The URL can be used to link to this page

Home My WebLink About197-216 BP Exploration Alaska Inc Well: 17-03A Field: Prudhoe Bay North Slope, Alaska, USA Report Production Log Analysis Prepared For : BP Exploration Alaska Inc Logging Date : 04/23/2014 Report Date : 05/01/2014 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 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 Log Analysis 2 1.0 EXECUTIVE SUMMARY Production logging was done in Well 17-03A on April 23rd, 2014 in flowing conditions with the objective to identify the feasibility of setting a plug to reduce the watercut. 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 was able to detect the hydrocarbon producing zones qualitatively by observing the deflection on the temperature. Unfortunately, the flow was too small to be picked on any of the other sensors. The major water producing zone is 11729’ – 11771.5’, producing 40% of the total water. The estimated flow rates at surface condition while flowing from each of the perforations and the production profile is given in the table below: Perforations Water rate From , ft To , ft STB/D % 11038 11092 0 0 11189.5 11224 58.1 6.685846 11518.5 11616.5 175 20.13809 11729 11771.5 345 39.70081 11795 11858 117 13.46375 11937.5 11982.5 63.4 7.295742 12008 12102 25.3 2.911392 12130 12158 85.2 9.804373 869 BP Exploration Alaska Production Log Analysis 3 2.0 BACKGROUND AND OBJECTIVES The objective for running the PL was to identity the possibility of setting a plug to try and reduce the water cut from the well. BP Exploration Alaska Production Log Analysis 4 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT Well 17-03A is completed with a 2 7/8” inch production liner across which the production log was run. Owing to the small liner size, it was not possible to run array tools. 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 - Caliper - Capacitance Water Holdup – Temperature – Inline Spinner – Continuous Flowmeter. The data quality is summarized below TOOL USAGE LOG DESCRIPTION LOG QUALITY REMARKS WELL BORE PARAMETERS QP Well bore pressure Good Except for DOWN 30, DOWN passes showed a consistent pressure response TEMP Well bore temperature Good Temperature response was consistent across the down passes except for DOWN 30 pass FLUID TYPE CWH Uses capacitance to measure the differences between hydrocarbons and water Good Capacitance tool is unable to pick up the entry of hydrocarbons FLUID VELOCITY CFS Continuous Flow Meter Good DOWN 60 and DOWN 90 show a consistent response on the CFS. ILS Inline Spinner Tool Poor Inline Spinner is unable to read a continuous profile . BP Exploration Alaska Production Log Analysis 5 Figure 1: Wellbore Schematic BP Exploration Alaska Production Log Analysis 6 Figure 2: PL Toolstring BP Exploration Alaska Production 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 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 viscosity 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 °F psi UNITY g/cc cP UNITY g/cc cP ft3/bbl 10717.00 206 2745 1.03 .994 .329 1.06 .824 3.37 0 10899.50 207 2797 1.03 .994 .329 1.06 .824 3.36 0 11082.00 207 2819 1.03 .994 .329 1.06 .824 3.36 0 11264.50 207 2822 1.03 .994 .329 1.06 .824 3.36 0 11447.00 207 2828 1.03 .994 .328 1.06 .824 3.36 0 11629.50 207 2832 1.03 .994 .328 1.06 .824 3.36 0 11812.00 207 2837 1.03 .994 .328 1.06 .824 3.36 0 11994.50 207 2845 1.03 .994 .328 1.06 .824 3.36 0 12177.00 207 2853 1.03 .994 .328 1.06 .824 3.36 0 12359.50 206 2853 1.03 .994 .330 1.06 .824 3.37 0 To estimate the flow rates, the caliper log recorded during the UP passes was used to estimate the nominal ID throughout the log. Tool information The following capacitance tool characteristics were used HydroWater Hz 29063 (Surface Calibration) HydroHyd Hz 34516 (Surface Calibration) BP Exploration Alaska Production Log Analysis 9 4.1 FLOWING SURVEY The raw data from the flowing survey are presented in the Figures 3 to 4. 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. For the interpretation, only DOWN 60, 90 passes have been used since they indicated a consistent response. Down 30 pass shows an erratic response across both the spinner and pressure and hence hasn’t been used in the interpretation, whereas the spinner response across the UP passes isn’t good. Since there was hardly any flow of hydrocarbon on the surface during logging operations, the capacitance hold up tool is unable to pick it up. Deflections on the temperature have been used to identify qualitatively, the possible entry points (Figure 5). The final flow profile, after the global optimization, along with the comparison of the measured and theoretical tool values are presented in Figure 10. The production rates at surface conditions estimated from the production log analysis are presented in Figure 11 and are summarized in the table below: feet Profile Q-Water-STP Qp-Water-STP BFPD BFPD 11038.00 11092.00 Produce 869 0 11189.50 11224.00 Produce 869 58.1 11518.50 11616.50 Produce 811 175 11729.00 11771.50 Produce 636 345 11795.00 11858.00 Produce 291 117 11937.50 11982.50 Produce 174 63.4 12008.00 12102.00 Produce 111 25.3 12130.00 12158.00 Produce 85.2 85.2 BP Exploration Alaska Production Log Analysis 10 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 Log Analysis 11 Figure 4: Input data from the conventional production logging sensors along with station measurements. BP Exploration Alaska Production Log Analysis 12 Figure 5: Temperature deflections indicate entry of hydrocarbons Temperature deflections indicating the entry of hydrocarbons BP Exploration Alaska Production Log Analysis 13 Depth Matching Figure 6: Passes had to be shifted to bring it on depth with open hole gamma ray OH GR BP Exploration Alaska Production Log Analysis 14 Pre- Processing Figure 7: Down 60 and Down 90 passes have been used in the interpretation, the figure above shows an average of the two passes (black line) BP Exploration Alaska Production Log Analysis 15 Calibration of Spinner Array Data The spinner was analyzed to calculate the apparent velocity at each depth. The spinner sensitivity (Slope) and threshold (Vthr) were calculated globally (held constant over zones) and are displayed below. The figure shows a comparison between the flowmeter data and the flowmeter values calculated for each cable speed, with the globally determined slope and intercept. - For each cable speed a different color is used. - The data is shown as solid lines and the calculated values in dotted lines. - For a good calibration the solid lines and dotted lines should match for each pass (color). Figure 8: Velocity profile from continuous flow meter for Down 60 and Down 90 passes BP Exploration Alaska Production Log Analysis 16 The image below displays cross plots for the continuous flow meter. The estimated slopes are used for converting the spinner response to flow velocities. Figure 9: Spinner cross plot for Down 60 and Down 90 passes BP Exploration Alaska Production Log Analysis 17 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 10: Flow profile at reservoir conditions BP Exploration Alaska Production Log Analysis 18 The production rates at surface conditions are presented in the figure below: Figure 11: Flow profile at surface conditions STATE OF ALASKA• F KA OIL AND GAS CONSERVATION COMF ,ON REF-URT OF SUNDRY WELL OPERATIONS MAY 2 0 20e4 1.Operations Abandon U Repair Well LI Plug Perforations H Perforate Lf Other Li AOG C Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Weill] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development El Exploratory ❑ • 197-216-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 f 50-029-20492-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: S ADL0028334 % PBU 17-03A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): 11 PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured • 12590 feet Plugs measured 11785 feet true vertical 9068.6 feet Junk measured 12294 feet Effective Depth measured 11785 feet Packer measured 10608 feet true vertical 9034.86 feet true vertical 8776.54 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"94#H-40 32-112 32-112 1530 520 Surface 2666 13-3/8"72#L-80 32-2698 32-2698 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 1695 2-7/8"6.5#L-80 10670-12365 8818.38-9063.19 10570 11160 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet SCANNED MAY p v 2 rr U n h Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment `t See Attachment Packers and SSSV(type,measured and true vertical depth) 8776.54 10608 8776.54 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): FIBDMS17,3MAY 2 0 n1 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 246 2504 5562 1673 384 Subsequent to operation: 20 0 1137 1801 1440 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratorl❑ Development ' Service Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil . U Gas 1 i WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUGE 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: N/A Contact Garry Catron Email Garry.CatronBP.Com Printed Name y(Garry Catron Title PDC PE Signature 7J 4/441. C Phone 564-4424 Date 5/20/2014 A .0-07 Form 10-404 Revised 10/2012 Submit Original Only w 000 0.c, 00 00000 ▪ N �- CDCON- 030 OCDNL[) N co r- C.) ' 0000000 � C.) N- N- 10C• Tr C', co CO e- a) N- v ,- QO CO 00 N OD O) co N- O) O) co co N Ocxi • co• cn co 0) N co rn co co co ODLn co CD N co CO of N f� C N co Cr) N CO 0 CO CO UC) 00 Tt co 00 ch O O N- N O N O V CU CI 111111 M Q M o o CO r's coC) (V c cN� N st C O CC) Q OO CA � O � co CD co 0 , co , / J 0 J J J N � N N (.0 • co V 00 00 W C , O ti to 00 M N • ch Ln N— N , 4 CA .c C0a) ccoc� COD � O C CO CD Nr CO CD 0 J — O) CV Z Z O 00 w H 0 C.) 0 - OO 0 O p p LL Z Z v Z w O O m O J D d v) F- I- N CO cc N CO CO CO CO CO CO N CD U) 'Kt N CO (D O O) () L0 co Cr- co O co. 0) p. r U) Cn CD M O O Ln lLo co CO U j W N N N Cr) Cr) '1' CC) LO Lf) LC) 0 O 0 0 0 0 0 0 0 0 0 O O O CA O 0 0) O O) O) O) 0) CA O CA O 0) O O CD 0 co Z W W 0 W 0 F- r- J a " o p 00 < Y Y ti CO N CO CO LO LO CO CD CO x ti N J U U W w t �OC0000CDC3) COMCC) OC7OOONC7OCr J J J Q Q m w oair: 4LriuiCnaia � v (ri � LON- Q ¢ a W a aO ? O ap 00 � NNNMMMODCt) Cnocn00) O O O J J J > p O 0 0 0 0 0 0 0 0 0 0 00 O 0 0 2-22- 0 p p ~p J CA O O O CA O O CA O O CA 0 0 U U U = = = z < < 0 ~ 0 r? w w W a < -J < O co co co co co a> ea m r N- CD LO NOON M � ON- CCI O Cy) V' COD0C() CD C COO N CO Lf) CO N. CO C O O) CA 0 N N N N d p E coY co J I H IO d J d V a 2 O co co m N v) C co d N = p w ('40 CD U) O U) 0 0 0 0 0 0 CA 0 0 0 J C O r` O N Cf) r` O Ch c ti '- Cr) CO M_ Q 0 O O N LO CA CA CO CO 0) 0) N N N 0 N (o L m 0 M L d a. O U ° aaarLILa. acncnCOCOCOCOCDCi) oaaaaaaaaaaaaaaaa m m m Q Q m m CO CO m CO CO m CO CO m a 0 a, m a p W LU J m Q COpw co OOOMC7OO V V' d' 1' 1- 1 p a O c O O O O O O O O O co O O O O O Cl LU _ J Z LL O N N CV N N N N N N N N N N N N N ZW a a < W W N N N CD 0 N N N N N N N N N N N N N p a C 111 _1 0 (9 O W W LL W a r` N- N N- N- v v v v v t v < O a a J J D p CC a O Q Q m m LL LL tan N d W a, E Z ¢ Q ¢ QaQaaaa « « « M co co co co co co co (v.) co co (v) (h M co 0000000000000000 i i i i i i i LL a m OLL N [Y LL W t` r- r` r- t` t` t` t` t` r` r-- m a a a o J a a w a Q Q CO m LL Li Cl) Cn a cc 7 I G 2 m Et 5 ' _ 7 » f 5 \ % \ t 0)D o / \ oRS \ E¥ 2 � .2 \ / — \ g 6 / f o t E 2 E \ _r \ \ \ % « •a ƒ / ® b \ % c\ 0 i � § E E a) 0 5 0. \ 7 \2 W Q > Na0 # / .-- 00c6 a) 0m / E " O ��a0) 2• % ± _ ® E - co® I o/ ._ •o c R / ? / ® / E 9 \ \ R D o o g n ¢ Q c e CO O & » 2 G k \ \ E ® \ 5 I . 9 O m - eL0 07 o6G / � Ro % E / Q - > 00 co ■ E E o E » c .§ 2 ° n 2 " ^ E $ ) ƒ 0 g t $ ƒ > 0 \ 0 - \ 0/ a 03 , ,�2 0 0 te a ) m 2 f L. q % E/ b A 5 $ CL 4.00 LI C \ O c > / / / 70 \ / .- el / Ci)J % 6) / o * -5 0 \ k cv 0 / / 0- / 0 \ 4 / \ x \ f o o _ - 0 3 0 3 I- < ib D ® 5 / a c $ 7 ¥ co 9 ® I . o « \ / \ \ � \ ct ,— / / E f / / & II / ) o \ ƒ / § 0 0 # .2 / \ \ as Ce 11 _ -0 o ¥ \ .§ C 0 6 g _ o >. 6 cc ® f / \ @ a) N- ƒ # E • E £ 2 �� - Q. 02 oaE _ e e o � o & $ $ % CL<E C u) k g \ / EL ƒ / 7 6 E I / ) ° > - - t / // \ � � » \ / o/ � � k C - (NJ• ƒ c = r ± @ ) - @ ° a a E » ® 2 2 CL a - S t ® a ± E \ ,- .0 / \ i z •4 E 0 CC \ o \ 0 0 \ 9 2 0 7 \ / G / 0) _ = 0 -0 U c I C ed = 2 \ <Zo _ NW / / ocp d0 : yENO3 6 o 2 0 O CCN $ f 2 / ? * O ƒ ' r : # t # / \ \ CV \ 'Cl" # # # ' FEAD= FKC 1 7-0 3 A H 'Y NOTES: WELL ANGLE>700 @ 10945'. ACTUATOR= BAKER C OKB REV= 70' BF. REV= NA KOP= 3550' 1 2192' --14-1/2"0115 HRO SSSVN,D=3.813" Max Angle= 91"@ 11195' O Datum MD= 10745' GAS LFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH FORT DATE 1 3007 3007 0 MG DONE RK 16 09/10/10 13-3/8"CSG,72#,L-80,0=12.347" —{ 2698' 2 5215 4942 45 MIG DOME RK 16 09/10110 3 7160 6385 41 3 DOME RK 16 09/10/10 II PI 4 8324 7258 44 k 3 DMY RK 0 09/10/10 5 8901 7644 48 NMC DMY RK 0 03/26/90 6 9479 8041 45 NM3 SO RK 28 12/12/13 Minimum ID = 2.387" @ 10674' 7 9938 8353 51 MMG DMY RK 0 03/26/90 3-1/2" X 2-7/8" LNR XO 8 10396 8638 50 MutG DMY RK 0 09/10/10 •CHEMICAL MANDRELS(P 3-LTS) C , ST MD ND DEV TYPE VLV LATCH PORT DATE �I"il 9 10502 8707 49 WAG DMY RK 0 07/21/92 4-1/2"TBG-FC,12.6#,L-80,.0152 bpf,D=3.958" —{ 10605' 10605' H4-1/2"BKR GBH LOC SEAL ASSY,D=3.875" 10608' --19-5/8"X 4-1/2"BKR DB PICK,D=4.750" 10627' —14-1/2"BKR SEAL BORE EXT,D=6.29" 3-3/4'BKR DEPLOY SLV,D=3.00" H 10670' 3-1/2"X 2-7/8"LNR XO,D=2.387" --{ 10674' .1v. 4 tv41 10716' —14-1/2"OTIS XN NP,MLLEDTO 3.80"D 4-1/2"TTP-IPC, 12.6#,L-80, .0152 bpf,0=3.958" — 10727' .414111 11.1111 14:4111 11111111 '4.41 I**• 10728' —4-1/2"WLEG,D=3.958"(BEHIND LNR) FERFORATON SUMMARY .11111 I4,111�1 111.1 •4111 REF LOG:SWS MEMORY GR/CCL ON 12/25/98 1111. .111. ,' 9-5/8"CSG MLLOUT 1NFDOW ANGLE AT TOP FERE:45°@ 10807111.11�11�.. 10814'-10819'(OFF CMT RAMP) ♦•••••♦ Note:Refer to Production DB for historical perf data 111.1.1♦ _ 1.1...1.1. SCE SPF INTERVAL Opn/Sqz SHOT SQZ .• /?•/ •/• ........../�/ �_� ��`� �— ` 2" 6 10802 10817 0 05/06/01 1*/*/........./..//..4 � 11785' —2-7/8"WFDCEP(04/24/14) 4.4.41.11.4.4.4.4.4.1, 2" 6 11070-11079 O 05/06/01 2" 6 11206-11210 0 05/06/01 --or -' -.. i 2" 6 11525 11575 0 01/20/13 2" 6 11550-11600 0 06/17/04 12294'Jl FISH:2-7/8'CSP MILLED 2" 8 11740-11770 0 12/24/98 &PUSHED(01/18/13) 2" 8 11800-11830 C 12/24/98 2" 4 11830-11840 C 03/20/98 2" 8 11940-11970 C 09/24/99 2" 4 11970-11980 C 09/24/99 PBTD H 12336' 2" 8 12010-12040 C 09/24/99 / 2" 6 12010-12060 C 01/20/13 2" 4 12040-12100 C 09/24/99 1, 2" 6 12130- 12155 C 01/20/13 %'�'�4j 9-5/8"CSG,47#,L-80,D=8.681" — 11865' I 12-7/8"LW 6.5#.L-80,_0058 bpf,D=2.441 ]—L 12365' DATE REV BY COM U4TS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/29/80 ORIGINAL COMPLETION 01/28/13 CJS/JND MELEDCIBP&ADFERFS(01/18-20/13) WB-L: 17-03A 03/23/90 RINO 12/20/13 LEGJMD GLV GO(12/12/13) PERNIT Ab: 1972160 03/20/98 CTD SIDETRACK(17-03A 04/28/14 SET/JMD SET CSP(04/24/14) AR Pb: 50-029-20492-01 09/02/08 JLJ/PJC GLV C/O(08/16/08) SEC 22,T1 ON,R15E,2604'FNL&475'FWL 07/28/10 '/PJC TREE GO(07/16/10) . 09/21/10 CJNIPJC GLV C/0(09/10/10) BP Exploration(Alaska) STATE OF ALASKA KA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LI Repair Well Li Plug Perforations LJ Perforate U OtherLI Mill CIBP Performed: Alter Casing 0 Pull Tubing0 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 0 Exploratory ❑ " 197 -216 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50-029-20492-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028334 ` PBU 17 -03A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): u To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 12590 feet Plugs measured None feet true vertical 9068.6 feet Junk measured 12291 feet Effective Depth measured 12336 feet Packer measured 10608 feet true vertical 9062.33 feet true vertical 8776.54 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H -40 30 - 110 30 - 110 1530 520 Surface 2669 13 -3/8" 72# L -80 29 - 2698 29 - 2698 4930 2670 Intermediate None None None None None None Production 10791 9 -5/8" 47# L -80 28 - 10819 28 - 8921.07 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet 2 x11'3 SCANNED MAR 0 5 U t True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 27 - 10728 27 - 8858.19 I Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker DB Packer 10608 8776.54 Packer None None None SSSV 12. Stimulation or cement squeeze summary: u �` Intervals treated (measured): �Q12 Treatment descriptions including volumes used and final pressure: FEB LD U AOGCC 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 306 2675 4979 1742 330 Subsequent to operation: 296 2755 5015 1791 311 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorC Development . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil • U Gas ❑ WDSPLIJ 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: N/A Contact Nita Summerhays Email Nita.Summerh BP.com Printed Name Nita Summerha s Title Petrotechnical Date Technician ' __ ' / / Signatur � � � / / � • , , , ,4� �,...- > �� Phone 564 -4035 Date 2/12/2013 RBIDMS FEB 14 2013 UL 2051 r- r r rY ,,, Form 10 -404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028334 ACTIVITYDATE 1 TV • ff 1 • - - VAL * ** (Perforating) DRIFT TO 10,798' SLM W/ 2.25" CENT, 2.00" x 22' DUMMY GUN. SET DOWN DUE TO SEVERE DOGLEG. ABLE TO WORK DUMMY GUNS TO 10,810' SLM (Pulls free w/ 100# over - pull). 11/30/2012 ** *JOB IN PROGRESS, CONTINUED ON 12/1/12 WSR * ** ** *CONTINUED FROM 11/30/12 WSR * ** (Pre adperf) DRIFT TO DEVIATION @ 10,938' SLM W/ 2.25" CENT, S -BLR (No sample or issues). ** *WELL FLOWING ON DEPARTURE, NOTIFIED DSO OF WELL 12/1/2012 STATUS * ** CTU #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs RU and cut 25' of pipe. MU 1 11/16" jars/ motor /2.3" three blade junk mill. Tool make up in progress. 1/6/2013 « <Job continued on 1/7/13 »> CTU #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs RU and cut 100' of pipe. 1/6/2013 « <Job continued on 1/7/13 »> C1U #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs RU and cut 25' of pipe. MU 1 11/16" jars/ motor /2.3" three blade junk mill. Tool make up in progress. 