIGMA NBgR YT :U 9202 18,77 19 920I 17.52 17 9200 17,30 lB 9199 17~89 lB, 9198 17,52'1~ 9197 17;70 .i~ 9195 21,28 ~0 48 18 94 17 · 91 17, O0 17. 6r8 19, 4'5 2'0 9194::2!.23 9:193 20'52 20,34:20" 9192 20,6{ 20.:7:7 20~ 9191 20,91 20 9190 2 1, 21 91~89 2i; 2i 9!88: 27:21~: ~ 9! 87 42 21 9186 9~.52 19 .1.9 91B5 1~i;80 I9 I9 9184 ~.28 t8' 9~83 ~7;70 9: 9 9179 2 9~3 ~9, 47 917m 19'64 I9 ::i8 ;9176 19,75 917~ 19'27 ,I6 9174 20,56 917~ 22'50 20 9172 21,08 19 9171 i8'89 lB 9170 17 9169 17'55 16 9:268 17,81 9167 iB'94 19 9166 20.77 20, 9165 21'25 20~ 916 22.64 9~63 27,36 9162 32.47 916~ 24.02 9159 16.59 9158 17 '47 9157 ~ 8.16 1 9156 17.27 coMPANY : ~IRCG NEaR NEAR 9155 15,95 17,27 16,39 17,1"-1 _,~ 915] 15"75 16,~6 16,81 9153 1~-36 17.38 15,63 17,~ 9151 }~.50 17.7~ 17.28 1-~, ' ~148 ~7.02 1~88 17.23 914? 16,28 16,52 17,14 !,3, 91~-~~9.]~ ~7.~7 ~7;64'~'i7' 9i42 22.91 2~.2S 22', 9~41 22.02 23.65 22., %'i40 21.59 21.49 21. .91S9 25.42 20.S8 -,9~38 24.06 23.44 ~9~37 2~.36 2~-.11 ~9~]6 {~.92 19.59 9~e ~9.6~ 19 4~ 913~ ~9.09 ~8 9~3~ ,9,45 9~30 ~9,23 ~9 9~29 9~2e ~6 ' 9127 9 i 26 912:5: 9124 9123 :9i22 9121 l 9120 1 9119 1 9118 I : 9117 1 9116 9115 ,7C 21, 9114 9113 23~4 24.63 23.~5:22. 9~:i2 2~'31 26;~ 25 9110 9109 COMPA~i ~' : ARCO DEPTH PASS! PASS2 .$IGMA SIGMA NEAR NEAR FT CU CU '910'7 15.98 16.94 91o5 19,5~ 19.56 9104 21,~9 2'1,64 9103 21150 21.75 9102 19.92 9'101 18.63 19 0319 9100 17.97 IS 909'9 18,72 20 9098 21,4 9097 20,2~2022 9096 17~13 9095 17,4! 18 9094 17o42 9093 17.17 9092 17,28 i.i 9091 17.73 ~9090 17, 9089 17, 9.088 17~ 9087 17.0 ,9086 17o5i 95 17 9085 I7.7' 5'6 17 9084 18.1 9083 19.~ :9082 21, 22 9081 2I, 20' 17,, 98 18, ' 90 76 90'/5 90~I~19,95 19, 906~ i8'20 90~;' 2~,?0 2~'5~ 23, 9066 20 9~5 i9'25 16 9~4 19.1 6062 19,06 18,8~ 18'61 18'98 18, !.9,:0. 33,fi. 4.fi;.,3 :51,2 62,i 18,92~ .i6'06 COMPANY OEPTH PASS1 $/GHA NEAR FT CU 9061 9057 9056 9054 .905 9051. 19 9050 18 9049 17 9048 17, 9047 17, 9046 18 9045 20, 9044 19 9043 20, ~9042 19 9041 18, 9040 17, 9039 20, 9038 19, PASS2 PASS3 PASS4-' PAS SIGMA flGMA ~IGMA S.IG~A &IG~A ~IGMA ~,G~ GA .......... G=A ~GE ..... GE 8_I.GMA_$!G~A 64 ~,4l 1.g.09 20.2.2. 20.78 1-7.O2..:t6.6~--~t6.~-t L8.08 16.64 36.A ...... 45.9 ........ 52.8 ........ 63.1 31 ~u.22 19.70 21.06' 2 ,91 I9 95 20.86 20.94 05 20~47 20.81 2t~13 78 22.16 22 47 48 22.36 22 23 ~I 20.06.19 18.77 ~9 .28 20,~ 20.56 20. .50 19'78 20.00"19, ,39 19,75 19 ,63 19.09 18 28 17.fi3 .45 18.03 .95 18.94 19 .59 19;59 19 ~00 19.1e 18 73,.18. 