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192-108
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 14-43 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 192-108 50-029-22296-00-00 9700 Conductor Surface Intermediate Production Liner 9231 80 3158 9051 771 7048 20" 10-3/4" 7-5/8" 5-1/2" 6874 35 - 115 35 - 3193 32 - 9083 8929 - 9700 35 - 115 35 - 3193 32 - 8670 8534 - 9231 9227 520 2480 5120 6280 7048, 9433, 9438 1530 5210 8180 7740 9233 - 9500 4-1/2" 12.6# 13Cr80 30 - 8934 8805 - 9048 Structural 4-1/2" Baker SABL-3 Packer 8872 8484 Bo York Operations Manager Jerry Lau jerry.lau@hilcorp.com 907.564.5280 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 028312 30 - 8538 N/A N/A 25 Well Not Online 8217 7300 1520 164 387 0 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed 8872, 8484 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 12:34 pm, May 15, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.05.15 11:09:14 - 08'00' Bo York (1248) DSR-6/3/25JJL 6/13/25 RBDMS JSB 051525 ACTIVITY DATE SUMMARY 4/21/2025 **WELL S/I ON ARRIVAL*** (WELLTEC MILL XN TO 3.805'' /PERFORATE INTERVAL & SET NS ER CIBP ) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH MILL XN AT 8922' TO 3.805'' ID, WITH WELLTEC MILLER 3.805'' OD BIT PERFORATE INTERVAL 9233'-9245' WITH 2 7/8'' GEO RAZOR 6spf 60 DEG PHASE CCL TO TOP SHOT=10.2' CCL STOP DEPTH= 9222.8'. CONFIRM SHOTS FIRED SET " NS ER CIBP AT 9260' CCL TO MID ELEMENT=13.3' CCL STOP DEPTH=9246.7 '. PLUG PARTIALLY SET AND PULL OUT OF ROPESOCKET PLUG AND GUN CORRELATE TO SLB GAMMA-RAY,CCL JEWELRY LOG DATED 13-NOV-2010 BRING S/L TO FISH THE TOOL STRING *** WELL S/I ON DEPARTURE*** ***FISH IN HOLE: OAL: 17.13', GR/CC/SETTING ADAPTER/PARTIALLY SET NS 5.5ER CIBP, 1' FN (SEE WELL PICTURES FOR DETAILS)*** 4/22/2025 ***WELL S/I ON ARRIVAL*** (Perforating) PLANTED 4-1/2" BAITSUB W/ 3.50" WFD RELEASABLE OVERSHOT ON EL FISH AT 9,223' SLM PULLED OVERSHOT AT 9,223' SLM (grapples smeared) ***CONTINUE ON 4/23/25 WSR*** 4/23/2025 ***CONTINUED FROM 4/22/25 WSR*** (Perforating) PLANTED 4-1/2" BAITSUB W/ 3.50" WFD RELEASABLE OVERSHOT ON EL FISH AT 9,223' SLM PULLED OVERSHOT FREE FROM FISH AT 9,223' SLM (unable to keep planted) JAR DOWN FOR 2 HOURS ON TOOLSTRING @ 9,223' SLM JARRED 8 TIMES WITH 1-3/8" JDC ON TOOLSTRING @ 9,223' SLM(skirt blown out) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 4/25/2025 ***WELL S/I ON ARRIVAL*** SET NON RELEASABLE OVERSHOT ON FISH @ 9,229' SLM(Bowen 9300 series w/ 1.50" basket Grapple) LAID DOWN FOR WINDS ***CONTINUE AFTER WEATHER STBY*** 4/26/2025 ***CONTINUED FROM 4/25/25 WSR*** JAR ON E-LINE TOOLS & CIBP @ 9,227' SLM (2 HRS 2800#) RECOVERED BAIT SUB, E-LINE TOOL STRING & CIBP (CIBP MISSING SLIPS & ELEMENT) ***CONTINUE 4/27/25*** 4/27/2025 ***CONTINUE FROM 4/26/25*** DRIFT W/ 3.80" CENT. 2' X 1-7/8" STEM, 3.80" GAUGE RING S/D @ 9,390' SLM ***WELL LEFT S/I*** Daily Report of Well Operations PBU 14-43 Daily Report of Well Operations PBU 14-43 4/30/2025 ***WELL S/I ON ARRIVAL*** (PLUG SET) MIRU HES ELINE, FUNCTION WLVS PROGRAM DPU FOR 160 MIN, START TIMER @ 12:20 PM PT 300 PSI LOW, 3000 HIGH RIH WITH NS 4.5 X 5.5 ER CIBP, GET HUNG UP IN NIPPLE AT 2161' ABLE TO WORK FREE BUT NOT POOH THROUGH NIPPLE, GET HUNG UP AGAIN IN GLM AT7047' TIMER EXPIRED - PLUG SET OFF DEPTH AT ~ 7048' IN GLM. RDMO HES ELINE ***WELL S/I ON DEPARTURE*** 4/30/2025 T/I/O= 500/150/0 Assist E-line ( Stuck in Hole ) Pump 71 bbls crude as directed by Eline FQWHPs=500/150/0 5/12/2025 ***WELL S/I ON ARRIVAL*** JAR DOWN ON CIBP @ 7,020' SLM FOR 4 HOURS W/ NO MOVEMENT MULTIPLE ATTEMPTS TO LATCH CIBP W/ 3.65" RELEASABLE OVERSHOT (ONLY FRICTION BITES). RAN 3.72" LIB TO 7022' SLM. SHOWS SHEAR STUD (~.80" OD). RAN 2.25" BDK RELEASABLE OVERSHOT (.82 - .95" GRAPPLE) TO 7022' SLM. ONLY FRICTION BITES. RAN 2.25" BDK RELEASABLE OVERSHOT (.70 - .83" GRAPPLE) TO 7022' SLM. ONLY FRICTION BITES. ***CONTINUED ON 5-13-25*** 5/13/2025 ***CONTINUED FROM 5-12-25*** JARRED DOWN ON CIBP @ 7021' SLM FOR 2 HOURS W/ NO MOVEMENT. ***WELL S/I ON DEPARTURE*** By Grace Christianson at 10:48 am, Apr 23, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.04.23 09:41:45 - 08'00' Sean McLaughlin (4311) 325-248 DSR-4/25/25JJL 4/23/25 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. SFD 5/5/2025 10-407 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.12 08:08:41 -08'00'05/12/25 RBDMS JSB 051225 To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: April 23, 2025 Re:14-43 Sundry Request Sundry approval is requested to set a whipstock in the 14-43 wellbore as part of the drilling and completion of the proposed 14-43A CTD lateral. Proposed plan: Prior to drilling activities, screening will be conducted to drift for whipstock. E-line will set a 4-1/2"x5-1/2" whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to pre-rig, the rig will set the 4-1/2"x5-1/2" whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in the Shublik and lands in Ivishak Zone 3 and continue drilling Zone 4/3 to TD. . The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in May 15th, 2025) x Reference 14-43 Permit submitted in concert with this request for full details. 1. Slickline : Set DGLVs 2. E-Line : Set 4-1/2" x 5-1/2" Whipstock at 9,100’ MD at 0 deg ROHS 3. Coil : Mill Window 4. Valve Shop : Pre-CTD Tree Work 5. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in June 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2387 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not done pre-rig). 3. Drill build section: 4.25" OH, ~152' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2440' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 35 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Liner lap test. Set LTP if necessary. Set live GLVs 3. Service Coil : Post rig RPM, CBL, and perforate 30' Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3"or 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee \ort- \.Coq. I2.. 1.c) I HALLIBURTON RECEIVED I FEB 0 6 2015 I AOGCC 1 I scow FEB 1 12015 BP America I Well: Prudhoe 14-43 I North Slope, Alaska, USA i Production Array Log Analysis IPrepared For 1 BP Alaska Logging Date 1 26 November 2014 IReport Date 1 16 December 2014 I Submitted By 1 Eric Michael Staib I +1 419.552.1643 1 10200 Bellaire Blve, 2SW 17E IHouston, Texas 77072 1 eric.staib@halliburton.com II LIBURTON 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 OR 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 I XCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT,FOR ANY LOSS,DAMAGES,OR EXPENSES RESULTING FROM THE USE THEREOF I HALLIBURTON 1 BP Alaska HALLIBURTON 0 Production Array Log Analysis TABLE OF CONTENTS I 1.0 EXECUTIVE SUMMARY 2 ' 2.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT 3 3.0 PRODUCTION LOG PROCESSING 6 3.1 Flowing Survey 8 3.2 Shut-In Survey 18 4.0 STATIONARY SURVEYS 4.1 Flowing Survey 28 4.2 Shut-In Survey 31 I I I I 1 BP Alaska ' HALLIBURTON 0 Production Array Log Analysis 1.0 EXECUTIVE SUMMARY Production logging was done on Prudhoe 14-43 on November 26, 2014 in flowing and shut-in conditions. Both passes and stations were recorded. The flowing PL analysis showed the well to be producing gas almost exclusively from ' the top perforation zone, with oil spread throughout the four deeper perforations. The lowest perforation, at 9340-9346', produces -33% of the well's water with only-34 bbl of oil. ' The estimated flow rates at surface condition from each •erforation are liven below: Dept Water Oil Feet BFPD % BFPD 9269.5 9289.5 1306 18.6% 0 0.0% 10551 97.3% 1 9290.5 9295.5 6.43 0.1% 137 38.3% 148 1.4% 9296.5 9308 580 8.2% 81.1 22.7% 94.3 0.9%r 9321 9338 2805 39.9% 106.1701 29.7% 37.95 0.3% 9340 9346 2338 33.2% 33.56 9.4% , 16.5535 0.2% CUMULATIVE 7035.43 357.8301 i 10847.8 Logging Rates Reported: 7200-7500 BPD Water, 11MMSCFD Gas,350 STBD Oil The production log analysis shows a very good fit to the rates reported by the field. I I 1 I I I 2 I 1 BP Alaska HALLIBURTON 0 Production Array Log Analysis 1 2.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT Well 14-43 is completed with 7 5/8"casing and 5.5 tubing across which the production ' log was run. The wellbore schematic is presented in the Figure 1. The tool string diagram used for the PL logged is presented in Figure 2. The tool string consisted of the following production logging sensors: Spinner Array Tool - Casing ' Collar Locator — Gamma Ray - Pressure - Inline Spinner— Radioactive Fluid Density — Inertial Fluid Density — Capacitance — Gas Holdup Tool - Temperature — Resistance Array Tool—Caged Fullbore Spinner The data quality is summarized below TOOL USAGE LOG DESCRIPTION DATA REMARKS 1 QUALITY QP Well bore pressure Good Required for Plato analysis. WELL BORE PARAMETERS TEMP Well bore temperature Good Provides quality control on other logs. Radioactive density tool uses FDR radioactive source and Good Used as density tool for holdup. detector to measure density and is a center sample device Uses capacitance to measure FLUID TYPE CWH the differences between Good Down passes used. hydrocarbons and water RAT Resistivity Array Tool Good Reacted strongly to gas production. GHT Gas HoldUp Tool Good Aided greatly in analyzing gas production. Uses attenuation of tuning Mimicked FDR,but read too low above FDI fork to infer fluid density. Good the main gas producer. Good Provided reliable uppasses for flow rate SAT Spinner Array Tool calculation. 1 CFB Caged Fullbore Spinner Poor Suffered polarity issues,very noisy. FLUID VELOCITY ILS Inline Spinner Good Was the basis of Vapp analysis. 1 i 3 1 I 0 ' HALLIBURTON BP Alaska Production Array Log Analysis I , - ow ( : 1 4.43 SMUT NOM.N2S REACINGO AVERAGE 125 iCJFt 1iAlAli(L'! ppm WIMI ON MI-"1 iROME T80&LW.'•• PAW KB lily- /4' OF aCV- 1I I I KON.• 5340 Nuc WAngleI MU. 3r a 9317 41 ?NV Dt4ua+lU= 9169 p ! 2151' i1l/ZCAM Bi1L0AVlNNP.D•7ali" owe IVO- NOP ... GAS LFT MANS I 20'4201434C100.0$410,$40.0.19.134' 1ir ST( MD 1VU DPI(T4FE VLV iLAT01 P*8 OAR 1 1651'3663 1 4VAX COME BK 46 amp NSl4'O50 43 IA N>509 4).11 963x• 1111' 2 5872 5851 22 wax mkt! 8K 16 0312913 r _ �_ _ ` (" "'" 3 7047 873 29 VAX MAE.' OK 16 037J113 1 -J +— 4 7715 7462 27 VYdX OW 8K O IW&08 I S 5046 7757 26 VAX 00iE BK 16 o u j MN11r11UR11 q•3.726• 8822' 0 6413 Ball 29 VIB)t tilt BK 0 1/r SAM 4-112'OM XN NIPPLE 7 PA AM 41+-wa�c �a OK_ r.. a I i---- sow H4-18!PNIlARMRS MP.D.341r z+ --- 7 0A'x 4-112* MII.3 MK I). "7 I I MU' 4-114 MOM OW NT,D•sow I 1 L Mer H4-112OToKNNP.D=1726' 1 [TOPOFD il?1104H Mgr I sow_ ,-t'9!6'x61?OO4Ta1AGKAV,Am1 J 4-1ir Tett 12.56.on)CR.N NSCT. Mir / ` � NK' 1/r VAS%O.3.968'' 01521p1, v-1450 J sor 1-+1j rm000n)limos 1 Mfr fir•oor.x 3.yr wpm,/ J 7•M'COQ 29.161NT-N,D-$Vrj-- –� k IREFFORA RON SUMMARY I *8*tOO BRCS0N11x380 I I ANGLE A T IOP Mr 25'v 92117 *Yr Rater b Roduc 4a+08 far lusiorcal part di set EN 4ABtVALOpnif- 51t)T SQZ ' I 3-2/7r3-2/7rS 9970-9290 0 1 ttt3t10 1346" 4 9290-90'7 S ' 1111442 081M81 1 I 3118' 4 4298-NMI O i Obn5411OBVH4T CAPMi3 95T10dl 1310 4 9321-9339 C I Ansa* 1!!1!!!!!!!!!!1 B' >S 4 9016-5310 S i tV14*2 0911'50!; 8iJa�BPsET0780i011 3310 4 9042,9346 C 1 0611601 1 2-74' 8 4404•94011 s l Otn2l9 0211 MAI I 7-1/r 6 9472.9487 C0►tan1 i I 2-715' 8 9496-9600 S I 01/1249902/1Ua l I Fum_I-{ sew 1 11111/!11/.!!/!, I E Vr SIR 1UR i ri,13-0111,On?i K.a a 4 oar 4 WAWA (ATE REV BY 1 commas 1797E mal BY OOMde(TS FR.DIOESAY UV 1171582 CO SGML COM!l.LRIC41 013813 511013PJC SET) N 1LU3(1209x12) VAIL 14-43 12/20409 SEWSV CAN S`JO(128989) _0210813 SVIG.M)PILLED IV 4 S.WQ15 5/407991 POW Fe 1921060 DMIN 11/16110 RAG SET66111713WW) 0822/13 TRAM)TR$00(00111/13) —1 APINo'50 029 2224800 _1210810 TN RIC SLIM:3 S(12104/118 547/1413 T.M.MI)ALL XXIIPLUGPGLV(0(001m13) S!!;4 71014 814E 20 Ht.A 12/V 1* 12/1810 CORM OLV caittetiiiii _ 0111'7112'IMi.1b A 114)3 `SAF 4183E I j Bp Paploratlon(Alam a) IFigure 1: Wellbore Schematic 1 4 I 1 BP Alaska 0 HALLIBURTON Production Array Log Analysis Sensor Offset ft Schematic Descrirtion Lenrih ft O.D. in We.ht lb STNDCH-STND_CH 1.08 1 1.44 1.00 l_:, 1.43751N CABLE HEAD 169_evans1.92 1 1.69 5.00 I _WT-2.75'Tungsten 5.00 2.75 168.00 5'x 2.75'Tungsten Weight Bar I GR#2 32.76 i CCL#2 31.39 ■ 1 1 _X-OVER-GoxSondex 0 27 1.69 1.00 I OTMP#2 30.99 `{ Go Box x Sondes Pin Crossover OP#2 30.99 _1XTU-XT0002(10004796) 1.79 � 1.69 9.50 OTMP#2 30.99 Crossover Ultrawire Toolbus to UltralInk RATHS 24.38 j �PKJ-013(10003476) 0 56 1 69 ; 5.00 Production Knuckle Joint With Gender Benders i RATMS 24.38 _,• PGR#2-020(218310) 1.92 1.69 9.50 • YG 21.11 Production Gamma Ray XCAL 18.90 _�QPC#2-002(AJD00049) 1.58 1.69 9.00 YCAL 18.61 _ Quartz Pressure/Collar Locator SATROT 12.81 �PKJ#2-013(C1311) 0.56 1.69 I 5.00 SATINCY 12.81 Production Knuckle Joint With Gender Benders SATINCX 12.81 \_PRC-034(10000616) 2.77 1.69 13.00 SATT6 12.81 Production Roller Centroliser(4 Arm) SATT5 12.81 I SAI I4 11.81 - CRAT-001 Array To 205) 4.28 1.69 18.00 SATT3 12.81 Resistance Tool SATT2 12.81 SATT1 12.81 _ _ SATD6 12.81 SATD5 12.81 HGHT-A(214594) 1.96 1.88 10.00 Halliburton GHT SATD4 12.81 SATD3 12.81 SATD2 12.81 ! PDC-015(10002128) ! 3.13 1.69 15.00 Production Dual X-Y Caliper SATD1 12.81 SATR6 12.81 • SATRS 12.81 - PRC-034(10004677) 2 77 1.69 13 00 ; �� Production Roles Centraliser(4 Arm) I SATR4 12.81 SATR3 12.81 SATR2 12.81 '-, SATR1 12.81 SAT-001 (217682) 3 79 1.69 14.30 DENR 9.86 '' ( l Spinner Array Tool FDRC 9.86 \ / TEMP#2 8.61 �, . • FDIB 7.00 1 . FDR-020(217915) 1.92 1.69 10.00 I EDIT 7.00 -1'I p _ `Ilrki Density Radioactive FDIF 1. 7.00 ZPRT#2-PRT016(10004629) 1.04 1.69 6.00 ILSDIR 2.89 7 - UW Platinum Resistance Thermometer ILSRATE 2.89 •V • ._FDI-001 (10003246) 1.71 • 1-69 8.80 I TEMP 1.80 ' I _ Fluid Density Inertial CWHG 1.44 CWH 1.44 4I -.`PRC#3-034(AJC00008) 2.77 1.69 13 00 Production Roles Centralises(4 Arm) at CFBDIR 1.10 I CFBRATE 1.10 H - ILS-022(AJE00017) 1 44 2.13 6.00 HVOLTX 0.00 '' `Irine Spinner ITEMPX 0.00 n -'. CTF-003(10000059) 1 54 1.69 5.40 TSTAMP 0.00 - Capacitance Temperature Flow ' LLMTEN 0.00 -- -'CFBM-5.5"_6ARM(214819) 1.00 1.69 5.00 g --tying --- 5.5.6Arm Caged Fullbore Spimer ' Figure 2: PL Tools L_... 1 5 I I BP Alaska 0 1 HALLIBURTON Production Array Log Analysis 1 3.0 PRODUCTION LOG PROCESSING The production log data from the flowing were processed using the PLATO software. I 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 Idata 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 Idiscrepancies include tool measurement errors, conflicts between the parameters or conditions that make the underlying empirical models(such as flow regimes) less applicable. I • The flow regimes were determined, directly from the flow rates and holdups, according to the Taitel -- Dukler analytic model. I • The profile factors,to calculate the true fluid velocity from the apparent velocity, were based on the Reynolds numbers. is • Solution gas in oil was derived from the correlations (Vasquez-Beggs or Oistein- Il Glaso). The analysis was performed in six steps: I • The data preparation to filter the data, compute gradients and error estimates. • The calibration of the array tools and full-bore flow meter. I • The computation of the layered holdup and layered flow-rates. • The profile determination to identify the potential producing and/or injecting zones. I • The computation of the flow rates by global optimization. • The computation of surface productions and reporting. I I I I I 1 6 I I BP Alaska 0 I HALLIBURTON Production Array Log Analysis IThe water density and viscosity were calculated using a salinity of 20.6 kppm. The Craft & Hawkins correlation was used.The oil density and viscosity were calculated using an I oil gravity of 28.4 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 I was calculated using the Lee Gonzales Eakin correlation. The following gas parameters were used: I GasType SPGG UNITY Miscellaneous 0.751 GP-0O2 UNITY 0.1285 I GP-H2S UNITY 0 GP-Nitrogen UNITY 0.0059 Tool Calibration I Capacitance Hydrocarbon Hz 29060 (Downhole) Capacitance Water Hz 27272 (Sump Calibration) GasHoldupWater Hz 31030 (Sump Calibration) IGasHoldupGas Hz 12415 (Surface Calibration) RAT Calibration I Probe Hv Lv 1 0.7 0.391 3 0.7 0.404 1 5 0.7 0.402 7 0.7 0.416 I 9 0.7 0.391 1 1 0.71 0.393 RAT IWH 0.29 IDepth ' feet ' 9225.00 217 2213 1.04 .978 .295 1.18 .797 1.16 330 .00803 .114 .0174 9240.50 217 2216 1.04 .978 .295 1.18 .797 1.16 331 .00802 .115 .0174 9256.00 217 2219 1.04 .978 .295 1.18 .797 1.16 331 .00801 .115 .0174 I 9271.50 218 2223 , 1.04 .978 .294 1.18 .797 1.16 332 .00801 .115 .0175 9287.00 221 2229 1.04 .977 .289 1.18 .797 1.15 331 .00804 .114 .0175 9302.00 221 2235 1.04 .977 .289 1.06 .838 3.74 332 .00802 .114 .0175 I 9317.50 221 2241 1.04 .977 .289 1.06 .838 3.74 333 .00800 .115 .0175 9333.00 221 2247 1.04 .977 .288 1.06 .838 3.73 334 .00799 .115 .0175 I 9348.50 222 2253 1.04 .977 .288 1.18 .796 1.13 335 .00797 .115 .0176 9364.00 220 2259 1.04 .977 .290 1.18 .796 1.14 336 .00792 .116 .0176 I 7 1 BP Alaska HALLIBURTON 0 Production Array Log Analysis ' 3.1 FLOWING SURVEY The raw data from the flowing survey are presented in Figures 3 to 5. Figure 3 has the ' data from conventional production logging sensors. The response from the Resistance Array Tool is presented in Figure 5. The response from the Spinner Array Tool is presented in Figure 4. Analysis shows that oil production is spread throughout the well, though massively ' overwhelmed by water production. Over 97% of the gas comes from the top perforation, but there are shows of small gas quantities in lower perforations, which is also apparent in the temperature curve. PL analysis does not indicate a problem with thief perforations. ' From the spinner response, the velocity profile was estimated using the slopes calculated from the spinner calibration (Figures 7-10). The estimated SAT velocities and the RAT holdups are used to calculate the flow profile presented in Figure 10. ' The final surface flow profile, after global optimization, is presented in Figure 11. ' Depth Water Oil Gas t BPD % BPD % MCFD % 9269.5 ' 9289.5 1306 18.6% 0 0.0% 10551 97.3% 9290.5 9295.5_ 6.43 0.1% 137 38.3% 148 1.4% ' 9296.5 9308 580 8.2% 81.1 22.7% 94.3 0.9% 9321 j 9338_ 2805 39.9% 106.1701 29.7% 37.95 0.3% ' CUMULATIVE9340 9346 2338 33.2% 33.56 9.4% 16.5535 0.2% 7035.43 357.8301 10847.8 8 1 I BP Alaska 0 I HALLIBURTON Production Array Log Analysis IRaw Data - The figure below summarizes the input data recorded at the well site. - Each pass is shown with a fixed predefined color. I Depth LSPC LIEN CFB CAP ILS DENS CENR GR YG OTHR 'ft: 12 t. g!cc 12 rps 18 rps 24 C 0 gicc1.2 212 224 1 I I I I, I — _ I _ I I 5 I .