1/6/2013 « <Job continued on 1/7/13 »> CTU #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs Finish making up tools, FP flowline. RIH w/ jars, 1 11/16" motor, 2.3" three blade concave junk mill. FP backside to 2000'. Dry tag CIBP @ 1/7/2013 11840'. CTU #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs Finish making up tools, FP flowline. RIH w/ jars, 1 11/16" motor, 2.3" three blade concave junk mill. FP backside to 2000'. Dry tag CIBP @ 1/7/2013 11840'. PUH and est free spin. Mill on HES CIBP, see log for details. CTU #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs Finish making up tools, FP flowline. RIH w/ jars, 1 11/16" motor, 2.3" three blade concave junk mill. FP backside to 2000'. Dry tag CIBP @ 11840'. PUH and est free spin. Mill on HES CIBP, see log for details. Mill with 16 stalls on plug © 11842'. Reduce rate to 1 bpm, mill to 11851'. Stacking weight/getting work/no stalls. Make trip out of 2 7/8" liner to 10505'. RIH, dry tag @ 11777'. Work through. Resume milling @ 11848', stacking weight/getting motor work but no stall. Chase out of liner. Come to surface to inspect BHA. FP coil. Continued on 1/7/2013 01/08/13 WSR. CTU #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs Finish making up tools, FP flowline. RIH w/ jars, 1 11/16" motor, 2.3" three blade concave junk mill. FP backside to 2000'. Dry tag CIBP @ 11840'. PUH and est free spin. Mill on HES CIBP, see log for details. Mill with 16 stalls on plug @ 11842'. Reduce rate to 1 bpm, mill to 11851'. Stacking weight/getting work /no stalls. Make trip out of 2 7/8" liner to 10505'. RIH, dry tag @ 11777'. Work through. Resume milling @ 11848', stacking weight/getting motor work but no stall. Chase out of liner. Come to surface to inspect BHA. FP coil. Continued on 1/7/2013 01/08/13 WSR. • • Daily Report of Well Operations ADL0028334 - CTU #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs POOH. Inspect BHA. Several chunks of rubber and peice of 1/4" brass shear stock stuck in mill. Motor was very loose. Calibrate injector 1/8/2013 weight cell. MU /RIH w/ jars and 2.11" Venturi BHA. CTU #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs POOH. Inspect BHA. Several chunks of rubber and peice of 1/4" brass shear stock stuck in mill. Motor was very loose. Calibrate injector weight cell. MU /RIH w/ jars and 2.11" Venturi BHA. Venturi down to 11845' and tagged down. PUH and venturi down to 11870', pushing plug down hole. Attempted 3 more times w/o making it any deeper. POOH and inspect venturi. Recovered 1 tablespoon of metal and 2 cups of scale. RIH w/ motor and 2.3" 5 bladed junk mill. Mill from 11866 - 11869'. Make wiper trip to TOL @ 10570'. Dry tag @ 11875. Mill to 11875'. Total 15 stalls so far on this run. Make wiper trip up. In progress. 1/8/2013 « <Job continued at 1/9/13 »> CTU #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs POOH. Inspect BHA. Several chunks of rubber and peice of 1/4" brass shear stock stuck in mill. Motor was very loose. Calibrate injector weight cell. MU /RIH w/ jars and 2.11" Venturi BHA. Venturi down to 11845' and tagged down. PUH and venturi down to 11870', pushing plug down hole. Attempted 3 more times w/o making it any deeper. POOH and inspect venturi. Recovered 1 tablespoon of metal and 2 cups of scale. RIH w/ motor and 2.3" 5 bladed junk mill. 1/8/2013 « <Job continued at 1/9/13 »> CTU #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs POOH. Inspect BHA. Several chunks of rubber and peice of 1/4" brass shear stock stuck in mill. Motor was very loose, but after inspecting it confirmed that the rubber was from down hole, not the motor itself. Calibrate injector weight cell. MU /RIH w/ jars and 2.11" Venturi BHA. Venturi down to 11845' and tagged down. PUH and venturi down to 11870', pushing plug down hole. Attempted 3 more times w/o making it any deeper. POOH and inspect venturi. Recovered 1 tablespoon of metal and 2 cups of scale. RIH w/ motor and 2.3" 5 bladed junk mill. Mill from 11866 - 11869'. Make wiper trip to TOL © 10570'. Dry tag @ 11875. Mill to 11875'. Total 15 stalls so far on this run. Make wiper trip up. In progress. 1/8/2013 « <Job continued at 1/9/13 »> CTU #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs Make backream /wiper trip from 11875' to 10570' (TOL). RIH, stall #16 © 11855'. Resume milling from 11875.1'. Mill to 11880' with one additional stall. Make backream wiper trip to TOL. Had motor work @ 11852'- 11851'. Mill to 1/9/2013 Job in progress. • • Daily Report of Well Operations ADL0028334 CTU #3 1.75" CT. Job Scope: Mill CIBP, shootAddperfs Make backream /wiper trip from 11875' to 10570' (TOL). RIH, stall #16 @ 11855'. Resume milling from 11875.1'. Mill to 11880' with one additional stall. Make backream wiper trip to TOL. Had motor work @ 11852'- 11851'. Mill from 11885 - 11890'. PU and RIH for dry tag, push plug down to 11909'. Mill from 11909- 11912', after stall made wiper trip to 11650'. Tight spot at 11852' while PUH. Drift back through w/o any obstructions encountered. RIH for dry tag, push /mill plug down to 11955'. POOH for BOP test. Overall progress, milled /pushed plug from 11845 - 11974' thus far. Stalled BKR motor 48x throughout 2nd milling run. FP well w/ 35bbls of 60/40 methanol. Notified to RD and move to 05 -35A for pre -rig work, scheduled to come back. 1/9/2013 « <Job Incomplete »> CTU #3 1.75" CT. Job Scope: Mill CIBP, shoot addperfs Notified to RD and move to 05 -35A for pre -rig work, scheduled to come back. Perform BOP test. RDMO. 1/10/2013 « <Job Incomplete »> CTU #3 1.75" CT. Job Scope: Mill CIBP, shoot addperfs MIRU. MU /RIH w/ BOT jars and 2.11" venturi. Tag fish /cibp @ 11995'. Push cibp to 12291' (uncorrected ctm up). Venturi proposed perf interval @ 1 bpm /20 fpm from 12205'- 11475'. POOH. At surface venturi returned 6 small slip pieces and -1 cup of thin scale flakes. Stack down injector and secure well in preparation for weather standby 1/12/2013 ...Job in progress... CTU #3 1.75" CT. Job Scope: Mill CIBP, shoot addperfs 1/12/2013 MIRU. CTU #3 1.75" CT. Job Scope: Mill CIBP, shoot addperfs MIRU. MU /RIH w/ BOT jars and 2.11" venturi. Tag fish /cibp @ 11995'. Push cibp to 12291' (uncorrected ctm up). Venturi proposed perf interval 1/12/2013 © 1 bpm /20 fpm from 12205'- 11475'. POOH. in progress):» CTU #3 1.75" CT. * * *Contined from 1- 12 -13 * ** Job Scope: Mill CIBP, shoot addperfs Resume job after weather standby. Dig out. 1/16/2013 ...Continued on WSR 1- 17 -12... CTU #3 1.75" CT. Job Scope: Mill CIBP, shoot addperfs 1/16/2013 Resume job after weather standby. Dig out. CTU - 1.75"Toil Job Scope: Add -Perf Continue preparing equipment after weather, BOP Test. 1/17/2013 ...Job in Progress... CTU #3 - 1.75" Coil Job Scope: Add -Pert Continue preparing equipment after weather, BOP Test w/ no failures. Injector chain inspection 1/17/2013 ...Job in Progress... . . Daily Report of Well Operations ADL0028334 CTU #3 - 1.75" Coil Job Scope: Add -Perf Continue preparing equipment after weather, BOP Test. 1/17/2013 ...Job in Progress... CTU #3 - 1.75" Coil Job Scope: Add -Pert Continue preparing equipment after weather, BOP Test w/ no failures. Injector chain inspection 1/17/2013 ...Job in Progress... CTU #3 w/ 1.75" CT (CTV =33.2) Scope: Add perfs Finish chain inspection. RIH w/ PDS MGR /CCL. Noticed elec. counter slippage due to ice on pipe, mechanical OK. Tagged plug at 12294m, 12056e and began logging pass. Painted red /white flag at 11300m, 11073e and continued up to 10000m, 9775e to include all desired jewelry. While at surface determined +237' correction for elec, only +10 mech. No elec. counter slippage across logging interval when compared to ref. log. Begin making up 25' perf guns for first run. 1/18/2013 ....In progress CTU #3 w/ 1.75" C1 (CTV =33.2) Scope: Add perfs Finish chain inspection. RIH w/ PDS MGR /CCL to 1/18/2013 In progress C1 U #3 w/ 1.75" CT (CTV =33.2) Scope: Add perfs Finish chain inspection. RIH w/ PDS MGR /CCL. Noticed elec. counter slippage due to ice on pipe, mechanical OK. Tagged plug at 12294m, 12056e and began logging pass. Painted red /white flag at 11300m, 11073e and continued up to 10000m, 9775e to include all desired jewelry. While at surface determined +237' correction for elec, only +10 mech. No elec. counter slippage across logging interval when compared to ref. log. RIH w/ SWS 2.0" perf gun #1 and perforate 12130 - 12155' w/ 6 spf. POH. MU perf gun #2 1/18/2013 In progress CTU #3 w/ 1.75" CT (CTV =33.2) Scope: Add perfs Finish chain inspection. RIH w/ PDS MGR /CCL. Noticed elec. counter slippage due to ice on pipe, mechanical OK. Tagged plug at 12294m, 12056e and began logging pass. Painted red /white flag at 11300m, 11073e and continued up to 10000m, 9775e to include all desired jewelry. While at surface determined +237' correction for elec, only +10 mech. No elec. counter slippage across logging interval when compared to ref. log. RIH w/ SWS 2.0" perf gun #1 and perforate 12130- 12155' w/ 6 spf. POH. MU perf gun #2 1/18/2013 In progress • • Daily Report of Well Operations ADL0028334 CTU #3 w/ 1.75" CT (CTV =33.2) Scope: Add perfs Finish chain inspection. RIH w/ PDS MGR /CCL. Noticed elec. counter slippage due to ice on pipe, mechanical OK. Tagged plug at 12294m, 12056e and began logging pass. Painted red /white flag at 11300m, 11073e and continued up to 10000m, 9775e to include all desired jewelry. While at surface determined +237' correction for elec, only +10 mech. No elec. counter slippage across logging interval when compared to ref. log. Begin making up 25' perf guns for first run. 1/18/2013 ....In progress CTU #3 w/ 1.75" CT (CTV =33.2) Scope: Add perfs RIH w/ SWS 2.0" perf gun #2 and perforate 12035 - 12060' w/ 6 spf. POH. At surface stack down to inspect injector. Rig up SWS perf gun #3 and perforate 12010 - 12035' w/ 6 spf. POH. 1/19/2013 In progress CTU #3 w/ 1.75" CT (CTV =33.2) Scope: Add perfs RIH w/ SWS 2.0" perf gun #2 and perforate 12035 - 12060' w/ 6 spf. POH. At surface stack down to inspect injector. RIH w/ SWS perf gun #3 and perforate 12010 - 12035' w/ 6 spf. POH. RIH w/ PDS MGR /CCI to 12000'. Log coil flag to 10300' and paint flag at 11500' 1/19/2013 In progress CTU #3 w/ 1.75" CT (CTV =33.2) Scope: Add perfs RIH w/ SWS 2.0" perf gun #2 and perforate 12035 - 12060' w/ 6 spf. POH. At surface stack down to inspect injector. RIH w/ SWS perf gun #3 and perforate 12010 - 12035' w/ 6 spf. POH. RIH w/ PDS MGR /CCI to 12000'. Log coil flag to 10300' and paint flag at 11500' 1/19/2013 In progress CTU #3 w/ 1.75" CT (CTV =33.2) Scope: Add perfs RIH w/ SWS 2.0" perf gun #2 and perforate 12035 - 12060' w/ 6 spf. POH 1/19/2013 In progress CTU #3 w/ 1.75" CT (CTV =33.2) Scope: Add perfs Finish POH w/ PDS MGR /CCL. Determined +14' depth correction. RIH w/ SWS 2.0" perf gun and perforate 11550 - 11575' w/ 6 spf. When back at surface make up SWS 2.0" perf gun and perforate w/ 6 spf. 1/20/2013 In progress CTU #3 w/ 1.75" CT (CTV =33.2) Scope: Add perfs Finish POH w/ PDS MGR /CCL. RIH w/ SWS 2.0" perf gun and perforate 11550 - 11575' w/ 6 spf 1/20/2013 In progress Daily Report of Well Operations ADL0028334 CTU #3 w/ 1.75" CT (CTV =33.2) Scope: Add perfs Finish POH w/ PDS MGR /CCL. Determined +14' depth correction. RIH w/ SWS 2.0" perf gun run #4 and perforate 11550 - 11575' w/ 6 spf. POH. RIH SWS 2.0" perf gun run #5 and perforate 11525 - 11550' w/ 6 spf. POH. FP wellbore w/ McOH. RD. Can't LD mast due to wind 30 -40 mph. Go to weather ticket at midnite 1/20/2013 In progress CTU #3 - 1.75" Coil ***Continued from WSR 1- 20 -13 * ** Finish rig down unit after weather subsided. Unable to leave location due to tractor issues. 1/21/2013 ..Continued on WSR 1- 22 -13... CTU #3 - 1.75" Coil ** *Continued from WSR 1- 21 -13 * ** Continue Rig down unit. Having tractor issues. Going on Weather at 10:00 1/22/2013 ...In Progress.. FLUIDS PUMPED BBLS 7 DIESEL 552 60/40 METH 2341 1% SLICK KCL 228 1% SLICK KCL WITH SAFELUBE 176 METH 3304 TOTAL Perforation Attachment ADL0028334 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 17 -03A 7/22/2010 BPP 10802 10817 8909.8 8919.8 17 -03A 7/22/2010 BPP 11070 11079 9009.87 9011.42 17 -03A 7/22/2010 BPP 11206 11210 9017.53 9017.46 17 -03A 1/20/2013 APF 11525 11550 9024.02 9025.03 17 -03A 1/20/2013 APF 11550 11575 9025.03 9025.96 17 -03A 7/22/2010 BPP 11575 11600 9025.96 9026.83 17 -03A 7/22/2010 BPP 11740 11770 9031.65 9033.58 • 17 -03A 7/22/2010 BPP 11800 11830 9036.35 9039.58 17 -03g, 7/22/2010 BPP 11830 11840 9039.58 9040.72 17 -03A - 1/12/2013 ---- BPP 11940 ----- 11"97O -------- 904 9051. 17 -03A 1/12/2013 BPP 11970 11980 9051.86 9052.5 \\ 17 -03A 1/20/2013 BPP 12010 12035 9054.08 9055.04 17 -03A 1/20/2013 APF 12035 12040 9055.04 9055.2 17 -03A 1/20/2013 APF 12040 12060 9055.2 9055.81 17 -03A 1/20/2013 BPP 12060 12100 9055.81 9056.96 .. 17 -03A 1/20/2013 APF 12130 12155 9057.47 9057.6 � fIL- - - " - '\ 'FttL - - - - -- \ - % STRADDLE ' ' , OPEN / SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF III 1 Casing / Tubing Attachment ADL0028334 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H -40 30 - 110 30 - 110 1530 520 LINER 5 3 -1/2" 8.81# L -80 10670 - 10675 8818.38 - 8821.78 LINER 1690 2 -7/8" 6.5# L -80 10675 - 12365 8821.78 - 9063.19 10570 11160 PRODUCTION 10791 9 -5/8" 47# L -80 28 - 10819 28 - 8921.07 6870 4760 SURFACE 2669 13 -3/8" 72# L -80 29 - 2698 29 - 2698 4930 2670 TUBING 10701 4 -1/2" 12.6# L -80 27 - 10728 27 - 8858.19 8430 7500 • s TREE= FMC WH LFEAD= FMC SY NOTES: wet ANGLE> 70° Q 10945'. 1 ACTUATQR= BAKE C 17 -03A KB. T3EV = 70.0' BF. ELEV = NA KOP 3550' I 2192' H4 OM I SSSVN, D = 3.813" I Mans Angle = 91° @ 11195' Datum MD= 10745' Datum TV D = 8800' SS GAS LIFT MANDRELS ST RED 1VD DEV TYFE VLV LATCH PORT DATE I 13 - 3/8° CSG, 72#, L - 80, D = 12.347" H 2688' , 1 3007 3007 0 SNAG DOME RK 16 09/10J10 2 5215 4942 45 MMG DOME RK 16 09/10/10 3 7160 6385 41 MMG DOME FE 16 09/10110 I I -I I 4 8324 7258 44 MMG MY FE 0 09/10/10 5 8901 7644 48 MMG DMY FE 0 03/26/90 Minimum ID = 2.387" 10674' 6 9479 8041 45 MMG SO FE 24 09/10/10 7 9938 8353 51 MMG DMY FE 0 03/26/90 3 -1/2" X 2 -7/8" LNR XO 8 10396 8638 50 MMG DMY RK 0 09/10/10 * t:HEMCAL MANDRELS ( MYIG -LTS ) C NT MD TVD DEV TYFE VLV LATCH PORT DATE L 10502 8707 49 MMG DMY RK 0 07/21/92 141/2" TBG - PC, 12.6#, L - 80, .0152 bpf, D = 3.958" H 10605' I _1 10606' H4_112" BKR GBH LOC SEAL ASSY, D = 3.875'1 10608' H9 -5/8" X 4-1/2" BKR DB R(R, D = 4.750" I i 1062T H4-1/2' BKR SEAL BORE ECT, D = 629° I 13 BKR DEPLOY SLV , D = 3.00" H 10670' I 13 X 2 -718" LNR XO, D= 2.387" H 10674' I 1 1 1 1 1 1 •1 I 10716' H 4 OTIS XN NP, MLLED TO 3.80" D I 14 -1/2" TTP -IPC, 12.8#, L -80, .0152 bpf, ID= 3.958" H 10727' 1 �1 �1 �1 / 1 1 D 4 ►1/1141 10728' H4-1/2" {AILED, D = 3.958" (BEHIND LNR) I 1111 ►1* * $ PERFORATION SLIMMRY 1 1 1 1 1 1 4 ,1 1 1 1 REF LOG: SWS MEMORY GR/CCL ON 12/25/98 1 4 9-5/8" CSG M LOUT WINDOW ANGLE AT TOP FERF: 45° r' 10802' 1111 ♦ ••••••. 10814' - 10819' (OFF CxuTT RAW Note: Refer to Production DB for historical perf data • , ••••••••■ 5;17F SFF MHWAL Opn/Sgz SHOT SQZ 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11 ` 2' 6 10802 -10817 0 05/06/01 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 2" 6 11070 -11079 0 05/06/01 • 1.4 .4 .4 .11.1...1.1 ___ 112tiELT121U_ -- _2 -- z 0 \ 2" 6 11525 - 11575 0 01/20/13 2" • 1550-11.11 0 1' ` ( 12294' I— MR 2 -7/8" CSP M1.® 2" 8 11740 - 11770 0 12/24/98 2" 8 11800 - 11830 0 12/24/98 & PUSHED (01/18113) 2" 4 11830 - 11840 0 03/20/98 2" 8 11940 - 11970 0 09/24/99 2" 4 11970 - 11980 0 09/24/99 FOLD 12336' 2" 8 1201d,1204�Q_.__ O 0j1/2 4 CZ - 6 12010 - 12060 0 0120/13 4 1 4..q -1 is 0 0924' C 2" 6 12130 -12155 0 01/20/13 ,/�1t ...-- 1 9-518' CSG, 47 #, L-80, D = 8.681" 11866' I 12 -7/8" LM , 6.5#, L-80, .0058 bpf, D = 2.441" H 12365' DATE REV BY COMMENTS DATE REV BY CONSENTS I PRUDHOE BAY (NT 08/29/80 CRIGINAL COMPLETION 01/28/13 CJS/JMD MILLED CEP & ADPERFS (01/18- 20/13) WELL: 17 -03A 03123190 MO PERMIT No: 1972160 03/20/98 CTD SIDETRACK (17 -03A) AR Na: 50 -029- 20492 -01 09/02/08 JLJIPJC GLV CIO (08/16108) SEC 22, T10N, R15E 2604' RC & 475' FWL 0728/10 ?/ PJC TREE CYO (07/16/10) 09/21/10 C.#4/PJC GLV C/O (09110/10) BP B ploration (Alaska) OPERABLE: Producer 17 -03A (PTD #19721•AxOA Manageable by bleeds Page 1 • Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, October 16, 2011 1:39 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead Cc: Walker, Greg (D &C); Huebel, Ross ; Arend, Jon (NORTHERN SOLUTIONS LLC); Olson, Andrew; Reynolds, Charles (Alaska) Subject: OPERABLE: Producer 17 -03A (PTD #1972160) IAxOA Manageable by bleeds Attachments: 17 -03A TIO Plot 10- 16- 11.doc All, Prodcuer 17 -03A (PTD #1972160) passed an OA Repressurization Test performed 10/9- 10/14/2011. The OA build up rate during the test was -14 psi /day making the well manageable by bleeds. The well is reclassified as Operable. An updated TIO Plot is attached for reference: «17 -03A TIO Plot 10- 16- 11.doc» Thank you, Melireen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: Reynolds, Charles (Alaska) Sent: Wednesday, October 05, 2011 4:04 PM To: AK, D &C Well Integrity Coordinator; 'Maunder, Thomas E (DOA)'; 'Regg, Ja - B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Oper- ors; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C • Services Operations Team Lead Cc: Walker, Greg (D &C); Clingingsmith, Mike 3 (Swift); Huebel oss Subject: UNDER EVALUATION: Producer 17 -03A (PTD fk 972160) Sustained OA Pressure Above MOASP z All Producer 17 -03A (PTD #1972160) was found with sustained casing pressure above MOASP on the OA. The wellhead pressures were,tubing /IA/OA equal to 304/1640/1100 psi on 10/01/11. The well has been reclassified as Under Evaluation and may be produced while diagnostics are conducted. The plan forward is s follows: 1. DHD: OA Re essurization Test 2. W: PPPO -IC 11/2/2011 PBU 17 -03A PTD # 1972160 10/16/2011 TIO Pressures Plot Wet 17-03 4,000 3,000 • – ♦ Tbg –IA 2,000 . -A_ OA 00A t 000A —On 1.000 Ali Ill A rip 07/16/11 07/23/11 07/30/11 08/06/11 08/13/11 08/20/11 08/27/11 09/03/11 09/10/11 09/17/11 09/24/11 10/01/11 10/08/11 10/15/11 • UNDER EVALUATION: Producer 17 -, (PTD #1972160) Sustained OA Pres. Above MO... Page 1 of 1 Regg, James B (DOA) From: Reynolds, Charles (Alaska) [Charles. Reynolds @bp.com] Sent: Wednesday, October 05, 2011 4:04 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Huebel, Ross Subject: UNDER EVALUATION: Producer 17 -03A (PTD #1972160) Sustained OA Pressure Above MOASP Attachments: 17- 03A.pdf; Producer 17 -03A TIO (PTD #1972160).doc All, tg72.i4,0 Producer 17 -03A (PTD #204 found with sustained casingpressure above MOASP on the OA. The wellhead pressures were tubing /IA/OA equal to 304/1640/1100 psi on 10/01/11. The well has been reclassified as Under Evaluation and may be produced while diagnostics are conducted. The plan forward is as follows: 1. DHD: OA Repressurization Test O,4 Se P = ZO , +sic ,M1-( p 2. W: PPPOT -IC NO 1 (€ c*— A TIO plot and wellbore schematic have been included for reference. «17- 03A.pdf» «Producer 17 -03A TIO (PTD #1972160).doc» Thank you, Charles Reynolds - - ; �` • Filling in for... Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 10/6/2011 PBU 17 -03A PTD # 1972160 10/5/2011 TIO Pressures Plot Well: 17 -03 I 3,000 Tbg --M— IA -A- OA 2,000 00A OOOA On 1,000 - i w 111 .0 03/12/11 03128/11 , 04/09/11 04/23/11 05/07/11 05/21/11 08!04/11 - 06/18/11 07/02/11 07/16/11 07130/11 08/13/11 08/27/11 09/10/11 - 09/24/11 • TREE = FMC WELLHEAD = FMC 1 SAFETY N*: WELL ANGLE > 70° @ 10945'. 7-03A I ACTUATOR= BAKER C Ka ELEV = 70.0' 6T. ELEV = NA 2192' H4-1/2" OTIS HRQ SSSVN, ID --= 3.813" I Max Angle = 91 @ 11195' 0 Datum MD = 10745 GAS LIFT MANDRELS Datum - ND = 8800' SS ST MD TVD DEV TYPE VLV LATCH PORT DATE k 1 3007 3007 0 MMG DOME RK 16 09/10/10 13-3/8" CSG, 72#, L-80, ID = 12.347" 1--1 2698' Hi 2 5215 4942 45 MMG DOME RK 16 09/10/10 OA- Mr-yp. 53 (.60p; 3 7160 6385 41 MMG DOME RK 16 09/10/10 4 8324 7258 44 MMG DMY RK 0 09/10/10 5 8901 7644 48 MMG DMY RK 0 03/26/90 6 9479 8041 45 MMG SO RK 24 09/10/10 Minimum ID = 2.387" @ 10674' 7 9938 8353 51 MMG DMY RK 0 03/26/90 3-1/2" X 2-7/8" LNR XO 8 10396 8638 50 MMG DMY RK 0 09/10/10 ' * CHEMICAL MANDRELS ( MMG-LTS ) ST MD 'TVD DEV TYPE VLV LATCH PORT DATE C 9 10502 8707 49 MMG DMY RK 0 07/21/92 14-1/2" TBG-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" H 10605' 1 i I 10605' H4-1/2" BKR GBH LOC SEAL ASSY, ID = 3.875" I I MI 1 10608' 1 —1 9 - 5/8 " X 4-1/2" BKR DB PKR, ID = 4.750" I 3-3/4" BKR DEPLOY SLV, ID = 3.00" H 10670' 10627' 1-14-1/2" BKR SEAL BORE IXT, ID = 6.29" 13-1/2" X 2-7/8" LNR X0, ID = 2.387" 1-1 10674' I Fl rgee 10716 H 4 - 1 / 2" OTIS XN NIP, MILLED TO 3.80" ID 1 ; 0 0 i'0• 1 4A4 4-1/2" TTP-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" H 10727' 1 ki w , 0 fr44: 10728' —14-1/2" WLEG, ID = 3.958" (BEHIND LNR) I I 4 4 * 4, Aa PERFORATION SUMMARY i Of 9-5/8" CSG MILLOUT WINDOW REF LOG: SWS MEMORY GR/CCL ON 12/25/98 i A * • ..\ 10814' - 10819' (OFF CMT RAMP) ANGLE AT TOP PUT: 45 @ 10802' Note: Refer to Production DB for historical perf data W 4 \ '... . 4 SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10802 - 10817 0 05/06/01 11900' H2 - 7/8" H2 CIBP (09/24/99) 2" 6 11070 - 11079 0 05/06/01 Ar I 2" 6 11206 - 11210 0 05/06/01 2" 6 11550 - 11600 0 06/17/04 2" 8 11740 - 11770 0 12/24/98 2" 8 11800 - 11830 0 12/24/98 2" 4 11830 - 11840 0 03/20/98 2" 8 11940 - 11970 C 09/24/99 \ H I 2" 4 11970 - 11980 C 09/24/99 :TD 12336' 2" 8 12010 - 12040 C 09/24/99 2" 4 12040 - 12100 C 09/24/99 ■ ' 9-5/8" CSG, 47#, L-80, ID = 8.681" H 11865' 12-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.387" — 1 12365' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/29/80 ORIGINAL COMPLETION WELL: 17-03A - - 03/23/90 RWO PERMIT No: v 1972160 03/20/98 CTD SIDETRACK (17-03A) AR No: 50-029-20492-01 09/02/08 JLJ/PJC GLV C/O (08/16/08) SEC 22, T1ON, R15E, 2604' FNL & 475' FWL 07/28/10 ?/ PJC TREE C/O (07/16/10) 09/21/10 CJN/PJC GLV C/O (09/10/10) BP Exploration (Alaska) OPERABLE: Producer 17 -03A (PTD #1972160) IA x OA communication manigeable by bleeds Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellintegrityCoordinator @bp.com] � � a LCHlO Sent: Saturday, October 30, 2010 8:43 PM l To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, RES GPB Central Prod Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Bommarito, Olivia 0 Cc: Janowski, Carrie; AK, D &C Well Integrity Coordinator Subject: OPERABLE: Producer 17 -03A (PTD #1972160) IA x OA communication manageable by bleeds All, r An OA represurization test was completed on Producer 17 -03A (PTD #1972160) on 10/30/2010. The BUR measured during the five da monitor was 56 si/day, which is deemed manageable by bleeds. The well has been reclassified as perable and may continue on production. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Wednesday, October 27, 2010 8:37 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, RES GPB Central Prod Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Bommarito, Olivia 0 Cc: Janowski, Carrie; Holt, Ryan P (ASRC); AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer 17 -03A (PTD #1972160) Sustained OA Pressure Above MOASP All, Producer 17 -03A (PTD #1972160) has been found to have s ustained casing pressure on the O A above MOASP. The wellhead pressures were tubing /IA/OA equal to 400/1950/1 0 psi on 10/25/10. The well has been reclassified as Under Evaluation and may be produced under a 28 -day clock. The plan forward is as follows: 1. DHD: OA repressurization test A TIO plot and wellbore schematic have been included for your reference. Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/1/2010 PBU 17 -03A PTD # 1972160 10/27/2010 TIO Pressures Plot Well: 17 -03 4,000 1 I • 3,000 i i �r -- Tbg i @in IA 2,000 OA OOA ' OOOA On 1,000 07131110 08/07110 08114110 08121/10 08128110 09104110 09111/10 09118110 09125110 10/02/10 10/09/10 10 10123110 TREE = FMC SAFET TES: WELL ANGLE > 70° a� 10945'. WELLHEAD = FMC ACTUATOR= BAKERC 17 - 0 3 A KB. ELEV = 70.0' BF. ELEV = _NA _ KOP — =— – 3550 2192 4 -1 /2" OTIS HRO SSSV N, ID = 3.813" Max Angle = 91 @ 11195' Datum MD = 10745' Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3007 3007 0 MMG DOME RK 16 09/10/10 13 -318" CSG, 72 #, L -80, ID = 12.347" 269$" 2 5215 4942 45 MMG DOME RK 16 09/10/10 3 7160 6385 41 MMG DOME RK 16 09/10/10 4 8324 7258 44 MMG DMY RK 0 09/10/10 5 8901 7644 48 MMG DMY RK 0 03/26/90 6 9479 8041 45 MMG SO RK 24 09/10/10 Minimum ID = 2.387" tt.,7X 10674' 7 9938 8353 51 MMG DMY RK 0 03/26/90 3-1/2" X 2 -7/8" LNR XO 8 10396 8638 50 MMG DMY RK 0 09/10/10 'CHEMICAL MANDRELS ( MMG -LTS ) C ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 110502187071 49 1 MMG I DMY I RK 1 d 1 07/21/92 4 -1/2" TBG -IPC, 12.6 #, L-80_0152 bpf, ID = 3.958" 10605' 10605 4 -1/2" BKR GBH LOC SEAL ASSY, ID= 3.875" 10608' 9 -5/8" X 4 -1/2" BKR DB PKR, ID = 4.750" 10627' 4 -1/2" BKR SEAL BORE EXT, ID = 6.29" 3 -3/4" BKR DEPLOY SLV, ID = 3.00" 10670' 1 3-1/2" X 2 -7/8" LNR XO, ID = 2.387" 10674' 10716' 4 -112" OTIS XN NIP, MILLED TO 3.80" ID 4 -1/2" TTP -IPC, 12.6 #, L-80_0152 bpf, ID = 3.958" 1072T 1072$' 4 -1/2" WLEG, !D = 3.958" (BEHIND LNR) PERFORATION SUMMARY 9 -5/8" CSG MILLOUT WINDOW REF LOG: SWS MEMORY GR/CCL ON 12/25/98 10814'- 10819' (OFF CMT RAMP) ANGLE AT TOP PERF: 45 @ 10802' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 10802 - 10817 O 05/06/01 11900 2 -718" CIBP (09/24/99 2" 6 11070 - 11079 O 05/06/01 2" 6 11206- 11210 O 05/06/01 2" 6 11550- 11600 O 06/17/04 2" 8 11740 - 11770 O 12/24/98 2" 8 11800 - 11830 O 12/24/98 2" 4 11830 - 11840 O 03/20/98 2" 8 11940 - 11970 C 09/24/99 2" 4 11970 - 11980 C 09/24/99 F PBTD 12336' 2" 8 12010 - 12040 C 09/24/99 2" 4 12040 - 12100 C 09/24/99 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 11865' 2 -7/8" LNR, 6.5 #, L -80, .0058 bpf, ID = 2.387" 12365' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHgE BAY UNIT 08/29/80 ORIGINAL COMPLETION WELL: 17 -03A 03/23/90 RWO PERMIT No: 1972160 03/20/98 CTD SIDETRACK (17 -03A) API No: 50- 029 - 20492 -01 09/02/08 JLJ /PJC GLV C/O (08/16/08) SEC 22, T1 ON, R1 5E, 2604' FNL & 475' FWL 07/28/10 ?/ PJC I TREE C/O (07/16/10) 09/21/10 CJN/PJC I GLV C/O (09/10/10) BP Exploration (Alaska) 09/10/07 Schlumbepger NO. 4406 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth StANNED SEP 1 8 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Well Job# Loa Description Date BL Color CD 17-14 N/A JEWELRY/SBHP JWV\.. J~4 -, l.(_ 08/17/07 1 MPC-10 11767137 MEM iNJ PROFILE I )ï.~ 1"';(.' -DI< 08/13/07 1 17-01 11824337 SBHPS/JEWELRY LOG j'7rl\ -O~.ç- 08/15/07 1 P2-30 11686776 PRODUCTION PROFILE I 'ì ~ - {)C>¡,,,\ 08/25/07 1 L 1-31 11865639 LDL I c...::-- ,- C- 08/14/07 1 P2-10 11846804 PRODUCTION PROFILE /crlr -tA9- 08/17/07 1 17 -03A N/A JEWELRY/SBHP ¡c¡q.-tlll_ 08/17/07 1 C-26 11824342 LDL Iq"jç - 11..J~ 08/22/07 1 15-07C 11594517 SBHP SURVEY .;:)f"'I~- Oc¡-::+ 08/23/07 1 D-04B 11591451 SBHP SURVEY ;)ö3 - II D 08/24/07 1 P2-24 11865643 PRODUCTION PROFILE ¡CiSC - ('\C")'1( 08/21/07 1 P2-03 11855502 PRODUCTION PROFILE 1'1 ~ - fY...I t../ 08/19/07 1 09-44 11855501 SBHP/JEWELRY JO¡I"I - ~ - 08/16/07 1 09-23 11824337 SBHP/JEWELRY 1'7r4 - N..;. 08/16/07 1 2-52/S-41 11846807 PRODUCTION PROFILE J¿¡;' -t"I~~ 08/18/07 1 F-08A 11638646 USIT :)f\~ -0 06/28/07 1 02-16C 11628790 SCMT dbr-()7-t5 08/24/07 1 L2-32 11695060 RST I ,.,..." . I.....,~ _I~-':} .. t."'í /q l,.;. OS/23/07 1 1 L5-09 11492259 RST ICif1 - 1;:)4 ~ ,K(//':J. 11/11/06 1 1 02-12B 11767132 MCNL .9C{':} -(""\.<;"'$r ..,. I~Jd.. 06/21/07 1 1 18-09B 11366500 MCNL 1'1'1r-- ('I"":."k :t. t.",,\J..[ let 1 0/23/06 1 1 G-14A 11485777 MCNL /0,"8' -()~":1\ 'it /!'\'-IQ..ò 11/27/06 1 1 05-20B 10942220 MCNL :J(}Lf - !:I-:<¿¡ .. 1.'''1<-/ JJ 1 06/26/05 1 1 PLEASE ACKNOWLEDGE RECEIPT BY Atdn r\T~I~NE COPY EACH TO: BP Exploration (Alaska) Inc. f~~E:J~E~'~ 'Ii ¡L",L.i Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 ., 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage. Alaska 99508 SEP L\ 007 Anchorage. AK 9' '''~'2 . ATTN: Beth i. Received bY:C/~. Â---- Date Delivered: , C·' \ Olll1l1ia]10[ì 'I I" 1"'\:1 Ü ¡ ,,.', (}P') , , /\' ::]:;,)ì<;:~ "'_;~ ,') \yl;~, , ,h . . REf' n D DEe 1 (; Z005 a STATE OF ALASKA a ALA_ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS Stimulate 0 Afa£àìbocQ ',;" , , , ' . WaiverD Time~'xt:~i6~¡OU'~' 'J~':¡t., .,,,,,;;ïlISSI 11 Re-enter Suspended Well o Anchorttge 5. Permit to Drill Number: 197-2160 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Class: Development P' Stratigraphic 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Exploratory Service 6. API Number: 50-029-20492-01-00 9. Well Name and Number: 17 -03A 70 KB 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool 8. Property Designation: ADL-028334 11. Present Well Condition Summary: Plugs (measured) 11900 CI BP, 10670 L TT Junk (measured) None feet feet measured 12590 true vertical 9068.6 Total Depth feet feet measured 12336 true vertical 9062.33 Effective Depth 8ÇAN~~f[, n F 5' <j r)rí ni) .....-' -,~ '.",:' d {...·,.J'Vu TVD 33 - 113 32 - 2698 28 - 9043.44 8818.38 - 8821.78 8821.78 - 9063.19 Collapse 520 2670 4760 10530 11160 Burst 1530 5380 6870 10160 10570 Length Size MD 80 20" 94# H-40 33 - 113 2666 13-3/8" 72# L-80 32 - 2698 11837 9-5/8" 47# L-80/S00-95 28 - 11865 5 3-1/2" 9.3# L-80 10670 - 10675 " 1690 2-7/8" 6.5# L-80 10675 - 12365 Casing Conductor Surface Production Liner Liner 11740 - 11770 Open 12040 - 12100 Closed 9031.65 - 9033.58 Open 9055.2 - 9056.96 Closed 11550 - 11600 Open 11970 - 11980 Closed 9025.03 - 9026.83 Open 9051.86 - 9052.5 Closed 11206 -11210 Open 11940 - 11970 Closed 9017.53 - 9017.46 Open 9049.8 - 9051.86 Closed 11070 -11079 Open 11830 - 11840 Open 9009.87 - 9011.42 Open 9039.58 - 9040.72 Open Perforation depth: Measured depth: 10802 - 10817 Open 11800 - 11830 Open True Vertical depth: 8909.8 - 8919.8 Open 9036.35 - 9039.58 Open 27 - 43 43 - 10728 L-80 L-80 5-1/2" 17# 4-1/2" 12.6# Tubing: (size, grade, and measured depth) 10608 4-1/2" Baker DB Packer Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure SHUT-IN SHUT-IN 15. Well Class after proposed work: Exploratory Development P' 16. Well Status after proposed work: Oil P' Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RBDMS BFl DEt r 9 2D05 13. Tubing pressure Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service x WDSPL Contact Sharmaine Vestal Title Data Mgmt Engr Printed Name Sharmaine Vestal Signatu~~ Date 12/12/2005 Phone 564-4424 Submit Original Only Form 10-404 Revised 04/2004 ~ e e " 17-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 11/5/2005·***CONT. FROM 11/4/05***(Secure Well) BRUSH LINER TOP @ 10,619 SLM MADE TWO ATTEMPTS TO LATCH LINER TOP, UNSUCCESFULL 3.75" LIB RAN TO CHECK FN CONDITION - GOOD IMP OF G FN. RUN 2.8 SWEDGE THROUGH LINER TOP, SAT DOWN IN XO @ 10,630 ***CONT. ON 11/6/05*** 11/6/2005 ***CONT. FROM 11/5/05*** MADE SEVERAL ATTEMPTS WITH VARIOUS TOOL CONFIG. TO LATCH LINER TOP. NEVER ABLE TO LATCH. GOING TO SET L TTP IN FUTURE, BUT NEED TO RELOAD THE TUBING. NO PUMP TRUCKS AVAILABLE AT PRESENT TIME, WILL COME BACK AT LATER DATE. RDMO. ****LEFT WELL SHUT-IN**** 11/15/2005 ***WELL SI ON ARRIVAL*** RAN 3.75" GAUGE RING TO TOP OF LINER TOP-TAGGED @ 10627' SLM, CALIPER TBG FROM 10627' SLM TO SURFACE, GOOD DATA FROM CALIPER, PUMP TRUCK NOT AVAILABLE TO COMPLETE JOB PER PROGRAM, WILL RETURN @ A LATER TIME. ***WELL LEFT S/I*** 11/17/2005 ***WELL SI ON ARRIVAL*** (secure well) RIG UP SLlCKLlNE UNIT, STBY FOR PUMP TRUCK TO LOAD TUBING. ***CONTINUE WSR TO 11-18-05*** 11/18/2005 TIO=200/1000/320 LOAD TBG SHUT IN ON ARRIVAL SECURE WELL SPEARED IN TBG W/10 BBLS OF 50* 60/40 METH H20 FOLLOWED BY 196 BBLS OF 75* 1 % KCL CAPED W/40 BBLS OF 40* 60/40 METH H20 FWHP= 150/1100/300 11/18/2005 ***CONTINUE WSR FROM 11-17-05*** (secure well) LRS PUMPED 196 BBLS KCL, 40 BBLS 60/40 METH DOWN TUBING SET 4.5" L TTP @ 10643' SLM, PUMP TRUCK UNAVAILABLE TO TEST PLUG ***TURN WELL OVER TO DSO, LEFT WELL SHUT IN*** FLUIDS PUMPED BBLS 196 1 % KCL 50 MeOH 1 Diesel 247 TOTAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Repair Well 0 AbandonD PluQ Perforations 0 Stimulate D OtherD Alter Casing D Pull TubingO Perforate New Pool D WaiverD Time ExtensionO Change Approved ProgramD Operation Shutdown 0 Perforate IK] Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceD 5~29-20492-o1-o0 7. KB Elevation (ft): 9. Well Name and Number: 70.00 17-o3A 8. Property Designation: 10. Field/Pool(s): ADL-0028334 Prudhoe Bay Field / Prudhoe 011 Pool 11. Present Well Condition Summary: Total Depth measured 12590 feet true vertical 9068.6 feet Plugs (measured) 11900 Effective Depth measured 11900 feet Junk (measured) None true vertical 9046.7 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 33 - 113 33.0 - 113.0 1530 520 Liner 5 3-1/2" 9.3# L-80 10670 - 10675 8818.4 - 8821.8 10160 10530 Liner 1710 2-7/8" 6.5# L-80 10675 - 12385 8821.8 - 9063.6 10570 11160 Production 9450 9-5/8" 47# L-80 28 - 9478 28.0 - 8040.0 6870 4760 Production 2387 9-5/8" 47# 500-95 9478 - 11865 8040.0 - 9043.4 8150 5080 Surface 2666 13-3/8" 72# L-80 32 - 2698 32.0 - 2698.0 4930 2670 Perforation depth: Measured depth: 10802 -10817,11070 -11079,11206 -11210,11550 -11575,11575 -11600,11740 -11770,11800 -11830 11830 -11840 True vertical depth: 8909.8 - 8919.8,9009.87 - 9011.42,9017.53 - 9017.46,9025.03 - 9025.96,9025.96 - 9026.83,9031.65 - 9033.58 9036.35 - 9039.58, 9039.58 - 9040.72 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 @ 27 - 43 RECEIVED 4-1/2" 12.6# L-80 @ 43 - 10728 SEP - 3 2004 Packers & SSSV (type & measured depth): 4-1/2" Baker DB Packer @ 10608 .. . -....... " - 12. Stimulation or cement squeeze summary: ""101". \I" .... ....... Intervals treated (measured): Anchorage Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaoe Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl Casino Pressure TubinQ Pressure Prior to well operation: 183 0.4 1799 1320 274 Subsequent to operation: 161 0.4 1652 1320 289 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations. ! OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 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 Garry Catron NIA Printed Name Garry Catron Title Production Technical Assistant Signature ~r- .. ~ ~ C~iT.~ Phone 564-4657 Date 8/31 /04 1\ Form 10-404 Revised 4/2004 ORIGINAL RBDMS BFL SEP 0 3 20fPt 17-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/16/04 CTU #5, ADD PERF; MIRU DS CTU #5. SHUT WELL IN AT WING. RIH WITH PDS MEMORY GR/CCL INSIDE 2.2" CARRIER. LOG INTERVAL 11750' UP TO 11250' CTMD. FLAG PIPE AT 11600' CTMD. POOH. MU/RIH W GUN #1: 25' OF 2" PJ. TIE IN TO FLAG. PERFORATE 11575'-11600'. POOH. MU/RIH W/ GUN #2: 25' OF 2" PJ. TIE IN TO FLAG. DROP BALL, CONTINUED ON 06/17/04 WSR. 06/17/04 Perforate 11550'-11575' 6 SPF FLUIDS PUMPED BBLS 227 227 11 % KCL TOTAL Page 1 TREE = 5-118" M:B'OY WElLI-EAD - FM:: ACfUATOR = AXELSON KB. ELEV = 70.0' BF. ELEV = N.J.\ KOP= 3550' Max Angle = 91 @11195' Datum MD = 10745' Datum lVD = 8800' SS 17-03A SAÆTY NOTES: ***TxIAxOA COMM, OPERATIIIG LIMITS: MAX lAP = 2000 PSI, MAX OAP = 2000 PSI (09/21/03 WAIVER)*** WaLANGLE> 70o@ 10945' & > 90o@ 11163', . 2192' 4-1/2"011S I-RQSSSVN,ID=3.813" c ST MD 1 3007 2 5215 3 7160 4 8324 5 8901 6 9479 7 9938 8 10396 Oð.TE 03126198 03126198 12/12/99 03126190 03126190 12/12/99 03126190 02/14/98 13-3/8" CSG, 72#, L-80,ID = 12.347" Minimum ID = 2.387" @ 10674' 3-112" X 2-7/8" LNR XO 4-1/2" TBG-IFC, 12.6#, L-80, .0152 bpf, ID = 3.958" 10605' 4-1/2" BKR GBH Lac SEAL ASSY, ID = 3.875" 9-5/8" X 4-112" BKR DB PKR, ID = 4.750" 10627' 4-1/2" BKR SEAL BORE EXT, D = 6.29" 3-3/4" BKR DEPLOY SLV, D = 3.00" 3-1/2" X 2-7/8" LNRXO, ID = 2.387" 10716' 4-1/2" 011S XN fliP, MILLEDT03.80"ID 4-1/2" TTP-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" 10727' 10728' 4-1/2" WLEG, ID = 3.958" (BEHND LNR) PERFORATION SUMMARY REF LOG: SWS MEMORY GR/CCL ON 12/25/98 ANGLEATTOPPERF:45@10802' flbte: Refer to A"oductbn DB for historical perf data SIZE SPF INTERVAL Opn/SQz oð. TE 2" 6 10802 -10817 0 05l06¡Q1 2" 6 11070 -11079 0 05l06,Q1 2" 6 11206-11210 0 05l06,Q1 2" 6 11550 - 11600 0 06l17,Q4 2" 8 11740-11770 0 12/24/98 2" 8 11800-11830 0 12/24/98 2" 4 11830-11840 0 03120/98 2" 8 11940-11970 C 09/24/99 2" 4 11970-11980 C 09/24/99 2" 8 12010 - 12040 C 09/24/99 2" 4 12040 - 12100 C 09/24/99 9-518" CSG, 47#, L-80, ID = 8.681" 11865' 9-518" CSG MlLOUT WINDCNV 10814'- 10819' (OFFCMT RAMP) DATE REV BY COMMENTS DATE REV BY COMMENTS 08129/80 ORIGINAL COMPLETION 06/17/04 DBM'KAK ADÆRFS 03/23190 RWO 03120/98 CTD SlDErRACK (17-03A) 12/29/01 CHlfP CORREC110NS 09/02/03 KC/TLH WAIVERSAFETY NOTE 09/21/03 KDClfLP WAIVERED WELL PRUŒiOEBAY UNIT WElL: 17-O3A ÆRMIT fib: 1972160 API fib: 50-029-20492-01 SEe 22, T10N, R15E26O4' FNL & 475' FWL BP EKploration (Alaska) .... STATE OF ALASKA ~__ ALASKA OIL AND GAS CONSERVATION COMMISSION 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 BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development ___X Exploratory_ Stratigraphic_~ Sen,'ice.