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Home My WebLink About182-136 BP Exploration Alaska Inc Well: 13-34 Field: Prudhoe Bay North Slope, Alaska, USA Report Production Array Log Analysis Prepared For : BP Exploration Alaska Inc Logging Date : 10/26/2013 Report Date : 11/15/2013 Submitted by: Waqar Khan Phone: +1(281)575-5051 10200 Bellaire Blvd, Houston, Texas-77072 Email: waqar.khan2@halliburton.com HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF BP Exploration Alaska Production Array Log Analysis 1 TABLE OF CONTENTS 1.0 EXECUTIVE SUMMARY ............................................................................................................................. 2 2.0 BACKGROUND AND OBJECTIVES .......................................................................................................... 3 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT ............................................................ 4 4.0 PRODUCTION LOG PROCESSING ........................................................................................................... 7 4.1 FLOWING SURVEY ...................................................................................................................................... 9 BP Exploration Alaska Production Array Log Analysis 2 1.0 EXECUTIVE SUMMARY Production logging was done in Well 13-34 on October 26th, 2013 in flowing conditions with the objective to estimate the production profile. As the well is deviated, Resistance Array Tool (RAT) and Spinner Array Tool (SAT) were included in the tool string to accurately estimate the holdup and phase velocities as there can be segregated flow of the three phases due to well deviation. The flowing PL analysis showed the oil production to be coming from the second set of perforations (9102-9142 ft). This set of perforation is contributing about 90% of the total flow. The bottom set of perforations (9156-9216 ft) are only producing water. It’s contributing to 5% of the total water produced with the majority of the water coming from the second set of perforations. For the analysis, SAT and RAT along with the gas holdup tool were used to separate out the three phases. The reported surface production while running the PL was 232 STB/D oil and 2523 BPD water with 319 MSCF/D. Based on the well test data during logging, the well is slugging severely. The estimated flow rates at surface condition while flowing from each of the perforations and the production profile is given in the table below: feet Profile Qp-Water-STP Qp-Oil-STP Qp-Gas-STP BFPD BFPD MCFD 9026.50 9043.00 Produce 178 0 93.3 9102.00 9142.50 Produce 3172 353 562 9156.00 9203.00 Produce 190 .214 11.3 BP Exploration Alaska Production Array Log Analysis 3 2.0 BACKGROUND AND OBJECTIVES The objective for running the PL was to identity the production profile to identity options for increasing the oil and gas production. BP Exploration Alaska Production Array Log Analysis 4 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT Well 13-34 is completed with 7 inch production liner across which the production log was run. The wellbore schematic is presented in the Figure 1. The tool string diagram used for the PL logged is presented in Figure 2. The tool string consisted of the following production logging sensors: Gamma Ray - Casing Collar Locator – Pressure - Resistance Array Tool – Gas holdup – Caliper - Spinner Array Tool – Radioactive Density –Capacitance Water Holdup – Temperature – Caged Fullbore Spinner. The data quality is summarized below TOOL USAGE LOG DESCRIPTION LOG QUALITY REMARKS WELL BORE PARAMETERS QP Well bore pressure Good Pressure readings varied b/w UP and DOWN passes TEMP Well bore temperature Good Temperature readings varied b/w UP and DOWN passes FLUID TYPE FDR Radioactive density tool uses radioactive source and detector to measure density and is a center sample device Good Density tool is pretty consistent b/w the UP and DOWN passes except at the top perforation, at which, density increases for DOWN passes whereas it decreases for UP passes CWH Uses capacitance to measure the differences between hydrocarbons and water Good Capacitance tool is also behaving as the density tool after the top perforation RAT Resistivity Array Tool Good UP passes see a lot more hydrocarbons than DOWN passes GHT Gas HoldUp Tool Good Behaves similar to density tool after the top perforation FLUID VELOCITY CFB Caged Fullbore Spinner Good Owing to the slugging nature of the well, CFB is not able to read continuously. This becomes more apparent in the station measurements SAT Spinner Array Tool Good Slugging nature of the well prevents the spinner from reading a continuous increasing profile. . BP Exploration Alaska Production Array Log Analysis 5 Figure 1: Wellbore Schematic BP Exploration Alaska Production Array Log Analysis 6 Figure 2: PL Toolstring BP Exploration Alaska Production Array Log Analysis 7 4.0 PRODUCTION LOG PROCESSING The production log data from the flowing were processed using the PLATO software. The software uses a global probabilistic method for the production log analysis. In this method, known as the Maximum Likelihood method, a well flow model is compared to all available data and improved, by optimization, until the best possible match with the data is obtained. By using this method the result is the most likely interpretation. A comparison between the model and the data is shown in this report and allows the analyst or the reader to determine validity of the answer obtained. Potential sources of discrepancies include tool measurement errors, conflicts between the parameters or conditions that make the underlying empirical models (such as flow regimes) less applicable.  The flow regimes were determined, directly from the flow rates and holdups, according to the Taitel- Dukler analytic model.  The profile factors, to calculate the true fluid velocity from the apparent velocity, were based on the Reynolds numbers.  Solution gas in oil was derived from the correlations (Vasquez-Beggs or Øistein- Glaso). The analysis was performed in six steps:  The data preparation to filter the data, compute gradients and error estimates.  The calibration of the array tools and full-bore flow meter.  The computation of the layered holdup and layered flow-rates.  The profile determination to identify the potential producing and/or injecting zones.  The computation of the flow rates by global optimization.  The computation of surface productions and reporting. BP Exploration Alaska Production Array Log Analysis 8 The water density and viscosity were calculated using a salinity of 20000 ppm. The Craft & Hawkins correlation was used. The oil density and viscosity were calculated using an oil gravity of 25.7 API. The Vasquez & Beggs correlation was used to calculate the solution gas. Viscosity was calculated using the Beggs & Robinson correlation. The Pc and Tc parameters were calculated using the Brown et al. correlation. The gas viscosit y was calculated using the Lee Gonzales Eakin correlation. The following gas parameters were used: GasType Miscellaneous SPGG UNITY .750 GP-CO2 UNITY 0 GP-H2S UNITY 0 GP-Nitrogen UNITY 0 Utilizing the above fluid information, measured down hole oil density, temperature & pressure, the following fluid properties were calculated at well conditions: feet Twf Pwf Bwater water water Boil oil oil Rsb Bgas gas gas °F psi UNITY g/cc cP UNITY g/cc cP ft3/bbl UNITY g/cc cP 9010.00 217 2038 1.04 .978 .295 1.35 .754 .703 743 .00848 .108 .0171 9031.50 217 2047 1.04 .978 .295 1.35 .754 .703 743 .00844 .109 .0171 9053.00 217 2058 1.04 .978 .295 1.35 .754 .702 743 .00839 .109 .0171 9074.50 217 2068 1.04 .978 .295 1.35 .754 .703 743 .00835 .110 .0172 9096.00 217 2082 1.04 .978 .295 1.35 .754 .703 743 .00829 .111 .0172 9117.00 217 2101 1.04 .978 .294 1.35 .754 .702 743 .00823 .111 .0173 9138.50 218 2133 1.04 .977 .293 1.35 .754 .700 743 .00812 .113 .0174 9160.00 218 2183 1.04 .977 .293 1.35 .754 .700 742 .00794 .116 .0175 9181.50 218 2238 1.04 .978 .292 1.35 .754 .700 742 .00774 .118 .0177 9203.00 219 2138 1.04 .977 .292 1.35 .754 .699 742 .00811 .113 .0174 To estimate the flow rates, the caliper log recorded during the UP passes was used to estimate the nominal ID throughout the log. BP Exploration Alaska Production Array Log Analysis 9 4.1 FLOWING SURVEY The raw data from the flowing survey are presented in the Figures 3 to 8. Figure 3 has the data from conventional production logging sensors. Figure 4 has the same data that was presented in Figure 3 with the addition of the station measurements. To generate this plot, Emeraude software was used which allows overlay of the station measurements and the logging passes in the same track. Plato can only plot the st ation measurement against time. The spread in the station measurements indicate the well is in a slugging condition. Figure 4a shows a zoomed in view of station measurements at 9090 ft. The fullbore spinner along with the density and pressure measurements are plotted against time. As a slug of water passes through the density tool, an increase in pressure is observed. As pressure increases, the fullbore is unable to spin properly. This can be attributed to water dropping down, causing the spinner to rotate in an opposite direction. For the interpretation, UP 30, 60 and DOWN 30, 60 passes have been used since they indicated a consistent response. Down 60 and 90 passes showed an erratic response across the middle perforation, whereas UP 60 and 90 passes indicated movement across the bottom perforation, which wasn’t seen on any of the other passes. The response from the Resistance Array Tool is presented in Figure 5. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values. Only the active sensors were used in the interpretation. Figure 6 shows only the active RAT sensors along with the station measurements. The response from the Spinner Array Tool is presented in Figure 7. The fullbore spinner did not respond well owing to the slugging nature of the well. Figure 8 shows the station measurements. The bottom perforation was not able to be logged fully. Valid spinner data is available till 9207 ft. After depth matching the cased hole gamma ray with the open hole gamma ray, a depth shift of 4 ft in the upward direction occurs, limiting the data to 9203 ft. From the raw data it is clear that most of the production is coming from the top two perforations. All the spinners show a big change across 9128 ft. with slight increase observed across the top perforation as well. The density, Capacitance and RAT all indicate possible oil production from these two perforations. From the spinner response, the velocity profile was estimated using the slopes calculated from the spinner calibration (Figures 9 and 10). Velocity is highest across the 2nd perforation, indicating this zone as the main contributor. The calibrated RAT response is presented in Figure 11. Above the top perforations, evidence of oil flow towards the top is seen from the RAT response. The estimated SAT velocities and the RAT holdups are used to calculate the flow profile presented in the Figure 12. The final flow profile, after the global optimization, along with the comparison of the measured and theoretical tool values are presented in Figure 13. BP Exploration Alaska Production Array Log Analysis 10 The production rates at surface conditions estimated from the production log analysis are presented in Figure 14 and are summarized in the table below: Depth Profile Q-Water- STP Qp-Water- STP Q-Oil- STP Qp-Oil- STP Q-Gas- STP Qp-Gas- STP feet BFPD BFPD BFPD BFPD MCFD MCFD 9568.00 9588.00 Produce 8196 6327 327 308 103 93.8 9602.00 9634.00 Produce 1870 1870 19.1 19.1 8.82 8.82 9640.00 9650.00 Produce 0 0 0 0 0 0 Raw Data - The figure below summarizes the input data recorded at the well site. - Each pass is shown with a fixed predefined color. Figure 3: Input data from the conventional production logging sensors BP Exploration Alaska Production Array Log Analysis 11 Figure 4: Input data from the conventional production logging sensors along with the station measurements. BP Exploration Alaska Production Array Log Analysis 12 Figure 4a: Station measurements at 9090 ft. BP Exploration Alaska Production Array Log Analysis 13 The figure below shows the RAT input data. The first track shows the RAT rotation curves for each pass. The next tracks show the RAT data: A curve for each pass for each of the 12 probes. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values and were not used in the interpretation. Figure 5: Input data from the Resistance Array Tool (RAT) BP Exploration Alaska Production Array Log Analysis 14 Figure 6: Input data from the Resistance Array Tool (RAT) showing just the active sensors along with station measurements BP Exploration Alaska Production Array Log Analysis 15 The figure below shows the SAT input data. The first track shows the SAT rotation curves for each pass. The next track shows the linespeed for each pass. The remaining tracks show the array spinner data: A curve for each pass for each of the 6 array spinners, for the fullbore spinner (ASpinner07) and for the inline spinner (ASpinner08). The fullbore spinner does not appear to be turning well and its response is not consistent with the remaining spinners. This was not used in the analysis. Figure 7: Input data from the Spinner Array Tool (SAT) and conventional spinners. BP Exploration Alaska Production Array Log Analysis 16 Figure 8: Input data from the Spinner Array Tool (SAT) and conventional spinners along with the station measurements. BP Exploration Alaska Production Array Log Analysis 17 Calibration of Spinner Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and measured Array Tool responses. Track 2: Line-speed for each pass. Track 3: 'Unwrapped' rotation curve for each pass. Track 4: Normalized layered velocity profile. This profile is optimized by comparing the measured and theoretical SAT response for each pass of each spinner. Tracks 5-10: Measured and theoretical SAT responses for each spinner. Track 11: Measured and theoretical responses for the full-bore spinner. Track 12: Measured and theoretical responses for the inline spinner. Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity profile. Figure 9: Velocity profile from SAT data. The image below displays cross plots for each SAT spinner and the Inline spinner. The estimated slopes are used for converting the spinner response to flow velocities. BP Exploration Alaska Production Array Log Analysis 18 Figure 10: Spinner cross plot BP Exploration Alaska Production Array Log Analysis 19 Calibration of Resistance Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and the measured RAT responses. Track 2: 'Unwrapped' rotation curve for each pass. Track 3: Normalized layered RAT profile. This profile is optimized by comparing the measured and theoretical RAT response for each pass for each probe. Tracks 4-15: Measured and theoretical RAT responses for each probe. Below are the results from the calibration of the RAT data. The determination of this calibration is a layered resistivity profile. To obtain this profile, calibrations for water/ hydrocarbon were entered for each probe. Figure 11: Calibrated RAT response. BP Exploration Alaska Production Array Log Analysis 20 Holdup and Velocity Profile: Shown on the image below from left to right: Track 3: Layered velocity profile. Track 4: Layered water holdup profile. Track 5: Layered oil holdup profile. Track 6: Layered gas holdup profile Track 7: Total holdup. Track 8: Cumulative flow rates Track 9: Density of fluid Track 10: Apparent Velocity from Fullbore Spinner Figure 12: Holdup and velocity profile BP Exploration Alaska Production Array Log Analysis 21 Flow Profile The quantitative production rates were determined by comparing the well flow model with all available data. The figure below is provided to verify the agreement of the flow model with the data. In this figure the data is represented by the blue curves, while the calculated tool values are shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. The small fluctuations around the data are to be expected, since the tools have intrinsic errors. Large sustained discrepancies indicate problems with the data, conflicts between parameters or conditions that make the underlying empirical models less applicable. To the right of the figure the flow regimes are shown. Within the transition zones several regimes can exists intermittently. Figure 13: Flow profile at reservoir conditions BP Exploration Alaska Production Array Log Analysis 22 The production rates at surface conditions are presented in the figure below: Figure 14: Flow profile at surface conditions • �. bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 August 10, 2012 — � Mr. Jim Regg v EG ENED Alaska Oil and Gas Conservation Commission NOG 1 5 7.12 333 West 7 Avenue Anchorage, Alaska 99501 AQGGG Subject: Corrosion Inhibitor Treatments of GPB DS -13 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 13 were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659-5102. Sincerely, Mehreen Vazir BPXA, Well integrity Coordinator 0 • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -13 Date: 10131/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal 13-02B 1990110 50029203246000 Sealed conductor NA NA NA NA NA 13-03A 2090480 50029203250100 Sealed conductor NA NA NA NA NA . 13 -04 1780630 50029203260000 Sealed conductor NA NA NA NA NA 13 -05 1811030 50029206260000 Sealed conductor NA NA NA NA NA 13 -06A 1972180 50029206420100 Sealed conductor NA NA NA NA NA 13 -07 1811290 50029206500000 Sealed conductor NA NA NA NA NA 13-08A 1982150 50029206670100 Sealed conductor NA NA NA NA NA 13-09 1811580 50029206710000 Sealed conductor NA NA NA NA NA 13 -10 1811650 50029206780000 Sealed conductor NA NA NA NA NA 13-11 1810760 50029206040000 0.0 NA 0.0 NA 11.1 10/31/2011 13 -12 1801420 50029205380000 Sealed conductor NA NA NA NA NA 13 -13A 2030360 50029208520100 0.4 NA 0.4 NA 11.1 10/31/2011 13 -14 1821710 50029208450000 2.0 NA 2.0 NA 13.6 10/6/2009 13 -15 1821570 50029208310000 Sealed conductor - NA NA NA NA NA 13-16 1821480 50029208230000 0.4 NA 0.4 NA 13.6 10/31/2011 13 -17 1820260 50029207180000 Sealed conductor NA NA NA NA NA 13-18 1820350 50029207240000 Sealed conductor NA NA NA NA NA 13 -19 1811800 50029206900000 Sealed conductor NA NA NA NA NA 13 -20 1820090 50029207050000 Sealed conductor NA NA NA NA NA 13 -21 1820530 50029207890000 Sealed conductor NA NA NA NA NA 13 -22 1820770 50029207490000 Sealed conductor NA NA NA NA NA 13 -23A 1820230 50029207150000 Sealed conductor NA NA NA NA NA 13-24A 2042430 50029207390100 Sealed conductor NA NA NA NA NA 13-25 1820910 50029207610000 Sealed conductor NA NA NA NA NA 13 -26 1820740 50029207460000 Sealed conductor NA NA NA NA NA _ 13-27 1961210 50029209490200 17.0 NA 17 NA 130.9 11/22/2009 13 -28 1830600 50029209420000 5.0 NA 5.0 NA 144.5 11/19/2009 13 -29L1 2020690 50029209286000 Dust Cover NA NA NA NA NA 13-30C 2080870 50029207680300 Sealed conductor NA NA NA NA NA 13-31A 2051600 50029224590100 0.5 NA 0.5 NA 3.4 10/6/2009 13 -32A 2012350 50029207980100 0.0 _ NA 0.0 NA 10.2 10/31/2011 13 -33 1821060 50029207730000 5.2 NA 5.2 NA 27.2 11/17/2009 __-7 13-34 1821360 50029208110000 0.3 NA 0.3 NA 11.1 10/31/2011 13 -35 1940410 50029224600000 0.9 NA 0.9 NA 5.1 11/17/2009 _ 13 -36 1951670 50029226130000 0.0 NA 0.0 NA 4.3 10/31/2011 13 -37 2100820 50029234280000 3.8 NA 3.8 NA 33.2 10/31/2011 13 -98 1822070 50029208780000 1.0 NA 1.0 _ NA 5.1 10/6/2009 • • RECEIVED STATE OF ALASKA APR 10 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon 11 Repair Well Li Plug Perforations 11 Perforate J Other LJ Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska) Inc. Development © Exploratory ❑ - 182 -136 3. Address: Stratigraphic Service ❑ 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20811 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 028315 .. PBU 13 -34 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): .. Prudhoe Bay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 95 feet Plugs measured NONE feet true vertical 9275 feet Junk measured 9212 feet Effective Depth measured 9230 feet Packer measured 8385, 8539, 88OQfeet true vertical 8982 feet true vertical 8147,8299, 8557feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 94# H -40 31' - 110' 31' - 110' 1530 520 Surface 2555' 13 -3/8" 72# L -80 30' - 2585' 30' - 2585' 4930 2970 Intermediate Production 8963' 9 -5/8" 47# SOO -95 29' - 8992' 29' - 8747' 8150 5080 Liner 4050' 7" 29# L -80 5473' - 9523' 5355' - 9273' 8160 7020 Perforation depth Measured depth SEE ATTACHED feet True Vertical depth feet 4 -1/2" 12.6# 13Cr80 8814' 8571' Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 8894' 8650' 4 -1/2" BKR S -3PKR 8385' 8147' Packers and SSSV (type, measured and true vertical depth) 4 -1/2" BKR S -3 PKR 8539 , 8299' 5 BKR FB -1 PKR R800 8557 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: E APR .. 6 ?0 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 176 381 2544 301 Subsequent to operation: 179 416 2763 3 04 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development ® - Service ❑ Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work: - Oil ® Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name ' to S mr rhays Title Data Manager Si .riii05.0777 �IAnd_ Phone 564 -4035 Date 04/06/2012 ,,ely, Form 10-404 Revised 11/2011RB ®MS APR 1 1 20 12 / j7 -R- Submit Original Only • • 13 -34 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY • i i �PJO ,. � �.., WMI i cy.' s � 2/14/2012,T/I/0= 1350/1640/540 Temp =130 Freeze Protect for Slickline (PERFORATING) 1 Pumped 38 bbls Crude Down Tbg for FP. Pumped 3 bbls meth down Flowline !followed with 114 bbls Crude, 3 bbl Meth Trail for FP. Pressure Flowline to 1500 psi. DSO notified SV, WV, SSV, AL =C. MV= 0. IA, 0A= OTG. 1 FW HP= 1100/16400/540. 2/14/2012, ** *WELL S/1 ON ARRIVAL * ** RAN 20' x 2.5" DMY GUN, TEL, 2.5" S. BAILER, TAGGED TT @ 8,885' SLM :(8,906' ELM) +21' COR. TAGGED HARD BTM @ 9,210' SLM (9,231' ELM) —15' OF RAT HOLE, RECOVERED TWO SMALL PEBBLES IN BAILER ** *WELL LEFT S/I ON DEPARTURE * ** 3/14/2012 ; ** *WELL SHUT IN ON ARRIVAL * ** (E -LINE PERFOREATION) 3/18/2012 ** *WELL SHUT IN UPON ARRIVAL * ** (E -LINE: PERF) 'INITIAL TWO = 1500/1350/550 PSI CURRENTLY RIGGING UP ELINE UNIT TO PERF ** *JOB IN PROGRESS * ** 3/18/20121T/I/0 = 1490/1400/500. Temp = SI. T & IA FL (E -Line Call in). AL Shut in @ casing valve. TBG FL @ 8234'(STA # 1, S /0) (127 bbls). IA FL @ 8234'(STA #1, S /0) (446 bbls). SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 1200 3/19/2012' ** *JOB IN PROGRESS * ** E -LINE: PERF PERF INTERVAL = 9027' - 9043', CCL TO TOP SHOT = 7.3' AND CCL STOP DEPTH = 9019.7'. GOOD INDICATION AT SURFACE OF FIRING. 'FINAL TWO = 1460/1350/550 PSI `FINAL VALVES POSITION = SWAB, WING, GAS LIFT = CLOSED, SSV, :MASTER, CHEM INJECTION = OPEN ** *JOB COMPLETE * ** WELL SHUT IN UPON DEPARTURE FLUIDS PUMPED BBLS 1 DIESEL 14 METH 15 TOTAL 13 -34 182 -136 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 13 -34 2/9/83 PER 9,156. 9,216. 8,909.13 8,968.58 13 -34 2/22/86 APF 9,102. 9,142. 8,855.64 8,895.26 13 -34 8/29/91 APF 9,031. 9,035. 8,785.33 8,789.29 13 -34 8/29/91 RPF 9,116. 9,126. 8,869.51 8,879.41 13 -34 8/29/91 RPF 9,156. 9,166. 8,909.13 8,919.03 13 -34 7/29/98 APF 9,312. 9,330. 9,063.75 9,081.61 13 -34 1/28/03 SPS 9,230. 9,480. 8,982.45 9,230.55 13 -34 9/8/07 BPS 8,774. 8,775. 8,530.97 8,531.96 13 -34 9/20/07 BPP 8,774. 8,775. 8,530.97 8,531.96 13 -34 9/21/07 BPS 9,230. 9,480. 8,982.45 9,230.55 • 13 -34 3/19/12 APF 9,027. 9,043. 8,781.37 8,797.22 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • TREE OW • SAFETY OS:** *4- 1/2 " CHROME TBG** *2008 RW O WELLHEAD = BAKERY 13-34 ACTUATOR = BAKER C DOYON 1 SU RKB RFA --CE T 8479') ARE CORRECT TO KB. ELEV = 87' , BE ELEV = 11 11 KOP= 2900' 11 �1 1857' H9-5/8" HES CEMENTER I .1 Ma x Angle = 19° © 5800' 20" CONDUCTOR, H 79' 1- •I 4 Datum NO = 9134' 94 #, H -40, Datum TVD = 8800' SS ID = 19.124" P r 1 2116' H 4-1 /2" HES X NIP, ID = 3.813" 19 -5/8" CSG, 47 #, L -80 HYD 563, ID = 8.681" H 1873' ■ GAS LIFT MANDRELS STj NO TVD DEV TYPE VLV LATCH PORT DATE 113 -3/8" CSG, 72#, L80 BUTT, ID = 12 347" H 2585' 6 2851 2850' 8 MMG DONE RK 16 05/25/09 5 4559 4484 18 NIMG DMY RK 0 0525/09 1TOP OF 7" LNR- TIEBACK I 5473' *4 5633 5507 19 KBG2 DONE BK 16 05/25/09 *3 6500 6329' 18 KBG2 DNIY BK 0 081330/08 Minimum ID = 2.75" @ 8881' o t4 *2 7325 7115 " 16 KBG2 DONE BK 16 05/25/09 3 -1/2" OTIS XN NIPPLE '4 1 8234 7998 10 KBG2 SO BK 20 05/25/09 ■ • 4 *STA's #1 - #4 = GLM'S HAVE SPECIAL CLEARANCE, ID= 3.938' I 9 -5/8" CSG, 47 #, L -80 XO TO SOO -95 -1 • / 1 / I ; N 8354' I-14-1/2" HES X NIP, ID = 3.813" • • � 4 -1/2" TBG, 12.6#, 13CR -80 VAM TOP, -I 8479' 11� �� 8385' ,-17" X 4-1/2" BKR S -3 PKR ID = 3.870" 0152 bpf, ID = 3.958" ∎ • ; I 8418' 1- 14 -1/7' HES X NIP, ID = 3.813" 14 -1/2" TBG STUB (TAGGED08 /18/08) -1 8483' / � � GAS LIFT MANDRELS 'i 1 8494' 1-1 X 4 -1/2" UNK�UEOVERSHOT ST NC TVD DEV TYPE VLV LATCH PORT DATE ■ �, �� '8513 8273 9 KBG2 -LS DMY BK 0 ' , ■ I 8539' 1-1 X 4 -1/2" BKR S -3 PKR, ID = 3.875" —� —� " NOT OPERABLE - ISOLATED BY Plot (a 1 8385' 1 ( 1 14 ... 7" TIEBK LNR, 29 #, L -80 BTC, 8704' I 8774' H4 -1/2" CAM DB XN NIP, ID = 3.50" 1 0371 bpf, ID = 6.184 17" BOT LNR HGR -1 8710' 1 ' I 8795' -14-1/2" X 3-1/2" XO, ID = 2.992" 1 8811' 4 -1/2" BKR GBH -22 SEAL ASSY W/O SEALS, 4-1/2" TBG, 12 6 #, 13CR -80 NSCT, -I 8795' ' ID = 2.992" .0152 bpf, ID = 3.958" e 8800' --17" X 5" BKR FB -1 PKR w/ SEALBORE EXT, ID = 4.00 I MI 8813' - 15 -5/8" MILLOUT OCT, ID = 4.00" 3 -117" TBG, 9.3 #, L -80 8RD AB-MOD -1 8894' 1 1 8814' - 15-5/8 "X3-1 /2" XO, ID = 2.992' I .0087 bpf, ID = 2.992" 19 -5/8" CSG, 47 #, SOO -95 BTRS, ID = 8.681" 8992' I 8881' H3-1/2" OTIS XN NIP, ID = 2.75" I PERFORATION SUMMARY 8893' -I3 -112" BKR SHEA ROUT SUB REF LOG: BHCS ON 09/08/82 ' I 8894' H3-1/2" TUBING TAIL, ID = 2.992" I ANGLE AT TOP PERF: 8° @ 9027' 8906' H ELMD TT LOG ON XX/XX/XX 1 Note: Refer to Production DB for historical perf data SIZE SR= INTERVAL Opn/Sgz DATE 1 2' 6 9027 - 9043 0 03/19/12 ( 9046' -17" DOUBLE MARKER JOINT 2 -5/8" 2 9031 - 9035 0 08/29/91 1 3-1/8" 4 9102 - 9142 0 02/22/86 2 -5/8" 4 9116 - 9126 0 08/29/91 1 2 -5/8" 4 9156 - 9166 0 08/29/91 3-1/8" 4 9156 - 9216 0 02109/83 ;1 ;1 ;1 ;1 ;1 ;1 ;1;,. 9230' -I CLA SS G CEMENT CAP - 01/28/03 1 2 -1/8" 4 9312 - 9330 C 07/12/98 _ 9268' --1TOP OF SAND (CARBOLITE) - 01/28/03 1 9212' SLM I- - IFISH - CA -E 1" DGLV (LATCH PULLED) (08/12/95) 1 1 PBTD -1 9480' $ .1 4 . • • ..1 011. • 17" LNR, 29 #, L -80 BTRS, .0371 bpf, ID = 6.184" H 9523' DATE REV BY CONINENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/11/82 ROWAN 41 ORIGINAL COMPLETION 06/02/09 JLJ/TLH GLV C/O (05/25/09) WELL 13 -34 06/15/88 AUDI 1 WORKOVER 1220/10 NG/JN) ADDED SSSV SAFETY NOTE PERMIT No. 1821360 02/13/96 D-16 LAST WORKOVER 02/09/11 MB /JNt) REMVDSSSV SAFETY NOTE AR No: 50 -029- 20811 -00 08/31/08 D-16 RWO 03/20/12 JTC/JMD ADPERF (03/19/12) SEC 14,110N, R14E, 2226' FSL & 1561' FEL 10/20/08 PJC DRAWING CORRECTIONS 10/23/08 LJH/PJC 9 -5/8" CSG CORRECTIONS BP Exploration (Alaska) OPERABLE: 13-34 (PTD #1860) OA Pressure Stabilization • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ,.~ Sent: Tuesday, October 14, 2008 3:36 PM ~~~) To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 DS Ops Lead; GPB, FS3 OTL; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: Bommarito, Olivia O; Holt, Ryan P (ASRC); Reem, David C; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 13-34 (PTD #1821360) OA Pressure Stabilization Follow Up Flag: Follow up Flag Status: Yellow /-CJ:T2 All, Well 13-34 (PTD #1821360) has been reclassified as Operable. Bleed operations were conducted on the OA between 09/20 and 10/11. Since then, the wellhead pressures have been monitored and the OA pressure has stabilized below MOASP. The source of the OA repressurization is suspected to be a shallow gas zone and a repair option is currently being evaluated for this well and others like it. Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Sunday, September 21, 2008 7:43 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr Central (GCl/3/FS3); GPB, FS3 DS Ops Lead; GPB, FS3 OTL; Rossberg, R Steven; Engel, Harry R; Daniel, Ryan; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: Bommarito, Olivia 0; NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Reem, David C Subject: UNDER EVALUATION: 13-34 (PTD #1821360) Sustained OA Casing Pressure All, Well 13-34 (PTD #1821360) has been found with sustained casingpressure on the OA. The TIOs were SSV/1640/1230 psi on 09/20/08 when an OA bleed was performed. The OA was cemented Burin a recent work over to repair the previous IAxOA communication. Initial analysis of this wel hasT d-us to conclude the Is not being repressured by the IA. Annular gas sampling was conducted and found that the OA gas has a higher methane content and no C02 as is seen in the IA qas. The well has been reclassified as Under Evaluation and placed on a 28-day clock while diagnostics continue. The plan forward for the well is as follows: 1. D: Maintain an open bleed on the OA - In progress 2. F: MIT-OA to 2000 psi, LLR if fails 3. WIE: Evaluate for possible Seal-Tite repair 4/16/2009 OPERABLE: 13-34 (PTD #1860) OA Pressure Stabilization • Page 2 of 2 A wellbore schematic and TIO plot have been included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 4/16/2009 PBU 13-34 PTD 182-136 9/21 /2008 TIO Pressures • • TREE = CM/ WELLHEAD= MCEVOY ACTUATOR= BAKERC KB. ELEV =~ 8T BF. ELEV KOP = __ 2900' Max Angle- 19° @ 5600' Datu Datu i - 20" CONDUCTOR, -I 79, m MD - 9134'. g4#, H-40, ID = ? m TV D = 8800' SS 9-5/8" CSG, 47#, L-80 HYDRIL 563, 1873' ID = 8.681" (RWO 08/31/08) 13-3/8" CSG, 72#, L80 BUTT, ID = 12.347" 2585' Minimum ID = 2.75" @ 8881' 3-1 /2" OTIS XN NIPPLE TOP OF 7" LNR-TIEBACK 5473' SAF TES: *'4"-1/2"CHROMETBG** 13 -34 CORRECTOTO DOYON 16RRKBE 20 5579') ARE 1777' 9-518" HES CEMENTER 2116' -j 4-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 2851 2850 8 MMG DOME RK 16 09101!08 6 4557 4484 18 MMG S/O RK 20 09101 /08 5 5643 5507 19 KBG2 DMY BK 0 08/30/08 4 6500 6329 18 KBG2 DMY BK 0 08/30/08 3 7324 7115 16 KBG2 DMY BK 0 08/30/08 2 8234 7988 10 KBG2 DMY BK 0 08/30/08 1 8513 8273 9 KBG2 DMY BK 0 4-1/Z" x 1" KBG-2-LS GLMs = 3.ti5" ID 9-5/8" CSG, 47#, L-80 XO TO 50095 ~~ $2$$' 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, I 8479' 0152 bpf, ID = 3.958" 7" TIEBK LNR, 29#, L-80 BTC, $704' .0371 bpf, ID = 6.184 7" BOT LNR HGR 8710' 4-1/2" TBG, 12.6#, 13CR-80 NSCT, 8795' .0152 bpf, ID = 3.958" 3-1/2" TBG, 9.3#, L-80 8RD AB-MOD -1 8894• .0087 bpf, ID = 2.992" 9-5/8" CSG, 47#, S0095 BUTT, ID = 8.681" PERFORATION SUMMARY REF LOG: BRCS ON 09/08/82 ANGLE AT TOP PERF: 8° @ 9031' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-518" 2 9031 - 9035 O 08/29/91 3-1/8" 4 9102 - 9142 O 02/22/86 2-5/8" 4 9116 - 9126 O 08/29/91 2-518" 4 9156 - 9166 O 08/29/91 3-1/8" 4 9156 - 9216 O 02/09/83 2-1/8" 4 9312 - 9330 O 07/12/98 PBTD 9480' 7" LNR, 29#, L-80 BUTT, .0371 bpf, ID = 6.184" 9523' $3$4' - j4-1/2"HES X NIP, ID = 3.813" 8385' 7" X 4-1/2" BKR S-3 PKR, ID = 3.870" 8418' 4-1/2"HES X NIP, ID = 3.813" 8494' 7" X 4-1 /2" UNIQUE OV ERSHOT 8539' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" $774' 4-1/2" CAM DB XN NIP, ID = 3.50" 8795' 4-1/2" X 3-1/2" XO, ID = 2.992" 8811' 4-1/2" BKR GBH-22 SEAL ASSY W/O SEALS 8800' 7" X 5" BKR FB-1 PKR w / SEALBORE EXT, ID = 4.00 8813' 5-5/8" MILLOUT IXT, ID = 4.00" 8814' 5-5/8" X 3-1/2" XO, ID = 2.992" 8881' 3-1/2" OTIS XN NIP, ID = 2.75" $$93' 3-1/2" BKR SHEAROUT SUB 8894' 3-1/2" TUBING TAIL, ID = 2.992" 8906' ELMD TT LOG NOT AVAILABLE 9046' ~~ 7" DOUBLE MARKER JOINT 9230' 11CLASS G CEMENT CAP- 01/28/03 I 9268' TOP OF SAND (CARBOLITE) - 01/28/03 9212' SLM FISH - CA-E 1" DGLV (LATCH PULLED) (08/12/95) DATE REV BY COMMENTS DATE REV BY COMMENTS 09/11/82 OWAN 4 ORIGINAL COMPLETION 09/02/08 JCM/TLH GLV C/O & CORRECTIONS 06115/88 AUDI 1 WORKOVER 09/19/08 AW/JMD DRLG DRAFT CORRECTONS 02/13/96 D-16 LAST WORKOV ER 08/31/08 D-16 RWO 08/05/08 JKD/PJC JET CUT (07/27/08) 08/31/08 PJC DRLG CORRECTIONS PRUDHOE BAY UNIT WELL: 13-34 PERMfT No: 1821360 API No: 50-029-20811-00 SEC 14, T10N, R14E, 2226' FSL & 1561' FEL BP Exploration (Alaska) A OIL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERAT~QNS.T r _,,e~ .STATE OF ALASKA ~ ~,~j l!T 1. Operations Pertormed: ^ Abandon ®Repair Well . ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ®Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. - ®Development ^ Exploratory 182-136 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029.20811-00-00 - 7. KB Elevation (ft): 87, , 9. Well Name and Number: PBU 13-34 8. Property Designation: 10. Field /Pool(s): ADL 028315 ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9525' - .feet true vertical 9275' ~ feet Plugs (measured) 8774' Effective depth: measured 9230' feet Junk (measured) 9212' true vertical 8982' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2585' 13-3/8" 2585' 2585' 4930 2670 Intermediate 8992' 9-5/8" 8992' 8747' 6870 4760 Production Liner 4050' 7" 5473' - 9523' 5355' - 9273' 8160 7020 ~~~~~~~ ~~;;T ~ Zoos Perforation Depth MD (ft): 9031' - 9330' Perforation Depth TVD (ft): 8785' - 9082' 4-112" x 3-1/2" 13CR-80 / L-80 8894' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packer; 8539'; 7" x 5" Baker'FB-1' packer 8800' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 8483'. Cut and pull 9-5/8" casing from 1872'. Run 9-5/8" (47#, L-80) tieback to surface. Cement w/ 130 bbls Class'G' 730 cu ft /648 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram - ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Hank Baca, 564-5444 308-266 Printed Name Sondra Stewman Title Drilling Technologist ' /~ Prepared By Name/Number. ~ ature Sig Phone 564-5743 Dat (.,O Sondra Stewman 564-4750 Form 10-404 Revised 04/2006$°~~ ( ('~ ~](~ ~j Submit Original O~~ ~rs~ ~~~ ~ ~ A L TREE = CNV WELLHEAD = MCEVOY ACTUATOR = BAKER C KB. ELEV = 8T BF. ELEV ._ KOP = 2900' Max A I 19° @ 5600' Datu Datu i ng e = 20" CONDUCTOR, 79' - m MD - 9134' g4#, H-40, ID = ? m TV D = 8800' SS 9-5/8" CSC, 47#, L-80 HYDRIL 563, 1$73' ID = 8.681" (RWO 08/31/08) 13-3/8" CSC, 72#, L80 BUTT, ID = 12.347" 25$5' Minimum ID = 2.75" @ 8881' 3-1 /2" OTIS XN NIPPLE TOP OF 7" LNR-TIEBACK 5473' SAF TES: ""4"-1/2"CHROMETBG*" 13 -3 4 CORRECT TO DOYC?N 9 6 RKE3~ 2~1 5579") ARE bl--I 1777' 9-5/8" HES CEMENTER 2116' I~ 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 7 2851 2850 8 MMG DOME RK 16 09/01 /08 6 4557 4484 18 MMG S/O RK 20 09/01 /08 5 5643 5507 19 KBG2 DMY BK 0 08/30/08 4 6500 6329 18 KBG2 DMY BK 0 08/30/08 3 7324 7115 16 KBG2 DMY BK 0 08/30/08 2 8234 7988 10 KBG2 DMY BK 0 08/30/08 1 8513 8273 9 KBG2 DMY BK 0 `4-7/Z° x 7" KBG-L-LS GLMS = 3.6b° IU 9-5/8" CSC, 47#, L-80 XO TO S0095 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, I $479' .0152 bpf, ID = 3.958" 7" TIEBK LNR, 29#, L-80 BTC, 8704' .0371 bpf, ID = 6.184 7" BOT LNR HGR 8710' 4-1/2" TBG, 12.6#, 13CR-80 NSCT, $795' .0152 bpf, ID = 3.958" 3-1/2" TBG, 9.3#, L-80 8RD AB-MOD $$94' .0087 bpf, ID = 2.992" 9-5/8" CSC, 47#, S0095 BUTT, ID = 8.681" 8992' PERFORATION SUMMARY REF LOG: BRCS ON 09/08/82 ANGLE AT TOP PERF: 8° @ 9031' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-5/8" 2 9031 - 9035 O 08/29/91 3-1/8" 4 9102 - 9142 O 02/22/86 2-5/8" 4 9116 - 9126 O 08/29/91 2-5/8" 4 9156 - 9166 O 08/29/91 3-1/8" 4 9156 - 9216 O 02/09/83 2-1/8" 4 9312 - 9330 O 07/12/98 PBTD 9480' 7" LNR, 29#, L-80 BUTT, .0371 bpf, ID = 6.184" 9523' $j 354' I- ~4-1/2"HES X NIP, ID = 3.813" I $385' 7" X 4-1/2" BKR S-3 PKR, ID = 3.870" 8418' 4-1/2"HES X NIP, ID = 3.813" 8494' 7" X 4-1/2" UNIQUE OVERSHOT $539' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" $774' 4-1/2" CAM DB XN NIP, ID = 3.50" $795' 4-1/2" X 3-1/2" XO, ID = 2.992" $811' 4-1/2" BKR GBH-22 SEAL ASSY W/O SEALS 8800' 7" X 5" BKR FB-1 PKR w / SEA LBORE IXT, ID = 4.00 8813' S-5/8" MILLOUT EXT, ID = 4.00" 8814' 5-5/8" X 3-1/2" XO, ID = 2.992" $881' 3-1/2" OTIS XN NIP, ID =2.75" 8893' 3-1/2" BKR SHEAROUT SUB $894' 3-1/2" TUBING TAIL, ID = 2.992" $906' ELMDTTLOGNOTAVAILABLE 9046' I-~ 7" DOUBLE MA RKER JOINT 9230, I~ CLA SS G CEMENT CAP - 01/28/03 I 9268' TOP OF SAND (CARBOLffE) - 01/28/03 9212' SLM I-)FISH - CA-E 1" DGLV (LATCH PULLED) (08/12/95) DATE REV BY COMMENTS DATE REV BY COMMENTS 09/11/82 OWAN 4 ORIGINAL COMPLETION 09/02/08 JCMITLH GLV GO & CORRECTIONS 06/15/88 AUDI 1 WORKOVER 09/19/08 AW/JMD DRLG DRAFT CORRECTONS 02/13/96 D-16 LAST WORKOVER 08/31/08 D-16 RWO 08/05/08 JKD/PJC JET CUT (07/27/08) 08/31/08 PJC DRLG CORRECTIONS PRUDHOE BAY UNff WELL: 13-34 PERMIT No: 1821360 API No: 50-029-20811-00 SEC 14, T10N, R14E, 2226' FSL & 1561' FEL BP Exploration (Alaska) Page 1 of 2 Well: 13-34 Well History Well Date Summary 13-34 7/22/2008 T/IA/OA= SSV/500/500 Temp=cold PPPOT-T (PASS) PPPOT-IC (FAIL) (Pre Rig) PPPOT-T RU 1 HP bled tool onto THA void 150 psi to 0 psi. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Cycle out 1.5" ran in and torqued to 500 ft/Ibs "Standard" all LDS .were in good visual and working order. Bled void to 0 psi, RD test equipment re-installed Alemite cap. PPPOT-IC RU 1 HP bled tool onto IC test port, 500 psi on void and would not bleed down. Cycle LDS out1.5" ran back in torqued to 500 ft/Ibs, "Standard" all were in good visual and working order. Void will not bleed off. tag on void indicates this void has been Seal-Tite (Tru-Flo) treatment. *** Alignment pin on tubing spool was also functioned with no problems*** 13-34 7/23/2008 T/I/0=260/380/380. Temp=Sl. T, IA, OA FLs (RWO prep). TBG FL C~ surface. IA FL ~ 120' (3 bbls), & OA FL @ surface.***Intergal on IA, OA & companion***. 13-34 7/23/2008 T/I/0= 200/400/420 Temp = SI CMIT-TxIAxOA PASSED to 2000 psi (RWO prep) Pumped 6.6 bbls crude down IA to pressure up 2000 psi. T/IA/OA lost 20/10/0 psi 1st 15 min, T/IA/OA lost 20/10/0 psi 2nd 15 min, T/IA/OA lost 0/0/0 psi 3rd 15 min. Bled WHP's to normal. FWHP's=340/350/350 ***Annulus valves open to gauges, tags hung, & DSO notified upon departure.*** 13-34 7/23/2008 ***WELL S/I ON ARRIVAL*** RAN 3.75" G-RING, SAT DOWN AT #3 @ 6175'SLM (KGB-2-LS 3.65" ID) DRIFT W/ 3.625" G-RING TO TOP OF PLUG AT 8774'MD (NO PROBLEMS) DRIFT W/ 3.65" CENT TO TOP OF PLUG AT 8774'MD (NO PROBLEMS) ***CONT WSR ON 7-24-08*** 13-34 7/24/2008 ***CONT WSR FROM 7-23-08*** (pre rwo) RIG DOWN S/L UNIT *** LEFT WELL SI AND TURNED OVER TO DSO*** 13-34 7/25/2008 ***WELL S/I ON ARRIVAL***(pre rwo) SET 4-1/2" JUNK CATCHER (OAL 110.5 "LARGEST O.D. 3.605 I.D. 3.00) C~3 8747' SLM ***JUNK CATCHER HAS NO G- FISHING NECK, WILL NEED TO SPEAR 3.0" ID*** ***WELL S/I ON DEPARTURE, DISCUSS VALVE POSITION W/ DSO 13-34 7/26/2008 ***WELL SHUT IN ON ARRIVAL*** INITIAL T/I/O = 250/350/350. RAN 3.65" SCP POWER CUTTER AND JET CUT TUBING IN MIDDLE OF FIRST JOINT ABOVE PACKER AT 8480' TUBING TALLY DEPTH .DID NOT TAG PLUG AT 8774. TBG PSI INCREASED FROM 250 TO 500 PSI AFTER SHOOTING AND IAP DROPPED FROM 350 TO 300 PSI. WELL SHUT-IN ON DEPARTURE. FINAL T/I/O = 500/325/300. ***JOB COMPLETE*** 13-34 7/31/2008 T/I/0=350/350/350 Temp=S/I Circ well to 9.3 ppg NaCI brine (RWO Prep) Speared in w/ 5 bbls of 60/40 meth water followed by 702 bbls of 9.3 NaCL Brine down tbg to IA to open tops. Freeze protect tbg w/ 10 bbls of diesel. Pumped 5 bbls of diesel down IA taking returns from tbg to open tops. Bled whp's to 0 psi. Final Whp's=0/0/0 Casing valves open to gauges swab wing SSV shut 13-34 8/5/2008 T/I/0=10/0/0. Set 5" Gray K BPV thru tree. Pre-Rig. 13-34 8/16/2008 T/I/0=0/0/0; Pull 5-1/8" Gray "K" BPV thru tree for Doyon 16 decompletion; 1-2' ext. used, tagged C~3 84"; (Best/Wortham) 13-34 8/17/2008 T/I/0=vac/0/0; Pulled 5-1/8" Gray "K" BPV #601 thru stack for Doyon 16 post BOP test; 2-5', 1-2' and centralizer used, tagged C~3 94"; ***Complete*** (Best/Wortham) 13-34 8/17/2008 T/I/0=0/0/0. Set 5" Gray K BPV #601 thru tree, ND/NU. 1-2' ext used, tagged@ 84". No problems 13-34 8/30/2008 T/I/O=Vac/0/0. Pull 6" CIW J TWC thru tree, post tree test. 1-2' ext used, tagged @ 114". No problems. 13-34 8/31/2008 ***WELL S/I ON ARRIVAL*** (post rwo) ASSIST BPV CREW W/ REMOVING BACK PRESSURE VALVE PULL BALL & ROD FROM RHC IN X-NIPPLE @ (8,418' MD) PULLED RK-DGLV FROM STA# 5 C~ (4,557' MD) ***CONT ON 9-01-08 WSR*** 13-34 8/31/2008 T/I/0=0/0/0. Pull 6" CIW J BPV .Post Rig. 13-34 9/1/2008 ***CONT FROM 8-31-08*** (post rwo) PULLED RKP-DCR SHEAR VLV FROM STA# 7 C~3 2,851' MD SET RK-LGLV IN STA'S# 7 & RK-S/O GLV IN STA# 6 (GENERIC DESIGN) PULLED RHC-M PLUG BODY FROM X-NIPPLE @ 8418' MD RIH W/ 3.50" LIB TO 8,763' SLIM (IMPRESSION OF FILL /TRASH) CURRENTLY BAILING METAL & RUBBER DEBRIS FROM TOP OF P-PRONG @ 8,774' MD W/ 10' X 3" BAILER Page 2 of 2 . ***CONT ON 9-0~** 13-34 9/2/2008 *** CONT FROM 09-01-08 WSR *** BAIL MULTIPLE TIMES WITH 3.0" x 10' P-BAILER FROM 8765' SLM TO 8,769' SLM (RECOVERED 1- 1/2 GAL OF MUD /METAL DEBRIS) RECOVERED APPROX -1-1/2 CUPS OF METAL DEBRIS WITH 3.50" MAGNET *** CONT ON 09-03-08 WSR *** 13-34 9/3/2008 *** CONT FROM 09-02-08 WSR ~** PULL P-PRONG FROM 8,771' SLM BAIL MULTIPLE TIMES WITH 8' x 2.25" P-BAILER (SNORKEL BTM) AT 8,778' SLM. (RECOVERED 3 CUPS OF METAL DEBRIS). CURRENTLY STUCK IN HOLE WITH 8' x 2.25" P-BAILER SNORKEL BOTTOM. *** CONT ON 09-04-08 WSR *** 13-34 9/4/2008 *** CONT FROM 09-03-08 WSR *** DROP CUTTER BAR (1-7/8" F.N. 4' OAL. RECOVERED ALL WIRE). FISH CUTTER BAR FROM 8746' SLM. TOOL STRING LEFT IN HOLE (SEE LOG FOR DETAILS). *** WELL LEFT S/I. TURN OVER TO DSO *** 13-34 9/5/2008 T/I/O=SI/Vac/0. Install 2-1/16" CIW I/A valve & 3-1/8" CIW O/A valve on front side of wellhead. Flanges torqued to API specs & tested to 3500 psi. No problems. 13-34 9/7/2008 *** WELL S/I ON ARRIVAL *** (rwo expense) RIH WITH 3.625" CENT AND 3.47" LIB TO FISH AT 8740' SLM. IMPRESSION OF CLEAN ROPE SOCKET. *** CONT ON 09/08/08 WSR *** 13-34 9/8/2008 *** CONT FROM 09/07/08 WSR *** (rwo expense) RAN 3.625" CENT AND 3.47" LIB TO FISH AT 8740' SLM. IMPRESSION OF ROPE SOCKET. RAN 3.6" BELL GUIDE AND 2-1/2" JDC TO FISH AT 8740' SLM AND JARRED FOR 1 HR. DSO FLOWED WELL FOR 6 HRS TO UNLOAD WELL. FISHED SLICKLINE TOOLSTRING. RECOVERED ALL TOOLSTRING. RAN 3.725" CENT AND 3.7" LIB TO 4-1/2" DB PLUG BODY AT 8760' SLM. IMPRESSION OF DB LOCK PINNING COLLAR. *** CONT ON 09/09/08 WSR *** 13-34 9/9/2008 *** CONT FROM 09/08/09 WSR *** (rwo expense) PULL 4-1/2" DB PLUG BODY FROM 8760' SLM. DRIFT WITH 2.25" CENT AND S-BAILER TO TD AT 9204' SLM. (RECOVERED PARRAFIN) *** LEFT WELL S/I. TURNED WELL OVER TO DSO *** 13-34 9/20/2008 T/1/O = SSV/1640/1230. Temp = SI. Bleed OAP < 1000 psi. AL SI C~ manifold. Bled OAP from 1230 psi to 0 psi in 1 minute, all gas. Monitored for 30 minutes, OAP increased 150 psi. FWHPS = SSV/1640/150. SV, WV, SSV =Closed. MV =Open. IA, OA = OTG. 13-34 9/21/2008 T/I/O = SSV/1640/1210. Temp = SI. Monitor WHPs post bleed. Bled OAP from 1210 to 0 psi in one minute. Held open bleed for three hours. Shut in and monitored for 30 minutes, OAP increased 90 psi. FWHPS = SSV/1640/90. SV, WV, SSV =Closed. MV =Open. IA, OA = OTG. 13-34 9/22/2008 T/l/O =SSV/300/1300. Temp = SI. Maintain open OAP bleed. IAP decreased 1340 psi. Operator used well as gas source for pigging. OAP increased 1210 psi overnight. Bled OAP from 1300 to 0 psi in 1 minute. Shut in and monitored for 1.5 hrs. OAP increased 640 psi. Bled back to 0 psi and maintained open bleed for 4 hours. Shut in and monitored for 30 min. OAP increased 260 psi. FWHPs = SSV/300/260. SV, WV, SSV =Closed. MV =Open. IA, OA = OTG. 13-34 9/23/2008 T/I/0=0/320/1120. MIT OA to 2000 psi. (Eval high OAP) Rigged up to OA, bled down to O psi. (Gas) ****Continued on 09/24/08 WSR**** 13-34 9/24/2008 ***Continued from 09/23/08*** MIT OA FAILED to 2000 psi (Eval High OAP) Bled OA to 0 psi. OAP rose from 0 psi to 260 psi. in -30 min. Bled to 0 psi., (Gas) Pumped up OA to test pressure with .02 bbls diesel. On 3rd test OA lost 440 psi in 1st 15 min and 100 psi in 2nd 15 min for a total loss of 540 psi in 30 min. Pump rate too low to LLR with LRS pump. Bled OAP to 0 psi. (Gas & fluid) FWP=SSV/320/70. Tags hung. Casing valves open to gauges. Print Date: 9/25/2008 Page 1 of 1 • • BP EXPLORATION Operations Summary Report Page 1 of 14 ~ Legal Well Name: 13-34 Common Well Name: 13-34 Spud Date: 8/28/1982 Event Name: WORKOVER Start: 8/16/2008 End: 8/30/2008 Contractor Name: DOYON Rig Release: 8/30/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task ~ Code', NPT Phase ~~ Description of Operations 8/16/2008 09:00 - 10:30 1.50 MOB PRE Move rig from well 13-29 to well 13-34. 10:30 - 11:30 1.00 RIGU PRE Spot and shim rig over well 13-34. 11:30 - 12:00 0.50 RIGU PRE Install double IA valve. 12:00 - 13:30 1.50 RIGU PRE RU cellar equipment, lines, & manifold. Spot motor complex, mud pump module, & rig slop tank. Install double OA valve. Rig up flowback tank, choke and hardline. Pressure on OA = 200-psi. Pressure on IA = 500-psi. "Rig accepted at 1300-hrs." 13:30 - 14:30 1.00 WHSUR DECOMP DSM open SSSV. PU DSM lubricator and test to 500-psi. lubricator. 14:30 - 15:30 1.00 KILL DECOMP Fill pits with 120-degree, 8.5-ppg 2% KCI. Mix 20-bbl Hi-Vis sweep. 15:30 - 18:30 3.00 KILL DECOMP PJSM with rig crew and truck drivers. Discuss upcoming circulation, positions of people, monitoring all lines and necessary permits. Pressure test surface lines to 3,500-psi. Good Test. Pump 20-bbl Hi-Vis sweep and chase with 550-bbls of 8.5-ppg brine. Pump at 9.5-bpm / 1,540-psi. 18:30 - 19:30 1.00 WHSUR DECOMP Monitor well -Static. Prep for DSM setting type-K BPV in tubing hanger and wait for DSM crew to complete crew change. 19:30 - 20:30 1.00 WHSUR DECOMP PU DSM lubricator and test to 500- si. Good test. Set e- BPV in tubin han er. LD DSM lubricator. 20:30 - 23:00 2.50 WHSUR DECOMP Cameron wellhead tech T-bar type-K test dart into BPV. Test to 3,500-psi above BPV and hold for 10 charted minutes. Good test. Attempt to test below BPV to 1,000-psi. Consistently losing between 120-psi and 200-psi per 10-minute test. Confer with rig team and town engineer. Decide to use test um to maintain 1,000-psi below BPV for 10 charted minutes. Good test. 23:00 - 23:30 0.50 WHSUR DECOMP Blow down and RD circulating manifold and lines in cellar. 23:30 - 00:00 0.50 WHSUR DECOMP Remove nuts from adapter flange and tree in preparation for ND of exisiting production tree. 8/17/2008 00:00 - 01:00 1.00 WHSUR P DECOMP ND existing production tree and adapter flange. Cameron wellhead tech check condition of tubing hanger threads and verify MU of XO to tubing hanger. During the thread testing operation, the XO slipped into the thread pocket and caused some drops of KCI fluid to shoot up onto the face of a floorhand who was assisting with the insertion of the XO. The job was immediately stopped and the crew helped the floorhand wash out his eyes with eyewash solution. Please see details in the Remarks section. 01:00 - 04:00 3.00 BOPSU P DECOMP NU BOP stack and connect all lines. Change VBRs from 2-7/8" x 5"to 3-1/2" x 6". 04:00 - 08:00 4.00 BOPSU P DECOMP Test ROPE per BP and AOGCC rocedures. All tests witnessed by BP WSL and Doyon toolpusher. All tests held for 5 charted minutes. All tests done at 250-psi low pressure and 3,500-psi high pressure. AOGCC rep Chuck Scheve waived witness of BOPE test at 1800-hrs on 8/16. 08:00 - 08:30 0.50 BOPSU P DECOMP R/D test equipment and blowdown Choke Manifold. 08:30 - 09:30 1.00 BOPSU P DECOMP Cameron Tech P/U d rod RIH and remove the K-t t P/U and install Dutch Riser. P/U, install and test DSM lubricator to 500-psi. RIH with BPV run/pull tool and POH with BPV. A slioht vacuum "whoosh" was heard when the bleed valve was Printed: 9/15/2008 3:33:40 PM ~~J • BP EXPLORATION Page 2 of 14 Operations Summary Report Legal Well Name: 13-34 Common Well Name: 13-34 Spud Date: 8/28/1982 Event Name: WORKOVER Start: 8/16/2008 End: 8/30/2008 Contractor Name: DOYON Rig Release: 8/30/2008 Rig Name: DOYON 16 Rig Number: 16 i ~ Date '~ From - To ' Hours I Task Code NPT Phase Description of Operations 8/17/2008 08:30 - 09:30 1.00 BOPSU P DECOMP opened on the lubricator. 09:30 - 10:00 0.50 BOPSU P DECOMP R/D DSM lubricator and Dutch Riser. See that the BOP stack is standing full of fluid to a foot below the flowline outlet. 10:00 - 11:00 1.00 PULL P DECOMP P PUB ker Itco tubin sear dressed with 4.805" grapple. M/U to DP landing joint. M/U landing joint to Top Drive. RIH and engage in Hanger. BOLDSs, slowly pull hanger to 250K-Ibs -25-times with no movement of tubing hanger out of the tubing spool. Pull one time to 275K-Ibs and han_ er lets . Continue POH to position the hanger about 2' above the tubing bowl to CBU. 11:00 - 12:00 1.00 PULL P DECOMP CBU at 8-BPM and 840-psi. Monitor well and see no flow from or loss to the well. 12:00 - 13:00 1.00 PULL P DECOMP Pull Han er to ri floor and terminate control lines. One control line had pulled loose before the hanger made it to the rig floor. Drain stack and see it at the bottom of the stack. Will wait for it to be pulled to the rig floor when resume POH. 13:00 - 13:30 0.50 PULL P DECOMP Service rig. 13:30 - 14:30 1.00 PULL P DECOMP Replace O-ring in Main Skate Ram. 14:30 - 16:00 1.50 PULL P DECOMP POH and UD 5-1/2" tubing from 8,480' to 7,880'. Gathered the second control line when the first SS band came to the floor. Spooled two SS control lines while UD 5-1/2" tubing. Safe-out well. No fluid loss or gain while pulling the first 20-joints out of the hole. 16:00 - 17:00 1.00 PULL P DECOMP Hold Safety Stand Down with Toby Pickworth's crew to discuss the most recent safety incidents on the North Slope. Rig mechanic, rig electrician, and rig welder were also in attendance with the Schlumberger Spooler operator and a Doyon Casing hand. Asked for and received input from every person regarding what they could individually do to improve safety performance as well as what recommendations they might have for ways for all of us to improve. The entire discussion was positive and productive. 17:00 - 18:00 1.00 PULL P DECOMP Resume POH and UD 5-1/2" tubing to 6,277'. Continue to spool dual SS control lines while UD tubing. 18:00 - 18:30 0.50 PULL P DECOMP RD Schlumberger control line spooling unit and clear rig floor. 51 SS bands recovered of 52 SS bands reported. 18:30 - 21:00 2.50 PULL P DECOMP Resume POH and UD 5-1/2" tubing from 6,277' to 3,047'. LD 131-'ts of 5-1/2" tubin , 1-SSSV and 2-GLMs. 21:00 - 21:30 0.50 PULL P DECOMP RD 5-1/2" tubin handlin a ui ment. R 4- / " t i handlin a ui ment. MU 4-1/2" NSCT XO to floor valve. 21:30 - 23:00 1.50 PULL P DECOMP Resume POH and LD 4-1/2" tubing from 3,047' to cut jt. LD 74-its of 4-1/2" tubing and 2-GLMs. Cut jt is 18.72' and the cut was flared to 4-3/4". No major condition issues with any of the tubing pulled. Wear noted in tubing connections. LD a total of 205-jts of tubing, 4-GLMs and 1-SSSV. 23:00 - 00:00 1.00 PULL P DECOMP Clean and clear rig floor. Load and strap 4-3/4" DCs in pipe shed. 8/18/2008 00:00 - 00:30 0.50 PULL P DECOMP Clean and clear rig floor. LD tubing handling equipment. Install 8-7/8" ID wear ring in Tubing spool. RILDS. 00:30 - 01:00 0.50 CLEAN P DECOMP PU dress-off BHA com onents. RU BHA and DP handling equipment. Change out skate cable while PU & MU BHA. PJSM held for work on skate that covered lock out -tag out, positions of people, safely securing skate while working on it. Printed: 9/15/2008 3:33:40 PM • r BP EXPLORATION Page 3 of 14 Operations Summary Report Legal Well Name: 13-34 Common Well Name: 13-34 Spud Date: 8/28/1982 Event Name: WORKOVER Start: 8/16/2008 End: 8/30/2008 Contractor Name: DOYON Rig Release: 8/30/2008 Rig Name: DOYON 16 Rig Number: 16 Date ~ From - To Hours ~ Task Code ~' NPT ' Phase. I Description of Operations 8/18/2008 01:00 - 02:00 1.00 CLEAN P DECOMP MU dress-off and dual casing scraper BHA to DCs and RIH. BHA consists of dress-off shoe, washpipe extensions, internal dress-off mill, boot basket, 7" casing scraper, bumper sub, pump out sub, 6-jts of 4-3/4" DCs, 90-jts of 4" DP, and 9-5/8" casing scraper. 02:00 - 09:00 7.00 CLEAN P DECOMP PU 6-jts of 4-3/4" DCs and 4" DP from pipe shed and RIH. 150-joints RIH at 0715-hours. Run through 7" liner top with joint #161 at 0725-hours. S/D for Safety Stand-down meeting at 0900-hrs. 09:00 - 10:00 1.00 CLEAN P DECOMP Conduct Safety Stand-Down meeting in Doghouse with Night Tour crew, Toolpusher, Doyon HSE Rep, and WSL.This crew included the floorhand who experienced the eye injury the morning of the 17th. The floorhand added positively to the discussion in the meeting. 10:00 - 11:00 1.00 CLEAN P DECOMP Continue RIH to dress-off the 4-1/2" stub. Reciprocate across the potential 7" packer setting depth of 8280' to 8 16 . 11:00 - 12:00 1.00 CLEAN P DECOMP Get parameters with joint #261 RIH: P/U wt 170K-Ibs, S/O wt 155K-Ibs, 50-RPM, Free Torque 2-3K-Ib-ft, 4-BPM at 400-psi. Stop rotating and slowly RIH, see stub at 8482'. P/U and start rotating at 50-RPM, slowly RIH and easily get over stub, continuing in to see the inside mill stack out on the stub. Stop with -5000-Ibs WOB and mill off stub. P/U to verify; RIH and easily slip down over the stub. Stop rotating and P/U to verify; RIH and stack out at 8483' fora 1' dress-off. Check once more to verify ease of swallow, for good dress-off. 12:00 - 13:00 1.00 CLEAN P DECOMP Pump 20-Bbls HiVis sweep followed by full wellbore volume of 2%KCI brine from Plts at 12-BPM. Did not see any debris other than pipe dope/fine scale across shakers. Saw small traces of oily fluid come from OA line in the cuttings tank. 13:00 - 15:30 2.50 CLEAN P DECOMP POH and S/B DP and DCs in Derrick. 15:30 - 16:00 0.50 CLEAN P DECOMP Breakout and L/D dress-off BHA. Get only -1-Ib of junk out of the Junk Baskets. 16:00 - 18:00 2.00 CLEAN P DECOMP Clear and clean rig floor, P/U and install Dutch Riser. Wait on Schlumberger E-line crew and equipment. 18:00 - 19:00 1.00 CLEAN P DECOMP PJSM on E-line logging with rig crew and Schlumberger. Discuss hazards unique to togging, restricting all areas around wire, and communications between rig and logging unit. RU Schlumberger a-line equipment. MU USIT logging tools. 19:00 - 19:30 0.50 CLEAN P DECOMP Wait for Schlumberger crew change and Schlumberger pressure testing equipment needed. 19:30 - 20:30 1.00 CLEAN P DECOMP Pressure test Dutch riser system and Schlumberger pressure control equipment to 1,000-psi. Good test. 20:30 - 23:00 2.50 CLEAN P DECOMP Change out a-line sheave at rig floor. Zero tool depth at rig floor. RIH with USIT logging tools to 3,050'. Make correlation log to ECP. RIH and log up at 60-fUmin. Locate TOC at 2,000' and ECP at 1939.5'. RIH and log back up to surface at same rate. 23:00 - 00:00 1.00 CLEAN P DECOMP RD Schlumberger E-line unit. 8/19/2008 00:00 - 01:00 1.00 CLEAN P DECOMP Complete tally 9-5/8" casing, Bowen casing patch and XO pup. Test OA hardline to flowback tank to 3000-psi. Good test. 01:00 - 02:00 1.00 DHB P DECOMP PU HES 9-5/8" RBP and running tool. RIH with RBP to 1.972'. Planned cut depth at 1,869', in middle of second full jt above ECP. Printed: 9/15/2008 3:33:40 PM • BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: 13-34 Common Well Name: 13-34 Event Name: WORKOVER Contractor Name: DOYON Rig Name: DOYON 16 Date From - To Hours ! Task I Code i 8/19/2008 02:00 - 02:30 0.50 DHB P 02:30 - 04:30 I 2.001 DHB I P 04:30 - 05:00 ~ 0.50 ~ CLEAN ~ P 05:00 - 08:00 I 3.001 CLEAN I P 08:00 - 09:00 1.00 CLEAN P 09:00 - 10:30 1.50 PULL P 10:30 - 11:15 I 0.751 PULL I P 11:15 - 12:00 I 0.751 PULL I P 12:00 - 13:00 1.00 PULL P 13:00 - 13:30 0.50 PULL P 13:30 - 14:00 I 0.50 I PULL I P Spud Date: 8/28/1982 Start: 8/16/2008 End: 8/30/2008 Rig Release: 8/30/2008 Rig Number: 16 Phase ', Description of Operations DECOMP Obtain parameters: PU wt = 75K-Ibs, SO wt = 70K-Ibs. Set RBP per HES rep. Top of RBP at 1,972' and COE at 1976.5'. DECOMP Stand back 1-std of DP and pressure test RBP to 1,500-psi for 15 charted minutes. Good test. DECOMP RU to displace well. Pump 20-bbl Hi Vis sweep and chase with 130-bbls to 9.8-ppg brine. Circulate at 8-BPM / 490-psi. DECOMP Stand back 1-std of DP. PU sand hopper and dump 2,200# (44-sks) of 20-40 river sand on top of RBP. Saw small amount (<1-bbl) of crude /diesel mix from OA. DECOMP RIH to tag sand at 1935'. POH and SB DP and DCs in Derrick. DECOMP PJSM. P/U and M/U stabilizer and Baker Multi-string cutter and RIH to find collar at 1,855'. Get parameters: P/U wt 65K-Ibs, S/O wt 70K-Ibs, 50-RPM, 2K-Ib-ft free torque, 6-1/2-BPM at 1150-psi. DECOMP PJSM to discuss possible movement we might expect when the cutters sever the casing. Also discuss each person's responsibilities during the circulation of the 9-5/8" x 13-3/8" annulus. P/U to position cutters at 1,866' and start pump, bring up to 6-1/2-BPM, 1150- si. 1100-hours, start rotatin at 50-RPM, rotating torque started at 5K-Ib-ft when cutters the i e cut throw hat 1107-hours. Rotating torque limited out at 10K-Ib-ft. S/D pump, S/D TopDrive, P/U 5', restart pump and bring up to 4-BPM, then slowly RIH with pump pressure at 500-psi. Pressure dropped to 300-psi when cutters engaged the cut. DECOMP Open the choke 1/4-open on the manifold connected to the Wells Support Slop Tank and diesel flows to the Slop Tank. Start pump and pump 20-Bbl HiVis sweep chased with 9.8-ppg KCI brine from Pits. Pump at 7-BPM, 1560-psi. Continue to open the choke to full open and get back 100-Bbls of diesel and 125-Bbls of 9.8-ppg brine to the W/S Slop Tank. Returns were opaque brine after -150-Bbls pumped. DECOMP POH and UD cutter. DECOMP Clear and clean rig floor. Pull wear ring. Bring 9-5/8" casing equipment to rig floor. DECOMP P/U, M/U Baker Casing Spear with 8.681" Grapple and packoff with bullnose to D joint. M/U DP to Top Drive. RIH and park above casing spool. 14:00 - 15:00 1.00 PULL P DECOMP PJSM with crew, Baker fisherman, Cameron technicians, Toolpusher, WSL to discuss unseating 9-5/8" casing and POH. Discuss weight of 1866' of 9-5/8" in 9.8-ppg brine (-76,000-Ibs) with respect to maximum pull expected. Engage spear in casing hanger to No-Go. P/U to 130K-Ibs, no movement. P/U to 200K-Ibs and move about 1-1.5". P/U to 225K-Ibs with -2" movement. P/U to 250K-Ibs and see only 2-2.5" movement. Try several more times to 250K-Ibs. S/D and call ADW engineer to discuss. Cameron technician reviews drawings in their office and determine that the u er 9-5/8" casin ackoff has a_ flange that is inset into a profile in the top of the casing spool that cannot ass u through the tubin spool. ADW Engineer called to say that he is working on a single barrier dispensation to allow BOP stack to be removed to allow extrication of the Printed: 9/15/2008 3:33:40 PM • • BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Weli Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 3-34 3-34 WORKO DOYON DOYON Hours VER 16 Task ', ode PT 8/19/2008 14:00 - 15:00 1.00 PULL P 15:00 - 18:00 3.00 PULL N SFAL 18:00 - 21:00 3.00 PULL N SFAL 21:00 - 22:30 1.50 PULL N SFAL 22:30 - 00:00 1.50 PULL N SFAL 8/20/2008 00:00 - 04:30 4.50 PULL N SFAL 04:30 - 06:00 1.50 PULL N SFAL 06:00 - 07:00 1.00 PULL N SFAL 07:00 - 07:30 0.50 DHB N SFAL 07:30 - 08:00 0.50 PULL N SFAL 08:00 - 08:30 0.50 PULL N SFAL 08:30 - 10:30 2.00 PULL N SFAL 10:30 - 11:00 0.50 PULL N SFAL 11:00 - 11:30 0.50 PULL N SFAL 11:30 - 18:00 6.50 PULL N SFAL 18:00 - 19:00 1.00 PULL N SFAL 19:00 - 20:00 1.00 PULL N SFAL 20:00 - 23:00 3.00 WHSUR N SFAL Spud Date: 8/28/1982 Start: 8/16/2008 End: 8/30/2008 Rig Release: 8/30/2008 Rig Number: 16 Phase Description of Operations DECOMP packoff. DECOMP Wait on instructions regarding the removal of the BOP stack to pull packing to facilitate removal of 9-5/8" casing. DECOMP Discuss options with ADW Engineer. Will run a balanced 17-Bbl cement plug across the cut at 1866' to cover to 1816'. Call Schlumberger cementers and set up a 18-Bbl pumpable volume with 3-4-hour thickening time. Order 100-bbls fresh H2O & Contam vac truck. DECOMP MU 3-1/2" muleshoe. RIH w/ 4" DP. Sat down on CSG cut ~ 1866' rotate 1/2-turn and reciprocate t_hru cut depth w/ muleshoe - no problems. Cont to RIH and tag TOS ~ 1918'. POH above casing cut to 1863', reverse circulate DP volume to ensure clear. DECOMP Monitor well and continue wait on SLB cementers. DECOMP Continue to wait on SLB cementers. DECOMP Spot cement truck & pump truck. RU hardline from pump truck to cement line. RU fluid lines, spot vac trucks. DECOMP Circulate warm 9.8-ppg KCI brine from Pits 4-BPM, 300-psi. DECOMP PJSM to discuss issues surrounding reason for the Balanced Plug, safety aspects associated with R/U and tersting the cementing equipment and lines, and the responsibilities for the crew and third party personnel. Pressure test lines to 2500-psi. Open the OA line to the Cuttings Tank, ensure Hydrill is open. Start batching 18-Bbls, 15.8-ppg Class G cement with D-186 Cement Set Enhancer at 0708-hrs. 0710-hrs, start pumping cement (slurry temp = 88F), average rate 2.7-BPM. Total volume cement pumped = 19.8-Bbis, but 17.8-Bbls pumped into DP. 0721-hrs, start displacement and displace DP with 16-Bbls of 9.8-ppg brine for a -2.5-Bbl Drillpipe under-displacement. Cement in place at 0725-hours. See a constant flow rate of fluid comin from the OA into the Cuttin s tank Burin the entire um in o eration. S/D pumping, open . side outlet valve on cementing line and DP is on vacuum. Blowdown lines, Vac truck suck out Schlumberger equipment, then switch to cuttings tank. DECOMP POH and S/B 4-stands of DP slowly to allow cement remaining in DP to keep balance with plug. DECOMP R/U to reverse circulate cement lines. Reverse circulate at 8-BPM, 780-psi for two wellbore volumes returns cleaned up within a few minutes. DECOMP Circulate heated 9.8-ppg KCI brine from Pits, 2-BPM at 60-psi while waiting on cement UCA test results. DECOMP Rig down circulating lines and prepare to POH. DECOMP POH, S/B DP in Derrick, break off the HT-38 Muleshoe. DECOMP RIH with 8-112" bit and park at 1583' to wait on 500-psi UCA lat t t DECOMP RIH local an t ', set 10K WOB. PU 15', break circulation the long way ~ 2-BPM / 50-psi. MU top drive, shut bag. ,PST cement plug to 2000-psi for 10-min charted. OA ressure sta ed ~ i urin test DECOMP POH w/ 4" DP. Break out 8-1/2" bit. DECOMP PJSM with all crews. ND TBG spool from casing spool and disconnect with BOP bridge crane. Unable to pry out pack-off Printed: 9/15/2008 3:33:40 PM • • BP EXPLORATION Page 6 of 14 Operations Summary Report Legal Well Name: 13-34 Common Well Name: 13-34 Spud Date: 8/28/1982 Event Name: WORKOVER Start: 8/16/2008 End: 8/30/2008 Contractor Name: DOYON Rig Release: 8/30/2008 Rig Name: DOYON 16 Rig Number: 16 Date 'From - To Hours Task Code NPT Phase Description of Operations 8/20/2008 20:00 - 23:00 3.00 WHSUR N SFAL DECOMP with bars. Set spool & BOP stack on CSG head and gush out pack-off with drill pipe on elevators. Remove Grey secondary 23:00 - 00:00 1.00 PULL N SFAL DECOMP seal ana clean up oowi. NU BOPE & spool. RU lines to test BOP body & flange. 8/21/2008 00:00 - 01:00 1.00 PULL N SFAL DECOMP Cont to NU TBG spool & BOP stack. Re-connect bell nipple and air up boots. 01:30 - 02:00 0.50 PULL N SFAL DECOMP Shut blinds, P/T BOP body and TBG spool break against cement plug to 2000-psi. 02:00 - 04:30 2.50 PULL N SFAL DECOMP MU 8-1/2" mill tooth bit BHA. RIH out of derrick to 1790' to drill cement. -Free drilling parameters: PUW = 66K, SOW = 70K. Free torque = 50-RPM / 1500 ft-Ibs. Rot wt. = 70K. Circulation = 7-BPM / 320-psi. -Drill semi-hard cement from 1790' to 1.866.' with 2-7K WOB; 50-RPM / 2000 ft-Ibs; 7-BPM / 350-psi. -Recovered cement over shakers while drilling. Pumped hi-vis sweep C~3 1866' with 14-BPM / 600-psi. Sweep recovered cement over shakers. 04:30 - 06:00 1.50 PULL N SFAL DECOMP POH w/ BHA. Break out 8-1/2" bit -good shape. Clear rig floor. Pull wear ring. 06:00 - 07:00 1.00 SFAL DECOMP P/U ITCO s ear with 8.681" grapple on 1 joint of drill pipe. RIH and egage 9-5/8" casing in casing spool. P/U and work spear from 150,000-Lbs to 300,000-Lbs. Able to lift the casings' where 9-5/8 Veco Grey Gen III emergency slips reset to hold extra P/U weight. Attempt to break circulation without success. Disenaaae spear and POOH. UD spear. 07:00 - 08:30 1.50 PULL N SFAL DECOMP PU/MU 9-5/8" Baker Multi String Cutting Assembly and RIH on 19 stands of 4" HT-38 drill pipe from derrick to 1726'. Attempt to M/U to top drive. Saver sub would not M/U. 08:30 - 09:30 1.00 PULL N SFAL DECOMP Change out top drive saver sub. Inspect top drive. 