( i I �Iil { 1CC I ' I I 1 I !11 �cy I — — I I • I 1� I I I L I�iI i 1 1:1:11eI 4r111.1 — — I 1,?t �I 11 t Y : I I; 9200 • 1. i I I1 {i i,____,I,' _ iI I I I I I I + + — — I II k I I '. i ! HI l' l T I, I _ — zi 1 93C0 I , e 1 I { 11 I E' I , I — r I 1 I r'll If' 411 — 1 IsI. i I I ;'tr ': ___i I I I — 9zCC i I i I Figure 3: Input data from the conventional production logging sensors. Temperature is charted as OTHR. I 9 I IBP Alaska 0 HALLIBURTON Production Array Log Analysis I D.Ptn -180 ionCa ASpinn.Ol.Flt ASpin..02-Fit ASFinn.r03-Flt ASPinn..04-Fit ASpinnr08-Flt ASoinneg8-Flt ASPinrnr07.FIt ASpinn..08-Flt fi.t OpM9 0 RPS ❑ RPS 0 RPS ❑ RPS 0 RPS 0 RPS 0 RPS 0 RPS ❑ 832•.00 -180 190 4 43 1 40 -0 42 -0 41 4 43 -0 .. -9 22 -4 22 93e.00 ATRo 811en-Farm ASNnn.AB-TP.o ATRobeon-TMo RPS 0 I Variance at on rotation t 0.901811 .4 22 ). ,4 / ' ', ) 11(,. 9232 �'i ' �� 92.0 (t4V1 '' z 92.8 1 I i/ 9296 .! ' 1 * t 926. • I y I 9272 — f J .__....__.. 9280 ; b R ) ),; I 9288i t($ 4 ))jj 1 9290 1 830'• \ / 1 931:. RE 'F .i• i r �i i : : . 1 9320. A f/ , , i )::::: , , r 9302. 1 777 9300. I Figure 4: Spinner input data.Notice that Fullbore(ASpinner07 in Plato) is very erratic.Inline Spinner data (ASpinner08)was used for the flowing analysis velocity profiles. 1 I I I I 10 I BP Alaska 0 I HALLIBURTON Production Array Log Analysis ICe tr RATRobocrlcp44_,8_73'4,2:'.Z:' RAT03.Cm RAT01NCp RAT07.1 Cc' RAT09-NC r RAT11•NCp tett Dp44_,8_73'4,2:' ohm ohm ohm ohm ohm 922!.00 0 •3 7 29 28 74 3 !9 27 .74 28 7!' I9364.00 4,4 9232. y . I t me '^ 9240■ j , } h... :+ 1 4. --' 111 ; '_ Cry o,,. '.� .r! r`i 4 .5„ 4. r 4 A::r 4. 41. 9272. `h �f Y ilio. r-,o` 0- qS I 9280. / t r 1,- ( e( > �,' NF 1 is I J! 9288. il t I ' ) 8296 t....— i I 5304. ` /i r 9312,/ ill 93213. I [ .I 1 i i 9328 ) , 1'-r 1i I t 1.+ v. 8 I 9244 8362 Ii { f, j r'if 9360 ' i. IFigure 5: Input data from the Resistance Array Tool (RAT) I 11 I IBP Alaska 0 HALLIBURTON Production Array Log Analysis IPre-Processing D•pth Caliper Temperature-Ca P...,-Cw �D.ulry{er Dialittviata GMT PIPNndlnetlon TVC Not In 0 'F 0 PO B ape B Mz 0 K. 0 Daytnp n I 922".00 4.M 0.11 169 223 2211 2261 .33 1 27200 29000 0 37070 2s u ..20 113 260 930400 GIIpW TW Pwf RMFIuW M,aMFRQ 0 44Ip�p��_ In ❑ 'F El PP 8a'a B BM: B •8a 0.11 1139 223 2211 2201 33 1 27200 29000 0 33000 DP1pe TM{RP Pn1-ERP RncPIui6ERP I+y FRQ•ERP Oe*MoIC�.pFR,'t.ERP In 9 'F I, 0 CP 0 we‘ 0 M) 0 Mi ❑ a 34 6.11 0 399999 3 1 0 01 0 100 0 33003 DCa11pr DT4}DI CP.,fC_ DG.Woloi.pFRQCp ♦.0 0.181 • 1t ❑ .Fs^ 6 .2 -2 s00 8 DTn} Dz-ERP DPw}C:ERP 'Fry 0 tPe'm ❑ 01 0 1 0 Tpeptne.m 'F 9 I169 223 9232. :‘:, .:::. .- 9260. ; I 9243. . 9206. _ R 9264. ., t 9272. ', ti\�+ __- 4. 9260. $ ,.. > t .. ,'.. 9260. i ' 9296. r '' ''''': i .. . 9304. 9312.I I 9320. • V 9328. I 433E. • 11 93+4. 9702. i 9360. r• II .. Figure 6: All the passes have been used in the interpretation, excluding up passes of Capacitance. I I I I 12 I BP Alaska 0 I HALLIBURTON Production Array Log Analysis ICalibration of Spinner Data Shown on the image below from left to right: I Track 1: Track 2: Incoherence between the theoretical and measured Array Tool responses. 'Unwrapped'rotation curve for each pass. Track 3: Normalized layered velocity profile. This profile is optimized by comparing the I measured and theoretical SAT response for each pass of each spinner. Tracks 4,5: Vapparent as calculated from ILS and CFB. Recall ILS was substituted for CFB. Tracks 6-11: Measured and theoretical SAT responses for each spinner. I Track 12: Track 13: Measured and theoretical responses for the substituted inline spinner. Measured and theoretical responses for the inline spinner. I Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity rofile. CBCAATT Ver -VXP9M1 -AD19T8gR0sAn4Fal1pnCpr 080 FV•3P0M 0 11408®20 FV-t0M B]a0 V-t0pl. 7 4 0 M90.2258M00 =1 rn40 ApS rrMQ ApSlnnaQ AP9 rM9Q AS9 n..Q07 ASPSlnn9Q0 :,s nuO =70:5 RAT ATRpution-atm - 930400 A9pinn..r01 ASpin W2 ABpinn4.03 A90554904 ASpinn4t07 ASFInn..P ASpinna.08 0 9 � ATApg9pn-TM9pIGO RPS 0 RPB Q fun O RPS 0 RPS O RPS O RPS O •VF.ieno9 art on tooth -SO 0 120.0 { 43 { K { 42 { ♦f -0 43 .43rf f 'ffl +a + _._.._ 9232 •I i '. 1I. 1 I .9240. I` J .9248. y A I it rf! 92!10 '1 I _ ' 11 920+ 3 I 24/.1.1 -- o / /. 92]2 ! r/ ::::: , ( 19312: 3304jr ( (I' 7 E / _8320_ a' I \le I I . I I M I { ` 9328 {)` i I. I 1 9330 ( P i . I1 .f 9372 I 93W � tc i I i Figure 7: Velocity profile from SAT data I I 13 I IBP Alaska 0 HALLIBURTON Production Array Log Analysis I ASp nrOTFhiAPS)Y4141,17) 17.0 VabAspnMAiFPMXx•157770; ASgnMA1Fh!AP51Yy.T.7.45i UMSpid0cnOrIFPM)Xylta2.43211 ASpinnt4441t lint Yy-0!2 VnbAapin4O4 PMXR•200.800i VnbMSpinMO1 iPM)X.150,900) Spinrw5amde;RPS)Yy1.a,4a) 42 450 13.5 35 1 I 37` ' . 05 b 24 to.a 300 9.0 4!... : , I1.5 A 18 I 5.0 .. 17.0 r,:. 12 I 4.53.0 1.5 ti 0 0 1.5 I t s: !0 0 150 300 450 503 170 908 230 3 200 400 800 Vb0 b' i' t> Spirmx041[PM) , 1.6 V0044914MA1(FFM) 4Sprtw024It'9FS ' .543 IV26ASpi•,r40.:41' +50770 45r-^4;5.:I'4F$'='545) IVettASpinn40505,1)X4-2004800; j 4.0 I et 4.5 4.0 75 I 1 30 80 �, 470 0 150 000 450 500 750 24 VnbAS04n407 FPM) .._ ' I 4.494111410041(RPS)7414.72) IYo14.41nn4rp9;FPDX41•150.750) it 17.0 22 12 • 15 m 5 I 16 O , I 1s 4 •7.5 .150 0 150 300 450 500 7% •200 0 20C 408 500 900 I 14 VabA4144 02 iFFA1i VO0A13044.00 pia) ASpfnror03Fh;RP9iY4t,421 IVb10ASpinruA3!FPAtyXN•150770) A.4104.054h;RPS)Y.-0,45) IVn0A5pinns451FPM))01.170,900) 12 42 45 40 I10 3e 37 1 30 30 4. 5 24 r�N:L�1•• 27 ",..!4'1.)•'5- . � '•'I 1 ,t ., 1 /yam. • 2 le I 10 5 :_'4, 2 0 00 ,...../ 1 .ISO 0 150 300 400 MO 754 .150 0 150 300 450 000 750 .150 0 150 300 450 500 750 900 VaOAS0044.0111PM) V00Aspin44031PPM) VobASpin4t071PPM) Figure 8: Calibration crossplots of spinner data. Note the poor behavior of CFB(ASpinner07,top left) I 14 I 0 I HALLIBURTON BP Alaska Production Array Log Analysis IHoldup and Velocity Profile: Shown on the image below from left to right: I Track 1: Track 2: Incoherence Profile for Holdup and Velocity evaluation Layered velocity profile Track 3: Layered water holdup profile I Track 4: Track 5: Layered oil holdup profile Layered gas holdup profile Track 6: Total holdup varying with depth I Track 7: Track 8: Flow Rate profile expressed with holdup Layered Resistivity Profile Tracks 9-14: Calibrated RAT responses feeding holdup profile ITrack 15: Density profile(radioactive)feeding holdup profile 0 Cm..Vs091 I.1 AT 17151 ATNIn.y-OII ATgm 9•,(!.NWeu Pro01. MTO1-Flt RAT03-FIi MTO!-FR - Ot•Plt T11 11 RntFlulo Ei OR SAT FPM UrOrr 0 UNITv ®UMTY I 0 1 - RAPUNIT enm ❑enm ❑enm ❑Mm ❑onm ❑Mm ❑03� L2 CAT 40 920 0 /0 I 0 I 0 I •• 0 i 39 N! 9! . .02 At 02.39 00 39 00 0 t2 RAT N. 119 iiii I OX: Y alta ..t. 9�� MTO/.Tn.. RAT03-TMc TO0-T1c T••TMo - TO9•Tw MTII•TMa -noFluni I 0 219•30 •, al a,m ❑mm ❑enm ❑onm ❑pp ❑mm ❑pa B ' '••• Gees 39 0•• .09 4 02 •I .02.99 09 39 00 0 12 RATO!N• RAT0111v T09-14v RAT 07M711M BR.oFlule-T atm B atm B anm B atme39 N A 09 • 03.1 ME39 O MT011v RA 0 • RATO M ,,T07• RA 09... RATI1.l. enm B t.- B onm B eme B enm B 0- 9 39 O<.• 09 • 03.•1 .02.30 OS 39 00 � r � f {!1 92W I q tF;d { 9211 I+` j 4 i ,. 92'2 6 777 I ..(1 e 9:90 , , I r 9:99 ..4 I t 11 929! - I( t a , II ! neo 1 ' � , 9129 n30 I , WA I �1 I93.2 5 i 9x0 1 i IFigure 9: Holdup and velocity profile and calibrated RAT responses used for profile. I 15 I IBP Alaska HALLIBURTON 0 Production Array Log Analysis I 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 I data. In this figure the data is represented by the blue curves, while the calculated tool values are I shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. I 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 I the flow regimes are shown. Within the transition zones several regimes can exist intermittently. D 4Y I700V.e Nolou.NO 0le*R.N V.>W'..p Rn*Flu,O43 MerpFR0.W' ;:.1/4:":11,'(:P: WObuoURO- CAT4O.s-W,.,OAT-0iFW.K OAT-0.o-Wo. VAT-0aaW.K OAT.Ta.W.9p Nn UNITY UNITY R B BFPO FFA1 ❑ooc %NF 0* ❑BF00 ❑BFPD ❑BF00 UNITY ❑m3. ❑ 0220 00 0 32000 0 1 0(200 0 2.000 .10 7!0 0 1.2 27200 11900 01000 31100.100 9000.100 3.00 1000 17000 0 72.001 0..09.7 9350001 M.09l.n0. gra-NR U01' yap 91001..10 0yp.FFRO ONNOIOuo$RO OA7n -0n W. . GAT-0.1 OAT VAT•OK OAT.Tet Sue I Hlip 00 Pa Oil FPM 9 o.r_ 9 NF 9 No a 0090 9 BFPO 9 BFPO B UNITY B m3. B 01* Tool. On PM Oa .10 7.0 2 1 2 27200 28900 21000 31100.100 9300.100 3000 1000 17000 0 72.001 0...1-M.M T.mpv.lun P.O V.0.Tn a #10F1544330 NyO.e300 Tn.o 0UNUICYPFRO-'OAT-W.1.o.TM.OAT-0110AT-0K.Tn.o VAT.OKT1ue OAT•ToaTM.e Y Mn 00. FPM 0 13,99 B W B 1.0 B BFPO B BFPO B110190 B UNITY 9 mi. 9 0a. 10 '50 2 1.2 27200 29830 21300 31100-100 9700.100 3000.1000 17000 0 7. .201 000 A•Tub GM OTB 0233 92 I 00. 11 1i it K.4 I me .,�Fy, 1 k a ) , I 917' \ / j/kr. / 3391 I(/i 1 rf 1/ ::.:.. ......„ .e I 9189. 9281. 93100.0- I ::::i I 9312. 9120. M :X.. 9318. 011.* 1.ee'e' 6°` sa e✓ 9301. ( li �yb'.f°'e' I 9352 .•J °. ye 9350 }i°�•e�s a0�e Figure 10: Flow profile at reservoir conditions along with layered holdups, apparent velocities, and holdup calculation tracks. I I 16 I BP Alaska 0 HALLIBURTON Production Array Log Analysis I The production rates at surface conditions are presented in the figure below: I C.pt� T FI0ePna OOn OOiI :As* CpCNF OPOiI ,2 Naw 3Yt.2ii Cate-011 9an-�Aat« tan ft 9 BFPC AIAICFC SPC .BPC 3,,,,u© +BPC +BPC tICFCR 0tI ft ebi PE 9H! YD 280 0 2a030 0 !0 !0 a!0 t0 0 t!0 Y00 0 7a 0 W3 93!4 00IF PEfF Auv I 9:: . I 5.<. I 5:5:. I 9:99. w h 9:9i. i :K.. r ■ I 9?:E. L E 9??!. I ..2..• Phil WI 1 IFigure 11: Flow profile at surface conditions I I 17 I I BP Alaska HALLIBURTON 0 Production Array Log Analysis 3.2 SHUT-IN SURVEY Processing of the shut-in data revealed no apparent crossflow, and reflected only apparent ' downflow because of water fallback and the reservoir taking on fluid with wellhead backpressure. Raw data showed no statistically significant variation in any measured property, and the well fluid density was near 1.00 g/cc throughout the logged interval, indicating a nearly- ' pure water column with some small quantity of oil throughout. Plato picked up a tiny quantity of oil near the perforations,but this is merely an artifact of processing the shut-in survey in three- phase mode as was done for the flowing analysis. 1 1 1 I i 1 1 i 1 L 1 1 1 18 1 I IBP Alaska HALLIBURTON 0 Production Array Log Analysis 1 I Raw Data - The figure below summarizes the input data recorded at the well site. I - Each pass is shown with a fixed predefined color. Cepth ;R PPRE —EMP LSPC L—EN CENR DENS CAP YG CFB ILS ft ... -12rps 10 -6. rps 6. 111 _ I I I I I — I YI I j'�' t : 1 I I �I 41CL' _ _ I I � � f I I ,.,;) �t��'�j — — I• I M— li ,— — I _ � I rI o — Ili I t 1__i II ��';CSC Ia, ii s!I _ l IIIa 1-0 I i I I 1 i4Ir �. 1 r4 I t I — I ,i :....'.-r I 1; F I 1li _ _ ii ‘ fr I/e __ 1 ils ,1r I IE. . i ) I I — —1.i) 101 ', 1 ? 4f:4 li. , 1 t 1,. ,',11;' ' fl- ' 1 ? , , — — I ' it /p r , — — I I • I � Iti • 4.4 ;ti, of :'40) Figure 12: Input data from the conventional production logging sensors I 19 I I IBP Alaska 0 HALLIBURTON Production Array Log Analysis I opr ATR ti L AS9044t+Ka ASp^'O2+Ka ASpi'aO3.4Ca ASp'. I Ca ASconeSSNCa A9p•^dOe a ASpimw07JGor Asp wot4lc« 1 APS APs APS R h'11200 00 0 300-0 e•7 e t t-0 e{ 7 4 7.10 t 3.0 3! Fie 00 J 921., i ._ — 1 ' 1 9=0. ' c, I\ , I c ,,, ', t, i, 939:'. { + l r 1 I� 1 53 . �, .• r Ir • r .. ( ( ) • ', i Kr. i . .1 '''', i '' ' ) , L LLL : } rl ( i \ i ? i ( l /, 111 �� i '\ I j l i •::: ' r. 1 • ' c • . Fx. _ 1'l ? 1 j : t 1 r a { I 1 \ Figure 13: Spinner input data. I I 1 20 I BP Alaska 0 HALLIBURTON Production Array Log Analysis ' D.? AAT9 oM.ap MT3I440 MT09HCa MT004 Ca BAT0141Cat NCa MT11•C tot onm anm anm ahm anm 970000 q 300 377 170.775 4431t 317 b M5 155 370RA108 .k anm.SN ce 433 N350 0700 e Y {r. 9710• .-: ; x. I 9770• -` 9730. I � � i i , 9710• r�� �r ? I 'a I 97".0. i .. ,91 ', ff , 1k• I 9750• a ` I 975. 5 . a :a 5:80. I 94' . > 5790• ¢ `a. r 4 9300• 5: $ `,r k *r. f t., 9310I : ( 46 o 9320 of-di ,W' l •j 4tP 4e• 1, IPy r ,- 9330• '! �' t{ i�. 1 ?` w 931. - ,..., � d 1 1 , s, i,, 03!7. ,,1) :� ` �- f 1 9300• } ' Z4 9770. 11 ' .� 4 I k P a a 9390. e ,, 900 I i elm• 7 i t , t`.. tip elm. 1 1. s 1 cj 9130• 1 7. > 11', l �. G` Figure 14: Input data from the Resistance Array Tool (RAT) I ' 1 1 21 A I BP Alaska 0 I HALLIBURTON Production Array Log Analysis 1 Pre-Processing 0.0 UN*, renown Pnwo 0 MEW a1 MA Mj n 0,F Dow OdaI 12543 004514.35 00 CAW( 7.13,M 223 3230 3218 9912 .9981 27312 27310 0 32000 BIn07 PO Boy B9 B B 1.t7 7.t7 109 223 3230 32e8 8912 .999 272G 2739*0 3m00 Apo B f$FRP hAFRP 1041410411,Inc B cc B tee 0 M3boFRO RP B ki It B 1.87 0.13 0 08BBM 0 1 0 01 0 100 0 32000 I OCWiprin B MID: 8�Dim PMDi OGdhICuOFA�+t 1.87 713 1 .24 .12 720 210 D7*1EAP OPwAIEAP 'FA 0/P►n+ 0 01 01 0 i - Winn 'F B 08 223 8200 ...... .a..� ase 1 T haug . ♦ I 9220 I 9710. ,�1\ - -411w.c ..std II, �.P r..._ � `1 . I 44'-30. 9283. • •--.— .o.— _ -. WNW 9300. 4' 'R►..�..,+.x• •_ 4 7 I9320. ,.�- • \ .. a Jr.. 937. t+ ........n--,-......„,,,_ , . 5Y0. f)r i- 111W. - s c' 5380. .,.1G ,��.i. - ..- . -� "-�� go _ Y c K \ . • 900. i .... .._ - 11 , si. IL 9120• _ I ,r,. .Z . i , Figure 15: All the passes have been used in the interpretation I I 1 22 I IBP Alaska HALLIBURTON 0 Production Array Log Analysis I Calibration of Spinner Data Shown on the image below from left to right: I Track 1: Track 2: Incoherence between the theoretical and measured Array Tool responses. 'Unwrapped'rotation curve for each pass. Track 3: Normalized layered velocity profile. This profile is optimized by comparing the I measured and theoretical SAT response for each pass of each spinner. Tracks 4,5: Vapparent as calculated from ILS and CFB. Recall ILS was substituted for CFB. Tracks 6-11: Measured and theoretical SAT responses for each spinner. I Track 12: Measured and theoretical responses for the substituted inline spinner. Track 13: Measured and theoretical responses for the inline spinner. I Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity profile. zz, C0 V.01 41.81 ATR07GO7 C0/ VPre81RI CProII1Nm0F RP.94 VpA V11. 987V.79140 A9:m.4240 Fir 997.11.4147 A,994.5.1.900'&111 AS71n1x06F0 997111.4740 957 101.0 1w1 SAT FFM 017'114 ❑FP71 ®CAPNAT [J RMVIMT Q RM FPtl RP8 ❑RPB ❑ flP9 ❑ RP8 ❑RP8 ❑R►9 ❑ 9200.00 CAT 30 00 90 !70 17 �! 003 I 0 1 A •tA•1.1 71 fi 9-0 0 -0 !fi 4 !4 t t 1 91 9919 00 RAT A 01:11 - 5, 4 ASNnny0'.T1 AS:nw0YT1 At7.n1.43T1 A97.n1.41.h A n1.46T1 M.n1M6TI 997.11707 T1 990 Tr I "'I A7P7YO7roT1.7 �9R9�}R!��RI9��TR,!�,� RPi ❑RPS ❑RPS ❑RPS Cs ❑0.P9 ❑RP$ ❑it ❑ 0 !9000 VPIM!a op en n)Y7M OP. 0 9:00 y"' 7. 17 " ' 1 ; i 9:1^. ; 1 j N.D. ! {i � ,' t l 1 I I 1 i I1. 1 9:90. � (. i•� 1 ( i101. E `, � I , 1 9I,. ! I1 ! I f �I 97:0. ' 1 I 9090. ; j I l' q i I 1 1 9794. o 1 [ I + 7.A f 7 i 9750. *-Y I I I' t Iii' I I �. 9.00. I I I 1 ; 1 \l, 1 7 I � f } I I i 1 1 1 59.0..II) 1 1k 1 al �, �' Figure 16: Velocity profile from SAT data. The fourth up pass was excluded from the analysis. 1 1 23 I IBP Alaska 0 HALLIBURTON Production Array Log Analysis I ,�r AlpIMINNI RIbS1'titeel 1vetlAepNMA7(FPSlI)(4Y•100,164 AIpInMAt;OIRPelYM-0,QI UMep440/wn04RM1}3(gdW°.1337I ASpUwO4Fh MPS)Y44,6) �VdoA3F1r•v04 FFA..... ° Vp4pAep,nnY0lI4PU Xp•100,1701 epinMAwn04IPP/1 Y41-0,01 !0 7 00 40 � 41 FIFA ° 3e �° ° 24 _ 2X s 2 2 O. a -0 2 •t 2 1 a! 24 0 .3, 4 4e .1 •4 6 {i I 1 ?J d0 •,00 •30 0 !0 100 IN 100 40 0 nA 100 131 ] vo4WSo, 2l;FPM, V9°AIpIn11Y04;TPM Al11nMi02•811;R14e3 Y4444 1V046Ae0‘4s02;F U XK•120.te0! A3448Flt 1RPS)1.4,e) JVp10Ae001940;FM X4'-100.130! .4 40 00 I u H -0 3e H .1 24 24 -I 12 12 nl 40 ° m oo eo vocAaprwot,FPM; -0 -0 ASpinM,01.FIl RPS l.;-3230 IVUDASFInn 40l(01111)241-100,160) .12 •12 36 72 Q4 •2A 2t •7e .36 24 .46 u 20 -0.0 -00 .120 42 .40 0 40 10 120 100 .100 a 1 E1 100 1: 1.0 Vot4Soirn4A2;FP1.11 VaeA34E 4641FP/1. I12 I AIOIm4A3Fh;NP1)'.,?' II .0 0Asp4 3,FPMIX-100.106 M.0 Aso 0.h;RP4.r.:-0!', 1 VOWSpw.0l,1141.1,4-.100 .t00. 