__ 4. Location of well at surface 2600' FNL, 4804' FEL, Sec. 22, T10N, R15E, UM At top of productive interval 4451' FNL, 1081' FEL, Sec. 21, T10N, R15E, UM At effective depth (asp's 708731, 5928026) (asp's 707230, 5926137) At total depth 378' FNL, 4894' FEL, Sec. 28, T10N, R15E, UM (asp's 703456, 5924824) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12590 feet Plugs (measured) 9069 feet 11900 feet Junk (measured) 9047 feet 6. Datum elevation (DF or KB feet) RKB 70 feet 7. Unit or Property name Prudi;oe Bay Unit 8. Well number 17-03A 9. Permit number / approval number 197-216 10. APl number 50-029-20492-01 11. Field / Pool Prudhoe Bay Oil Pool Tagged CIBP @ 11900' MD (10/26/1999) Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 300 Sx PF 110' 110' Surface 2628' 13-3/8" 215o Sx Fondu & 400 Sx PF II 2698' 2698' Production 10743' 9-5/8" 1400 Sx Class G 10813' 8917' Liner 1693' 3-1/8"/2-7/8" 14 bbls LARC 10675' / 12363' 8822' / 9063' Perforation depth: measured 10802' - 10817'; 11070' - 11079'; 11203' - 11210'; 11740' - 11770'; 11800' - 11840'; (Peals isolated below ClBP are 11940' - 11980'; 12010' - 12100'). true vertical 8910' - 8920'; 9010' - 9011'; 9018' - 9017'; 9032' - 9034'; 9036' - 9041'; (Perfs isolated below ClBP are 9050' - 9053'; 9054' - 9057'). Tubing (size, grade, and measured depth) 4-1/2"12.6ff, L-80 PCT RECEIVED Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2' BAKER DB PACKER @ 10609' MD. 4-1/2' OTIS HRQ SSSV @ 2193' MD. MAY 1 i Z001 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure (see attached) Alaska Oil & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation OiI-Bbl 132 198 Representative Daily Average Production or Iniection Data Gas-Mcr Water-Bbl 30 1338 n/a 1504 Casing Pressure Tubing Pressure 287 293 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 hereby certify thaJ.th, e forego~ing is true and correct to the best of my knowledge. Title: DS 17 Surveillance~ Engineer Signed '~ ~~ Danlelle Ohms Date May 10, 2001 Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · ORIGIi\!AL SUBMIT IN DUPLICATE MEMORANDUM TO: Julie Heusser Commissioner State of Alaska Alaska Oil and Gas Conservation CommissiOn DATE: DeCember 15, 2000 THRU: Tom Maunder, P. I. Supervisor ~.¢_\% ?~:~:~'"~ FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit Drill Site 17 Friday, December 15, 2000: I traveled to BPX's Drill Site 17 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 15 wells and 30 components with one failure. The Surface Safety Valve on Well 17-4 Failed to close on its initial test. After this valve was serviced and the' hyd lines flushed it operated properly and passed the retest. Mark Womble performed the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspected the wellhouses on this location while witnessing SVS tests. All the wellhouses and associated equipment appeared clean and in good condition : Summary: I witnessed SVS testing at BPX's PBU Drill Site 17. PBU DS17, 15wells 30 components 1 failure 3.3% failure rate 19 Wellhouse inspections' Attachment: SVS PBU DS17 12-15-00 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: BPX Submitted By: Chuck Scheve Date: 12/15/00 Operator Rep: Mark Womble Fielcl/U~ad: Prudhoe / PBU / DS 17 AOGCC Rep: Chuck Scheve . Separator psi: LPS 165 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 17-01 i800550 ' 165 150 130 P P ' 17-02 1800700 165 150 100 P P OILI 17-03A 1972160 165 150 110 P P OIL , 17-04A 1960500 165 150 120 P 5 12/15/00 OIL 17-05 1800960 165 150 110, P P OIL 17-06 1801320! 17-07 1810660 165 150 140' P P oil 17-08 18107401 17-09 1810900! 165 150 100 P P oil ,,, 17-10A 1991100! 17-11 18424401 f65 "' 150. 120 P P OIL 17-12 18424501 165 150 120 P P OIL! 17-13 1841790 165 150 110 P P OIL 17-14 1841660 165 150 140 P P OIL 17-15A 1991310 ,, 17-16 1920910 165 150 130 P P OIL 17-19A 19705501 ~65 150 130 P P OIL 17-20 1921150 165 '" 150 120 P P OIL 17-21 19212501 165 150 130 P P ' OIL . Wells: 15 Remarks: Components: 30 Failures: 1 Failure Rate: Surface Safety on 17-4 failed to close, it was serViced and retested. 3,3% [~ 90 Day 10/1 O/(Ifl Page 1 of 1 SVS PBU DS17 12-15-00 CS.xls ~THE. MATERIAL UNDER THIS COVER ~S BEEN_-- ON OR BEFORE PL M___~_A T E IA THIS E L U N D Wr M ~ E R A R K E R Well Compliance Report File on Left side of folder 197-216-0 PRuDHoE BAy UNIT 17-03A 50- 029-20492-01 ARCO MD 12590~' TVD_0906~. etion Date: 3/20/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D D 8430 I-I,~/SPERRY GR OH 5/6/98 5/6/98 D 8431 ~ SPERRY GR PB1 OH 5/6/98 5/6/98 D 8833 ~ SCHLUM IEL/BHC OH 12/17/98 1/5/99 L BHC AC/GR ~NAL 10750-12406 PB1 OH 3/22/98 3/31/98 , L IEL/GR I~N, AL 10750-12406 PB1 OH 3/22/98 3/31/98 L NGP-MD ~NAL 10718-12590 OH 5/6/98 5/6/98 L NGP-MD ~INAL 10694-12640 PB1. OH 5/6/98 5/6/98 L NGP-TVD F~INAL 8847-8998~ OH 5/6/98 5/6/98 L NGP-TVD LfflNAL 8847-8980 PB1 OH 5/6/98 5/6/98 . R SRVY E~RRY 11528.19-12590. OH 4/3/98 4/8/98 · R SRVY ~RRY 10700.-12640. PB1 OH 4/3/98 4/8/98 Daily Well Ops~/,~ ~[/¢I~ ~/~ 6p/~/L[9 Was the well cored? yes ~n~2.~, -~' Are Dry Ditch Samples Required? yes ~~And Re. ' . Analysis Description Receiv o. e ~ ..... Comments: Tuesday, April 04, 2000 Page 1 of l STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X(ClBP & Frac) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2600' FNL, 4804' FEL, Sec. 22, T10N, R15E, UM At top of productive interval 4451' FNL, 4198' FWL, Sec. 21, T10N, R15E, UM At effective depth At total depth 378' FNL, 4894' FEL, Sec. 28, T10N, R15E, UM 5. Type of Well: Development__X Explorato~__ Stratigraph lc__ Service__ 6. Datum elevation (DF or KB feet) RKB 70 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 17-03A 9. Permit number / approval number 97-216 10. APl number 50-029-20492-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 1 10' Surface 2628' Production 10743' Liner 1693' 12590 feet Plugs (measured) 9069 feet 1 1900 feet Junk (measured) 9047 feet Tagged CIBP @ 11900' MD (10/26/1999) ORIGINAL Size Cemented Measured Depth True vertical Depth 20" 300 sx PF 110' 110' 13-3/8" 215o sx Fondu & 400 Sx PF II 2698' 2698' 9-5/8" 1400 Sx Class G 10813' 891 7' 3-1/8"/2-7/8" 14 bbls LARC 1 0675' / 12363' 8822' / 9063' Perforation depth: measured 11740' - 11770'; 11800' - 11840'; (Perfs isolated below CIBP are 11940' - 11980'; 12010' - 12100'). true vertical 9032' - 9034'; 9036' - 9041'; (Perfs isolated below CIBP are 9050' - 9053'; 9054' - 9057'). Tubing (size, grade, and measured depth) 4-1/2"12.6#, L-80 PCT @ 10670' MD; 4-1/2"12.6#, L-80 PCT @ 10727' MD. Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2" BAKER DB PACKER @ 10609' MD. 4-1/2" OTIS HRQ SSSV @ 2193' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Shut in Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 280 168 3498 Casing Pressure Tubing Pressure 298 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 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title ARCO EngineeringSupervisor Erin 0 Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 17-03A "- DESCRIPTION OF WORK COMPLETED SET ClBP & HYDRAULIC FRACTURE TREATMENT Date Event Summary 9/23/1999: 9/24/1999: 9/26/1999: 9/28/1999: 10/01/1999: Jetted hydrates, hot oiled tubing f/430' to 4500' CTM, FCO. Tagged PBTD @ 12299' CTM. RIH & set CIBP @ 11900' MD to isolate the perforation intervals listed below: 11940' - 11980' M D (Zone 4) 12010' - 12100' MD (Zone 4) RIH & DGLV's. Set 4-1/2" Frac Sleeve to 2163' MD. MITIA to 3000 psi- passed. MIRU & PT'd equipment to 8300 psi. Performed a FB Hydraulic Fracture Treatment using 20/40 mesh ceramic proppant through the open perforation intervals listed below: 11740' - 11770' MD (Zone 4) 10800' - 11840' MD (Zone 4) Pumped: (a) 250 bbls Pre-Pad @ 20 bpm, followed by shutdown. ISIP @ 2242 psi. (b) 20 bbls 1 ppg scour stage @ 20 bpm, (c) 200 bbls flush @ 20 bpm, followed by (d) Shutdown. ISIP @ 1780 psi. Resumed pumping Datafrac Treatment: (e) 40 bbls 40# Crosslinked Gel @ 20 bpm, followed by (f) 165 bbls 20# Linear Gel Flush @ 5-20 bpm, followed by (g) Shutdown. Closure press - 1474 psi. Resumed pumping Frac Treatment: RECEIVED ! ,iO V 0 1999 Alasla Oil & 6as Cons, CommOn Anchorage (h) 35 bbls 40# Crosslinked Pad @ 20 bpm, followed by (i) 100 bbls Crosslinked Slurry @ 20 bpm w/proppant stages @ 2-12 ppg, followed by (j) Flush to top perforation, followed by (k) Shutdown. 10/03/1999: 10/26/1999: Placed a total of 24571 lbs of proppant into FM. This was 98% of the design amount. Max proppant concentration placed was 12 ppg. This well was treated at an ave surface press of 4300 psi @ 20 bpm. RD. RIH & pulled Frac Sleeve. RIH & jetted hydrates, hot oiled tubing w/Crude, & FCO'd to CIBP @ 11900' MD. Returned well to production & obtained valid welltest data. 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_ Per/orate _X Other_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2604' FNL, 475' FEL, SEC. 22, T10N, R15E, UM At top of productive interval 900' FSL, 1205' FWL, SEC. 21, T10N, R15E, UM At effective depth At total depth 378' FNL, 4894' FEL, SEC. 28, T10N, R15E, UM 5. Type of Well: Development__X Exploratow__ Stratigraphic_ Service__ 6. Datum elevation (DF or KB feet) RKB 70 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 17-03A 9. Permit number / approval number 97-216 10. APl number 50-029-20492-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2628' Production 10743' Liner 1693' 12590 feet Plugs (measured) 9068 feet 12319 feet Junk (measured) 9062 feet Size Cemented 20" 300 Sx Permafrost 13-3/8" 215o Sx Fondu/400 Sx PF II 9-5/8" 14oo sx Class G 3-1/8"/2-7/8" 14 bbls I_ARC PBTD tagged @ 12319' MD (12/25/98) Measured Depth True vertical Depth 110' 110' 2698' 2698' 10813' 8917' 10 675'/12363' 8822'/906 3' Perforation depth: measured 11740'- 11770'; 11800'-11840'; 1194O'- 11980'; 12010'- 12100'. true vertical 9032' - 9034'; 9036' - 9041'; 9050' - 9053'; 9054' - 9057'. . , Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 10727' MD. ~ackers & SSSV (type & measured depth) 9-5/8" x 4-1/2" Baker DB Packer @ 10608' MD. 4-1/2" Otis HRQ SSSV @ 2192' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl no production - - 132 22 387 Casing Pressure Tubing Pressure . 277 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 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ba.~./~~ ~. ~ Title Arco Engineering Supervisor Erin 0 Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 17-03A DESCRIPTION OF WORK COMPLETED PERFORATION Date Event Summary 12/24/1998: 12/25/1998 - 1 2/26/1998: MIRU CTU. PT BOPE. RIH & tagged PBTD 12298' MD. Pumped BU & POOH. RIH w/GR- CCL Memory tool. Logged f/12319' to 10500' MD. POOH w/logging tools. RIH w/per[ guns &shot 120' of Reper[orations @: 11740' - 11770' (Zone 4) 11940' - 11970' (Zone 4) 11800' - 11830' (Zone 4) 12010' - 12040' (Zone 4) Used 2" carriers & shot all Per[s @ 4 SPF, overbalanced, 0° phasing, random orientation. POOH w/guns. ASF. RD. Returned well to Production and obtained a valid well test. 12/17/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12174 Company: Alaska Oil & Gas Cons Comm ( Attn: Lori Taylor r 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) Floppy Well Job # Log Description Date BL Sepia DiSK D.S. 17-03A 98358 IEL, BHC -r'~.~.~>"~ 980318 1 SIGN DATE: J~.~l ~,.! !'i ~'.'"'~ ~ Please sign and return copy of this transmittal to Sherrie at the above address. Thank .~!!:.~!;;;~' SENT BY :ARCO ALASKA INC ' 5- 1-88 ' 8: 28A1~ ;PRB RESOURCE DEVELOP-'- 807 276 7542' # 1 / 2 ARCO Alaska, Inc Instructions; 1)Number Pages 2)Remove Staples 3)U;e Only Black Ink 4)Use Only Clear/Defined Copies 5)Thank You For Your Coc~peration TO LOCATION/ROOM COMMENTS: COPIES TO: COMPANY CITY STATE FAX # VERIFY # FROM BLDCgJROOM TELEPHONE '2oS- NO. OF PAGES FOLLOWING COVER / SENT BY:ARCO ALASKA INC ' .5- 1-88 ' 8'28A~1 'PRB RESOURCE DEVELOP-,- ~07 276 7542'# 2/ 2 ............ -"- 'ir .... --i -- ' -- ~ ...... OEOLO(~IC MAHKEH~ FORMATION 'I'EST~: NAME Incfu~ I~telVal te~led, p~u~ure data, --,nd fluifl~ re, covered end ~r~v~.y, MEA$ DEPTH TRUE VERT DEPTH 3'1 LISTOF ^TT^OHMENTS ................. Summ...ary of 17-03A CT Sidetrack Drlllln~l operations ~- survey. P~l~rl~d ..... L~ndlneerlr~o ~uomrvi~or_ Date Erin .~.,. .....~. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and 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. Prepared by Paul FI,"t~/26,3~49~0 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 ~nd 24: If this well is completed for separate production from more th~n 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 cementing and the location of the cementing tool. Gas Injection,. Shut-In, ~th~r~exp~ain~~tem27;Meth~d~f~pera~i~n:F~owing~GasLift~R~dPum~Hydrau~icPump~Submersib~e~W~ter~j]~E ~V~'D Item 28:I1 no cores taken, indicate "none". Form 10,407 Re,/, 7-1-80 WELL LOG TRANSMITTAL To: State of Alaska May 6, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. )mchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 17-03A & 17-03A PB 1, AK-MW-80142 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, 7G, Anchorage, ,4aK 99518 2 LDWG formatted Discs with verification listings. ,~°I#: 50-029-20492-01 & 50-029-20492-70. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, inc. WELL LOG TRANSMITTAL To: State of Alaska May 6. 1998 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Alaska 99501 ~r~ ~ 91 (,,0 Anchorage, RE: MWD Formation Evaluation Logs D.S. 17-03A & 17-03A PB1, ~M(-~MW-80142 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' .Mi Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, ,ad<2 99518 DS 17-03A: 2" x 5" MD Gamma Ray Logs: 50-029-20492-01 2" x 5" TVD Gamma Ray Logs: 50-029-20492-01 DS 17-03A PBI: ""') I I 511 . , x MD Gamma Ray Logs: 50-029-20492-70 2" x 5" TVD Gamma Ray Logs: 50-029-20492-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia ~.,, /_~. f-, 1Blueline "'.~(:~'t.~/"""'7, -- j 1 Folded Sepia ~ 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, ALaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~, ~ C E IV E D WELL COMPLETION OR RECOMPLETION REPORT AND LOG w~ 1 Status of Well Classification of Service Oil_× Gas__. Suspended__ Abandoned__ Servioe__ 2 Narr~ of Operator 7 Permit Number }-~l/4~k~ 0il & ARCO Alaska, Inc. 97-216 3 Address 8 APl Number 'i~ 9 Unit50-029'20492'0 lor Lease Name P.O. BOX 100360, Anchorage, AK 99510-0360 _ ? 4 Location of well at surface 2604'FNL, 475'FWL, Sec22, T10N, R15E, UM !~~..~_" PRUDHOE BAY UNIT At Top Producing interval _ 10 Well Number 900'FSL, 1205'FWL, Soc21,T10N, R15E, UM ' ~:.;i ~! 17-03A At Total Depth . . 11 Field and Pool 378' FNL, 4894' FEL, Sec 28, T10N, R15E, UM. ~ ...... PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 70' RKB ADL 28334 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 2/26/98 3/11/98 3/20/98 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 12590' MD / 9068' TVD 12336' MD / 9062' TVD YES_X NO__ 2192' feet MD 1900' (approx) 22 Type Electric or Other Logs Run MWD; IEL, Sonic, GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP DO'FI'OM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 94# H-40 Surf 110' 32,, 300 Sx Permafrost - 13-3/8" 72# L-80 Surf 2698' 17.5" 2150 Sx Fondu & 400 Sx Permafrost II 9-5/8" 47# L-80 Surf 10813' 12.25" 1400 Sx Class G 3-1/2" 8.81# L-80 10670' 10675' 3.75" 14 bbls LARC 2-7/8" 6.5# L-80 10675' 12363' 3.75" I ........ , 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 4-1/2" Tbg 10727' 10608' 11740'-11770'MD; 9032'-9034'TVD; @4spf. 11800'-11840'MD; 9036'-9041'TVD; @4spf. 11940' - 11980' MD; 9050' - 9053' TVD; @ 4 spf. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12010' - 12100' MD; 9054' - 9057' TVD; @ 4 spf. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 3/27/98 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GOR 3/28/98 5.0 TEST PERIOD__ 576 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) 297 24 HOUR RATE _X 4 59 431 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved 1/19/97(Permit # 97-216). miss' Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE _5_¢4 GEOLOGIC MARKERS NAME MEAS DEPTH TRUE VERT DEPTH FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase. 31 LIST OF ATTACHMENTS Summary of 17-03A CT Sidetrack Drilling Operations + Survey. 321 hereby certify that the foregoing is true and correct to the best of my knowledge Erin Oba Engineering Supervisor Date ~- 3~ ~ ? ¢ INSTRUCTIONS Prepared by Paul Rauf 263-4990 General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. 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 cementing and the location of the cementing tool. R, ECEiVED Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection ,._ Aias~. 0il & 6a~-~ Cons. C~mmission Gas Injection, Shut-In, Other-explain. Anchorage Item 28: If no cores taken, indicate "none". Form 10-407 Rev. 7-1-80 17-03A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 2/24/98 - 2/25/98: MIRU CTU & PT BOPE. RIH w/BHA & milled through X/N nipple @ 10693' MD. Tagged top of cement plug at 10713' MD. Milled pilot hole from 10713' to 10775' MD. 2/26/98: Milled pilOt hole to 10814' MD. POOH w/BHA. RIH w/BHA & milled a window through the 9-5/8" casing from 10813' to 10819' MD. Milled formation to 10826' MD. POOH w/BHA. 2/27/98: RIH w/BHA & reamed window to 10837' MD. POOH. RIH w/BHA & drilled to 10855' MD. Performed leak off test to EMW 9.4 ppg. Drilled sidetrack build to 10897' MD. POOH w/BHA. 2/28/98: RIH w/Bi-centered bit & drilled to 10970' MD. POOH w/BHA. RIH w/BHA & drilled to 11038' MD. 3/1/98: Drilled to 11160' MD. Shod trip to window then drilled to 11203' MD to turn in horizontal section. POOH w/BHA. RIH w/BHA & drilled to 11540' MD w/periodic short trips to window. 3/2/98: Drilled to 11729' MD. POOH w/BHA. RIH w/BHA & drilled to 12192' MD w/periodic shod trips to window. POOH w/BHA. 3/3/98: RIH w/BHA & drilled to 12192' MD w/lost circulation. Drilled to 12257' MD followed by a shod trip to window. Pumped LCM pill. Tagged BTM & reamed to 12250' MD. Drilled to 12400' MD. 3/4/98: Drilled to 12500' MD w/periodic short trips to window. Experienced drilling problems associated w/ shale/fault zone while drilling to 12640' MD. POOH w/BHA. PT BOPE. 3/5/98: RIH w/BHAto 12454' MD. Hole problems persisted. POOH w/BHA. RIH w/CTto 12150' MD & pumped 14 bbls 17# Class G cement to plug back hole. POOH w/CT. WOC. 3/6/98: WOC. RIH w/BHA & milled through cement stringers. Tagged TOC @ 11592' MD. Drilled new sidetrack off cement plug to 11605' MD. 3/7/98: Drilled to 11806' MD. POOH w/BHA. RIH w/drilling BHA. Tagged bottom at 11809' MD. Drilled to 11990' MD. 3/8/98: Drilled to 12046' MD w/periodic shod trips to the window. POOH w/BHA. RIH w/BHA & drilled to 12400' MD. POOH w/BHA. Page 1 17-03A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 3/9/98: RIH w/BHA & drilled to 12521' MD w/lost returns. POOH w/BHA. RIH w/nozzle & LCM pill to 12500' MD. PU to 10400' MD & PU to 500 psi. RIH to 12500' MD &circulate out excess LCM. POOH. Bull head down backside to push LCM to bottom & pumped 11 bbls of 13 ppg Magna Plus Plug cement for plugback. Displaced cement w/KCL water. PU into casing & WOC. 3/10/98: WOC. RIH to 12480' MD & circulated 28 bbl MI Poly-plug Gel pill down CT. PU to 10600' MD & squeezed gel to 1000 psi. POOH w/BHA. RIH w/BHA & cleaned out gel to 12500' MD. Circulated hole clean. 