09:30 - 10:00 0.50 PULL N SFAL DECOMP M/U stand 19 into top drive and establish casing cutting parameters of P/U Wt- 70,000 Ibs; S/O Wt- 67,000 Ibs; Rot Wt- 67,000Ibs at 50 rpm with 2000 ft-Ibs free torque. Open Baker Multi String Cutter with 500-Psi and 4.2-BPM. RIH and locate 9-5/8" casing collar at 1767'. P/U to 1762' and stand by. 10:00 - 10:30 0.50 PULL N SFAL DECOMP Hold safety meeting in dog house with rig crew, Baker Fisherman, BPX WSLs, Doyon Toolpusher, BPX Superintendents Paul Forman, Steve Rossberg, and Jim ', Willingham. Discuss recent dropped object on Doyon 14 and ', how to avoid the same incident on Doyon 16. 10:30 - 11:00 0.50 PULL N SFAL DECOMP B in cuttin 9-5/8" casing at 50 rpm with 3500 to 4000 ft-Ibs torque, Pump Rate at 6.3-BPM with 1090 to 1170-Psi. ', Continue cutting operations with same parameters until cutting through casing when indications were pump pressure dropped to 830-Psi and pump rate increased to 7-BPM, casing jumped simultaneously. Shut down cutting operation. P/U 5' and S/O and confirm cut at 1762'. Casing cut in 5 minutes. 11:00 - 11:30 0.50 PULL N SFAL DECOMP CBU at 6.8-BPM with 1040-Psi. 11:30 - 12:00 0.50 PULL N SFAL DECOMP POH and S/B DP in Derrick and B/O and UD Multi-String Cutter. 12:00 - 12:30 0.50 PULL N SFAL DECOMP Clear and Clean Rig Floor. 12:30 - 13:30 1.00 PULL P DECOMP P/U, M/U 9-5/8" S ear dressed with 8.681" grapple and M/U to joint of DP. RIH and engage in top of 9-58" casing. BOLDS. Printed: 9/15/2008 3:33:40 PM • • BP EXPLORATION Page 7 of 14 Operations Summary Report Legal Well Name: 13-34 Common Well Name: 13-34 Spud Date: 8/28/1982 Event Name: WORKOVER Start: 8/16/2008 End: 8/30/2008 Contractor Name: DOYON Rig Release: 8/30/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To 'Hours Task Code NPT Phase Description of Operations 8/21/2008 12:30 - 13:30 1.00 PULL P DECOMP Pull 9-5/8" casin free with 165K-Ibs, then ull to ri floor with 115K-Ibs. UD Spear. Remove packoff and slips from 9-5/8". UD single joint of DP. 13:30 - 14:00 0.50 PULL P DECOMP R/U Doyon Casing handling egpt. UD cut joint with spear in it. Install stripping rubber. 14:00 - 14:30 0.50 PULL P DECOMP Circulate bottoms up 5-BPM at 230-psi. 14:30 - 17:30 3.00 PULL P DECOMP POH and UD 9-5/8" casing. Average breakout torque is 30,000-Ib-ft. Casing joints are very clean. Recovered the top joint (34.61') that had been landed in the casing hanger, 38 full joints, and the cut joint of 39.53'. 17:30 - 18:00 0.50 BOPSU P DECOMP Clear rig floor. MU landing joint and test plug. Set test plug in casing head bowl. RU lines to test BOP body. 18:00 - 18:30 0.50 BOPSU P DECOMP Test BOP bod 250- si tow and 3500- si hi h to 5-mi charte .Test witnessed by Toolpusher Glenn Herman and WSL Vincent Volpe. R/D test equipment. 18:30 - 21:30 3.00 CLEAN N SFAL DECOMP Set 12-1/4" wear ring. PUMU BHA #6. RIH BHA to 430'. 21:30 - 22:30 1.00 CLEAN N SFAL DECOMP RIH w/ 4" DP from 430' to tag ~ 1732'. PU to establish parameters. 22:30 - 00:00 1.50 CLEAN N SFAL DECOMP PUW = 75K, SOW = 72K, ROT wt. = 75K, 40 RPM / 8K ft-Ibs, 10 BPM / 580 psi. -Drill cement from 1732' to 1765' w/ 2-10K WOB, torque = 5-18K ft-Ibs, 10 BPM / 600-650 psi. Stalled out several times around collar depth ~ 1765'. Control drill to pass thru collar restriction, unable to drill thru, continuous high torque ~ 18K ft-Ibs -won't drill off. Small chunks & fines of cement returns over shakers throughout drilling. 8/22/2008 00:00 - 03:30 3.50 CLEAN N DPRB DECOMP Continue drilling on cement and collar restriction w/ 2-8K WOB, 40 RPM / 18 ft-Ibs. Dry drilled on tight spot at 1765' and pushed thru obstruction (~ 0225-hrs. Continue drilling cement w/ 2-8K WOB, 50 RPM / 17K, 10 BPM / 600 psi. Pump sweep around, recovered cement and metal slivers. Unable to make hole past 1768', high torque not indicating cutting action on obstruction. Drilled from 1732' to 1768'. 03:30 - 05:30 2.00 CLEAN N DPRB DECOMP POH with Washover BHA. Washpipe body had cuts on lower body that appeared to be made from junk or restriction in the hole. The 11-3/4" shoe carbide cutters were in good shape. 05:30 - 06:30 1.00 CLEAN N DPRB DECOMP Clear and clean rig floor. Changeout tubulars handling equipment. 06:30 - 07:30 1.00 CLEAN N DPRB DECOMP P/U M/U Multi-cutter and change out blades. 07:30 - 08:00 0.50 CLEAN N DPRB DECOMP RIH to 1725'. 08:00 - 08:30 0.50 FISH N DPRB DECOMP RIH to 1772', get parameters: Up weight 65K, Down weight 70K. Rotate at 50-RPM, bring pump up to 6.8-BPM, 1070-psi. Cut 9-5-8". Stop rotating, stop pump, POH -5', start pump, 44-BPM at 500psi and slowly lower. Stacked out and see pressure drop from 500-psi to 200-psi. 08:30 - 09:00 0.50 FISH N DPRB DECOMP Monitor well. POH, Blow-down lines and Top Drive. S/B DP and DCs in Derrick. 09:00 - 09:30 0.50 FISH N DPRB DECOMP Clear and clean rig floor. 09:30 - 10:30 1.00 FISH N DPRB DECOMP P/U M/U spear, changeout grapple, add spear extension. 10;30 - 11:00 0.50 FISH N DPRB DECOMP RIH with S ear BHA on DP and DCs from Derrick. 11:00 - 11:30 0.50 FISH N DPRB DECOMP Get parameters: Up weight 70K-Ibs, Down weight 72K-Ibs. S ear into stub and P/U to 110K-Ibs and comes free with dra . Set down to check, P/U and see same drag. Decide to POOH. Printed: 9/15/2008 3:33:40 PM C: • BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: 13-34 Common Well Name: 13-34 Spud Date: 8/28/1982 Event Name: WORKOVER Start: 8/16/2008 End: 8/30/2008 Contractor Name: DOYON Rig Release: 8/30/2008 Rig Name: DOYON 16 Rig Number: 16 Date. From - To Hours ~ Task Code' NPT ', Phase Description of Operations 8/22/2008 11:30 - 12:00 0.50 FISH N DPRB DECOMP POOH and S/B DP and Dcs in Derrick. 12:00 - 12:30 0.50 FISH N DPRB DECOMP B/O and UD Spear with fish, Bottom of the cut joint previously pulled = 4.44'; top cutoff length from the fish remaining in hole = 4.81'. 12:30 - 14:30 2.00 FISH N DPRB DECOMP M/U Washover Shoe BHA and RIH DCs and DP from Derrick. Slow RIH due to piston effect from the 122' of 12.125" Washpipe. See a little restriction at the top of the stub like debris piled on top of the stub. 14:30 - 00:00 9.50 FISH N DPRB DECOMP PJSM for washing over 9-5/8" casing. P/U get parameters: Up weight 85K-Ibs, Down weight 67K-Ibs, Rotating weight, 75K-Ibs, 5-BPM ~ 200-psi, 7K-Ib-ft free torque. Slowly RIH and start washover/milling at 1772', rotating torque 7K-15K-Ib-ft, WOB 5K-15K-Ibs. 1700-hours, get 17' of progress to 1789' (approximate TOC inside the 9-5/8" after cement plug was set). Drilling on cement torque fell to 5-8K ft-Ibs - ROP is 10-ft/hr thru cement. Milled thru collar at 1808' for 45 min. Drilling over collars torque increased to 15K ft-Ibs. Ran sweeps after swallowing collars, recovered cement and metal shavings. -Started millin on 2nd collar at 1850' ~ 22:45 hrs. 8/23/2008 00:00 - 02:30 2.50 FISH N DPRB DECOMP Continue drilling on cement and collar restriction ~ 1855' w/ 5-15K WOB, 40 RPM / 18 ft-Ibs. Pump sweep around, recovered cement and metal slivers. Unable to make hole past 1855', high torque not indicating cutting action on obstruction. 02:30 - 04:30 2.00 FISH N DPRB DECOMP POH w/ washover BHA. Shoe body cracked 8" along body between each blade. Carbide worn off face of blades. Pictures in folder. 04:30 - 06:00 1.50 FISH N DPRB DECOMP PUMU s ear BHA#9 RIH to 1772'. 06:00 - 06:30 0.50 FISH N DPRB DECOMP Get parameters----engage spear in stub at 1772' and P/U to 30K-Ibs over and casing pulls free. 4-5K-Ibs additional weight on string. 06:30 - 09;00 2.50 FISH N DPRB DECOMP POH with fish and L/D to cut 'oint--37.62' full 'oint--44.89' and the bottom cut joint--11.63'. VD Spear assembly. P/U stand of washpipe and RIH to POH and L/D in singles. 09:00 - 09:30 0.50 FISH N DPRB DECOMP Clear and clean rig floor. 09:30 - 10:00 0.50 CLEAN N DPRB DECOMP P/U, M/U 8-1/2" bit to cleanout additional 15' f the stub at 1866'. 10:00 - 10:30 0.50 CLEAN N DPRB DECOMP RIH 8-1/2" bit to 1838', get parameters: Up wt 70K, Down wt 70K, 50-RPM, 2K-Ib-ft free torque. 10:30 - 12:00 1.50 CLEAN N DPRB DECOMP Start reaming on restriction at 1847' drilling at 5.5-BPM, 180-psi, 50-RPM, 2K-Ib-ft torque with no WOB and get quickly to 1866', the top of the stub. Bit will not work itself into the top of the stub. Do not want to tear up stub. Stop and circulate a HiVis sweep. 12:00 - 12:30 0.50 CLEAN N DPRB DECOMP POH and S/B DP and DCs in Derrick. 12:30 - 13:30 1.00 CLEAN N DPRB DECOMP PJSM on M/U BHA with internal bit assembly. M/U W/O Shoe with 8-1/2" bit on extension inside washpipe. W/O Shoe on bottom of 31' of washpipe, with bit 25' up inside washpipe. 13:30 - 14:00 0.50 CLEAN N DPRB DECOMP RIH W/O BHA to 1856'. P/U to get parameters. 14:00 - 20:30 6.50 CLEAN N DPRB DECOMP Get Parameters: Up wt 75K-, Down wt 72K, 5-BPM, 40-RPM, 4K-Ib-ft free torque, Rot wt 75K. RIH and tag 1856' and quickly mill cement to 1866' and continue washing/milling over stub. Printed: 9/15/2008 3:33:40 PM ~~ • BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: 13-34 Common Well Name: 13-34 Spud Date: 8/28/1982 Event Name: WORKOVER Start: 8/16/2008 End: 8/30/2008 Contractor Name: DOYON Rig Release: 8/30/2008 Rig Name: DOYON 16 Rig Number: 16 Date I From - To ~ Hours Task Code NPT Phase Description of Operations 8/23/2008 14:00 - 20:30 6.50 CLEAN N DPRB DECOMP Torque increased to 8-15K going over stub ~ 1866' down to 1876'. Torque fell off to 3-7K ft-Ibs and continue to drill cement w/ 5-20K WOB, 9 BPM / 620 psi. Wash down w/drag tooth mill to 1897', putting 8-1/2" bit 6' down thru 9-5/8" stub ~ 1872'. Pump sweep f~ 10 BPM / 650 psi -recovered cement. 20:30 - 21:30 1.00 CLEAN N DPRB DECOMP POH w/ BHA. Stop and inspect top drive. Cont POH. 21:30 - 22:30 1.00 CLEAN N DPRB DECOMP LD BHA. Wall on box of 11-3/4" washpipe junk cut paper thin on one side. Drag tooth mill fractured on water courses between blades. 22:30 - 00:00 1.50 CLEAN N DPRB DECOMP PUMU BHA #12. 8/24/2008 00:00 - 00:30 0.50 CLEAN N DPRB DECOMP Crew change. Continue PUMU BHA #12 to 323'. 00:30 - 01:00 0.50 CLEAN N DPRB DECOMP RIH w/ BHA from 323' to 1866'. 01:00 - 02:30 1.50 CLEAN N DPRB DECOMP Slip & cut drilling line. 02:30 - 05:00 2.50 CLEAN N DPRB DECOMP RIH to top of stub C~1 1866'. Establish parameters: PUW = 74K, SOW = 74K, ROT wt = 74K. 40 RPM / 3K ft-Ibs. 10 BPM / 600 psi. -Dress off stub w/ 10-15K WOB, torque = 5-8K ft-Ibs. Pump hi-vis sweeps, recovered metal chunks & shavings. -Dress stub from 1866' - 1870'. Reciprocate while rotating over stub to ensure clear. Reciprocate without rotating over stub. Both runs without any problem. 05:00 - 06:30 1.50 CLEAN N DPRB DECOMP Pump hi-vis sweep and chase w/ clean 9.8-ppg brine. Displace wellbore ~ 10 BPM / 700 psi. 06:30 - 08:00 1.50 CLEAN N DPRB DECOMP Wait on additional brine to finish fluid displacement. 08:00 - 09:00 1.00 CLEAN N DPRB DECOMP Take on hot 9.8-ppg KCI brine to pits and finish displacement of wellbore to clean brine. Called AOGCC at 0800-hours with update for BOP test to start -1000-hours. 09:00 - 10:00 1.00 CLEAN N DPRB DECOMP Pump dry job. PJSM. POOH and S/B DP, DCs in Derrick. 10:00 - 10:30 0.50 CLEAN N DPRB DECOMP B/O and UD Dress-off BHA. 10:30 - 11:30 1.00 BOPSU P DECOMP P/U Johnny Whacker, run into BOP stack and clean out cement and metal cuttings from previous operations. 11:30 - 12:30 1.00 BOPSU P DECOMP Pull wear ring and clean out drilling riser. 12:30 - 18:30 6.00 BOPSU P DECOMP Startweekl BOP testin with the Totco Gain /Loss system. Test all BOP components 250-psi low, 3500-psi high. Use 4" and 4-1/2" test joints and test only the 4" test joint in the Hydril. Test witnessed by AOGCC rep Jeff Jones, WSL Mike Rooney, Toolpusher Dave Evans. 18:30 - 19:30 1.00 BOPSU P DECOMP RD test equipment. Pull test plug. 19:30 - 21:00 1.50 CASE P TIEB1 RU casing equipment. 21:00 - 22:00 1.00 CASE P TIEB1 PJSM with all crews. MU Bowen patch assembly with ES cementer. Baker lock connections below ES cementer. 22:00 - 00:00 2.00 CASE P TIEB1 RIH with 9-5/8", 40#, L-80 casing. Put straight vane centralizer every joint. MU torque = 13K. -18 joints in hole C~3 24:00 hrs. 8/25/2008 00:00 - 01:30 1.50 CASE P TIEB1 - MU torque =13K. 01:30 - 02:00 0.50 CASE P TIEBi PUW = 105K, SOW = 110K. Tag stub ~ 1870'. Rotate pipe 1 turn to slide over stub to 1873' (3' swallow), S/O 30K down on Bowen patch. P/U to 250K to set grapple. 02:00 - 03:00 1.00 CASE P TIE61 Function test Halliburton cement head. Load plug in cement head. RU head to casing. P/T lines to 3500-psi. 03:00 - 04:30 1.50 CASE P ~ TIEB1 Overpull casing to 235K (130K over PUW). Pressure test casing to 1500-psi for 5 min. Attempt to pressure up on patch to 2000- si leaked off ~ 1 - si. Made several attempts to Printed: 9/15/2008 3:33:40 PM • • BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: 13-34 Common Well Name: 13-34 Spud Date: 8/28/1982 Event Name: WORKOVER Start: 8/16/2008 End: 8/30/2008 Contractor Name: DOYON Rig Release: 8/30/2008 Rig Name: DOYON 16 Rig Number: 16 i Date I From - To Hours Task Code NPT Phase Description of Operations 8/25/2008 03:00 - 04:30 1.50 CASE P TIEB1 pressure up on patch to 2000-psi, kept leaking off. Unable to pressure back up to 1500-psi. Appears cementer partially o ened. Make calls to town. Pressure up on cementer ~ 1.5-BPM to 3000-psi, ES cementer completely sheared w/ positive indication @ surface. Establish circulation ~ 6 BPM / 350 psi. CBU w/ warm 9.8-ppg thru cementer. 04:30 - 08:00 3.50 CEMT P TIE61 PJSM with all crews. --Schlumberger lead with 5-Bbls freshwater. S/I valve on Cementing head to check pump trips. P/T SLB lines to cement head to 4500-psi. --Schlumber er um 135-Bbls Class 'G' cement ~ 6 BPM /, 1100- si. --S/D pumping, drop ES Cementer Closing Plug, Schlumberger kick out Closing Plug with 5-Bbls freshwater. --Use rig pump to displace cement. See cement at surface and reduce pump rate to 2-BPM to watch or Closing Plug to hit ES Cementer. Got -15-Bbls of cement in returns with the last 5-Bbls as ood uali cement. --Closin Plu bum ed at 1599-strokes versus 1614-strokes calculated displacement. Increase pressure and see cement line jump at -1530-psi, indicating Cementer had closed. Increase pressure to 1850-psi, S/D pump and hold for 15 charted minutes. Cement in Place at 0633-hours. --Open to casing and have flowback. Use rig pump to pressure up to 2100-psi and hold 10-minutes. --Pump eiozan pill through kill line and stack to Slop Tank. --O en to 9-5/8" to check for flow, and still flowin bac . --S/I and casing pressures up to 300-psi in 30-seconds. --Halliburton office said to pressure up to 3000-psi and hold for 5-minutes. Pressure up and bleeds off, S/D and close OA and close Hydril. Bleed off pressure per Halliburton's lead-hand, Tom Crabtree, and flows back. S/I and pressure builds to 500-psi within 20-seconds and stays there, as of 0800-hours. 08:00 - 09:00 1.00 CEMT P TIEB1 Wait on cement. Pressure on 9-5/8" continuously charted and holding at 500-psi. Pressure steadily decreasin at -80- si/hr 09:00 - 09:30 0.50 BOPSU P TIEB1 _ N/D Tubing Spool from Casing Spool. Lift BOP stack; Cameron set emergency slips. Set stack back down, run in studs, and W OC. 09:30 - 15:00 5.50 CEMT P TIEBi WOC. Bring 4-1/2", 12.6#, 13Cr80, VamTop tubing into Pipe Shed. Clear and clean rig floor. Clean cement lines, perform work orders. 1400-hrs, 0-psi on the pressure chart, opened cement line and a small amount of fluid drained out of the line, then quit. Line is dead. Contacted ADW engineer and received "go-ahead" to cut the 9-5/8" casing. 15:00 - 16:00 1.00 BOPSU P TIEBi B/D cement lines; R/D and L/D cement head. Suck fluid out of casing to get ready for Wachs cut. N/D stack at Tubing spool / Casing spool connection. Lift stack to make room for Wachs Cutter. 16:00 - 17:30 1.50 WHSUR P TIEB1 PJSM to cut 9-5/8" casin with crew, Cameron hand, and WSL. S/O blocks to set 40K-Ibs in emergency slips. P/U 2K-Ibs tension on casing while making Wachs cut. UD cutoff; length = 30.29'. N/D old Tubing Spool from BOP stack and remove from Cellar. N/U new Tubing Spool to BOP stack. Cameron install Printed: 9/15/2008 3:33:40 PM • • BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: 13-34 Common Well Name: 13-34 Spud Date: 8/28/1982 Event Name: WORKOVER Start: 8/16/2008 End: 8/30/2008 Contractor Name: DOYON Rig Release: 8/30/2008 Rig Name: DOYON 16 Rig Number: 16 I I NPT Phase Description of Operations Date From - To Hours Task Code; - - - 8/25/2008 -- 16:00 - 17:30 1.50 WHSUR P TIE61 - new primary packoff on 9-5/8" casing stub. 17:30 - 19:00 1.50 WHSUR P TIE61 N/U new tubing spool to Casing spool and test the spool break. and primary packoff to 80% of 9-5/8", 40#, L80 collapse pressure of 3080-psi or 2400-psi. 19:00 - 19:30 0.50 WHSUR P TIE61 N/U BOPE stack to new tubing spool. 19:30 - 20:30 1.00 WHSUR P TIEB1 Set test lu .Test break on tubin s ool to 250- si low/ 3500-psi high for 5 charted minutes. Pull test plug. 20:30 - 22:00 1.50 DRILL P TIEB1 MU BHA #13. RIH to TOC at 1842'. SLB called with UCA resuts of 526-psi at 21:47 hrs. 22:00 - 00:00 2.00 DRILL P TIEB1 Drilling parameters: PUW = 67K, SOW = 70K, ROT wt = 70K. Rotate 80 RPM / 3K ft-Ibs, 40 RPM / 2K ft-Ibs. Circulate 6 BPM / 190 psi. -Drill cement from 1842' to top of pluo at 1848' with 15K WOB and 40 RPM / 3K ft-Ibs torque. -Drill thru plug with 15-25K WOB and 70 RPM / 7K ft-Ibs. -Drill thru ES cementer at 1855' with 1 K WOB and 10K ft-Ibs torque. -Recovered cement, 2" pieces of rubber and aluminum shavings while circulating. 8/26/2008 00:00 - 03:00 3.00 DRILL P TIEB1 Continue to drill thru cement. Depth 1856' at midnight. SLB called with UCA at 1200-psi at 02:20 hrs. -Cement drilling hard with 25K WOB and 3K ft-Ibs torque. Drilled ce -CBU 12-BPM / 800-psi, recovered cement. -Stand back 1 stand. MU top drive. 03:00 - 03:30 0.50 CASE P TIEB1 PJSM. Line up flowpath for casing test. Clock on test chart failed. Call for new clock. 03:30 - 04:30 1.00 CASE P TIEB1 Wait for new chart recorder. 04:30 - 05:30 1.00 CASE P TIEBi RU new chart recorder. Test 9-5/8" casin to 3500- si for 30 minutes. 05:30 - 08:00 2.50 DRILL P TIEB1 MU stand and RIH to 1877'. Continue to drill cement with 20K WOB, 3K ft-Ibs torque. Vary WOB, pump rate, and try dry drilling with very little progress beyond 1885'. Talk with ADW engineer and decide to POOH and check condition of bit. 08:00 - 09:30 1.50 DRILL P TIEB1 POH and S/B DP and DCs in Derrick. 09:30 - 10:00 0.50 DRILL P TIE61 B/O, empty Boot Baskets--get 3-gallons, 32-Ibs of ground-up aluminum, brass, and cement. The 8-1/2" milled tooth bit is in good shape and will be re-run for next run. M/U cleaned boot baskets and 8-1/2" bit to bumper sub and RIH to continue cement cleanout at 1885'. 10:00 - 12:00 2.00 DRILL P TIEB1 RIH 8-1/2" bit BHA on 6-1/4" DCs from Pipe Shed and 4-3/4" DCs and DP from Derrick. f 2:00 - 17:00 5.00 DRILL P TIEB1 P/U stand #14 and get parameters: Up wt 83K-Ibs, Down wt 87K-Ibs, Rotating wt 88K-Ibs, free torque 4K-Ib-ft, 3-1/2-BPM, 80-psi. Stop rotating and RIH to tag at 1885'. P/U, start pump and bring up to 5-BPM, 160-psi, rotate at 70-RPM, and RIH to start drilling. Make much better progress: 3' in the first 30-minutes. Drill to 1910' at 1615-hours. Punched into the sand at 1920' at 1715-hours. 17:00 - 17:30 0.50 DRILL P TIE61 Mlx and pump a 20 bbl Hi-Vis sweep and circulate back to surface at 11 bpm/700 psi. 17:30 - 18:00 0.50 DRILL P TIEB1 Dry drill into top of sand at 1,921' down to 1,926'. 18:00 - 18:30 0.50 DRILL P TIEB1 Trip out with BHA #14. Stand back Drill Plpe and the 4 3/4" Printed: 9/15/2008 3:33:40 PM • • BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Name: 13-34 Common Well Name: 13-34 Spud Date: 8/28/1982 Event Name: WORKOVER Start: 8/16/2008 End: 8/30/2008 Contractor Name: DOYON Rig Release: 8/30/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase ', Description of Operations 8/26/2008 18:00 - 18:30 0.50 DRILL P TIEB1 Drill Collars. 18:30 - 19:30 1.00 DRILL P TIEB1 Lay down 9 ea 6 1/4" Drill Collars in Pipe Shed. lay down BHA #14. Clear and clean floor. 19:30 - 20:00 0.50 CASE P TIEB1 Make u BHA #15 as follows: 8 1/2" RCJB, Boot Basket, Boot Basket, Bit Sub, Bumper Sub, Pump-out Sub, XO, 9 ea 4 3/4" Drill Collars. 20:00 - 20:30 0.50 CASE P TIEB1 Trip in to 1,835'. PUW = 70K. SOW = 70K. Drop ball and bring pump on line at 3.0 bpm/150 psi. Pressure increased to 530 psi with ball on seat. Wash into sand from 1,921'to 1,943' at 4.5 bpm/1,125 psi. 20:30 - 21:00 0.50 CASE P TIEB1 Drop Dart to open Pump-out Sub. Circulate out sand at 12.0 bpm/930 psi. 21:00 - 21:30 0.50 CASE P TIEB1 Trip out with BHA #15. 21:30 - 22:00 0.50 CASE P TIEB1 Lay down BHA #15. Clean RCJB and Boot Baskets. Recovered one piece of 3" x 3" and three pieces of 2" x 2" flat iron (from 9 5/8" cutting/dress off ops). Boot baskets were empty. Rebulid BHA #16 to include a Casing Scraper. 22:00 - 22:30 0.50 CASE P TIEB1 Trip in to 1,839'. Drop ball. 22:30 - 23:30 1.00 CASE P TIEB1 Ball on seat. Wash down through sand from 1,943' to 1,964' at 5 bpm/1300 psi. -8 feet of sand remains on top of RBP. Mix and pump a 20 bbl Hi-Vis sweep. Drop ball and open Pump-out Sub. Pump sweep to surface at 12.0 bpm/960 psi. 23:30 - 00:00 0.50 CASE P TIE61 Trip out with BHA #16 8/27/2008 00:00 - 01:00 1.00 CASE P TIE61 Blow down Top Drive. Lay down BHA #16. Clean RCJB and Boot Baskets. Recovered 4 more small pieces of iron and one 2" x 2" piece of iron in the RCJB. Boot Baskets were clean. 01:00 - 03:00 2.00 CASE P TIEBi Pick u Halco Running Tool. Trip in with Drill Pipe to 1,913'. PUW =70K . 50W =73K . Wash down to 1,972' (top of Halco RBP) at 6.0 bpm/670 psi. 03:00 - 04:00 1.00 CASE P TIE61 Reverse circulate Hi-Vis sweep to clean up well at 12.0 bpm/1250 psi. 04:00 - 04:30 0.50 CASE P TIE61 Rig back up to circulate the long way. Displace the 9,8 Ib/gal Brine over to 2 % KCL down to the RBP at 1,972'. 04:30 - 05:00 0.50 CASE P TIE61 Latch and release Halco 9 5/8" RBP. Circulate bottoms up. Monitor Well. Hole remains full and static. 05:00 - 06:00 1.00 CASE P TIEB1 POOH with Drill Pipe and Halco RPB. 06:00 - 11:00 5.00 CASE P TIE61 P/U Halco 7" RBP and RIH on DCs and DP from Derrick to test 7" and 9-5/8" from -8450'. Have to rotate full turn to get through the 7" Liner Top at 5473'. Continue RIH. P/U stand #86, M/U to Top Drive, and get parameters: Up weight 170K-Ibs, Down weight 150K-Ibs. RIH to 8433' to set RBP; establish circulation• S/D um . P%U and set RBP at 8 3'. 11:00 - 12:00 1.00 CASE P TIE61 Bring pressure up to 3700-psi and hold for 30-minutes recording on chart. Ending pressure was 3580-psi, 12:00 - 14:00 2.00 CASE P TIE61 Release RBP and POH, S/B DP and DCs in Derrick. 14:00 - 14:30 0.50 FISH P RUNCMP B/O RBP and L/D. Bring 2-7/8" PAC DP handling equipment to the rig floor. 14:30 - 16:00 1.50 FISH P RUNCMP P/U M/U Junk Catcher Spear BHA: Baker Spear dressed with 2.93" grapple, 10-joints 2-7/8" PAC DP from Pipe Shed. 16:00 - 17:15 1.25 FISH P RUNCMP RIH with S r er. 50-stands RIH at 1715- 17:15 - 19:00 1.75 FISH P RUNCMP Continue RIH with BHA #17 to top of 4 1/2" tubing stump at Printed: 9/15/2008 3:33:40 PM BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: 13-34 Common Well Name: 13-34 Event Name: WORKOVER Contractor Name: DOYON Rig Name: DOYON 16 Date From - To Hours '~, Task Code' NPT 8/27/2008 17:15 - 19:00 1.75 FISH P 19:00 - 20:00 1.00 FISH P 20:00 - 23:30 3.50 FISH P 23:30 - 00:00 0.50 FISH P 8/28/2008 ~ 00:00 - 03:30 3.501 FISH ~ P 03:30 - 04:30 I 1.001 FISH I P 04:30 - 05:30 ~ 1.00 ~ FISH ~ P 05:30 - 16:00 I 10.501 FISH I P 16:00 - 16:30 0.50 16:30 - 17:00 0.50 17:00 - 18:00 I 1.00 18:00 - 18:30 0.50 18:30 - 19:00 0.50 19:00 - 22:30 I 3.501 RUNCON'N I WAIT 22:30 - 23:00 I 0.50 23:00 - 00:00 I 1.00 8/29/2008 ~ 00:00 - 05:30 ~ 5.50 05:30 - 10:30 I 5.00 Spud Date: 8/28/1982 Start: 8/16/2008 End: 8/30/2008 Rig Release: 8/30/2008 Rig Number: 16 Phase '~ Description of Operations RUNCMP 8,483'. PUW = 170K. SOW = 150K. Entered stump without m .- Continue to ease through 4 1/2" completion. Set down at 8,522' (top of Junk Catcher Sub at 8,747'). Pick up with 20K over pull. Set back down at same spot. Pull up above tight spot. Discovered that the ID of a GLM below the top of the 4 1/2" stump is only 3.650" ID. OD of the "stop" on the Spear is 3.750". RUNCMP Pull BHA and park above top of stump. Bring pump on line at 2.5 bpm/1930 psi. Discuss finding and plan forward with Anch Eng. Pump dry job. RUNCMP Blow down Top Drive. Trip out with BHA #17. RUNCMP Chan a out S ear assembl .BHA #18 as follows: Bowen Itco Spear w/ 3.03 Grapple (catch range 2.90" - 3.10"), XO, XO, 10 Jts 2 7/8" PAC Drill Plpe, XO, Bumper Sub, Oil Jar, Pump-out Sub, XO, 9 ea 4 3/4" Drill Collars. RUNCMP RIH with BHA #18 and 4" Drill Pipe. Stop to break circulation at 3,500' and 6,300'. Enter 4 1/2 Tubing Stump with no problems. Continue down to 8,688' with no problems. PUW = 170K. RUNCMP Bring #1 Pump on line at 2.5 bpm/680 psi. Ease in looking for top of Junk Catcher Sub (expected top at 8,747'). Tagged Junk Catcher Sub at 8,760' dpm. Plant Spear. Pick up. Set back down 2' higher at 8,758'. Repeat with same results. RUNCMP Pull back out of 4 1/2" Stump to _8,470'. Drop dart to open Pump out Sub. Mix a 10 bbl Hi-Vis pill. Circulate bottoms up at 11.5 bpm/1740 psi. RUNCMP POOH and single down Drill Pipe in Pipe Shed. Filling DP with 1-2 to 1-Bbl freshwater every 15-joints to clean brine from inside DP before L/D through the Pipe Shed. Have to steam all the DC joints to break them with rig tongs; torque breaks up to 40K-ft-Ibs. 1500-hours at 2-7/8" PAC pipe. BO the 3" Junk Catcher. It was in good shape and had funk inside it.. RUNCMP Pull Wear Bushing. Clear and clean floor. RUNCMP Safety Meeting with Doyon General Manager, WSL, and Rig Crew. RUNCMP Rig up floor to handle 4 1/2" chrome completion. Rig up torque turn equipment. RUNCMP PJSM with WSL and Crew. RUNCMP Prep to begin picking up completion equipment. Perform final equipment inspection. Discovered that the Unique Overshot shoe measured 8 1/2" and will not fit inside the 7" Liner section. RUNCMP Contact Stores to get the correct size Unique Overshot made up and delivered. RUNCMP Receive proper size Unique Overshot. Measure OD = 5.875". ID = 4.654". Tally same. RUNCMP Pick up completion jewelry as follows: Unique Overshot, 1 Joint 4 1/2" 12.6 Ib/ft 13Cr 80 Vam Top Tbg, X-Nipple assy w/RHC-M installed, Baker 7" x 4 1/2" S-3 Packer, X-Nipple assy. All connections below Packer are Baker-Lok'd. RUNCMP Continue picking up 4 1/2" 12.6 Ib/ft 13Cr80 Vam Top completion as designees. thea~eac-Sea;~uard pipe dope. Make-up torque = 4,440 ft-Is. RUNCMP Enter the 7" Liner at 5,473' with no problems. Continue running Printed: 9/15/2008 3:33:40 PM c: BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: 13-34 Common Well Name: 13-34 Spud Date: 8/28/1982 Event Name: WORKOVER Start: 8/16/2008 End: 8/30/2008 Contractor Name: DOYON Rig Release: 8/30/2008 Rig Name: DOYON 16 Rig Number: 16 I I Code N'PT Phase Description of Operations Hours Task Date From - To 8/29/2008 05:30 - 10:30 5.00 BUNCO RUNCMP completion. P/U joint #194, RIH slowly with 128K-Ibs down weight. See first set of pins shear with 9K-Ibs, putting top of stub at 8485'.. See second set of pins shear with 8K-Ibs. P/U jt #195 to continue in to check No-Go. Find No-Go at 13.5' swallow; P/U 20' to RBIH to verify ease of getting over the stub. Stack out on No-Go with 10K-Ibs. Calculate space-out with a 10' pup joint under joint #193. R/D Torque Turn Compensator. H/U trucks to get ready for pumping completion/packer fluid. 10:30 - 11:30 1.00 BUNCO RUNCMP P/U M/U Tubing Hanger to tubing and M/U Landing Joint with XOs to Tubing Hanger. Hold PJSM for landing hanger and packer fluid circulation. P/U weight 142K-Ibs, S/O weight 130-K-Ibs. RIH and land hanoer. RILDS. 11:30 - 16:00 4.50 BUNCO RUNCMP R/U to reverse circulate packer fluid. Pressure test lines to 3,500-psi. Pump 130-Bbls 120E 2%KCI, followed by 360-Bbls 2%KCI with EC-1124A Corrosion Inhibitor at 2.5-BPM, 420-psi. 16:00 - 18:00 2.00 BUNCO RUNCMP R/U to drop ball and rod. Drop ball and rod and wait for. 20-minutes. Pressure u on tubin to 3600- si and h Id for 30-minutes recorded on chart. Bleed off tubing to 1500-osi. Pressure uo on IA to 3600-psi and hold for 30-mintes recorded on chart. Packer/Casin test lost 225 Ibs in 35 minutes. Bleed_ pressure off of the tubing side and shear open the DCR valve. Pump both directions at 3 bpm to confirm valve is sheared. 18:00 - 20:00 2.00 BOPSU P RUNCMP Lay down landing joint. Set and test TWCV at 3,500 psi from below and 1,000 psi from below x 10 minutes each. Record on chart. 20:00 - 21:30 1.50 BOPSU P RUNCMP Blow down lines. Suck out stack. Nipple down BOP stack and spacer spool. 21:30 - 23:00 1.50 WHSUR P RUNCMP Nipple up Adaptor Flange and test at 5,000 psi x 30 minutes. Good test. 23:00 - 00:00 1.00 WHSUR P RUNCMP Nipple up production tree. 8/30/2008 00:00 - 01:00 1.00 WHSUR P RUNCMP Complete nipple up Production Tree. Fill tree with diesel and rig up test equipment. 01:00 - 02:00 1.00 WHSUR P RUNCMP Test Production Tree at 5200 psi x 30 minutes. Record on chart. (Lost -200 psi in 30 minutes. No visable leaks). 02:00 - 03:00 1.00 WHSUR P RUNCMP Pick up lubricator and test to 500 psi. Pull TWCV. Lay down_ same. 03:00 - 05:00 2.00 BUNCO RUNCMP Rig up Lil' Red. Pressure test line at 3,500 psi. Pump diesel at 4.0 bpm/700 psi. Total diesel pumped = 150 bbls. 05:00 - 06:00 1.00 BUNCO RUNCMP Allow diesel to u-tube. Rig down Lil' Red. 06:00 - 08:00 2.00 BUNCO RUNCMP Secure Production and cellar. Bridle up and prep to rig down Derrick. Release rig at 08:00 hrs. Printed: 9/15/2008 3:33:40 PM 08/26/08 ~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wpu .Inh ~ N0.4843 Company: State of Alaska ~`~~~ ~ ~ ~ ~ ~~~~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ ..,. ~e ...:,... .,_._ e~ H-31 11999035 USIT k3 _ IG 08/16/08 1 1 14-22A 11999036 PPROF W/FSI 08/17/08 1 1 13-34 11676963 USIT a - 08/18/08 1 1 H-35 11970840 RST .. , G f 3 08/12/08 1 1 G-16 11982438 RST 1 06/21/08 1 1 L1-09 12017501 CH EDIT (SONIC SCANNER) ~ '~ 06/06/08 1 1 ~ ~a...v~ ..•..~~.v..~cvvc nca.ur ~ o. ~I171Y11Y17 /a1VU r1C1 Urfnllnlta VIVO ~.VYT CAG17 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ,~ ,~,,~ a.~ ~, 900 E. Benson Blvd. ~~ ~R Anchorage, Alaska 99508 s Date Delivered: h i ~{{~ c~.-~ac~; ~\~SSk~3 tJi~ is ~ae3S ~.sC+lla. ~.-~~(1STlf(lf~`:nl0il ~n~h~afa~e Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 Anchorage, AK 99503-2838 ATTN: Beth Received by: 1r u • ie • • } ~, ~. q ¢~ ' ~'t~ ~t ~ SARAH PAL/N, GOVERNOR ~ ~~ ~ ~ ~€~ ~ -~J~ Ais[s-7~ OIL A1~TD GA5 333 W. 7th AVENUE, SUITE 100 CO1~T5ER'QA'1`IO1~T CODZl-IISSIOrT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Q' ~- ~ 3 lv Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-34 Sundry Number: 308-266 Dear Mr. Reem: ~~'~~~~~ AUu ~ ~ 2Q0$ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~„ Chair DATED this / day of , 2008 Jt~ Encl. STATE OF ALASKA ALA~IL AND GAS CONSERVATION COMM~N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 -- ~ . ,. 3' 1 J ~~ E_ ~~. ~ r'_ li It 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ dime Ekten5ian - ® Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspdnded WeN - ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 182-136 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20811-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 13-34 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft}: 11. Field /Pool(s): ADL 028315 87' Prudhoe Bay Field I Prudhoe Bay Pool 12- PRESENT WELL CONDITION' SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9525' 9275' 9230' 8982' 8774' 9212' Casin Len th Size MD TVD Burst Colla se Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2585' 13-3/8" 2585' 2585' 4930 2670 Intermediate 8992' 9-5/8" 8992' 8747' 6870 4760 Production Liner 4050' 7" 5473' - 9523' 5355' - 9273' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 9031' - 9330' 8785' - 9082' 5-1/2" x 4-1/2" x 3-1/2" L-80 8894' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer; Packers and SSSV MD (ft): 8539'; 7" x 5" Baker'FB-1' packer 8800' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: September 1, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Name D id Reem Title Engineering Team Leader Prepared By Name/Number. Signature Phone 564-5743 Date. ~ r7 Terrie Hubble, 564-4628 Commission- Use.Qnl Sundry Number: _ a Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: °~ ~V~ ~S ~ \~ ~ -~~,~ Subsequent Form Required: i-r~ ~1 APPROVED BY Q~~C O A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Rev d 06/2006 ~ ~ ~'"° ~~ `~g S ~~ ~u~ o ~ zoos Submit In Duplicate r 9w71 $ • by c am,, 13-34 Rig Worlcover (Restore OA/IA integrity) Scope of Work: Pull 5.5/4.5" 13 Cr-80 tubing (2 packers will remain in well), cut and pull 9-5/e" casing, tie- back w/ new 9 5/$" casing (cemented to surface), replace 9 e/8" hanger and primary pack-off, and run 4.5" 13 Cr-80 completion. Engineer: Hank Baca MASP: 3300 psi Well Type: Producer Estimated Start Date: September 1St, 2008 F 1 CMIT TxIAxOA to 2000 psi for 30 minutes. Circulate well with seawater and FP w/ diesel thru the cut. Bleed WHP's to 0 si. NOTE: well failed MIT TxIA 9/15/07, but assed TxIAxOA S 2 Dum bail 15' slu its on to of PDB ron / lu E 3 Power Jet cut tubing C~1 8,483' (Ref: 2/11/96 tubing summary). Jet cut desired to be 20' down on the 1st full 'oint above the acker 40' 'oints . O 4 PPPOT-T, -IC, check all LDS. O 5 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/ 3500 psi high. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD tubing string to the cut. 3. RU wireline and run USIT from cut to surface. 4. Run 9 5/$" RBP and set -100' below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set. Dump ~50 ft of sand on RBP. 5. Mechanically cut 9 s/8" casing in 1St full joint above top of cement. Pull casing thru stack. Dress-off 9- 5/e" stub in preparation of casing overshot. Note: VBR's will not be changed to 9-5/$" pipe rams as `~~ the well has two tested barriers (PDB ~ 8,774' MD and RBP) to the reservoir. 6. Run back in with new 9 s/8", 47#, L-80 casing and land on new emergency slips with new primary ~~ 3 pack-off. PT 9 s/a" pack-off to 3500 psi. Cement new 9 5/8' casing to surface 7. Cleanout above 9 5/" RBP. Pull 9-5/" RBP. 8. Run 4-th" 13Cr-80 completion with Baker S-3 packer. 9. Displace the IA to packer fluid and set the packer. 10. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 11. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. ~~'~c; WELL EAD = GRAY ACTUATOR= __ AXELSON B. ELEV = 87' BF. ELEV = KOP = 2900' Max Angle - 19 @ 5800' Dat Datu - 20" CONDUCTOR, - j 79• um MD = 9134' 94#, H-40, ID = ? m TV D = 8800' SS 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681 " 1609' (RWO 05/29/88) 13-3/8" CSG, 72#, L80 BUTT, ID = 12.347" 2$$5' Minimum ID = 2.75" @ 8881' 3-1/2" OTIS XN NIPPLE 5-112" TBG, 17#, 13CR NSCC, 5433' .0232 bpf, ID = 4.892" TOP OF 7" LNR TIEBACK 5473' 9-5/8" CSG, 47#, L-80 XO TO S0095 - SAFETY NOTES: *" 5-112" 8~ 4"-1/2" CHROM E TBG " 13 -3 4 0~ ~~ CORRECTED TAO ORIgNAL 1RFB~ ~16' 2240' 5-1/2" CAM BAL-O SSSV NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH R7RT DATE 1 3600 3571 18 LB DMY T-2 0 03/08!07 2 5414 5299 18 LB DMY T 2 0 03/08/07 3 6170 6016 19 *KBG-2-LS DMY BK 0 03/08/07 4 7648 7427 15 'KBG-2-L DMY BK 0 5 8513 8273 9 `KBG-2-L DMY BK 0 "4-7/Z" X 7" KBG-Z-LS GLMS = 3.65" ID 5-1/2" X 4-112" XO, 3.875" 17" X 4-1/2" BKR S-3 PKR, ID = 3.875" I 7" TIEBK LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ 8704' 7" BOT LNR HGR 8710' 4-1/2" TBG, 12.6#, 13CR-80 NSCT, I 8795' .0152 bpf, ID = 3.958" 3-1 /2" TBG, 9.3#, L-80 8RD, $$94' .0087 bpf, ID = 2.992" 9-518" CSG, 47#, S0095 BUTT, ID = 8.681" - PERFORATION SUMMARY REF LOG: BHCS ON 09/08/82 ANGLE AT TOP PERF: 8 @ 9031' Note: Refer to PI'oduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-518" 2 9031 - 9035 C 08/29!91 3-1/8" 4 9102 - 9142 C 02/22/86 2-5/8" 4 9116 - 9126 C 08/29/91 2-5/8" 4 9156 - 9166 C 08!29!91 3-1/8" 4 9156 - 9216 C 02/09/83 2-1/8" 4 9312-9330 C 07/12/98 PBTD 7" LNR, 29#, L-80 BUTT, .0371 bpf, ID = 6.184" I 9523' I $774' - 14-1/2" CAM DB NIP NO-GO, ID = 3.50" 8774' 4-1/2" PDB PLUG (09/08/07) 8795' 4-1/2" X 3-1/2" XO, ID = 2.992" 8811' 4-112" BKR GBH-22 SEAL ASSY W/O SEALS 8800' 7" X 5" BKR FB-1 PKR w / SEALBORE EXT, ID = 4.00 8813' 5-5/8" MILLOUT EXT, ID = 4.00" 8814' 5-518" X 3-1/2" XO, ID = 2.992" 8881' 3-1 /2" OTIS XN NIP, ID = 2.75" 8893' 3-1/2" BKR SHEAROUT SUB 8894' 3-1/2" TUBING TAIL, ID = 2.992" 8906' ~ ELMDTT LOG NOTAVAILABLE 9046' I-17" DOUBLE MARKER JOINT 9230' H CLASS G CEMENT CAP- 01/28/03 I 9268' TOP OF SAND (CARBOLfTE) - 01/28/03 9212' SLM FISH - CA-E 1" DGLV (LATCH PULLED; DATE REV BY COMMENTS DATE REV BY COMMENTS 09/11/82 AN 4 ORIGINAL COMPLETION 02/17/07 DAV/PAG GLV CORRECTIONS-3.65" ID 08!15/88 AUDI 1 WORKOVER 03/02/07 KSB/TLH DIAGRAM & DEPTH CORRECTION 02/13/98 D-18 LAST WORKOVER 03/08/07 TEVPAG GLV GO 08/02/01 RWKAK CORRECTIONS 05/28/07 SPF/TLH PLUG SET (04!17/07) 01/28/03 TNfTP SAND DUMP W/CMT CAP 09/08/07 JCM/PJC SET PDB PLUG @ 8774 10/09/05 RPH/TLH WANERSFTY NOTE DELETED PRUDHOE BAY UNfT WELL: 13-34 PERMfT No: 1821360 API No: 50-029-20811-00 SEC 14, T10N, R14E, 23.08' FEL i£ 2183.39' FNL BP Exploration (Alaska) WELL EAD = GRAY ACTUATOR = _ AXELSON B. ELEV = 8T BF. ELEV = KOP = 2900' Max Angle - 19 @ 5800' oat Da 13 -34 SAFETY NOTES: *" 5-1/2" 8 4"-1/2" CHROM E TBG *" PROPOSED 1996 DEPTHS (SURFACE TO 8811') ARE-16' OFF CORRECTF~ TO ORIgNAL RKB - 20" CONDUCTOR, ~ 79• um MD = 9134' 94#, H-40, ID = ? tum TV D = 8800' SS 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" 1609' (RWO 05/29/88) 13-3l8" CSG, 72#, L80 BUTT, ID = 12.347" 2585' Minimum ID = 2.75" @ 8881' 3-1/2" OTIS XN NIPPLE NEW 9-5/8" CSG, 47#, L-80 from TOC to surface GAS LIFE MANDRFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2863 2 4575 3 5626 4 6520 5 7358 s 8234 ~4-1/2" HES X NIP, ID = 3.813" I TOP OF 7" LNR TIEBACK 5473' 4.5" X 7" Baker S-3 PKR 4-1/2" HES X NIP,ID = 3.813" 9-5/8" CSG, 47#, L-80 XO TO S0095 8286' UNNIUE MA CHINE OV ERSHOT 8539' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 7" TIEBK LNR 29#, L-80, .0371 bpf, ID = 6.184" $704' 8774' 4-1/2" CAM DB NIP NO-GO, ID = 3.50" 7" BOT LNR HGR 8710' 8795' 4-1/2" X 3-1/2" XO, ID = 2.992" 4-1/2" TBG, 12.6#, 13CR-80 NSCT, 8795' 0152 b f ID = 3 958" 8811' 4-1/2" BKR GBH-22 SEAL ASSY W/O SEALS p , . . 8800' 7" X 5" BKR FB-1 PKR w / SEA LBORE EXT, ID = 4.00 8813' S-5/8" MILLOUT EXT, O = 4.00" 8814' 5-5l8" X 3-1/2" XO, ID = 2.992" 8881' 3-1/2" OTIS XN NIP, ID = 2.75" 3-1/2" TBG, 9.3#, L-80 SRD, 8894' .0087 bpf, ID = 2.992" 9-5l8" CSG, 47#, Soo95 BUTT, ID = 8.681" H 8992' PERFORATION SUMMARY REF LOG: BRCS ON 09/08/82 ANGLE AT TOP PERF: 8 @ 9031' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-5/8" 2 9031 - 9035 C 08/29/91 3-1/8" 4 9102 - 9142 C 02/22/86 2-5/8" 4 9116 - 9126 C 08/29/91 2-5/8" 4 9156 - 9166 C 08/29/91 3-1/8" 4 9156 - 9216 C 02/09/83 2-1/8" 4 9312 - 9330 C 07/12/98 PBTD 9480' 7" LNR, 29#, L-80 BUTT, .0371 bpf, ID = 6.184" 9523' 3-1/2" BKR SHEAROUT SUB 3-1/2" TUBWG TAIL, ID = 2.992" ELMD TT LOG NOT AVAILABLE 9046' H 7" DOUBLE MARKER JOINT 923' J-{CLASS G CHNENT CAP- 01/28/03 9268' TOP OF SAND (CARBOLITE) - 01!28/03 FISH - CA-E 1" DGLV (LATCH PULLED) (08/12/95) DATE REV BY COMMENTS DATE REV BY COMMENTS 09!11/82 OWAN 4 ORIGINAL COMPLETION 02/17/07 DAV/PA GLV CORRECTIONS-3.65" ID 06/15/88 AUDI 1 WORKOV ER 03/02/07 KSB/TLH DIAGRAM 8~ DEPTH CORRECTION 02/13/96 D-16 LAST WORKOVER 03/08/07 TEL/PAG GLV GO 08/02/01 RWKAK CORRECTIONS 05/28/07 SPFfrLH PLUG SET (04/17/07) 01/28/03 TN/TP SAND DUMP W/CMT CAP 09108/07 JCIWPJC SET PDB PLUG @ 8774 10/09/05 RPHITLH WA V ER SFTY NOTE DELETED PRUDHOE BAY UNfT WELL: 13-34 PERMfr No: 1821360 API No: 50-029-20811-00 SEC 14, T10N, R14E, 23.08' FEL & 2183.39' FNL BP Exploration (Alaska) '-"' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSluN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__~ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 2225' NSL, 1560' WEL, Sec 14, T10N, R14E, MM. At top of productive interval: 2196' SNL, 77' WEL, Sec 14, T10N, R14E, MM. At effective depth: 2188' SNL, 28' WEL, Sec 14, T10N, R14E, MM. At total depth: 2187' SNL, 24' WEL, Sec 14, T10N, R14E, MM. 5. Type of Well: Development _X Exploratory _ Stratagrapic _ Service _ 6. Datum of elavation (DF or KB feet): 87' RKB 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 13-34 9. Permit number/approval number: 82-136 10. APl number: 50-029-20811 11. Field/Pool: Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured true vertical 9525 feet Plugs (measured) 9275 feet PBTD Tagged @ 9131' MD (12/4/98), Effective Depth: measured true vertical Casing Length Conductor 79' Surface 2546' Production 8955' Liner 4050' 9380 feet Junk (measured) 9131 feet Size Cemented 20" 300 Sx PFC 13-3/8" 2200 Sx Fondu & 400 Sx PFC 9-5/8" 500 Sx Class G & 300 Sx PFC 7" 855 Sx Class G Measured depth 79' 2585' 8992' 9523' True ve~icaldepth 79' 2584' 8746' 9273' Perforation Depth measured 9031 - 9035'; 9102- 9142'; 9156 - 9216'; 9312 - 9330' true vertical 8785 - 8789'; 8855- 8895'; 8909 - 8968'; 9064- 9082' ORIGINAL Tubing (size, grade, and measured depth) 5-1/2", 17#, 13 CR-80 Tbg @ 5433' MD; 4-1/2", 12.6#, 13 CR-80, Tbg @ 5433- 8795' MD 3-1/2", 9.3#, L-80, Tbg @ 8795- 8894' MD. Packers and SSSV (type and measured depth) 7" Baker S-3 Packer @ 8539' MD; 7" Baker FB-1 Packer @ 8800' MD 5-1/2" Camco Bal-O SSSV @ 2204' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured) see a~ached 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ %. ~__ Title: Engineering Supervisor Form 10-404 Rev 06/15/88 Represen~t~eDailyAverage Productionorlnjec~on Data OiI-Bbi Gas-Mcf Wa~r-Bbl 186 2877 3351 199 2693 3016 Casing Pressure Tubing Pressure 217 222 16. Status of well classification as: Oil _X Gas _ Suspended _ Service _ Date SUBMIT IN DUP 13-34 DESCRIPTION OF WORK COMPLETED ADD PERFORATIONS & CT ACID STIMULATION TREATMENT W/PACKER 7/24/98: RIH & tagged PBTD at 9219' MD. 7/25/98: RIH w/CT & jetted a fill cleanout from 9219' to 9380' MD. 7/26/98: RIH & tagged PBTD at 9380' MD. 7~29/98: Added Perforations: 9312 - 9330' MD Ref. Log: BHCS 9/8/82. Shot the perfs at 4 spf @ 180 degree phasing at overbalanced pressure. POOH w/guns. RD. 10/5/98: Ran a PPROF which indicated no flow from the add perf interval (listed above). 12/4/98: RIH & tagged PBTD at 9380' MD. 12/13/98: A CT Acid Stimulation Treatment w/Inflatable Packer was performed as follows: MIRU CTU & PT equipment. Loaded the wellbore w/NH4CI Water, then RIH w/CT mounted Packer. Inflated & set the packer at 9270' MD, to isolate the upper open perforation intervals located at: 9031 - 9035' MD (Sag) 9102- 9142' MD (Z4) 9156 - 9216' MD (Z4) Ref. Log: BHCS 9/8/82. Pumped · a) 20 bbls 1% KCI Water @ 1.5 bpm, followed by b) 17 bbls 50% Diesel/50% Xylene @ 1.3 bpm, followed by c) 35 bbls 12% HCI w/10% Xylene w/4% Acetic Acid @ 1.35 bpm, followed by d) 20 bbls 9% HCI- 1% HF @ 1.5 bpm, followed by e) 36 bbls 12% HCI w/10% Xylene @ 1.6 bpm, followed by f) 70 bbls 90% NH4CI w/10% Mutual Solvent @ 1.6 bpm, followed by g) Shutdown. Deflated & POOH w/Packer. RD. Returned the well to production w/gaslift & obtained a valid production welltest. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing :' Alter casing __ Repair well tv, Perforate__ Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2225'NSL, 1560' WEL, SEC. 14, TION, R14E At top of productive interval 2196' SNL, 77' WEL, SEC. 14, TION, R14E At effective depth 2188' SNL, 28' WEL, SEC. 14, TION, R14E At total depth 2187' SNL, 24' WEL, SEC. 14, TION, R14E ORI61NAL 12. Present well condition summary 6. Datum elevation (DF or KB) KBE = 87 7. Unit or Property name Prudhoe Bay Unit 8. Well number 13-34 9. Permit number/approval number 82-136 10. APl number 50- 029-20811 11. Field/Pool Prudhoe Bay Field/Oil Pool RECEIVED feet Total depth: Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 9525 true vertical 9275 measured 9480 true vertical 9230 Length Size .. 79' 20" 2546' 13-3/8" feet Plugs (measured) feet feet Junk (measured) feet Cemented APR 0 9 1996 Alsska 0il & Gas Cons. Commission Ancb.oraae Measured depth I rue'vertical depth 300 sx PF 'C' 79' 79' 2200 sx Fondu, 400 sx PF 'C' 2585' 2584' 8955' 9-5/8" 500 sx 'G', 300 sx PF 'C' 8992' 8746' 813' 7" 285' SX C/ass 'G' 8710'- 9523' 8467'- 9273' 3237' 7" 570 sx Class 'G' 5473' - 8710' 5355' - 8467' measured 9031' - 9035', 9102'- 9116', 9116'- 9126', 9126'- 9142', 9156' - 9166', 9166' - 9216' true vertical 8785'- 8789', 8855'- 8869', 8869'- 8879', 8879'- 8895', 8909'- 8919', 8919'- 8968' Tubing (size, grade, and measured depth) 5-1/2", 17#, 13Cr80 to 5433'; 4-1/2", 12.6#, 13Cr80, 5433'- 8795'; 3-1/2", 9.3#, L-80 8795'- 8894' Packers and SSSV (type and measured depth) 5-1/2" Camco Bal-O SSSV at 2204'; 7" Baker S-3 packer at 8539'; 7" Baker FB-1 packer at 8800' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I herebyf~i~ that the~ true and correct to the best of my knowledge. Signed %"-~/'~,t-,-~ Title Senior Dri/ling Engineer Form 10-404 Rev 06/1-5/8§ - t./ Date SUBMIT IN DUPLICATE SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: Accept Date: 13-34 RWO Rig Name: Doyon 16 AFE: 02/08~96 Spud Date: N/A Release Date: 4J8036 O2113/96 Feb 9 1996 (1) Rig moved 100 %. Fill pits with Seawater. Removed Hanger plug. Circulated at 8180 ft. Feb 10 1996 (2) Circulated at 8180 ft. Installed Hanger plug. Removed Xmas tree. Rigged up BOP stack. Tested BOP stack. Retrieved Hanger plug. Pulled Tubing on retrieval string to 20 ft. Pulled Tubing on retrieval string to 20 ft. Feb 11 1996 (3) Pulled Tubing hanger. Circulated at 8800 ft. Laid down Tubing to 2180 ft. Rigged down sub-surface equipment - SCSSSV nipple assembly. Laid down Tubing to 0 ft. Tested Casing - Via an- nulus. Tested BOP stack. Conducted slickline operations on Slickline equipment- Tool run. Feb 12 1996 (4) Conducted slickline operations on Slickline equipment - Tool run. Rigged down Slickline unit. Tested Completion equipment. Rigged up Tubing handling equipment. Ran Tubing to 6607 ft (5.5 in OD). Rigged up sub-surface equipment - SCSSSV nipple assembly. Feb 13 1996 (5) Held safety meeting. Ran Tubing to 8810 ft (5.5 in OD). Space out tubulars. Installed Tubing hanger. Circulated at 8810 ft. Ran Tubing on landing string to 8810 ft. Conducted slickline operations on Slickline equipment - Tool run. Rigged up sub- surface equipment - Setting tools. Set downhole equipment (wire- line). Set Permanent packer at 8539 ft with 4000 psi. Installed Hanger plug. Rigged down BOP stack. Feb 14 1996 (6) Held safety meeting. Rigged down BOP stack. Installed Xmas tree. Tested All tree valves. Removed Hanger plug. Freeze pro- tect well - 140 bbl of Diesel. Installed Hanger plug. Rig moved 2 %. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9739 Company: 9/20/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk O.S. 1-11 "7 "~ C~ 5'-7 PERFRECORD 950902 I 1 'D.S. 1-10 -7 ~ ~) H_~ PROD PROFILE 9 5 09 0 2 I 1 D.S. 1-20 ~f"7,-- I H ~' PRODPRORLE 950905 I 1 D.S. 1-22A ~ ~ ~ ~ , BAKER INF~TABLE BRIDGE PLUG 950906 I 1 D.S. 5-6A ~ ~ ~ ~ PERF RE.RD 9 5 09 05 I 1 D.S. 9-4A~ O ~ RSTB/GR 950813 I 1 D.S. 11-28 OO ~ CHEMICAL C~ER RECORD 950903 I 1 D.S. 13-34 ~ I ~ ~ LEAK DETECTION 950904 I 1 D,S, 15-12~ ~ ~ BAKER INF~TABLE BRIDGE PLUG 950901 I I ~,. I1 ~ I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Alaska Off & G~is (., ..... DATE: A~cho~','~' Culm~Us,s~t,, GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I-I'N: Sherrie NO. Company: 9725 9/1 5/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 13-34 '[~~C~ LEAK DETECTION LOG 950829 I 1 D.S. 14-3 '-~,~'" ~ ~'"'Z-- CHEMICALCU'I-FERRECORD 950831 I 1 D.S. 16-31~"~- (~'7 ~ STATIC PRESSURE SURVEY 950827 I 1 D.S. 2-3 ~ (,~ (~ ~ \ PERF RECORD 95 0 8 2 7 I 1 D.S. 5-28 ~ \ ~ \ t.~. PRODUCTION PROFILE 950830 I 1 D.S. 12-21 ~- c~ ~H ~ CNTG 950828 I I Please si copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: 8EP 151995 Alaska Oil & Gas Cons. Commission Anchorage GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I-I'N: Sherrie NO. 9683 Company: 8/31/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 1-10 -~'~- /'~:~ CNTG 950818 1 1 D.S. 01-33 _~~~_ /~~.~ LEAK DETECTION 950808 I 1 D.S. 4-19 TEMPERATURE/pRESSURE & 950811 I 1 9.S. 6-8 BAKER INFLATABLE BRIDGE PLUG 950 S 12 I 1 9.S. 6-17 <~-- ~.7~ LEAK DETECTION LOG 950807 I 1 9.S. 6-24~'"~ )~_'~ PRODUCTION PROFILE 950802 I 1 D.S. 9-4A 7d~Z~ CNTG . 950819 I 1 D.S. 9-41 C)~0~- "70'lL PRODUCTION PROFILE 950810 I 1 D.S. 11-25~'~l t.~ CNTD 950811 I 1 D.S. 13-34 ~'~-- ~ .~) ~ PRODUCTION PROFILE 950801 I 1 D.S. 14-18~/ ~,O~_ STATIC BHp SURVEY 950812 I 1 D.S. 15-12 ~ / I~-~ ~ BRIDGE PLUG SET RECORD 950805 I 1 , ( Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. · . SEP 0 1 1995 DATE: Alaska 0ii & ~85 C0;~s. commission Anchora.qe STATE OF ALASKA ~--~. ALASKA" _ AND GAS CONSERVATION CC /IlSSION REPORT UF SUNDRY WELL OPERATJO.N ,. 1. Operations performed: Operation shutdown Stimulate ~ Plugging ..~, Perforate ~ It 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 Stradgraphic 6. Datum of elevation(DF or KB) 87 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-34 9. Permit number/approval number 82-136/9-1036 10. APl number 50 - 029-20811 4. Location of well at surface 2225' FSL, 1560' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 2196' FNL, 77' FEL, Sec. 14, T10N, R14E, UM At effective depth 2188' FNL, 28' FEL, Sec. 14, T10N, R14E, UM At total depth 2187' FNL, 24' FEL, Sec. 14, T10N, R14E, UM 9525' feet Plugs(measured) 9275' feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 9480' feet true vertical 9230' feet Junk(measured) 11. Field/Pool Prudhoe Bay Oil Pool Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 300 sx PFC 79' 79' Surface 2546' 13-3/8" 2200 sx Fondu & 400 sx PFC 2585' 2584' Production 8955' 9-5/8" 500 sx Class G & 300 sx PFC 8992' 8746' Liner 813' 7" 285 sx Class G 8710-9523' 8467'-9273' Tieback Liner 3237' 7" 570 sx Class G 5473'-8710' 5355'-8467' Perforation depth: measured 9031-9035'; 9102-9116'; 9116-9126'; 9126-9142'; 9156-9166'; 9166-9216' true vertical 8785-8789'; 8855-8869'; 8869-8879'; 8879-8895'; 8909-8919'; 8919-8968' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 5338' MD; 3-1/2", 9.3#, L-80, PCT @ 8894' MD Packers and SSSV (type and measured depth) 7" Baker FB-1 pkr @ 8800' MD; 5-1/2" Cai~i.B, aJ-~.§,~S~V~180' MD I~' ~ / I-/%/I- I i 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation N 0V 2 § 199 Alaska 0il & (~as Cons, Commission Anr. hnr~n~ Reoresentative Daily Averacm Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 2239 3525 1772 Tubing Pressure 263 482 14. 4191 6236 2229 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 v Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE DS 13-34 DESCRIPTION OF WORK COMPLETED PERFORATING & FRACTURE TREATMENT OF SAG & Z4 8/29/91: Added perforations: 9031 - 9035' MD (Sag) Reperforated: 9116 - 9126' MD (Z4) 9156 - 9166' MD (Z4) Ref. Log: BHC$ 9/8/82. Ref. Log: BHC$ 9/8/82. 9/29/91: MIRU & PT equipment to 8500 psi. Pumped a Hydraulic Fracture Treatment, using 12/18 mesh carbolite & resin coated proppants, through the perforations at: 9031 - 9035' MD (Sag) 9102 - 9116' MD (Z4) 9116- 9126' MD (Z4) 9126 - 9142' MD (Z4) 9156 - 9166' MD (Z4) 9166 - 9216' MD (Z4) Ref. Log: BHC$ 9/8/82. Pumped: a) 275 bbls 20# Gelled Pre Pad, @ 40 bpm, followed by b) Shutdown. ISIP @ 1850. Resumed pumping: c) 280 bbls Gelled Crosslinked Pad w/5% Diesel, @ 40 bpm, followed by d) 225 bbls Sand Slurry in 1-10 ppg stages, followed by e) 95 bbls Flush, followed by f) Shutdown. Placed a total of 28,000 lbs of proppant into the formation. Rigged down. 8/30/91: Performed a proppant fill cleanout to 9133' MD. Returned well to production & obtained a valid welltest. RECEIVED NOV 2 5 1991 ^lash.Oil & 6as Cons. Commission Anchoraqe 995 i ,::) D*'~TE · t O-25-9~ F-.' i: F E i;.: F-',Z N C E ' ARCO CA£ED HOLF FiNA[_':j INJ F'ROF:I LE PROD F'ROFiLE ~ -'"' INJ PRFiF/GR/:'EM,''~;¢~ d-' INJ F'ROFILE ~ co INJ PROFILE ~ PROD ~"'-'"'F':r ~--r.,U LE k_.,) ~ LEAK i;,E ]"~G_T-- -._L ~ .... ~ LEAK DETECT ~' F'ROD PROFILE: PROD PROFILE L. E A 1'-':.' D F: T F: C T PROD PROFILE 6R/CC.L - GAit LEAK DETECT L ": A i'-:: ¥':,....':: T F-f".' T .,' ................ RUN RUN RUN RUN F;..' U N R d N RUN RUN F;: U N RUN ,¢.....: U i"-i RUN RUN RUN F: U N i, i, i, i, i, i, i, i, i, i, t, i i ~" C A r'i L; ....-' ~' · C A M (J' 5" C A f'i C [) ~:_," CAMC ,_. n 5" C A H C ~'-J ~" CAMCO s. CAHL;U S" CAdCO ~" C~MCO i" CAMCO 4 ~ '-' ~ + ~' ~"" '~ ""'' - , ~ ~ ~:4 .... ~..¢ l:"l ['] L.~ ~_.5 F'L_EA,<-..~E ,'",':iGN AND RETURN THE A'i-TACHED COPT' A,? RECE:LF',: UF' DA'iA .~, ,:.- ,-- r.:- ]: V E: D EIY HAVE A N!-'f :::F.)N YA WALL. ACE D!$TRiBIJi'ION ARCO ALASKA, INC. F'.O. BOX ANCHORAGE, ALASKA 995t0 DATE' 9-t3-9t REFERENCE' ARCO CASED HOLE FINALS 3-4'" 8-25-9t TUBING CUTTER RUN t, 3-3t" 9-t-9t PERF RECORD RUN t, 4-t 5" 8-28-9t COLLAR RUN I , £4-38~ 9-4-9t CBT RUN ~ , 9-4-9i COMPLETION RUN 7-6~- 7-27-9t PROD PROFILE RUN t5-4- 7-25-9t PROD PROFILE RUN t3-34'- 8-29-9t COLLAR-PERF RUN t , i4-6-- 7-27-9t GAS LIFT RUN t 4-7" 9-2-9t PERF RECORD RUN t 4-~ 8t 8-$i -9t COLLAR-PERF RUN t4-29' 8-29-9t PERF RECORD RUN t8-t6~ 8-3t -9t -F'ERF RECORD RUN ! 5' 5' 5' 5' 5' 5' 5' 5' 2'&5" 5' 5' PLEASE SIGN AND RETURN THE ATTACHED COPY AZ RECEIPT OF DATA. RECEIVED BY ~_._~ HAVE A NICE DAY! _$ONYA WALLACE AT0-t529- APPROVED TRAN$"~ 9t~76' ATLAS SCH ATLAS $CH $CH $CH CAMCO CAMCO ATLAZ CAMCO SCH ATLAS $CH ZCH DISTRIBUTION CENTRAL FILES CHEVRON D & ~ EXTENSION EXPLORATION EXXON MARATHON ' OBZ-b' ._ .. __ F'HILLIF'$ PB WELL FILES R & D BPX STATE OF ALASKA TEXACO 1~. Type of Request: 2. Name of Operator ARCO Alaska, Inc. STATE OF ALASKA ~ ~j~.~ ALASKA''~---''.AND GAS CONSERVATION C( "AISSION 0 ~ I ~ [ APPLICA, iON FOR SUNDRY APHROVALS 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 Operation shutdown Plugging Pull tubing Vadance 5. Type of Well Development X Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate Perforate X Other , 6. Datum of elevation(DF or KB) RKB 87' feet 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 2225' FSL, 1560' FEL, Sec 14, T10N, R14E, UM At top of productive interval 2196' FNL, 77' FEL, Sec. 14, T10N, R14E, UM At effective depth 2188' FNL, 28' FEL, Sec. 14, T10N, R14E, UM At total depth 2187' FNL, 24' FEL, Sec. 14, T10N, R14E, UM 8. Well number 13-34 9. Permit number 82-136 10. APl number 50 - 029-20811 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 9480' feet true vertical 9230' feet Junk(measured) None Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 300 Sx PFC 79' 79' Sudace 2546' 13-3/8" 2200 Sx Fondu & 400 Sx PFC 2585' 2584' Production 8955' 9-5/8" 500 Sx Class G & 300 Sx PFC 8992' 8746' Liner 813' 7" 285 Sx Class G 8710'-9523' 8467'-9273' Tieback Liner 3237' 7" 570 Sx Class G 5473'-8710' 5355'-8467' 9525' feet 9275' feet Plugs(measured) None Perforation depth: measured 9102'-9142'; 9156'-9216' true vertical 8856'- 8896'; 8909 -8968' Tubing (size, grade, and measured depth) 5-1/2" & 3-1/2", L-80 tbg w/tail @ 8894' Packers and SSSV (type and measured depth) FB-1 pkr @ 8800' & BaI-O SSSV @ 2180' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation DECEMBER, 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 '~'~'~'7"F*- ~ .~',~..J'~,,~ Title 15. Status of well classification as: Gas Suspended. Operations Engineering Manager Date 2 ~','~,/~ ~ ~ FOR COMMISSION U~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Mechanical Integrity Test Approved by order of the Commissioner Form 10-403 Rev 06/15/88 [ Approval No¢_//~ Location clearance Subsequent form required 10---~'~~' ~pproVOd I. ONNIE C. SMITH Co~ner Date /J'""'~-" SUBMIT IN TRIPLICATE Abandon . Suspend Alter casing Repair well Change approved program WELL 13-34 SAG RIVER PERFORATING PROCEDURE 1. MIRU ELU and test lubricator. 2. Flow well on artificial lift to achieve drawdown. . Perforate the Sag River interval 9020' 9045' MD (Ref. B HCS 9/8/82) at 4 SPF. 5. Test well. 2 4. SO00 PSI 4 1/r itl. OW Ti, III PACK-Of'IL' o STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL J~[J GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-136 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50-- 029-20~11 4. Location of well at surface 9. Unit or Lease Name 2225' FSL, 1560' FEL, Sec.14, T10N, R14E, UM Prudhoe Bay Unil; At Top Producing Interval 10. Well Number 2196' FNL, 77' FEL, Sec.14, T10N, R14E, UM 13-2,4 At Total Depth 11. Field and Pool 2187' FNL, 24' FEL~ Sec.14~ T10N, R14E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 87'I ADL 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 08/28/82 09/08/82 09/16/82'J N/A feet MSLJ 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9525'MD/9275'TVD 9480'MD/9230'TVD YES ~ NO []J 2180 feet MD 1750' (Appro×~ 22. Type Electric or Other Logs Run D I L/BHCS/GR/SP, FDC/CNL/GR/Cal, CBL; Gyro. CBL/CET/£CI_ 23. CASING, LINER AND CEMENTING RECORD , , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 79' 30" 300 sx PFC 13-$/8" 72.0# I-gO S,,rf 2585' !7-!/2" 2200 sx Fend,- & a. 00 sx FF C 9-5/8"- 47.0# L-RO/~O0-95: S,,rf Rgc~?, 17-!/4" 500 sx C~.~_~_s C & 300 s: PFC 7" tieback 29.0# L-80 547.3' R710' R-l/?" 7" 29.0# L-80 8710' 9r~?~' R-l/?" ?Rr~ Kw ~'l. esS C_. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) Perforated w/4 spf SIZE DEPTH SET (MD) PACKER SET (MD) 5~2"/3 ~2" 8894 ' 8800 ' 9102 ' -9216 ' MD/8854 ' -8968 ' TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) F1 owing Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO 4/15/83 12.2 TEST PERIOD J~ 2144 965 80 41 588 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press.82,0 N/A 24-HOUR RATE j~ 2,761 2212, 156 27° APl 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None * NOTE: Drilled RR 9/11/82. Gyro ran 9/16/82. Perforated well 2/1.3/8.3 ' " & 2/22/86. Workover performed 6/10/88. (Dani ) WC5/024 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE L~ 29. GEOLOGIC MARKERS NAME Top Sadlerochit OWC Base Sadlerochit MEAS. DEPTH 9096' 9368' Not Reached TRUE VERT. DEPTH 8849' 9119' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 6/15/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~f~]'~ ~ Title Associate Enqineer' 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 for 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 10-407 ADDENDUM WELL: 5112188 6/11/88 13-34 RU S/L, tst lubr to 3000 psi. RIH, pull equalizing prong in PXN plug @ 8710'. RIH, pull PXN plug. RIH, set alum plug on 4½" X lock in XN nipple @ 8749'. RIH, set equalizing prong in plug. Tst to 1000 psi; OK. RIH, pull circ vlv @ 8492' in 3 att's. RD. Secure well. (NOTE: Pump out plug set to shear @ 1500 psi.) RU WL, RIH, pull dummy f/Bal-O SSSV @ 2180', POH. RIH, pull GLM dummy f/GLM @ 3183', RD Camco. RU Dowell, displ well w/240 bbls diesel. SI well, RD Dowell. Suspend operations. ~ Dril~'~g Supe~-v~isor STATE OF' ALASKA ALASKA OIL AND GAS CONSERVATION COMM,oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging ~ Perforate ~ Pull tubing Alter Casing ~ Other ~ WORKOVER 2. Name of Operator 5. Datum elevation (DF or KB) AEC0 Alaska, Inc. RKB 87' Feet 3. Address 6. Unit or Property name P.0. Box 100360, Anchorage, AK 99510-0360 Prudhoe Bay Unit 7. Well number 13-34 4. Location of well at surface 2225' FSL, 1560' FEL, Sec.14, T10N, R14E, UM At top of productive interval 2196' FNL, 77' FEL, .Sec.14, TION, R14E, UM At effective depth 2188' FNL, 28' FEL, Sec.14, TION, R14E, UM At total depth 2187' FNL, 24' FEL, Sec.14, TION, R14E, UM 8. Approval number 8-295 9. APl number 50-- 029-20811 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length 79' 2546' Casing Conductor Surface 9525'MD 9275'TVD 9480 'MD 9230'TVD Size 20" 13-3/8" Producti on 8955 ' 9-5/8" Liner 813' Ti eback Li ncr 3237 ' Perforation depth: measureo 7'1 7" 9102'-9216' true vertical 8854 ' -8968 ' feet feet feet feet Plugs (measured) None Junk (measured) None Cemented 300 sx PFC 2200 sx'Fondu & 400 sx PFC 500 sx Class G & 300 sx PFC 285 sx Class G 570 sx Class G Measured depth 79 ' MD 2585 ' MD 8992'MD 8710'-9523'MD 5473'-8710'MD True Vertical depth 79'TVD 2584 ' TVD 8746'TVD 8467'-9273'TVD 5355'-8467'TVD Tubing (size, grade and measured depth) 5½"/3½", L-80, tbg w/tail ~ 8894' Packers and SSSV (type and measured depth) FB-1 pkr @ 8800' & Bal-O SSSV ~ 2180' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1,Hi story) Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer Date (Dani) 5W03/008 Submit in Duplicate ADDENDUM 5/12/88 13-34 RU S/L, tst lubr to 3000 psi. RIH, pull equalizing prong in PXN plug @ 8710'. RIH, pull PXN plug. RIH, set alan plug on 4½" X lock in XN nipple @ 8749'. RIH, set equalizing prong in plug. Tst to 1000 psi; (I<. RIH, pull circ vlv @ 8492' in 3 att's. RD. Secure well. (NDrE: Pu~p out plug set to shear @ 1500 psi.) Dri 11 ing Supervi sot ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field ARCO ALASKA INC. ICounty, parish or borough NORTH SLOPE Lease or Unit ADL: 28315 Title WORKOVER PRUDHOE BAY FIELD Auth. or W.O. no. AS2238 IWell no. DS 13-31 API: 50-029-20811 Operator ARCO I Date I Hour HRS ACCEPT 05/24/88 1900 IARCO W.I. 21.0000 Prior status il a W.O. Spudded or W.O. begun Date and depth as of 8:00 a.m, 05/25/88 ( TD: 9525 PB: 9480 SUPV:RWS 05/26/88 ( TD: 9525 PB: 9480 SUPV:RO 05/27/88 ( TD: 9525 PB: 9480 SUPV:RO 05/28/88 ( TD: 9525 PB: 9480 SUPV:RO 05/29/88 TD.-..' ~952 ;5~, ' PB:: 9'480 SU?V: ~0 05/30/88 ( TD: 9525 PB: 9480 SUPV:RO Complete record for each day reported WESTWARD RIG i TEST BOPE 7"@ 9523' MW: SEAWATER MOVE RIG TO DS 13-34. PULL BPV. BLEED PRESS. CIRC WELL W/ SEAWATER. SET BPV. ND TREE. NU BOPE. PULL BPV. TEST BOPE. DAILY:S43,796 CUM:$43,796 ETD:S43,796 EFC:$974,000 RIH W/ OVERSHOT 7"@ 9523' MW: 8.5 SEAWATER TEST BOPE. PULL TEST PLUG. MU LANDING JT. PULL HGR/SHEAR PBR. POOH LD 5-1/2" TBG. RU FLOOR AND LOAD PIPE SHED. MU BHA AND TIH. PU 3-1/2" DP. DAILY:S28,275 CUM:$72,071 ETD:S72,071 EFC:$974,000 MILL PN PKR 7"@ 9523' MW: 8.5 SEAWATER FIN TIH. TAG UP AND LATCH ONTO PBR BARREL. RELEASE SAME. POOH LD PBR BARREL AND BHA. TIH. CDL. TIH. TAG PKR AT 8638'. PRESS UP ON TBG TAIL AND SHEAR OUT PLUG W/ 1800 PSI. MILL ON PKR. DAILY:S28,316 CUM:$100,387 ETD:S100,387 EFC:$974,000 PUMP 20/40 MESH SAND 7"@ 9523' MW: 8.5 SEAWATER POOH W/ FISH. LD FISH AND TRI-STATE TOOLS. RU SOS. RIH. W/ 8.5~IGR/JB TO TOL AT 8710'. MU BAKER K-1 AND RIH. SET AT 8200'. POOH. RU W/CBL/CET/CCL AND LOG F/ 5000' TO 2000' RD SOS. PRESS TEST CSG TO 2500 PSI. NO BLEED OFF IN 30 MIN. TIH W/ 3-1/2" DP TO TOP OF RET AT 8700'. RU DOWELL AND PUMP 20/40 MESH SAND ON TOP OF RET. DAILY:S67,696 CUM:$168,083 ETD:S168,083 EFC:$974,000 CiRC CLEAN DIESEL 7"@ 9523 MW: 8.5 SEAWATER/DIESEL POOH W/ 3-1/2" DP. PU 6-1/2" DC. MAKE UP TRI-STATE MULTI-- STRING CUTTER AND TIH. DISPL SEAWATER W/ DIESEL. CUT CSG AT 1609'. POOH. CHANGE BLADES ON CUTTER. TIH. CUT CSG AT 1609'. DISP ARCTIC PACK W/ DIESEL. POOH W/ CUTTER. PULL WEAR BUSHING. MU 9-5/8" SPEAR AND SPEAR CSG. PULL HGR AND 9-5/8" CSG. LAY DOWN SAME. MU 12-1/4" BIT AND SCRAPER. TIH TO 1906'. DISP W/ CLEAN DIESEL. DAILY:S28,152 CUM:$196,235 ETD:S196,235 EFC:$974,000 RIH W/ 9-5/8" CSG 7"@ 9523' MW: 8.5 SEAWATER CIRC W/ CLEAN D!