0.0 00 41 41 .4 3.0 30 1 0 14 24 4 12 2 -0 .0 .12 1 .1.0 4 0 .12 d2 14 .24 ' • d4 -0e 30 •3.1 .4.1 •4.1 42 -0o -0o • 100 ?0 ] V '10 t30 •100 -00 0 30 10015p 100 409 30 101 X30 �tASF 4'J3:c., VahA401mP031FPMi Vp48A4p,nn4400IFP1Ai Figure 17: Calibration crossplots of spinner data.Note the very consistent slopes. 1 1 I I 1 24 I I BP Alaska 0 I HALLIBURTON Production Array Log Analysis ' Holdup and Velocity Profile: Shown on the image below from left to right: I Track 1: Track 2: Incoherence Profile for Holdup and Velocity evaluation Layered velocity profile Track 3: Layered holdup varying with depth I Track 4: Track 5: Flow Rate profile expressed with holdup TVD Track 6: Layered Resistivity Profile I Tracks 7-12: Calibrated RAT responses feeding holdup profile Track 15: Density profile(radioactive) feeding holdup profile Tracks 16-18: Apparent velocities and resulting QAT profile calculated from CFB and ILS. I Coo pm Cht.Vap51 0%9494 00W4 7 51.400.587 TV. 55197Nm4. 7,61„7,,01009 5870159 NATp6F11 5870719 78T094h :::,,7,11.111 750413.41. V9079.Wnp `444,1i.Wgp QAT To M, id 6A7 FMl rig BFPO h RAF,;r.0T 0.9m 0 09rn 0 ahm 0 enm 0 ❑p¢ FPM ❑ ❑9FP0 9200 00 CAT 42 25 0 t 100 90 9'70 0990 3 1 .406 434.417 .409.411 455 431 .581 .401 .436,362 420 2 12.42 .7.2 3 0.1.100 20 ..39.30 n.58T s.. A'0 Waw t :VI 119930*470179.. 7810619.. :7,07.77.. MT0111ha 58711.99. 0rove,. V90F6 7 W1. 0 13000 4700 le 000' GI PI 0 1.0000 091, ❑ 411 ❑.991 ❑ ❑05m ❑anm p 7. a rP. a FP31 9 Cin Or 400 094.917 .400 411 99 029 951 .400 030.913 420 2 1.3•2 .7 4.9 O1 *4t01d0 *4703.00, 7875604 58707.* *4t06* *4711+w 159379/0 Thu V..111 Theo V.FILThn I ..m B.. El... B 016 B..m Bo. By= a"V 9 FP. a .000 .434 417 ,400 411 490.029 001 400 491.362 424 2 12.42 .7.23 6.1 787011, *41034. x7661, 58T07i, 7870►.. 78771 I, awe a7a7. 9071 a09m Bo.m g 10 421 491 001 431 302 .4244 9333 - ". � 1 .. f 1 r 1 f ffA' I 93:0 , 12.0 jl1 r I { }if ( 1210 I 1 9:10 9323 j �+ 1 T 1 ..i (i ' 9120 ':I I 1 I ,1 . •. t , 9:99 1 'i) kt� 9791 41'I i1 i (1 / X e.lJ 1; i II J I Figure 18: Holdup and velocity profile and calibrated RAT responses used for profile. I I 25 I I I HALLIBURTON 0 BP Alaska Production Array Log Analysis I 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 I data. In this figure the data is represented by the blue curves, while the calculated tool values are I shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. I 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 I the flow regimes are shown. Within the transition zones several regimes can exist intermittently. 0.001 1,99V40 114141.9.TVD ontt. V.o-w"!o R000LIO.Qrap CP.100M'np GT4wgrwM.OAT-0II.Wray VAT.wl4rvw.p YAY-0II-Wrap QAT-TM-5..o 9.91m. 1.x UNITY UNITY R B 6TPC GP61 0 000 ❑wa-0. ❑IPC �]$PT 0 uwTY p waTV ❑r4o 0 9200•00 0 3700 0 1 977)90-7 0-9 4 2 1 2+2 41.100 20-4 3 4 $99. 1 0 040.11000].000!6 0 943300 1 0 RI 4 VMS 4.0 ..95.01.10 0RNO1 OAT-0nar -DAT-011 VAT-Wow YAT-02 OAT-Tot $40 I -- 001 al 9P.I 9 2222 B da-. B$000 B I.PO B uwrY B UwTY B 71.'0.2.....9 1234 B Ptw Peek -On .! 2 1 2.4t 4 9.100 20.4 3 A.106 1 0 .046 190001$0009-9 31 MIR Pao V.p.T5.o Rn0p1410•TMo 0PM00•TM0 6117-.11911.75.0 301-011.05.0 VAT.W0MTMO YAl.04.1 0 001.709.75.0 W Mn ew 2P2 1 B o..: B u.m B Icv0 B$000 9 uwr, 9 uwrY B m3) B O..r -! ♦ 2 12 r2 .!9.100 20 r) 1.6 0 040.15.007..1000 1401 C15r �CT8 9200 4, 4 , t -•1. r:f''.+ i ! 'ti°•Yie, 9220 •:�y iiiig 4 4 •.0.•:, 9240 C° ' ' eo oYi I o dJ 9160 ► It �:'°° r :f.F.e :,.,.... ...: , 1 3090III" t 4 •.°�1 1300 1 �� l • . d: I ,.,:qtr .320 0 1 °f ' 9340 4 . }o'.' I r —_ Tl y.. :1 9360 -�Pa Y`.' 8390 ,f:K 9100 °•'°"ilV 11420 "°�r / ' I I : ° 111 Figure 19: Flow profile at reservoir conditions along with layered holdups, apparent velocities, and holdup calculation tracks. I 1 26 I 0 I HALLIBURTON BP Alaska Production Array Log Analysis I The production rates at surface conditions are presented in the figure below: Ceps TJ: FI: ,t* :21s 23UI Wry CpOn CpCil 4141•1 CrE.4n ,ate-Cil ;.mavvaa I het h 6 BFPCBPC .BPC I MCMC r9PC ea MCt boF9A sbI ft 910000 87 999'77•09' 0.08 7 OOt3 0.0329 0-09 0•t2 0•3 3934. 9'1'00 PE= ,‘,.1.1FSI Cil Pali II 311 II Fn. Sm 3avt Taw :gin :TSI i 5200 I i ill ::-J• 1 1 l 11 1 111111 MEM 1 9247. 9277. 1 IFigure 20: Flow profile at surface conditions I 1 27 I I IBP Alaska HALLIBURTON 0 Production Array Log Analysis I 4.1 RAW DATA INCLUDING STATIONS-FLOWING SURVEY Because PLATO cannot handle stationary logs in the current release, it is necessary to plot I stationary surveys in KAPPA's Emeraude software. The following plots the station surveys along with passes for the flowing survey. r� Log Emeraude ICompany BP EXPLORATION ALASKA INC Test Field PRUDHOE BAY Date Wed Nov 26 23-24-10 2014 Well 14-43 Survey FLOWING IGR CCL ept Z CFB ILS DEtS PPRE LSPD L''EN OHR DEUR CAP CAL 'YG , 1 - 1 �• j 1= y- - 8' I � I :I I I I I O +b Ito+ O —fa 1 \ _ . i 10t 1 1 I _ h I I I i .4 ' I i I; _ _I I I I I .' I I - - i • c I I. I^ I + I I ' I0 ii�t I-(. I '' II I I I 1 - - i'_5 II I ! t }. I I I : . '�^ I !! I I II. ' I • I e I I I: I it i i 1 I - -- - ,� 1!� I II, , 1 .4, . a - - s r3 - I I sot io I _ _ 1I IF. ..: , i I - - 1 r `12 1 I I r , 4C 1. I . - . I 1 Figure 21: Data from conventional PLT along with stations. Temperature is labeled"OTHR." 1 28 I I BP Alaska HALLIBURTON 0 Production Array Log Analysis I ripip Log E meraude Company BP EXPLORATION ALASKA INC Test I .J Field PRUDHOE BAY Well 14-43 Date Wed Nov 26 23-24-10 2014 Survey FLOWING ept 2 SPIPi1 SPIN2 SPIN3 SPIP14 SPIRE SPINE LSPG CFO LS SATROT 'n -10 rps 50 -10 rps 50 -10 rps 50 -10 rps 45 -10 rps 50 -10 rps 5C -12 rps 18 -6. rps 24 0 ' 360 I 1 1 i I i I ,I I , I, I 11 }I I I 1, I I I I I . 1H10 i1. t1 a , I is I 1 I car I I X31/ G 4 10 I `` I I I # I I I , I 11 I 4ill , i I I ' I I r I I ; I 1r 14 I , i € �` ` I 1 •1 I I I I I � I I e \( I rl f I `r 1 ,,, I I i I I Ij I ! A i f t ,. I I ! l i I i I I I I / t I I I / I 16 11 I ;a I I �' I I - I 4 ! I III I1 ' \ I ,r IIII I' 2CC I a I k(� tII 1 J ' 1 I i''' I . I If.:rI ; f I I .14411 i I i 1 1 II I 140 I i J 1 ') '` . A ' i + I r I I S` ` � t I I 1 I f I •.) I I '- I :t' i ir7 i el is i t i ' i i i f t I !-.1! III; !I I II! f' 11 l 1)16" I.y I I I�I rrS -Ir Je 1 151) Ii ! I +': 'r' I ,• d1YYY, 'f' _ ' ., j17), i fl. I 1;11 l fAP I I i i i i i , Figure 22: Data from SAT spinner array along with stations. I I 29 I IBP Alaska HALLIBURTON 0 Production Array Log Analysis Ir .„, Log Emeraude Company BP EXPLORATION ALASKA INC Test IL Field PRUDHOE BAY Date Wed Nov 26 23-24-10 2014 Well 14-43 Survey FLOWING epi RATMN01 RATMNO3 RATI.INOE RAT61t407 RATI.INO9 RATMN11 RATROT 'n 0 1 0 1 0 1 0 1 0 1 0 1 0 360 . . iF. ti ; ; t- is 4,6 0/ ti t.. .� ,' - - k 4 1 , I - - ; �Cr i 111r / I F I tr. = t Si , A: I . ' 1:11114 , , . I i itt Leil\ ,,,, ' I �e IFigure 23: Data from RAT resistivity array along with stations. I 30 I I I BP Alaska HALLIBURTON 0 Production Array Log Analysis I4.2 RAW DATA INCLUDING STATIONS-SHUT-IN SURVEY Fr. Log Emeraude Company BP EXPLORATION ALASKA INC Test Field PRUDHOE BAY Date Wed Nov 26 23-24-10 2014 Well 14-43 Survey SHUTIN GR CCL ept CFB ILS DENS TEMP PPRE LSPD LTEN DENR CAP CAL G Z ' R &.rps 8 2 m 8 / — T -T•- — -�. ---t----, - I I I I } I I I) i))sl I f r 1 . I ' I� I I .^ ' I I _ _ ,I1 +ti I i s . i` I ( t _n i I' II S� I i f ti I zc� 1 i 1 I I i i i it• I `�. I _ _ a • ' I I yl I I ' i tN I ! i - - iI ,. i I� _ i i 1 :" ( �= til I } { II i i- yi 1. I { I 2p( t I I Ar 1, • i tf. 1 i i • if I I i I } f I • I i i` f ' I I ;I. I I i • I I ' ' - - - 1 I I . HCl }.� I ) 1 I Figure 24: Data from conventional PLT along with stations. I 31 I 0 I HALLIBURTON BP Alaska Production Array Log Analysis I r Log E meraude Company BP EXPLORATION ALASKA INC Test I L _A Field PRUDHOE BAY Well 14-43 Date Wed Nov 26 23-24-10 2014 Survey SHUTIN ePtZ SPIN1 SPIN2 SPIN SPIN4 SPINS SPINE LSPO CFB ILS SATRO' '1<• -8 rps 8 -8 rps 8 -8 rps 14 .8 rps 8 -8 rps 10 -8 rps 8 ... -12 rps 10 -6. rps 6. 0 ' MC T- ., � ` i tll} ,. I I I �I 1 - - lid i ;l I� 1 1 Vii. �i7 I 'c< ;-I j�. ;I,) rI e,[ ' sl( X14 J I .?11I1 I I ' I I I', I 11 11( II ;I Itis I I I h li ',i,!".1 �IS I ', I I I Ij l i 01 ' 11) li f : 1. I) i I' 1 'r' I ; I I • , I'` ! #I 1 ' • 1 1: I .I JI *4' ( ' 1 I 1 } ;I} i 1 I i� fiii• i S' it , ` `ii sl {1r I: f,• It il,I -- - 1{ I{ 112 ii( yF� I I I I� 1 I i � II 11::1 I 'II 'I' I , i ' �1i Ij•li . j,c I I 111 Iil r - 1 • 1 111. jl `I�'`�} 1 I 'cc f } t.l1, l I �I • `I1Irf I 1 I } + r� r+ il11 lll; 1I yl} 1). I I }IIS I — }I , `j� (II I1 Cwl sr I , I l� I I 1 1 I. i �� ?. iS i. I I , ,I,_ I I I I 1 I 11 - - 1111 I Ii If 1 t I' I I ?I I I i ` 1`y .).:i )1 I� li t.ii; &r'I� It ,I! ii ll I Ii I 1 I1 . l j.i ., is , t et 1 IIli I\ 11 t. ilk. I `� 'I� II I I 40t r. �.� r j. rl i f it •1� $1 ;1,) IFigure 25: Data from SAT array spinners along with stations. I 32 I BP Alaska 0 I HALLIBURTON Production Array Log Analysis 1 rill; Log E meraude I L. Company BP EXPLORATION ALASKA INC Test Field PRUDHOE BAY Date Wed Nov 26 23-24-10 2014 Well 14-43 Survey SHUTIN I ept RA'I.N01 RATGINO3 RATMN05 RATMNO7 RATMN09RATMN11 RATROT 'ft, 0.373 0.4841 0.381 0.8079 0.3875 0 5708 0.2875 0.8833 0.3625 0.487E 0.3 0.5292 0 360 a Ict I . , { I = I ': , : /1 I , � I - _ . to 1 I X ti ' ____-,i S5 4yt j, 1 r• 4t : I s . 1. 1; 1. t Ills t- tfl I .. _ , L . ,.. , ,.. I _ .. s, a. 1 . . 1, , t, , _ ,, ,,, i .4c a I -i I I. I s t 1 1 Figure 26: Data from RAT array resistivity probes along with stations. I 33 I \92- kog 2 "tc) WELL LOG TRANSMITTAL DATA LOGGED 2 � i2o1 M ,K.END To: Alaska Oil and Gas Conservation Comm. February 3, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED RE: Production Profile: 14-43 F E Fs 0 015 Run Date: 11/26/2014 AO C The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 14-43 Digital Log file, Interpretation Report 1 CD Rom 50-029-22296-00 Production Profile (Final Field Print) SCOWFE 1 2V5 1 Color Log 50-029-22296-00 Production Profile Report (Interpretation Report) 1 Report 50-029-22296-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: S fined: (44/""1"Li 01/20/11 Schlumberger NO. 5676 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 4 Log Description Date BL Color CD 14-43 NGI -14 BGZ7 -00010 CROSSFLOW CHECK / AV1H-00052 USIT t)Z i' t � )'i 12123110 „b�l 'J. Q 1 1 L -205 BL - 00073 MEM LDL 0 $ .- 12/21110 1 A-42A BL65 -00012 MEM PRODUCTION PROFILE Q f — / a (� 01/06/11 1 n 1 01 -30 BCZ2-00031 INJECTION PROFILE Z 3 (p -)) 1 12/03/10 1 , U t 1 02 -20 BBSK -00040 RST / ' - —() Q 11/19110 1 , y , 1 07 -23B AY1M -00056 RST a .- J !I 11/28/10 1 ; A - #' 1 el BD88 -00073 MCNL + r� � 11/03/10 1 a 1 04 -24 AY1M -00058 RST J ,Tj () _ 12/05/10 1 ji' a 1 11 -12 BCZ2 -00033 RST J �} 6— 12/07110 1 p7, 1 • 2- 28B/0.19 BCRJ -00055 RST • --(C( 12/01/10 1 Q 3 i S-128 BCZ2 -00035 USIT — / TCI 01/02/11 /1(,410 1 1 W -220 BG4H -00025 USIT O — )� 12/27/10 •61 y 1 1 S-41A 10AKA0108 OH MWD WD EDIT V — U 1 10/15/10 2 a 1 S -41ALI 10AKA0108 OH MWD /LWD EDIT L) . —J(9, 10/15/10 2 1 H -11 BGZ7 -00014 RST / 'Zf) — r 12/18/10 1 AO 1 ---32gfq a h (n ts'� PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2 -1 k 2525 Gambell Street, Suite 400 900 E. Benson Blvd. %1', '1 �� Anchorage, AK 99503 -2838 i 'K a.�,.tL 0 . e:5--"-- lw,,,,,..,4, 4 . i 1 „., , , tc „,,,, , : ; ,,,,,7 . . i . , .;.,,, .z.;.r ,„ii : ., :,,,, ,7,, , : „ g ar, ,d! 19 STATE OF ALASKA ALASAIL AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other 0 SET IBP Performed: Alter Casing ❑ Pull Tubing El Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate Q Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑r Exploratory ❑ 6 w 192 -1080 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 4 50- 029 - 22296 -00 -00 8. Property Designation (Lease Number) : 4� 9. Well Name and Number: ADLO- 028312 v PBU 14-43 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9700 feet Plugs (measured) 9438,9433(TO ),9313 feet true vertical 9231. feet Junk (measured) None feet Effective Depth measured 9430 feet Packer (measured) 8872 feet true vertical 8984 feet (true vertical) 8484 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" SURFACE - 110 SURFACE - 110 Surface 3119' 10 -3/4" 45.5# NT -80 SURFACE - 3193 SURFACE - 3193 5210 2480 Intermediate Production 9020' 7 -5/8" 29.7# NT -95 SURFACE - 9094 SURFACE - 8680 8180 5120 Liner 782' 5 -1/2" 17# 13CR80 SURFACE - 9700 SURFACE - 9231 7740 6280 Liner Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6 _ 13CR80 SURFACE - 8934 SURFACE - 8538 Packers and SSSV (type, measured and true vertical depth) 7 -5/8" X 4 -1/2" BAKER SABL -3 PKR 8872 8484 12. Stimulation or cement squeeze summary: # t k Intervals treated (measured): 03w COrt . C ti " Si0R1 Treatment descriptions including volumes used and final pressure: Anchorage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory[] Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas WDSPL Lj GSTOR ❑ WINJ ❑ WAG[] GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed N me J Last ca Title Data Manager Signat re Phone 564 -4091 Date 11/15/2010 I � RIBDMS NOV 16 1010 < en Form 10-404 Revised 10/2010 6 47- le. Submit Original Only / / O af r '( /7/%a 14-43 192 -108 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth ToF Tvd Depth Bas 14-43 11/14/92 PER 9,321. 9,339. 8,884.85 8,901.21 14-43 12/1/93 APF 9,290. 9,308. 8,856.73 8,873.05 14-43 1/12/99 APF 9,464. 9,468. 9,015.2 9,018.86 14-43 1/12/99 APF 9,496. 9,500. 9,044.49 9,048.16 14-43 2/11/99 SQZ 9,290. 9,500. 8,856.73 9,048.16 14-43 3/4/99 RPF 9,472. 9,487. 9,022.52 9,036.25 14-43 7/16/01 BPS 9,438. 9,500. 8,991.44 9,048.16 14-43 8/15/01 APF 9,342. 9,346. 8,903.94 8,907.57 14-43 8/15/01 RPF 9,296. 9,308. 8,862.17 8,873.05 14-43 8/15/01 RPF 9,321. 9,338. 8,884.85 8,900.3 14-43 11/13/10 APF 9,270. 9,290. 8,838.62 8,856.73 • 14-43 11/14/10 BPS 9,313. 9,314. 8,877.59 8,878.5 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 14 -43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/13/2010 ** *WELL SHUT IN ON ARRIVAL * * *(E -LINE PERF, XFLOW CHECK) � INITIAL T /I /O= 1900/1950/0 PSI INITIAL VALVE POSITIONS: WV, SV = CLOSED, MV, SSV = OPEN, IA/OA = OTG PERFORATED 9270'- 9290" WITH 3 -3/8" HSD PJ, 6 SPF, 60 DEG PHASE GUN CHECKED FOR CROSSFLOW AT IBP SETTING DEPTH AND FOUND NO CROSS' FLOW FINAL T /I /O= 1900/1950/0 PSI FINAL VALVE POSITIONS:WV, SV, SSV = CLOSED, MV = OPEN, IA/OA = OTG "" *JOB IN PROGRESS * ** (SHUT DOWN FOR NIGHT, WILL RESUME JOB IN THE ? MORNING) ___... _ _ __ ___ i 11/14/20101 ***WELL SHUT IN ON ARRIVAL, JOB CONTINUED FROM PREVIOUS DAY * * *(E - LINE, SET IBP) INITIAL T /I /O= 1900/1950/0 PSI INITIAL VALVE POSITIONS: WV, SV = CLOSED, MV, SSV = OPEN, IA/OA = OTG .SET BAKER RETRIEVABL BRIDGE PLUG AT 9313', 9 840# DOWN TO j I EQUALIZE, 5520# UP TO RELEASE, IBP SHEAR PIN DID NOT RELEASE, PULLED FREE AT BAKER 900# EMERGENCY RELEASE, FISHING NECK IS 1.375 CONFIRMED BAKER FISHING NECK AT 9304' BY CORRELATING UPHOLE, THEN GENTLY TAGGING [ AND LOGGING OFF OF IBP. IFNNAL T /I /O= 1900/1950/0 PSI DSO NOTIFIED OF FINAL VALVE POSITIONS:WV, SV, SSV = CLOSED, MV = E OPEN, IA/OA = OTG ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 2 METH 2 DIESEL 4 TOTAL TREE = FMC NEW STD SLIM HOLE SAFETY NOTES: WELLHEAD= M cEVOY 14 -43 ACTUATOR = KB. ELEV = 74' BF. ELEV = _? KOP _ 5363' Max Angle = 32 @6348' 2161' 4 -1/2" CAM BAL -0 SVLN NIP, ID = 3.813" Datum MD = 9309' Datum TVD 8800'SS GAS LIFT MANDRELS 10 -3/4" CSG, 45.5 #, NT -80, ID = 9.953" L ST MD TVD I DEV TYPEI VLV LATCH I PORT DATE 1 3564 3564 1 WBX DOME BK 16 07/02/09 2 5872 5850 22 WBX DOME BK 16 07/02/09 3 7047 6873 29 WBX DOME BK 16 07/02/09 7714 7462 27 WBX DMY BK 0 Minimum ID = 3.725" @ 8922' 5 8044 7757 27 WBX DOME BK 16 07/02/09 4 -112" OTIS XN NIPPLE 6 8413 8082 29 WBX DMY BK 0 7 8783 8405 28 WBX SO BK 26 12/19/09 8812' 4 -1/2" PARKER SWS NIP, ID = 3.813" 8872' 7 -518" X4-1/2" BAKER SABL -3 PKR, ID = 3.992" 8904' 4 -1/2" PARKER SWS NIP, ID = 3.813" TOP OF 5 -1/2" LNR 8918' 8922' 4 -1/2" OTIS XN NIP NO GO, ID = 3.725" 4 -1/2" TBG, 12.6 #, 13 -C R, .0152 bpf, ID = 3.958" 8934' 8934' 4 -1/2" TUBING TAIL, ID = 3.958" 8928' ELMD TT LOGG 11 / 11 /92 7 -5/8" CSG, 29.7 #, NT -95, ID = 6.875" 9094' PERFORATION SUMMARY REF LOG: BHCS ON 11/3/92 ANGLE AT TOP PERF: 25 @ 9290' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 9290-9296 S 02/15/99 3 -3/8" 4 9296-9308 0 08/15/01 3 -3/8" 4 9321- 9338 0 08/15/01 3 -3/8" 4 9338-9339 S 02/15/99 3 -3/8" 4 9342-9346 O 08/15/01 9433' CEMENT CAP SET 08/10/01 2 -7/8" 6 9464-9468 S 02/15/99 2 -7/8" 6 9472-9487 C 07/16/01 IBP SET 07/16!01 2 -7/8" 6 9496-9500 S 02/15/99 9438' PBTD 9619' 5 -1/2" LNR, 17 #, 13 -CR, .0232 bpf, ID = 4.892" 9700' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/15/92 ORIGINAL COM PLEtION 07/15/09 DMS /SV GLV C/O (07/02/09) WELL: 14 -43 07/16/01 IBP SET AT 9438' MD 12/20/09 SEW /SV GLV C/O (12119/09) PERMIT No: '1921080 08/10/01 CEMENT CAP SET AT 9433' API No: 50- 029 - 22296 -00 09/04/01 RN/TP CORRECTIONS SEC 9, T1 ON, R1 4E, 2886.35' FEL & 4281.32' FNL 10/16/03 BHC/TLP 1 PERF CORRECTIONS 04/21/07 JLJ/TLH I GLV C/O BP Exploration (Alaska) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 • bP L7EC ~ ~ ~0~9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, ~. ~ ~ e, a -;,~i~~s .