3/11/98: Circulated out LCM gel pill. RIH & drilled to 12590' MD TD w/losses @ 50 bph. POOH w/BHA. RIH w/ nozzle & washed to BTM. Pumped 2 bbls Neat Class G cement, followed by 4 bbls Class G cement w/ fibers, & 2 bbls Neat Class G cement. CT stuck @ 12525' MD while POOH. 3/12/98: Cut &dress coil at surface. RIH w/1-11/16" chemical cutter &cut CT @ 12450' MD. POOH w/cutter. RD wireline. RU injector, install connector, & POOH w/coil. 3/13/98: Continued to POOH w/CT. RD CTU. RU CTU #1. PT BOPE. MIRU & ran logs. POOH. 3/14/98: Ran IEL/Sonic/GR logs. POOH w/logging tools & RD CTU#1. Circulated LCM pill. Waited on CTU repairs. 3/15/98: Waited on CTU repairs. Pumped LCM pill to retard mud loss. RU CTU. 3/16/98: RIH & circulated LCM pill to nozzle. PU to 10500' MD. PU to 300 psi to squeeze LCM. RIH to spot cement but unable to reach to TD. POOH. RIH w/TT Iocator & tie in to TT @ 10705' MD. POOH. 3/17/98: RIH w/hole opener & reamed tight spot located @ 11800' to 11803' MD. Reamed to 12450' MD. Spotted LCM pill & displaced w/FIo Pro. POOH w/BHA. RIH w/cementing BHA & pumped 2 bbls of 17 ppg Class G Neat cement, followed by 10 bbls of Class G cement w/3% fibers, & finished up w/2 bbls Neat Class G cement. Spotted cement from 11700' MD holding 400 - 700 psi on annulus. PU to 10800' MD & held @ 500 psi. WOC. RIH & cleaned out cement to 12350' MD. POOH. 3/18/98: Test BOPE. RIH & tagged TOC at 12370' MD. Laid in Hi-Vis pill. POOH. MU & RIH w/ 2-7/8" liner assembly. Landed liner @ 12370' MD. 3/19/98: Pumped 14 bbls of Latex Acid Resistive cement to set liner from 12370' - 10670' MD. Contaminated cement w/Biozan. POOH w/BHA while displacing well w/1% KCL. WOC. RIH W/liner cleanout BHA & milled cement stringers. Tagged BTM @ 12336' MD. Circulated Hi-Vis sweep. POOH w/BHA. Page 2 .... 17-03A '--- - DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 3/20/98: RIH w/Perf guns & shot initial perforations at: 11740' - 11770' MD 11800' - 11840' MD 11940' - 11980' MD 12010' - 12100' MD Used 1-11/16" carriers & shot all perfs at 4 spf. POOH w/perf guns. RD. Placed the well on initial production w/gas lift & obtained a valid well test. Page 3 0'" Prudhoe Bay Unit Measured Depth (ft) 11528.19 11591.00 11623.42 11667.17 11709.92 11760.09 11790.42 11842.52 11871.79 11912.22 11948.22 11982.19 12002.39 12040.04 12069.77 12095.74 12144.82 12175.52 12215.84 12264.54 12304.44 12333.22 12367.27 12401.84 12432.79 12469.32 12503.79 12530.79 12568.67 12590.00 Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 87.630 217,880 8954.05 9024.05 2159.68 S 5010.52 W 88.040 216,300 8956.42 9026.42 2209.75 $ 5048.37 W 88,070 223.890 8957.52 9027.52 2234.51 S 5069.22 W 88.590 227.900 8958.80 9028.80 2264.94 S 5100.62 W 87.800 231.060 8960.15 9030.15 2292.70 S 5133.10 W 86.220 229.130 8962.76 9032.76 2324'.84 $ 5171.53 W 84,290 227.200 8965.27 9035.27 2345.00 S 5194.05 W 83.320 220.870 8970.90 9040.90 2382.21 S 5230.03 w 84.550 224,210 8973.99 9043.99 2403.65 S 5249.71 W 85,340 221.220 8977.56 9047.56 2433.24 S 5277.02 W 85,960 220,340 8980.29 9050.29 2460.42 $ 5300.47 W 86.480 217,000 8982.53 9052.53 2486.88 S 5321.64 w 87,280 216.480 8983.63 9053.63 2503.05 S 5333.71 w 88.240 215.070 8985.10 9055.10 2533.57 S 5355.70 w 88,240 210.150 8986.01 9056.01 2558.59 $ 5371.71 w 88,500 205.050 8986.75 9056.75 2581.59 S 5383.73 W 89.820 201.890 8987.47 9057.47 2626.60 S 5403.28 w 89.820 197.490 8987.57 9057.57 2655.49 $ 5413.62 w 89.470 192.040 8987.82 9057.82 2694.47 S 5423.89 W 87.630 186.420 8989.05 9059.05 2742.50 S 5431.70 w 87.100 181.320 8990.89 9060.89 2782.25 S 5434.39 W 87.980 177,630 8992.12 9062.12 2811.00 S 5434.12 w 88.590 172,180 8993.14 9063.14 2844.89 S 5431.10 w 89.300 169.540 8993.78 9063.78 2879.01 S 5425.61 W 88.940 167.260 8994.25 9064.25 2909.32 S 5419.39 W 88.680 164.090 8995.01 9065.01 2944.70 S 5410.35 w 88,500 157,590 8995.86 9065.86 2977.24 S 5399.05 W 88,420 155,830 8996.59 9066.59 3002.03 S 5388.38 W 88.070 153.900 8997.75 9067.75 3036.30 S 5372.30 w 88.000 153,000 8998.48 9068.48 3055.37 S 5362.77 w Survey Report for 17-03A Your Ref: API-500292049201 Alaska State Plane Zone 4 PBU EOA DS 17 Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) Comment 5925727.79 N 703782.57 E 1564.00 5925676.70 N 703746.12 E 2.597 1609.34 5925651.37 N 703725.96 E 23.398 1631.52 5925620.08 N 703695.41E 9.239 1658.10 5925591.43 N 703663.72 E 7,616 1681.91 5925558.25 N 703626.19 E 4.967 1709.37 5925537.47 N 703604.24 E 8.983 1726.78 5925499.28 N 703569.29 E 12,221 1759.57 5925477.30 N 703550.22 E 12.100 1778.59 5925446.97 N 703523.73 E 7.621 1804,81 5925419,15 N 703501.04 E 2,984 1829.08 5925392.12 N 703480.61 E 9,929 1852.91 5925375.63 N 703468.99 E 4.721 1867.57 5925344.51N 703447.85 E 4,528 1895.33 5925319.05 N 703432.54 E 16.541 1918.33 5925295.73 N 703421.16 E 19,656 1939.78 5925250.20 N 703402.87 E 6.977 1982.21 5925221.03 N 703393.33 E 14,332 2009.72 5925181.78 N 703384.14 E 13.544 2047.24 5925133.55 N 703377.66 E 12.139 2094.04 5925093.74 N 703376.07 E 12.837 2133.21 5925065.01 N 703377.13 E 13.169 2161.80 5925031.22 N 703381.09 E 16.099 2195.81 5924997.27 N 703387.52 E 7,907 2230.33 5924967.14 N 703394.58 E 7.457 2261.16 5924932.02 N 703404.58 E 8.705 2297.35 5924899.81 N 703416.78 E 18.858 2330,98 5924875.32 N 703428.14 E 6.523 '2356.84 5924841.51N 703445.16 E 5.176 2392.75 5924822.71 N 703455.21 E 4.230 2412.79 <= Window Point / Tie-On survey at 11,528.19 Projected Survey ORI$1N AL Continued... 2 April, 1998- 19:57 ,1 - DrillQuest Prudhoe Bay Unit Sperry-Sun Drilling Services Survey Report for ~ 7-03A Your Ref: API-500292049201 Alaska State Plane Zone 4 PBU EOADS 17 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 173.340° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12590.00ft., The Bottom Hole Displacement is 6172.08ft., in the Direction of 240.328° (True). 2 April, 1998 - 19:57 - 2 - DrillQuest Prudhoe Bay Unit Measured Depth (ft) Incl, 10700.00 10800.00 10815.00 10832.24 10860.54 10897.24 1 o915.09 10945.47 10972.07 110oo.19 1 lO31.17 1 lO64.o2 1 lO99.84 11127.44 11162.92 i 1194.64 11224.59 11258.42 11297.22 11338.37 11366.57 11433.72 11461.32 11491.87 11528.19 11607.o7 11655.87 11682.o9 11736.39 11779.17 46.620 45.320 49.800 54.400 60.560 68.030 69.520 71.37o 71.89o 73.830 75.940 78.920 82.970 86.220 90.350 90.930 90.880 88.770 88.680 88.820 8g.030 88.770 88.150 87.86O 87.630 88.150 88.330 88.330 88.860 90.000 249.500 251.400 251.500 249.400 246.200 242.700 241.260 240.730 241.260 242.670 242.140 241.260 239.680 237.920 238.100 231.990 230.360 228.080 226.140 223.880 222.450 218.060 219.640 220.560 217.880 215.950 213.490 214.370 211.380 207.160 Sub-Sea Depth (ft) 8768.80 8838.31 8848.42 8859.01 8874.22 8890.13 8896.6O 8906.76 8915.15 8923.43 8931.51 8938.66 8944.30 8946.9O 8947.96 8947.60 8947.13 8947.23 8948.10 8949.00 8949.52 8950.81 8951.56 8952.62 8954.05 8956.95 8958.45 8959.22 8960.55 8960.97 Sperry-Sun Drilling Services Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 8838.80 8908.31 8918.42 8929.01 8944.22 8960.13 8966.60 8976.76 8985.15 8993.43 9001.51 9008.66 9014.30 9016.90 9017.96 9017.60 9017.13 9017.23 9018.10 9019.00 9019.52 9020.81 9021.56 9022.62 9024.05 9026.95 9028.45 9029.22 9030.55 9030.97 Survey Report for 17-03APBI , Your Ref: API-500292049270 Alaska State Plane Zone 4 PBU EOA DS 17 Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/lOOft) (ft) Comment 1718.90 S 4388.00W 1742.97 S 4455.74W 1746.49 S 4466.23W 1751.o5 S 4479.05W 1760.08 S 45o1.12w 1774,36 S 4530.91W 1782.17 S 4545.60W 1796.o5 S 457o.63W 18o8.29 S 4592.71w 182o.92 S 4616.43w 1834.78 S 4642.93W 1849.98 S 4671.16w 1867.41 s 47o1.93W 1881.64 s 4725.42w 19oo.43 S 4755.5ow 1918.59 s 4781.48w 1937.36 S 48o4.81W 1959.46 S 483o.42w 1985.86 S 4858.84w 2014.94 S 4887.94W 2035.50 S 49o7.22w 2086.73 S 4950.60w 21o8.21 S 4967.9ow 2131.57 S 4987.57w 2159.68 S 5010.51w 2222.70 S 5057.86w 2262.79 S 5o85.64w 2284.54S 51oo.27W 233o.12 S 5129.73w 2367.43 S 515o.64W 5926185,61 N 704392.67 E 1198.39 5926159.68 N 704325.62 E 1.886 1214.44 5926155.87 N 704315.23 E 29.871 1216.72 5926150.96 N 704302.55 E 28.358 1219.76 5926141.32 N 704280.74 E 23.759 1226.17 5926126.22 N 704251.35 E 22.090 1236.90 5926118.00 N 704236.88 E 11.235 1242.96 5926103.44 N 704212.24 E 6.308 1253.84 5926090.59 N 704190.51 E 2.720 1263.44 5926077.31 N 704167.15 E 8.400 1273,23 5926062.73 N 704141.04 E 7.008 1283.92 5926046.76 N 704113.24 E 9.441 1295.74 5926028.48 N 704082.97 E 12.116 1309.49 5926013.60 N 704059.87 E 13.377 1320.90 5925994.00 N 704030.33 E 11.651 1336.07 5925975.12 N 704004.86 E 19.348 1351.10 5925955.71 N 703982.06 E 5.444 1367.04 5925932.92 N 703957.06 E 9.182 1386.01 5925905.74 N 703929.39 E 5.004 1408.94 5925875.87 N 703901.11 E 5.501 1434.45 5925854.78 N 703882.39 E 5.124 1452.64 5925802.37 N 703840.45 E 6.548 1498.49 5925780.42 N 703823.75 E 6.148 1517.82 5925756.53 N 703804.73 E 3.156 1538.74 5925727.79 N 703782.58 E 7.400 1564.00 5925663.49 N 703736.99 E 2.532 1621.11 5925622.64 N 703710.33 E 5.052 1657.70 5925600.50 N 703696.31 E 3.355 1677.61 5925554.12 N 703668.12 E 5.591 1719.47 5925516.25 N 703648.25 E 10.217 1754.10 Window Point / Tie-On survey at 10,700.00' MD OR1GINAL Continued... 2 April, 1998- 19:31 - 1 - DrillQuest Sperry-Sun Drilling Services Survey Report for 17-03APB1 Your Ref: API-500292049270 Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) 11799.24 90.350 201.710 8960.91 9030.91 2385.70 S 5158.94 W 11825.82 90.620 200.660 8960.69 9030.69 2410.48 S 5168,54 W 11867.89 90.970 195.030 8960.10 9030.10 2450.50 S 5181.43 W 11920.12 90.970 190.110 8959.22 9029,22 2501.46 S 5192.79 W 11955.59 90.790 185.890 8958.67 9028.67 2536.57 S 5197.72 VV 11983.94 90.440 183.960 8958.37 9028.37 2564.81 S 5200,16 W 12010.32 88.940 177.450 8958.51 9028.51 2591.18 S 5200.48 W 12040.12 88.420 173.940 8959.20 9029.20 2620.88 S 5198.25 W 12065.27 88.590 170.240 8959.86 9029.86 2645.78 S 5194.79 W 12098.32 87.450 166.380 8961.00 9031.00 2678.12 S 5188.10 VV 12142.59 88.330 163.560 8962.63 9032.63 2720.84 S 5176.62 VV 12171.57 89.910 159.390 8963.07 9033.07 2748.31 S 5167.42 VV 12237.27 91.320 154.800 8962.37 9032.37 2808.80 S 5141.86 W 12286.69 88.940 156.000 8962.26 9032.26 2853.74 S 5121.29 VV 12310.54 86.840 155.600 8963.13 9033.13 2875.47 S 5111.52 VV 12344,74 87.450 157.600 8964.84 9034.84 2906.82 S 5097.95 W 12393.44 87.540 159.700 8966.97 9036.97 2952.13 S 5080.24 W 12439.39 87.980 161.100 8968.76 9038.76 2995.39 S 5064.84 VV 12492.27 85.600 166.400 8971.72 9041.72 3046.05 S 5050.07 VV 12546.92 85.600 166.900 8975.92 9045.92 3099,07 S 5037.49 W 12640.00 85.600 166.900 8983.06 9053.06 3189.46 S 5016.45 W 5925497.76 N 703640.46 E 27.211 1771.28 5925472.72 N 703631.54 E 4.079 1794.78 5925432.36 N 703619.76 E 13.407 1833.04 5925381.11N 703609.82 E 9.419 1882.33 5925345.87 N 703605.85 E 11.907 1916.64 5925317.57 N 703604.20 E 6.918 1944.41 5925291.21N 703604.60 E 25.323 1970.55 5925261.58 N 703607.66 E 11.904 2000.32 5925236.79 N 703611.81 E 14.722 2025.45 5925204.65 N 703619.39 E 12.171 2058.34 5925162.26 N 703632.04 E 6,669 2102.11 5925135.05 N 703642.00 E 15.385 2130.46 5925075.29 N 703669.22 E 7.308 2193.51 5925030.94 N 703691.02 E 5.393 2240.52 5925009.48 N 703701.39 E 8.963 2263.25 5924978.52 N 703715.82 E 6.107 2295.96 5924933.72 N 703734.77 E 4.312 2343.02 5924890.91 N 703751.37 E 3.191 2387.77 5924840.67 N 703767.53 E 10.972 2439.80 5924788.02 N 703781.57 E 0.912 2493.92 5924698.24 N 703805.10 E 0.000 2586.14 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 173.340° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12640.00ft., The Bottom Hole Displacement is 5944.53ft., in the Direction of 237.552° (True). Comment Projected TD Alaska State Plane Zone 4 PBU EOA DS 17 2 April, 1998 - 19:31 - 2 - DrfllQuest I:::) F! I I_1_ I ~ G SE FI~./I (: E S 03-Apr-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 17-03A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: 11,528.19' MD Window / Kickoff Survey: 11,591.00' MD Projected Survey: 12,590.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc, 03-Apr-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 17-03APB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,700.00' MD 10,815.00' MD 12,640.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. _, State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 22-Mar-98 Well Name Services Bluelines R/F Sepia Film DS 17-03A PB1 BHC AC/GR 1 I 0 ?! DS 17-03A PB1 IEL/GR 1 ' 1 0'.i Rece~ Date Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. TONY KNOWLE$, GOVEF~NOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: ~907) 276-7542 November 19. 1997 Erin Oba Engineering Superintendent ARCO Alaska. Inc. P O Box 100360 Anchorage. AK 99510-0360 Re: Prudhoe Bav Unit 17-03A ARCO Alaska. Inc. Permit No: 97-216 Sur. Loc.: 2604'FNL. 475'FWL. Sec. 22. T10N. R15E. UM Btmhole Loc: 1094'FNL. 3690'FEL. Sec. 28, T10N. R15E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe ~nust be given so that a representative of the Commission may witness the test. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-360J._____- Chairman" BY ORDER OF THE COMMISSION dlf/enclost,res cc~ Department or' Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill _ Redrill X I lb. Type of Well Exploratory_ Stratigraphic Test Development Oil_~X Re-Entryp Deepen -I Service_ Development Gas_ Single Zone. X Multiple Zone_ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 52' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28334 Prudhoe Bay Oil Pool 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2604' FNL, 475' F-WL, Sec 22, T10N, R15E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 900' FSL, 1205' FWL, Sec 21, T10N, R15E, UM. 17-03A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 1094' FNL, 3690' FEL, Sec 28, T10N, R15E, UM. March, 1998 $200,000 12. Distance to nearest 113. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) property line No Close Approach 13875' MD / 9070' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 10802' MD Maximum hole angle 89° Maximum surface 2800 psig At total depth (TVD) 9070' 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4 L-80 FL4S 3200' 10700' 8839' 13875' 9070' 21 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: truemeasuredvertical 967611885 feetfeet ,:i ....... i.., ~-.! '"['~'. '~ 9'"'"~lugs(moasured) 0 R f '~'~" [ r~J A"' L · Effective depth: measured 11823 feet .... true vertical 8924 Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 300 Sx Permafrost 110' 110' Surface 2628' 13-3/8" 2150 Sx Fondu & 2698' 2698' 400 Sx PF II Production 11795' 9-5/8" 1400 Sx Class G 11865' 9962' Perforation depth: measured 10804 - 10823'; (Isolated below Cement Cap/Sand Plug: 10823 - 10836'; 10942 - 10962') true vertical 8911 - 8924'; (Isolated below Cement Cap/Sand Plug: 8924 - 8934'; 9008 - 9023') 20. Attachments Filing fee x Property plat _ BOP Sketch x Diverter Sketch _ Ddlling program X Ddlling fluid program __ Time vs depth plot _ Refraction analysis Seabed report_ 20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge (.~ Signed '~'.,~-.- '~. Commission Use Only Permit Number _ I APl number I Approvaldate ~ See cover letter for ~'....~//~ 50- 4~,~Ye~s -,~?/-7~ ~2.,--' O~! //'"' / ~:~'"'other requirements Conditions of approval Samples required _ ' Mud Icg required _ Yes "~ No Hydrogen sulfide measures ~'Yes _ No Directional survey required ~¢'Yes _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M X 3500 psi for CTU Other: Original Signed By David Approved by Commissioner the commission Date . . . Form 10-401 Rev. 7-24-89 Submit in triplicate DS 17-3A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 2-7/8" cementedliner. Intended Procedure: Cement squeeze the current perforations and plugback the existing completion to - 10770' md. Mill window in 9-5/8" casing at -10802' md. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight. Build angle to -90°. Dh'ectionally drill 3-3/4" x 3000' horizontal well to access Zone 4 reserves. · Run and cement 2-7/8" liner to TD. · Perforate selected intervals. · Place well on production. November 6, 1997 4-1/2" Camco MMG GLMs @ 3007',5215',7160', 8324',8901',9479',9938', &10396' 9-5/8" Baker DB Pkr. 4-1/2" HES 'XN', 3.725" ID 4-1/2" Tubing tail Original perforations cement sqz'd. DS 17-3A PROPOSED CTD COMPLETION 10608' 1O716' 10728' 2192' 5-1/2" Tubing 4-1/2" Tubing 4-1/2" HRQ SSSV Nipple (3.813" ID) 4-1/2" GS FN on top of liner @ _+10700' Window Cut in 9-5/8" casing with CT. ~ 10800 - 10805' 3-3/4" Open hole 2-7/8" FL4S liner TD @ + 13875' 9-5/8" Casing Shoe @ 11865' ARCO ALASKA INC. ARCO ALASKA INC. DS 17-03A CT SIDETRACK PRUDHOE BAY. ALASKA NORTH REF. TO TRUE True (+0) Mag (+28.48) Departure Scale 1 inch · 800 ft 17-3AT 17-3ORTR o o o o o o 8500 -3200 8700 ~ , 8900 ~ ~T[~I~ Tgt 2 __t% gt 3 o ~ o o o O o o o o O o o O o o o o o o Ve~ical Section Scale 1 inch · 200 ff Plane of Veritcal Section = 173.34 degrees ' 17-3A Plan 3 3/4" Hole Size Plane of Vertical Section = 173.34° Relative to True North Magnetic Declination = 28.49° Grid Convergence = 1.584° RKB = 70ft. Surface Coordinates = 708730.8 X 5928027.4 Y Alaska State Plane Comments MD ft. Coordinates referenced to True Nodh Inc Dir SS Tvd Vsec Lat Dep Build Turn Dleg deg. deg. ft. ft. ft. ft. °/100' °/100' °1100' Alaska State Plane Grid Coordinates ASP ASP X Y 1. Tie in point. 10700 46.62 249.50 8768.8 0.0 -1718.9 -4388.0 0.0 0.0 0.0 704392.1 5926188.0 (Actual, not interpolated) 2. Kick off point. Build a 20° dogleg with a -20° toolface 3. End of angle build. 