45 20.03 19 45'19~ x!9 20.75 20 ,20 20.16 20 ,.00 17.8{ 18. ,91 18.11 18, 09 19.66 19, 20 18.94 18, 903718.88 ~ 9036 19'55 ~9035 18.58 9'034 I7'03 19, 19 ,16 1'7 ,28 17; : 9033 16,97 17,,34 9032 i7;66i8 ,25 90~1 18.58 9030 t8'59 18 9029 16.00 16 t3 9028 i5'45 16 :9027 16.64 9026 1'/'6i 16 9025 !7.14:16,78 9024 16'72 16 55 9023 15.88 9022 1 ? ' 1 1 9021 17 · 30 :9020 16'03 15;62 15 9019 16.28 16. 90! 8 15'78 9017 16..70 15,1t5 16,42 16.63 .... 1~.51 4:0 5 ............ 51:,.3 67,.~0 70.:9 ....... 8.0.6 .... 1fi.42 13,.9b 9016 15'95 t6' 9015 16.08 16.59 15.70 16.04 !6 SIGMA SIGMA SIGMA SIGMA SIGMA G~ G.~ ............ GR.._ GE .- .GE .... ~IGMA SIG[~A 9012 15.41 16,1~ 15.25 16,34--15 9011 15.10 15.31 9010 15.66 15.69 , .-.. ~:;,~, - ~, . 9009 18.92 19,03 19'64 20,3'7~ I9 9008 20,00 20,38 21,'13 19,83 19,95 .:36, t ..... .16.89 9007 I9.39 20'25 19'92~ 19;12: 9006 19.39 20.31 20,61 9005 21.02 21,25 22'73 9004 22.14 22,58 23-1b~ 9003 23.20 23'75 23,20' 9002 24.48 23,78 22,55. 9oo 28.45 9000 31,98 32.~3 3~ 6~ '8999 30.28 30.61 30 03 30. 899~ 31.08 ~1.31 JO 8997 32.50 32.50 31 8996 ~.22 8995 2.13 32, 8994 31.23 32, 75 30 8993 32.13 29, 95 31 8992 32 . 06 32 82~. 32 .~,~8.- 3.'1~;::,-~08~-~.:3~1.-,-I.:t':~.. 1-56 ~. 3- .t..7.2.-8 ..187:~...8 :.19.3..! ......... 21.1: . 32. 30.. 69_ 8991 31.48 32 .S'1::' 8990 ~ 0,78 30 48 30.5 O- 3 O. 57: 2:9- 69.29:-, :;20 - 2:8 :,~50~:~ .~:~:~8 .~&9~-...~2] :...8.7 :~ 29.. 44 17..4.. 4. !79:.6 :~ .20. 8..::~ ~20 :. ~ ..... 2.16.5.~. 3.0~. 50 28. b 5 8989 27.75 27, 2~ 27, ~9~'~2'~.5'4: 8988 24,..81 23~ 33 25 20 25.34: 23-,8~'~22~.~2'3:-..2:2~..-.~.~ ..... 1..44.8 ....... 22.16 e986 ~0,, 6~ 29, 83 30,00~ 00.25.73 8984 26, 08 25, 91 25 84: 24. 8-8 25.33~:~.-22~:, ~:~3~'-~,~.~4.8..:2:3,~3.:?.23-~0.7,~:' ~!~:..53....1 ........ 31,~b..,.3:...25.62 .22.80 . 8982 32, 13 31, 89 31 ;48 32.68: 3.~.:~0~.~t~, 5 ..... ~..48...6.. 31 91 30..64 05 ?0 4] 29 78 77 3! 27 30 8980 29, :52 8979 29, 91 :;8978 29.02 30 8977 31'64 31 8976 31.78 30 8975 31 '05 8974 29.78 30, !:3 8973 29*78 30, ~8972 31.08 3.1.05 8971 32.44 33'5 36,Q3 34,94 8979O 896 35.13 35;.59 8968 31.86 31,59 29.3 COMPANY SIGMA SIGMA NEaR NEAR ~U CU 8967 8966 8965 8964 8963 8962 8961 8960 8959 8958 8957 8956 8955 8954 8953 8952 895! 