~.. _- -: ~ ~~;- /©~ ~ ~- c.~-3 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 Date: 12/05/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 14-01A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-05A 1920010 500292032701 Sealed Conductor NA NA 14-O6A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-08A 2022100 500292033001 Sealed Conductor NA NA 14-O9B 1820340 500292053402 Sealed Conductor NA NA to-10 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conductor NA NA 1a-13 1811010 500292062400 Sealed Conductor NA NA is-14 1811020 500292062500 Sealed Conductor NA NA 14-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-186 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 14-28 ]820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-40A 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 OPERABLE: 14-43 (PTD# 1921 ~) Tubing Integrity Restored • Page 1 of 2 Regg, James B (DOA) . ~~~~~.~ e_~~~. ~ ,~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ LZi Z(j Sent: Monday, December 21, 2009 2:06 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Bommarito, Olivia O; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, FS3 DS Operators Cc: Daniel, Ryan; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 14-43 (PTD# 1921080) Tubing Integrity Restored All, ./ Well 14-43 (PTD #1921080) passed a TIFL after changing out the orifice gas lift valve, proving tubing integrity has been restored. The well has been reclassified as Operable. Please let us know if you have any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Weii Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~~ .~~]~l fit, ~ ~~~ From: NSU, ADW Well Integrity Engineer Sent: Sunday, December 13, 2009 10:30 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; GPB, Area Mgr Central (GCl/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Bommarito, Olivia O; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, FS3 DS Operators Cc: Daniel, Ryan; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 14-43 (PTD# 1921080) Sustained Casing Pressure on IA AI I, Well 14-43 (PTD# 1921080) has been found to have sustained casing pressure on the IA. The well broke MOASP on 12/10/09 with TIO pressures of SSV/2300/20 psi. A TIFL was conducted on 12/11/09 that failed when the IA fluid level rose 739'md during the bleed. The well has been reclassified as Under Evaluation and has been placed under the 28 day clock. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. WOE: POP 3. DHD: Re-TIFL A wellbore schematic and TIO plot have been included for reference. « File: 14-43.pdf» « File: 14-43 TIO Plot 12-13-09.doc» 12/21 /2009 OPERABLE: 14-43 (PTD# 1921 ~) Tubing Integrity Restored • Page 2 of 2 Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 12/21 /2009 UNDER EVALUATION: 14-43 ~D# 1921080) Sustained Casing Press~on IA Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] I~u` Sent: Sunday, December 13, 2009 10:30 AM ~~C' I~ i ~ ~ 7 To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, A'rlea Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Bommarito, Olivia O; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, FS3 DS Operators Cc: Daniel, Ryan; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 14-43 (PTD# 1921080) Sustained Casing Pressure on IA Attachments: 14-43.pdf; 14-43 TIO Plot 12-13-09.doc All, Well 14-43 (PTD# 1921080) has been found to have sustained casin ressure on the IA: -The-.well broke MOASP on 12/10/09 with TIO pressures of SSV/2300/20 psi. A TIFL was conduce on 12/11!09 that failed when the IA fluid level rose 739'md during the bleed. a well has been reclassified as Under Evaluation and has been placed under the 28 day clock. The plan forward for the well is as follows: '~~~~~~, ~~~~ ` ~ ~~~~ 1. DHD: TIFL -FAILED 2. WOE: POP 3. DHD: Re-TIFL A wellbore schematic and TIO plot have been included for reference. «14-43.pdf» «14-43 TIO Plot 12-13-09.doc» /~ Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 c `~oM~(P= 2~`~ ~ Z ~u~ r'C'S iG- t~ 12/14/2009 PBU 14-43 PTD# 1921080 12/13/2009 TIO Pressures 4,000 3,000 ~ 2,000 1 ADO ~- Tbg --f- IA ~ OA OOA ~-- OODA On 09/19/09 09/26/09 10I03N9 1011D/09 10/17/D9 1N24109 1N31/09 11/07/09 11114!03 11121/09 11/28109 12/051D9 12/12/09 TREE = FMC NEW STD SLiM NOLE EAD = McEVOY r1 is r Uta i vY-T = KB. ELEV - 74 BF. ELEV.. __ KOP = _.5363' -Max Angle = 32 @ 6348' Datum MD = - 9309' -- _ Datum TV D = 8800 55 ~ 14-43 10-3i4" CSC, 45.5#, NT-80, ID = 9.953" 3193" ~~~ c ~ZIC`~~i Ildlttllt11Ut7t I®- 3.721° ~ $~2~' 4-1f2°' OTIS XN NIPPLE ~TOPOF 5-1/2" LNR 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 891$' 8934' .~`(° _ ~ ( 7-5/8" CSC, 29.7#, NT-95, ID = 6.875" 9094' PERFORATION SUMMARY REF LOG: BRCS ON 11 /3192 ANGLE AT TOP PERF: 25 @ 9290' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-3/8" 4 9290 - 9296 S 02115/99 3-3(8" 4 9296 - 9308 O 08/15/01 3-3/8" 4 9321 - 9338 O 08/15/01 3-318" 4 9338 - 9339 S 02/15/99 3-318" 4 9342 - 9346 O 08!15/01 2-7/8" 6 9464 - 9468 S 02(15/99 2-7/8" 6 9472 - 9487 C 07(16!01 2-7/8" 6 9496 - 9500 S 02/15!99 PBTD 9619' 5-112" LNR, 17#, 13-CR, .0232 bpf, ID = 4.892" 9700' SAFE?Y FVOTES: 2161' --~ 4-1/2" CAM BAL-O SVLN NIP, ID = 3.813" GA S I JFT MA NDRFI_ S ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3564 3564 1 WBX DOME BK 16 07(02!09 2 5872 5850 22 WBX DOME BK 16 07!02!09 3 7047 6873 29 WBX DOME BK 16 07(02/09 4 7714 7462 27 WBX DMY BK 0 5 8044 7757 27 WBX DOME BK 16 07!02!09 6 8413 8082 29 WBX DMY BK 0 7 8783 8405 28 WBX SO BK 26 07102(09 8812' -~ 4-1/2" PARKER SWS NIP, ID = 3.813" $$72' 7-518" X 4-1 /2" BAKER SABL-3 PKR, ID = 3.992" $g04' 4-112" PARKER 5WS NIP, ID = 3.813" 8922' 4-112" OTIS XN NIP NO GO, ID = 3.725" $934' 4-1I2° TUBING TAIL, ID = 3.958"' $g2g' ELMD TT LOGGED 11/11/92 9433' 9438' DATE REV BY COMMENTS DATE REV BY 11!15!92 ORIGINAL COMPLETION 07/15/09 DMS/SV 07!16101 IBP SET AT 9438' MD 08/10/01 CEMENT CAP SET AT 9433' 09104!01 RN(TP CORRECTIONS 10/16/03 BHC/TLP PERF CORRECTIONS 04121/07 JLJITLH GLV C/O CEMENT CAP SET 08/10/01 ~ IBP SET 07116/01 PRUDHOE BAY UNIT WELL: 14-43 PERMIT No: 1921080 API No: 50-029-22296-00 SEC 9, T10N, R14E, 2886.35' FEL & 4281.32' FNL BP Expiaration (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 _X(ClBP) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 19' FNL, 1277' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 5225' FNL, 2668' FEL, SEC. 4, T10N, R14E, UM At effective depth At total depth 4281' FNL, 2886' FEL, Sec. 4, T10N, R14E, UM 5. Type of Well: Development __X Exploratow__ Stratigraphic__ Service__ (asp's 675161, 5940320) (asp's 673751, 5941145) (asp's 673527, 5941298) 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-43 9. Permit number / approval number 192-108 10. APl number 50-029-22296 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9700 feet Plugs (measured) 9231 feet Effective depth: measured 9430 feet Junk (measured) true vertical 8984 feet Placed IBP @ 9438' on 7/16/2001. Casing Length Size Cemented Measured Depth Conductor 110' 20" 2000# Coldset II 110' Surface 3119' 10-3/4" 1900 cuft CS III & 403 cuft Class G 3193' Production 9020' 7-5/8" 1179 cuft Class G 9094' Liner 782' 5-1/2" 125 Sx Class G 9700' True VerticalDepth 110' 3193' 8680' 9231' Perforation depth: measured 9296' - 9308'; 9321'- 9338'; 9342' - 9346'; (Isolated below ClBP w/cement cap are 9472' - 9487'). true vertical 8862' - 8873'; 8885' - 8900'; 8904' - 8908'; (Isolated below ClBP w/cement cap are 9023' - 9036'). Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR Tbg @ 8934' MD; 5-1/2", 17#, 13CR Tbg @ 9700' MD. Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" BAKER SABL-3 PACKER @ 8872' MD. 4-1/2" CAMCO BAL-O SVLN @ 2161' MD. RECE v -D AUG 2 1 001 Alaska Oil & Gas Cons. Comrnission Anchorage 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 (8/19/2001) OiI-Bbl (shut in) 697 Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 5449 1812 Casing Pressure Tubing Pressure 273 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 hereb,y, certify that the[oregoing is true and correct to the best of my knowledge. -- / - Title: DS 14 Surveillance Engineer Signed / ; Brandon France / Form 10-404 Rev 06/15/88 · ORIGINAL Date Auqust 20, 2001 Prepared by Paul Rauf 564-5799~ ~,,~ SUBMIT IN DUPLICAT 14-43 DESCRIPTION OF WORK COMPLETED SET CIBP & PERFORATING OPERATIONS Date Event Summary 5/13/2001: 7/16/2001: 8/10/2001: 8/15/2001: 8/15/2001: Weft 14-43 has been shut in since 12/30/2000. RIH & tagged PBTD @ 9564' MD. RIH & set a Baker Non-Retrievable IBP @ 9438' (in the 5-1/2" Liner) to isolate the open perforations from: 9472' - 9487' MD (Zone 2) Reference Log: BHCS 11/03/1992. These perforations were used in the past while this well was in MI service. RIH & dump bailed cement ontop of the IBP. Estimated TOC @ - 9430'. MIRU ELU. PT'd equip to 3500 psi. RIH w/perf guns & performed tie-in. Shot 33' of add perforations f/: 9296'- 9308' MD (Zone 4) 9321' - 9338' MD (Zone 4) 9342' - 9346' MD (Zone 4) Used 3-3/8" carriers & all shots @ 4 SPF. POOH w/guns - ASF. RD ELU. Placed 14-43 BOL as a producer. Performed a representative welltest. Page I 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 (Conversion) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 19' FNL, 1277' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 5225' FNL, 2668' FEL, SEC. 4, T10N, R14E, UM At effective depth At total depth 4281' FNL, 2886' FEL, Sec. 4, T10N, R14E, UM 5. Type of Well: Development__X Exploratory__ Stratigraph lc__ Service__ (asp's 675161, 5940320) (asp's 673751,5941145) (asp's 673527,5941298) 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-43 9. Permit number / approval number 192-1o8 / 300-289 (signed November 22, 2000) 10. APl number 50-029-22296 ,- ~ 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 1 10' Surface 31 19' Production 9020' Liner 782' 9700 feet Plugs (measured) 9231 feet 9564 feet Junk (measured) 91 06.5 feet Tagged PBTD @ 9564' on 7/16/2000. Size Cemented Measured Depth 20" 2000# Coldset II 1 1 0' 1900 cuft CS III & 403 cuft Class 10-3/4" G 31 93' 7-5/8" 1179 cuft Class G 9094' 5-1/2" 125 Sx Class G 9700' True vertical Depth 110' 3193' 8680' 9231' Perforation depth: measured true vertical Tubing (size, grade, & measured depth) Packers and SSSV (type & measured depth) 9472' - 9487'. 9023' - 9036'. 4-1/2", 12.6#, 13CR Tbg @ 8934' MD; 5-1/2", 17#, 13CR Tbg @ 9700' MD. 7-5/8" X 4-1/2" BAKER SABL-3 PACKER @ 8872' MD. 4-1/2" CAMCO BAL-O SVLN @ 2161' MD. RECEIVED JAN 0 5 ; 001 Alaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation Subsequent to operation 26 Representative Daily Average Productionorlnjection Data Gas-Mcf Water-Bbl 10000 - 3753 4966 Casing Pressure Tubing Pressure 24OO 269 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~e~rect to the best of my knowledge. Signed/~~,~ Title: DS 14 Surveillance Engineer B ra,G¢5 n France FJ Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 14-43 DESCRIPTION OF WORK COMPLETED CONVERSION (MI INJECTOR TO PRODUCER) Date Event Summary 12/01/2000: 2/23/2000: Blinds swapped f/MI to production. Installed GLV's. 12/29/2000: Placed well BOL. 12/30/2000: Performed a well test. Well is currently shut in due to FS 3 water handling issues. RECEIVED JAN 0 5 2__001 Alaska Oil & Gas Cons, Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ (conversion f/ Inj -> Prod) Other_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 19' FNL, 1277' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 5225' FNL, 2668' FEL, SEC. 4, T10N, R14E, UM At effective depth At total depth 4281' FNL, 2886' FEL, Sec. 4, T10N, R14E, UM 5. Type of Well: Development __ Exploratory __ St ratig raph ic __ Service__X (asp's 675161, 5940320) (asp's 673751, 5941145) (asp's 673527, 5941298) 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-43i 9. Permit number / approval number 192-108 ~ 10. APl number 50-029-22296 ¢ 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 110' Surface 3119' Production 9020' Liner 782' 9700 feet V/ Plugs (measured) Tagged PBTD @ 9564' on 7/16/2000. 9231 feet '~ 9564 feet Junk (measured) 9106.5 feet Size Cemented Measured Depth True vertical Depth 20" 2000# Coldset II 110' 110' 10-3/4" 1900 cuft CS III &403 cuft Class 3193' 3193' G 7-5/8" 1179 cuft Class G 9094' 8680' 5-1/2" 125 Sx Class G 9700' 9231' Perforation depth: measured 9472'- 9487'. i true vertical i i iTubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 9023' - 9036'. 4-1/2", 12.6#, 13CR Tbg @ 8934' MD; 5-1/2", 17#, 13CR Tbg @ 9700' MD. 7-5/8" X 4-1/2" BAKER SABL-3 PACKER @ 8872' MD. 4-1/2" CAMCO BAL-O SVLN @ 2161' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation November 20, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Service __.(WAG)__ Suspended__ 17. I hereby certify that the fore~oing is true and correct to the best of my knowledge. Signed#,/~~ ' "-"-~ Title: DS 14 Surveillance Engineer · Brandon France ~7 Questions? Call Brandon France @ 564-5767. Date Prepared b)/Paul Rauf 564-5799 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- ~ Approved by order of the Commission ORIGINAL SIGNED BY Commissioner ORIGINAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE bp To.' State of Alaska Alaska Oil and Gas Conservation Commission From: Brandon France DS- 14 Surveillance Engineer Subject: 14-43 Conversion to Producer Date: November 14, 2000 BP Exploration Alaska, Inc. proposes to convert well 14-43 from an MI injector back to an active producer. Well 14-43 was converted to an injector as part of the GDWFI (Gravity Drainage Water Flood Interaction) MI project on 3/16/99 (Approval number 398-326). This conversion back to producer status is part of the original scope of the project. The pattern area for this project is not covered in the Prudhoe Bay Miscible Gas Project (PBMGP). This well currently exhibits mechanical integrity as an injector. No facility modifications are required for this conversion. Current plans are to test production from the injection interval and then re-complete the well in the original production interval. THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 P 1~ M A T E E E W T E R IA L U N D ER H IS M A R K ER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate _X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 19' FNL, 1280' FEL, SEC. 9, T10N, R14E, UM At top of productive interval 838' FSL, 2668' FEL, SEC. 4, T10N, R14E, UM At effective depth 4317' FNL, 2843' FEL, SEC. 4, T10N, R14E, UM At total depth 997' FSL, 2891' FEL, SEC. 4, T10N, R14E, UM 5. Type of Well: Development__ Exploratow__ Stratig raph lc_ Service__X 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-43i 9. Permit number / approval number 92-108 / 398-326 10. APl number 50-029-22296 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical 9700 feet Plugs (measured) 9231 feet Tagged PBTD @ 9562' MD (6/28/1999). Effective depth: measured true vertical 9562 feet Junk (measured) 9105 feet Casing Length Conductor 110' Surface 3158' Production 9059' Liner 782' Perforation depth: Size Cemented 20" 2000# Coldset II 10-3/4" 1900 cubic ft CS III & 403 cubic ft Class G 7-5/8" 1179 cubic ft Class G 5-1/2" 125 Sx Class G measured 9472' - 9487' Measured Depth True vertical Depth 110' 110' 3193' 3193' 9094' 9700' 8680' 9231' true vertical 9023' - 9036'. OP, IGI AL A/aska Oil a ~as Cons Tubing (size, grade, and measured depth) 4-1/2", 12.6~, 13 Or Tubing ~ 8934' MD; 5-1/2",17~, 13 Or Tubing ~ 97oo'~hor~ Packers and SSSV (type and measured depth) 7-5/8" x 4-1/2" Baker SABI-3 Packer @ 8872' MD; 4-1/2" Camco BAL-0 SLVN @ 2161' 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 OJI-Bbl Represen~tive Daily Average Production orlniection Data Gas-Mcr Water-Bbl 6305 - 39041 - Casing Pressure Tubing Pre~ure - 3326 3013 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas __ Suspended __ Service MI Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Erin Oba ' Form 10-404 Rev 06/15/88 · Title Arco Engineering Supervisor Date 7" 30- ?~ Prepared by Paul Rauf 263-4990~..