10710 46.54 249.90 8775.6 1.7 -1721.4 -4394.8 -0.8 4.0 3.0 10740 46.30 251.09 8796.3 6.5 -1728.6 -4415.3 -0.8 4.0 3.0 10770 46.08 252.30 8817.1 10.9 -1735.4 -4435.8 -0.7 4.0 3.0 10800 45.87 253.51 8837.9 14.8 -1741.8 -4456.5 -0.7 4.0 3.0 10802 45.86 253.57 8839.0 15.0 -1742.1 -4457.5 -0.7 4.1 2.9 10830 51.24 251.07 8857.8 19.1 -1748.6 -4477.8 18.9 -8.8 20.0 10860 56.96 248.82 8875.4 24.8 -1756.9 -4500.6 19.1 -7.5 20.0 10890 62.71 246.85 8890.5 31.7 -1766.7 -4524.6 19.2 -6.6 20.0 10920 68.49 245.07 8902~9 39.9 -1777.8 -4549.6 19.3 -5.9 20.0 10950 74.28 243.43 8912.5 49.2 -1790.2 -4575.2 19.3 -5.5 20.0 10980 80.09 241.88 8919.1 59,5 -1803.6 -4601,1 19.4 -5.2 20.0 11010 85.90 240.38 8922.8 70.7 -1818.0 -4627.2 19.4 -5.0 20.0 11026 89.01 239.60 8923.5 77.1 -1826.0 -4641.0 19.4 -4.9 20.0 11040 88.99 238.96 8923.7 82.8 -1833.1 -4653.1 -0.2 -4.5 4.6 11070 88.94 237.60 8924.3 95.5 -1848.9 -4678.6 -0.1 -4.5 4.6 11100 88.90 236.23 8924.8 108.8 -1865.3 -4703.7 -0.1 -4.5 4.6 11130 88.85 234.87 8925.4 122.8 -1882.3 -4728.5 -0.1 -4.5 4.6 11160 88.81 233.50 8926.0 137.4 -1899.8 -4752,8 -0.1 -4.5 4,6 11190 88.77 232.14 8926.7 152.7 -1917,9 -4776.7 -0.1 -4.5 4.6 11220 88.73 230.77 8927.3 168.5 -1936.6 -4800.1 -0.1 -4.5 4.6 11250 88.69 229,41 8928.0 184.9 -1955,9 -4823,1 -0.1 -4.5 4.6 11280 88.65 228,04 8928.7 202.0 -1975.6 -4845.7 -0.1 -4.5 4.6 Maintain a 4.6° dogleg at a -92° toolface 704385.4 5926185.5 704365.1 5926177.5 704344.8 5926170.0 704324.3 5926163.0 704323.3 5926163.0 704303.1 5926156.0 704280.6 5926147.0 704256.8 5926136.5 704232.3 5926124.5 704207.0 5926111,5 704181.4 5926097.5 704155.8 5926082.0 704142.1 5926074.0 704130.3 5926066.5 704105.3 5926050.0 704080.6 5926033.0 704056.3 5926015.0 704032.5 5925997.0 704009.1 5925978.0 703986.2 5925959.0 703963.8 5925939.0 703941.8 5925918.5 10/31/97 17-3AT1 .XLS 1 Comments MD Inc Dir SS Tvd Vsec Lat ft. deg. deg. ft. ft. ft. Dep ft. 11310 88.61 226.68 11340 88.57 225.31 8929.4 8930.2 219.6 237.8 -1996.0 -2016.8 -4867.7 -4889.3 11370 88.53 223.95 11400 88.49 222.58 11430 88.46 221.22 11460 88.42 219.85 11490 88.39 218.49 8930.9 8931.7 8932.5 8933.3 8934.1 256.6 275.9 295.7 316.1 337.0 -2038.1 -2060.0 -2082.3 -2105.1 -2128.3 -4910.4 -4930.9 -4951.0 -4970.5 -4989.4 11520 88.36 217.12 11550 88.32 215.76 11580 88.29 214.39 11610 88.26 213.03 11640 88.23 211.66 8935.0 8935.9 8936.8 8937.7 8938.6 358.4 380.3 402.6 425.5 448.8 -2152.0 -2176.1 -2200.7 -2225.6 -2251.0 -50O7.8 -5025.6 -5042.8 -5O59.5 -5O75.5 4. Target 1, 8940 ff. SS TVD. 11670 88.20 210.30 11681 88.19 209.80 8939.5 8939.9 472.5 481.4 -2276.7 -2286.2 -5090.9 -5096.5 Maintain a 5.4° dogleg with a -89° dogleg. 11700 88.20 208.77 11730 88.22 207.15 11760 88.24 205.53 8940.5 8941.4 8942.3 496.7 521.4 546.5 -2302.8 -2329.2 -2356.1 -5105.7 -5119.8 -5133.1 11790 88.26 203.91 11820 88.29 202.29 11850 88.31 200.67 11880 88.34 199.05 11910 88.36 197.43 11940 88.39 195.81 11970 88.42 194.19 12000 88.45 192.57 12030 88.48 190.95 12060 88.52 189.33 8943.2 8944.1 8945.0 8945.9 8946.8 8947.6 8948.4 8949.3 8950.1 8950.9 572.1 598.2 624.6 651.5 678.7 706.2 734.1 762.2 790.7 819.4 -2383.3 -2410.9 -2438.8 -2467.0 -2495.5 -2524.2 -2553.2 -2582.4 -2611.7 -2641.3 12090 88.55 187.70 8951.6 848.3 -2670.9 12120 88.59 186.08 8952.4 877.5 -2700.7 12150 88.62 184.46 8953.1 906.8 -2730.6 12180 88.66 182.84 8953.8 936.4 -2760.5 12210 88.70 181.22 8954.5 966.0 -2790.5 -5145.6 -5157.4 -5168.4 -5178.6 -5188.0 -5196.5 -5204.3 -5211.2 -5217.3 -5222.6 -5227.1 -5230.7 -5233.4 -5235.3 -5236.4 Build o1100' -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 Turn o1100' -4.5 -4.5 -4.5 -4.5 -4.5 -4.6 -4.6 -4.6 -4.6 -4.6 -4.6 -4.6 -4.6 -4.6 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4 -5.4' Dleg o/100, 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.5 5.4 5.4 5.4 5.4 5.4 5.4 5.4 5.4 5.4 5.4 5.4 5.4 5.4 5.4 5.4 5.4 5.4 5.4 ASP X ASP Y 703920.3 703899.3 5925897.5 5925876.0 703878.8 703858.9 7O3839.5 703820.6 703802.4 5925854.5 5925832.0 5925809.0 5925785.5 5925762.0 703784.6 703767.5 703751.0 703735.1 703719.7 5925737.5 5925713.0 5925688.0 5925662.5 5925637.0 703705.0 703699.8 5925611.O 5925601.0 703690.9 703677.6 703665.1 5925584.5 5925557.5 592553O.O 7O3653.3 703642.3 703632.1 703622.8 703614.1 5925502.5 5925474.5 5925446.5 5925418.0 5925389.5 703606.4 703599.4 703593.3 703588.0 703583.6 5925360.5 5925331.0 5925302.01 5925272.5 5925242.5 703579.9 703577.2 703575.3 703574.2 703573.9 5925213.0 5925183.0 5925153.0 5925123.0 5925093.0 10/31/97 17-3AT1 .XLS 2 Comments MD Inc Dir SS Tvd Vsec Lat ft. deg. deg. ft. ft. ft. Dep Build Turn Dleg ft. °1100' °1100' °1100' 12240 88.74 179.60 8955.2 995.8 -2820.5 -5236.6 0.1 -5.4 5.4 12270 88.78 177.99 8955.8 1025.6 -2850.4 -5236.0 0.1 -5.4 5.4 12300 88.82 176.37 8956.4 1055.5 -2880.4 -5234.5 0.1 -5.4 5.4 12330 88.87 174.75 8957.1 1085.5 -2910.3 -5232.2 0.1 -5.4 5.4 12360 88.91 173.13 8957.6 1115.5 -2940.1 -5229.0 0.1 -5.4 5.4 12390 88.95 171.51 8958.2 1145.5 -2969.9 -5225.0 0.1 -5.4 5.4 12420 89.00 169.89 8958.7 1175.5 -2999.5 -5220.1 0.2 -5.4 5.4 12450 89.05 168.27 8959.2 1205.4 -3028.9 -5214.5 0.2 -5.4 5.4 5. Target 2, 8960 ft. SS TVD. 12475 89.08 166.91 8959.7 1230.3 -3053.4 -5209.1 0.2 -5.4 5.4 Maintain a 6.1° dogleg with a -92° toolface. 12480 89.08 166.61 8959.7 1235.2 -3058.2 -5207.9 -0.2 -6.1 6.1 12510 89.02 164.79 8960.2 1264.9 -3087.2 -5200.5 -0.2 -6.1 6.1 12540 88.97 162.96 8960.8 1294.5 -3116.1 -5192.2 -0.2 -6.1 6.1 12570 88.92 161.13 8961.3 1323.9 -3144.6 -5183.0 -0.2 -6.1 6.1 12600 88.87 159.31 8961.9 1353.1 -3172.8 -5172.8 -0.2 -6.1 6.1 12630 88.82 157.48 8962.5 1382.1 -3200.7 -5161.8 -0.2 -6.1 6.1 12660 88.77 155.65 8963.1 1410.8 -3228.2 -5149.8 -0.2 -6.1 6.1 12690 88.72 153.83 8963.8 1439.3 -3255.3 -5137.0 -0.2 -6.1 6.1 12720 88.68 152.00 8964.5 1467.4 -3282.0 -5123.4 -0.2 -6.1 6.1 12750 88.63 150.17 8965.2 1495.1 -3308.3 -5108.9 -0.1 -6.1 6.1 12780 88.59 148.35 8965.9 1522.5 -3334.1 -5093.6 -0.1 -6.1 6.1 12810 88.55 146.52 8966.6 1549.5 -3359.3 -5077.4 -0.1 -6.1 6.1 12840 88.51 144.69 8967.4 1576.0 -3384.1 -5060.5 -0.1 -6.1 6.1 12870 88.47 142.86 8968.2 1602.1 -3408.3 -5042.8 -0.1 -6.1 6.1 12900 88.43 141.04 8969.0 1627.7 -3431.9 -5024.3 -0.1 -6.1 6.1 12930 88.40 139.21 8969.8 1652.8 -3454.9 -5005.0 -0.1 -6.1 6.1 12960 88.37 137.38 8970.7 1677.3 -3477.3 -4985.1 -0.1 -6.1 6.1 12990 88.33 135.56 8971.6 1701.3 -3499.0 -4964.4 -0.1 -6.1 6.1 13020 88.30 133.73 8972.4 1724.7 -3520.1 -4943.1 -0.1 -6.1 6.1 13050 88.27 131.90 8973.3 1747.5 -3540.5 -4921.1 -0.1 -6.1 6.1 13080 88.25 130.07 8974.2 1769.7 -3560.2 -4898.5 -0.1 -6.1 6.1 13110 88.22 128.24 8975.2 1791.2 -3579.1 -4875.2 -0.1 -6.1 6.1 13140 88.20 126.42 8976.1 1812.0 -3597.3 -4851.4 -0.1 -6.1 6.1 13170 88.18 124.59 8977.0 1832.1 -3614.7 -4827.0 -0.1 -6.1 6.1 ASP ASP X Y 703574.6 5925063.0 703576.1 5925033.0 703578.4 5925003.5 703581.5 5924973.5 703585.5 5924943.5 703590.4 5924914.0 703596.1 5924884.5 703602.6 5924855.5 703608.6 5924831.0 703609.9 5924826.5 703618.1 5924797.5 703627.2 5924769.0 703637.3 5924740.5 703648.2 5924712.5 703660.0 5924685.0 703672.7 5924658.0 703686.3 5924631.0 703700.6 5924605.0 703715.9 5924579,0 703731.9 5924553.5 703748.8 5924529.0 703766.4 5924504.5 703784.8 5924481.0 703803.9 5924458.0 703823.8 5924435.5 703844.3 5924413.5 703865.6 5924392.5 703887.5 5924372,0 703910.1 5924352.0 703933.3 ' 5924333.0 703957.0 5924315.0 703981.3 5924297.5 704006.3 5924280.5 10/31/97 17-3AT1 .XLS 3 Comments 6. TD, Target #3, MD Inc Dir SS Tvd Vsec Lat ft. deg. deg. ft. ft. ft. Dep ft. 13200 88.16 122.76 8978.0 1851.5 -3631.3 '-4802.0 13230 88.14 120.93 8979.0 1870.2 -3647.1 -4776.6 13260 88.13 119.11 13290 88.11 117.28 13320 88.10 115.45 13350 88.09 113.62 13380 88.08 111.79 8980.0 1888.1 -3662.1 -4750.6 8980.9 1905.3 -3676.3 -4724.2 8981.9 1921.6 -3689.6 -4697.3 8982.9 1937.1 -3702.1 -4670.0 8983.9 1951.8 -3713.6 -4642.4 13410 88.08 109.97 8984.9 1965.7 -3724.3 13440 88.07 108.14 8985.9 1978.7 -3734.1 13470 88.07 106.31 8987.0 1990.8 -3743.0 13500 88.07 104.48 8988.0 2002.1 -3750.9 13530 88.07 102.65 8989.0 2012.5 -3758.0 Build Turn °1100' °/100' 13560 88.07 100,83 8990.0 2021.9 -3764.1 13590 88.08 99.00 8991.0 2030.5 -3769.2 13620 88,09 97.17 8992.0 2038.1 -3773.5 13650 88.10 95,34 8993.0 2044.8 -3776,7 13680 88.11 93.51 8994.0 2050.6 -3779.0 Dleg o1100' 13710 88,12 91,69 8995.0 2055.4 -3780,4 13740 88.14 89,86 8995.9 2059,3 -3780.8 13770 88.16 88.03 8996.9 2062,2 -3780.2 13800 88.17 86,20 8997.9 2064,2 -3778.7 13830 88,20 84,37 8998.8 2065,2 -3776.3 -0.1 -6.1 6.1 -0.1 -6.1 6.1 13860 88.22 82,55 8999,8 2065.3 -3772.9 13875 88.23 81,65 9000.2 2064.9 -3770.8 -0.1 -6.1 6.1 0.0 -6.1 6.1 0.0 -6.1 6.1 0.0 -6.1 6.1 0.0 -6.1 6.1 -4614.4 0.0 -6.1 6.1 -4586.0 0.0 -6.1 6.1 -4557.4 0.0 -6.1 6.1 -4528.5 0.0 -6.1 6.1 -4499.3 0.0 -6,1 6.1 -4470.0 0.0 -6.1 6.1 -4440.4 0.0 -6.1 6.1 -4410.8 0.0 -6.1 6.1 -4381.0 0.0 -6.1 6.1 -4351.1 0.0 -6.1 6.1 -4321.1 0.0 -6.1 6.1 -4291.1 0.1 -6.1 6.1 -4261.1 0,1 -6.1 6.1 -4231,2 0,1 -6,1 6,1 -4201.3 0,1 -6.1 6.1 -4171,5 0,1 -6.1 6.1 -4157.0 0.1 -6,1 6.1 ASP X 704031.6 7O4O57.6 704083.9 704110.7 704137.9 704165.6 704193.5 7O4221.8 704250.4 704279.3 704308.4 704337.8 704367.3 704396.9 704426.7 704456.6 7O4486.6 704516.5 704546.5 704576.4 704606.3 704636.1 7O4665,8 704680.3 ASP Y 5924264.5 5924249.5 5924235.5 5924222.0 5924209.5 5924197.5 5924187.0 5924177.0 5924168.0 5924160.0 5924153.0 5924146.5' 5924141.5 5924137.0 5924133.5 5924131.0 5924129.5 5924129.0 5924129.5 5924131.0 5924133.5 5924136.5 5924141.0 5924143.5 9000 ft. SS TVD. 3175 ft. Total Footage 10/31/97 17-3AT1 .XLS 4 ~: 'C T Drilling Wellhead Detail ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure .- I-7" Riser Methanol Injection ~ I Otis 7" WLA Quick I' ' I Connect - I I Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold \ Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manualover .Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus Mu~ Tanks 6O/4OI I TrplxI hire Ext. Shop Fuel Boilers Water Pump Fire Ext. kire Ext. Pipe ra~/~ I--(/) II Drilling J EquipD°Wement Trailer Preferred Major Equipment Layout for CT Drilling · WELL PERMIT CHECKLIST COMPANY FIELD&POOL WELL NAME,~::::'~¢./ //7 - ~__.).'~.,~ ! GEOL AREA ~_.) PROGRAM: exp [] de?~/redrll~serv [] wellbore seg F~ ann. disposal para req [] UNIT# //~,~'~ ON/OFF SHORE ('? %/' ADMINISTRATION DATE/ ENGINEERING APPR DAT~E GEOLOGY APPR · , _ 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... REMARKS 14. Conductor string provided ................... Y N 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... YN/ 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate 'for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. (2~b N 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ~iN 25. BOPEs, do they meet regulation ................. 26. BOPE press rating appropriate; test to ._'~5,~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ .,-,,(~ N 28. Work will occur without operation shutdown ........... ~4~¢~ N 29. Is presence of H2S gas probable ................. ~ N 30. Permit can be issued w/o hydrogen sulfide measures ..... Y 31. Data presented on potential overpressure zones ....... ~ 32. Seismic analysis of shallow gas zones ............. /,'f N N 33. Seabed condition survey (if off-shore) ............. / Y N 34. Contact name/phone for we_eklyprogress reports ...... / Y lexploratory only] ~ GEOLOGY: ENGINEE~NG: COMMISSION: JDH ~ R N C ,g~.,~ co C~ Commentsllnstructions: HOW/Ijt- A:\FORMS\cheklist rev 09~97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ******************** ~**** ~**** ^~"~'~ Oil '-' ****************************** * ..... WESTE~ AT~S LOG COMPANY NAMiE : ARCO ALASKA WELL NAME : DS 17-03A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API ~ER : 500292049201 REFERENCE NO : 98358 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/12/16 ORIGIN : FLIC REEL NAME : 98358 CONTINUATION # PREVIOUS REEL : COMNENT : ARCO ALASKA, DS 17-03A, PRUDHOE BAY, API #50-029-20492-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/12/16 ORIGIN : FLIC TAPE NAME : 98358 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, DS 17-03A, PRUDHOE BAY, API #50-029-20492-01 TAPE HEADER PRUDHOE BAY OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION RUN1 98358 E MURPHY G GOODRIC SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING DS 17-03A 500292049201 ARCO ALASKA WESTERN ATLAS 16-DEC-98 RUN 2 RUN 3 22 iON 1SE 2604 475 70.00 69.00 30.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 9.625 10815.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 3RD STRING PRODUCTION STRING REMARKS CONTAINED HEREIN IS THE LDWG FORMATTED OPEN HOLE WESTERN ATLAS BHC AND IEL DATA AQUIRED ON ARCO ALASKA'S DS 17-03A WELL. THE REPEAT SECTION IS NOT INCLUDED IN THIS EDIT BECAUSE WESTERN ATLAS LOST THE DATA. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH BCS 12408.0 IES 12404.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888 0 12352 5 12343 0 12329 0 12323 5 12277 5 12271 0 12256 0 12252 5 12247 5 12243 0 12240.0 12222.0 12210.5 12204.0 12201.5 12198.0 STOP DEPTH 10815.0 10815.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BCS IES 88890.5 12355.0 12345.5 12330.5 12326.0 12278.0 12272.5 12259.0 12255.0 12250.5 12245.0 12242.0 12225.0 12212.5 12206.0 12203.5 12201.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12195.5 12187.0 12161.0 12142.0 12130.0 12118.5 12111.0 12107.0 12098.5 12090.5 12071.5 12056.0 12051.5 12048.0 12032.5 12014.5 12007.0 12003.0 11998.0 11990.5 11984.0 11981.0 11965 5 11956 0 11944 5 11922 5 11917 0 11908 5 11892 5 11890.0 11878.0 11867.5 11851.5 11830.5 11827.5 11823.0 11806.5 11796.0 11793.0 11788.5 11783.0 11775.5 11767.5 11733.5 11729 0 11714 5 11701 5 11688 5 11680 5 11668 5 11664 5 11656.0 11636.5 11630.0 11622.5 12197.5 12188.5 12165.0 12144.5 12133.5 12123.5 12116.0 12111.5 12103.5 12094.0 12075.0 12059.0 12055.5 12051.0 12037.0 12019.0 12009.5 12006.0 12000.0 11993.0 11986.5 11983.5 11969.5 11958.5 11948.5 11928.5 11922.0 11913.5 11897.5 11894.5 11881.5 11872.0 11858.5 11837.5 11834.5 11827.5 11808.5 11801.5 11798.5 11793.5 11790.5 11781.5 11773.5 11735.5 11731.5 11716.5 11705.5 11693.5 11685.0 11672.5 11668.5 11659.5 11639.5 11634.5 11624.0 16-DEC-1998 16:19 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11612.0 11610.0 11600.0 11596.5 11585.0 11578.5 11569.5 11557.0 11552 0 11544 0 11534 0 11507 0 11502 5 11480 0 11475 0 11470 0 11459 5 11432 5 11423.0 11407.5 11397.0 11395.0 11385.0 11382.0 11377.5 11374.5 11369.0 11360.0 11347.5 11337.0 11334.0 11302.0 11296.0 11289.5 11283.5 11268.0 11262.5 11256.0 11252.5 11248.5 11241.0 11231.0 11219.5 11216.5 11207.0 11204.5 11200.5 11196.5 11172.0 11165.0 11163.0 11161.5 11152.0 11147.0 11127.5 11616.0 11613.0 11603.0 11599.5 11583.5 11576.5 11569.5 11554.5 11550.0 11542.0 11531.5 11505.0 11499.0 11478.0 11473.5 11468.0 11458.0 11429.5 11422 0 11405 5 11393 5 11392 0 11384 0 11380 0 11375 5 11372 5 11366.5 11358.5 11348.0 11336.0 11333.5 11302.5 11295.0 11287.5 11281.5 11267.0 11262.0 11254.0 11251.0 11247.0 11240.0 11230.0 11218.0 11215.5 11204.5 11203.0 11198.5 11194.5 11172 0 11167 5 11165 0 11164 0 11154 5 11148 5 11130 0 16-DEC-1998 16:19 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11123.5 11120.0 11117.5 11115 5 11107 5 11105 0 11102 0 11100 0 11095 5 11094 0 11052.5 11048.0 11042.0 11039.0 11026.5 11023.5 11020.0 11017.5 11016.0 11008.0 11005.0 11002.0 10999.5 10997.0 10994.5 10990.0 10983.5 10980.0 10978.5 10977 0 10971 0 10967 5 10965 0 10963 0 10960 0 10955 0 10951.0 10947.0 10942.5 10935.0 10931.5 10928.0 10918.0 10912.5 10908.5 10904.0 10895.0 10890.5 10888.0 10886.0 10881.5 10872.0 10867.5 10859.0 10853.5 11125.5 11122.5 11119.5 11118.5 11109.5 11107.0 11104.0 11101.5 11098.0 11095 5 11055 0 11051 0 11044 0 11041 5 11029 5 11026.0 11024.0 11022.5 11020.5 11012.5 11008.0 11005.5 11002.0 11000.0 10997.5 10993.0 10986.5 10983.0 10981.0 10979.5 10973.5 10971.0 10968.0 10965.0 10962.5 10958.5 10954.5 10948.5 10944.5 10935.5 10932.5 10929.0 10918.5 10912.5 10909.5 10904.0 10894.5 10890.5 10887.5 10885.0 10880.5 10870.5 10868.0 10860.0 10853.5 16-DEC-1998 16:19 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE: 10851.5 10846.5 10844.0 10840.5 10838.0 10837.0 10831.0 10825.5 10815.5 10812.0 10804.0 10801.5 10784.0 10769.5 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REM_ARKS: 10851.5 10847.0 10844.0 10842.0 10840 0 10838 0 10830 5 10823 5 10814 0 10811 5 10805.0 10802.0 10785.0 10769.5 100.0 RUN NO. PASS NO. MERGE TOP ~iERGE BASE ................... THIS FILE CONTAINS THE EDITED OPEN HOLE DATA. THE CURVES HAVE BEEN CLIPPED AT FIRST READING AND AT CASING. THE BCS GR WAS SHIFTED TO THE MWD GR RUN BY SPERRY-SUN ON lO-MAR-98. ALL CURVES WERE CARRIED WITH THE GR.BCS SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE TYPE REPR CODE VALUE 0 66 0 ** SET TYPE - CHAN** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI O0 000 O0 0 1 1 1 4 68 0000000000 TENS BCS LB O0 000 O0 0 1 1 1 4 68 0000000000 DT BCS US/F O0 000 O0 0 1 1 1 4 68 0000000000 ILD IES OH~ O0 000 O0 0 1 1 1 4 68 0000000000 SN IES OH~M O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12408.000 GR.BCS -999.250 ILD. IES -999.250 SN. IES -999.250 DEPT. 10815.000 GR.BCS 69.164 ILD. IES 8.172 SN. IES 0.223 TENS.BCS 799.558 DT. BCS -999.250 TENS. BCS 1142. 061 DT. BCS 45.523 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE : 98/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~9~ARY LDWG TOOL CODE START DEPTH BCS 10815.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 12352.5 12343.0 12329.0 12323.5 12277.5 12271.0 12256.0 12252 5 12247 5 12243 0 12240 0 12222 0 12210 5 12204 0 12201 5 12198.0 12195.5 12187.0 12161.0 12142.0 12130.0 12118.5 12111.0 12107.0 12098.5 12090.5 12071.5 12056.0 12051.5 12048.0 12032.5 12014.5 12007.0 12003.0 11998.0 11990.5 STOP DEPTH 10750.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BCS 88890.5 12355.0 12345.5 12330.5 12326.0 12278.0 12272.5 12259.0 12255.0 12250.5 12245.0 12242.0 12225.0 12212.5 12206.0 12203.5 12201.0 12197.5 12188.5 12165.0 12144.5 12133.5 12123.5 12116.0 12111.5 12103.5 12094.0 12075.0 12059.0 12055.5 12051.0 12037.0 12019.0 12009.5 12006.0 12000.0 11993.