8950 8949 8948 8947 8946 8945 8944 27.36 2 97 27 27.16 26 7( 27 30.48 28 36 2'9 33,88 34,59 31100 31.16 27,1 27 26.7~ 27,09 26,78 26 25 25 24,72 24 23.34 23,58 23 23.45 23.08 22 ~.13 2-2.58 2:3 .9! 25.28 25 28.~86 29,39 29 34,75 34.31 33 34 29 25 24 24, 24~ SIGMA SIGMA. SIGMA. :&I:~N~A.::8t. GMA~:~:~ :~i:-GMA. ::~:-:~::G:~ .:GB.-:.:. ~iGMA $!.G~A ;.: NEAR NB~R NEAR · CU CU CU 39 28,41 28 27 ~6;7'0'27 67 26,69 2~ ~2:~..:~25,~3.~ :24.9:4 =. 66.2 ::: 78.,6: 92.-,3:.:::.::1.:.:04.:7::~- 111,8-2 95' 30.61 30: 33::"~6:;:8~'0::: ::~:::2::8~8~:::28~ -':'::~9% 92':--:"' :6:8; 9:: :"' ?:?::' 94:,::6 :::~H 5 J:q:~:6::~;:5~?~ 3.0;:; 25 33 4J 30 09 26 ll 26 59 33,78 34 0634. 6 6 29'83 30 ;22 30~ 73 27-30 29 6 7 26'9427 38 26.5~ 26 97 25' 47 26 61 25.03 25 :06 25;:t9 25 :8943 24.78 25 8942 25'38 2:5 8941 24-94 25 8940 25'8i 25 8939 24.91 24 22 24, 893:8 24'59 23 50 231 8936 ~23'67.-.'27 231 8935 23~55 23.75 8934 22L97 23 '41 8933 22.48 23~ 8932 23'16 22. 8931 23.36 22 '8930 24.17 23 8929 25.27 25.48 24 8928 26"28 25'59 251 8927 28.31 :28o 8926 26'22 26,63 :8925 27.66 28.28 8924 33'91 33,22 8923 35.94 36.91 892'2 37.34 37°38 8921 38 25 38 , 3 J 37 22 37 , 20 3~:, 7.:2 38,69. 40"56.:..:39..~.4..:..3..7.,..36: ~., 38,3~: 82'3 98..~:~ 116'9 1.,!8~.:~ ...... 1::39.5~i:=:37:~3~==~ 8.~ 8920 37.72 37,88 37 8939 36,88 37,93 37 89~8 38.03 37,28 3b ~89~7 37.38 38,29 36 8916 ~7.97 39,34 89~5 7.41 39,4~ 8914 37,03 38,31 37 16 37,34 37~ 0'9:16: 85. t .111~::.-0:...~.109.:~6 .~:~1.26.3...~ 1:3.4..4 -37~_. :22. 38.17 8913 37.13 37.78 36 ~6 891~ 37.0~ 37.66 37,25 36. 89t. 36.8~ 37.13 37.81 37, 8950 37.25 37. 84 8909 38,03 38, 8908 37.50 39,~f 8907 36'66 38,00 37 890~ 37.44 38,~3 ~6 5~ 37, 8905 37,09 36,9~ 36 09~37, 8904 ~8,~4 ~7 59 8903 37'9~ 37 3~ 36 8902 37.44 ~7 890~ 37,~6 37 8900 ]8,28 37 l~f 37 00 36,47 - =========================================== ::::::::::::::::::::::::::::::::::: ~.:: _:::: ::' ::: .: : LT~S TAP '~ LVP OlO.H02 VERIFICATION LISTING ** REEL HEADER ORIGIN : ~EEL NAME :2233B9 CONTINUATION # PREVIOUS REEl, COMMENTS ~LIRRARY TAPE ** T~PM MEADER SEPVICE MA~E :EDIT DATE :84/05/ 9 DRTGIN :0000 TAPE NAME :9160 CONTINUATION PREVIOUS TAP~ COMMENTS :;,IRRARY TAPE ** FILE MEADER ~* FILE NAME :EDIT ,001 SERVIC~ NA~E VEP$ION ~ DATE : ~AXI~IJ~ LENGTH : 1024 FiLE TYP~ : PREVIOUS FILE : ** INFORMATION RECORDS ** MNEM CONTENTS CN : ARCO AI,ASKA WN : ~2-9 ~N ~ PR~D~OM BAY RANG: TOWN: ]OM SECT: COLIN: M, SLOPE STAT: ALASKA CTRY: USA MNEM CONTENTS PRES: TDTGPFF 6"00 000 0 ~i 2 0'65 LVP 010.H02 VERIFICATION LISTING I ALAgKA CO~PL1T~NG CENTER COmPAnY = A?LA~TIC ~ICH~IF, b~ COmPAnY WELL = DS 1 ~I~LO = PRUDHOE BAY COUNTY = NORTH ~LOPE BOROUGH STATF = ALASKA ~OB NU~FR AT ACC~ 6gi60 RUN ~, DATE LOGGEDI 2~ APR 84 LDP~ d, KOHRTNG CAS!