~ SUBMIT IN DUPLICATE 14-43i DESCRIPTION OF WORK COMPLETED MUD ACID STIMULATION WITH INFLATABLE PACKER Date Event Summary 5/04/1999' 5/05/1999' 5/09/1999' 6/28/1999: Killed well w/225 bbls of KCL Water. RIH & tagged PBTD @ 9566' MD. A CTU Mud Acid Stimulation using an inflatable treating packer was performed on a MIST well as follows: MIRU CTU. PT'd BOPE. Killed well w/182 bbls of 2% NH4CL down backside. RIH w/CT & inflatable treatment packer. Tagged PBTD @ 9566' MD. Inflated & set the treatment packer in the 5-1/2" Liner @ 9400' MD to isolate the previously squeezed perf intervals above 9400' MD. Pumped treatment fluids to treat the open perforation intervals @: 9472' - 9487' (Zone 2C) Ref Log: BHCS 11/03/1992 Pumped: (a) 47 bbls of 50% Diesel/50% Xylene @ 1.5 bpm, followed by (b) 48 bbls of 12% HCL - 10% Xylene - 3% Acetic Acid @ 1.7 bpm, followed by (c) 25 bbls of 9% HCL - 1% HF - 3% Acetic Acid @ 1.7- 2.1 bpm, followed by (d) 20 bbls of 12% HCL - 10% Xylene - 3% Acetic Acid @ 2.1 bpm, followed by (e) 180 bbls of 2% NH4CL @ 2.1 - 2.25 bpm, followed by (f) shutdown. POOH w/inflatable treatment packer while displacing NH4CL f/CT w/33 bbls of MEOH Water. RD. RIH & tagged PBTD @ 9562' MD. Returned well to MI Injection & gathered representative injection data. " 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 (Conversion to MI) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 74 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 19' SNL, 1280' WEL, SEC. 9, T10N, R14E, UM 14-43 At top of productive interval 9. Permit number / approval number 838' NSL, 2668' WEL, SEC. 4, T10N, R14E, UM 398-326 At effective depth 10. APl number 50-029-22296 At total depth 11. Field / Pool 997' NSL, 2891' WEL, SEC. 4, T10N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 9700 feet Plugs (measured) true vertical 9231 feet Effective depth: measured 9563 feet Junk (measured) true vertical 9106 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 2000# Coldset II 110' 110' Surface 3158' 10-3/4" 1900 cubic ft CS III & 3193' 3193' 403 cubic ft Class G Production 9059' 7-5/8" 1179 cubic ft Class G 9094' 8680' Liner 782' 5-1/2" 125 Sx Class G 9700' 9231' Perforation depth: measured 9472' - 9487' · true vertical 9023' - 9036'. ' · . · Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 Cr Tubing @ 8934' MD; 5-1/2",17#, 13 Or Tubing @ 9700' MD. ' ., Packers and SSSV (type and measured depth) 7-5/8" x 4-1/2" Baker SABI-3 Packer @ 8872' MD; 4-1/2" Camco BAL-0 SLVN @ 2161' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - Subsequent to operation - 12511 3316 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service MI Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~~_~. ~~'~"'rl ~/t,;~ Title Arco Eng in e e ring Su p e rv is or Date Erin Oba , ! . Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATF~~ 14-43 DESCRIPTION OF WORK COMPLETED PRODUCER TO MI CONVERSION (SQUEEZE/PERFORATION) Date Event Summary 1/07/1999: 1/12/1999: 2/11/1999: 2/14/1999: 2/15/1999: 2/22/1999: 2/22/1999: RIH & tagged PBTD @ 9554' MD. Performed MITIA - passed. MIRU ELU. RIH w/perforating guns & shot 8' of Add Perforations @: 9464'- 9468' 9496'- 9500' Used 2-7/8" carriers and all shots were 6 SPF, balanced, 60° phasing, & random orientation. POOH w/guns. ASF. RD. (Perfs shot for upcoming Cement squeeze). A CTU Cement Squeeze for conversion of a Producer well to a MI Injector well was performed as follows: MIRU CTU. PT'd BOPE. Killed well w/hot 1% KCL Water, followed by Crude. RIH w/CT & tagged PBTD @ 9556' MD. Pumped 15 bbls Neat Latex Acid Resistive Cement, followed by 40 bbls LARC w/aggregate, followed by 5 bbls Neat LARC to squeeze off the open perforations intervals located @: 9290' - 9308' (Zone 4) Ref Log: BHCS 11/03/1992 9321' - 9339' (Zone 4) 9464' - 9468' 9496' - 9500' Placed 5 bbls of Cement behind pipe & attained a max sqz press of 3500 psi. Observb"d,'.800..., psi breakback. Contaminated Cement w/Biozan & cleaned out contaminated Cement to 9563' MD. (Lost returns.) POOH w/CT. FP'd well. RD. Injectivity test failed. A CTU Cement Re-squeeze for conversion of a Producer well to a MI Injector well was performed as follows: MIRU CTU. PT'd BOPE. Killed well. RIH w/CT &tagged PBTD @ 9571' MD. Pumped 44 bbls Neat LARC to squeeze off the open perforation intervals listed above. Placed -4 bbls of Cement behind pipe @ a max sqz press of 3000 psi. Contaminated Cement w/Biozan & jetted contaminated Cement to 9563' MD. POOH w/CT. FP'd well. RD. RIH & tagged PBTD @ 9563' MD. PT'd sqz to 1550 psi - passed. MIRU ELU. RIH w/perforating guns & shot 15' of Add Perforations @' 9472'-9487' (Zone2C) Ref Log: BHCS 11/3/92. Used 2-7/8" carriers and all shots were 6 SPF, underbalanced, 60° phasing, & random orientation. POOH w/guns. ASF. RD. Initial MI Injection began on 3/16/99. ./ ARCO Alaska, Inc. Post Office Box i00360 A~chorage; Alasha 99510 0360 '?eiepi~©ne 907 276 !215 December 4, 1998 Mr. David Johnston, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Fax 276-7542 Dear Mr. Johnston: Re: DS14-13 MI Injection: The purpose of this letter to notify you of a change in the injection fluids into 14-13. Injector 14- 13 has been injecting water since January of 1983. Facility modifications are currently underway to allow for this well to inject water or MI. The expansion of MI injection to this pattern is for EOR purposes and as a result the offset producers are expected to recover an additional 2.0 MMBO. Facility work will be completed my mid December of 1998 and the well is expected to begin its' first cycle of MI injection by the end of this year. The last mechanical integrity test was performed on 7/16/95. This well is included in the Prudhoe Bay Miscible Gas Project (PBMGP). If notification other than this letter is necessa.ry or you require anything else from us, please let us know. Please call me at 265-1501 if you have any questions. '~Danielle H. Ohms Senior Drillsite Production Engineer Prudhoe Bay Resource Development cc M. Bill ATO-1530 ARCO Alasha, inc. is a Subsidiary ol Atlantic',~ichfieldd:,,~,::.:,i~v STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend_ Operational shutdown _ Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ Re-enter suspended well _ Time extension _ Stimulate _ ~""4~~ "~ ~[ Varian ce _ Per/orate _ Oth er _X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 19' SNL, 1280' WEL, SEC. 9, T10N, R14E, UM At top of productive interval 838' NSL, 2668' WEL, SEC. 4, T1 ON, R14E, UM At effective depth At total depth 997' NSL, 2891' WEL, SEC. 4, T10N, R14E, UM 5. Type of Well: Development ~X Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-43 9. Permitnumber/approvalnumber 92-108 10. APInumber 50-029-22296 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summer Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 3158' Production 9059' Liner 782' 9700 feet Plugs (measured) PBTD tagged @ 9560' MD (9/24/95) 9231 feet 9560 feet Junk (measured) t i :,J ! '~ 9103 feet Size Cemented Measured Depth True vertical Depth 20" 2000# Coldset II 110' 110' 10-3/4" 19oo cubic ft CS III & 3193' 3193' 403 cubic ft Class G 7-5/8" 1179 cubic ft Class G 9094' 5-1/2" 125 Sx Class G 9700' Perforation depth: measured 9290' - 9308'; 9321' - 9339'. true vertical 8856' - 8874'; 8824' - 8885'; 8901'. Tubing (sizo, grado, and moasuroO Oopth) 4-1/2", 12.8~, 13 Gr Tubing ~ 8~34' MD: 5-1/2",17~, 13 Cr Tubing ~ ~700' MD. 8680' 9231' Packers and SSSV (type and measured depth) 7-5/8" x 4-1/2" Baker SABI-3 Packer @ 8872' MD; 4-1/2" Camco BAL-0 SLVN @ 2161' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation December 14, 1998 16. If proposal was verbally approved Name of approver Date approve¢ 15. Status of well classification as: Oil __X Service Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowled! Signed ~2..,,~ ""~, ~ Title Arco Engineering Supervisor Erin Oba FOR COMMISSION USE ONLY Questions? Carl Danielle Ohms @ 265-1501. Date / 2. ~ L/~ ¢ ~ Prepared b)/ Paul Rauf 263-4990 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission ,,,,o;n~.i Signed By ;~avid W. Johnston Commissioner Form 10-403 Rev 06/15/88 · -6 0o9") Appr°val n°;,~_ 3,~:' SUBMIT IN TRIPLICATE .ARCO Alaska, Inc. Post Office BO.. _ J0360 Anchorage, Alaska 99510-0360 DS 14-43 Conversion of a Producer Well to MI Injection DS14-43 GDWFI MI: Well 14-43 is currently a producer in the Gravity Drainage Water-flood Interaction (GDWFI) area. Because of high GORs this well cycles on and off of production. Plans are to convert this well to MI injection for approximately one year to enhance oil recovery in offset wells in addition to increasing production from 14-43 once converted back to a producer. This project is considered a pilot test of the application of MI injection in the GDWFI area. One of the primary reasons this well was selected is that it was drilled on 40 acre spacing which allows for a much quicker response time in offset wells. The pattern area for this pilot project is not covered in the Prudhoe Bay Miscible Gas Project (PBMGP). This well currently exhibits mechanical integrity as a producer. Plans are to dummy all gas lift mandrels prior to commencing injection of MI. An MIT will be scheduled shortly after conversion to MI injection. Facility modifications will take place in mid December and the well is expected to be ready for MI injection by the end of this year, ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10120 Company: Alaska Oil & Gas Cons Camm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 4/9/96 Field: Prudhoe Bay Anadrill Anadrill Anadrill Well Job # Log Description Date BL RF Sepia Survey Program Performance Calculation Letter D':'S, 1 '11 '" ~-'DUAL BURST TDT-P BORAX 960401 I 1 D.S. 5-07 '~~GCT DIRECTIONAL SURVEY 960331 1 1 ......... D.S. 13-29 ~--PRODUCTION PROFILE 96031 3 I 1 ,, .D~-~;. 13-29 "' ,.~ DIGITAL ENTRY FLUID TOOLS~F?' 96031 3 I 1 D.S. 14-3 ~PRODUCTION PROFILE 960322 1 1 ,,, D.S. 14-43 -~PRODUCTION PROFILE 960323 1 1 ........ D.S. 16-2 -'~INJECTION PROFILE 960326 I I ,,, :'D.S. 16-8 '~ PRODUCTION PROFILE 96031 5 I 1 D.S. 16-8 ~/ DIGITAL ENTRY FLUID TOOL 96031 5 I I S I G N E D' _~ DATE: Alaska Oil & Gas Cons. Commission Anchorage GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9486 Company: 5/30/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 1-12 77 b$ , PROD PROFILE 051195 1 1 D.S. 4-24 ~I'7-.~1 CNTG 051395 I 1 D.S. 4-35 q f-. 0 ~ ti PERF RECORD 0511 95 I 1 D.S. 4-41 (~/--I ~'~ PERFRECORD r 051195 I 1 D.S. 5--31 q l'" Pr ~'~. PROD PROFILE' 05 I 3 95 I I . D.S. 7--32 ~' 5/- ! ~O DUAL BURST TDT'P 05 I 2 95 I 1 !D.S. 18--10 ~,---- )~ TUBG PUNCHER RECORD 051295 I 1 D.S. 14-43 ~Z-J~ 95171 DUAL BURST TDT-P 042795 .1 .. D.S. 2-3 '7~-~] 95183 DUAL BURST TDT-P 050795 1 I1~ ~ · SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9471 Company: 5/23/95 Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 2-31 ~/-- tO__~ TBG CUTTER RECORD 043095 I 1 D.S. 3-06 '~ (.p- ~ O M.I. INJEC LOG 0421 95 I 1 D.S. 3-31 ~ ~-~ Z_ ,CEE 050295 I 1 D.S. 7-32 =~ ~-/~'O IPERFRECORD 042895 I 1 D.S. 9-8 '~"'70 iPERFRECORD 042995 I 1 D.S. 9-12 ~-)"7 ,INJECPROFILE 050395 I 1 D.S. 11-16 ST1 ~'~-'7~ IPERFRECORD 042995 I 1 D.S. 11-23A c~-'~I IPERFRECORD 050195 1 1 D.S. 11-28 ~c]--~O I LEAK DETECTION 042895 I 1 cl ICNL 090299 I 1 D.S. 11-36c~' c~-/E'/-~ I DUAL BUST TDT-P 0501 95 I 1 D.S. 11-36 C~ c-/- G ~:>1 EST 042195 I 1 D.S. 14-5A c~.~_... / PERFRECORD 042795 I 1 D.S. 14-22A c~,~,- /~,~ PERFRECORD 042795 I 1 D.S. 14-28 ~,- I ~ LEAK DETECTION 042995 I 1 ,D.S. 14-33 ~-/~,_~ CEE 042795 I 1 D.S. 14-43 C~ ,~-- j O~ DUAL BURST TDT-P 042795 I 1 D.S. 16-12 ~' I'" ~-- q=> 'I'BG CUTTER RECORD 043095 I 1 D.S. 18-02A C~5-~O PERFRECORD 050295 ~1 1 D.S. 15-19 * 95176 DUAL BURST TDT-P 050495 1 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: ,,~ ~t 2 1995 Alaska Oil & Gas Cons. Commission Anchorage PERMIT DATA .OGCC Individual Well Geological Materials Inventory T DATA_PLUS Page' 1 Date: 11/02/94 RUN DATE_RECVD 92-108 92-108 92-108 92-108 92-108 92-108 92-108 92-108 92-108 92-108 BHC/AC/GR CBT CNL/GR/CCL DB TDTP (BRX) DIL/FL/GR PERF PERF PROD PROF SBT/GR/CCL SSTVD 92-108 USIT 92-108 407 92-108 DAILY WELL OP 92-108 SURVEY 92-108 SURVEY 92-108 SURVEY 92-108 5448 L 9082-9664 L 9032-9570 L 3200-9639 L 9000-9443 L 9082-9696 L 8850-9480 L 8900-9413 L 9200-9595 L 5100-9840 L 9082-9696 L 9032-9606 R COMP DATE: 11/15/92 R 10/22-10/31/92 R 0-9092 R 0.00-9700 R 7161-9092 T 3194-9696 OH/FINALS Are dry ditch samples requ,' ed? yes ~ And received? 1 11/19/92 1 12/30/92 1 11/19/92 1 05/06/93 1 11/19/92 1 01/14/94 1 03/26/93 1 05/10/93 1 12/30/92 1 11/19/92 1 12/30/92 01/28/93 01/28/93 01/28/93 01/28/93 03/09/93 1 11/19/92 yes ~ yes was the well cored? yes ~/~U~alysis & description received? COMMENTS STATE OF ALASKA · ~ ALASKA' . AND GAS CONSERVATION CO fISSION REPORT SUNDRY WELL OPF_.dATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 19" SNL, 1280' WEL, Sec. 9, T10N, R14E, UM At top of productive interval 838' NSL, 2668' WEL, Sec. 4, T10N, R14E, UM At effective depth At total depth 997' NSL, 2891' WEL, Sec. 4, T10N, R14E, UM 6. Datum of elevation(DF or KB) 74' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-43 9. Permit number/approval number 92-108 10. APl number 50 - 029-22296 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9700 feet 9231 feet Plugs(measured) PBTD @ 9586' (11/30/93) Effective depth: measured 9586 feet true vertical 9126 feet Junk(measured) Casing Length Size Cemented Conductor 110' 20" 2000# Coldsetll Surface 3119' 10-3/4" 1978 cu ft CSIII & 403 cu ft CIG Measured depth True vertical depth 110' 110' 3193' 3193' Production 9020 7-5/8" 1179 cu ft Gl G Liner 782' 5-1/2" 125 sc CIG Perforation depth: measured 9290-9308', 9321-9339' true vertical 8856-8874', 8885-8901' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, 13 Cr, Tubing @ 8934' MD 9094' 8680' 9700' 9231' RECEIVED MAR 1 6 1994 Alaska 0il & (]as Cons, Commission Anchorage Packers and SSSV (type and measured depth) 7-5/8" Baker SABL-3 Packer @ 8872' MD; 4-1/2" Camco BaI-O SLVN @ 2161' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 407 571 2666 1975 632 970 3009 1975 Tubing Pressure 225 225 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 // RJR cc: J. DeGrey, J. W. Peirce Title Senior Engineer SUBMIt' IN~DI~PLICATE ~ . . . . DS 14-43 Summary of Perforating Operations 12/1/93 Move in and rig up SWS. Pressure test lubricator to 3000 psi. Run in hole, tie in, and perforate from 9290' MD to 9308' MD (ref. 11/3/92 BHCS) at 4 shots per foot. Pull out of hole return well to production. MAF~ 1 6 1994 Gas Cons. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-4-94 REFERENCE: ARCO CASED HOLE FINALS 5-7 11-30-93 Prod Profile~¢~¢/le~'~?l 'l~un 1, 5"~t~4~h 5-23 11-30-93 Dual Burst TDT-P R~_m 1, 5" Sch 6-6 11-30-93 Perf Record ll~L~ZL9Z R~m 1, 5" Sch 6-12A 12-02-93 PerfRecord 'io~0o-llc%- R~m 1, 5" ~ch 11-12 12-02-93 Prod Profilel~;~p/~.~/,';':Run 1, 5''/zl~z~q~ch 11-18 11-29-93 Prod Profile/~,:,~ i";~-'~,f'!~~-~ Run 1, 5"~'!~?~%~Sch 14-2 11-26-93 PFC/GR/CCL~!:~~ Run 1, 14-5A 12-01-93 Completion ~a~':~cc~- R~ 1, 5" Sch 14-43 12-01-93 Pe~Record~;~%~:~f'~ R~ 1, 5" Sch 16-17 12-03-93 ~b~g GLM Packer R~ 1, 5''(~e'':~;'~ Sch ~8-23A 11-24-93 ~~ Cl~l ?~._7~c R~ 1, 5" ~18-23A 12-01-93 CBT/GR/CCL ~lo~S R~ 1, 5" '~ Sch ~8-23A 12-01-93 USIT i~&~ ~ ~lor R~ 1, 5" ' ~ Sch Please sign and return the attached copy as receipt of data.~/~/~~ . RECEIVED BY' ., Have A Nice Day! ~ ~70//~.~os ¢o~ John E. DeGrey APPROVED ATO-1529 ~s$ 94003 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA # Ptm~LIPS # AN08 GEOLOGY # EXXON # MOBIL The corrected well name is 14-2 and the corrected API# is 50-029-20318-00. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-6-93 REFERENCE: 1-24A 2-7-93 .~ ~//~ i~. 3-20 4-6-93 ~~0A 4-13-93 .pp~.3-20A 4-28-93 -lO 77~ ~'~' ~-~-~a -18 7Z~ ~-~0-¢8 ~6-12At' . ~ 4-24-93 ~6-17 F~6 4-25-93 7-4A ARCO CASED HOLE FINALS GR/CCL/Jewelry/Temp Tubing Cutter SBT/GR/CCL Perf Record Jewelry/GR/CCL Tie-In CNL/GR Color USIT/GR Color Leak Detect Static Press/Temp Leak Detect Prod Profile Production Log Pressure Build-Up Press/Temp Perf Record Production Log Dual Burst TDTP (Borax). Perf Record - PFC/GR (Packer Set] lnJ Profile Leak Detect Leak Detect Leak Detect InJ Profile Prod Profile Prod Profile Leak Detect SBT/GR/CCL ~'2-,- (, ? 4,23-03 7-7A ~$~t3 4-21-93 ./0-27 ~ 1F-:'~' 4-20-93 ~-31A ~-5~ 4-19-93 , ~ , ~_~0-40 ~/i ~ 1-1-03 ~l~~~2-13 ~/- ~ ~ 1-2-03 ~-- **~2-14ST ~/~/~4-27-93 ~3-20~-~ 4-25-03 ~13-25 ~-?/ ~2-26-~3 ~-43 ~-/~r 1-3-03 ~6-27 ~;,~i ~2-27-~2 ~7-13 ~;~ 4-~8-~3 ~GX-O i~.~ 4-~ ~-~3 Run 1. Run 1. Run 1. Run 1. Run 1. Run 1. Run 1. Run 1. I~' Run 1, R~ 1. ~'~' R~ 1, R~ 1, R~ 1,. R~ 1, R~ 1, R~ 1, 1"~" R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, ~'&5" R~ 1, ~'~" R~ 1, ~'~" Please sign and retull~:~ attagh~l c~ as reci~ of data. RECEIVED BY~~_~t_~~~ ~~ Sonya Wallace · ATO-1529 # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # EXXON # MOBIL Camco Atlas Atlas 8ch 8ch Sch ~ch Camco 8ch 8ch Camco Sch 8ch 8ch Sch Sch Sch 2ch Atlas Camco Camco [ich 8ch Camco Camco Camco Sch Atlas # STATE OF ALASKA The Correct well -_-_me for this log is 1-24A. The correct Al)It for 3-20.6. is 50-02~2~1. The correct API# for 12-14ST is 50-029-20659-00. . /? ARCO Alaska~ Inc. P.O.Box 100360 Anchorage, Alasl~ 99510 DATE: 4-30-93 REFERENCE: 4-16-93 Inflatable IBP Setting Run 1, 5" 4-11-93 Dual Burst TDTP (Borax) Run 1, 5" 4-13-93 Production l~m 1, 4-9-93 Static Press/Temp Run 1, 5" 4-10-93 Perf Record li~_m 1, 4-Z-93 Tubing Cutter Run 1, 4-11-93 Production Run 1, 4-8-93 Static Pressm'e/Temp Run 1, 4-1-93 Perf Record l~m 1, 5" 4-3-93 SBL/GR/CCL Run 1, 5" 4-4-93 PFC/CC& (packer Settt_ n~ Run 1, 5" 4-7-93 Dual Burst TDTP/Temp (Borax) Run 1, 5" 4-12-93 Production Run 1, 4-10-93 Dual Burst TDTP (Borax) Run 1, 4-9-93 Dual Burst TDTP (Borax) Run 1, 5" 4-8-93 Production Run 1, 5" 3-24-93 SBL/GR/CCL Run 1. 5" 3-24-93 SHL/GR/CCL Run 1. 5" 3-29-93 SBL/GR/CCL Run 1, 5" Please sign and return tl~ attached copy a~ receipt of data. RECEIVED BY ~~~__~ Have A Nice Day! Sonya Wallace AT0-1529 # CENTRAL FILES # CHEVRON D&M # CLINT CHAPMAN # EXXON MARATHON # MOBIL RECEIVED APPROVED "/" M.