~EL. TEST 9-5/8" X 13-3/8" ANN TO 2000 PSI. POOH W/ BIT AND SCRAPER BHA. MU TRISTATE BACK OFF TOOL AND BHA. TIH. ATTEMPT TO BACK OFF AT 1974' POOH W/ BACK OFF TOOL, BHA AND LD SAME. MU 9-5/8" SPEAR. TIH. SPEAR INTO CSG AND BACK OUT SAME. CIRC. POOH. LD FISH AND BHA. RU GBR AND RIH W/ 9-5/8" CSG AND EXT PKR. DAILY:S34,267 CUM:$230,502 ETD:S230,502 EFC:$974,000 The above is correct Signature For form prep~'~tion and distribution, see Procedur~'Manual, Section 10, Drilling, Pages 86 and 87. I 7_~~Date -- I Title ASSOCIATE ENQINEER ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or {2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish ARCO ALASKA INC. I NORTH SLOPE I Lease or Unit PRUDHOE BAY FIELD I DS 13-34 Complete record for each day while drilling or workover in progress 05/31/88 ( TD: 9525 PB: 9480 SUPV:RO 06/01/88 ( TD: 9525 PB: 9480 SUPV:RO 06/02/88 ( TD: 9525 PB: 9480 SUPV:RS 06/03/88 ( 1, TD: 9525 PB: 9480 SUPV:RS 06/04/88 ( 1 TD: 9525 PB: 9480 SUPV:RS 06/05/88 ( 1: TD: 9525 PB: 9480 ~UPV: R-~ The above is correct For form prel:~ration and distribution see Procedu~} Manual Section 10, Drilling, Pag~ 86 and 87 State Well no. WESTWARD RIG 1 LOOK FOR LEAK IN CSG MW: 8.5 SEAWATER RUN 44 JTS OF 9-5/8" CSG W/ FS AT 8992' AND FC AT 8905' DISP DIESEL IN HOLE W/ 211BBLS OBM. SCREW INTO 9-5/8" STUB. TEST ANN TO 2000 PSI. PRESS 9-5/8" CSG AND SET PKR. TEST FOR 30 MINS AT 2500 PSI. BLED BACK TO 2100 PSI. RETEST 9-5/8" X 13-3/8" ANN TO 2000 PSI. OK. ND BOPE. SET SLIPS AND HANG 9-5/8" CSG OFF. CUT AND DRESS STUB. INSTALL NEW PACKOFF. NU BOPE. TEST PACKOFF TO 5000 PSI. TEST BOPE TO 5000 PSI. MU RTTS AND RIH. SET RTTS AT 2079'. TEST 9-5/8" TO 2500 PSI. OK. CIRC OUT OBM W/ CLEAN SEAWATER. RIH W/ RTTS TO 5080'. SET SAME AND TEST TO 2500 PSI. OK. RIH W/ RTTS TO 8650'. DAILY:S101,897 CUM:$332,399 ETD:S332,399 EFC:$974,000 DRILL BP @ 8700' MW: 8.5 SEAWATER TEST 9-5/8" CASING TO ISOLATE LEAK. ISOLATED LEAK @ 5842~5847'. SLIP DRILLING LINE. POOH WITH RTTS. LD SAME. MU 8-1/2" BIT AND TIH. TAG SAND @ 8653'. MIX HEC PILL AND PUMP DOWN DRILL PIPE AND SPOT IN ANNULUS. REVERSE CIRC WHILE WASHING SAND OFF BRIDGE PLUG. REVERSE CBU. DRILL BRIDGE PLUG @ 8700' DAILY:S62,181 CUM:$394,580 ETD:S394,580 EFC:$974,000 POOH WITH 6" BIT MW: 8.5 SEAWATER POOH WITH DP. LD 8-1/2" BIT AND BHA. RIH WITH 6" BIT AND BHA. DRILL RETAINER @ 8692'. AND CLEANOUT TO PBTD @ 9460' (WSR RKB). POOH WITH 6" BIT. DAILY:S36,330 CUM:$430,910 ETD:S430,910 EFC:$974,000 PREP TO RUN VERTILOG MW: 8.5 SEAWATER POOH WIH 6" BIT. PU 8-1/2" BIT, SCRAPER AND RIH TO TOL. POOH. PU POLISH MILL. RIH AND POLISH LINER TIEBACK SLEEVE. REVERSE CIRCULATE. POOH. RU WL. RIH WITH 7" RETAINER. MISFIRE. POOH WITH RETAINER AND SET @ 8737' DAILY:S29,219 CUM:$460,129 ETD:S460,129 EFC:$974,000 RIH W/ BIT AND SCRAPER MW: 8.5 SEAWATER FIN POOH W/ WIRELINE RET SETTING TOOL. RIH W/ ATLAS VERTILOG. LOG F/ 8707' TO 2550' WLM. TOOL FAILURE. POOH. RIH VERTILOG RUN # 2. TOOL FAILURE. POOH AND RIG DOWN. MU 7" LINER AND RIH ON 3-1/2" DP. TOL @ 5473'. FS @ 9523'. CEMENTED W/570 SX CLASS G. DAILY:S74,250 C~M:~534,379 ETD:S534,379 EFC:$974,000 DRLG CMT AT 8195' MW: 8.5 SEAWATER RIH W/ 8-1/2" BIT AND CSG SCRAPER TO TOL AT 5457' (WLM). CIRC AND COND. POOH. LD BHA. PU 6" BIT AND RIH W/ 4-3/4" DC. DRLD 9079'. TES~oCSG TO 2500 PSI +~.~le30 ~ ........ ll~,%~"~D S,'iT =/ ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when lilled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. County or Parish NORTH SLOPE ARCO ALASKA INC. Lease or Unit PRUDHOE BAY FIELD DS 13-34 Complete record for each day while drilling or workover in progress WESTWARD RIG 1 06/06/88 ( TD: 9525 PB: 9480 SUPV:RS 06/07/88 ( TD: 9525 PB: 9480 SUPV:RS 06/08/88 ( TD: 9525 PB: 9480 SUPV:RS 06/09/88 ( TD: 9525 PB: 9480 SUPV:RS 06/10/88 ( TD: 9525 PB: 9480 SUPV:RO 3) ¸4) ,5) ,6) ,7) 8078fTO 8195' DAILY:S69,570 IState AK CUM:$603,949 ETD:S603,949 EFC:$974,000 RIH W/ NEW BIT DRLD CMT F/ 8195' TO 8594'. AND CSG SCRAI~ER. 7"@ 9523' MW: 8.5 SEAWATER PUMP HEC SWEEP. TRIP F/ BIT DAILY:S29,935 CUM:$633,884 ETD:S633,884 EFC:$974,000 RIH W/PACKER ON DP 7"@ 9523' MW: 8.5 SEAWATER RIH WITH BIT AND CASING SCRAPER TO 8574'; DRILLED CMT TO RETAINER @ 8724'. TESTED CASING TO 2500 PSI. DRILLED RETAINER AND RIH TO PBTD @ 9455' (WSR RKB). MIXED & PUMPED SWEEP. DISPLACED HOLE WITH INHIBITED SEAWATER. POOH. MAKE UP PACKER & TAILPIPE ASSEMBLY. RIH ON 3-1/2" DP. DAILY:S95,202 CUM:$729,086 ETD:S729,086 EFC:$974,000 RIH W/PACKER SPEAR 7"@ 9523' MW: 8.5 SEAWATER RIH WITH 7" FB-1 PACKER. PACKER SET @ 6908' AND UNABLE TO WORK FREE. DROPPED BALL AND SET PACKER. POOH WITH SETTING TOOL. RIH WITH MILL AND MILLED FROM 6908'-6912' PUSHED PACKER TO 9360' POH WITH MILL. PICKED UP SPEAR & CSG SCRAPERS; RIH. DAILY:S32,754 CUM:$761,840 .ETD:S761,840 EFC:$974,000 SET PB-1 PKR 7"@ 9523' MW: 8.5 SEAWATER FIN TIH W/ SPEAR. TAG PKR AT 9370'. WORK PKR FREE AND POOH W/ FISH. TIH W/ NEW FB-1 & TAIL ASSY. POOH W/FB-1 & TAIL ASSY. RU DRESSER & RUN IN HOLE W/6" GR/JB. TAG UP AT 8585' RIH W/ GR/JB. RD DRESSER. MU FB-1PKR & TAIL ASSY AND RIH. SLIP DRLG LINE. TIH TO 8800'. BREAK CIRC AND DROP BALL TO SET PKR. DAILY:S50,962 CUM:$812,802 ETD:S812,802 EFC:$974,000 RUN TUBING TO 8800' 7"@ 9523' MW: 8.5 SEAWATER SET PACKER @ 8800'. TESTED PACKER TO 2500 PSI. POOH LAYING DOWN DRILLPIPE. RU AND RUN 3-1/2", 9.3#, L-80/5-1/2",17#,L-80 BTC TUBING. (TAIL @ 8894',BAL-O SSSV @ 2180',FB-1PKR @ 8800') DAILY:S46,900 CUM:$859,702 ETD:S859,!702 EFC:$974;000 . IWell no. The above is correct Signature For form prep,~ation and distribulion see Procedur.~,,4 Manual Section 10, Drilling, Pag~ 86 and 87 IDate ITitle ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Reporl" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative tesl data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District IC°unty or P. arish ARCO ALASKA INC. Ii NORTH SLOPE Field Lease or Unit PRUDHOE BAY FIELD ADL: 28315 Auth. or W.O. no. ITitle AS 2238 J . WORKOVER IAccounting cost center code Stat~ I Well no. DS 13-3~ Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. API: 50-029-20811 ]A.R.Co. W.I. rrotal number of wells (active or inactive) on thisI Icost center prior to plugging and 21. 0000 labandonment of this well 05/24/80 / 1900 HRS Complete record for each day reported WESTWARD RIG i 06/11/88 ( 1 TD: 9525 PB: 9480 SUPV:RO Old TD New TO Released rig Date RELEASED RIG 7"@ 9523' MW: 8.5 SEAWATER TAGGED PACKER @ 8800'. STING INTO PACKER. TEST TO 2500 PSI. SHEARED OUT SOS & SPACED OUT WITH PUPS. MU GRAY GEN III TUBING HANGER. LANDED TUBING. TEST BACKSIDE TO 500 PSI. INSTALLED BPV. ND BOPE. NU TREE & TESTED TO 5000 PSI. ATTEMPTED TO PULL BPV. WELL HAD PRESSURE BELOW BPV. SECURED WELL AND RELEASE RIG @ 1530 HRS, 6/10/88. DAILY:S180,783 CUM:$1,040,485 ETD:S1,040,485 EFC:$974,000 Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) I Producing method I Official reservoir name(s) I Potential test data PB Depth JKind of r g Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form prepa,~on and distribution, see Procedures~lanual, Section 10, Drilling, Pages 86 and 87. ASSOCIATE ENGINEER OATF' A-6-RR !::'l.~..~'."a;~U- .5;Ti].;N ,:~hJB I;;I:-"TIIF,:N TH~,",""¥At"'.H,i"'~, ?:I''':'v ~.'.~;'--.; :;::""'7:,':",'"" ........... T'A., l.-lchVl:-- & ?,J T Alaska Oil & Gas Cons. Commission r:' !:--_ C.., f..', Y ~:t:.-. i',! H g T T Anchorage ~,'¥cl-'i ~.-.--..,o.,.. , .~ ..'7: M ?. I'] 1.4 5:: c': I-4 .? f'.-l.q .":,' ,"".' !--I .? F: 1-4 :~ CENTRAl.. F'[!...F..:...' ~ RHEVD:nN -"- ~'XTFN:'--.' T fIN FyF-'! f"iR'AT T ?4 [] B T !. MEMO-RANDdM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Smith ~ DATE: May 26, 1988 Commi s s loner F~LENO: D.ADA. 111 THRU: Michael T Minder Sr Petroleum Engineer TELEPHONE NO: SUBJECT: BOP Test AAI PBU DS 13-34 Permit No. 82-136 'Prudhoe Oil Pool FROM: Doug Amos Petroleum Inspector Wednesday, May ~5, 1988: I traveled this date from AAI PBOC to AAI PBU DS '13-34 well tO witness the BOP test at Westward Rig No. 1. The test commenced at 4:00 a.m. and was concluded at 8:00 a.m. The upper kelly cock failed this test, but was replaced and retested this date. I filled out an AOGCC BOP inspection report which is attached. in summary, I witnessed the BOP test at AAI PBU DS 13-34 well on Westward Rig. No. 1. ! Attachments STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report ~ Location: Sec_ I'.~ Drilling Contractor ~<iT~~ Ri LOcation, General w'/Well Si General Housekeeping Reserve Pit Hud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors Test Pressure !1 BOPE Stack Annular Preventer Pipe Rams ~ Blind Rams w~' Choke Line Valves~ H.C.R. Valve ~ Kill Line Valves ~/~ Check Valve Test Results: Failures .... i ~resentative ~, ~wrz. r-z~ ACCUMULATOR SYSTEM '~ "' ~: ~''' '''~ Full Charge Pressure ~000 Pressure After Closure. Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master ~" Remote psig .psig ,/ rain ~ sec. min Z ~ sec. /Blinds switch cover~ Kelly'and Floor Safety Valves..- Upper Kellx~Lv, Test Pressure , Lower Kell~w'I Ball Type u- I Inside BOP .w,' l Choke Manifold No. Valves Test Pressure , , Test Pressure Test Pressure { ~Test Pressure No. flanges Adjustable Chokes Hvdrauic.all7 operated choke Test Time . _.5~_ hrs. · Repair or Replacement of failed, equipment to be made within Commission office notified. Remarks: ~~/ Ill · I I ' ' Distribution orig. - AO&GCC ce - Operator - Supervisor Inspector / days and Inspector/ STATE OF ALASKA ~-"- ALAS,._. OIL AND GAS CONSERVATION COMN. ~,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ..~ Operation Shutdown [] Re-enter suspended well ~ Alter casing Time extension [] Change approved program [] Plugging FI, Stimulate [] Pull tubing ,~-' Amend order rF Perforate r~ Other/~ 2. Name of Operator 5. ARCO Alaska~ Inc. R 3. Address 6. P. O. Box 100360, Anchorage, AK 9951 0-0:360 p 4. Location of well at surface 7. 2225' FSL, 1560' FEL, Sec.14, T10N, R14E, UM 1 At top of productive interval 2196' FNL, 77' FEL, Sec.14, TION, R14E, UM At effective depth 2188' FNL, 28' FEL, Sec.14, TION, R14E, UM At total depth 2187' FNL, 24' FEL, Sec.14, T10N~ R14E~ UM 11. Present well condition summary Total depth: Plugs (measured) Datum elevation (DF or KB) KB 87 ' Unit or Property name rudhoe Bay Unit measured 9525 ' MD feet true vertical 9275 ' TVD feet Well number 3-34 8. Permit number 82-1'~R 9. APl number 50-- 029-20811 10. Pool Prudhoe Bay 0il None Pool feet ': Effective depth: measured 9480 ' MD feet true vertical feet 9230'TVD Casing Length Size Conductor 79 ' Surface 2546' Junk (measured) Production 8955' Liner 813' Perforation depth: measured Cemented true vertical 20" 300 sx PF C 13-3/8" 2200 sx Fondu & 400 sx PFC 9-5/8" 500 sx Class G & 300 sx PFC 7" 285 sx Class G 9102'-9216' 8854'-8968' None ~bing(size, grade and measured depth) 5-1/2", 17#, L-80, LTC ~ 8640'MD; 4-1/2" Measured depth Rue Verticaldepth 79'MD 79'TVD 2585'MD 2584'TVD 8992'MD 8746'TVD 871 0 ' -9523 ' MD 8467 ' -9273 ' TV RECEIVED APR 2 0 Alaska 011 & Gas Cons. Comrnis. , 12.6#, N-80 ~ 8640'-8761 'MD Packers and SSSV (type and measured depth) BOT 3-H pkr ¢ 8660'.: Otis ~;-1/?" ~Y SSSV 12.Attachments Description summary of proposal Anchorage BOP sketch 13. Estimated date for commencing operation April 30, 1988 14. If proposal was verbally approved ~'ul~$equent Wor]~ .l~ported on Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~J~ ~ ~~,.~, Title Asso~l;e Engineer ~/ Commission Use Only ( J G ) SA2/69 Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test ,~ Location clearance Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned ~ Commissioner Approval No. C(~ ~&'~-"' ~ ~'/..~_2 by order of the commission Date-~ ~ '~ Form 10-403 Rev 12-1-85 Submit in triplicate APPLICATION FOR SUNDRY APPROVALS PBU DS 13-34 WORKOVER PROCEDURE OBJECTIVE: Retrieve the existing 5-1/2" tubing and Brown 3-H packer and PBR. Set an EZSV cement retainer above the 7" liner top and dump sand on top of retainer. Cut, pull and replace the leaking 9-5/8" BTC casing above ±2000'MD with new 9-5/8" Mod-BTC casing. After successfully testing the new 9-5/8" casing, drilling out the cement retainer and cleaning out the 7" to the PBTD, 5-1/2" Mod IPC tubing with GLMs and a permanent packer will be installed. 1) RU slickline. Replace 3/4" orifice in lowest GLM (8495' SLM) with circulating valve. RD slickline. 2) MIRU workover rig. Circulate seawater through circulating valve in lowest GLM. 3) Set BPV. ND, NU, test, retrieve BPV. 4) PU on 5-1/2" tubing to release PBR seal assembly. POOH, LD 5-1/2" tubing, PBR seal assembly. 5) Retrieve PBR and anchor. Mill and recover BOT 3-H packer. 6) RIH w/EZSV cement retainer. Set retainer at ±8700' in 9-5/8" casing. Pressure test 9-5/8" casing to 2500 psi. Record bleed off. 7) RU electric line. Run CBL/CET/CCL from 3000'-iO00'MD (or TOC behind 9-5/8", whichever is shallower). 8) Circulate 2200' diesel cap. POOH. 9) RIH, mechanically cut 9-5/8" casing at ±2000'MD. 10) Pull 9-5/8" casing. 11) Roundtrip 13-3/8" scraper and 12-1/4" bit to top of cut. 12) Test Arctic pack to 2000 psi. 13) RIH, back off 9-5/8" casing at 2060'. POOH. RECEIVED APR 2 o Alaska Oil & Gas Cons. Comrnissior~ Anchorage 14) RIH, recover 9-5/8" casing stub. POOH. 15) Run new 9-5/8" Mod-BTC casing with external casing packer. 16) Circulate oil base fluid into 9-5/8" x 13-3/8" annulus. 17) Screw into 9-5/8" BTC casing with new Mod-BTC. -2- 18) Test 13-3/8" x 9-5/8" annulus to 2000 psi. 19) Set 9-5/8" external casing packer. 20) ND BOPs, install slips, cut casing, install packoff, NU and test BOPs. 21) Test casing to 2500 psi. 22) RIH w/bit. Drill cement retainer and clean out to PBTD at 9480'. 23) RIH with 9-5/8" packer and tailpipe on DP, set, POOH and LDDP. 24) Test 9-5/8" casing and packer to 2500 psi. 25) RIH with 5-1/2" IPC tubing and GLMs. 26) Freeze protect well, ND, NU tree, test, release rig. Anticipated bottomhole pressure: 3750 psi (8.21 ppg EMW) Workover fluid: 8.5 ppg seawater DCS/19a 4/6/88 ANNULAR PREVENTER I I I I PIPE RAMS 5 BLIND RAMS 4 TUBING HEAD 1. 13-3/8" CASING HEAD 2. 9-5/8" CASING HEAD 3. 5000 PSi TUBING HEAD 4: !5-5/8" - 5000 PSI BLIND RAMS 5. !3-5/8" - 5000 PSi PIPE PAM_q 6. 13-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST I . 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 SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FiLL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL, 2, CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT iN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5, INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. ,N~REA~E.,.~.~.~ TO 5000 PS~, AND HOLD FOR I0 MINUTES, CLOSE VALVES DIRECTLY UPSTREAM OFCHOKES. DLEED DOWNSTREAi PRES~URE TO ZERO PSi TO TEST VALVES. TEST~EMAINING UNTESTED MANIFOLD VALVES, iF ANY. WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TOZEROPSI. 9. OPEN PiPE RAMS. BACk, OFF g~iJNNiHGJTAND PULL OUTOF HOLE. P, nc~ BLIND ~' "~"': TEST r.~ ,~ AHD 50(:'0 PSI FOR !r, '""'NLITES. BLEED ~.~ ,J~ , · ,.~ TO ZERO PSi. !O. OPEN BLiHDRAMS ANDRECOVEP TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 1 ~z. ~,E~,~ KELLY COCKS AND INSIDE BOP TO 5000 PSi WITH KOOMEY PIJMP. !3 RECORD ~'; . _. . , ~T ~NFOPP1AT!ON nN ~LO~OUT PREVENTER TEST FORM. '~!GN AND SEND TO DRiLLiNG SUPERVISOR. 14. PERFORM COMPLETE DOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BORE DAILY. JG NOVEMBER 21 , 1986 ARCO AIm~km, Inc, F'.O· Bo)< t00368 Anchor'mge, A la.skin DAI'E: 9-30-8'? REFERENCIE: ARCO Cased [tole F'inaL ~--~_~3-7 9-20-8? BoTTom Hole ,~ZTatic Pressure Run 2, 3-..~3 9-2~-87 Bo~¢om Hotm ~'¢a}ic f:'re~ure Run 2, 8-t t 9-2t-87 CET Run 8-tt 9-2t -87 CBI' Run 1, 5' t3-~4 9-i9-87 Noise/Temperatur~ ko~ ~un 1, ,~ ~:: h S'ch ,.~' ~': h S'ch · .~?,: h [:'tease $igl'l and ret~l-~~ c£alS~y a).~ I-eceip~: of data. Received By .... HA V E A N I C E D A ~ Alaska O~l & (]as Cons. C0mrnjssJ0r~ A~ch0rage Record.s F'rocm~$or ATO-t 529 TRAN£ ~87F85 Approved Central Fi Les ,~ Phi L t ip.~ Chevron F'B WeLt Fi le.$ D & M R & I) Exten.sion Exploration ~ $6~] ~ S~ate of ALaska Exxon ~ MaraShon ~' Texaco Mob i t ARCO Alaska, Inc. Prudhoe Bay ~..gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 14, 1986 Mr. C. V. "Chat" Chatterton State of A1 aska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Me- DS 13-34 Permit No. 82-136 Enclosed is the Comp'letion Report for work done on the above-mentioned well. Very truly yours, D. F. Scheve DFS/SKAD/jj Enclosure cc' SOHIO Alaska Petroleum Co. File PI(DS 13-34)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .... ,/~' STATE OF ALASKA ' ALASKA _ ~L AND GAS CONSERVATION C~ tMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILX[] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-136 3. Address 8. APl Number Post Office Box 100360~ Anchorage~ AK 99510 50- 029-20811 4. Location of well at surface 9. Unit or Lease Name 2225' FSL, 1560' FEL, Sec. 14, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2196' FNL, 77' FEL, Sec. 14, T10N, R14E, UM At Total Depth 11. Field and Pool 2187' FNL, 24' FEL, Sec. 14_, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 87' RKB ADL 28315 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116' No' of Completions 08/28/82 09/08/82 09/16/82] N/A feet MSL1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9525'MD~9275'TVD 9480'MD,9230'TVD YES ~ NO []I n(pplp (a??D5 feet MD 17q~, (=pprox.) 22. Type Electric or Other Logs Run DIL/BHCS/OR/SP, FDC/CNL/GR/Cal, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 79' 30" 300 sx Permafrost C 13-3/8" 72.0# L-80 Surf 2585' 17%" Z200 sx Fondu & 400 sx Permafrost C 9-5/8" 47.0~ L-80& Surf 8992' 12~4" 500 sx Class G & 300 Permafrost C S00-95 7" 29.0# L-80 8710' 9523' 8%" 285 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5~" 8761' 8660' 9102- 9142'MD 4 spf 9156-9216 'MD 8856_8968,~D 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED i ' Ref: BHCS 09/08/82 N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 03/31/83 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 03/04/86 6.O TEST PERIOD I~ 922 665 264 44 721 Press.Fl°~2-~ubing Ca[~Pressure CALCULATED24-HOUR RATEI~.~ Gl L,j~ GASJ~ WATER-BB L1056 OIL GRAVITY-APl27.0 (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ;V-"" ', . ,i:~slon AIask,l .Oil L Form 10-407 Rev. 7-1-80 ,/~, //// CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. · : . GEOLOGIC MARKERS FORMATION TESTS NAME I Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9096' 8849' N/A O/W Contact 9368' 9119' Base Sadlerochit Not Reached 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the' details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 14, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-34 Permit No. 82-136 Enclosed is the "Subsequent" Sundry Notice detailing work completed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/SKAD/jj Enclosure cc: SOHIO Alaska Petroleum Co. rile PI(DS 13-34)W1-3 .'.:, 'i '0 ];'~?:q ^lasl<a 0:,i & Gas Cons. Goinmia:~io.n /*,nchorarja ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~X OTHER [] 2. Nameof Operator 7. Permit No. ARCO Alaska, Inc. 82-136 3. Address 8. APl Number P,0. Box 100360, Anchorage, Alaska 99510 50- 029-20811 4. Location of Well 2225' FSL, 1560' FEL, Sec. 14, T!ON, R14E, UM (Surf) 2196' FNL, 77' FEL, Sec. 14, TION, R14E, UM (Top Prod) 2187' FNL, 24' FEL, Sec. 14, TION, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 87' RKB 6. Lease Designation and Serial No. ADL 28315 9. Unit or Lease Name Prudh0e Bay Unit 10. Well Number DS 13-34 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] 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 10407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: 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). Began perforating operation on 02/22/86. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 9122-9142'MD (4 spf) flowed well to cleanup. Shut-in well, POOH, all shots fired. RIH w/gun #2, shot interval 9102-9122'MD (4 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. Ran SSSV, secured well. R.D. Ref: BHCS 09/08/82 14. I hereby cer,t-iify that the foregoing is true and correct to the best of my knowledge. Signed///~_~~~~ Title Operations Fngine~ring Mgr_ The space below for Commission use Conditions of APproval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10403 Rev. 7-l-80_ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~-- Prudhoe Bay L .neering 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 13-1 DS 13-2A DS 13-3 DS 13-4 DS 13-5 DS 13-8 DS 13-12 DS 13-13 DS 13-14 DS 13-26 DS 13-29 DS 13-30 DS 13-33 ~DS 13-34 Permit No. 78-60 Permit No. 83-21 Permit No. 78-62 Permit No. 78-63 Permit No. 81-103 Permit NO. 81-148 Permit No. 80-142 Permit No. 82-178 Permit No. 82-171 Permit No. 82-74 Permit No. 83-43 Permit No. 82-101 Permit No. 82-106 Permit No. 82-136 Enclosed are the "Intention" Sundry Notices detailing work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS:BSM:vh Enclosure RECEIVED JAN 1 1986 Alaska 011 & cc: SOHIO Alaska Petroleum Co. File PI(DS 13-1)W1-3 P1 (DS 13-2A)W1-3 Pi(DS 13-3)W1-3 Pi(DS 13-4)W1-3 Pi(DS 13-5)W1-3 P1 (DS 13-8)W1-3 Pi(DS 13-12)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany Pi(DS 13-13)W1-3 Pi(DS 13-14)W1-3 PI(DS 13-26)W1-3 Pi(DS 13-29)Wl-3 Pi(DS 13-30)Wl-3 PI(DS 13-33)Wl-3 Pi(DS 13-34)W1-3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~:X OTHER [] 2. NamR nf Ooerator 7LRCO AIaska, Inc. 3. Addr~s.o. BOX 100360, Anchorage, Alaska 99510 Surface :- At Top Producing Interval: 2196'FNL & 77'FEL, Sec.14, T10N, R14E, UM At Total Depth: 2187'FNL & 24'FEL, Sec. 14, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 87' RKB I ADL 28315 12. 7. Permit No. 82-136 8. APl Number 50- 029-20811 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-34 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) Perforate j~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.) (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 13-34 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 cleanup operation. Proposed Perforation Intervals: 13-34: 9102-9142' MD 9226-9252' MD 9258-9278' MD 9284-9294' MD Ref: BHCS 9-8-82 RECEIVED JAN 1 ) 1986 14. I hereby cer,,tify that the foreg~ng is true and correct to the best of my knowledge. Signed .... _ Title Operations Engineering Mgr. The space below for Commission use Date Conditions of Approval, if any: Approved by BY LONI~IE C. $1111TJ~ :7 Approved Copy Returned _ By Order of COMMISSIONER the Commission Form 10-403 RRv_ 7-1-RO Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~%_, Post Office B I00360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: August 1, 19 85 Reference: ARCO CH Finals ~2-13~Epilog 3-6 Temp Log 3-6/ spinner · 3-7 / Temp 3-10~ Spinner 4-12~' Epilog 6-10 ~ Epilog *'13-3 ~' TDT 15-9 ~ CET 5-12-85 Run 1 5" DA 7-13/14-85 1 5" Camco 7-17-85 7-13-85 7-17-85 5-13-85. 5-10-85 11-23-84 1 5" Camco 1 5" Camco ' 1 5" Camco 1 5" DA 1 5" DA 3 5" Sch ***This log has the wrong date on it. 11-23-84 is the correct date, not 11-23-85.?,~*********** 11-24-84 2 5" Sch 5-11-85 1 5" DA 7-15-85 1 5" Camco 11-8-84 1 5" Sch Trans 249 Chevron' D&M Sxpl. SerVices- Ext. Exploration Exxon Marathon Mobil Phillips. PB Well Files R&D Sohio State of Alaska Tmxa co ARCO Alaska. Inc, Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: Apr il 23, 1985 Reference: ARCO Magnetic Tapes -9J ~ CNL 927003 ~_~_~:~.~__ ? CNL #281920 13-98 CH CNL~70273 13-98 CH DILl70272 4-20-85 4-20-85 4-5-85 4-5-85 Please sign as receipt of data. _. :9L-r-?~/~-;r% ' Received by~~" '~' %'~ "-. . ~". ~ ~ Para Lambert A~ask~ 0ii & G3s C~;~. C0mmiss~o~ ATO 1429C ),networks,, Trans 9083 Chevron Mobil E & P D & M Phillips Expl. Services PB Well Files Ext. Exploration R & D Exxon Sohio Marathon --~S~a~e.o~_..A~aska Mobil Texaco ARCO ALa_'.-:k~, Inc~ P,.O~ Box iO(~S60 Ancho)"age, AI.a~ka 99'~' t ('3 H,.':: I. e Fin a I. s' D ~ i .... '7 i i .... ::.::'8-;=' .... ....... ,:.., 4 '.[:' i '1' I- 'f' e m i::, I... o g !) ,. ;.?,i .... '7 ''/' i i .... 28-'--84 C:F'S/;ii:I::, innc-.:,r g~ ,S' , '~ ..... - i i .... 'i ,':', -..- 8 4,, ,.,;'"I-.I f':Ni...... D 5: "z .... i ':~' -~ i 2. ..... i 7- 84 F:' L...9 D., S' ,. 4-i ':ii:' '/ i '2 ..... J 6'"'84 ;}?p i v'~n,:.:.:,r Lo,:'.4 g ::'i: "" '" -/ i 2 .... i q- '::)/' ,. , 7 .... .,.: .... ,.,--,- F:'I....? 'r), ,?., 9-3 /~ ' ' F:' ... -' 'J 2- 'i 3 -84 I.., D.. ,?, (:'., ..... .'), ~ i ,.."-"- i 5:---- :..,° 4 I::' I... ~-i.' "'", ;ii: ? .... i .i --~- ' ' .....~ . '~ 2- '~ 6 .... :.,° ..~.-'"F:' 1._ "'" ,'ii: i 3 .... 2A -/'" 'i 'i -2¥ 84 Co L I. a 'F/Pe'r' f I ,"',q .i,,/ ~, ~ ~ "" . ..... ' '7 .... :n .' : .... ,..:'; -...::) c:.' ' D, ;!'? .~ ~, .....::. '~ '~ ......... ;'.~ j:.', ~ n n e r L,.':.', g · --.:..- .... .-:,, , .... z. .... r.:-- F-- ,... j. j a ~" L ,'"~ q .',".).. ;!¢ ,. '~ ....... 'i '~ :.: 8...:- ,.. ......... ...... }"::-"-:-' -'" ---' ' ':'" 4 H C N I... ; ~ ,"-. 'I ..... :---.-- ] i - 7 .... ~:~ ~"~ .,: ~. ;, D ;".i.' i "; .... i; '" " ., ~'.~- --' i '2 -" 2 "" ii!: "; f": I::' ::? /,S' r..', i 'i'~ n e 'r' .-.:, ,.. · c., ;~.'.~ i -'-"-..'- ..... i 6/ i i-29-'--i.:.'~-.:,'"' "" F= ;:=.,' ,'" ,5.:: p i nn,::.','r'. .L; .: I.... , i> .: 5', i 5: .... 4/` i i .... i ,:.'i:,-:::i~4 r;H C:NL.. ..,!":, :. ;-',': ., i 5:-.--'7 -- ?-,::':,-...8,~. Gq,,.. ;'", ;:.-?i 6-.--3 ~-''' i '2 .... i 2..--84 C:F'E:/;ii:r.:, i 'r', 'n ,:.:.:, 'F ..'..,' a _ f). ,S' i 6 .... ~i'.". '"-"- 'i 2 ..... J 2 -;'" "" v... i f i" '1" e m !::' L o ..::~ ...... (:'";' :--" · .. . ,...v; :. ;!i; ~ i 6----i '~, ~ i 2 .... i .... iii:-,-'" ,_~"': F ii; / ii; p i n 'ne 'r' D,,!'?, i6-.--ii / i2 .... i-8,:'-,'. Di fi: .,feral=, 1} :. ii;.:: 6-.--i 2 ~'~ i ':?. .... 22 .... iii:-'.':; ;.':-:p i ',q'r'~e'r' I...og ~. 6-' 1 ,..~ ~'~' 5 "':" "" ~':' ': ..... ""::' '"" ~' I... o g .-.'.. ...'_ ~.. ~...~ -'v ;~i i::~ i i"~ 13 ~'."? 'i- · 4 .......~ ......... l- h F.. .:'..'i '~' ® ... h :", ~'~ -:':i "-Y 'i- e C E-) i [::: i: ,3 ]': ..'.:i :'..'i 4. ,. -:':'I ... Recel;,,.'ed By_ ....................................................... i'...;, j; !/ I<,:..'..', I. I.y ?ici::'ar Land A 'T 0 ..... i 4 2 9 i::' '~ ~a s'-k,-a T F;.: A N S' :ii: ."':', ,'q ~ " ..... -- ~- D ]: .:7 "i" R I B U T I 0 i'-~. Ch err on ;';.,..-- ,~..: EXp Lora~ion Z,F, rvice:~ Exten~i on Exp Lorat: i on Ex xon Getty Mob i L i"-i,,';I.; i I c- :~ I::' ...... !... :.'-: Phi L L i p.'_~ F"r' ,'..,'.cl h ,::~e I{-:a '::,' We I. !. F;..' & D &'oh i o State of ALaska ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 6, 1984 Reference: ARCO Cased Hole Finals D.S. 1-26-~ 5-17-84 D.a. 2-17// 5-12-84 D.a. 4-1 5-6-84 D.S. 5-8-' 5-5-84 D.S. 6-18~ 5-22-84 D.S. 9-4~/~ 5-7-84 D.a. 9-6/ 5-7-84 D.S. 12-17j'' 5~14-84 D.a. 12-23-~ 5-16-84 D.S. 13-34/ 5-17-84 D.S. 13-98_~5-16-84 D.S. 16-13 5-20 84 · D.S. 17-7~ 5-25-84 D.S. 17-10 5-18-84 D.S. 17-10 ~' 5-18-84 D.S. 18-3-' 5-14-84 Collar/Perf Log Run 1 5" 'GO Collar Log to set Casing Patch Run 1 5" GO CN/MSN/GR CN/MSN/GR CPL/TDT-M w/listing CN/MSN/GR CH CNL CPL/TDT-m w/listing Run 2 5" DA Run 1 5" DA 5" ach Run 1 5" DA Run 1 5" GO 5" ach X-Y Caliper Log w/Borehole Volume Run 1 5" GO CPL/TDT-M w/listing CH DI L Collar/Perf Log Collar/Perf Log CET Log CCL/Perf Record Temperature Log 5" Sch Run 12 5" Sch Run 1 5" GO Run 1 5" GO Run 1 5" Sch Run 1 5" Sch Run 1 5" GO //asesign return copy as receipt and the attached of data. Be PATRIOTIC! - Hang out your flag on the 14th. Kelly McFarland ATO-1429F Trans. %231 DISTRIBUTION Chevron D & M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob Phillips Prudhoe Bay Well 'Files '~, · : ~, ,.:.,/~ :.. , · R & D Carolyn Smith Sohio State of Alaska ARCO Alaska, ~'-'~, Post O1. _ Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 24, 1984 Reference: ARCO Magnetic Tapes >D.S. 4-1~ 5-6-84 CN/MSN #1965 w/listing ~/D.S. 6-8?' 5-18-84 CH/CNS #281781 w/listing ,-D.S. 7-14~ 5-22-84 CH/CNS #281783 w/listing / D.S. 7-13/ 5-22-84 CH/CN.S #281782 w/listing ,-D.S. 15-13~'j 5-23-84 CH/CNS #252598 w/listing /D.S. 7-19-" 5-18-84 CH/CNS #281784 w/listing /D.S. 5-12~'- 5-23-84 CH/CNS #281788 w/liSting /D.S. 9-26'' 4-18-84 OH #1946 w/listing ,-JD.S. 3-27~'~ 5-15-84 OH #69234 w/listing ' D.S. ~'l-3~3'474'--2q--8~---'--An'swe~ #69198 w/listing /D.S 12-21 4-29-84 OH #69188 w/listing -~D.S. 13-34~' 4-21-84 TDT Edit #69197 w/listing /D.S. 12-17~j 4-22-84 TDT Lis #69164 w/listing · -4~.S-~-3~--AT--.u<~---4-22.~.84 ...... AnsweL. #69165 w/listing · /D.S. 7-11~'' 4-26-84 CH CNL #69179 w/listing ~D.S. 12-21~'~4-29-84 RFT #69188 w/listing DA GO GO GO GO GO GO DA Run Sch Run Sch Run Run Run Run Sch Sch 1 Sch 1 Sch 1 Sch 1 Sch Post Office Box 360 Anchorage. Alaska 99510 Reference: Arco Cased Hole Einal~ ~-~ -a-a4 / s',', Sch . J 5-10-84 / CPL~TDT-M y!isting ~ 5 Sch D.S. 1-10'.-~' 5-8-84 / CPL/TDT-M ~/listing \ 5" Sch /D.S. 12-9~' 4-22-84' TDT . ' Run 2 5" Sc ~ 5-9-84 D.S ' 12-16 J'5-11- 84 ~-D.S. 12-17'_~''4-22-84 ,, D.S. 13-5 / 4-21-84 ~; 5-8-84 ~D.S. 13-34J 4-21-84 CPL/TDT-M /listing CPL/TDT-M/~/listing TDT / TDT / CPL/TDT-~ w/listing ign and return the attached copy as receipt of data. 5" Sch 5" Sch Run 1 5" Sch Run 2 5" Sch 5" Sch 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 Getty , :.~Mara'th0'n Mobil M6bil E & P Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc"~' Post Office ..)x 360 Anchoraae. Alaska 99510 August 8, 1983 Reference' Arco Cased Hole Finals D.S. 1-20 ~f 7-17-83 CFS Run 1 5" GO D.S 2- IA"-"/' ' 4-1'5-8 3 CNL/GR/MSN Run 8 5" DA D.S 2-20' 4-9-83 PLS/PBU-Spinner Run 1 5" DA D.S 3-12- 5-8-83 CNL/GR/MSN Run 3 5" DA D S 4-13~/ 4-23-83 CNL/GR/MSN Run 6 5" Da D .S 6-4''' 5-9-83 CNL/GR/MSN Run 2 5" DA D.S 6-20' 7-1-83 CFS Run 1 5" GO D. S 7-7A-. 7-3-83 CF$ Run 1 5" GO D .S 7-11 . 4-16-83 CNL/GR/MSN Run 9 5" DA D. S 7-14 ..... 4-22-83 CNL/GR/MSN Run 9 5" DA D.S 11-2--/ 5-7-83 CNL/GR/MSN Run 2 5" Da .- D.S 13-34/ 6-10-83 CFS Run 1 5" GO D.S. !5'-llt~ 5-6-83 CNL/GR/MSN 'D.S. 18-10''/'~'' 5-20-83 CFS Please sign and return the attached copy as receipt of data. Run 2 5" DA Run 1 5" GO Kelly McFar land ATO-1429F Trans. # 450 DISTRIBUTION Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil North Geoloyy ARco Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 JUly 5, 1983 Re fe~ence: Arco Pressure Data D,$o 13-34 6-10-83 6-10-83 Pressure Build-up Pressure Build-up Survey Report GO sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 414 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA _. .... ~,. ~--, ~ DALLAS .4 -,_ ~i~-'-.~/.~/,,~,...::~,C~,..,,~ CAROLINE S ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 26, 1983 Reference: Arco Cased Hole Finals D.S. 2-lA~' 11-28-82 CN/MSN/GR Run 7 D.S. 4-15/ 4-1-83 CH CNL Run 8 D.S. 5-7,- 4-14-83 CH CNL Run 10 D.S. 6-3 -- 4-13-83 CH CNL Run 7 D.S. 7-3/' 12-3-82 CN/MSN/GR Run 3 D.S.. 7-11'f 12-4-82 CN/MSN/GR Run 8 D.S. 7-14/ 12-5-82 CN/MSN/GR Run 8 D.S. 7-18~ 1-9-83 ACBL/VDL/GR Run 1 D.S. 7-19 1-28-83 ACBL/VDL/GR Run 1 D.S. 12-1~ 12-2-82 CN/MSN/GR Run 3 D.S. 12-18~ 1-11-83 ACBL/VDL/GR Run 1 D.S. 13-18''~ 3-23-83 EPL Run 1 D.S. I3.~34--- 4-2-83 TDT Run 1 D.S. 14-17 ~ 3-27-83 EPL Run 1 D.S. 14-19 J~ 12-9-82 CN/MSN/GR Run 2 D.S. 14-2~ ,3-25-83 EPL Run 1 5" DA 5" Sch 5" Sch 5" Sch 5" DA 5" DA 5" DA 5" DA 5" DA 5" DA 5" DA 5" Sch 5" Sch 5" Sch 5" DA 5" Sch sign and return the attached copy as r'eceipt of data. Kelly McFarland AFA-403 Trans. # 361~ DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D &.M STATE OF ALASKA DALLAS CAROLI~MITH ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 21, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 , Dear Mr. Chatterton: Re: ~DS 13-14 DS 13-34 Permit No. 82~171 Permit No. 82-136 Enclosed are Completion Reports for work done on the above- mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFs/TKKW/lmi Enclosures cc: Sohio Petroleum Co. ,, : STATE OF ALASKA ~, ALASKA 'iL AND GAS CONSERVATION C IMISSION 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. 82-136 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50_029- 20811 4. Location of well at surface 9. Unit or Lease Name 2225' FSL, 1560' FEL, Sec. 14, TiON, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2196' FNL, 77' FEL, Sec. 14, T10N, R14E, UM DS 13-34 At Total Depth 11. Field and Pool 2187' FNL, 24' FEL, Sec. 14, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 87' RKB ADL 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 8/28/82 9/8/82 9/16/82 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9525'MI), 9275'TVD 9480'MD, 9230'TVD YES ~ NO [] nipple @220~eet MDI 1750' (approx) 22. Type Electric or Other Logs Run Z)Z~,/BHCS/6~t/S?, ~)C/Ct~/OR/Cal, CBT~ 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5f~ H-40 Surf. 79' 30" 300 sx Permafrost C 13-3/8" 72.0# L-80 Surf. 2585' 17~" 2200 sx Fondu & 400 sx Permafrost C 9-5/8" 47.0# L-80 Surf. 8992 12~" 500 sx Class G & 300 sj', Permafrost C S00-95 7" 29.0# L-80 8710' 9523 8½" 285 sx Class G 24. Perforations open to ProdUction (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Ref: BHCS 9/8/82 5~" 8761' 8660' 9156-9216, t~ ;~[(,: 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8909-8968' TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First ProductiOn I Method of Operation (Flowing, gas lift, etc.) I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO 4/15/83 TES-F PER]OD I1~ 2144 965 80 41 588 12.2 Flow Tubing Casing PreSsure CALCULATED ..~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 830 N/A 24-HOUR RATEI~ 3761 2213 156 27.0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · : .. ;~/ii4-"¢ 0 '" Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ';: ......S~lsmit in duplicate 29. 