~G = 7,000" 97~4' TO 9524' TYPE FLUID CRUDE O~L (F~OWTNG) ~{'.:: FLUID 5EVEL = FULl, · TDT DATA DEPTH SHI.TED TO 8HC GAMMA R' - · *************************************** . · · $ bVP Ol0,H02 VERIFICATION LISTING I * T~ERMAL DECAY TIME (TDT - 5 PAStiES) * DATA FDRMA~ RECORD ~ ~YP~ ~I~ R~PR COD~ ~N~RY 8 4 73 60 9 4 65-: '--liN.::' .~ -_ ::~:: ':_ ':' ::~-:::~:' ::::: :: : 0 1 66 0 >:~ ::: :..: ~ ::.:~-:~ :'. :~ L: .:;: ==== ======== ======== ========= ======= ====== ==== ::~': ' :.~:.L~:::' · DATU~ Sp.~CTFICATION . .. :. · p - .... ~. -. ~_ ~ ..... ~N~:~ SERVICE SERVICE U~IT API API API API ~:~S:I .:::< .SS .:SA~P~ ~:~8 ::::::::::::::::::::::: ~>: :~::.: .: ..>: :::~>:~ ~:: :;:: ID oRDER ~ LOG TYPE CLASS MOD 'NO', 5~'VED CODE DEPT FT 0 0 SIG~ PS1 CU 0 FSIG PSi CU 0 0 TRAT PS1 0 42 GR p$1 GAPI 0 31 BACK DS1 CPS 0 0 FBAC PS1 CPS 0 0 ~TOT WTDT PSi $IC~ FSTG TRAT GR PS2 BACK FBAC PS2 NTDT PS? FTDT PS2 SIGM TRAT PS3 GR PS3 BACK PS3 FBAC NTDT PS3 WTDT SIG~ PS4 FSIG TRAT GR P$4 BACK FBAC MTDT PS4 FTDT P$4 SIGM PSq FSIG PS5 TRAT P$5 BACK FBAC PS5 NTDT PS5 FTDT GR 7E~ VERIFICATION DATA ** DEPT ~R FTDT FTDT WTDT FTDT FTDT DEPT GR FTDT 9441 5000 -~99 2500 -999 9500 -ogq ~500 -g99 500 -o9 : 5oo -999 500 -999 2500 -999 2500 -~gg,~LO0 -g99,~500 9400 0000 14!5352 185 O508 SIGM RACK SIGM RACK SlGM RACK BACK BACK BACK CPS 0 0 CPS 0 0 CU 0 40 CU 0 0 C, API 0 CPS 0 0 CPS 0 0 CPS 0 0 CPS 0 0 CU 0 4O CO 0 0 0 42 GAPI 0 31 CPS 0 0 CPS 0 0 CPS 0 0 CPS 0 0 CU 0 40 CU 0 0 0 4~ ~API 0 CPS 0 0 CPS 0 0 CPS 0 0 CPS 0 0 CU 0 40 CU 0 0 0 42 GAPI 0 3I CPS 0 0 CPS 0 0 CPS 0 o CPS 0 0 ~AP1 0 -999 -999 -999 -999 -999 -990 -999 -99g -999 ~50~ -999 ~50~ -O99'2500 I o o o 4 0 I 68 O. 0 '_ 0 '- iii: 4 : . : ::<::0 1:68:.? :- :~ ' ~ 1 0 0 4 0 ~ 68 0 0 : '- 0 >:,J · 4 ':: "?0' i -: i~: ~i' ::::::::::::::::::::::::: <:. :.'. ':': :.:' i: :i'! -: i_ I 0 0 4 0 1 68 32 0 ~:0 · 4 .: ::'. : :::::0 .: ,~-:.: ::t:: '. ;::;68::, :::<i.i::{: ::!i~-:::; :!h:'i!::::: .:::: ::' ~- - ~ 0 0 0 a 0 1 68 0 0 0 4 0 1 68 0 0 0 .: :~: 4~..~ :-: ~ : 0 ~ t:~:.~:::~'< ~::/<:~;~-;~<.~>'': ~'::':??:~ : 0 0 4 0 ~. 