~y 0 6 1995 Trans# 9305~ - # PHILLIPS PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO Sch Sch Sch Sch Sch Atlas Sch Sch Sch Atlas Atlas Sch Sch Sch Sch Seh Arias Atlas Atlas ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOLE FINALS _~~1-30 -11 -11 f0-b * q-13 .... ~1-18 L- 2-10A Iq ~~ ~6-25 ~6-30 1-31-93 Perf Record 1-4-93 Perf Record 1-10-93 Perf Record 1-11-93 Perf Record 11-12-92 Perf Record 11-8-92 Perf Record 11-28-92 Perf Record 1-29-93 Perf Record 11-15-92 Perf Record 11-19-92 Perf Record 11-6-92 Perf Record 11-27-92 Peri Record 11-18-02 Perf Record 1-2-93 Perf Record 1-1-93 Perf Record 3-1-93 Perf Record 1-9-93 Perf Record 11-18-92 Perf Record 11-15-92 Perf Record 1-3-93 DSN 1-8-93 Perf Record 11-2-92 Collar (Inflatable Packer) 11-16-92 Collar (To spot Jet cutter) 1-8-93 Perf Record 11-14-92 Perf Record 12-2-92 Perf Record 11-29-92 Perf Record 12-31-92 Perf Record 11-29-92 Perf Record 1-5-93 Perf Record 11-17-92 Perf Record Please sign and return the attached copy as receipt of data. Have A Nice Day[ Run 1. Run 1. Run 1, Run 1. Run 1, Run 1. Run 1, Run 1. Run 1, Run 1. R~ 1. R~ 1, R~ 1. R~ 1. R~ 1. R~ 1, R~ 1, R~ 1. R~ 1. R~ 1. R~ 1. R~ 1. R~ 1. R~ 1, R~ 1, R~ 1. R~ 1. R~ 1. R~ 1, Sonya Wallace ATO-1529 #PHILliPS PB WI/I,L F~m~J #BPX # STATE OF These logs were mn in 1993 not 1992. The correct API# for 4-14A is 50-02~2031~. The correct API~ for 1~-29A is 50-029-22272-01. HIS HIS HLS HIS HL~ HL~ HI~ HIS HIS HIS HIS HIS HIS HLS HIS HL$ HIS HIS HL~ HL~ HIS HL~ HIS HIS HIS HLS HIS HLS HIS HL~ HIS RECEIVED Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK"~--"IL AND GAS CONSERVATION ¢ "'/MISSION REPORT OF SUNDRY WELL OF RATIONS i Operations performed: Operation shutdown Stimulate X Plugging Perforate ~ ' Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) ARCO Alaska, inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Development Exploratory Stratigraphic 4. Location of well at surface 19' SNL, 1280' WEL, Sec. 9, T10N, R14E, UM At top of productive interval 838' NSL, 2668' WEL, Sec. 4, T10N, R14E, UM At effective depth At total depth 997' NSL, 2891' WEL, Sec. 4, T10N, R14E, 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-43 9. Permit number/approval number 92-108 10. APl number 50 - 029-22296 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 9700 feet 9231 feet Production Liner Plugs(measured) PBTD @ 9597' MD (2/25/93) 9597 feet 9137 feet Junk(measured) Length Size Cemented Measured depth True vertical depth 110' 20" 2000# Coldset II 110' 110' 3119' 10-3/4" 1978 cu ft CS III & 403 cuft Cl G 3193' 3193' 9020' 7-5/8" 1179 cu ft Cl G 9094' 8680' 782' 5-1/2" 125 sx Cl G 9700' 9231' PeRoration depth: measured 9321-9339' true vertical 8885-8901' Tubing (size, grade, and measured depth) 4-1/2", 12.6g, 13 Cr, Tubing @ 8934' MD Packers and SSSV (type and measured depth) 7-5/8" Baker SABL-3 Packer @ 8872' MD; 4-1/2", Camco BaI-O SLVN @ 2161' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 168 322 601 -- Subsequent to operation 1433 ~-~-~' 1183 2015 -- Tubing Pressure 227 225 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil~ Gas ~. Suspended ..._ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~-~"~, ~'~--- Form 10-404 Rev 06/15/88 971/1 KRF cc: SW, JWP Title Engineering Supervisor SUBMIT IN DUPLICATE 14-43 DESCRIPTION OF WORK COMPLETED NITRIFIED MUD ACID STIMULATION TREATMENT 2/25/93 · RIH & tagged bottom at 9597' MD. 2/26193: MIRU CTU & PT equipment to 4000 psi. RIH w/CT to 9260' MD, then reciprocated a tubing wash & acid wash while the well was flowing, across the perforations at: 9321 - 9339' MD (Z4) Ref. Log: BHCS 11/3/92. Pumped 50 bbls Seawater, followed by 26 bbls 15% HCI w/10% Xylene, followed by Seawater displacement. POOH w/CT. Rigged down. 2/27/93: A Fullbore Nitrified Mud Acid Stimulation was performed as follows: MIRU & PT equipment to 4500 psi. Treated the perforations (listed above), pumping 50 bbls 1% NH4CI Water, followed by 25 bbls 50% Diesel/50% Xylene @ 10 bpm, followed by 26 bbls 1% NH4CI spacer, followed by 26 bbls 15% HCI w/Nitrogen injected @ 700 scfb, followed by 26 bbls 1% NH4CI spacer, followed by 26 bbls 9% HCI - 1% HF w/Nitrogen injected @ 700 scfb, followed by 202 bbls 1% NH4CI Water overflush, followed by Shutdown. Rigged down. Returned well to production w/gaslift & obtained a valid production welltest. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 11-13-92 REFERENCE: ARCO D~ONAL DATA ~...-I I ~... II-IA ~_~o] _~J12-10A - ~12-10A 2-14ST 4-41 7-15 lo-18-92 10-30-92 lo-26-92 lo-27-92 lo-9-92 lo-14-92 10-29-92 10-14-92 10/19-31/92 10-3-92 · MWD Directional Survey MWD Directional Survey MWD Directional Survey Electronic Survey System MWD DlrectioT~nl Survey MWD Directional Survey MWD Directional Survey MWD Dlrectio-.l Survey MWD Directional Survey MWD Directional Survey Please sign and return~the attached copy as receipt of data. RECEIVED BY~_~_~ff~ ~ ~ Have A Nice Day~ ~ 8onya Wallace ATO-1529 Sperry Cd~DI Sperry Sperry Teleco Teleco Aha APPROVED___~ Trans# 92252 CENTRAL FILES CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON MOBIL PmTJ~TPS # PB WELL FILE~ R&D #BPX # ST. OF AK. (2 COPIES) TEXACO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v,MISSION WELL COMPLETION OR RECOMP L£TION REPORT AND LOG OIL [] GAS [] SUSPENOED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 92-108 3. Address 8. APl Number P. 0. Box 196612, Anchora~le, Alaska 99519-6612 ,50- 029-22296 4. Location of well at surface 9. Unit or Lease Name 19' SNL, 1280' WEL SEC. 9, TION, R14E, UM ~'~;~'~;;~:~;:~;';;~, Prudhoe Bay Unit 838' NSL, 2668' WEL, SEC. 4, TION, R14E, UMi DS 14-43 .............. ; 11. Field and Pool At Total Depth UM __ -'_~.~' i~i r ~ Prudhoe Bay Field/Prudhoe Bay Pool 997' NSL, 2891' WEL, SEC. 4, TION, R14E, 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 74' I ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. o¢ Aband. 115. Water Depth, if offshore 116. No. of Completions 10/21/92 11/2/92 11/15/92I N/A feet MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey IO. DopthwhereSSSVset I1. Th,cknoss o, Permafrost 9700'MD/9£31' TVD 9619'MD/9157'-I-VD ~ [] I,~ [] 2161'feet MD 1900' (Approx.) 22. Typo Electric or Oth~' I.D,S Run G R/C N/A C/D IFL/M WD 2~. CASIN~. LINER CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 2000 # Coldset II 10-3/4" 45.5# NT-80 35' 3193' 13-1/2" 1978 Cu fl CS i11/403 Cu fl"G 7-5/8" 29. 7# NT-95 35' 9094' 9-7/8" 1179 cu ft Class "G" 5-1/2" 17# 13CR80 8947' 9700' 6-3/4" 125 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET(MDI PACKER SET (MD) Gun Diameter 3-3/8" 4spf 4-1/2" 13CR80 8933' 8872' MD TVD 26. ACID, FRACTURE, CEMENT SQUEF_Z~ ETC. 9321 '-9339' 8885'-8901' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 11/15/92 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. '"' 30. GEOLOGIC MARKERS r .... ~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 9045' 8636' Shublik 9067' 8656' Top Sadlerochit 9155' 8734' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ' Tit lo Drilling Engineer Suoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ~). ~--~ ~ ,,~ ,~ ~_~. r~.~ Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 14-43 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 10/21/92 12:10 SPUD: 10/21/92 02:10 RELEASE: 11/06/92 04:11 OPERATION: DRLG RIG: DOYON 9 WO/C RIG: DOYON 9 10/22/92 (1) TD: 2082'(2082) 10/23/92 (2) TD: 3210' (1128) 10/24/92 (3) TD: 3840' ( 630) 10/25/92 (4) TD: 5300' (1460) 10/26/92 (5) TD: 6700' (1400) DRLG. MW: 9.0 VIS:300 MOVE RIG. RIG ACCEPTED @ 12:00 HRS, 10/21/92. M/U BHA #1. TEST DIVERTER. MIX SPUD MUD. SPUD WELL @ 14:30 HRS, 10/21/92. DRLG TO 2082'. CMT CSG. MW: 9.5 VIS:300 DRLG TO 3210'. CBU. SHORT TRIP. CBU. POOH. L/D BHA. RIH W/ 10-3/4" CSG. CIRC. BEGIN CMT CSG. DRLG. MW: 9.1 VIS: 37 N/D DIVERTER. R/U BJ. TOP JOB W/ 200 SX CMT. N/U BOPE. TEST BOPE. RIH W/ BIT #2. TEST CSG. OK. DRLG FLOAT EQUIP TO 3220'. CIRC. FIT (12.0 PPG EMW) . DRLG TO 3840' DRLG. MW: 9.3 VIS: 39 DRLG TO 4913' CBU. POOH. CHANGE BHA. RIH. DRLG TO 5300' DRLG. DRLG TO 6700'. MW: 9.5 VIS: 38 10/27/92 (6) TD: 7275' ( 575) 10/28/92 (7) TD: 7769' ( 494) DRLG. DRLG TO 7149' 7275' MW: 9.5 VIS: 40 CBU. POOH. CHANGE BHA. RIH. DRLG TO RIH. DRLG F/ 7275'-7769' MW: 9.6 VIS: 37 CIRC. POOH. CHANGE BHA. RIH. 10/29/92 ( 8) TD: 9064' (1295) DRLG. DRLG F/ 7769'-9064'. MW: 9.7 VIS: 36 10/30/92 (9) TD: 9094' ( 30) 10/31/92 (10) TD: 9094' ( 0) WAIT FOR WH TO COOL. MW: 9.7 VIS: 36 DRLG F/ 9064'-9094' CBU. SHORT TRIP 20 STDS. CIRC. POOH. RIH W/ HALIB RTTS. SET @ 90' JAR ON WEAR BUSHING. NO GO. N/D BOPE. CUT SPEED HEAD. CHANGE RAMS. MW: 9.9 VIS: 38 COOL WELLHEAD. N/U BOPE. TEST BOPE. L/D RTTS. CBU. RIH. REAM F/ 8903'-9094' CIRC. SHORT TRIP 15 STDS. CIRC. POOH. L/D BHA. T~ST BOPE. SUB- SURFACE DIRECTIONAL SURVEY F~ UIDANCE F~ ONTINUOUS ~ OOL Company Well Name ARCO ALASKA, INC. D.S. 14-~{1g' FNL, 1280' FEL, SEC 9, TION, R14E) Field/Location PRUDHOE BAY, NORTH SLOPE, ALASKA Job Reference No. 92672 Logcjed BV: ~ARNER Date 11-NOV-92 Computed By' KRUWELL * SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. D.S. 14 - 43 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE' ll-NOV-1992 ENGINEER' D. WARNER METHODS OF COMPUTATION TOOL LOCATION' TANGENTIAL- Averaged deviation and azimuth INTERPOLATION' LINEAR VERTICAL SECTION' HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH $7 DEG 48 MIN WEST ARCO ALASKA, INC. D.S. 14 - 43 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE' 17-NOV-92 PAGE 1 DATE OF SURVEY: 11-NOV-1992 KELLY BUSHING ELEVATION: 74.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 -74 O0 26 O0 126 O0 226 O0 326 O0 426 O0 526 O0 626 O0 726 O0 826 O0 0 0 N 0 0 E 0 8 S 78 45 W 0 7 S 56 44 W 0 2 S 17 40 W 0 6 N 54 49 W 0 9 S 54 11W 0 I N 62 34 E 0 7 S 80 44 W 0 2 N 33 30 W 0 4 S 57 26 W 1000 O0 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 926 O0 O0 1100 O0 1199 O0 1299 O0 1399 O0 1499 O0 1599 O0 1699 O0 1799 O0 1899 O0 1026 O0 99 1125 99 98 1225 98 98 1325 98 97 1425 97 97 1525 97 96 1625 96 96 1725 96 95 1825 95 0 14 S 16 54 W 0 34 S 3 19 E 0 41 S 5 34 E 0 41 S 2 59 E 0 37 S 3 58 E 0 31 S 3 41E 0 31 S 3 22 E 0 33 S 3 36 E 0 37 S 5 19 W 0 49 S 17 19 E 2000 O0 1999 94 1925 94 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2099 O0 2199 O0 2299 O0 2399 O0 2499 O0 2599 O0 2699 O0 2799 O0 2899 92 2025 91 2125 89 2225 88 2325 86 2425 83 2525 81 2625 79 2725 76 2825 92 91 89 88 86 83 81 79 76 0 58 S 33 39 E 0 59 S 35 59 E 0 56 S 44 42 E 0 57 S 44 58 E 1 1 S 46 33 E 1 16 S 51 26 E 1 18 S 53 7 E 1 16 S 55 49 E 1 14 S 53 37 E 1 16 S 51 59 E 3000 O0 2999 73 2925 73 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 3099 O0 3199 O0 3299 O0 3399 O0 3499 O0 3599 O0 3699 O0 3799 O0 3899 68 3025 60 3125 52 3225 47 3325 44 3425 43 3525 42 3625 41 3725 41 3825 68 60 52 47 44 43 42 41 41 1 35 S 48 6 E 2 13 S 40 53 E 2 23 S 39 4 E 1 58 S 37 10 E 1 36 S 40 40 E 1 12 S 41 37 E 0 48 S 41 28 E 0 39 S 45 14 E 0 36 S 49 41E 0 25 S 49 15 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 O9 0 25 0 28 0 35 0 54 0 54 0 67 0 72 0 81 0 O0 0 09 0 13 0 20 0 18 0 15 0 17 0 O9 0 35 0 18 0 O0 N 0 O1 N 0 10 S 0 21 S 0 17 S 0 17 S 0 29 S 0 24 S 0 29 S 0 28 S 0 O0 E 0 10 W 0 36 W 0 46 W 0 52 W 0 75 W 0 82 W 0 94 W 1 03 W 1 13 W 0 O0 N 0 0 E 10 N 83 34 W 37 S 74 58 W 51 S 65 33 W 55 S 72 7 W 77 S 77 5 W 87 S 70 41W 97 S 75 44 W O7 S 74 26 W 17 S 76 16 W 0 8O 0 40 -0 24 -0 93 -1 62 -2 23 -2 76 -3 29 -3 82 -4 54 0 34 0 13 0 24 0 20 0 26 0 12 0 22 0 13 0 12 0 59 0 44 S 1 22 S 234 S 3 49 S 4 63 S 5 64 S 6 55 S 7 47 S 8 50 S 9 69 S 1 22 W 1 24 W 1 18 W 1 10 W 1 O0 W 0 92 W 0 87 W 0 82 W 0 84 W 0 74 W I 30 S 70 7 W 74 S 45 36 W 62 S 26 53 W 66 S 17 27 W 74 S 12 10 W 71 S 9 15 W 61 S 7 32 W 52 S 6 14 W 54 S 5 37 W 72 S 4 22 W -5 90 -7 48 -9 08 -10 72 -12 39 -14 46 -16 67 -18 87 -21 04 -23 21 0 43 0 18 0 10 0 2O 0 35 0 85 0 30 0 13 0 38 0 81 11.08 S 12.43 S 13.68 S 14.87 S 16.10 S 17.46 S 18.86 S 20.15 S 21.42 S 22.76 S 0 O0 E 1 O1 E 2 12 E 3 30 E 4 51 E 6 09 E 7 82 E 9 61 E 11 37 E 13 09 E 11 08 S 0 0 12 13 15 16 18 2O 22 24 26 47 S 4 39 85 S 8 47 23 S 12 32 71 S 15 39 49 S 19 13 42 S 22 31 33 S 25 30 25 S 27 58 26 S 29 54 -25 58 -28 75 -32 62 -36 30 -39 19 -41 47 -43 26 -44 50 -45 50 -46 34 0 54 0 65 0 22 0 89 0 21 0 52 1 14 0 3O 0 14 0 O8 24.31 S 26 66 S 29 81 S 32 87 S 35 26 S 37 06 S 38 41 S 39 31 S 39 99 S 40 56 S 14 93 E 17 18 E 19 78 E 22 20 E 24 11E 25 67 E 26 93 E 27 83 E 28 59 E 29 22 E 28 52 S 31 33 31 35 39 42 45 46 48 49 49 72 S 32 48 77 S 33 34 66 S 34 2 72 S 34 22 09 S 34 42 91 S 35 2 17 S 35 18 16 S 35 34 99 S 35 46 ARCO ALASKA, INC. D.S. 14 - 43 PRUDHOE BaY NORTH SLOPE, ALASKA COMPUTATION DATE- 17-NOV-92 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH PAGE 2 DATE OF SURVEY: 11-NOV-1992 KELLY BUSHING ELEVATION: 74.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 4000 O0 3999 41 3925 41 0 18 S 52 35 E 41 0 12 S 53 53 E 41 0 9 S 45 29 E 41 0 11 S 52 42 E 41 0 16 S 53 56 E 40 0 27 S 65 51E 4O 0 36 S 7O 5 E 39 0 39 S 69 56 E 38 0 39 S 68 34 E 38 0 36 S 7O 25 E 4100 4200 43OO 4400 4500 4600 4700 4800 4900 1 3 O0 4099 O0 4199 O0 4299 O0 4399 O0 4499 O0 4599 O0 4699 O0 4799 O0 4899 41 4025 41 4125 41 4225 41 4325 40 4425 40 4525 39 4625 38 4725 38 4825 N 34 16 W N 42 39 W N 47 27 W N 47 55 W N 49 54 W N 53 46 W N 53 5O W N 56 49 W N 59 11 W N 59 56 W 5000 O0 4999 37 4925.37 5100 5200 5300 5400 5500 5600 5700 5800 5900 24 5025.24 4 15 84 5124.84 5 44 12 5224 12 7 56 73 5322 73 10 32 67 5420 67 12 37 85 5517 85 14 46 06 5614 06 17 6 86 5708 86 20 1 95 5801 95 22 47 O0 5099 O0 5198 O0 5298 O0 5396 O0 5494 O0 5591 O0 5688 O0 5782 O0 5875 FEET DEG/IO0 FEET FEET FEET DEG MIN -46 91 -47 26 -47 47 -47 71 -48 12 -48 73 -49 69 -5O 75 -51 84 -52 96 -52 61 -47 86 -39 23 -27 44 -11 09 8 95 32 43 59 67 91 45 127 92 0 18 0 25 0 34 0 35 0 20 0 24 0 51 0 17 0 17 0 23 1 30 1 49 1 12 2 23 1 2O 1 98 2 56 2 07 2 76 2 32 40 90 S 41 08 S 41 16 S 41 25 S 41 45 S 41 73 S 42 12 S 42 49 S 42 87 S 43 25 S 29 69 E 29 98 E 30 18 E 3O 4O E 30 76 E 31 31E 32 20 E 33 22 E 34 27 E 35 36 E 5O 54 S 35 58 5O 51 51 51 52 53 53 54 55 86 S 36 7 O4 S 36 15 24 S 36 24 62 S 36 35 17 S 36 53 O1 S 37 24 93 S 38 88 S 38 38 86 S 39 16 42 67 S 39 O0 S 32 80 S 24 80 S 13 81 S 1 55 S 12 48 N 28 O0 N 44 82 N 63 35 3O E 32 25 16 4 11 3O 52 79 18 N 111 55 38 S 39 36 E O0 E 50 71E 41 81E 29 41E 14 55 W 11 47 W 32 88 W 59 84 W 91 38 W 128 45 S 39 22 E 67 S 38 5 E 96 S 34 8 E 5O S 17 43 E 65 S 82 22 W 93 N 67 43 W 83 N 62 6 W 57 N 60 41W 06 N 60 26 W 6000 O0 5967 19 5893 19 25 40 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 6056 O0 6143 O0 6228 O0 6313 O0 6399 O0 6486 O0 6572 O0 6659 O0 6745 15 5982 14 6069 81 6154 97 6239 88 6325 29 6412 67 6498 07 6585 71 6671 15 28 37 14 30 23 81 31 39 97 31 16 88 30 11 29 30 15 67 30 15 07 30 18 71 29 45 N 59 45 W N 60 19 W N 60 35 W N 60 30 W N 61 36 W N 62 9 W N 61 59 W N 62 4 W N 60 15 W N 58 54 W 168 78 214 39 263 64 315 16 367 51 418 55 468 76 518 98 569 25 619 17 2 81 2 98 1 62 1 19 0 87 1 38 0 62 0 34 1 12 1 43 83 65 N 146 78 W 168 94 N 60 19 W 106 130 156 181 2O5 229 252 277 302 50 N 186 80 N 229 19 N 274 67 N 319 77 N 365 39 N 409 96 N 454 29 N 498 71N 541 30 W 214 20 W 263 09 W 315 90 W 367 04 W 419 50 W 469 02 W 519 10 W 570 09 W 620 59 N 60 15 W 89 N 60 17 W 47 N 60 19 W 89 N 60 24 W 04 N 60 35 W 37 N 60 45 W 73 N 60 53 W O8 N 60 54 W O1 N 60 47 W 7000 O0 6832.30 6758.30 30 5 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 6919.36 6845.36 29 18 O0 7006.49 6932.49 29 12 O0 7094 10 7020.10 28 35 O0 7182 32 7108 32 27 43 O0 7270 92 7196 92 27 41 O0 7359 63 7285 63 27 2 O0 7448 73 7374 73 26 57 O0 7538 15 7464 15 26 19 O0 7627 82 7553 82 26 12 N 58 51W N 58 4 W 718 N 57 10 W 767 N 57 3 W 815 N 57 4 W 862 N 56 39 W 909 N 55 28 W 955 N 55 6 W 1000 N 55 17 W 1045 N 55 26 W 1089 669 18 38 44 66 74 O9 22 59 30 53 0 59 1 O0 0 43 0 74 1 04 0 43 1 09 0 42 0 61 0 37 328 53 N 583 93 W 670 O0 N 60 38 W 354 38O 4O6 432 457 483 5O9 534 56O 25 N 625 59 N 667 79 N 707 43 N 747 77 N 786 58 N 824 42 N 861 98 N 898 13 N 934 87 W 719 26 W 768 75 W 816 24 W 863 06 W 909 32 W 955 65 W 1000 41W 1045 83 W 1089 17 N 60 29 W 17 N 6O 18 W 32 N 60 7 W 34 N 59 57 W 64 N 59 47 W 70 N 59 36 W 98 N 59 24 W 63 N 59 Z4 W 79 N 59 4 W ARCO ALASKA, INC. D.S. 14 - 43 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE' 17-NOV-92 PAGE 3 DATE OF SURVEY: 11-NOV-1992 KELLY BUSHING ELEVATION: 74.