30. GEOLOGIC MARK'ERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9096' 8849' N/A O/W Contact 9368' 9119' Base Sadlerochit Not Reache 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S,§.e~ ~~~~~ Tit,e Regional Engineer Dste INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- 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". ARCO Alaska, In¢ Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 21, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission -3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: D.S. 13-14 Permit No. 82-171 D.S. 13-34 Permit No. 82-136 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentiOned wells. Very truly yours, D. F. Scheve DFS/TKKW/lmi Attachments cc: Sohio Petroleum ARCO Alaska, Inc. II a Sublldlery of AtlenllcRIchfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLYE3 OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-136 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20811 4. Location of Well 2225' FSL, 1560' FEL, Sec. 14, T10N, R14E, UM 2196' FNL, 77' FEL, Sec. 14, T10N, R14E, UM 2187' FNL, 24' FEL, Sec. 14, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 87' RKB I ADL 28315 9. Unit or Lease Name Prudhoe Bay Unit 12. 10. Well Number DS 13-34 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 [] 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 operation 2/9/83. RU perforating unit, pressure tested surface equipment. RIH with gun ~1, shot 9196-9216' MD 4 spf (20' ref: CBL 9/11/82), flow to tank for cleanup, monitored rate and took shakeouts. POH - all shots fired. RIH with gun #2, shot 9176-9196' MD 4 spf (20' ref: CBL 9/11/82), flow to tank. POH - all shots fired. RIH with gun #3, shot 9156-9176' MD 4 spf (20' ref: CBL 9/11/82), flow to tank. POH - all shots fired. RD. Ran SSSV. Secured well 2/13/83. Alaska Oil & G~s Cons~ L;ommissiop Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ _ ~ Title R~_gi ~nm The space below for Commission use Conditions of Approval, if any: 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 ARCO Alaska, Inc. Post Office Bo^ ,S60 Anchorage. Alaska 99510 Telephone ~C7 277 5637 April 20, 1983 Reference: Arco Cased Hole Finals D.S. 2-22 4-3-83 'CFS D.S. 13-5 4-12-83~ CPL/TDT-M w/Listing D.S. 13-6 3-16-83 Diff Temp 3-16-83 CFS D.S. 13-34 D.S. 14-11' D.S. 15-6 .. ~.','~ .~- ; .' 4-14-83 -- CPL/TDT-M~w/Listing 2-12-83 X-Y Caliper 3-27-83 CFS Run 1 5" GO 5" Sch Run 1 5" GO Run 1 5" GO 5" Sch Run 1 5" GO Run 1 5" GO ease sign and return the attached copy as receipt of data. Kelly McFarland AFA-4 03 Trnas. # 297 DISTRIBUTION NORTH GEOLOGY- R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D'&M STATE OF ALASKA DALLAS ~.,,,/,,~/~.:.Cf,.,f~,~: , CAROLINE SMITFFL~ '~ "',-:'~ ARCO Alaska, Inc. Post Office B~"~360 Anchorage. A..,Ka 99510 Telephone 907 277 5637 February 23, Reference; 1983 Arco Pressure Data D.S. 1-10~ 1-27-83 J 1-27/28-83 D.S. 7-2~- 12-3-82 ~ ~ 12-2-82 D.S. 13-14 ---2-12-83 D.S. 13-24 ~ 2-10-83 D.S. 13-26f 2-5-83 D.S. 13-30~ 2-5-83 - D.S. 13-34~ _2-10-83 D.S. 15-14/ 11-26-82 ~11-26/27-83 Pressure Build-up Camco Pressure~ Build-up Survey Report Pressure Build-uD Otis -- -Pressure Build-up Survey Report Static Survey Camco Static Survey Camco Static Survey Camco Static Survey Camco Static Survey Camco Pressure Build-uD Camco -- Pressure Build-up Survey Report '/P'lease sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. 9 153 NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION EXXON - _ - F~.. -';~~ ~..., ' ~/J 2 ~'~~ MOBIL Alaska Oil ~ , ~ , GETTY ~ ~'~a~ Cmos. cotnmis,~iort A~chorage D&M STATE OF ALASKA DALLAS CAROLINE SMITH ARCO Alaska, Inc. Prudhoe Bay, ,ineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 18, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine DriVe Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: D.S. 13-14 D.S. 13-33 D.S. 13-34 Permit No. 82-117 Permit No. 82-106 Permit No. 82-136 Attached are "Notice of Intention" Sundry Notices for work proposed'on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TKKW/lmi Attachments cc: Sohio Petroleum JAN2 i Alaska Oil & Gas Cons, Con"un~ssioP, Anchorage ARCO Alalk., Inc. Ime Sub.ldlary of AtlanllcRIchfleldCompany ,,-; STATE OF ALASKA ..-,: ALASKA ,.. _~ AND GAS CONSERVATION C(. .MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLX~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of Well 2225' FSL, 1560' FEL, Sec. 14, T10N, R14E, UM 2196' FNL, 77' FEL, Sec. 14, TION, R14E, UM 2!87' FNL, ?4' FEL, Sec: !4,. TION, R14E: IIM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 87' RKB I ADL 28315 12. 7. Permit No. 82-136 8. APl Number 5o- 029-20811 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-34 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 [~A~]X Alter Casing [] Perforations [] 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). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals' Ref' BHCS 9/8/82 9104-9144' MD* 9156-9216' MD Subsequent Work Repoz'tecl on For~ No./~ Dat~ -~/~~ .JAN 2 i .(98,% Alaska 0il & Gas Cons. Commission * To be perforated if necessary to sustain production, Anchorage 14. I hereby,c~ertify that the foregoing is true and correct to the best of my knowledge. Signed ~,t'9~,//~/*~//~'~ / Title Regional The space below for Commission use Engineer Conditions of Approval, if any: Approved by Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 q30 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Anchorage, Alaska 99510 Telephone.,~ 277 5637 December 3, 1982 RE: ARCO Directional Surveys · 1-21 10-22-82 ..,6-24 10-22-82 · 7-15 10-28-82 · 12-4A 11-15-82 1-15-82 1-15-82 1-15-82 1-15-82 1-22-82 1-15-82 1-15-82 1-15-82 11-15-82 11-22-82 11-15-82 11-15-82 11-15-82 12-7A 1 12-8B 1 12-14; -1 13-14 'l 13-15 1 13-16 1 13-17 1 13-18 1 13-23 13-.23A 13-24 13-25 13-26 · ·- · · · · · · · ·- · Single Shot Single Shot Single Shot Single Shot Single Shot Single Shot Single, Shot Single Shot Single Shot S i ngl e Shot Single Shot Single Shot -Single Shot Single Shot Single Shot Single Shot Single Shot ~D.S. 13~30 11-15-82 Single ~ot ~q)?S. ~1~3=32 11-15-82. Single Shot ~ i~/13-34 11-15-82 Singl. e Shot lease ign and return the` attached copy as receipt of data. E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W Bec'ky Benedi ct AFA - 403 -Trans. #638 DISll~IBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON GaS Co~s. GETTY N~s~ oit & D&M STATE OF ALAS~ DALES CHEVRON ARCO Alaska& 14tc~ is a Subsidia~f of AtlontJcRichfieldCompany ARCO Alaska, Inc. Post Office ~ 360 Anchorage, ~ka 99510 Telephone 907 277 5637 November 15, 1982 ' Re: ARCO Cased Hole Finals D.S. 1-19 D.S. 6-20 D.S. 6-22 · D.S. 13-32 · D.S. 13-34 D.S. 18-6 D.S. 18-7 9-i0-82 ACBL/VDL Run 1 8-25-82 ACBL/VDL-. Run 1 -9-30'82 ACBL/VDL Run 1 8-25-82 ACBL/VDL Run 1 9-11-82 ACBL/VDL Run 1 9-10-82 ACBL/VDL Run 1 10-2-82 ACBL/VDL Run 1 ease sign and return the attached copy as receipt of data. - Becky Benedict AFA - 403 D/A D/A D/A D/A D/A D/A D/A Trans. #622 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS ~., ?t ' '~ Alaska 0il & ~as Cons ~nchoi~go' ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 18, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are completion reports and gyroscopic surveys for the following wells' DS 1-19 DS 6-21 DS 13-34 DS 18-6 Sincerely, P. A. Van Dusen District Drilling Engineer PAV/JG'sm Enclosures GRU2/L18 OCT2 5' i982 Anch~'~s"~go Camm/ex/on ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ~ ;' ~ STATE OF ALASKA -~',. NO RIG IN A [ ALASKA~_:LAND GAS CONSERVATION CC. MISSIO WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILYJ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-136 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20811 4. Location of well at surface 9. Unit or Lease Name 2225' FSL, 1560' FEL, Sec. 14, T10N, R14E, UN ]LOCAfIONS Prudhoe Bay Unit At Top Producing Interval J VERiFiED lO. Well Number 2196' FNL, 77' FEL, Sec. 14, T10N, R14E, UM iSurf. ----~---', 13-34 At Total Depth'lB. H.~[ 11. Field and Pool 2187' FNL, 24' FEL, Sec. 14, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 87' RKBI ADL 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/28/82 09/08/82 09/16/82 N/A feet MS L 1 17. Total Depth (M D+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey J 20. Depth where SSSV set J 21. Thickness of Permafrost 9525'MD,9275'TVD 9480'MD,9230'TVD YES ~ NO [] nipple (~ 220~eet MD 1750' (approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR/$P, FDC/CNL/GR/Cal , CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 79' 30" 300 sx Permafrost C ~3-3/8" 72.0# L-80 Surf 2585' 17-1/2" 2200 sx Fondu & 400 sx Pe'mafrost C 9-5/8" 47.0# L-80/ Surf 8992' 12-1/4" 500 sx Class G & 300 sx 'ermafrost C 500-95 7" 29.0# L-80 8710' 9523' 8-1/2" 285 sx Class G 24. Perforations Open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 5-1/2" 8761 ' 8660' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. . DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A ., . 27. N/A PRODUCTION TEST Date First Production Method of Operation (FIowing~ gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure . CALCULATED' OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE 2l~. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~ OCT 2 5 ~g82 Alaska 0il & Gas Cons. Anchorage, Form 10-407 Submit in duplicate Rev. 7-1-80 GRU2/WC7 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS Top Sadl erochit O/W Contact Base Sadl erochit MEAS. DEPTH 9096' 9368' Not Reach~ TRUEVERT. DEPTH 8849' 9119' d 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Area Drilling Engr. 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 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" DS 13-34 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 2030 hrs, 08/28/82. Drld 17-1/2" hole to 2600'. Ran 63 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2585'. Cmtd 13-3/8" csg w/2200 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 9000'. Ran 218 jts 9-5/8" 47#/ft, L-80/SO0-95, BTC csg w/shoe @ 8992'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi-ok. Drld FC and cmt. Tstd csg to 3000 psi-ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW-ok. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 300 sx Permafrost C, & 130 bbls Arctic Pack. Drld 8-1/2" hole to 9500'. Ran DIL/BHCS/GR/SP f/9404'-8990', FDC/CNL/GR/Cal f/9498'-8990' & continued w/CNL/GR to 2452'. Cont drlg 8-1/2" hole to 9525' TD (09/08/82). Ran 20 jts 7" 29#/ft, L-80, BTC liner f/8710'-9523'. Cmtd 7" lnr w/285 sx Glass G. Drld cmt to 9480' PBTD. Tstd lnr lap to 3000 psi-ok. Displaced well to NaC1. Ran CBL. Ran 5-1/2" completion assy w/tail @ 8761' & pkr @ 8660'. Tstd tbg hanger & packoff to 5000 psi-ok. ND BOPE. NU tree & tstd to 5000 psi-ok. Nipple for SSSV @ 2205'. Secured well & released rig @ 0600 hrs, 09/11/82. Gyroscopic survey ran 09/16/82. JG:sm 10/05/82 GRU2/DH4 OCT2 1982 Alaska Oil & ~as Cons ucu'uiJis~,,ion Anct~orag~ Eastman ~~ Whipstock ~_~ A PETROLANE COM~ REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY DS 13r Well Number: 34 WELL NAME Prudhoe Bay, North Slope, Alaska LOCATION JOB NUMBER TYPE OF SURVEY DATE Directional Single Shot Anchora§:) SURVEY BY OFFICE American Directional Drilling (G. Thibodeaux) ARC:r-~ ALA'?--;I<A., I NC, l'iS 1 :?, klEL L NO: 34 I::~S'.E: F'RUDHOE BAY? NORTH SLOPE, ALA.=,I....A "1,-','" . 'i.;' 45 O , I...::, .:, -., ,r)- M D D R I L L E R: L3 l H ]~ [.[1"'1 [! E 1~1U X ( AMER I CAN D I RECT I ONAL DR ILL I NG ) '.E;I..I R V E Y P R O V I I:E E 1"~ B Y A M ES R I (:: A N I:) I R E C'I" I O N A L D R I L.L. I N G ,. 'v'ERTIC:AL SECTION I-:AI._C:ULA"ITEri ~'IN PLANE OF F'ROPO.'E;C4L !": ':DIRECTIOI',I-" N 62 DE!3.." !.Q. MIN, E .. RECORI-~ OF '.SURVEY R ~ D I U'.--; Ii F ¢:I_IR VA 1- U Rli:_' r,1E T H 0 D ~C:O AI..~'.=;KA., ! NF':. !: 1:3., WELL. Nl-~ :34 Jif-::::; ~1..11') H 0 E B A ¥., N 0 R T H F; L 0 P E., A L. A F-: K ~ ( AMER I F:AN lei I RECT I ONAL [iR IL[_ I NI".~ ) C("IMF:'LIT Al" ! F)N · r :r rq I.~ r) A T E 11: 3 :':::: 09 15- N 0 V -. 82 F:'AGF NCI, ' 1., TRUE ' '-'1 "- '1 I" '-'1 '~' _ :. A .:, .-I R [: E [IRIFT £KIFT I]:ClI_IR:Z;E VERTICAL VERTICAL ::,JBc, EA R E C T A N C'; U I_ A R C: L FI '.-]]; I_1 R E:' )"l l"l l-.i L [:' l] :IEF'TI-I ANGL. E DII'RECTIF'~N LEI',ICi'I'H DEPTH SEC'rlriN I'VD C 0 0 R D I N A 'T E S DI'.::;TANCE DIRECTIr'-IN :::;r:-:VEF,~.['T'Y F E EE -F D I'1 D M F' E E'I' F E E T F' E E T F E E T ' F E E T F: E E T El M l"l G / 100 F 'r o. 0 0 0 0 A. 0.00 0.00 -87.00 0. Ao 0.00 ':2500. 0 0 0 0 .'2500. 2500.00 0.00 2413.00 0. 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' ...... :.:.;:.~:~....~:.~.`..?.~..`.~.~::..~.~.~:.`.`'.~:~`~i.~.:...:~..~p:~.:~::;.:~:::;..~.~:~:~::~;:~.....~'~J..q::.::~.::~.~..:`.~:~.~::~.`.:;i~.1..r-`.r~.~.::~r..1:~:..~:~:`~:~.~::~`` i::iii'~:.i~'r.~:,5:.~:.:.'..:';~:.~S,! ..i.~::i:~.~..~:~]q..:i~i.~i:~:i?::`?~if:~!~:.~r.~:~i~;~i..~.i~i~i~!~ii~iii!:i!i!i~f?~ ~, ...... . ......... , ........ ~,..~,... !i i ii! (ii ':i i ,,!.,: !;~:i~,'. :':.:! ~i:. :.:i':: ~::~,i: ?:??::.?i:,:?::~.: .' .:::.:. ~!'~ '..:" '., .. ' .~...!~'. ...... ..:.':,~j '"::..'i':, ';..: :':;'~" ':".:': W':':';'~ ~;i"'.- "i':"' ~i.'.~:~'::.i:~!::"!~'.~:":~:.:~" 1-HE NEAREST 20 FOOT MD (FROM RADZLIS OF CURVATURE)' F'OINTS * ''- : '.., .. . - .... ~ - ..... ,. -'. ,...-..'-;: ' ' ·..::'.....:,:.::'. ;':",:::::.' :.' ' .. '" . ..' ', . .' : .,!: '..:':: '": ,..-:",".' ;r":: /::-;: .:/.'..',..,, .. ' ..... -' [.it tr, ,t..r '.:'ut~v~.f: ~'bP'/b. 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(.!t..:; :..:DE:t:.'..:..I .;[.LL .. :.: ...: ..'.,::.:' ~ .... ! ::::i" ".',?:~':..'.: :!' :%. ;' .':' ::!:ti:i;:'i':i::~. !;': ;*:.'.:: .:. ::;:. ::':: '~i:;:!?.ii~i:ii:?:i:i!?:i ii:~i:: :: ii: ?:?. iL::?:i.!:i!ii! ::i!.:i ~; ii i~i!i s i!il ii:!~ ~ii ': !!~ , . DERIVED LIE;lNG DII_ BEPTH.'3. AND SPERRY .':;LIN SLIRVEY DATA ( TOP ~]F :3AG RIVER '-"-" _ ::~(J..-.u ::-':774.1 '2 :3687.12 TOP OF 'F.;FILIBLIK A 904.6 :'-':7'P'.:.)~j~7 ' ,, !~LZ~".~.. c,~_ ' . ...' Tu F..:. LIE :.~.:,H. U DL I'l'.:,..:i. B!:~:.". ~::'.:..:..?.: :, ~'~ ~;:::~::.:~:.':.::: ~:: ~'.:::~'::: ~:;~:!~i~:~. :'? :. :.....:'. ~::~..'~':':. :~...: ..:~::...:: c,.o ! ~L,'~ ..,.' ~Z. J, .:.. ~":.:,',i. ~.' :,:,."i: 7.~.c.,:i: ? .I.'.~: :: :::..:..::~.?~::: ~: ~':~ .:;..~.;.~ ::'~.. .... .', ~::;~.. ?...:.. ::,.. '....: .~.:.. :...~:..:...:..'..::.:.: ................. ~1.1'1i~..'::1 I~:::";_-_, I.l.~ ......... '~.'~ .......... 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' ~.~ ' '~.;;'~,~. ,' .................. ]'7 t ...,:, ....... ;l~i .......................................... ~81.0. ........... . .................................. , ..., .,,-, .'~ ........ . ....... . ......... .....¢f ...... :-E,:::.:Z. ..... .E .............. ~: ............ . .......................................... ..,...~: .......... ,:...... ............. . ............... . ......... .:....:.... ................. . ......... ,...'.t..' ......... .,... ,,~.. ,.-...~:..? :,. TO'I'AL DEP]"t'-'i DRILLER 952.5 9'274,.9; ,9187 8 5 8.2 7 N 14 '71.9 :::~ E ~: 1-,::;: z '" % ·/. ;:' - _~.,.N ..... ~ .... /-.~U. :::'..:':i,'i~,c.'~-,' ,..;, '.' / .-. ,...,..--, .... :v::.~::,~..,,::,.; 4. N · 1-1'77. ,::,.::,E .::::~..iil.i':::::i;:~ ~.~;~..:',::~;.':;..;.,~.,, "...:'. ' ".., - ' .. . .:~,:~:,::..~.~::.:..,:,5.1,...,.:~..--N.:.,:.,::: .... :1..4~0~ :t yE. ~'~!i::~iii::'i!~::~!~ ~";9' ~:':"~2I,,1'~ :~:~:i.:'.':::. ~ (~ ~ .":~y~:,.: ' I'"l ,:,6..:,. 60N .1. ;5 J I. :'::::31.:..': 863.98N 151 ::ii:. ::50E ' · ,-, , ',/-, ·, , .--, ..:,1"' ~:.!iiii!;',:'::iiii~..::.;i ;:/,;:! :: :"i i::!]:::.i;!i'ii:,7:i!~.!il !!:.!':::!'i!:,~i.:!?.i:::.::ii':.;iiiiiii;!B ~ ~;-'i.;:: ].2...N.~':.' h:' :::':" ! 5 ~ !)'~'.4 6 E': 'i.::., ::'.":' ~,~'.: .':.'.::.":':::.!: .':::::::::: .... :'" :.. ".':. :;" '.:'::::, '.: '.: :i: i...:,%'"":. ':'"'::.,.-_;~'.:'"". ':... "..~='.?,; .... .'" .~.,',.;, ' :",:',;:,.,."~.'.~::i::'i :::',':!':'.',:~::,.:~)".,::': :i::',i;~:: ",;;:;::i',i' !.:: ':,':...",':',' :'::: :', ".'..":::.:',,' ':,',' ..:::. ',,~',:::.:'. ,;";::N':,,::",.: ,:':,::.t .'::, ;', ',,'.::, , . . . ,~,,.,, . .. 't , ,, .:' '. :','.' "- ~ * ~:'. "", ' . ii.~i~i"":hi~:ihii'iii!i:H:!':i :' "',i'!"ii:':': ]:i::' ,:',:!:F:': ', 'i":i:: i.',:!,.',i.i,:; :!'i?i<h~!',::!i:'~::'"'4;.": :,~ 'J:.':'", "' '.:: ,.::.'., ..~' ~.~,,,,~ :.' 6 ,, ,.; ..... ' ~ · .'. ~L~.:..~..~`:::~::..~.~.:.::.:..~:..;..;.~..~..~.:..~:.:.~`....:........::;~.::~:~ .......................... ~':c.: :~'.::.'::.'.;~:-::~...::~:~:'.';':".:':~" E:/,5 ?"'~' U 1 I~1'_'~' :--']. :-,~ ].'. '.-:','1 868. OON 15:36. ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No.. Boss-16113 Well: D.S. 13-34 (SEC14- T10N R14E) Prudhoe. Bay Field North' Slope, Alaska Survey ~ate: Sept~nber-16, 1982 Operator: EVerett Sellers . Scale: 1" = 500' -T~U~ NO~TH · .soo. oo - ~2' %/-" -- ..,,-. ~ '(~225FSL 1560FEL) ' · . soo'. oo ~oob. oo, ~sob, oo / . ~50 . 0 HO~IZONTRL- PROJECTION 2000.00 '4000.00 6000.00 8000.00 10000,00~ ARCO Alaska, Inc. Our Boss Gyroscopic. Survey Job No. Boss-16113 Well: D.S. 13-34. (S~C14 T10N'R14E) Prudhoe Bay Field_ North_ Slope, Alaska Survey Date: Septerker 16, 1982' Operator: Everett Sellers Scale: 1"= 2000' z?e4 ,~?' ~6° ~z'~: '-. 2OHO. O0 · ' · .. VERTICRL PBOJECTION Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ~)pe. rator, Wel 1 N~ame and ~umber Reports and Materials to be received by: ._/0 -- Date Required Date Received Remarks · ccmple~on Report Yes /~. _ ! ._Samples /~///~ -- ~/ --- ~ ~9 .~.,~ ud. r.o ./pO --'P / --------- CoreChips .////~///~e. ~i /5"" ' ., . , Core Description ./~.r.O/$"~ Registered Survey Plat /'C~s 5 Inclination Survey ,~'0 ~ /~-.?( ' · .Directi°nal Survey ~"~-~/ /~ ~'~.~'" F2 ~7-,z~.-;4.-~- /'/i ~/~'_. ., Drill Stem Test Reports /~/~;._~GJ , ,, Production Test Reports /~/~ ~ ~Q~:.~ Logs Run. Yes t , Digitized Data ~S5 ~ ..... ~,~ ~ ~- : ['" ARC~O Alaska, Inc. Post Office Box=' Anchorage, Alaska 99510 Telephone 907 277 5637 October 14, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton- Enclosed are monthly reports for September on these drill sites' 1-19 18-6 1-20 18-7 6-21 1E-28 6-22 1E-29 13-16 1E-30 13-34 .1F-6 1G-2 1G-3 WSW-3 WSW-4 A1 .so enclosed are well completion reports for' 2-26 1G-1 6-20 14-15 (completion report & subsequent sundry report) 1E-17 1F-5 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG-11m Enclosures GRU2/L15 ,t', ARCO Alaska. Inc. is a subsidiery of AtlanlicRichfieldCompany · ' STATE OF ALASKA .'~ ALASKA ~-'-. AND GAS CONSERVATION CC VIISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS wellx~ Workover operation [] Drilling 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-136 3. Address 8. APl Number 029-20811 P. 0. Box 360, Anchorage, AK 99510 50- 9. Unit or Lease Name Prudhoe Bay Unit 4. Location of Well atsurface 2225' FSL, 1560' FEL, Sec. 14, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 87' RKB 6. Lease Designation and Serial No. ADL 2831 5 10. Well No. DS 13-34 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of September , 1982 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2000 hrs, 08/28/82. Drld 17-1/2" hole to 2600'; ran cmtd & tstd 13-3/8" csg. Dr 8-1/2" hole to 9 Ran, cmtd & tstd assy. Secured w SEE DRILLING HIS ld 12-1/4" hole to 9000'. Ran, cmtd, & tstd 9-5/8" csg. Drld 500'; ran open hole logs; cont drlg 8-1/2" hole to 9525' TD. 7" liner. Disp well to NaC1 and ran CBL. Ran 5-1/2" completion ell and released rig @ 0600 hrs., 09/11/82. TORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld, conductor set ~ 79'. Cmtd w/300 sx Permafrost C. 13-3/8",72.0#/ft,L-80,BTC, csg w/shoe ~ 2585'.Cmtd w/2200 sx Fondu & 400 sx Permafrost C. 9-5/8", 47.0#/ft, L-80/S00-95, BTC csg w/shoe @ 8992'. Cmtd w/500 sx Class G. 7", 29.0#/ft, L-80, BTC liner f/8710'-9523'. Cmtd w/285 sx Class G. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/BHCS/GR/SP f/9404'-8990' FDC/CNL/GR/Cal f/9498'-8990' CBL cont. w/CNL/GR to 2452'. 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 Area Dr,.'!!,.'ng Eng,.'neer DATE NOTE--Report ~n'this~-f~r~is required for each ~aalendar month, regardless of the status of operations, and must be filed', duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 C, RU 1 /MR4 Submit in duplicate DS 13-34 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 2030 hrs, 08/28/82. Drld 17-1/2" hole to 2600'. Ran. 63 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2585'. Cmtd 13-3/8" csg w/2200 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd ~to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 9000'. Ran 218 jts 9-5/8" 47#/ft, L-80/SO0-95, BTC csg w/shoe @ 8992'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi-ok. Drld FC and cmt. Tstd csg to 3000 psi-ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW-ok. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 300 sx Permafrost C, & 130-bbls Arctic Pack. Drld 8-1/2" hole to 9500'. Ran DIL/BHCS/GR/SP f/9404'-8990', FDC/CNL/GR/Cal f/9498'-8990' & continued w/CNL/GR to 2452'. Cont drlg 8-1/2" hole to 9525' TD (09/08/82). Ran 20 jts 7" 29#/ft, L-80, BTC liner f/8710'-9523'. Cmtd 7" lnr w/285 sx Glass G. Drld cmt to 9480' PBTD. Tstd lnr lap to 3000 psi-ok. Displaced well to NaC1. Ran CBL. Ran 5-1/2" completion assy w/tail @ 8761' & pkr @ 8660'. Tstd tbg hanger & packoff to 5000 psi-ok. ND BOPE. NU tree & tstd to 5000 psi-ok. Nipple for SSSV @ 2205'. Secured well & released rig @ 0600 hrs, 09/11/82. JG'sm 10/05/82 GRU2/DH4 Post Office Box 360 Anchorage~.~Alaska 99510 Telephon ~7 277 5637 October 15, Reference: 1982 ARCO Open Hole' Finals D.S. 6-21 9-6-82 FDC/CNL/GR (Porosity) D.S. 6-21 9-6-82 FDC/CNL/GR (Raw Data) D.S. 6-21 9-6-82 DIL/SFL/GR D.S. 6-21 9-6-'82 BHCS/GR D.S. 6-21 9-6-82 CPL/Cyberlook D.S. 6-21 9-6-82 RFT D.S. 13'-34 9-8-82 RFT D.S. 13-34 9-8-82 CPL/Cyberlook D.S. 13-34 9-8-82 FDC/CNL/GR (Raw) D.S. 13-34 9-8-82 FDC/CNL/GR (Porosity) D.S. 13-34 9-8-82' BH. CS/GR D.S. 13-34 9-8-82 DIL/SFL/GR /Please sign 'and return the attached copy as Becky Benedict AFA - 403 Trans. #551 Run 1 5" SCH Run 1 5" SCH Run 1 2"&5" SCH Run 1 2"&5" SCH Run 1 5" SCH Run 1 5" SCH Run 1 5" Run 1 5" Run 1 2"&5" Run 1 2"&5" Run 1 2"&5" Run 1 2"&5" receipt of data. SCH $CH SCH SCH SCH SCH DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL D&M · GEOLOGY STATE OF ALASKA DALLAS ~ C,'.,--,. Post Office Box 360 Anchorage, ,~'-":~ka 99510 Telephone 9,._ 277 5637 September 21, 1982 Reference: Arco Magnetic Tapes and Listings D.S. 18-6 9-7-82 ~~~_ 9 -8 -82 D.S. 6-21 9-6-82 D.S. 1-19 9-7-82 D.S. 6-4 7-28-82 OH tape and list (ACC 65554) OH tape and list (ACC 65556) OH tape and list (ACC 65553) OH tape and list (ACC 65552) C/O log (8 passes)(ECC 1389) Run 1 & 2 Run 1 Run 1 Run 1 ase sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 479 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE O~ ALASKA CHEVRON DALLAS ARCO Al,~ska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Teleph~)ne 907 277 5637 September 10, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for August on these drill sites' 1-19 13-32 1E-30 2-23 13-34 1G-1 2-26 14-21 1G-2 6-19 18-3 1F-5 6-20 18-6 WSW-2 6-21 1E-17 Also enclosed is a well completion report for Kuparuk 1E-16. Surveys for.2-22 and 6-18 are being reran; completion reports for these wells will be submitted when approved surveys are received. Sincerely, P. A. VanDusen District Drill ing Engineer PAV/JG'llm Enclosures GRU1/L93 .. ~fi-F~ I ~ '~.,~ ARCO Alaska. Inc. is a subsidiary ol AtlanlicRichfieldCompany ',. . STATE OF ALASKA ' ALASKA. "LAND GAS CONSERVATION C '1MISSION MONTHLY REPORT OF I RILLINO AND WORKOVER OPERATIONS · Drilling wel~ ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-136 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20811 4. Location of Well atsurface 2225' FSL, 1560' FEL, Sec. 1#, T10N, R14E, UPI 5. Elevation in feet (indicate KB, DF, etc.) 87' RKB 6. Lease Designation and Serial No. ADL 2831 5 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. DS 13- 34 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of. August ,1982 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2030 hfs, 08/28/82. Drld 17-1/2" hole to 2600'; ran, cmtd & tstd 13-3/8" csg w/shoe @ 2585'. Drld 12-1/4" hole to 4704'as of 08/31/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20" 91 5#/ft, H-40, weld, conductor set ~ 79' Cmtd w/300 sx Permafrost C 13-3/8" 72 O#/ft L-80 BTC csg w/shoe @ 2585' Cmtd w/2200 sx Fondu & 400 sx Permafrost C , · , , , · · SEE 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 N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED~.~~~ TITLE Area Dr illi ng 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 DS 13-34 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 2030 hrs, 08/28/82. Drld 17-1/2" hole to 2600'. Ran 63 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2585'. Cmtd 13-3/8" csg w/2200 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 4704' as of 08/31/82. JG-11m 09/03/82 GRU/DH419 Oil & Gas Cons. Commissior~ MEMORANDUM State of Alaska TO: T~tRU: FROM: ALASKA OIL AND C--AS CONSERVATION COMMISSIOI:~ DA/E~ C. ~.~a~tt/erton September 7, 1982 Cha~n~ '~2 .... ' FILE NO: o Lonnie C. Smith' ! Commissioner Petroleum., Inspector TELEPHONE NO: SUBJECT: Witness the BOPE Test on ARCO's DS 13-34 Well Sec. 14, T10N, R14E, Permit No. 82-136 on Rowan Rig No. 41 ~,~_on.~.?.y,_.August _30._~I982 - After witnessing the BOPE test on Sohio's B-23 well, I traveled to ARCO's DS 13-34 well to -witness the BOPE test. The test commenced at 9:05 p.m. and Ms Concluded at 10:55 p.m. There %,~re no failures and I filled out an A.O.G.C.C. BOPE test report which is attached. In summary, I witnessed the successful BOPE test on ARCO's DS 13-34. I filled out an A.O.G.C.C. BOPE test report %~.ich is attached. O&G #4 ~ 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Date Operator Location: Sec I~ T Drilling Contractor ~O~/d Representative Permit # M ~,~, [~Casing Set Rig ~ ~ Representativ~ Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams ij ~ Blind Rams ~,~ Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve ~ Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure. ~%d)fD psig Pressure After Closure I~Q psig 200 psig Above Precharge Attained: mil ~sec 'Full Charge Pressure Attained: ~ miL ~7..sec N2 ~),'~)~OO/ ~pfLo/ ~9 psig C~ Controls: Master ~p~ Remote ~k~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Lower Kelly Bal 1 Type Ins ide BOP Choke Manifold No. Valves No. flanges ~ Adjustable Chokes Hydrauically operated choke Test Results: Failures Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: · ~Test Pressure ~Test Pressure Test Pressure Test Pressure 'l ' ' - i Test Pressure Test Time / hrs. days and DistribUtion orig. - LO&GCC cc - Operator cc - Supervisor Inspector August 20, 1982 ~'r.- ~ark A. Ma jot Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 ~ie: Prudhoe Bay Unit DS 13-34 AF~OO Alaska, inc. Permit No. 82-136 Sur. Loc. 2225'FSL, 1560'FEL, Sec. Bt..~hole Loc. 2147'~1~L, 160'FI~7~, ,Sec. 13, Dear ~ir. ~{ajor: Enclosed' is the approved a~plication for permit to drill the above referenced weli. ~etl s~ples and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(§). If available, a tape containing the digitized log tnfornmtion shall be Submitted on all logs for copying except experimental logs, velocity survey~ and dipmeter surveys. ~any rivers in Alaska and their drainage systems have been classified as important 'for the spawning or migration of anadro~us fish. Operations in these areas are subject to AS 16.05.$70 and the regulations pro~ulgated thereunder (Title 5, 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 ? and the regulations pronnligated thereunder (Title 1~, ^la ~ ~ ~a A~ini~trative Code,- Chapter 70) and by the Federal Water Pollution Control Act, as a~nended. Prior to c~mencing operations you may be contacted by a ret~resentative of the Department of Envtro~aental Conservation. To aid us in schedulin~ field ~ork, please notify this office 24 hours prior to co~a{:encing installation, of the blowout prevention equipment so that' a representative of the Co~nmlssion may be present to witness testing of the equiI~ment before ti~e Mr. ~rk A. M~jox Prudhoe Bay Unit DS 13-34 -2- August 20, 1982 surface casing shoe is drilled, Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please gave this office adequate advance notification so that we may have a wi tness present. Very truly yours, Cha i ~n o f . BY ORDER OF ?HE CO-~[~".J~%q~o~ Alaska Oil and Gas ~nzervatzon ~~~ton Eric 1 o sure cc; Department of Fish '& Game, Habitat Section w/o encl. Department of Bnvironmental Conservation w/o enel. CVC = be ARCO Alaska, Inc. Post Office B~ J60 Anchorage, Alaska 99510 Telephone 907 277 5637 August 16, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 13-34, Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill DS 13-34 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; and a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we estimate spudding this well August 25, 1982, your prompt approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG: 1 lm Enclosures GRU1/L72 o ,qUG' 1 .!982 Alaska Oil & Gas Cons /tnchorag~ C°mr~issioa ARCO Alaska. Inc. is a subsidiary of AtlaniicRichfieldCompany ?-" STATE OF ALASKA ALASKA O,- AND GAS CONSERVATION CO~v,~vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL I~( DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE []~]X MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address ~ ~ P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 2225' FSL, 1560' FEL, Sec. 14, T10N, R14E, UN Prudhoe Bay Unit At top of proposed producing interval 2200' FNL, 60' FWL, Sec. 13, T10N, R14E, UN At total depth 2147' FNL, 160' FWL, Sec. 13, TION, R14E, UN 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 87' PAD 47' ADL 28315 12. Bond information (see 20 AAC 25.025) Federal insurance Company Type Statewi de Surety and/or number #8088-26-27 10. Well number DS 13-34 11.Fieldandpool Prudhoe Bay Field Prudhoe Bay 0i] Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 5-1/2 Hi. NW Deadhorse miles 2200' (~ target feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 9540' ND, 9247 ' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT 2700 feet. MAXIMUM HOLEANGLE 17.4° (see2OAAC 25.035 (c) (2) 21 SIZE ,Casing 20" 13-3/8" 9-5/8" Hole 15. Distance to nearest drilling or completed 13-24 well 120' (~ surface feet 18. Approximate spud date 08/25/82 3600 psig@.~ Surface 4500 psig@ 9247 ft. TD (TVD) Weight 94# 7- ~/2" 72# i Z-1/~"I_ . 47# 8-1/z" I l" 29# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER Grade CouplingI Length H-40 Welded ) 75' L-80 BUTT I 2566' L-80 BUTT 8994 ' 1-80 BUTT 813 ' SE~'I'ING DEPTH MD TOP TVD 35' I 35' 34' I 34' I 33' ~ 33' I 8727' 18472' I MD BOTTOM TVD 110'1 110' 2600'12600' 9027'18758' I 9540' 9247' QUANTITY OF CEMENT (includestagedata) 275sx PF to surf 2300sx Fondu + 400 sx PF 500sx G 1st Stage 300sx PFI 2nd Stage 400sx Class G Cmt ARCO Alaska, Inc., proposes to directionally drill this well to 9540' MD (9247' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17# L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A separate !thist'SundrYwellN°tice will be submitted when the well is to be perforated. A surface ~IF~r[~e used on 23. I hereby certify that the foregoing is true and correct to the best of my knowledge Alas~t 0il & Gas Cuns. C;01rlmJss[0rl SIGNED TITLEArea Dri 11 lng Engineer DATE The space below for Commission use Samples required []YES Permit number APPROVED BY CONDITIONS OF APPROVAL Mud Icg required I Directional Survey required I APl number []YES ~NO I ,~¢.YES i--INO I 50- ~' ~OO// Approval date I SEE COVER LETTER FOR OTHER REQUIREMENTS ~COMMISSIONER DATE Aucust 20, 1982 /f'"- / /f by order of the Commission Form 10401 GRUl/PD20 " Submit in triplicate .... i ii t 'I I ~ . , I I I i I i ii ', ,~ , i i1~ !iii ii~ I It Ilii II .... ~ I . , ,I,, :,:' . ~., , ,, . Iii ~,,,~i' fill :iii I!~ ~ i, , ~ ,~11 ,~ , t11, I ! III!Il I !!ii ' i'' i'] ii,I '111 iili ili, iilii]lii fill I I I' i 11i ii, !iii. ii Ii,i ~. ~ i!iI: 'il,' i i I Ii' 'i,' ii' ', ~i.,.,~.J~ : ' ' i.' ....i,,.4~ ' ' ....... : ' I t 111. ,1[il ~i~:' - i il ~i' ~Iii :~ i~ii iiii !iii ' !ii. i F TT'F i' i'~']-'i% .... T 'q ..... ! ' -~ "T .... ,"ii i~ll ~_,~ IIII ~lll , iii Iii1 1[ I I I I l; I I Il I11~ I! ' ' , , ' : ' ' .... ,ill II!' 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[iii Iii I~ I ~ I Il ~ } IIil I ~ 'i}i i{ii iiil ii'} ii{ { Iii. i{ I ~ ~ I I{ i i Illl ]..i Iii} ~i{i iii{ i{ii {iii I!Ii ii!i ifil i){{ II I i} I Iill ,Ii! I { {Ii! iii{ ~ I ~ i I j - ~ ' = · ~ ' ~i i 'i ~ j ''. I~_~Ii Illl ~:~ Iti] ~I~1 t II ~I~ ~ :, . ,~ , ~ z ~ , , ~, .... ~l!I ', ' ..... ' - ~i ~ ', ' ~ ~lI ~11 i ~lli il~! ''' i ~ i, · Ii~ I~ ;:~ , :{ I ,,: ...... ~ ~!i iiii ii~i ilii ili! iil! iii~ ., i !iii itl~ ill II~ ~1~ ~i~ 'ii: ~{i {il~,,,~ .... ,"i ~li ifil~'~ ~~ ii" '"' '"~ ~"~ '" ~ i~ .. ~ ' ~ ' ; 1 ' - ' t ' ' ~ '' ' ! I' : ' _L · '. - I ! ! ' ~ i I i -; ~ T '~' , '-; - ~'-'~ ......'