68 BAC 17,0332 :FSIG 55.3125 FBAC 17,7136 F$IG T LVP 010.H02 FTDT 173 ;R 73 ?TDT 199 ~TDT 1.79 ?TPT 179 3EPT WTDT FTDT FTDT ~R FTDT ~R WTDT 9300. 14. 197. 206. 49. 198 67 200 ?? 206 DEPT FTDT FTDT FTDT FTDT FTDT 1 1 1 00 17 8R 45 97 55 60 77 87 80 71 DEPT FTDT FTDT FTDT WTDT FTDT 9100 ~76 55 237 72 283 266 10~ 286 DEPT GR FTDT FTDT FTOT FTDT 9000 104 240 131 270 151 ~13 163 267 VErIFICATiON LISTING ~867 BACK 61ql SIGN R125 RACK 0156 SIGN 5000 RACK 1250 SIaM 3633 RACK 8643 GR 0000 SIGN 1577 RACK 9453 ~678 BACK 3672 SIGN O977 BACK 3574 SIGN g453 BACK 9701 1004 RACK 3203 0000 1406 BACK 1250 6~50 0000 0625 RACK ~500 SIGN 31~5 RACK 3750 81~5 BACK 5000 0000 SIGN 2613 BACK 7500 SI~M 6563 BACK 3750 00n0 BACK 0000 SIGN 7734 BACK 6250 SIG~ 1875 RACK 2500 ~R 0000 SZGM 6016 RACK 4375 SIGN 5000 BACK 7500 SIGN 7500 BACK 2500 SIC~ 0820 BACK 3750 SIG~ 1. ~500 FBAC 70.0000 NTDT ~03.6094 187;~294~$I~1 5<- ~16,i680 FBAC 8~.6875 NTDT 220,9844 243,1250 FBAC 92.6250 NTDT 225,1250 17.3074 238,0234 FBAC 92 3125 NTDT 215 12,2734 · F 7 1 9' NTD'- 206 783 7773 .BAC 3 ...0 4 ,~ '..T . . 2 015:9 FSIG -~: :i 9~ i ~ ~' ~ i~~ ::_ 5625 rBhd ~'3.t'875 NT.'DT 226,7852 2383 FBAC 87,5508 ~TDT ~220,8145 ~250 FBAC 93'06~5 NTDT 221,5703 86. 17, I. 7214 1 196 24 19 18 0000 FBA~ 37,~187 NTD~ 204,7500 75O0 PBAC 83 7188 FSIG 3750 WBAC 88 I~94 F$IG 50 FOAC 13l 1250 l 8 i 719 236 6256 243 9506 F~A~ !0'9.50'00' 'NTDT 295, 237 FBAC 110:8125 NTDT 322, 31, 150, 31, 220, 31, 24O 31 75'00 0000 93261445 FSTGtBAC 6250 FSI.G - !:1..'-- T/:' :' :;'?'4 OJ~O~'.::::: ::'~;~< :.. :::. ~:. ::- - 25oo raac !i~2 ;"7~06 NgDT 484,'7500 6250 FBAC 1 ~0; 8'i'2~ "~'TDT 382;50'00 0469 FBAC ~6~99~2 N~ D'T 45~,5000 7 422 rS IG LVP 010.H02 VERIFICATION LISTING ~EPT rTDT :TDT -'TDT ~R }TDT P'TOT 8900,0000 SIGN lJO,OSg8 ~ACK 278,4375 SIGN 134 7930 BACK 26911445 SIGM 14g 3750 BACK 270 5000 SI~N 1.6t,0313 BACK 258,3672 SIGN ~92.0000 BACK 282.0000 CR )EPT FTDT ~R ?TDT ~TDT ~R ?TDT 889!0000 SIGN qgq 9500 BACK qgg 2500 SIGN -Egg 2500 BACK -099.2500 SIGN -qgg.2500 BACK -999.~5~0 SIGN -999 9500 BACK -999:2500 -q99 2500 ~ACK -Egg:2500 GR ** FILE TRAILER ** ~ILE NA~E ~EDIT .001 SERVICE ~AUE : VERSION # : )ATE : MAXIMU~ LENGTH : 1024 ?ILE TYP~ : .4EXT FIL~ NAME : ** TAPE TRAILER ** SERVICE NAME :EDIT DATE :~4/05/ 9 ORIGIN 20000 TA~E NAME :g~60 CONTI~UATION # ~0! 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