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 7717 24 7643 24 26 41 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 7806 O0 7895 O0 7983 O0 8070 O0 8157 O0 8244 O0 8332 O0 8419 O0 8507 81 7732 48 7821 O0 7909 08 7996 33 8083 80 8170 23 8258 85 8345 93 8433 81 26 31 48 28 29 O0 29 25 08 29 29 33 29 9 80 28 50 23 29 6 85 28 22 93 27 59 N 55 26 W 1134 24 N 55 10 W 1178 N 55 7 W 1224 N 56 23 W 1273 N 56 34 W 1322 N 56 29 W 1371 N 56 55 W 1419 N 58 34 W 1468 N 57 54 W 1516 N 58 4 W 1563 68 84 17 32 19 64 17 37 71 .81 51 21 25 24 38 42 94 O0 31 585 56 N 971 66 W 1134 46 N 58 56 W 610 637 664 691 718 745 771 796 821 85 N 1008 31N 1046 59 N 1086 70 N 1127 74 N 1167 42 N 1208 23 N 1249 49 N 1290 57 N 1330 24 W 1178 13 W 1224 07 W 1273 09 W 1322 80 W 1371 26 W 1419 36 W 1468 41W 1516 57 W 1563 85 N 58 47 W 97 N 58 39 W 28 N 58 32 W 41 N 58 28 W 26 N 58 23 W 70 N 58 20 W 23 N 58 19 W 43 N 58 19 W 78 N 58 18 W 9000 O0 8596 36 8522 36 27 32 9100 O0 8685 14 8611 14 26 56 9200 O0 8774 98 8700 98 25 25 9300 O0 8865 48 8791 48 24 56 9400 O0 8956 44 8882 44 24 17 9500 O0 9047 84 8973 84 23 38 9600 O0 9139 48 9065 48 23 33 9700 O0 9231 15 9157 15 23 33 N 57 43 W 1610 39 N 57 8 W 1656 42 N 56 34 W 1700 31 N 55 20 W 1742 83 N 53 43 W 1784 33 N 53 4 W 1824 78 N 52 22 W 1864 63 N 52 22 W 1904 41 1 24 1 07 1 64 0 76 0 76 0 89 0 oo 0 O0 846 44 N 1370 07 W 1610 45 N 58 18 W 870 99 n 1409 O0 W 1656 47 N 58 17 W 895 07 N 1445 71 W 1700 36 N 58 14 W 918 84 N 1480 99 W 1742 87 N 58 11 W 942 98 N 1514 82 W 1784 35 N 58 6 W 967 11 N 1547 43 W 1824 79 N 58 0 W 991 45 N 1579 21 W 1864 64 N 57 53 W 1015 85 N 1610 84 W 1904 41 N 57 46 W COMPUTATION DATE: 17-NOV-92 PAGE 4 ARCO ALASKA, INC. D.S. 14 - 43 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY: 11-NOV-1992 KELLY BUSHING ELEVATION: 74.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEP-FH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ~IN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 O0 1000 O0 1999 O0 2999 O0 3999 O0 4999 O0 5967 O0 6832 O0 7717 O0 8596 -74 O0 O0 926 94 1925 73 2925 41 3925 37 4925 19 5893 30 6758 24 7643 36 8522 0 0 N 0 0 E O0 0 14 S 16 54 W 94 0 58 S 33 39 E 73 1 35 S 48 6 E 41 0 18 S 52 35 E 37 1 3 N 34 16 W 19 25 40 N 59 45 W 30 30 5 N 58 51W 24 26 41 N 55 26 W 1134 36 27 32 N 57 43 W 1610 0 O0 0 80 -5 90 -25 58 -46 91 -52 61 168 78 669 18 24 39 0 O0 0 34 0 43 0 54 0 18 1 30 2 81 0 59 0 81 1 24 0 O0 N 0 11 24 40 42 83 328 585 846 0 O0 E 44 S 1 08 S 0 31S 14 90 S 29 67 S 35 65 N 146 53 N 583 56 N 971 44 N 1370 0 O0 N 0 0 E 22 W 1 O0 E 11 93 E 28 69 E 50 30 E 55 78 W 168 93 W 670 66 W 1134 07 W 1610 3O S 70 7 W 08 S 0 0 E 52 S 31 33 E 54 S 35 58 E 38 S 39 36 E 94 N 60 19 W O0 N 60 38 W 46 N 58 56 W 45 N 58 18 W 9700.00 9231.15 9157.15 23 33 N 52 22 W 1904.41 0.00 1015.85 N 1610.84 W 1904.41 N 57 46 W COMPUTATION DATE' 17-NOV-92 PAGE 5 ARCO ALASKA, INC. D.S. 14 - 43 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 11-NOV-1992 KELLY BUSHING ELEVATION' 74.00 FT ENGINEER' D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET OEO MIN 0 O0 74 O0 174 O0 274 O0 374 O0 474 O0 574 O0 674 O0 774 O0 874 O0 0.00 74 O0 174 O0 274 O0 374 O0 474 O0 574 O0 674 O0 774 O0 874 O0 -74 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 5 N 78 18W 0 8 S 65 4 W 0 4 S 36 7W 0 5 N 50 22 W 0 9 S 71 22W 0 2 S 4 55 E 0 7 N 83 59 W 0 2 S 57 12 W 0 5 S 64 50 W 0 O0 0 O5 0 22 0 28 0 31 0 51 0 54 0 62 0 71 0 80 0 O0 0 37 0 3O 0 26 0 2o 0 29 0 36 0 54 0 20 0 25 0 O0 N 00I N 0 07 S 0 I9 S 0 19 S 0 "14 S 0 28 S 0 24 S 0 29 S 0 26 S 0 O0 E 0 05 W 0 31W 0 45 W 0 49 W 0 69 W 0 82 W 0 89 W I 02 W I 10 W 0.00 N 0 0 E 0.05 N 79 8 W 0.31 S 77 15 W 0.49 S 67 8 W 0.53 S 68 16 W 0.70 S 78 31W 0.87 S 71 9 W 0.92 S 74 57 W 1.06 S 74 18 W 1.13 S 76 45 W 974 O0 1074 1174 1274 1374 1474 1574 1674 1774 1874 974.00 900.00 O0 1074.00 1000.00 01 1174.00 1100.00 02 1274.00 1200.00 02 1374.00 1300.00 03 1474.00 1400.00 03 1574.00 1500.00 04 1674.00 1600.00 04 1774.00 1700.00 05 1874.00 1800.00 0 8 S 25 48 W 0 33 S 3 26 E 0 41 S 3 29 E 0 40 S 2 46 E 0 38 S 5 18 E 0 32 S 4 37 E 0 32 S 3 35 E 0 33 S 2 28 E 0 38 S 3 42 W 0 46 S 10 3 E 0 82 0 55 -0 05 -0 75 -1 45 -2 09 -2 61 -3 15 -3 69 -4 28 0 21 0 48 0 21 0 10 0 20 0 34 0 13 0 17 0 31 0 55 0 36 S 0 97 S 2 02 S 3 18 S 4 35 S 5 40 S 6 31 S 7 23 S 8 22 S 9 35 S 1 20 W 1 26 W 1 21 W 1 12 W 1 02 W 0 93 W 0 89 W 0 83 W 0 81 W 0 83 W 1 25 S 73 3 W 59 S 52 29 W 36 S 30 54 W 37 S 19 19 W 47 S 13 15 W 48 S 9 49 W 37 S 7 59 W 27 S 6 33 W 26 S S 38 W 38 S 5 5 W 1974 06 1974 O0 1900 O0 2074 2174 2274 2374 2474 2574 2674 2774 2874 07 2074 09 2174 10 2274 12 2374 14 2474 16 2574 18 2674 21 2774 23 2874 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 O0 O0 O0 O0 O0 O0 O0 O0 0 56 S 30 51E 0 58 S 37 50 E 0 56 S 45 27 E 0 58 S 45 47 E 1 0 S 45 7 E 1 17 S 51 1E I 17 S 50 48 E I 17 S 54 14 E I 16 S 53 3 E I 16 S 51 8 E -5 51 -7 07 -8 67 -10 30 -11 94 -13 89 -16 08 -18 30 -20 47 -22 64 0 15 0 12 0 40 0 32 0 16 0 43 0 15 0 16 0 58 0 19 10 71 S 12 08 S 13 39 S 14 57 S 15 78 S 17 10 S 18 50 S 19 82 S 21 08 S 22 40 S 0 23 W 0 75 E 1 82 E 2 99 E 4 18 E 5 64 E 7 35 E 9 14 E 10 92 E 12 65 E 10 71 S I 14 W 12 13 14 16 18 19 21 23 25 10 S 3 33 E 51 S 7 44 E 87 S 11 37 E 32 S 14 51E O1 S 18 15 E 91 S 21 41E 83 S 24 46 E 74 S 27 22 E 72 S 29 27 E 2974.26 2974.00 2900 O0 3074.30 3074.00 3000 3174.38 3174.00 3100 3274.46 3274.00 3200 3374.52 3374 O0 3300 3474.55 3474 O0 3400 3574.57 3574 O0 3500 3674.58 3674 O0 3600 3774.59 3774 O0 3700 3874.59 3874 O0 O0 O0 O0 O0 O0 O0 O0 GO 3800.00 1 30 S 48 19 E 2 3 S 41 1E 2 25 S 38 22 E 2 8 S 37 33 E 1 40 S 39 15 E I 16 S 41 I E 0 56 S 40 16 E 0 41 S 44 2 E 0 35 S 46 42 E 0 25 S 44 18 E -24 90 -27 83 -31 60 -35 44 -38 50 -40 95 -42 gl -44 21 -45.24 -46.16 0 67 1 07 0 65 0 7O 0 26 0 54 0 34 0 23 0 15 0 59 23 84 S 25 94 S 28 97 S 32 14 S 34 70 S 36 65 S 38 13 S 39 10 S 39.81 S 40.43 S 14 41E 16 55 E 19 10 E 21 64 E 23 65 E 25 32 E 26 69 E 27 63 E 28 39 E 29 09 E 27 86 S 31 9 E 30 34 38 41 44 46 47 48 49 77 S 32 33 E 70 S 33 24 E 75 S 33 57 E 99 S 34 16 E 55 S 34 38 E 55 S 35 0 E 88 S 35 14 E 90 S 35 3O E 81 S 35 44 E ARCO ALASKA, INC. D.S. 14 - 43 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATZON DATE: 17-NOV-92 PAGE 6 DATE OF SURVEY' 11-NOV-1992 KELLY BUSHING ELEVATION' 74.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG 0 17 S 51 47 E O0 0 8 S 42 50 E O0 0 5 S 47 I1E O0 0 6 S 70 3 E O0 0 15 S 62 35 E O0 0 23 S 66 49 E O0 0 35 S 68 46 E O0 0 39 S 69 1E O0 0 39 S 70 16 E O0 0 40 S 72 7 E 3974 59 3974 O0 3900 O0 0 41 N 28 28 W O0 3 37 N 42 54 W O0 5 24 N 46 49 W O0 7 25 N 48 18 W O0 10 10 N 48 56 W O0 12 17 N 53 46 W O0 14 9 N 53 20 W O0 16 32 N 56 13 W O0 lg 40 N 58 55 W O0 22 44 N 59 56 W 59 4074 59 4174 59 4274 59 4374 60 4474 60 4574 61 4674 61 4774 62 4874 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 ENGINEER' D. WARNER 4074 4174 4274 4374 4474 4574 4674 4774 4874 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 71 5074 04 5174 67 5274 90 5374 83 5474 56 5574 31 5674 57 5774 89 5874 4974 62 4974 O0 4900 O0 5074 5175 5275 5376 5478 5581 5685 5790 5897 6007 54 5974 O0 5900 O0 25 55 N 59 42 W N 6O 26 W N 60 32 W N 60 49 W N 62 3 W N 61 57 W N 62 3 W N 60 OW N 58 58 W N 58 30 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 6120 6235 6353 6469 6585 6701 6817 6932 7048 36 6074 86 6174 13 6274 99 6374 78 6474 54 6574 29 6674 63 6774 O0 6874 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 6700 O0 6800 -46.79 -47.19 -47.43 -47 65 -48 O1 -48 55 -49 43 -50 46 -51 56 -52 69 -52 96 -49 54 -41 60 -30 64 -15 19 O0 29 6 O0 30 52 O0 31 46 O0 30 31 O0 30 16 O0 30 15 O0 30 16 O0 29 59 O0 29 21 7162.73 6974 O0 6900 O0 29 27 7277.11 7074 7390.60 7174 7503.48 7274 7616 13 7374 7728 32 7474 7839 99 7574 7951 59 7674 8063 40 7774 8175 62 7874 4 40 27 83 55 41 88 20 127 11 O0 7000 O0 7100 O0 7200 O0 7300 O0 7400 O0 7500 O0 7600 O0 7700 O0 7800 172 O1 224 16 281 89 343 07 403 41 461 61 519 76 577 97 635 41 692 94 N 57 25 W O0 28 37 N 57 4 W 804 O0 27 45 N 57 3 W 858 O0 27 42 N 56 37 W 910 O0 26 54 N 55 25 W 962 O0 26 42 N 55 6 W 1013 O0 26 18 N 55 22 W 1063 O0 26 43 N 55 22 W 1112 O0 26 6 N 55 12 W 1162 O0 28 5 N 55 3 W 1213 0 21 0 74 0 35 0 35 0 O8 0 49 0 17 0 14 00l 0 21 40.82 S 41.04 S 41.13 S 41.22 S 41 39 S 41 66 S 42 02 S 42 39 S 42 76 S 43 16 S 29 59 E 29 93 E 30 15 E 30 36 E 30 67 E 31 14 E 31 95 E 32 94 E 34 O0 E 35 O9 E 5O 41 S 35 56 E 5O 50 51 51 52 52 53 54 55 79 S 36 6 E 99 S 36 14 E 19 S 36 22 E 51 S 36 32 E O1 S 36 47 E 79 S 37 15 E 69 S 37 51E 63 S 38 29 E 62 S 39 7 E 749 18 70 36 71 55 36 O1 49 47 32 1 24 2 63 0 85 2 o4 1 77 1 88 1 54 1 79 2 64 2 38 42.99 S 40.28 S 34.44 S 26 96 S 16 51 S 4 24 S 9 75 N 25 66 N 43 16 N 35 51 E 33 18 E 27 47 E 19 23 E 7 56 E 7 87 W 26 76 W 49 32 W 77 05 W 62 55 76 S 39 33 E 78 N 110 52 44 33 18 8 28 55 88 68 W 127 18 S 39 29 E 06 S 38 35 E 12 S 35 30 E 16 S 24 35 E 94 S 61 41W 47 N 69 59 W 60 N 62 31W 31 N 60 45 W 24 N 60 26 W 2 95 3 14 1 56 0 92 0 92 0 37 0 34 0 90 0 82 1 17 85 28 N 149 58 W 172 18 N 60 19 W 111 139 169 198 226 253 281 311 340 34 N 194 78 N 245 89 N 298 66 N 351 02 N 403 32 N 454 63 N 505 09 N 555 89 N 604 80 W 224 10 W 282 44 W 343 63 W 403 17 W 462 71W 52O 67 W 578 O0 W 636 23 W 693 37 N 60 15 W 15 N 60 18 W 41 N 6O 21W 87 N 60 32 W 21 N 60 43 W 51 N 60 53 W 81 N 60 53 W 24 N 60 44 W 75 N 60 34 W 0 76 0 81 1 19 0 41 1 29 0 63 0 69 0 94 0 64 1 54 370 72 N 651 90 W 749 94 N 60 22 W 400 430 458 487 516 545 573 601 630 83 N 698 05 N 743 66 N 787 74 N 830 74 N 872 06 N 912 19 N 953 59 N 994 71N 1036 55 W 805 57 W 858 41W 911 37 W 963 14 W 1013 98 W 1063 75 W 1112 92 W 1162 68 W 1213 38 N 6O 9 W 97 N 59 57 W 25 N 59 47 W O1 N 59 34 W 73 N 59 21W 31 N 59 10 W 74 N 59 0 W 66 N 58 50 W 47 N 58 41W COMPUTATION DATE: 17-NOV-92 PAGE 7 ARCO ALASKA, INC. D.S. 14 - 43 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY: 11-NOV-1992 KELLY BUSHING ELEVATION: 74.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8289 67 7974 O0 7900 O0 29 20 8404 8519 8633 8747 8861 8974 9087 9198 9309 49 8074 08 8174 37 8274 76 8374 52 8474 77 8574 49 8674 91 8774 39 8874 O0 8000 O0 8100 O0 8200 O0 8300 O0 8400 O0 8500 O0 8600 O0 8700 O0 8800 O0 29 26 O0 29 5 O0 29 2 O0 28 53 O0 28 IT O0 27 37 O0 27 6 O0 25 26 O0 24 52 N 56 15 W 1268 12 N 56 32 W 1324 N 56 34 W 1380 N 57 37 W 1435 N 58 29 W 1491 N 58 5 W 1545 N 57 41W 1598 N 57 25 W 1650 N S6 34 W 1699 N 55 11W 1746 52 47 79 32 56 71 72 84 78 1.17 0 25 0 47 0 74 0 60 0 3O 0 67 1 O0 1 66 0 74 661 78 N 1081 88 W 1268 23 N 58 33 W 692 723 754 783 811 840 867 894 921 92 N 1128 86 N 1175 16 N 1221 32 N 1269 97 N 1315 19 N 1360 92 N 1404 81N 1445 09 N 1484 92 W 1324 55 W 1380 84 W 1435 10 W 1491 16 W 1545 20 W 1598 20 W 1650 32 W 1699 24 W 1746 61 N 58 28 W 54 N 58 23 W 85 N 58 19 W 38 N 58 19 W 62 N 58 19 W 77 N 58 18 W 78 N 58 17 W 89 N 58 14 W 82 N 58 11W 9419.25 8974.00 8900.00 24 7 9528.56 9074.00 9000.00 23 39 9637.66 9174.00 9100.00 23 33 9700.00 9231.15 9157.15 23 33 N 53 36 W 1792.19 N 52 40 W 1836.19 N 52 22 W 1879.61 N 52 22 W 1904.41 0 73 0,61 O. O0 O. O0 947.66 N 1521.18 W 1792.21 N 58 5 W 974.02 N 1556.56 W 1836.19 N 57 58 W 1000.64 N 1591.12 W 1879.61 N 57 50 W 1015.85 N 1610.84 W 1904.41 N 57 46 W ARCO ALASKA, INC. D.S. i4 - 43 PRUDHOE BaY NORTh SLOPE, ALASKA MARKER LAST READING GCT 'FID COMPUTATION DATE: 17-NOV-92 PaGe 8 DATE OF SURVEY: 11-NOV-1992 KELLY BUSHING ELEVATION: 74.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 19' FNL A 1280' FEL, SEC09 TION R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM'KB SUB-SEA NORTH/SOUTH EAST/WEST 9560.12 9102.92 9028.92 981.72 N 1566.59 W 9700.00 9231.15 9157.15 1015.85 N 1610.84 W ARCO ALASKA, INC. D.S. 14 - 43 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER LAST READING GCT ID COMPUTATION DATE: 17-NOV-92 PAGE 9 DATE OF SURVEY: 11-NOV-1992 KELLY BUSHING ELEVATION: 74.00 FT ENGINEER: D. WARNER ************ STRATIGRAPHIC SUMMARY .~**~*~ SURFACE LOCATION = 19' FNL & 1280' FEE, SEC09 TION R14E MEASURED DEPTH 1-VD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 9560.12 9102.92 9028.92 981.72 N 1566.59 W 9700.00 9231.15 9157.15 1015.85 N 1610.84 W FINAL WELL LOCATION AT ID: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9700.00 9231.15 9157.15 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 1904.41 N 57 46 W DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. ~ELD PRUDHOE BAY WE~ D.$. 14-43 COUNTRY USA nUN 1 D~TE L~)(:~ED 11 - NC)~ - 92 DEPTH UNiT FEET WELL' D.S. 14-34 (19' FNL, 1280' FEL, SEC 9, TION, R14E) HORIZONTAL PROJECTION ~o L.~.-.~i].i:: :: i::.}:: }::.;:: ::i::.i:;i::.i:i'::i::.i~:-i;:i:: :: i:: ;:: ;:: i ..... ;---i--~---i ..... !.--}--i-..:: .... i...}--!...i ...... !---}-+-i ..... }--}-'i-~ ..... ?--!...!---~-""i'-?--~--'i .... ~-.!.-?'i ..... j---.¢--;"¢ .... ~"i ..... :-'~ ..... ~ ..... :~ i:i:i: :-.~..-!--.~--i ..... i--~- ..... >"I .... 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'.:!:i:::i::!:: i::.:::~: ~:: !:: ::~::'~:::~::~::: ::i::i::'i::i:: ::::i::'i:::i:::~-.,-..~.-i..':.-! ..... i---!---i ..... ~-~ ~'i-'i--'}": ...... i-' !-:.':L:.i::.i::!::: :::!::i !'ii :: ~.: i:: .... i. '.: i:: i::. .... !--!--i--!'-i---! ..... i"!-'!"! .... ...... i'"?'?i .... i"i-iiii i iiiiiii! ii. ..... .... i.. i .:....!.. --~-.!---!---! .... !---!--!'-} .... !--!-'!-'~--I-->-:"~'!"i"!"~"i'-! .... i"'i"!"!"l"Z]il ill ~]i]]ZiiTi]]]i]~Li...~. .... L!.--.i..!- ..... i--.i---~-.~:--I--::.-i..~,--i .... i-.}--}-'! .... !-.i-.}-.~ .... i ..... I .... , ?!-:i'T"!'"i'"i"!"i i ii'~ ii':i i i;:]Li..i...i ...... L.LL.L~..i...i...i...L.!...i...!....i...i. ..... i...i..-i...i ..... 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SECT. 0 .00 463 463.00 977 977,00 1476 1475.97 1982 1981,91 -74 389 9O3 1401 1907 ,00 ,00 .00 ,97 .91 0 0 N .00 E .00 0 8 N 66,38 W ,03 0 15 S 30.12 W .05 0 43 S .3O E ,10 1 2 S 28,06 E ,10 4 11 .OON .OOE .00 .23N .52W .56 .49S 1.66W 1.15 .57S 2.19W -.55 .80S .01W -6.21 2456 2456.21 2961 2961.43 3171 3171.27 3488 3487.76 3964 3963,46 2382 2887 3097 3413 3889 .21 ,43 ,27 ,76 ,46 1 15 S 47,83 E ,09 1 22 S 46,55 E .02 2 57 S 32.26 E .79 1 5 S 44,15 E .60 0 19 S 57.47 E .16 19,07S 5.85E 26.93S 14,32E 33,24S 19,04E 42,32S 25.50E 46.30S 29.81E -15.03 -26.37 -33.70 -43.98 -49.74 4473 4472.55 4885 4884.73 4982 4981,54 5075 5074.73 5170 5169,51 4398 4810 4907 5000 5095 .55 .73 .54 ,73 ,51 0 16 S 58,48 E .01 0 39 S 68.75 E .09 1 0 N 31,35 W 1.64 4 0 N 42,06 W 3,24 5 24 N 46.64 W 1,51 47,74S 32.11E 49,13S 35.18E 48.60S 35.25E 45,47S 32,64E 39.93S 27,16E -52.45 -55.79 -55.58 -51 .71 -44.13 5267 5265.39 5363 5360,07 5459 5454,43 5554 5547,08 5647 5637,21 5191 5286 5380 5473 5563 ,39 ,07 ,43 ,08 ,21 7 19 N 47,76 W 2.00 9 51 N 48,40 W 2,64 11 55 N 53,68 W 2,38 13 34 N 53,28 W 1,74 15 37 N 54,43 W 2.22 32,68S 19.30E 23.13S 8,64E 11,78S 5,51W ,69N 22,35W 14,52N 41.31W -33,63 -19.54 -1 ,53 19.35 42.75 5744 5730.64 5838 5819.17 5934 5907.22 6O28 5992.84 6122 6075,90 5656 5745 5833 5918 6001 .64 .17 .22 .84 .90 18 8 N 57.09 W 2.70 21 14 N 58.37 W 3.33 23 34 N 60.03 W 2.53 26 22 N 59.46 W 2.98 29 10 N 60,35 W 3.03 30,43N 64.76W 47,32N 91,56W 65,88N 122.75W 85.98N 157,19W 107.90N 195.04W 71.07 102.75 139.04 178.89 222.62 6217 6158,15 6313 6240,22 6408 6321,18 65O3 6402,87 6598 6485,50 6084 6166 6247 6328 6411 .15 ,22 .18 ,87 ,50 30 28 N 59.59 W 1.42 31 43 N 59.94 W 1.33 31 7 N 60.78 W .78 30 4 N 60.62 W 1.11 30 14 N 61.81 W .65 131,50N 235.86W 156.43N 278.64W 180,90N 321.64W 204.55N 363.77W 227,66N 405.86W 269.75 319.24 368.68 416.95 464.89 6692 6566,55 6789 6650,45 6885 6733.2O 6980 6816,25 7076 6899,83 6492 6576 6659 6742 6825 ,55 ,45 .20 ,25 ,83 30 9 N 62.91 W .60 30 22 N 60.93 W 1.05 29 32 N 58.02 W 1.75 30 8 N 58.27 W .63 29 6 N 57,68 W 1.11 249 · 55N 447 . 64W 272,59N 490.83W 296,80N 531 , 92W 321 ,95N 572,39W 347 , 15N 612 . 69W '.~ ;; .... . ........ ..; 511.94 560,79 608.46 656.11 703.64 SF RY-SUN DR]:LL:[NG SERVZCES ANCHORAGE ALASKA PAGE PRUDHOE BAY DR:[LLZNG PBU/14-43 500292229600 NORTH SLOPE COMPUTATZON DATE: 11/ 3/92 DATE OF SURVEY: 102992 MWD SURVEY JOB NUMBER: AK-ND-921026 KELLY BUSHZNG ELEV. = 74.00 FT. OPERATOR: ARCO ALASKA ZNC TRUE SUB-SEA COURS COURSE HEASD VERTZCAL VERTZCAL ZNCLN DZRECTZON DEPTH DEPTH DEPTH DG MN DEGREES DLS TOTAL RECTANGULAR COORDZNATES VERT. DG/IO0 NORTH/SOUTH EAST/WEST SECT. 7198 7005,65 6931.65 29 21 N 57,42 W ,23 7293 7088,67 7014.67 28 40 N 57.24 W .72 7389 7173,77 7099,77 27 49 N 58,72 W 1,14 7484 7257,13 7183,13 27 58 N 57,17 W .79 7579 7341,75 7267.75 27 32 N 55.23 W 1.05 378.92N 662.66W 762,85 403.79N 701.43W 808,91 428.04N 740,20W 854,64 451,47N 777.61W 898.78 476,24N 814,63W 943.30 7677 7428.04 7354.04 27 32 N 54.54 W .33 7767 7508,36 7434.36 26 39 N 54.96 W 1.01 7863 7594,48 7520.48 26 24 N 57,33 W 1.13 7958 7679,59 7605,59 27 6 N 54.60 W 1,48 8054 7764.93 7690,93 26 27 N 54.21 W .69 502.13N 851.45W 988.24 525.86N 885,03W 1029.28 549.82N 920.73W 1072.24 573.84N 956.27W 1115.10 598,91N 991.29W 1158.08 8149 7849.17 7775,17 27 46 N 55,46 W 1,51 8244 7933.56 7859,56 28 57 N 55,85 W 1.25 8340 8016.58 7942,58 29 47 N 56.82 W 1,02 8435 8099.37 8025,37 29 32 N 55,84 W .58 8530 8182,37 8108,37 29 17 N 55,80 W ,25 623,74N 1026.56W 1201,14 649.44N 1064.17W 1246,65 675.34N 1103.07W 1293,36 701,48N 1142,32W 1340.50 727.78N 1181.04W 1387.26 8720 8347,48 8273.48 29 12 N 56.75 W .25 779.12N 8910 8514,78 8440.78 28 12 N 57.82 W .58 828.64N 9035 8624,66 8550.66 27 41 N 58.51 W ,49 859.39N 9092 8674.96 8600.96 27 41 N 58.51 W ,00 873,18N 1257.94W 1479.68 1335.01W 1571.27 1384,54W 1629.57 1407.05W 1655.97 THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF THREE-DZMENSZON MZNZMUM CURVATURE METHOD. HORZZONTAL DZSPLACEMENT = 1655,97 FEET AT NORTH 58 DEG, 10 MZN, WEST AT MD = 9092 VERTZCAL SECTZON RELATZVE TO WELL HEAD VERTZCAL SECTZON COMPUTED ALONG 301,82 DEG. SF .RY-SUN DRTLL~'NG SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY PBU/14-43 500292229600 NORTH SLOPE COMPUTATION DRILLING DATE: 11/ 3/92 DATE OF SURVEY: 102992 JOB NUMBER: AK-HD-921026 KELLY BUSHING ELEV. = 74.