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11984.0 11981.0 11965.5 11956.0 11944.5 11922.5 11917.0 11908.5 11892.5 11890.0 11878.0 11867.5 11851.5 11830.5 11827.5 11823.0 11806.5 11796.0 11793.0 11788.5 11783.0 11775.5 11767.5 11733.5 11729.0 11714.5 11701.5 11688.5 11680.5 11668.5 11664.5 11656.0 11636.5 11630.0 11622.5 11612.0 11610.0 11600.0 11596.5 11585.0 11578.5 11569.5 11557.0 11552 0 11544 0 11534 0 11507 0 11502 5 11480 0 11475 0 11470 0 11459 5 11432 5 11423.0 11407.5 11986.5 11983.5 11969.5 11958.5 11948.5 11928.5 11922.0 11913.5 11897.5 11894.5 11881.5 11872.0 11858.5 11837.5 11834.5 11827.5 11808.5 11801.5 11798.5 11793.5 11790.5 11781.5 11773.5 11735.5 11731.5 11716.5 11705.5 11693 5 11685 0 11672 5 11668 5 11659 5 11639 5 11634 5 11624 0 11616 0 11613 0 11603.0 11599.5 11583.5 11576.5 11569.5 11554.5 11550.0 11542.0 11531.5 11505.0 11499.0 11478.0 11473.5 11468.0 11458.0 11429.5 11422.0 11405.5 16-DEC-1998 16:19 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11397.0 11395.0 11385.0 11382.0 11377.5 11374.5 11369.0 11360.0 11347.5 11337.0 11334.0 11302.0 11296.0 11289.5 11283.5 11268.0 11262.5 11256.0 11252.5 11248.5 11241 0 11231 0 11219 5 11216 5 11207 0 11204 5 11200 5 11196 5 11172 0 11165.0 11163.0 11161.5 11152.0 11147.0 11127.5 11123.5 11120.0 11117.5 11115.5 11107.5 11105.0 11102.0 11100.0 11095.5 11094.0 11052.5 11048.0 11042.0 11039.0 11026.5 11023.5 11020.0 11017.5 11016.0 11008.0 11393 5 11392 0 11384 0 11380 0 11375 5 11372 5 11366.5 11358.5 11348.0 11336.0 11333.5 11302.5 11295.0 11287.5 11281.5 11267.0 11262.0 11254.0 11251.0 11247.0 11240.0 11230.0 11218.0 11215.5 11204.5 11203.0 11198 5 11194 5 11172 0 11167 5 11165 0 11164 0 11154 5 11148.5 11130.0 11125.5 11122.5 11119.5 11118.5 11109.5 11107.0 11104.0 11101.5 11098.0 11095.5 11055.0 11051.0 11044.0 11041.5 11029.5 11026.0 11024.0 11022.5 11020.5 11012.5 16-DEC-1998 16:19 PAGE: 10 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE: 11 11005 0 11002 0 10999 5 10997 0 10994 5 10990 0 10983 5 10980.0 10978.5 10977.0 10971.0 10967.5 10965.0 10963.0 10960.0 10955.0 10951.0 10947.0 10942.5 10935.0 10931.5 10928.0 10918.0 10912.5 10908.5 10904.0 10895.0 10890.5 10888.0 10886.0 10881.5 10872.0 10867.5 10859.0 10853.5 10851.5 10846.5 10844.0 10840.5 10838.0 10837.0 10831.0 10825.5 10815.5 10812.0 10804.0 10801.5 10784.0 10769.5 100.0 $ 11008.0 11005.5 11002.0 11000.0 10997.5 10993.0 10986.5 10983 0 10981 0 10979 5 10973 5 10971 0 10968 0 10965 0 10962 5 10958 5 10954 5 10948.5 10944.5 10935.5 10932.5 10929.0 10918.5 10912.5 10909.5 10904.0 10894.5 10890.5 10887.5 10885.0 10880.5 10870.5 10868.0 10860.0 10853.5 1085~ 5 10847 0 10844 0 10842 0 10840 0 10838 0 10830 5 10823 5 10814.0 10811.5 10805.0 10802.0 10785.0 10769.5 100.0 THIS FILE CONTAINS THE EDITED CASED HOLE DATA. THE CURVE HAS BEEN CLIPPED AT CASING AND AT LAST READING. IT HAS BEEN SHIFTED TO THE MWD GR AS SHOWN ABOVE. LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE: 12 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 GR BCS GAPI O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10815.000 GR.BCS 69.164 DEPT. 10750.000 GR.BCS 86.098 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE: 13 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SU~f4ARY FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH IEL 12408.0 10815.0 BHC 12408.0 10815.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~k4A RAY 13 -MAR-98 3.0 12640.0 12406.0 10750.0 12406.0 TOOL NUMBER ........... 1310XA GR LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE: 14 BHC IEL $ BOREHOLE COMP SONIC INDUCTION ELECTROLOG 160SEA~MA BHC 0811XA IEL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 3. 750 10815.0 10815.0 BOREHOLE CONDITIONS MUD TYPE: FLO- PRO MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) : 8.0 MUD PH: 9.0 FLUID LOSS (C3): 7.2 MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHNM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.091 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 099 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 80.0 80.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX'. MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: LOGS WERE RUN ON DOWELL SCLUMBERGER COILED TUBING UNIT #1. LOGS WERE CORRELATED TO SPERRY-SUN NGP/ROP MWD LOG DATED 26-FEB-98/O4-MAR-98 SP CURVES NOT PRESENTED DUE TO LACK OF CHARACTER, ATTRIBUTABLE TO THE HIGH CHLORIDE CONTENT OF THE MUD. CHLORIDES = 43000 PPM. REPEAT SECTION TAKEN FROM DOWN LOG AS PER CUSTOMER REQUEST. CALIBRATION/VERIFICATION SU~ff4ARY SHOWS TWO BEFORE LOG VERIFICATIONS FOR THE IEL. THE SECOND ONE, 13-MAR-98 14:57:29, WAS ACTUALLY THE AFTER LOG VERIFICATION. THIS FILE CONTAINS THE RAW OPEN HOLE MAIN PASS DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 GR BHC GAPI O0 000 O0 0 3 1 1 4 68 0000000000 CHT BHC LB O0 000 O0 0 3 1 1 4 68 0000000000 COND IEL M~IHO O0 000 O0 0 3 1 1 4 68 0000000000 DTC BHC US/F O0 000 O0 0 3 1 1 4 68 0000000000 RT IEL OHI~ O0 000 O0 0 3 1 1 4 68 0000000000 SN IEL OH~4~ O0 000 O0 0 3 1 1 4 68 0000000000 TT IEL US O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12415.000 DTC.BHC -999.250 GR.BHC -999.250 CHT. BHC -999.250 COND.IEL -999.250 RT. IEL -999.250 SN. IEL -999.250 TT. IEL -999.250 DEPT. 10815.000 GR.BHC DTC.BHC 35.100 RT. IEL 64.430 CHT. BHC 1141.556 COArD.IEL 20.591 SN. IEL 0.217 TT. IEL 48.564 131.332 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE: 16 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 4 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10518.0 10750.0 BHC $ LOG HEADER DATA DATE LOGGED: 13-MAR-98 SOFTWARE VERSION: 3.0 TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : 12640.0 TD LOGGER (FT) : 12406.0 TOP LOG INTERVAL (FT) : 10750.0 BOTTOM LOG INTERVAL (FT) : 12406.0 LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~4A RAY BHC BOREHOLE COMP SONIC IEL INDUCTION ELECTROLOG $ BOREHOLE AND CASING DATA TOOL NUMBER 1310XA GR 160SEA~MA BHC 0811XA IEL LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE: 17 OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 3. 750 10815.0 10815.0 BOREHOLE CONDITIONS MUD TYPE: FLO-PRO MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) : 8.0 MUD PH: 9.0 FLUID LOSS (C3): 7.2 MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.091 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 099 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 80.0 80.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: LOGS WERE RUN ON DOWELL SCLUMBERGER COILED TUBING UNIT #1. LOGS WERE COPJLELATED TO SPERRY-SUN NGP/ROP LOG DATED 26-FEB-98/O4-MAR-98 SP CURVES NOT PRESENTED DUE TO LACK OF CHARACTER, ATTRIBUTABLE TO THE HIGH CHLORIDE CONTENT OF THE MUD. CHLORIDES = 43000 PPM. REPEAT SECTION TAKEN FROM DOWN LOG AS PER CUSTOMER REQUEST. CALIBRATION/VERIFICATION SU~9~ARY SHOWS TWO BEFORE LOG VERIFICATIONS FOR THE IEL. THE SECOND ONE, 13-MAR-98 14:57:29, WAS ACTUALLY THE AFTER LOG VER I FI CA TI ON. THIS FILE CONTAINS THE RAW CASED HOLE MAIN PASS DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE: 18 DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUN~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 GR BHC GAPI O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10815.000 GR.BHC 64.430 DEPT. 10748.500 GR.BHC -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1998 16:19 PAGE: 19 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE ' 98/12/16 ORIGIN · FLIC TAPE NAME : 98358 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA, DS 17-03A, PRUDHOE BAY, API #50-029-20492-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/12/16 ORIGIN · FLIC REEL NAME : 98358 CONTINUATION # : PREVIOUS REEL : CONk4ENT : ARCO ALASKA, DS 17-03A, PRUDHOE BAY, API #50-029-20492-01 Sperry-Sun Drilling Services LIS Scan Utility Wed Apr 29 13:26:39 1998 Reel Header Service name ............. LISTPE Date ..................... 98/04/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/04/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: DS 17-03A PB1 500292049270 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 29-AP R- 98 MWD RUN 1 AK-MW-80142 D. LABRECQUE A. BASS MWD RUN 2 AK-MW-80142 D. LABRECQUE A. BASS MWD RUN 3 AK-MW-80142 D. LABRECQUE A. BASS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-80142 D. LABRECQUE A. BASS MWD RUN 5 AK-MW-80142 D. LABRECQUE A. BASS MWD RUN 6 AK-MW-80142 D. LABRECQUE A. BASS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MWD RUN 7 AK-MW-80142 K. MCCORMICK A. BASS MWD RUN 8 AK-MW-80142 K. MCCORMICK A. BASS MWD RUN 9 AK-MW-80142 K. MCCORMICK A. BASS SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: 22 i0N 015 2604 475 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD .00 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9.625 10815.0 PRODUCTION STRING 3.750 12640.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-9 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. MWD RUNS 1-9 REPRESENT WELL 17-03A PB1 WITH API #: 50-029-20492-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12640'MD, 8980'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUN94ARY PBU TOOL CODE START DEPTH STOP DEPTH ROP 10720.0 12642 . 5 GR 1~701.5 12610 . 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 10701.5 10700.0 EQUIVALENT UNSHIFTED DEPTH 10704 10705 10707 10708 10731 10736 10740 10743 10744 10758 10763 10769 10799 10802 10805 10808 12642 $ MERGED PBU MWD MWD MWD MWD MWD MWD MWD MWD MWD $ REMARKS: 10702 10703 10705 10706 10728 10734 10739 10742 10743 10756 10762 10768 10795 10799 10803 10806 12640 5 5 0 5 5 5 0 0 0 5 0 .0 .0 .0 .5 .0 .0 DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP MERGE BASE 1 10700.0 10813.0 2 10813.0 10826.0 3 10826.0 10837.0 4 10837.0 10896.0 5 10896.0 10974.0 6 10974.0 11204.0 7 11204.0 11729.0 8 11729.0 12192.0 9 12192.0 12640.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10701.5 12642.5 11672 3883 10701.5 ROP 0.91 3960 78.9722 3846 10720 GR 11.46 860.41 108.554 3818 10701.5 Last Reading 12642.5 12642.5 12610 First Reading For Entire File .......... 10701.5 Last Reading For Entire File ........... 12642.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10700.0 10783.5 ROP 10718.0 10810.0 $ LOG HEADER DATA DATE LOGGED: 25-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10813.0 TOP LOG INTERVAL (FT) : 10694.0 BOTTOM LOG INTERVAL (FT) : 10813.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM A~NGLE: .0 MAXIMUM A~GLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAP94A PROBE PCD 3.00 TOOL NUMBER PCG 76 BOREHOLE ~qD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 86.7 First Name Min Max Mean Nsam Reading DEPT 10700 10810 10755 221 10700 GR 44.25 78.16 68.5373 168 10700 ROP 8.48 90.69 24.9581 185 10718 Last Reading 10810 10783.5 10810 First Reading For Entire File .......... 10700 Last Reading For Entire File ........... 10810 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FI LE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10784.0 10799.5 ROP 10810.5 10826.0 $ LOG HEADER DATA DATE LOGGED: 26-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10826.0 TOP LOG INTERVAL (FT) : 10813.0 BOTTOM LOG INTERVAL (FT) : 10826.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMPUk PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): PCD 3.00 TOOL NUMBER PCG 76 3.800 3.8 SEA-WATER .00 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 .0 0 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 84.4 First Name Min Max Mean Nsam Reading DEPT 10784 10826 10805 85 10784 GR 66.55 120.45 75.7087 32 10784 ROP 0.91 842.84 156.455 32 10810.5 Last Reading 10826 10799.5 10826 First Reading For Entire File .......... 10784 Last Reading For Entire File ........... 10826 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10800.5 ROP 10826.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10807.5 10836.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 26-FEB-98 MSC 1.32 PCG 5.74 MEMORY 10837.0 10826.0 10837.0 PCD 3.00 .0 .0 TOOL NUMBER PCG 76 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 86.7 Dat MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: a Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10800.5 10836.5 10818.5 73 10800.5 GR 52.74 120.84 89.0387 15 10800.5 ROP 3.8 3960 899.805 21 10826.5 Last Reading 10836.5 10807.5 10836.5 First Reading For Entire File .......... 10800.5 Last Reading For Entire File ........... 10836.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Con~nent Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10808.0 10867.0 ROP 10837.0 10895.5 $ LOG HEADER DATA DATE LOGGED: 27-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 10896.0 TOP LOG INTERVAL (FT): 10837.0 BOTTOM LOG INTERVAL (FT): 10896.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.2 MAXIMUM ANGLE: 60.6 PCD 3.00 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER PCG 74 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.800 3.8 BOREHOLE CONDITIONS MUD TYPE: I~3D DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO PRO .00 .0 .0 0 .0 .000 .000 .000 .000 84.4 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN : EWR FREQUENCY (HZ : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 t 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10808 10895.5 10851.8 176 10808 GR 48.38 225.07 92.9855 119 10808 ROP 13.46 104.3 27.7244 118 10837 Last Reading 10895.5 10867 10895.5 First Reading For Entire File .......... 10808 Last Reading For Entire File ........... 10895.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUN/~ARY VENDOR TOOL CODE START DEPTH GR 10867.5 ROP 10897.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10944.5 10970.5 27-FEB-98 MSC 1.32 PCG 5.74 MEMORY 10974.0 10896.0 10974.0 PCD 3.00 68.0 71.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GA/V/WA PROBE $ TOOL NUMBER PCG 74 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.800 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO PRO 8.80 .0 9.2 .0 .000 .000 .000 .000 60.9 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .3 REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10867.5 10970.5 10919 207 10867.5 GR 79.57 860.41 252.132 155 10867.5 ROP 12.4 555.65 38.0218 147 10897.5 Last Reading 10970.5 10944.5 10970.5 First Reading For Entire File .......... 10867.5 Last Reading For Entire File ........... 10970.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10945.0 ROP 10971.0 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11174.5 11203.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHiVD4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN 28-FEB-98 MSC 1.32 PCG 5.74 MEMORY 11204.0 10974.0 11204.0 PCD 3.00 71.9 90.4 TOOL NUMBER PCG 74 3.750 3.8 FLO PRO 8.80 .0 8.9 6.0 .000 .000 .000 .000 60.9 .3 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 A. API 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10945 11203 11074 517 10945 GR 26.42 532.8 116.216 460 10945 ROP 4.97 596.79 50.1708 465 10971 Last Reading 11203 11174.5 11203 First Reading For Entire File .......... 10945 Last Reading For Entire File ........... 11203 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR ROP LOG HEADER DATA START DEPTH STOP DEPTH 11175.0 11700.0 11204.0 11730.0 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 01-MAR-98 MSC 1.32 PCG 5.74 MEMORY 11729.0 11204.0 11729.0 87.6 90.9 TOOL NUMBER PCG 76 3.750 3.8 FLO PRO 8.80 .0 8.9 5.9 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 PCD 3.00 63.3 GR MWD 7 AAP I 4 1 68 ROP MWD 7 FT/H 4 1 68 Name Min Max Mean Nsam DEPT 11175 11730 11452.5 1111 GR 22.33 274.35 51.0465 1051 ROP 37.33 777.88 86.2069 1053 First Reading 11175 11175 11204 Last Reading 11730 11700 11730 First Reading For Entire File .......... 11175 Last Reading For Entire File ........... 11730 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11700.5 121259.5 ROP 11730.5 12192.0 $ LOG HEADER DATA DATE LOGGED: 02-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12192.0 TOP LOG INTERVAL (FT): 11729.0 PCD 3.00 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMS4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 12192.0 87.4 91.0 TOOL NUMBER PCG 74 3.750 3.8 FLO PRO 8.80 .0 9.2 5.9 .000 .000 .000 .000 68.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading Last Reading DEPT 11700.5 12192 11946.2 984 GR 11.46 226.77 60.1861 919 ROP 37.52 200 89.3465 924 11700.5 11700.5 11730.5 12192 12159.5 12192 First Reading For Entire File .......... 11700.5 Last Reading For Entire File ........... 12192 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12160.0 12607.5 ROP 12192.5 12640.0 $ LOG HEADER DATA DATE LOGGED: 03-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12640.0 TOP LOG INTERVAL (FT) : 12192.0 BOTTOM LOG INTERVAL (FT): 12640.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 85.6 MAXIMUM ANGLE: 91.3 TOOL STRING (TOP TO BOTTOM) PCD 3.00 VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER PCG 74 3.750 3.8 FLO PRO 8.80 .0 9.0 6.5 .000 .000 .000 .000 70.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 AAPI 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12160 12640 12400 961 12160 GR 47.73 521.84 208.092 896 12160 ROP 6.04 2232.57 77.6307 896 12192.5 Last Reading 12640 12607.5 12640 First Reading For Entire File .......... 12160 Last Reading For Entire File ........... 12640 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF Tape Trailer Service name ............. LIST?E Date ..................... 98/04/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/04/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Thu Apr 30 10:11:35 1998 Reel Header Service name ............. LISTPE Date ..................... 98/04/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/04/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPA/qY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: M C OF LM D Date DS 17-03A 500292049201 ARCO /ALASKA, INC. SPERRY-SUN DRILLING SERVICES 30-APR-98 MWD RUN 1 AK-MW-80142 D. LABRECQUE A. BASS MWD RUN 2 AK-MW-80142 D. LABRECQUE A. BASS MWD RUN 3 AK-MW-80142 D. LABRECQUE A. BASS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-80142 D. LABRECQUE A. BASS MWD RUN 5 AK-MW-80142 D. LABRECQUE A. BASS MWD RUN 6 AK-MW-80142 D. IJtBRECQUE A. BASS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 AK-MW-80142 K. MCCORMICK A. BASS MWD RUN 11 AK-MW-80142 D. LABRECQUE G. GOODRICH PEWD RUN 12 AK-MW-80142 D. LABRECQUE G. GOODRICH JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 13 AK-MW-80142 D. LABRECQUE G. GOODRICH MWD RUN 14 AK-MW-80142 D. LABRECQUE G. GOODRICH 22 10N 015 2604 475 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD .00 .00 .00 MWD RUN 15 AK-MW-80142 W. JACKSON G. GOODRICH OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9. 625 10815.0 PRODUCTION STRING 3. 750 .12590.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-7, & 11-15 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. MWD RUN 1 WAS ENTIRELY IN CASING, AND IS PRESENTED FOR GAMMA RAY TIE-IN TO THE ORIGINAL 17-03 LOG. 4. MWD RUNS 1-7 AND 11-15 REPRESENT WELL 17-3A WITH API#: 50-029-20492-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12590'MD, 8998'SSTIrD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10701.5 ROP 10719.