~ ........ ~ - ' ' -'--~, .................. . ......... ~' ............. '1 - '~"t-:: l!iO0.:_-'~ ...... ~, ...... i- ~ -:':!. :_-- ' :_ ;'. .... : ...i : ..... ] ~ I i' ! ~ I' ~ I - '-T-:--i ..... , ..... ;. ...... : ...... ~ ...... ~- .............. ;- 'i · - ' - ~ ' - : ..... :_LL:__-_::_; :_.' ' :., -' . ...... ,.__._.___._._ -' . , - -'- : ....... i :-.-i- -/---- t-. : ~ i ' i .... : : ' ~: '' ' ~' ' I ' ',Il ..... ' ;'"~":--~'"'"""'" -'-"""-':"' BEYONE:-THIS--i;,,,' i ...... , ' -- ;- .~ .... ;.-I .... .... _ · ..... : : -i ! ' . ~ : ; . ! : ~ . ! : Z .~.i--~--- i --J' , ..... ~ -- , , . '-~T . ----~: ..... l -' ;-- : : , : . ! ; ! . ~ ~ i ~ , .t' - . , , . . ~' -: - - ~ i; - :--:'-r : --' ~"~ - ~.~--': ,~': :-1-'--- r~ . . ?.---. 'i' :l [ ';- ' , . · ~ ~ : . - j . , . . ! : - ~ ..... : : ' - T ........... : i ' -~ ........ i ..................... ~ .......... :? ' ; ' ·-- --: I ..... l ........ !.-~-..= ......... PREVENTER BLIND RAMS PIPE RAMS DRILLING SPOOL PIPE RAMS 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 simultane- ously 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 1200 psi remaining pressure. 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. 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 presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams 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. , 11. 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 and 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 Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. Rev. 5/13/81 ii~' I "~'"N. III _- ' 'i~ r~ '--.: '.. .: - ~' -'O~:-r.--i;'._. . ~NDucToR LOCATIONS ~ ~ X- ~5,5~q. I~' ~ a~o ' ~._" ~T- 70.13 13.~38 ~ ~ ~ ~ ~ ~ ~ ~ C0R CEL~R BOX ELEV = . ~ COR CELLAR BOX ELEV = 13/3~ Y- 5,~32,253.~8 x- ~5,6~.39 ~T=' 70 13 11.633 o7.7 I~ I~ ~ COR CEDAR ~X ELEV =. h7~28 13/25 Y- 5,)32 136.67 ~oT~~~ ~. I~, ' LONG- Iq8 30 07.063 Y g X C00ROS ARE A~S~ STATE P~NE ZONE~;~ ~ ? .~u,~ ~ COR CEL~ BOX ELE9 - q7 27 ALL D I STANCES ARE SURFACE. ,~'a;t(a 0it & C~'as Cons. ~~~. /~c'hor~~'~ Y= 5,~32,01 ~. 57 ~- OF AL?~'. X= 685,70~.86 ~~.,,.~,v,,~~ · I HEREBY GE~I~ THAT I AM' - '.- ~T- 70 1~ 0~.320 ~,, ~ %~,~ PROPERLY REGISTERED AND LONG= lq8 30 ;/49th ~ ~ ~ LICENSED TO PRACTICE ~ND ~ C0R CEL~R BOX ELEV ~,~.-~-~~.~ SURVEYING IN THE STATE OF , - ' " ~.~~.=:~7~ A~s~ A.D THAT TH~S ~T ~/~ ~- S,S~,~e~-O~ ~'~~~~~ ~~-c~s~--~ REPRESENTS AN A~BUILT SURVEY ~ .: X- 686,057. ~~_ ,.~4 ?~ MADE BY ME, AND THAT A~ -.. ~T-'70 13 02.779 '~1~""~__ .,/: ~ DIMENSIONS AND OTHER.D~AIL8 - ' ~': LONG- ~ ~8 2~ 56. 568 e~[~t,S~L~-- . ARE CORRE~,AS OF: g ~. COR CEL~R BOX ELEV = q8.79 ~ I I I I Oil and Gas II I I I I I J I I CHECK LIST FOR NEW WELL PERMITS Company Lease& Well No. ITEM APPROVE DATE (1) Fee (2) Loc (2 thru 8) (3) Admin ~K f~/~'f~ ~(~ 'thru 11) (4) Casg 9, 10. 11. YES NO REMARKS 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. /~ 4. Is well located proper distance from other wells .................... 5. Is sufficient Nndedicated acreage available in this pool ............ /~ 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... Does'operator have a bond in force .................................. ~/~ Is a conservation order needed .., ................................... Is administrative approval needed ................................... (12 thru 20) 13. 14. 15. 16. 17. 18. 19. 20. (21 thru 24) 22. 23. 24. Is conductor string provided ........................................ Is enough cement~ used to circulate on conductor and surface ...... -- Will cement tie in surface and intermediate or production strings. Will cement cover all known productive horizons .............. ---- Will surface casing protect fresh water zones ..... ' Will all casing give adequate safety in collapse, Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment ~procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached, ....... /~zf/~ Does BOPE have sufficient pressure rating - Test to b~~ psig .. ~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. i~o T ~' 6 8M ~ _TTED Additional Remarks: Geology: Engin~ing: · .,"-./.,,:~.,',~,. ,~ '~ ~,i, " HWK__ LCS ~,,,,, 'e BEW~...×.~, WVA fi~l~ J KT~']p-RAD rev: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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 APPENDIXi .. No special'effort has been made to chronologically organize this category of information. TDT DATA LISTING COMPANY : ATLANTIC ~ICH~I~LD ~EI~I~ : DS 13-]4 (2 APR 8]) FIELD : DRUDHOD BAY COUNTRY : USA REFERENCE: 68147 TDT DAT.~ LISTING COMPANY : ATLANTIC RfCHFIEbD %~ELL : DS 13-34 (2 APR 83) COUNTRY : USA , · !L,t'., : iDS 13-34 (2 APR 83) PAGE 004 ~8,:,o P.~t:Sl F AS,>.2 PAo,....] PA884 .. S5 ASS1 PASS2 PASS3 PASS4 PA 5 Ct. CU CU CD CU (;~PI GA:PI GAPI GAPI GAPI AVE. AVE NEAR FAD ~'U C O 9478 39 31:39.3t 34: 4:6:3~ :34:;37.13:36:78 42,:87 36,15 36 ~1 35.8 SSSS$ .$$$$$ '79;9 $$$$8 37;89 94:77 39 41 39'50 37 53 37 06 38,56 34 19 4(),27 35,39 36 22 35,8 $S$88 $$8$$ '79 9 88~8$ 3 9476 37 88 40,56 38~ ~5 38 ,):~ 37,B1:34 ~63 38 .~0 3~,00 35 ~ 35.8 $~8$8 $$$$$ -79'~ g475 34 ~8 39,94 3(4,89 86 ~0 22 35,91 35 O0 37 04. ~5;53 35 ~4 35,8 SS'SSS SSSSS 29~ ~ SSSSS 0474 37 O0 38,3~; 36~:05 j2: 3q 33:*:22 35 16:34.~6 34'74 36:06 35.8 $S8$$ $$$8$' 79~9 947~ 32 ~8 3~.,'~8 37;25 37 '~3 ~q '22 34,38 ~6 66 34 ~78 36,10 35'~6 35;8 $$$S$ $$$$$ '79 9 9472 37 97 3:6.4.7 35i52 3~ ~0 3~ ~4 35 ~77 35,56 35'75 39.8 $,S$S SS$$S-79. 047~ 38 ~4~ 37,97 36,78 38 ~9 39 ~3 36,56 35 84 37 16 35,70 36,34 35'8 $$$$$ $$$$~ '79 ~ 9470 36 .94 3~'75 37:;g6 38[ 63 40 00 ~3:6~06:35 87 36.~6 34.67:36.88 35.8 $$$$$ :$$$$$:'79. 9 55:$$ 9469 32.6g 37,03 37,19 3~ 79 37. 16 35,5] 35,54 ]6,44 33,92 35,~8 36,1 $$$$$ '$$$$$ 20 0 g46~ 3~.50 4~.48 37,30 4~ .34 ~8~63 34,9! 35,~:2 36,95 35,19 35'7 47'1 2~3".5 7~. 1 0467 35.38 39,63 34,7g 37 ~73 40, O0 31,55 33,69 33,63 32,99 33,56 36,7 46,0 217.6 67,5 9466 35,.~4 38'26 35~75:37~30 3~,72 31,05 32':87 33-56 31,97 35,~i, 3 38.6 47.7 290.4 63,3 9465 3,:~,22 40,47 39,~6 3~ ~'~ 39.28 34,63 35,71 37.21 34,85 36,i9 38.1 47.5 222.3 6~,9 70~ 9464 40..5~ 4t,1:4 3'g,'37 3g .37 4~ 63: 35.'7~ 37,68 3.5'.B0 36.7~ .35.28 34 9 47. ] 215,5' 64.~ 9463 43 .63 .42.~6 39,03 42 .96 42. 63 37,84 37.68 39.02 36,g3 ]4,g7 35 8 50. i 1~6.5 ~,6 69, 9462 44.38 41,89 40,94 43,26 43,~I 37,72 37. 07 41,20 39,02 37.31 34 7 ~5 6 1~8.6 67.0 67, ~9! ~:.,~ ~9,g9 ~9;g6 ~0,89 42,22 34.16 34 55 38~28 36,10 37.38 38 3 4.6 4 185,8 56.9 65. W~t6u 29~,i~3 31.,:3U 3~g'16 29,58 33'81 '25,36 26 90 28,90 28,34 ~9 55 3! 2 49 3 190.3 63.6 61, 30 9459 2t.,28 22,66 22,33 21,31 22,59 1~,48 20.6~5 20,30 20,23 20 06 3~ 8 47 2 184,9 66,1 68, 97 945~ ~.9~;94 20;60 19'14 19,73 ~9;34 i~.20 17 72 16,9~ 16,95 17 36 34 5 48 0 ~571~ 66,1 65. q457 ~0,13 1.9~53 19,~5 1~,79 ~.~,77 i6.73 17 34 16,12 i6.93 16 42 35 1 47 8 158,1 65.4 74, 3 ~454 20,1.6 20'45 lq'55 20,~3 19'45 17'22 17 65 18.05 17,48 17 53 36 6 42 9 156,3 69,2 68 95 9453 20,09 20,22 19,96 1g,32 19;4.1 17.19 17 03 17.30 16,98 17 59 ]3 8 45 t 160,6 7~,6 75 77 9452 lg,l. 9 19.05 ~,63 20,31 ~8;86 17,39 16 12 17,40 17,35 17 27 34 6 44 1 146.4 78.1 7~ ~45J. ~0,77 1~,64 !9,88 2~,06 ~9,20 17,06 !.6 52 17.75 16,66 16 6] 34 6 45 6 143.] 74 6 70 9450 19,28 19,80 19'66 19'41 19148 17.27 16 67 16,83 17'.08 lfi 45 34 1 46 5 150,8 73 2 75 53 94~Q 1g,03 19,02 lO,Og 1~.86 J8.~0 16.80 16 4.4 16.~3 17,05 16 24 37 2 44 0 140.0 71 .2 82 95 9448 19,7~ 19.05 19.34 19.70 19,12 16,50 16.31 15,71 16,67 16 04 33 7 42 3 138.6 66 5 75 41 ~4'7 20,34 1q,98 20,]1 19.41 19,72 17.63 1~,58 15,53 17,45 t7 56 31 8 41 9 182,6 72 2 74 98 46 ~9.69 19.6g 19,53 19.73 ~0.05 17.44 17,~19 ~8.44 18,41 17 73 35 ~ 45 5 320,8 87 4 88 7~ 0445 20.13 1g,75 19,64 2().5~ 20,56 17.47 1~,78 17,80 1R,88 17 19 38 3 50 5 376.0 91.0 90. .56 4 ~444 19,77 20,~1 0443 19,02 19,70 9442 lg,64 19.83 0441 19,70 19,38 0440 21,45 21,05 g43~ ~1, 11 21,61 ~438 20,42 20,73 ~436 20,gg 20,66 9435 20 33 l~,94. 9434 20:42 20,09 ~433 ~o 50 1~ 59 ... e .. .. ~ 043~ 19,44 ~0,20 2.~,3g 20.65 17.47 17 17,04 1~,'/7 20,17 lq.70 1.6.75 16 16.29 18.55 19.94 19,37 16.70 16 17.~5 lg,16 1.9,44 10.55 ~7,28 18,31 17.55 18 29 21.22 ].g.88 18,78 19,64 19,08 19~74 ~1 g2 2~,27 lg,34 18,06 18.96 IQ.55 21:~3 20,64 ]~,09 17,73 17.35 i9,06 20.H3 2~,30 lg,53 1~,25 17,1.5 19.13 20,44 20,44 17,97 18,25 16,90 ~g.54 lB.gl 19.73 16 ~2 lq,05 ~6.31 l~.4J 1~,44 19,39 16:75 17,82 17 34 19 54 J. 9 31 J.Q 66 17,34 17,51 18.25 16.84 16.g4 ]7,92 17,36 18,53 18,58 18 75 17 48 17 17 16 39 16 58 ~6.41 17 75 36 7 17 23 35 7 16 21, 42 8 17,01 39 3 17 55 35 2 18i~1 34 8 18 70 33 7 17.06 36 7 17,20 40 0 17.30 43!6 16.88 35 9 17.89 33 9 17,52 32,4 45 2 366,0 51 1 351.5 55 7 349.4 51.3 401.5 48 0 407.2 47 2 380.3 46 7 372.6 46 5 365,4 50 4 429.$ 56 1 475,6 48 5 232,8 44 9 89.8 45,1 57.9 90.2 88. 94.9 94, 90.5 90. 90.0 84. 91.0 81. ~6.8 91.2 90,7 97.2 93. 101,2 93,~ 79 1, 80. 70:4 71o2 65.2 66.0 19 58 47 24 44 70 02 72 95 92 52 14 34 30 36 95 84 7~ 7S 34 06 12 31 87 7! 36 10 27 90 20 18 17 20 16 73 17 O0 17 57 17 56 17 1,9 84 6 86 6 52 17 81 18 03 18 3~ 17 14 16 CO.~PA~.~'Y : ATbA~TIC R]C. HF].'ELf) WELl, : !)S 13-34 (2 APR 8B) PAGE 2 FPT~{ P~SSI P~S.S2 PASS3 t ~S~,...~ PAS..,5 P~S,.~I A$,..2 ASS3 PASS4 PASS5 PASSI PASS2 PASS3 PASS4 PASS5 AlE, AVE, SIG~..A SIGMA SIGMA Si~A SIGMA SIGM~ SIG~A GR GR GR GR GR SIGma SIGMA N E A i,~ ~ E A )} N )"C A R N F7 A v N E A R P A R F A ~ F A R F'A R F A R N E A R F A R F~ {.'.9 ~:~)) ~U CU C',LU : CU C'U CU CU CU GA;PI GAPI GAPI GAPI GAPI CU CU 94~.g lq ~.t ~0,74 lg 6" 645 74 942~"~ 1~ 33 19 37 1~ ~427 1.~I 73 .1.~.08 ~9 9426 1,9 27 17 91 19 9425 18 47 18 27 19 9424 1~ 08 17 6 3 94~3 Iq, 72 1,7 65, q422 1<, 8~ ~ 72 9421 2~ O, 30 20 q420 20 25 19 o4 2 9419 19 77 18 46 1 '. (~1 ..17 1 17 1..1, !6 76 16 94 !7 30 1,6 50 !.5 ~i 1,5 1,4 17 70 16 30 14. i 6,5 iS, 57 16 11 1 17 17:05 1 70 1,6 6t'16 91.7 ~2 16 17 9418 l.n 61 18 72 Iu 94 19 941.7 1,q 77 19 99 20 66 20 9416 20 02 20 '1.7 20 67 20 17 19 9415 lo 73 20 53iq 77 20 10 1:9 9414 lq 59 19,41 20 17 19 65 19 0413 19 09 19,18 1.9' "( · 1.6 2.3 04 19 9412 19 97 20,12 I9,64 20 .75 20,59 17 q4,1 20 67 20.58 20,75 20,78 20,79 1~ 941o 19 27 20,67 2o,11 20 6! 20 05 16 9~09 lq.77 20,09 19.70 19 9720.. 07 15 9408 20,03 1,9,66 1~,31 19,50 19 49 17 42 17~45 Oa07 20.23 20,10 10,98 20,28 1983 17 58 1.8.38 Q406 lq,i~O 1.9,96 19,67 ~0,00 20,0~ 16,61 0405 1.9,08 19.41 19.97 18,67 18,69 17,06 1.9,53 lC~ 95 1o 56 17,49 ,1,6 69 1,6,94:16 97 20 l~'15 1'7 ,01 J. 6 09 1 ,06 16 36 t.~ ,09 15 26 ,94 30 i ,.88 75 13 1.7,0~ I~ 46 1. 6. ~ 37 16, 7 1 96 I7.44 '17. 93 17,64 1 67 17,03 16 00 17,56 i7 45 } 86 77 03 16. Bi.. 16, 77 27 17 96 70 is ~9 18 03 1~ 52 1.~ I7 , 88 17 83 17,25 17~69 17 56 17 99 17,48 17.63 16 84 17 16,94 17 31 17 18,08 !7 77 16 40 39 .t2 70 34 .42 33 93 37 36 75 58 37 80 38 , 38 95 37 81. 29 82 34 08 40 62 34 99 33 77 40 44 40 99 33 17,87 17,56 17 41 17 24 34 16,81 16,66 1.6 84 16 84 38 17,77 16 50 16 41 1.6 56 37 17:14 16 73 17 4 7 52, 9 58 2 58 3 5:7 59 8 5:7 0 53 I 55 75 74 62,2 63,6 67 69 63,8 65 64:.0 65 3 49 8 4,5 7 4.6 7 4.4 7 .7 70 7'1,5 69 62 69,7 68 58,5 68 66 60, 70 . 67 65 6 41 9 54,6 66 4 44 7 58,8 69 1 46 0 60,4 70 1 50 8 57,4 68 0 46 3 59,0 66 6 2 47 7 58,9 66 3 3 52 2 58,9 66,0 45 3 58.8 65,7 5 58 8 65,4 2 58:7 61.8 3 58 4 63°5 69,~ 6 55~4 67,1 70. 9 59'7 62,1 68,0 74.7 7 63,6 7 59,6 68,4 73 ,o! 73 5 63, 4 74, 7 77. 6 73, 74, 69, 72. 70. 68, 71. ! 5 16 79 95 ~'1 85 6 ~5 09 93 17 65 16 60 17 16 6 72 17 82 17 58 17 80 17 38 17 41 16 77 16 84 17 9398 IO.OC) 10,64 1. c~,22 19,,'-;3 lq O0 16 9397 19,1.6 18,33 10,02 19,38 19,63 16 9396 ~0,63 19,72 ~0,(~0 19,83 2o.al 18 9305 19,47 19,.41 20,48 20,~7 20.76 17 .. 95 1.6 0394 lr~,88 19,83 19,92 20.f~3 19, 9393 19.17 1.0.39 19.61 20,25 19,34 16 9403 1.9,45 .73 19 61 17,69 17 55 , 58 35 4 940~ 19. ,7'1 1°,.,. .95 20.39 1. a"i~9,., .. 1o., 88 16,92.. 17 55 1.6,86 17,72 17 52 35. 8 49 9401 10.34 19.86 19,31 19.58 19 51 17,47 17 08 16.27 17,06 16 91 35 8 50 9400 2,.),33 1.~ 99 la Oq 20'45 19 52 17,25 17 13 1,6,97 1.7 13 16 78 34 4 49 9399 1.9,64 19~99 19~41 19,97 19 90 17,25 16 80 17.92 17:23 1.7 15 32 7 45 89 1.6,85 1.6,73 16,80 1.6.99 36 6 48 77 J7,50 16.50 16,50 16.56 40 7 52 13 18,75 17,48 17,52 16.54 43 8 57 41 17,58 17.55 18,06 17.69 39 6 49 78 17,04 17 1,7 17 34 17,92 38 1 51 98 16.91 16 81 17'.45 1,7,21 38 2 47 0392 18,92 lP.,.1,5 1.0,,4.4 lq,aO 18.54 lh 69 1.6,54 15 68 16: 88 16,43 45 7 55 9391. 1..~,11 19.78 ~.0.17 20,5?. 18.77 17 25 17.14 16 97 16 92 17.01 49 3 59 0300 lq,64 20.27 l<:,47 20.94 19.99 16,80 17,34 16 74 17,13 16,67 34 3 47 03~9 1q,,,,50 1~.83 1.q..61 19.!1.. lO.81. 16,50 16.23 16 34 16,48 15,97 32 3 45 93P8. 1'.,~. ,16 1.,~.. ,47 2o,11. :1a,77. la,5h 16.55 1.5,72 16 69 16,64. 16,19 36 2 44 ~3P7 1. q,31 1.1~,52 2n.28 1.8,80 18,59 15,88 16,51 16,12 16,36 16.78 42 8 52 9386 1.9,38 !~,9.4 2o,50 l~,30 1c~,7~ 16,97 16,67 1.6,73 18,3l 17,17 53 2 65 03~5 !e,81 20.41 20.10 I.~.~B 20.00 17,03 16,69 1.7.03 !7,69 1.7,41 41.6 58 02 17 58 17 38 17 02 16 o 57 7 64.0 7 52,9 62.1 65. 65,2 74,9 78 7 64.6 71.8 79 9 55,7 55 5 69 53.2 61:8 70~ 60 16. 67 4 99 16 53.2 60 4 71.2 79,8 871 9 93 17 62.8 67,8 74.2 (.,.i.)~[At'.~V : ~ l,,~i',i'rl NICH!~"~F'~[.,?) WEiI..~L : f')$ 13,,,34 (2 APR 83) PAGE; 3 PT CU CU 93P4 o383 9382 93~ i, 9380 c) 379 g37B 937~ g376 9373 9379 9371. 9370 0369 936~ 936~ ~3~6 364 936~ 9360 9359 935~ 9357 ~356 9355 9~54 9353 9352 9351. 9350 ~349 9347 9346 9345 9343 93a~ 93al 9339 PAS,.3 Pb. og4 [,.~8,.5 t.A,.~ol PASS2 PASS3 'PASS4 PASS5 CU CU ~ CU CI~ CU CU CU CU PASS1 , ASS2 GR GR GAPI C, API PASS3 PASS4 PASS5 AVE, G~ GR GR SIGMA $I NEAR FAR GAPI GAPI GAPI CU CU 1.7 17 1.7 1 ~ 1. (: 1 17, 17, 17. 17, 16, 17, 16. 16, 16, 15, 15. 15, 15. 15. 15, 15, 1.1 17 38 17 67 1.7 73 la 27 16 6 1.)8 17, 75 19, 63 17 06 17 l.a O6 IR 50 ~ 78 1.7 ~1. ~7 42 a5 79 08 69 55 79 5~ 60 5! a7 63 90 11 16 16 16 16 15 !6 15 lb !5 16,06 15.90 I 5.fl. 7 92 18 20 17 47 1:6 2 ~,6 9.6 1:6 66 t5 9~ ! 6 02 !6 50 17 ,54 15,54 1,51 '5!.~ 15,31. 14. ..~.'.:14,76:14, 60 14,34 14 31 14'80 14 ~..t 14,55 15 5.. 1.4.,~3 15 91 15,34 .15 1:4 '14~77 15 6(: 15 ,52 15,84 1:..,42 .78 15,45 14,30 1. 14.,71. 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O0 19.31 1~.62 20,%n lq,2o 17.64 ~a'67 17.19 18,98 17.~5 36 2 50,9 60,3 66.4 69 6 66 15 9293 1'7.41 17.72 XT.GO !7,38 57.08 15,23 16,27 15,25 15,69 14,59 44 1 51,9 59.4 67.5 75,9 17:67 15 q~a2 1~.14 1~o78 ~.7.~0 17.67 17.27 1.5,94 16.38 15.02 15,61 15,09 41,7 53, 9291, 17.ag 18.~ 1~.]1 1.~.65 ~,1~ 15,75 16,44 15.42 16,52 15,95 35.7 44,4 50,6 68.0 6 56,9 76,3 73.1 18,34 16,0 65,2 18,54 16, 0 PASS3 PASS4 GAPI GAPI PASS5 AVE~ GR MIG A iGMA NEAR FAR GA[I CCI CU 9290 18.19 1!9.39:18 32 1.9.:07 ~9,1:9:16'14 16,30 16 O0 16 28 15.71 32 ~9 1.~,72 1~,~4 !~ 79 18,95 18)55 16,3E 16,94 16 65 17 07 15,95 2B 9 8~ 1~ ~3 ~.(~ 1~ . 2 18 66 ~8 ~} ~6 06 16:13 16 72 16 33 ~5 ~8 28 9287 1~'~,()9 17,56 19 23 lB.4(.) ~8,03 15,9(; t5)55 16,55 ~5 34 16,55 30 9286 ~.7~66 17;86 1~ 99 17'59 t8;22 14.90 15'74 15:.99 15 29 16"~0 30 9~5 ]9,38 17~70 ~ 60 17,~2 ~.7~'9 !4.80 i5~09 15.24 14 69 14,94 31. ~}28f 16,~.6 ~6,?1 17 ~g ]6,69 1.7'2~ 1'4~4.9 15,24 14.)64 14.3! 14,23 34. 9282 lo,sa 17.78 15.~7 ~5~ 28 1$,20 40~ {)2of ~0.50 1..q,77 19 88 20,,I. 1 ~(),41 i7,63 i~,22 16..84 !7 36 16,5] 48 9280 21,~5 '19,~4: 2~.34 21,~6 20;:8.1 17,66 17,97 17~.87 17 53 17,66 ~579 ]~,2~ 17,'7! ~i,~5 lr~,{o 17'66 15,72 16,.13 15..~6 16.42 16,00 33 9.27~ 16,48 17,22 ~7':92 18,50 16,89 ~5,11 15,6~ 15:;04 15.38 15'57 33 {)277 17;4.7 1'.8;2~ i~,6~ i8,{J;Jl 17;64 i6.34 16;92 15,88 16.02 16,55 47 9976 21.09 20~22 22,38:2~;70 ~0 ; 80 '19", 39 :18 ,'72 18'42 18.30 1~;28 9275 ~2,30 1~,:~5 22~6 ~2~?()2:1.,94 19,1.6 18~45 19,18 18.52 17,94 45 9~7~ ]'~91 19~1~ 19~84 ~0,I6 19'63 ~7,36 17~52 17,57 17,gl. ~6,84 48 9273 lo.63 20,0~ 1. 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")9 18 60 15 73 15 44 15 66 15,59 15,78 45 9208 1,'~ 31 1[;..'18 1. q,¢1 18., . , 9207 10.36 18.8.4 19.48 19,78 19.68 16.25 15 '71 15,95 16,44 16,22 45 920b 17,17 17,75 lq.63 18.53 18,14 15,32 15.19 15.35 15.88 15,69 43 9205 17.4~ ~7,89 18,41 18,05 17,30 15.39 15,20 15.10 15.47 15,59 ~04 lq 3] lo 78 ?,9.06 19,~9 lq,lO 16,70 17.00 16.25 16.42 16.97 39:1 53 9203 '2~1] 10~53 19.66 l~.O1 18.80 16.48 16,41 16.75 16.97 17 08 34.8 50 0202 ~9,70 lq 92 , 2n.41 20.28 1.8,52 16,83 17,28 17,28 17,41 17 21 34.8 50 9201 20,50 20.39 21.45 20.45 20,31 16,97 17,17 17,47 17.17 ~6 ql ]6 7 56 0199 !7.96 17.14 17,~1 1.7,88 17,53 14'85 14.~2 15.25 15.23 ~5 11 37:1 56 9198 17,06 16.7o 16.t9 17,41 17,2~ 14,45 14,]6 13.99 14,64 14 43 .3~ 2 57 0197 17.39 17.70 1.6.50 17,31 18,17 15,34 15,]4 14,3~ 14,63 1.4.~6 40.7 55.4 56,9 75,4 78.4 1~.~4 15,4~ 5 60 7 68.4 77,4 79,9 19 21 0 58 0 69,6 71,7 79,4 18 08 15.48 0546 60,2 66.4 74,4 17 84 15,37 6 58,3 66,4 76,9 19.24 16,54 4 56.1 68.1 76,6 19 37 16,75 8 58,6 63,4 72,4 19 81 17,10 8 60,7 65,4 67 ~ 20 43 17,~7 8 59,4 78,6 79 17 71 14, 4 61,6 68,4 75 17 02 14, 4 3 58,6 68.4 72.1 17 41 14,89 ,,ol PASS2 P ....... 3 P~SS ASS5 PASS1. PASS2 P~SS3 PASS4 PASS5 AVE, o~G~A SI(,~A ,.>I~.~A SI, G~,A 8!G~A SI.G~A SIGMA SIGkA S'IG~,A SIGMA GR GR GR GP GR 8~G~ SIGMA 7 CU CU C[, C CU CU CO C ) CO CU GAPI GAPI GAPI GAPI GAPI CU CU ~)lq5 17 ~:.~ 1.7,44..17 R9 1'7,81. 1 : ¢'~ 14 85 14 96 14 ~6 14 34 15 11 41 2 5~ 9193 .1795~517,01,8.0~.. 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IR,64 71 15 23 1.4 14 92 ,23 14 4.5 14 41 15 ?7 14 5 B 4,2 55 43 4.4 42 99 42 97 37 52 40 41 38 I1 37 ~6 ~ 54 56 52 6 51 6 ~9 2 43 14,89 40 84 14,68 39 3.3 14.27 34 5 50 52 1.6 00 36 5 49. 27 17 34 34 7 46 17 19 33 35 7 44 O0 18 92 39 6 51 6 59 8 65 6 74 6 74 I 68 66 7 7~ 8 65 73: ,8 6.9 8 53 ? 67 6 56:,t 69 2 61 6 70 3 60 8 73 9 64 8 68 4 61 6 72 9 74 3 76 6 74 9172 21.94 21 9171. 1.~,23 1.8 94 1~,~o 18,48 1o 34, 1.6.28 16 4.2 1.6,42 1,6 0() 16 58 45 9 57 9170 1c),I4 1..f~181 19,09 17,77 20:25 16.,59 16 05 16,34 15 8~ 16 t. 9 47 3 53 . .. '.. , 0 43 2 52 ql, 6g 1.'),23 1R,73 19,58 1~,27 !q,35 16,33 16 35 1.6,75 15 74 15,{61) 91.68 17,94 1~,56 IS,O8 17,67 17,66 15,03 15 36 15,59 14 95 42 2 57 q 1, 6,7 17.B~ 5 ~6,56 14.88 ~4 51 14.61 14,55 17'97 17 53 15 74 15 O0 15'13 14 53 15,41 53 3 66 9166 17,47 17,63 17,20 16,. ., · · 6165 ~"~ ~4 1.~: ]5 19 41 18 95 20 21 17 13 16 52 17 08 16:34 16,~7 53 9 66 ...... ~ .... ~ ~ S ~ ~ · , ~164 19,38 20,06 20,61 1Q,86 19,55 17,14 17 13 1.6,75 16,22 16,14 44,0 58 63,3 75 g 76 68.9 78,4 63.4 67,4 70 64.2 70.1 74 76:6 83,9 82, 84.2 91 7 90.5 67,9 75:9 78.1 79.4 ,79 72 16,16 1.9 16,04 4 15,32 I]6 14,68 19 1.4,74 85 16.39 03 16,73 04 ~6.29 42 16,50 [ .,44 .5~ ,23 ,OC ,3E .6~ ,6f 9163. lq, !4 1~.,27 1a...O0 la. ,86 19,04 1~,45. I6 91.62 20,00 1,0,05 lq 4:8 20,27 19,36 16,48 16,37 1.6 73 916!. 1.9,45 19,01 I~:16 18,92 18,Rh 1,6,08 !6,63 15190 9160 19,30 18,21 18.13 18.77 1R.74 16.97 15,92 15,77 9159 ~9.d8 19,75 ~0,59 lq.55 19 04 16,30 16,64 9158 1~,05 lg. O0 !8,61 18.31 181~0 15.38 15,50 15 69 15.22 14 q157 17.~,1 17.00 17,~1 17,39 16,-3 14,69 1a.,58 14~67 141,51 14 i8 40 ~156 17,08 18,52 17.33 1.7,13 17.~2 14,91 14 35 14.45 15,59 14 23 53 -' 18.97 21.23 16.52 17 59 16.64 16.75 17 15 67 9155 20,70 22 28 19,17 9154 25.217 24~80 24.13 24.72 25,50 20,89 21 00 20 17 19,45 20 85 79 9153 27,72 2~ O0 27 98 27 33 27,52 24, 67 23 66 23:31 24,08 23 94 87 q152 28,70 29~75 29119 2q173 29,30 26113 26 39 26,1'6 27,03 25 ~1 88 9151 27,72 27.02 28,58 2~,33 27,26 22.95 23 ~4 24,13 25,09 24 02 66 9150 2~.53 22.73 22,81 23,59 22.68 21,05 19,70 19,81 20,89 20 13 57 08 16.47 16,()6 16.30 44.5 54 4 61.2 68.6 40 0 50.6 59,0 69.4 78.~ 19 42 16 77 15 16,94 16 50 16,75 15~75 34;6 46 8 63.1 76.4 15.98 37~1 50 1 60.2 74.4 9 4 57.9 69,1 7 59,4 68 2 8 60.7 71:9 I 71,7 84.6 1 93,1 9g.l 4 101.4 110,2 0 116,9 116,3 6 121,9 118,7 0 98,4 106,6 6 78,9 100.2 15,93 16,33 16,39 1.6 58 37 49 68 39 4 45 1 51 9 69 9 102 1 110 1 103 1 81 4 78 91 15 109 7 2 70 19 114,6 26 89 22 129.1 28 81 26 129,3 28 90 25 112,0 2469 21 94,3 22 39 19 PASS3 PASS4 PASS5 PA$SI PASS2 SIGMA SIGMA SIGMA GR GR FAR F~P FAR CU CU Ct) GAPI GAPI 91,49 2~,45 23 9188 2'2~83 24 9!47 20.00 21 9146 22,13 24 914,5 24.67 24 O144 19 67 9 9143 9 9111 20,41 20 19.~3 i9 9139 1~,47 . 9138 1.7~73 19 q137 20.61 20 91.36 19, 9135 17. 7t. 9 ~ 32 91'tl 17.0B 17 9130 17,08 16 ql~9 ~'7.~1 17 91.28 17,42 17 9127 91~6 1 ql~5 o.97 17 9!24 0121 17,81, 17 o120 911q 20.19 20 9~,~8 9! 1.~ allO I~.P8 17 9!09 I 7. 47 !7 Oln6 !7. 30 9!~4 ~.~. 13 2'3 0 (" ~ ) 22 27 20 36 23 69 2,4 00 19 27 1~ , '20 I q 03 2~,52 21,72 20 2. 22,8~ 21, 91 1.9 0:3 19~05 20 0:1 17 :0 I°,72 22 23 2! 8:22,78 23 80 ~0 38 19,50 19 53 ~7 36.18,52.:]8 1:6 ,94 1:9.97 19 ~5 ~ 0 ' · . 6'7 17' :.71 ' 1,:.,,18 ~.2,16 17,11 8 1~,09 17.61 1:7,49 '~4 I~,00 17,70 17,59 ~ , ,gl. 16,.q4. 1..7,00 16, .1~ 17,83 17,99 17.37 .~9 18,66 18,41 1.7,93 15 .51 la.S3 18.52 17,76 15 15 la,33 17.63 1~,52 15 'gB 17 ~5 16 go 1~,15 14 ,99 !.a.g6 !7,!2 1.7,33 !.a .45 ~8,33 19,05 18.06 16 ,56 I~,60 19,70 10,79 ~6 ,53 !a,17 1.7,95 18,35 15 .48 la.~9 1.~.RO 17,37 !4 ,~4 !0,79 !.o,~9 18,51 16 .O~ pa ~7 2° 71 20 09 17 .75 2c, 27.. e:TS o294 iV ,30 !~i,59 !9,59 lO.46 ,47 la,33 18,73 18,04 ,33 17.~3 1~,o7 !a,09 ,14 }.g,~4 l~.gO 17,97 ,53 10.77 !q.66 1~.53 .5$ 2!.)1 2P.O7 20.~6 .55 1~,73 lm.K6 !.~.~ .59 ~7..~ ~7.g0 17.~? !.P,O9 19,~3 !7.~9 17 74 17 g? !7.1'l 17 ~5 20,34 17.90 !O.P7 ,86 1q,.81 1 ~12 I~,81 19,, 02 2i' 92 1,9 98 18,72 17. 78 1 28 22,03 20,02 1. 8~ 20~91 21. 05:19 83 18,03 17 55 ~. 7 33 87 39 ,.41 °97 °44 1~,6l 17,0~ 15.59 15.93 17.99 15.7~ !5.77 15.55 t5.35 1.6.73 77 16 61 1.6 34' .02 .86 .17 22 O7 21 8O 53 t7 76 31 15,17 1,4 · 67 1~.42 · 15,91 15 ~ t~'"' ...,97 15 ag , 17,7~ 1~,1.1 17.03 15,9~ 16,84 !6,9!. 16,17 16.B3 !7,n2 1.5,21 1~,44 16,22 15.~o !a,9o 14,39 15,47 1.7,24 15 16 17 15, 15,1.1 I,.4,,; 90 14,90 t4,50 15,6(.) t5,94 1.5,32 15,25 15.1,0 15.87 16,79 15,55 14'60 1~,~4 17.~8 16.59 16,¢6 16,15 15.9"/ 17 24 17:73 1~,09 15.70 .!6.36 15,33 14,54 15.14 1.5,71 16,62 34 17 11 17. 4,4 1,6, 39 14. 08 14 34 16 75 1,6 59 15 15 15 14,35 14,45 15,21 16,17 ~.6,09 15,14 !5.04 ~4,87 96 15, 15,30 !5,39 17,06 !B,96 1.5,87 15.89 16,5~ !6,83 ~7,83 17.72 15.84 15,41 i6.~7 15,~0 15,00 15,46 I6,97 13 18 33 17 52 18 39 19 5b 17 27 16 :50 15 ~3 15 97 1'~ 75 1. 50 49 3~ 14 5O 96 88 59 95 95 67 24 64 ~36 17 02 1.5.45 14,98 14 83 14 69 15 14 15 43 14 57 15,71 17,60 ~5.26 16,69 ~,33 ~7 91 16~59 15,94. 16 48 17~95 ~.R,76 14.74 !6 38 14:6~ !4.79 74 6 4:1 5O 44 ~0 ~2 40 8 40,7 41,2 42,5 46,0 41,4 37.0 42~7 39 ! 38:9 40.3 43.5 4~.0 51 .3 45.~ 41,5 58.! 64,4 75 9 96 4 68 ~ $0 7 55 ! 51 9 52 ~ 49 8 53~1 5O 4 53,4 51,B 53.9 59.7 ~6:8 48.6 ~9.9 50.3 50.,7 54.4 58,3 60.3 ~2.3 70.1 ~6.9 54.2 58,1 60.3 73.0 73.~ PASS3 PASS4 PASS5 G~ GR GR GAPIGAPI GAPI 85,8 107 84,1 100 75,9 96 104. t 119 83 0 97 60 0 73 67 9 71 6 80 68 75 63 0 66 2 ~8 9 61 59 0 69 0 62,5 62.6 60,6 60.6 64,2 63,7 66,2 73,6 68.8 80,4 85,6 80,6 79,9 76,6 73,9 76,1 74,9 73,3 74,8 76,9 7~,1 8 ,1 71,4 66,1 6a,4 72,9 78.2 73'~ 76,9 80.7 78,1. 1 106.1 4 100.8 9 91,7 8 119,6 0 I00.5 7 79,9 7 82.9 ~8 80 79 78 7] 76 77 79 78 77 77 74 74~ 86,4 77. 81.3 ~5.~ 84.1 $IG,.~A NEAR CU IVE. IGMA FAR CU 77 19 64 18 O0 19 6 20 11 15 8 80 15 35 14 77 14 23 14 89 19 O4 7] 78 69 05 97 74 O1 11 98 ~9 0 1.5 75 15 35 15 O! 14 7I !5 52 16 67 63.0 60,9 63.9 65,1 63,5 68,4 71.6 7~ 1 79:3 73.5 65.4 66.5 6q.7 78.5 ~0,3 76,~. 70,9 71.7 74.3 76.4 78.0 77,8 70,4 90,0 03,6 69,6 73,6 73.6 81,7 94.1 6,1 95 18.28 20 33 17.47 ,0,6 18.83 16,55 78i! 18,30 la.so 79.0,o....48 17 36 83,418.34 15 56 ~4.a 18.~5 15 97 a6 17,77 15,20 77i~ 7.74 14,99 70 1.~ 34 15,50 86 ~.9~00 !5,9t 00.7 ~0 36 17 03 94.1. 191~3 16169 006~ ~:~9 ~:~ 2~,~1 }8,67 2~.:.:39 ~6.'11 25 83 ~8,08 .26:.42 26,83 129,6 154 3 1.5~.3 175"9 167..6 36 23 9 140,9 154,3 164,9 ~0~ i~'~ i~:'~ i~:;:~:2~ ':87 24,51 25;94 25.98 146.9 165 g t59.4 174,4 18:0,'8 88 00~6 ~.~,2~ ~7,~1 ~a,t9 ~g,66 ~9:,92 25,00 25 51 2&,~.l 24,2~ 25,22 i35,5 145.1 155.2 17J.,8 169...9 .11 2l gOp~ 6~ ~ '~S'8~ ~ :~9 ~a 48 ~6 ~ ~_~6 22,ag 23,6~ 22.23 22,72 137,9 1.48 3 159.7 174.4 168,6 33 21 o0~4 ~4.o8 ~4,S4 24'46 2~.03 25"31 20,:75 20,80 21.75 20.7~ 20,28 13~.4 143;3 162:,0 ~70.9 173~ 83 ~3 .......... . ................ ~' ~ .... ~ 'o 50 '1o '~4 ~ 14 i~ ~8 19 it 90~3 21.66 22,13 21,7.. 21. ..... 2 22, ..... 1 .... , ........ ,.., !... ...... , ...... · ..... 90~ 2~.38 23;}~1 2J.,~1 23,.31 23.05 20,72 ~!.,6}] 1~,82 19,05 20-72 90~1 ~5.~0 2~.~6 2S~o ~9..34 ~o~17 ~5,08 24,7~ 23,46 23,8~ 25,08 178.5 201,5 203,8 ~27,4 221,7 3 74 32 0079 ~0,55 '~0,72 3o,4s 3n,67 2~,P6 26,92 27,~} 26,95 ~9,~ ;If,t~ ~:2.: 320,2 299.4 316,8 307,3 ~ 18 3~ ~07~ ~i.~ ~.'~1 ~;~.~ '~i~8 3~78 2~,69 2~,67 27.~5 29,ll 29,0o 377,~ 375,9 371.5 40~,3 405,3 ~5 ~3 34 of)!~ 3~,~i 3~,~ 3%,.45 ~.~$ ~2,59 30,0~ 31.,91 29.73 31,56 30,31 383.3 ] .4s 29;85 33,78 31.8o 431.0 408.3 437.4 450,8 472.0 ~5,11 34 ~075 34.94 35.~2 35,00 35 ~ 34,69 34.4J 34,~ 33,~6 35,3a 34 72 308 0 304.2 353.8 ~22,3 360.5 35,09 34 6074 3~.dl 34..62 35,16 35~69 35.28 34"72 34,04 34.66 35,41 34:7~ 266.~8 285"3 293.2 294.0 307,0 ~5.22 34 0072 34.~1 35.19 3~:'7~ 35.48 35.34 34:34 35,31 34.47 34.95 34.59 ~75.3 2~7.6 292.0 301.0 310. 35 13 33 0071 35.i9 35 16 3~,~5 3~..81 35.9a 35.31 34.48 34 38 35.61 34 84 279. 8 294,4 28~.0 30~.5 306.5 35;16 34 ~ ~070 35.03 3~30 3i,75 3ao37 35,09 34,13 35 02 ~3169 35.$7 3~ 97 3o51o ]19.7 3!4.s 326.5 330.3 35.91 35 o0~9 3%o!6 35.01 34,s~ 35.69 34,7~ 33,19 33:72 3~..!6 34.63 33 oo 320.5 356.1 339°3 363.8 371.5 36.77 36 62 ~0~ ,~,.~4 35.66 35.49 3~.72 35,75 3~,66 32,59 33,01 34,03 33 16 399.5 448.6 405 , 442.5 446.3 i~' 21 37 ~I ~067 3~ ql 35.68 35,49 34,31 3~ R9 33 00 3~,94 39,5~ 33,?~ 33 16 559.5 566i~ 537:0 577,0 565.~ 151 37 qOa6 3~:03 36.05 34.97 3a.~9 3~ 34[59 3~.59 33.44 34.25 34 09 474.8 469 3 533.5 500.5 552, 36,45 36,32 9065 36,94 37 21 35,3~ 36.03 35,75 37 79 36 O1 37,04 37.44 37 47 ~R6.~ 2O4.1 349.6 317,8 35~ 3 ~; ~0 35,22 ~0~4 3~i.3~ 3R:41 3R.89 ~6.~8 37.7~ 3~[31 3~ ~4 3~.09 39.$~ 41 22 191.0 201.3 23~,3 230.4 2~8:6 :24 35.3~ 0063 3~ 13 37,31 37.3~ 37 ~6 37,56 39.2P 37 ~ 3~ 66 3~.~9 40,50 175 1 190 5 206.7 ~0~,3 224.~ ~4,95 34,05 ~06~ 37~5 36,56 36,a4 37~31 37.00 35.59 35 19 37~a0 3~.25 37.25 i67:1 1~1:5 ~9,3 197,$ 215.1 34.76 33,58 ~061 34o5~)35,~5 3~,5~ 35.69 36.44 35.47 35 50 36.71 35.69 35.47 159.3 ~74 9 ~,~ 1.~7.0 ~03.3 35.18 34,17 9060 3K.16 3~.~.9~ 3~.,79 35o34 35,~2 35.06 34 96 35,&9 34,7~ 34.31 146.4 169~ 17~.5 175,] 182.9 34,6R 32,90 ~O~q 34.~a '~3.6& 3t.,54 3~.3a 33.°~ 3a.~6 39 ~l 3~,~0 34,09 3~,6~ 13~.9 156.~ 16R.~ 163,3 169.9 37.79 31.~9 qO~P 35.47 3~,51 3~,93 35.59 35.~~ 34,50 33:~2 37,65 3~,3~. 33.99 123.7 134..~ 152.6 155,8 15~,4 29,66 27,4~ ~57 36.9~ 35,?3 35.1& 35.4i 3~ 9~ 33,19 33.54 33.0~ 3~ 63 32.5! 102.7 114,9 133.3 ~38.9 ~46.8 27,14 74,i ~656 37.53 37.41. 32.3i 3~.06 3~:9i. 30.45 30°74 3n.75 2~75 2R.32 91.0 !t2.4 118.3 ~29.a ~30.~ 25.39 22, ~ 0055 2~:~.39 9054 25,72 ~0~3 ?S, 36 9050 23,59 ~0~9 2~,95 90~7 25.33 90~6 ~9. ~ 6 90a4 3a, 3~ 9042 26,05 q040 25,36 0039 24'.~4' 9038 25,4~ 0n.37 76.31 ~036 ~,3~ .035 ,4,~ 9034 ~5.78 9033 ~, ~1 9032 25,27 0031 25, ~0 9030 25, ¢1 ~02~ ~5.75 0028 2~ 25 0025 26.34 0024 27.45 ao23 30.17 9021 27.q~ 0020 32. o, ~0~9 37.09 o0~8 3~.34 o0~ 7 39. ~4 90~6 37.75 00~ 5 37.2~ ~0~ 4 37. n3 ~0~ 3 37.50 ~0!2 37. a! a051 3n,Oq 90!0 37.~7 oOOq 37,5R 29,'!0 27 Ii 24 ~ 23 4} 2,1, 23 73 25 9t 32,7~ 2B.59 25.36 25,33 'S 80 25~]0 ?6.77 26, 25.56 24. 51, 25.3.4 25.~4 25.75 ~7,~ ~7.~ 33.38 37.~7 37,94 38,13 37.~7 37.n~ 39.63 26,,44 25,84 26,~0 23 ~'~0 24. 2..~.84 25,41. 25,' 30 21 94:22 23,90 23,56 23,94 20 ~8 2o 23,27 2~,25:22'55 20 oo 20 2.3,r. 5 3.55 22.86 1,9 13 20 9~.,.45 ...3.07 23'R:3 20; 77 20 "'a,90 23,75 23,7a 21. 28 20 ~ ..~ 68 26, 39 23 97 20 ~6 20 2:~ 20 ~0 20 84, 21 36 25,81 25,,10 77 23,05 22.,~ 14 22,17 2i, .... ,99 20,69 ~0,95 ,36 19,08 28 ~8,95 19.03 87 120,06. 9,85 81.. 19,00 20,17 5521,t7 22,71 84.1. 72 67 ~ 69~ 63, 89 139 2'7,60 29.06 29,54 25 ~a 26 59 24 5.3 25,al 26,19 255 35,17 .3.~,47 33,50 31 3n gO 32 q5 ,41 3~,74 30i79 29,!.4 29,29 27 . 25 97 2~ ~,3 ,34 26.70 ~Z,'?() 27,.06 26,59 23 86 23 14 ~5,05 73.92 23,"0 84. _~ -.. ~ 24.50 25.46 22 34 2~ 52 23, 23 22,75 22og7 80 ~,!4 ~,4.27 25.6t 21.69 . ... 22. 21.,08 22.18 76, 25,51 25.77 25,70. 22,75~ 23,92 22o7~ 22,58 22,66 2~,4~ 26,!7 25 84 23, ....2 23,13 22,63 2~,~0 27,50 6 25,93 25,20 25,5o 22,~8 22,n~ 21,92 ~,41 21,87 78, 2~,75 25.6] 2S.37 23,98 22.41 2~,13 ~z,63 2!.,79 79, ~5,~6 25.52 25.40 22.o~ 22,25 2!,92 2~,59 22,26 69 26,57 25.60 26,35 22.23 22,46 21.93 22,23 22+90 71: ~7,10 ~6.39 ~5 ~ 29 70 2~ 67 22,~4 ~1 O~ ~,gl 78 2~ 04 ' ~ ''' ' ' ' ' , 2~..~0 25.29 22:66 22.15 21.88 22,47 21,88 25,~S 26.n0 25.44 22.,6~ 22.54 2~,.~7 22 ]4 22 11 2~.6'6 25.01 25'39 22.23 22,07 22.,4~ 2J:g4 2J,:77 101. 20.92 21. 56 2~.57 2~ 48 ~2~38 2~,81 23 6& 2~i55 23.~6 26 41. 27 4.1 25.~2 24 67 2~ 55 25 19 24:53 24,69 30,36 2q'!.9 2~.75 37,00 36,94 3~,05 35,?] 40,3~ 3g,78 37,77 3P.09 40,22 38,78 30,89 37.63 38.31 3~.~8 38.n5 3~.75 3P.&3 38.07 39.1.3 40.~9 39.54 3n.5~ 30,00 3e 66 30 3° g~ 3P,~1 3~:$3 40' ,,.,., °50 3°.09 37,~ 3o;6~ 3~.15 3g.72 40.~5 40,~0 25,36 24.51 26,a8 26.06 26.14 ?~,43 29.~2 2~.9~ 2~.6! 27.~2 27.53 2o,~3 34.70 35.37 37.7~ 37,89 37.~.5 3~,7~ 37.73 37.]g 3P,70 37.~9 3o.!7 3P.~7 39,n7 39.06 3~,06 3~.75 3o,m3 3~.al 39.3! 3~.30 25.58 26.62 27.7~ 30.24 3!i~9 36 2~ 21,3a 22,50 19!. 22.39 22.93 266. 2~,1,! 23.07 293. 25,Rg 26.49 25.17 2~.03 135. 24,,44 24.95 186, 30.94 27.99 2B4. 36,60 35,38 214. 37,48 3~.52 135. 37.20 38.44 118. 37,57 3~.12 3~.2~ 37.70 3~.69 39:~.0 ~.~4 30.o3 3~.5~ 3g,09 110. 3~.59 3R.91 100. 1,03,3 113.,9 125,3 I22,6 24,57 21 P7,~ 104.~ ~06.4 111,.6 2,3.55 20 85, i00. 04,6 116,5 23,22 19 24o~5 20 4 79,~ 90, 30 3 ! 273 2~5.3 68 31 4,7 313 0 171 I ~23,4 125 4 147 40. 93 91. ~ 86 81 4 197 1 05 94 5 106 95 9 1Ol,5 98 7 t00,0 g4~l 3.8 97,5 97,9 2 95 6 117 95 9 ~3.3.~ !23.3 118 6 ~16.~ 138.5 202 8 ~70.4 220.8 272 8 257,9 299.8 2~3 7 303 8 306.0 227 7 275:9 237,4 152.~ ~02.7 166.1 130.3 345,6 153.B 133,1 la.O,5 !52,3 137,1 la~7,4 151.3 130,0 ~a3,6 i5~.3 127.4 143,0 ~39.4 121,5 138.6 139.9 115,6 130,0 140,9 111.5 1~7,1 137.3 209, 149;~ 27 25 123,~ 25 109. 25 ~08 25 25 44 57 64 93 39 51 97 07 74 23 3.0 31, 22 3~ 22 4t 5 ~ ~ O1 22 22 2~ 26 7 33,70 38'al 37,. 3~ n5 2~7. ]~,10 3~,03 2~3.0 38,17 39,63 166 ~ 3~.54 39 ~ is6:.. 3~,so 39 i6o.~ 3,.~9 39 i~ ~45, 38,34 40 i45.5 39.01. 39 67 146.4 39.25 39 5~ ~42.0 3~.96 39 59 134.6 38.~8 39: 116.~ 26 117: 25 11.8,1 25 105, 25 54 lO8.2 25 40 104,0 25 56 106,: 26 4 31.3. ~ 2~ 04 l~s:~ 29 04 ~25 27.57 20!.~ 35,71 286. 37,74 323. 37,0 263 ~ ,6 . 37.6~ 190.4 37,52 ;TpT~4 9008 3~. 19 3g,'17 0007 3~ ]3 39~46 9005 37, .... O004 3g.53 3~. ~0~3 oOO~ 3~.06 1~.7~ gO01 3~, 66 o000 ~99~ PASS.4 PASS5 PASS]· PASS2 CLI CU GADI GADI 39,34 38.75 38.47 40,Og 39,a7 3g.16 3g 37.56 3~,"1~ 38,70 39,66 39.~4, 4n.O0~]?~.~ 41. 3~,]9 3o.06 3~.g3 40.~3 4().14 39.94 3a;56. 40.63 §9,30 3...,o 56 40'.~I, 39'..09 30 5C)4(') ~0'72 39,~5 3~,71 40~41 3~,78 ~..72 41 ~2 3,- ~,.~4 ..... 3..., 3~,~, 3~.,:~, :....~.~o ~..~ ~.o:,4 Io ' 3~.97 40 3g.~ 40 2 3 ,40 ,~ 2 5 30 g 7 3 ~4 59 86,.7 1,00 83.2 99 86 2 9i 84. 9. Rg,~ 99. 94. 06. 87.3 03. ~ 3 ,. 4 04,, 4, 103, 84.6 o7. 7 112.I 118,9 i24,"2 39,:17 39,~7: 3 110,0 !17,! 122.1 39,~9 40,1!5 110,3 ~i2.6 I25.0 39.34 105.6 121 0 13i,0 ~,.16 4(),li5 ~,~2.6 1~9~8 136.0 9~24 40,~9 i1227 i, 30.,:4l~l.e 9,.ov 1 114,8 124 ~ 130,3 ~,~4 40,1~7 ~:13,7 I26 ~ 1~5,3 8,77 ~ i13,9 ~.~3 4 1.20,4 8,55 ~ !07.l 127 0 125,9 8.89 39~6 ~ ].09.9 12~. 6 1~8.9 ~,94 39,,54 {07.~ 19~ 9 125~4 8:.97 40,[9 ]NFDR~AYION RF'CF'IDDS ** **' T~E~'ORO TYPF 137 ** ** P,~:COP, D TYPF 04'/ ** UNIT TYPE CATE SIZE CODE 000 000 016 065 000 000 006 065 000 000 0~2 065 000 000 004 065 000 000 004 065 000 000 002 065 0~0 000 008 0~5 000 000 On6 065 OhO 000 004 065 HNTT TYPE CATE $IME CODE 000 000 oe7 065 Cr)M~E~TS ** ** R~CO[~D TYPF, 047 ** ** ~ECJRD TYP~ 04.7 ** SCHI,~,MBE G~,,R * AbASKA C'OMPUT~NG CENTER * ******************************************************************************** ~PANY = A~bANTIC RICHFIMbD 'Lb = DS 13-34 Mb~ = PRU~HOE BA'¥ tl,Y,NTY = NORTH SYi,,OPE BOROUGH 'ATM = .ALASK~ i~ NU~B.F:R AT ACC: 6~197 IN ~N'/A, ~ATE bOC;GEr~ 2! AP~ ~4 ~SING = 20,000" SURFACE TO 120" ~$I[,!G = I~.37~.' SURFACE TO ~SIWG = 9.6~50" SURFACE TO 89~3' ~SIHG = 7.000" 8709' TO 9523 FLUID = CRUDE OTb ******************************************************************************* PASS~ TD~ ON F~Et, D PRI~tT I.