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) 10704 10705 10707 10708 10720 10731 10736 10740 10743 10744 10758 10763 10769 10799 10802 10805 10808 12592 $ MERGED PBU MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ REMARKS: BASELINE DEPTH GR 10701.5 10700.0 .0 10702.5 .5 10703.5 .0 10705.0 .5 10706.5 .0 10718.5 .0 10728.5 .0 10734.5 .5 10739.0 .0 10742.0 .5 10743.0 0 10756.5 0 10762.0 0 10768.0 0 10795.0 0 10799.0 0 10803.5 .5 10806.0 .5 12590.0 DATA SOURCE TOOL CODE 12566.0 12592.5 EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 1 10718.0 10813.0 2 10813.0 10826.0 3 10826.0 10837.0 4 10837.0 10896.0 5 10896.0 10974.0 6 10974.0 11204.0 7 11204.0 11591.0 11 11591.0 11809.0 12 11809.0 12046.0 13 12046.0 12400.0 14 12400.0 12521.0 15 12521.0 12590.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR I~D AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10701.5 12592.5 11647 3783 10701.5 ROP 0.91 3960 96.0258 3747 10719.5 GR 21.56 860.41 66.7901 3730 10701.5 Last Reading 12592.5 12592.5 12566 First Reading For Entire File .......... 10701.5 Last Reading For Entire File ........... 12592.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10700.0 10783.5 ROP 10718.0 10810.0 $ LOG HEADER DATA DATE LOGGED: 25-FEB-98 SOFTWARE SURFACE soFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY PCD 3.00 TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION {DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH {FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 10813.0 10718.0 10813.0 .0 .0 TOOL NUMBER PCG 76 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 86.7 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 Name Min Max Mean DEPT 10700 10810 10755 GR 44.25 78.16 68.5373 ROP 8.48 90.69 24.9581 Nsam 221 168 185 First Reading 10700 10700 10718 Last Reading 10810 10783.5 10810 First Reading For Entire File .......... 10700 Last Reading For Entire File ........... 10810 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FI LE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10784.0 10799.5 ROP 10810.5 10826.0 $ LOG HEADER DATA DATE LOGGED: 26-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10826.0 TOP LOG INTERVAL (FT) : 10813.0 BOTTOM LOG INTERVAL (FT) : 10826.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 PCD 3.00 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER PCG 76 3.800 3.8 S EA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 84.4 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10784 10826 10805 85 10784 GR 66.55 120.45 75.7087 32 10784 ROP 0.91 842.84 156.455 32 10810.5 Last Reading 10826 10799.5 10826 First Reading For Entire File .......... 10784 Last Reading For Entire File ........... 10826 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10800.5 10807.5 ROP 10826.5 10836.5 $ LOG HEADER DATA DATE LOGGED: 26-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10837.0 TOP LOG INTERVAL (FT) : 10826.0 BOTTOM LOG INTERVAL (FT) : 10837.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION {DEG MINIMUM ~GLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA PCD 3.00 TOOL NUMBER PCG 76 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (O~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 86.7 First Name Min Max Mean Nsam Reading DEPT 10800.5 10836.5 10818.5 73 10800.5 GR 52.74 120.84 89.0387 15 10800.5 ROP 3.8 3960 899.805 21 10826.5 Last Reading 10836.5 10807.5 10836.5 First Reading For Entire File .......... 10800.5 Last Reading For Entire File ........... 10836.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10808.0 10867.0 ROP 10837.0 10895.5 $ LOG HEADER DATA DATE LOGGED: 27-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10896.0 TOP LOG INTERVAL (FT): 10837.0 BOTTOM LOG INTERVAL (FT): 10896.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.2 MAY~IMUM ANGLE: 60.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : PCD 3.00 TOOL NUMBER PCG 74 3.800 3.8 FLO PRO .00 .0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 84.4 First Name Min Max Mean Nsam Reading DEPT 10808 10895.5 10851.8 176 10808 GR 48.38 225.07 92.9855 119 10808 ROP 13.46 104.3 27.7244 118 10837 Last Reading 10895.5 10867 10895.5 First Reading For Entire File .......... 10808 Last Reading For Entire File ........... 10895.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Conument Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10867.5 ROP 10897.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10944.5 10970.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): PFO'D PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 27-FEB-98 MSC 1.32 PCG 5.74 MEMORY 10974.0 10896.0 10974.0 PCD 3.00 68.0 71.4 TOOL NUMBER PCG 74 3.800 3.8 FLO PRO 8.80 .0 9.2 .0 .000 .000 .000 60.9 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10867.5 10970.5 10919 207 10867.5 GR 79.57 860.41 252.132 155 10867.5 ROP 12.4 555.65 38.0218 147 10897.5 Last Reading 10970.5 10944.5 10970.5 First Reading For Entire File .......... 10867.5 Last Reading For Entire File ........... 10970.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FI LE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10945.0 11174.5 ROP 10971.0 11203.0 $ LOG HEADER DATA DATE LOGGED: 28-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11204.0 TOP LOG INTERVAL (FT): 10974.0 BOTTOM LOG INTERVAL (FT): 11204.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 71.9 MAXIMUM ANGLE: 90.4 PCD 3.00 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER PCG 74 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO PRO 8.80 .0 8.9 6.0 .000 .000 .000 .000 60.9 NEUTRON TOOL MTkTRIX: IV~TRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Lo99in9 Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined 7kbsent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10945 11203 11074 517 10945 GR 26.42 532.8 116.216 460 10945 ROP 4.97 596.79 50.1708 465 10971 Last Reading 11203 11174.5 11203 First Reading For Entire File .......... 10945 Last Reading For Entire File ........... 11203 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11175.0 ROP 11204.0 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: I~JD FILTRATE AT MT: MUD CAKE AT MT: STOP DEPTH 11591.0 11591.0 01-MAR-98 MSC 1.32 PCG 5.74 MEMORY 11729.0 11204.0 11729.0 PCD 3.00 87.6 90.9 NEUTRON TOOL MATRIX: IW_ATRIX DENSITY: HOLE CORRECTION (IN): TOOL NUMBER PCG 76 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 3.750 3.8 REMARKS: $ Data Format Specification Record FLO PRO 8.80 .0 8.9 5.9 .000 .000 .000 .000 63.3 .3 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11175 11591 11383 833 11175 GR 22.33 274.35 51.3444 833 11175 ROP 37.33 777.88 78.4282 775 11204 Last Reading 11591 11591 11591 First Reading For Entire File .......... 11175 Last Reading For Entire File ........... 11591 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File. Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11591.5 ROP 11591.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11775.5 11808.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 06-MAR-98 MSC 1.32 PCG 5.74 MEMORY 11809.0 11591.0 11809.0 PCD 3.00 88.1 88.6 TOOL NUMBER PCG 76 3.750 3.8 FLO PRO 8.80 .0 8.5 6.8 .000 .000 .000 .000 70.3 .3 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 AAPI 4 1 68 4 2 ROP MWD 11 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11591.5 11808.5 11700 435 11591.5 GR 22.6 143.7 44.7493 369 11591.5 ROP 3.66 1686.24 109.506 435 11591.5 Last Reading 11808.5 11775.5 11808.5 First Reading For Entire File .......... 11591.5 Last Reading For Entire File ........... 11808.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11776.0 12013.0 ROP 11809.0 12045.5 $ LOG HEADER DATA DATE LOGGED: 07-MAR-98 S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Dow~ Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MSC 1.32 PCG 5.74 MEMORY 12046.0 11809.0 12046.0 84.6 87.3 TOOL NUMBER PCG 43 3.750 3.8 FLO PRO 8.80 .0 9.0 7.0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 GR MWD 12 AAPI 4 1 68 4 2 PCD 3.00 68.0 ROP MWD 12 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 11776 12045.5 11910.8 540 GR 21.56 108.3 40.6472 475 ROP 49.51 337.44 108.133 474 First Reading 11776 11776 11809 Last Reading 12045.5 12013 12045.5 First Reading For Entire File .......... 11776 Last Reading For Entire File ........... 12045.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12013.5 12366.5 ROP 12046.0 12399.5 $ LOG HEADER DATA DATE LOGGED: 08-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12400.0 TOP LOG INTERVAL (FT) : 12046.0 BOTTOM LOG INTERVAL (FT) : 12400.0 PCD 3.00 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ~GLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 87.1 89.8 TOOL NUMBER PCG 43 3.750 3.8 FLO PRO 8.80 .0 8.5 7.4 .000 .000 .000 .000 70.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 AAPI 4 1 68 4 2 ROP MWD 13 FT/H 4 t 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12013.5 12399.5 12206.5 773 12013.5 Last Reading 12399.5 GR 22.06 133.77 37.5951 707 ROP 68.09 2682.87 137.163 708 12013.5 12046 12366.5 12399.5 First Reading For Entire File .......... 12013.5 Last Reading For Entire File ........... 12399.5 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12367.0 12487.5 ROP 12400.0 12520.5 $ LOG HEADER DATA DATE LOGGED: 08-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: M$C 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12521.0 TOP LOG INTERVAL (FT): 12400.0 BOTTOM LOG INTERVAL (FT) : 12521.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 88.7 MAY~IMUM ~GLE: 89.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCD 3.00 NGP $ NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point.- ............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 PCG 43 3.750 3.8 FLO PRO 8.80 .0 9.0 7.2 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 14 AAPI 4 1 68 4 2 ROP MWD 14 FT/H 4 1 68 8 3 72.6 First Name Min Max Mean Nsam Reading DEPT 12367 12520.5 12443.8 308 12367 GR 27.06 86.94 39.6055 242 12367 ROP 66.22 1260 129.111 242 12400 Last Reading 12520.5 12487.5 12520.5 First Reading For Entire File .......... 12367 Last Reading For Entire File ........... 12520.5 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF File Header Service name ............. STSLIB.013 Service Sub Level Name... Version Number ............ 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12490.5 12563.5 ROP 12521.0 12590.0 $ LOG HEADER DATA DATE LOGGED: 10-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12590.0 TOP LOG INTERVAL (FT) : 12521.0 BOTTOM LOG INTERVAL (FT) : 12590.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 88.0 MAXIMUM ANGLE: 88.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : PCD 3.00 TOOL NUMBER PCG 76 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 FLO PRO 8.80 .0 9.0 7.0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 15 AAPI 4 1 68 4 2 ROP MWD 15 FT/H 4 1 68 8 3 75.0 First Name Min Max Mean Nsam Reading DEPT 12490.5 12590 12540.2 200 12490.5 GR 25.95 456.91 103.049 147 12490.5 ROP 44.36 128.57 78.5296 139 12521 Last Reading 12590 12563.5 12590 First Reading For Entire File .......... 12490.5 Last Reading For Entire File ........... 12590 File Trailer Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.014 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/04/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 98/04/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File BP Exploration Alaska Inc Well: 17-03A Field: Prudhoe Bay North Slope, Alaska, USA Report Production Log Analysis Prepared For : BP Exploration Alaska Inc Logging Date : 04/23/2014 Report Date : 05/01/2014 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 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 Log Analysis 2 1.0 EXECUTIVE SUMMARY Production logging was done in Well 17-03A on April 23rd, 2014 in flowing conditions with the objective to identify the feasibility of setting a plug to reduce the watercut. 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 was able to detect the hydrocarbon producing zones qualitatively by observing the deflection on the temperature. Unfortunately, the flow was too small to be picked on any of the other sensors. The major water producing zone is 11729’ – 11771.5’, producing 40% of the total water. The estimated flow rates at surface condition while flowing from each of the perforations and the production profile is given in the table below: Perforations Water rate From , ft To , ft STB/D % 11038 11092 0 0 11189.5 11224 58.1 6.685846 11518.5 11616.5 175 20.13809 11729 11771.5 345 39.70081 11795 11858 117 13.46375 11937.5 11982.5 63.4 7.295742 12008 12102 25.3 2.911392 12130 12158 85.2 9.804373 869 BP Exploration Alaska Production Log Analysis 3 2.0 BACKGROUND AND OBJECTIVES The objective for running the PL was to identity the possibility of setting a plug to try and reduce the water cut from the well. BP Exploration Alaska Production Log Analysis 4 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT Well 17-03A is completed with a 2 7/8” inch production liner across which the production log was run. Owing to the small liner size, it was not possible to run array tools. 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 - Caliper - Capacitance Water Holdup – Temperature – Inline Spinner – Continuous Flowmeter. The data quality is summarized below TOOL USAGE LOG DESCRIPTION LOG QUALITY REMARKS WELL BORE PARAMETERS QP Well bore pressure Good Except for DOWN 30, DOWN passes showed a consistent pressure response TEMP Well bore temperature Good Temperature response was consistent across the down passes except for DOWN 30 pass FLUID TYPE CWH Uses capacitance to measure the differences between hydrocarbons and water Good Capacitance tool is unable to pick up the entry of hydrocarbons FLUID VELOCITY CFS Continuous Flow Meter Good DOWN 60 and DOWN 90 show a consistent response on the CFS. ILS Inline Spinner Tool Poor Inline Spinner is unable to read a continuous profile . BP Exploration Alaska Production Log Analysis 5 Figure 1: Wellbore Schematic BP Exploration Alaska Production Log Analysis 6 Figure 2: PL Toolstring BP Exploration Alaska Production 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 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 viscosity 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 °F psi UNITY g/cc cP UNITY g/cc cP ft3/bbl 10717.00 206 2745 1.03 .994 .329 1.06 .824 3.37 0 10899.50 207 2797 1.03 .994 .329 1.06 .824 3.36 0 11082.00 207 2819 1.03 .994 .329 1.06 .824 3.36 0 11264.50 207 2822 1.03 .994 .329 1.06 .824 3.36 0 11447.00 207 2828 1.03 .994 .328 1.06 .824 3.36 0 11629.50 207 2832 1.03 .994 .328 1.06 .824 3.36 0 11812.00 207 2837 1.03 .994 .328 1.06 .824 3.36 0 11994.50 207 2845 1.03 .994 .328 1.06 .824 3.36 0 12177.00 207 2853 1.03 .994 .328 1.06 .824 3.36 0 12359.50 206 2853 1.03 .994 .330 1.06 .824 3.37 0 To estimate the flow rates, the caliper log recorded during the UP passes was used to estimate the nominal ID throughout the log. Tool information The following capacitance tool characteristics were used HydroWater Hz 29063 (Surface Calibration) HydroHyd Hz 34516 (Surface Calibration) BP Exploration Alaska Production Log Analysis 9 4.1 FLOWING SURVEY The raw data from the flowing survey are presented in the Figures 3 to 4. 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. For the interpretation, only DOWN 60, 90 passes have been used since they indicated a consistent response. Down 30 pass shows an erratic response across both the spinner and pressure and hence hasn’t been used in the interpretation, whereas the spinner response across the UP passes isn’t good. Since there was hardly any flow of hydrocarbon on the surface during logging operations, the capacitance hold up tool is unable to pick it up. Deflections on the temperature have been used to identify qualitatively, the possible entry points (Figure 5). The final flow profile, after the global optimization, along with the comparison of the measured and theoretical tool values are presented in Figure 10. The production rates at surface conditions estimated from the production log analysis are presented in Figure 11 and are summarized in the table below: feet Profile Q-Water-STP Qp-Water-STP BFPD BFPD 11038.00 11092.00 Produce 869 0 11189.50 11224.00 Produce 869 58.1 11518.50 11616.50 Produce 811 175 11729.00 11771.50 Produce 636 345 11795.00 11858.00 Produce 291 117 11937.50 11982.50 Produce 174 63.4 12008.00 12102.00 Produce 111 25.3 12130.00 12158.00 Produce 85.2 85.2 BP Exploration Alaska Production Log Analysis 10 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 Log Analysis 11 Figure 4: Input data from the conventional production logging sensors along with station measurements. BP Exploration Alaska Production Log Analysis 12 Figure 5: Temperature deflections indicate entry of hydrocarbons Temperature deflections indicating the entry of hydrocarbons BP Exploration Alaska Production Log Analysis 13 Depth Matching Figure 6: Passes had to be shifted to bring it on depth with open hole gamma ray OH GR BP Exploration Alaska Production Log Analysis 14 Pre- Processing Figure 7: Down 60 and Down 90 passes have been used in the interpretation, the figure above shows an average of the two passes (black line) BP Exploration Alaska Production Log Analysis 15 Calibration of Spinner Array Data The spinner was analyzed to calculate the apparent velocity at each depth. The spinner sensitivity (Slope) and threshold (Vthr) were calculated globally (held constant over zones) and are displayed below. The figure shows a comparison between the flowmeter data and the flowmeter values calculated for each cable speed, with the globally determined slope and intercept. - For each cable speed a different color is used. - The data is shown as solid lines and the calculated values in dotted lines. - For a good calibration the solid lines and dotted lines should match for each pass (color). Figure 8: Velocity profile from continuous flow meter for Down 60 and Down 90 passes BP Exploration Alaska Production Log Analysis 16 The image below displays cross plots for the continuous flow meter. The estimated slopes are used for converting the spinner response to flow velocities. Figure 9: Spinner cross plot for Down 60 and Down 90 passes BP Exploration Alaska Production Log Analysis 17 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 10: Flow profile at reservoir conditions BP Exploration Alaska Production Log Analysis 18 The production rates at surface conditions are presented in the figure below: Figure 11: Flow profile at surface conditions