~ ~ FE~T OFF D~PTH ~TH ITS OW~ GA~A RAY, * P 010.H0~ VERIFIC,ATION [..,TSTING PA~E 3 ~) A[~ P~SS2 DA,f~,~H~FTED TO DRY R0N GR USING PA.$$2 4) ALL PA$S[(EXC~T ~R), ,A~tD PA$$3 THRU PASS6 DATA SHIFTFD TO PASS~ TDT DATA [NVAbiD 9480' TO 9387' (SEE FIEI.D PRINT~ * P~4 ?D? DATA INVALID 9104' TO 90:88' (SEE FIELD PRINT) * * THERMAL DECAY TIME (TDT - ~ PASSES) GA~M,A ~AY LO~ TYPE SIZE REPR CODE E~!TRY 4 i 66 1 8 4 73 ~0 9 4 65 .t~N 0 I. 66 0 ~? 0 0 0 0 0 4 PSi CU 0 40 1 0 0 ,4 PS,, CU 0 0 0 0 0 4 PS1 0 42 I 0 0 4 PS,. ~AP! 0 31 0 0 ~ PS1, CPS 0 0 0 0 0 4 PSi CPS 0 0 0 0 0 ~ PS' CPS 0 0 0 0 0 o o oo o 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 0 1 ! 1 1 ! ! ! ! ! 1 ! 1 ! ! ! t ! ! ! ! ! ! ODE ~8 P 010.~02 VE~IF.ICATION i,T$?ING PAGE 5 'DT p$5 CP~ 0 P$~ 0 :~T P:S6 0 P~6 GAPI 0 ,¢:K PS:6 CPS 0 ,AC P$6 CPS 0 'D? PS$ CPS 0 'DT PS6 CPS 0 ~E~ ~AP! 0 0 0 0 0 0 4~ 31 0 0 0 0 :¸PT 9483 -999: *999 -'99:9 -999 -999 '999 ,,999 -999 '099 "999 0000 2500 BACK 2500 ~50:0 BACK 2500 2500 ~ACK 500 ~ACK 500 '999,2500 ~999:i2500 -999,2500 '999.2500 ~999;2:500 -999.2500 ~999;:2500 -999.2500 ~999;2500 -999;2500 ~999,2500 -999~500 :PT 'DT ,DT 'DT 94 .I I 1 t 0O 28 38 4.t 77 6! 63 69 96 85 83 99 5938 RACK. 7500 SlG~ 8750 BACK ~563 ~ACK 2500 S~M 9927 BACK 3438 SIG~ 750 8ACK 750 ~ ~658 RA~K 0313 ~ 1.65 19 2O6 20 22'/ 19 ?,25 19 230 16 4319 5000 1625 1250 5469 8750 5273 7891 ~313 :PT :r~T 9300 49 190 65 189 188 90 183 1953 BACK 6250 2500 BACK 3750 ,5000 SIG~ ,68~5 BACK .2500 42 89 223, 4.1, 1250 4375 3643 7500 9687 1250 5313 8750 12~3 0 0 0 0 ! 0 0 0 0 0 F$~G FS~G F'BAC PS G PBAc ~BAC PSI:G PBAC FBAC rBAC FS~G FBAC rBAC PBAC FBAC rBAC rBaC ~BAC P$~G PSTG 0 0 0 0 0 0 0 0 0 0 0 0 0 4 4 4 4 " NTD!T -9 ?RAt :~:9'99 N~DT -999 -999. ~00 ?RAT '999~ NTDT -999.. TROT -999:,~500 NTDT -999~$00 14,0625 76.6 7 17,1~653 84,8672 17.~6~6 38,4588 41.~000 3 . 25O 86,4375 37,0938 9.1.9375 36.4814 TROT NTDT TRAT NTDT TROT NTDT TRAT NTDT TRRT NTDT ?RAT NTDT TRAT NTDT TRAT NTDT TRAT NTDT TRAT NTDT TRAT '999, '9! ~.9q ~999 .999 0999 68 68 68 68 se? oo0o ?~?~00 21) 5000 60?6 241 031.3 5469 215' O0 0 25~ OOt6 1.05 ~448 RACK !',I! 17~ l l 230,5000 42,0938 43,59~8 PT 9~00 DT ~97 DT 6~ DT 310 80 OT 300 94 DT 300 I03 DT .0000 $IC~ ,5352 ~ACK ~5 SIG,~ 17{9 2500 BACK ~5n0 0625 BACK 7500 6250 BACK 4688 SIaM 8125 BACK 50OO 20,2832 109.'2126 2~,1416 17~..0273 20,9531 ~13'5000 225,7500 20,~070 ~27~2363 19~5625 ~32'6250 24~453t PT 9100 8~ DT 125 97 OT 94 123 135 PT ~45 DT ~0~ 147 'DT 0000 SI~ ~500 ~ACK 3281. 3281 BACK 7500 8125 RACK ~500 7500 BACK ~250 Sl~ 5000 ~ACK 9:575 5000 ~ACK 0000 26,644 :{0,2109 1.98,0000 33,2813 ~18,8750 16.5625 ~28 5000 29 28! ~] 5OO 31 7500 m]~ 0000 5. 531~ 9035 -999 -999 -999 -999 -~9~ -999 ~999 999 'DT -999 ,0000 ,2500 BACK ,2500 ,2500 RACK ,~500 ,~500 RACK .~500 SI~ ,~500 RACK .2500 SI~M .~500 RACK ~500 :~500 RACK ,2500 -~99,~500 .99 ~500 -999 -999.~500 -999 2500 -u9o 2500 - 9 : soo -999,}~00 39,0313 :~VICF NA~E : ~TE : ** .001 !024 F,B ~ C FSYG rBAC FSTG rBAC rBAc FSYG FBAC FSYG FBAC FSYG FBRC FSIG FBA,C FBAC FSIG FB{C FSYG FBRC FSYG FBAC F$IG FBAC FB~C FBAC rSlO rB~C g~,.4570 3~.0938 94'6875 17.113.3 70,6406 18,3496 97.~56~ 17.28~ ~1[,8125 1 ,7227 1.~8'3750 13~ 'i719 ,1250 21.6563 95,~50 11~,4375 14.1406 114,2500 22,2344 116,5625 22,9844 12t,8125 -999.~500 -999.~500 -999.2500 -999,2500 -999,~500 -999.2500 -999.~500 -999.~500 -999.2500 -999.2500 -999,~500 TRAT: ?RAT MTDT TRAT NTDT TRAT NTDT TRAT NT~T TRAT NTDT TRAT ~TDT TRAT NTDT TRAT NTDT TRAT NTDT ?R~T NTDT ~XOX TRiT NTDT TROT NTDT TRAT NTDT TRAT MTDT TRAT NTDT TRIT NTDT WRAT HTDT ,6i25 24~, 9961 ~85,2:50'0 2.31.49 312. 2, 9 334 ~0 2 331 3t' 19 0000 6~67 i 230{750 4 6797 214 3750 4 621.1 ~92 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999,2500 -999.2500 7999,2500 999,~500 999,2500 P 010.H02 VEPIFICATIO, N,. LT,,S'q'"IhIG PAGE 7 Th.Pr ?Ra'Ir~E~ ** :RViC~ NAME TE 1,84/05/1.6 tGIN ~0000 :X.T T~P~ NAME :RVICM ~A:~E {~DTT ,TE INT~NUATION ~ :~T ~ET,~ NAME : ** PECORD TYPE 13,7 ** RECORD TYPR 137 ** EOF EOF DATF,, :82109/1.4 ORIG16i :i070 P R E S: [.~ J. [., 0 0 J E '.') 3 (,' V .,, R L ~ I C A T ',iCi M ~ T 1 1 1 1 1 1. 1, i t -4 Z SP N C ¢¢ L SP NCNL D E fa T SP OEPT GR SP N C ~ L NPIII DEP'[ SP GR N Ct,~ 1, NPni DEPT G~ -., .', 25(}[: 8g,18 7% t'l.; - 99 ¥. 250 ~. 3 9 d 20, ~¢3 ~ 3 :2,23 '~ 5 2.9,25oo O E.P. 8 '7 f) 0 S P -, 999 g R - 999 8P -999 GR -999 og C ~ L - 999 Npl-i I 4 '1 L)EPT SP r,~ C f,i b - 9 .... 9 a.. z."' 5 0 r,,, ,.r ,, -999,2530 -99.~. . ~,;~ ,:,4 9.5! 5, ~ c; '"2 -999.25,',r, -- 9 '? ":,. 2 5 ..)C, N P,t~.I *'"*:'~ 9 9 · ,,,'. 5 u t, DEPT $ P N C i:l SP N C N b SP N C PC 1., OEPT 8P GR NPHt D E ,~ T Sp GR DEFT SP N C r~! L) E:F1 $ P GR .* 9 '9 :'!~.: 5,) u ,-999 ,,'5:, - 9 !,'¢ :,~. 2 b !) 0 -999. -,.999.25t¢c: -999,25o¢ -9<~9. -999.2q )i) - 9 9 9. i,.i !:5 .i ~. ,,,, ,49 '::~, 25,' C' -:999' ,250(i '999. 2500 i'~'.,, r -99 4,2b,.}O ,.,990, - 9 '9 ':~. 25 u t, - 999 - 999 -999 -999. ZS,)u -999. -999. '.2.900 -999, - 9 9 ~-~. 2.5., -999. '999. 25')0 L'~ i'11111 i l ,Iq il.,_ [:-]: D E P T S P SP G~ DEPT SP N C b~ b D£PT SP GR OEDT SP NP~i 0 g P ~ GR D g P :.r NC:'a .L D E P T SP i'~C~i, 0 E, P 'I SP G ~ N C i.,,, t, - 9 9 :,~, 2 b ('.. ,5 R H 0 !3 - 9 9 9,2 5 L,'. :,, , ,~ i~ A i' , J~ ,-.999. 2500 -- "",.~ 9 9.2 5 2500 2500 ,.- '4 99.250 C' - 9 9 :.~. '2 5 t:, ,,.' N P H I, SP OEPT SP Gu NCN L SP GR DEP.T Sp GR $,p GR 8P NC~[., DEPT SP OEPT SP ,., 99 9 2 5 U 0 i.,~ i, i,,~ 0 ¢..,()0 0000 '4 .... ,-.r Ltl · s · -999,2bO~) f'C*~i ..... 7 1 . 3 8° 7 N~'.l ' 9 q 9 . 2 5 (.; u ~.: s: -99<.,, 2b('O t.'t' 4 3. t, F '? 5 ~ .- '.*. 9.0 5 b J . ,.,4 '.? '~. 25 ,,) :) ~',; i,'. 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'2¥uI: -!)99.2 t,u b, - 9' 9 9.2 L, i.:, ,,, DEPT SP -, 9 5~ '~. 2 .", (',1 T D~RECT ~'~. ~GITAL LOGGING COMPUTER PROCESSED ANALYS~S Comp.-~n.~,., ~RCO ALASKA IHC, Well OS 13-34 Fimld PRUDHOE BAY Count,,,: HORTH SLOPE St,.~stm ALASKA Count ry lJE;A CLIENT FORMAT OATA TAPE LOG I NF ORMA T I ON STANDARD F O R M A T ( L .~. I , S, ) Name: DS i~.-..4 T~PE RECORDS S.mrv i ce n.-."..,mm: HEADER RECORD®. o o.,,- ~4,-.~0 Origin: R,s'ml name: ,>[41'=",0 Conti;nuatior, #: O'i Coma.ants: Smr. vicm nature: "a. G5FO1 I..,~..mvious tapm: Date: 85/04/20 Origin: 'rape name: 281,920 Cor, tinuation ~: 0! F i i ,..-.., n .~.~ m e: ¢., G 5 F 0 1 , 0 0 1 M .a :,.'. i m u m I ,--. n g t h: i 0 2 4 H E A [)E R R E L. 0 R C, ,~=, Film t.~pm: LO Pr. mvi ou$ f'i M N E M CN WN FN C 0 UN STAT C TRY SEC]" T 0 I.d [.i R A i.4 G E k: B EOf-.' EGL PD LNF DMF RUN LC:C S 0 N L U N FL. LUL Eiq~ i I.d i T N DD DL. TLi BL.i TCS TL~B BHT NRT bi T N Y i S RN R i'i K NFST MFSS R bi C biCST NC SS I NFORMAT I ON RECORDS CONTEl-ITS UNIT TYPE CATG ARCO A : o -' . LR,.,I,, A INC DS i 3-'.34 PRUDHOE BAY NORTH SLOPE ........ A L A S K A ........ LoA ........ 14, i Of,1 i 4-F, 87 000 , 86 .O 0 O , .34 O'O 0 , SL I<B i<B .... ..-iLl 2e ,::,. 2 6 7542 NORTH SLOPE NORTH SLOPE ~RNOLD F~USETT ...... 9500, OOO 8990 , 000 .................. , . imIlimaIiiIlllilllliiiil~IdlttmiiIIt llelIlll* IllilllallllI Illllllll IIIIlalIll&II SIZE O, 000 ................................................... O, OOO ................................................... 0.000 ................................................... 0, 0 O 0 ................................................... [:,EGF ti: iD D E P ,'~ g e C O M M E N T RECORDS Th.i_~ LIS tapm wa~.", written b~.~ Gmarhmrt, Industr. ims Wirelinm S~."vicms, All cur-va and tool mnmmonics used arm those which mo~t closely match Gear'haft cu~"vm and tool mnemonics, ~EARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEi'I · ., c~.~ i, I CE UNIT DEP T H F,EE T DEP T F T RAT COI~PUTED RAT ...... NPHS MERGE f~ SAND NPHI MERGE F'U NCNL MERGE CPS NCNL. MERGE CPS CCL MERGE MV CCL MERGE MV FCNL MERGE CPS FCNL MERGE CPS AVG COblPUTED AVG ~ATA FORMA TYPE T SPEC I FI CA S i~-'"E CODE O' i 66 TIONS TYPE DESCR ! PTI 0 I'...! 0 T,arminator. ( no more entries ) ,~ A FORMAT" oPEL, ~ F ]] UAT IL] N :-,5 ~;E ,~.!CE SERVICE MNEM ii) cRiER ~ APl APl APl APl FILE LINIT LOG TYPE L: L. ~:~ ..-, DEPT 28i920 RAT '.2819~0 NPHi MERGE 28i 920 NCNL MER6E 28i 920 CCL ~ERGE 28i 920 FCNL MERGE 28~920 AVG 28 i 92 O ,F T 0 0 0 0 0 ........ 0 0 0 0 0 PU 20 68 :~ 0 0 CPS 20 78 30 0 0 MV 20 i50 i O 0 CPS 20 78 3I 0 0 0 O O O 0 PRC SIZE LVL SMPL RC 4 0 i 68 4 0 t 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 68 PROCEF-;S IhiDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DATA RECORDS D E P T R A T N P H i N C N L C C L F C N L A V G 9409,':800 -999,:..?.50 .-999,250 -999,250 -999,250 -".-'.)99,:250 -74! , 125 540 oO1 ~' '-~:= 24. 975 " ,.,00 , 070 ~.~:,..~ ,900 9t09 000 ,-,-,~ .... 090 "595 ~00 19 '>7':~ , .~,.,... '~'~ ,t. 50 580 300 9009.., 0.00 1 ,396 :51 ,":":'",=..,0 2¢'"'~,900.. , 1 01 200 ,500 50 , 'I25 I'1 m x i m u m i m n g t h: 10:2,4 TRAIL, ER R E,i C O R D S Film type: LO Nmxt 1:'ilm: ''5 Ma::<in~um i~ngth: 1 'HEADER RECORDS Version Date: File tppe: LO F'rev :i ou~. ¢ i ! e.: i 0 H N E M CN W N F N C:OUH S T A T CTRY SECT 'f' 0 i,,.i i.i R A N ,] EKB EDF' EGL PD L HF DMF RUN LCC SON L U N F' L LUL EN~ i WiTN TLi T C'.'.s YLA8 B H T H R T H T hiSS H V i S RH R bi F hiFS]" biFSS RH C H C: S T bi C S S IHFORMATt ON RECORDS C: 0 N T E N T S ARCO AI...ASKA DS 1 :~-.-_44 PRUDHOE BAY HORTH SLOPE ALASKA USA INC. IIIIIfIIlIIIII IlflIIIfl|llJI UNIT i ON i 4E S 7, O 0 O ............. ................. '. , ....... ........... F T S~, O O O ....................... . ..... FT ~i 4., O 0 0 ............. , ................................ F T i<B ............. KB .............. 2S i 9¢' O 7542 ...... NORTH SLOPE NORTH 9LOPE ................................... ~RNOLD F~USETT 95 00, O O 0 ................................................ FT 9~9~. 000 ................................................ FT ~0,000 ................................................. FT 9Z492,0'0'0 ................................................ FT O, O00 ................................................... HR O. OOO ....................... . ............................. HR ~l O. OOO ................................................. DE6K 2i O. OOO ................................................. DE6F' C R Li D E u OOO ................................................... CP 0 000 ................................................... 0 H M 0000 ................................................... OHid~ ~ I I i I I i I i i i i i i i I i i I i i I i I I ~ i I i i I i I i I i I i I I i i I i I i I i I i I I 0 OOO ................................................... DE6F , . . . , , . . . . ~ , , . , . ~ . , . . . . , . . . , . ~ , r , , . ! . . , . , , * . . . , . ~ * , . , ~ . , TYPE C iq T G 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 0 0 0 0 0 0 0 0 0 0 0 0 .'3 0 2 0 0 i 0 0 2 0 2 0 '2 0 '2 O 2 O 2 0 2 0 2 0 '2 0 '2 SIZE CODE P a ~Z,.J (:: t'i COMMENT RECORDS ~s~. Thi..'~ LiS t. ap~: was wcitt.mn b,,., t,]mar, har't Indu~t.r'im.-s tdir~line. · ~ All ,:urvm and tc, ol mnmmonic~ u~md ar, e .:~,~ 6e:ar:har. t ,:ur. ye :~nd tool mn~::monics, ~f: :~ :+: :¢ :~ :4~ :'1': :~: · · :~ :'1~ · :¢ :'~ ~': :~: :~ :~ :'~: :~ :'~ :~: :~ :'k :¢ :'~ :¢ :'~: :i: :~: :¢ :t: :¢ :'I': :¢ :+: :~': :+: a': :'~ :+: :'B GEARHART TO SCHLUMBERGER M N E H S E R V I C E U N I T M N E M DEPTH FEET DEPT RAT l COMPUTED RAT C:CL. l MERGE MY CCL NF'HSI MERGE ;. ,_~AND NPHI FC:NL ! blERGE C:PS FCNL N C N L ~ M E R G E C P S N C: N L SERVICE UNIT FT MERGE MV MERGE PU MERGE CPS MERGE CPS i 2 EN TR"t' SPEC I F I CA TYPE SIZE CODE O i 6 6 T I 0 N $ · .~,:*~.~: ENTRY BLOCK LEGEND TYPE D F_-:SCR ~ PT ~ ON 0 T,--.'r. minat, or. < no mor. m mntrims ) DATA FORMAT' ,.~-',',:~ DATUM ' SPEC i F i C.'AT i OH BLOC:KS :~: :~ :'1': :.k :ct: :~. :'I': :~ ~: :'1': :4': ~ :~ :~ :~ :'~ :'B :4: · :~, :'B :'~ ~ :4': :'i.: :'I'~ :+: ~: ~: :'k, :'1': SEF.:V i CE SERVICE AP1 MNEM iD OR[:,ER ~ UNiT .LOG DEPT 281928 FT 0 R A T '28 i 9'"' -- .,-=0 -- 0 CCL MERGE 28 J 9:;: 0 i'lV '"' NF, HI MERGE 281920 -"i ~-L 20 FC:NL MERGE 20i 920 CPS 20 N C N L hi E R G E 28 i 920 P_. ~- .=." '-'" ~.0'"" API APi APl FILE TYPE CLASS i'40i':, ~ O O O 0 0 0 0 i i50 i O i 68 .']¢." 0 'i 78. :.'gi 0 i ';;'8 :30 0 'I SPEPI.... F ! CA T 1 ON¢''o F' RC :.:.i:l,7'E LVL. SMPL 4 0 ~ 68 4 0 'i 68 4 0 i 68 4. 0 i 68 4 0 i" 68 4 0 i 68 PROCESS iNDir:ATCtRS DE- TA REC:ORDS D E P T R 1~ T C C L N P H ! F C: N L. N C N L. 94,0,4,~;~00 i ,499 -999 250 ~;'~' ..... ..... .,,.,, 4i 0 i ,';.-z. 800 259, 000 4.00 9204,500 1 ,i20 ,17'0 2.'3,84.0 44.5,508 499.,100 9 i O.'-~i., 5 O0 ,97"4 . i ."30 i 7,800 612, ~$00 .5':':,.6. 500 ""00 248 000 9004,500 1 ,529 , Ol Fii~-~ r~ame~ 8~G5FO~ o002 TRA I LER RECORD'~. ~ File ~tS,,pe: LO Mm::<imu~r, ie_ngth: ]024 HEA[)ER RECORD'-" Vmr.,_s i on ~ Fi. lin tppm: LO Pr'm.vious f'ilm: Date~ i'1 N E H C N Li i',l FN C 0 U i',l STAT CTR¥ SECT T 0 W N RANG EKB EDK EGL PD LHF D t'i F R U t',I LOC: S 0 N LUN FI.. t_ U L ENG i W i T I',i D D Di._ TL.i TCS TLAB BHT bi R T HT H S S F1ViS RH RHF biF'ST biF'SS F.: bi C HC Si' P, L; o o INFORMATiCtN RECORDS C 0 H T E N T S UN I T TYPE ARCO ALASKA I.NC, D S i '3- 3 4. PRUDFIOE BAY NORTH SLOPE ALASKh USA i ON,,. i4E, , , '87,8'00 ,.,e,, 0 O0 34; O00 ........ 5U .............. o'-. ~0 7542. , ~,~ORTH SLOP~ .... NORTH SLOPE ~R. NOL. D F~USETT 9500,000 ...................... 9~9S.000 ...................... 8990~00.0 ...................... 9392,000 ...................... 0.000 ......................... 0,000 ......................... 210,000 ....................... 210,000 ................................... CRUDE ...................... FT FT FT FT FT HR HR DEGF DEGF O. 000 ................................................... [;EGF' C: A T G :31 Z E C 0 D E P .st ~.::J e: COHMEHT r;'ECORD e., This LIS trope: ,,~a.-.--.. ,,~ritt. mr, bp Gsmr. har. t Industrims Wir.,lin~ Sarvic:ms, m~ All cur-yin and :tool ~nmmonics usmd ~.~.~, G,s;ar-hart curvm and tool GEARHART TO SCHLUMBERGER MNEi"i SERVICE UNIT I"iNEM DEPTH FEEl' DEPT CCL. 2 MERGE rlV CCL RAT2 COMPUTED RAT F CI',I'I_ ;~ MERISE CPS FCHL NCt'.IL2 MERGE CPS NCNL NF'HS2 MERGE ,% SAND NPHI .~ER ,. I CE UN I T F:'t" M E R G E' t~I V HERC~E CF'S MERGE CPS MERGE PU P ~ g e'; DATA FORMRT TYPE SIZE "'~PEC I F I C:A C: 0 P IL:. 0 ~ 66 TION® :+::~:s ENTRY BLOCK LEGEND :.1': :~-: :-i-: :t-: :~, :.I': H': :-lc :-I.: :'1': :'F; :+: :~ :tc :.lc :~; :.l.: ~ :~: .".It :~: ~ ~ 'F YF'E DE~'-'' '' ' ._,L. R T p T ~ 0N 0 Te-..r-minator ( r',,'_", more:. ~_-'.ntr. ims ) GEARHART DATA FO R MA T SERVICE SERVICE Mi'-IEM i i) ORDER ~ AP1 APl APl A'PI FiLE UNIT LOG TYPE CLASS MOD ~ DEPT 28 i 920 CCL MERGE 28i 920 RAT 28 'i 920 FCNL. MERGE 28i 920 NC:NL MERGE 28i 920 N P H i M E R ~] E 28 i 920 F T O 0 0 O O ,M ¥ 2 O i 5.0 i O 2 0 0 0 0 '2 C: P S' 2 0 ? 8 ~ i ' 0 2 · CPS 20 78 ,..,0 0 2 PU 2 O 68 ,3 0 2 P RC SIZE LVL. SMPL RC 4 0 .1 68 4 0 i 68 4. 0 i 68 -',i. 0 i 68 -'~ 0 i 68 4 0 i 68 P R 0 C - "" "'~ .I.~.:~.= I N D i r: A T 0 i;: S 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 .[:) A T A RECORDS D E P T C C L R A T F C N L N C: N l_ N P H I i ,265 2 8 4,9 0 0 500 9309,'000 ,120 1,i22 269,600 .7, 02.6 00 25, lO0 9209.:000 ,050 i , 112 44 0. I '00 489,300 25,170 9i09,000 ,150 ,990 585~600 579.700 t9, 020 900'9.000 ,101 1 .406 20i , 5:0 0 50,6i 0 M .~ >.'. i m u m I ,~: n g t h: i 0 2 4 TRA T LER R E p..,. Fl.. R C:~ ES Vets i c,n ~: [)at,'a: Film t:,upm: LO Next f'i!e:: EOF *** S,ar-vice.name: &GSFO~ N e ::.'. t t.apm: Datm: 85," 04,-"'2 0 Oi."igin: "rape name: 28'i920 Cor, tir, uati,:,n ~: Oi :+: :~. :~, REEL TRAILER :4-.: :.~ :~ :4< :.,.k :+: :4< :,lc :-14 :.i': :'E: :{': :'{': 4': :'1': :+: ]'~A,-, ,,.~" LER RECORL]~ 0 r. i g i n: R ~ ~ t n.,~ m ~a: 2 8 i 9 2 0 C o n t i n u .~ 'l':. i o :"'., 4i:: 0 "t BP Exploration Alaska Inc Well: 13-34 Field: Prudhoe Bay North Slope, Alaska, USA Report Production Array Log Analysis Prepared For : BP Exploration Alaska Inc Logging Date : 10/26/2013 Report Date : 11/15/2013 Submitted by: Waqar Khan Phone: +1(281)575-5051 10200 Bellaire Blvd, Houston, Texas-77072 Email: waqar.khan2@halliburton.com HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF BP Exploration Alaska Production Array Log Analysis 1 TABLE OF CONTENTS 1.0 EXECUTIVE SUMMARY ............................................................................................................................. 2 2.0 BACKGROUND AND OBJECTIVES .......................................................................................................... 3 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT ............................................................ 4 4.0 PRODUCTION LOG PROCESSING ........................................................................................................... 7 4.1 FLOWING SURVEY ...................................................................................................................................... 9 BP Exploration Alaska Production Array Log Analysis 2 1.0 EXECUTIVE SUMMARY Production logging was done in Well 13-34 on October 26th, 2013 in flowing conditions with the objective to estimate the production profile. As the well is deviated, Resistance Array Tool (RAT) and Spinner Array Tool (SAT) were included in the tool string to accurately estimate the holdup and phase velocities as there can be segregated flow of the three phases due to well deviation. The flowing PL analysis showed the oil production to be coming from the second set of perforations (9102-9142 ft). This set of perforation is contributing about 90% of the total flow. The bottom set of perforations (9156-9216 ft) are only producing water. It’s contributing to 5% of the total water produced with the majority of the water coming from the second set of perforations. For the analysis, SAT and RAT along with the gas holdup tool were used to separate out the three phases. The reported surface production while running the PL was 232 STB/D oil and 2523 BPD water with 319 MSCF/D. Based on the well test data during logging, the well is slugging severely. The estimated flow rates at surface condition while flowing from each of the perforations and the production profile is given in the table below: feet Profile Qp-Water-STP Qp-Oil-STP Qp-Gas-STP BFPD BFPD MCFD 9026.50 9043.00 Produce 178 0 93.3 9102.00 9142.50 Produce 3172 353 562 9156.00 9203.00 Produce 190 .214 11.3 BP Exploration Alaska Production Array Log Analysis 3 2.0 BACKGROUND AND OBJECTIVES The objective for running the PL was to identity the production profile to identity options for increasing the oil and gas production. BP Exploration Alaska Production Array Log Analysis 4 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT Well 13-34 is completed with 7 inch production liner across which the production log was run. The wellbore schematic is presented in the Figure 1. The tool string diagram used for the PL logged is presented in Figure 2. The tool string consisted of the following production logging sensors: Gamma Ray - Casing Collar Locator – Pressure - Resistance Array Tool – Gas holdup – Caliper - Spinner Array Tool – Radioactive Density –Capacitance Water Holdup – Temperature – Caged Fullbore Spinner. The data quality is summarized below TOOL USAGE LOG DESCRIPTION LOG QUALITY REMARKS WELL BORE PARAMETERS QP Well bore pressure Good Pressure readings varied b/w UP and DOWN passes TEMP Well bore temperature Good Temperature readings varied b/w UP and DOWN passes FLUID TYPE FDR Radioactive density tool uses radioactive source and detector to measure density and is a center sample device Good Density tool is pretty consistent b/w the UP and DOWN passes except at the top perforation, at which, density increases for DOWN passes whereas it decreases for UP passes CWH Uses capacitance to measure the differences between hydrocarbons and water Good Capacitance tool is also behaving as the density tool after the top perforation RAT Resistivity Array Tool Good UP passes see a lot more hydrocarbons than DOWN passes GHT Gas HoldUp Tool Good Behaves similar to density tool after the top perforation FLUID VELOCITY CFB Caged Fullbore Spinner Good Owing to the slugging nature of the well, CFB is not able to read continuously. This becomes more apparent in the station measurements SAT Spinner Array Tool Good Slugging nature of the well prevents the spinner from reading a continuous increasing profile. . BP Exploration Alaska Production Array Log Analysis 5 Figure 1: Wellbore Schematic BP Exploration Alaska Production Array Log Analysis 6 Figure 2: PL Toolstring BP Exploration Alaska Production Array Log Analysis 7 4.0 PRODUCTION LOG PROCESSING The production log data from the flowing were processed using the PLATO software. The software uses a global probabilistic method for the production log analysis. In this method, known as the Maximum Likelihood method, a well flow model is compared to all available data and improved, by optimization, until the best possible match with the data is obtained. By using this method the result is the most likely interpretation. A comparison between the model and the data is shown in this report and allows the analyst or the reader to determine validity of the answer obtained. Potential sources of discrepancies include tool measurement errors, conflicts between the parameters or conditions that make the underlying empirical models (such as flow regimes) less applicable.  The flow regimes were determined, directly from the flow rates and holdups, according to the Taitel- Dukler analytic model.  The profile factors, to calculate the true fluid velocity from the apparent velocity, were based on the Reynolds numbers.  Solution gas in oil was derived from the correlations (Vasquez-Beggs or Øistein- Glaso). The analysis was performed in six steps:  The data preparation to filter the data, compute gradients and error estimates.  The calibration of the array tools and full-bore flow meter.  The computation of the layered holdup and layered flow-rates.  The profile determination to identify the potential producing and/or injecting zones.  The computation of the flow rates by global optimization.  The computation of surface productions and reporting. BP Exploration Alaska Production Array Log Analysis 8 The water density and viscosity were calculated using a salinity of 20000 ppm. The Craft & Hawkins correlation was used. The oil density and viscosity were calculated using an oil gravity of 25.7 API. The Vasquez & Beggs correlation was used to calculate the solution gas. Viscosity was calculated using the Beggs & Robinson correlation. The Pc and Tc parameters were calculated using the Brown et al. correlation. The gas viscosit y was calculated using the Lee Gonzales Eakin correlation. The following gas parameters were used: GasType Miscellaneous SPGG UNITY .750 GP-CO2 UNITY 0 GP-H2S UNITY 0 GP-Nitrogen UNITY 0 Utilizing the above fluid information, measured down hole oil density, temperature & pressure, the following fluid properties were calculated at well conditions: feet Twf Pwf Bwater water water Boil oil oil Rsb Bgas gas gas °F psi UNITY g/cc cP UNITY g/cc cP ft3/bbl UNITY g/cc cP 9010.00 217 2038 1.04 .978 .295 1.35 .754 .703 743 .00848 .108 .0171 9031.50 217 2047 1.04 .978 .295 1.35 .754 .703 743 .00844 .109 .0171 9053.00 217 2058 1.04 .978 .295 1.35 .754 .702 743 .00839 .109 .0171 9074.50 217 2068 1.04 .978 .295 1.35 .754 .703 743 .00835 .110 .0172 9096.00 217 2082 1.04 .978 .295 1.35 .754 .703 743 .00829 .111 .0172 9117.00 217 2101 1.04 .978 .294 1.35 .754 .702 743 .00823 .111 .0173 9138.50 218 2133 1.04 .977 .293 1.35 .754 .700 743 .00812 .113 .0174 9160.00 218 2183 1.04 .977 .293 1.35 .754 .700 742 .00794 .116 .0175 9181.50 218 2238 1.04 .978 .292 1.35 .754 .700 742 .00774 .118 .0177 9203.00 219 2138 1.04 .977 .292 1.35 .754 .699 742 .00811 .113 .0174 To estimate the flow rates, the caliper log recorded during the UP passes was used to estimate the nominal ID throughout the log. BP Exploration Alaska Production Array Log Analysis 9 4.1 FLOWING SURVEY The raw data from the flowing survey are presented in the Figures 3 to 8. Figure 3 has the data from conventional production logging sensors. Figure 4 has the same data that was presented in Figure 3 with the addition of the station measurements. To generate this plot, Emeraude software was used which allows overlay of the station measurements and the logging passes in the same track. Plato can only plot the st ation measurement against time. The spread in the station measurements indicate the well is in a slugging condition. Figure 4a shows a zoomed in view of station measurements at 9090 ft. The fullbore spinner along with the density and pressure measurements are plotted against time. As a slug of water passes through the density tool, an increase in pressure is observed. As pressure increases, the fullbore is unable to spin properly. This can be attributed to water dropping down, causing the spinner to rotate in an opposite direction. For the interpretation, UP 30, 60 and DOWN 30, 60 passes have been used since they indicated a consistent response. Down 60 and 90 passes showed an erratic response across the middle perforation, whereas UP 60 and 90 passes indicated movement across the bottom perforation, which wasn’t seen on any of the other passes. The response from the Resistance Array Tool is presented in Figure 5. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values. Only the active sensors were used in the interpretation. Figure 6 shows only the active RAT sensors along with the station measurements. The response from the Spinner Array Tool is presented in Figure 7. The fullbore spinner did not respond well owing to the slugging nature of the well. Figure 8 shows the station measurements. The bottom perforation was not able to be logged fully. Valid spinner data is available till 9207 ft. After depth matching the cased hole gamma ray with the open hole gamma ray, a depth shift of 4 ft in the upward direction occurs, limiting the data to 9203 ft. From the raw data it is clear that most of the production is coming from the top two perforations. All the spinners show a big change across 9128 ft. with slight increase observed across the top perforation as well. The density, Capacitance and RAT all indicate possible oil production from these two perforations. From the spinner response, the velocity profile was estimated using the slopes calculated from the spinner calibration (Figures 9 and 10). Velocity is highest across the 2nd perforation, indicating this zone as the main contributor. The calibrated RAT response is presented in Figure 11. Above the top perforations, evidence of oil flow towards the top is seen from the RAT response. The estimated SAT velocities and the RAT holdups are used to calculate the flow profile presented in the Figure 12. The final flow profile, after the global optimization, along with the comparison of the measured and theoretical tool values are presented in Figure 13. BP Exploration Alaska Production Array Log Analysis 10 The production rates at surface conditions estimated from the production log analysis are presented in Figure 14 and are summarized in the table below: Depth Profile Q-Water- STP Qp-Water- STP Q-Oil- STP Qp-Oil- STP Q-Gas- STP Qp-Gas- STP feet BFPD BFPD BFPD BFPD MCFD MCFD 9568.00 9588.00 Produce 8196 6327 327 308 103 93.8 9602.00 9634.00 Produce 1870 1870 19.1 19.1 8.82 8.82 9640.00 9650.00 Produce 0 0 0 0 0 0 Raw Data - The figure below summarizes the input data recorded at the well site. - Each pass is shown with a fixed predefined color. Figure 3: Input data from the conventional production logging sensors BP Exploration Alaska Production Array Log Analysis 11 Figure 4: Input data from the conventional production logging sensors along with the station measurements. BP Exploration Alaska Production Array Log Analysis 12 Figure 4a: Station measurements at 9090 ft. BP Exploration Alaska Production Array Log Analysis 13 The figure below shows the RAT input data. The first track shows the RAT rotation curves for each pass. The next tracks show the RAT data: A curve for each pass for each of the 12 probes. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values and were not used in the interpretation. Figure 5: Input data from the Resistance Array Tool (RAT) BP Exploration Alaska Production Array Log Analysis 14 Figure 6: Input data from the Resistance Array Tool (RAT) showing just the active sensors along with station measurements BP Exploration Alaska Production Array Log Analysis 15 The figure below shows the SAT input data. The first track shows the SAT rotation curves for each pass. The next track shows the linespeed for each pass. The remaining tracks show the array spinner data: A curve for each pass for each of the 6 array spinners, for the fullbore spinner (ASpinner07) and for the inline spinner (ASpinner08). The fullbore spinner does not appear to be turning well and its response is not consistent with the remaining spinners. This was not used in the analysis. Figure 7: Input data from the Spinner Array Tool (SAT) and conventional spinners. BP Exploration Alaska Production Array Log Analysis 16 Figure 8: Input data from the Spinner Array Tool (SAT) and conventional spinners along with the station measurements. BP Exploration Alaska Production Array Log Analysis 17 Calibration of Spinner Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and measured Array Tool responses. Track 2: Line-speed for each pass. Track 3: 'Unwrapped' rotation curve for each pass. Track 4: Normalized layered velocity profile. This profile is optimized by comparing the measured and theoretical SAT response for each pass of each spinner. Tracks 5-10: Measured and theoretical SAT responses for each spinner. Track 11: Measured and theoretical responses for the full-bore spinner. Track 12: Measured and theoretical responses for the inline spinner. Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity profile. Figure 9: Velocity profile from SAT data. The image below displays cross plots for each SAT spinner and the Inline spinner. The estimated slopes are used for converting the spinner response to flow velocities. BP Exploration Alaska Production Array Log Analysis 18 Figure 10: Spinner cross plot BP Exploration Alaska Production Array Log Analysis 19 Calibration of Resistance Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and the measured RAT responses. Track 2: 'Unwrapped' rotation curve for each pass. Track 3: Normalized layered RAT profile. This profile is optimized by comparing the measured and theoretical RAT response for each pass for each probe. Tracks 4-15: Measured and theoretical RAT responses for each probe. Below are the results from the calibration of the RAT data. The determination of this calibration is a layered resistivity profile. To obtain this profile, calibrations for water/ hydrocarbon were entered for each probe. Figure 11: Calibrated RAT response. BP Exploration Alaska Production Array Log Analysis 20 Holdup and Velocity Profile: Shown on the image below from left to right: Track 3: Layered velocity profile. Track 4: Layered water holdup profile. Track 5: Layered oil holdup profile. Track 6: Layered gas holdup profile Track 7: Total holdup. Track 8: Cumulative flow rates Track 9: Density of fluid Track 10: Apparent Velocity from Fullbore Spinner Figure 12: Holdup and velocity profile BP Exploration Alaska Production Array Log Analysis 21 Flow Profile The quantitative production rates were determined by comparing the well flow model with all available data. The figure below is provided to verify the agreement of the flow model with the data. In this figure the data is represented by the blue curves, while the calculated tool values are shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. The small fluctuations around the data are to be expected, since the tools have intrinsic errors. Large sustained discrepancies indicate problems with the data, conflicts between parameters or conditions that make the underlying empirical models less applicable. To the right of the figure the flow regimes are shown. Within the transition zones several regimes can exists intermittently. Figure 13: Flow profile at reservoir conditions BP Exploration Alaska Production Array Log Analysis 22 The production rates at surface conditions are presented in the figure below: Figure 14: Flow profile at surface conditions