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-T DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFEREN VD VERTICAL CE CORRECTION 0 .00 -74.00 .00 N ,00 E , 1000 1000.00 926.00 ,58 S 1.71 W , 2000 1999,91 1925,91 12.09 S .14 E , 3000 2999.67 2925,67 27.56 S 14,99 E . 4000 3999.23 3925.23 46.41 S 29,98 E . O0 O0 .00 09 .09 33 .24 77 .45 5000 4999,19 4925.19 48,27 S 35,03 E . 6000 5967,06 5893,06 79.62 N 146,38 W 32. 7000 6832,88 6758,88 327.02 N 580.60 W 167, 8000 7716.24 7642.24 584.70 N 971,55 W 283, 9000 8593,49 8519.49 850.85 N 1370.59 W 406, 81 .04 94 32.12 12 134.18 76 116.65 51 122.75 9092 8674,96 8600,96 873,18 N 1407,05 W 417,04 10,54 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ;RY-SUN DRZLLZNG SERV]:CES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG PBU/14-43 500292229600 NORTH SLOPE COHPUTATZON DATE: 11/ 3/92 DATE OF SURVEY: 102992 JOB NUMBER: AK-MD-921026 KELLY BUSHZNG ELEV. = 74.00 OPERATOR: ARCO ALASKA ZNC FT, ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASD DEPTH : 0 74 174 274 374 TRUE SUB-SEA TOTA VERTZCAL VERTZCAL RECTANGULAR DEPTH DEPTH NORTH/SOUTH .00 -74,00 .00 N 74.00 .00 .00 N 174.00 100,00 .00 N 274.00 200.00 .04 N 374.00 300.00 .14 N COORDZNATES EAST/WEST MD-TVD VERTZCAL DZFFERENCE CORRECTZON .00 E .00 ,00 E .00 .00 ,00 E .00 .00 .10 W .00 .00 .32 W ,00 .00 474 474,00 400.00 .24 N ,54 W .00 .00 574 574,00 500,00 .34 N .77 W .00 ,00 674 674.00 600.00 .43 N ,99 W .00 ,00 774 774.00 700.00 .27 N 1.21 W ,00 .00 874 874.00 800,00 .10 S 1,43 W .00 .00 974 1074 1174 1274 1374 974.00 900,00 .48 S 1074.00 1000,00 .86 S 1174.00 1100,00 1.24 S 1274.00 1200,00 2.03 S 1374.00 1300,00 3.29 S 1,65 W ,00 ,00 1.87 W .01 ,00 2.09 W .01 .00 2.20 W .01 ,00 2,19 W ,02 .01 1474 1474.00 1400,00 4.54 S 2.19 W .03 ,01 1574 1574.00 1500.00 5.80 S 2.18 W ,03 .01 1674 1674.00 1600.00 7.06 S 2,17 ~ .04 .01 1774 1774,00 1700.00 8.47 S 1,78 W ,05 .01 1874 1874.00 1800,00 10.07 S .93 N .07 .02 1974 1974.00 1900.00 11.67 S .08 W ,09 .02 2074 2074.00 2000.00 13.28 S .78 E .10 ,02 2174 2174.00 2100.00 14.88 S 1,63 E ,12 .02 2274 2274.00 2200.00 16.40 S 2.90 E .14 .02 2374 2374,00 2300.00 17,87 S 4.52 E ,16 .02 2474 2474.00 2400.00 19.33 S 2574 2574.00 2500.00 20.80 S 2674 2674,00 2600.00 22,26 S 2774 2774,00 2700.00 23,85 S 2874 2874,00 2800.00 25,49 S 6.14 E .19 .02 7.76 E .21 .02 9.37 E .23 .O2 11.07 E .26 .03 12.80 E .29 .03 2974 2974,00 2900,00 27.13 S 3074 3074.00 3000,00 29.04 S 3174 3174,00 3100,00 33,36 S 3274 3274.00 3200.00 37.73 S 3374 3374,00 3300.00 40,76 S 14.54 E ,32 .03 16.37 E .36 .04 19.11 E ,49 .13 21,87 E ,62 .13 23.99 E ,70 .08 SF ,RY-SUN DRTLLTNG SERV]:CES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG PBU/14-43 500292229600 NORTH SLOPE COMPUTATZON DATE: 11/ 3/92 DATE OF SURVEY: 102992 JOB NUMBER: AK-MD-921026 KELLY BUSHZNG ELEV. = 74.00 OPERATOR: ARCO ALASKA ZNC FT. ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTZCAL VERTZCAL RECTANGULAR COORDZNATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DZFFERENCE VERTZCAL CORRECTZON 3474 3474.00 3400.00 42.13 S 25,32 E .72 3574 3574.00 3500.00 43.49 S 26.65 E .74 3674 3674,00 3600.00 44,86 S 27.97 E ,76 3774 3774,00 3700.00 45.71 S 28.89 E .77 3874 3874.00 3800,00 46,02 S 29.37 E .77 .O2 .02 .02 .01 .00 3974 3974.00 3900,00 46,33 S 29,86 E .77 4074 4074,00 4000.00 46.64 S 30.35 E .77 4174 4174.00 4100.00 46,95 S 30,83 E .78 4274 4274.00 4200,00 47.23 S 31,28 E ,78 4374 4374,00 4300.00 47,49 S 31.70 E .78 .00 .00 .00 .00 .00 4474 4474.00 4400.00 47.74 S 32.11 E .78 4574 4574.00 4500.00 48,00 S 32.53 E .78 4674 4674.00 4600,00 48.25 S 32.95 E .78 4774 4774.00 4700.00 48.66 S 33,99 E ,79 4874 4874.00 4800.00 49.08 S 35.06 E .79 .00 .00 .00 .01 .01 4974 4974.00 4900.00 48.71 S 35.32 E .81 5074 5074.00 5000.00 45.50 S 32.66 E ,91 5175 5174,00 5100.00 39.64 S 26.85 E 1,25 5275 5274.00 5200,00 31.93 S 18.48 E 1.91 5377 5374,00 5300.00 21,52 S 6.83 E 3,15 .01 .10 .35 .66 1 .24 5479 5474.00 5400,00 9.34 S 8.84 W 5.12 5581 5574.00 5500.00 4.57 N 27.55 W 7.81 5685 5674.00 5600.00 20.62 N 50.03 W 11.57 5790 5774.00 5700.00 38.43 N 77,30 W 16,75 5897 5874.00 5800.00 58,65 N 110,23 W 23.98 1 .97 2.69 3.76 5.18 7.22 6007 5974.00 5900.00 81.32 N 149,27 W 33,71 6120 6074.00 6000,00 107.38 N 194.12 W 46,38 6235 6174.00 6100.00 136.22 N 243,90 W 61.75 6352 6274,00 6200.00 166.89 N 296.71 W 78,93 6469 6374.00 6300.00 196.34 N 349,20 W 95,05 6585 6474.00 6400.00 224.50 N 399.95 W 111.27 6700 6574.00 6500.00 251.52 N 451.50 W 126.98 6816 6674,00 6600.00 279,30' N 502.89 W 142.79 6931 6774,00 6700.00 309,07 N 551,58 W 157,94 7047 6874,00 6800.00 339,46 N 600.53 W 173.35 9,73 12.67 15.38 17.18 16.72 15.62 15.71 15.82 15,15 15.41 .RY-SUN DRTLL:[NG SERVTCES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG PBU/14-43 500292229600 'NORTH SLOPE COMPUTATZON DATE: 11/ 3/92 DATE OF SURVEY: 102992 JOB NUMBER: AK-ND-921026 KELLY BUSHZNG ELEV. = 74,00 FT. OPERATOR: ARCO ALASKA ZNC ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH T MEASD VERTZ DEPTH DE RUE SUB-SEA TOTAL CAL VERTZCAL RECTANGULAR COORDZNATES MD-TVD VERTZCAL PTH DEPTH NORTH/SOUTH EAST/WEST DZFFERENCE CORRECTZON 7161 6974 7276 7074 7389 7174 7503 7274 7616 7374 ,00 6900,00 369,34 N 647,66 W 187,87 14.52 ,00 7000,00 399,44 N 694.68 W 202,40 14.53 ,00 7100,00 428,10 N 740,31 W 216,00 13,59 ,00 7200,00 456.33 N 785,14 W 229,17 13.17 ,00 7300,00 485,84 N 828,45 W 242.07 12.90 7728 7474 7840 7574 7952 7674 8064 7774 8177 7874 ,00 7400,00 515,94 N 870,88 W 254,80 12.73 ,00 7500,00 544,33 N 912,.16 W 266.65 11.85 ,00 7600.00 572,18 N 953.94 W 278.55 11,90 ,00 7700,00 601,55 N 994.95 W 290.56 12.01 ,00 7800,00 631,15 N 1037.33 W 303.14 12.58 8291 7974 8406 8074 8521 8174 8635 8274 8750 8374 ,00 7900,00 662,01 N 1082,76 W 317,23 .00 8000,00 693,41 N 1130.42 W 332.38 ,00 8100,00 725,14 N 1177,16 W 347,22 ,00 8200,00 756,59 N 1223,60 W 361,88 ,00 8300,00 787,24 N 1270,34 W 376,44 14,09 15.15 14.85 14.66 14,56 8864 8474.00 8400.00 816.99 N 1316,50 W 390.53 8977 8574.00 8500,00 845,49 N 1361,86 W 403.98 9092 8674.96 8600.96 873.18 N 1407.05 W 417.04 14.09 13,45 13,06 THE CALCULATZON PROCEDURES USE A LZNEAR ZNTERPOLATZON BETWEEN THE NEAREST 20 FOOT MD (FROM MZNZMUM CURVATURE) POZNTS COMPLETION DATE it /, ~ /~'~- CO. CONTACT ~f'~ '~.~ check off or list data as it is received.*list received date for 407. if not rec]uired list as NFl 40? I* I)Z~ i¢~ drilling history, v,'~] survey!~. ! we. tests O I core de~.Criptiol]i~l~ cored interval~ core analysis ~.. dry, ditch intervals digital data LOG I~P~ RUN iNTERVAL[; SCALF NO. {to the nearestfoot~ , {inch1100'} · iO} " 1:,1 141 171 ...... i i ii i i i i i i i i i i i ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-18-92 11-13A 11-1B,4~ 11-13A 11-112-92 11-13A 11-22-92 ~ ~/~'-%-~ 1~=~ 11-1~ ~1~ 11~ ~1~ 11-11~ fl7-m 11-1~ Ihml Burst TDT-P (Starx) Run L ~' ~ Burst TDT-P (B~e~J Run L ~' USIT (~~o~ / ~r ~ L F ~ (~t)- ~r ~ L ~ ~/~~~ ~ L ~ ~ ~ ~lor ~ L ~ ~ (~~t & ~ ~r ~ L ~ ~~ ~r ~ L ~ ~ (~m~t & ~ ~~r ~ 1, ~ Please sign and return 'the attached copy as receipt of dat~ RECEIVED BY ~_~__~ Have A Nice Dayi Sonya Wallace DEC 3 0 1992 APPROVED~~/ ATO-1529 Ala~a Off & Gas Cons. Commission ~# 92265 Anchorage # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL PB WELL FILES R&D #BPX # STATE OF ALAS~ TEXACO * The correct API# for 11-13A is 50-029-21229-01. WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 DECEMBER 29, 1992 MARION SLOAN BP EXPLORATION ALASKA INC. P O BOX 196612 ANCHORAGE, ALASKA 99518-6612 RE: 92-0108 PRUDHOE BAY UNIT DS14-43 COMPLETION REPORT 92-0102 PRUDHOE BAY UNIT S-33 COMPLETION REPORT DEAR MARION SLOAN, OUR FILES INDICATE THAT ARCO ALASKA AND BP EXPLORATION ALASKA INC. IS THE OPERATOR OF THE REFERENCED WELLS. THESE WELLS HAVE REPORTED PRODUCTION TO US AND WE HAVE NOT RECEIVED THE APPROPRIATE COMPLETION REPORTS (407 FORMS) TO DATE. NOVEMBERS MONTHLY PRODUCTION PREPORTS INDICATE THAT THESE WELLS ARE OIL PRODUCER FOR THE YEAR 1992. WE HAVE NO PAPER WORK SHOWING THE COMPLETIONS FOR THE WELLS OR PLUGGING AND ABANDONMENT OF THE ORIGINAL WELL. I AM FORWARDING THIS LETTER AS A RECORD FOR YOU AND ME. THANKS FOR YOUR QUICK RESPONSE ON THESE REPORTS. SINCERELY, STEVE MC MAINS ARCO ~1_~Irs; Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE:. 11-20-92 ~ ~-¢~4/ 11-1A~p-~/> 11-3-92 # z-~/? 12-10A~-~ 10-28-92 # s'¢~ 14-437~ o~ 11-3-92 #5'~ 17-1~;~/// 10-31-92 ARCO MAGNETIC TAPE(S) WITH LISTINGS DLL/AC/GR Run 1 DLL/C-ZDL/GR Run 1 DLL~/~/~ Run 1 DIFL/AC/CN/~ R,m 1 BCS/DTE Run 1 Please sign and return the attached copy as receipt of data. RECEIVED BY__~~. ~ Have A Nice Day~ Sonya Wallace ATO-1529 Atlas Atlas Aths Atlas Sch APPROVED :~ Trans# 9225~-~-''--- CENTRAL FILES (CH) CHE~ON D&M # BOB ~ (OH/GC~ # EXXON MARATHON MOBIL # ~.T.TPS PB WELL FILES R&D #BPI[ ~' # STATE OF ALAS~ TEXACO RECEIVED NOV 1 9 1992- Alaska 011 & Gas Cons. Commission Anchorage ARCO ~Ahska, Inc~ P.O.Box 1~ Anchorage, Alaska 99510 DATI~ 11-20-92 REFERENCE: ARCO OPEN HOLE FINALS 11-lA 11-3-92 8$TVD Run 1, 1"&2' ~/ I ll-lA 11-3-911 D~/GR R~ 1, ~'~ ~ 11-~ 11-3-92 ~L/C~/GR ~w) l~ 1, 2'~ ~ 11-~ 11-3-63 ~L/C~/GR ~ro) R~ 1, ~ -/ } 11- ~ 11-3-93 BH ~ffi~ R~ 1, ~ / ~11-~ 11/1-2/~ _GR~OP. ~ ~ R~ 1, 5'~ ~ ~11-~ 11/1-2/~ GR~OP w~ R~ 1, 5~ ~ /12-10A (12-10A 10-28-93 BHCA/GR R~ 1, ~'~ ~ 1~ 11-3-92 8S~ R~ 1, 1'~ ~ 1~ 11-3-92 BHCA/GR R~ 1.2'~ / 14~ 11-3-92 C~/GR/~L R~ 1, 2'~ ~ ~17-15 10/1~14/~ D~/GR ~ R~ ~ 2'~~ ~ ~17-15 10/1~14/~ D~/GR ~P R~ ~'~'~ ~ 10-31-92 8S~ Color R~ 1, 1"~ ~ g17-19 ~17-19 10-31-92 PISFL Color R~ 1,2'~ Please sign and return the attached copy as receipt of data. RECEIYED BY ~'~__~~.? Nice Sonya Wallace ATO-1529 Atla~ Atlas Atles Atla~ Ana Aha Arias Atla~ Arias Arias Arias Teleco Teleco Sch Sch Sch # CENTRAL FILES # _aI:r~-VRON #D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # pHr~IxpS ' # PB WELL FILF~ R&D #BPX # STATE OF ALASKA # TEXACO RECEIVED NOV 1 9 1992 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 October 20, 1992 Michael Zanghi Drilling Engineer Supervisor ~LRCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 14-43 ARCO Alaska, Inc. Permit No: 92-108 Sur. Loc. 19'SNL, 1280'WEL, Sec. 9, T10N, R14E, UM Btmhole Loc. 4277'SNL, 2941'WEL, Sec. 4, T10N, R14E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting 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 must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill I-IJlb. Type of well. Exploratory l-I Stratigraphic Test I-I Development Oil [] Re-Entry [] Deepen []l Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska,/nc. KBE = 74'feet Prudhoe Bay Fie/d/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL.2.85'¢1 ,'2, ~ .~ 1,2.. 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(eec 2o ^^c 25.025) 19' SNL, 1280' WEL, SEC. 9, TION, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well number Number 4390' SNL, 2723' WEL, SEC. 4, TION, R14E, UM DS 14-43 U-630610 At total depth 9. Approximate spud date Amount 4277' SNL, 2941' WEL, SEC. 4, TION, R14E, UM 10/20/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(MDa,dTVD) property line ADL 28312/2337feet DS 14-31/60'@ Surface feet 2560 9695'MD/9223'TVCIeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 5ooofeet Maximum hole angle~8.34 o Maximum surface 3330psig At total depth (TVD) 8800'/4390Psig 18. Casing program Setting Depth s;ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# BTC Weld 80' Surface Surface 110' 110' 2000# Coldset II 13-1/2" 10-3/4" 45.5~ NT8OLHE BTC 3175' 35' 35' 3210' 3210' 450 cu ft "G"/1930 cu ft AS ill 9-7/8" 7-5/8" 29. 7# NT95HS NSCC 9049' 35' 35' 9084' 8685' 1300 cu fl Class "G" 6-3/4" 5-1/2" 17# NT80S FL4S 761' 8934' 8380' 9695' 9223' 142 cuft Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural C ondactor ~ ~ ¢" ~ I '~u~ ~,: Surface _ ~-~i~ . .. !;~, ~ Intermediate Production [)0'~ 1. ;~ ,.. ,~ ~ ~ Liner .... Y-- ,-, ,o rjOrf~[~.~igs\o~ Perforation depth: measured /-t!dS/..~ 0[1 & (:~a,3 ,,(),'to. true vertical A~ch0r~ge 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] !Drilling 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 Title Drilling En£ineer Supervisor Date '-/Commission Use Only Permit_Number IAPI number _ IApprov_al date .,~ x' ~lSee cover letter ¢2 -/"0 ~ 150- 0,~.. ? - ~-~ ,2 ZT, ?,~' ! //~ - c~U "~"'~-~fomother requirements Conditions of approval Samples required [] Yes ~No Mud Icg required []Yes/[~No Hydrogen sulfide measures [] Yes ~__ No Directional survey requ~recl ~r Yes [] "No Required working pressure for BOPE []2M; D3M; 1-15M; D1OM; F'I15M; Other: by order of _Appr°wd ...... by O ioio*' Commissio,e; ,,,, comm, sion D te Form 10-401 Rev. E~2d-v.1i-o85¢V,~ dohnston Submit in triplicate . 10. 11. 12. 13. DS14-43 Operations Summary 1. MIRU drilling rig. NU diverter and function test same. 2. Spud well and drill a 13 1/2" hole to 3210' tvd/'md. 3. Set 10 3/4" casing and cement same. Test casing to 2500 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. 4. PU a 9 7/8" bit and BHA and drill 10' of new hole and pedorm leakoff test. Continue drilling a vertical 9 7/8" hole to 5000'tvd/md. 5. At 5000'tvd/rnd, build angle at 2.5 degrees/100'md in the N 57.8° W direction to 28.34 degrees at 6087'tvd/6133' md (EOC). *Hold angle at 28.34degrees to 8685'tvd/9084' md (7 5/8" casing set point). * Prior to reaching the 7 5/8" casing set point, run OH logs as programmed. 6. Set 7 5/8" casing and cement same. 7. PU 6 3/4" BHA and test casing to 3000 psi. Drill 10' of 6 3/4" hole and perform formation integrity test to 12.5 ppg EMW. 8. Continue drilling 6 3/4" hole in the N 57.8° W direction to 9225' tvd/9697' md while maintaining a 28.34 degree hole angle. Run wireline logs as programmed. Set 5 1/2" liner and cement same. Circulate well to brine. Run 4 1/2" tubing and packer assembly. NU tree and test to 3000 psi. Release Drilling Rig. Rig up wireline unit(s) to run gyro and pedorate well. DS 14-43 Operations Summary-State Permit CKH October 13, 1992 1:50 PM DS14-43 Operations Summary-continued NOTES: a. Excess non-hazardous fluids developed from well operations may be pumped down the 10 3/4" x 7 5/8" annulus. The annulus will be left with a non- freezing fluid during any extended period. b. Wells within 200' of the proposed well are: DS14-33: 46' at 1900'. DS14-32: 46'at 2800'. c. The drilling fluid program and fluid sudace system will conform to the regulations set forth in 20AAC25.033. d. The maximum surface pressure is based upon the BHP and a full column of gas to TD (0.10 psi/E). e. Based upon previous logs obtained from DS14 wells, no productive zones are anticipated above 4000' tvd. f. No hazardous levels of H2S are anticipated in this well. DS14-43 Operations Summary-State Permit October 13, 1992 1:50 PM 'P UDHOE BAY DRILLING CREATED BY : dONES For: C HURST iDATE PLOTTED : 13--OCT--g2 ?LOT REFERENCE IS 4-3 VERSION #2. !COORDINATES ARE IN FEET REFERENCE SLOT iTRUE VERTICAL DEPTHS ARE REFERENCE WELLHEAD. TELECO A Baker Hughes company g 0 4OO ,, 8OO O 12oc _ 1600- - 2000-_ _ 2400_ - =C 2800_ O_ - U 3200_ 3600_ _ 4000_ _ ~oo_ 5200_ - 5000- I - J6400_ V - 6800- - 7200- - 7600_ - 8000_ _ 840O_ _ 880O- _ 9200- Structure : D.S. 14 Well : 4.5 Field : Prudhoe Bay Location : North Slope, Alaska WELL PROFILE DATA .... POINT .... MD INC DIR TVD NORTH EAST jTIE ON 0 0.00 302.17 0 0 0 5000 0.00 302.17 5000 o o iEND OF BUILD 6134- 28.34-302.~? 6088 146 -232 !TARGET 9151 28.34 302.17 8744 gog -1445 iEND OF HOLD 9491 28.34 302.17 9043 995 -1582 iEND OF HOLD 9546 28.34 302.17 9091 }009 -1603 "-ND OF HOLD 9696 28,34 302.17 9223 1047 -1664 1 o 3/4- CSG T-5 K-15 KOP 2.50 TOP UGNU 7.50 < - - W e s f SCALE 1 : 75,00 1800 1650 1500 1350 1200 1050 900 750 600 450 300 150 0 150 f I I I I I I I I I I I I I I I I I I I I I I I I I J_l 2o0 r 1050 900 750 < 600 J 450 OZ 300 ~ L150 K_ I 2.50 17.50 BUILD 2.5 DEG / 100' 22.50 lo K-5 B/ HRZ - LCU - KINGAK SHALES SAG RIVER X. JURASSIC B 7 5fi8'- C~G-'IST ','%.%- SHUBLIK 7 5/8 CSG PT ~ TARGET - TOP SADLEROCHIT G/O CONTACT X O/W CONTACT HOT ~, "~"~ TD - 5 1/2 LINER I 2oloo I I I I I 2100 Io/ 400 800 1 16 0 AVERAGE ANGLE 28.34 DEG Mud Program for Slimhole WelI-PBU-EOA Date Well Field Type Depth, tvd 10/13/92 DS14-43 Prudhoe Bay Slimhole Density, ppg Funnel Vis PH YP, #/ft Int Gel Spud 8.5 300 9 40-60 30-60 to to to to to to 10 3/4" csg point 9.5 130 1 0 20-40 15-20 SET 10 314" CASING Density, ppg Funnel Vis PH Depth, tvd 10 3/4" csg pt <9.4 9.5-10 to to to 5000' 9.8 9.5-10 5000' 9.8 9.5-10 to to to 7 5/8" csg pt 1 0 9.5-10 For casing SET 7 5/8" CASING Depth, tvd 7 5/8" csg pt to TD 10 min Gel FL cc/30min 60-80 15-25 to to 20-30 15-25 SET 5 1/2" LINER YP, #/ft Int Gel 10 min Gel 10 5 10 to to to 15 10 20 10 to 15 5 to 10 Hardness mg/I <200 to <200 FL cc/30min Hardness mg/I 1 0 no control to to 1 5 no control 1 0 lowered to 6cc no control to by K10 shale to 2 0 no control 10 9.5-10 8 to 12 2 to 5 4 to 10 Density, ppg Funnel Vis PH 8.9-9.1 8 to 9 same as above no control YP, #/ft Int Gel 10 min Gel FL cc/30min Hardness mg/I 8 to 13 5 to 10 7 to 15 <6cc <4000 Mud Type GeI-Benex Spud Mud GeI-Benex Spud Mud Mud Type LSND Gel/Water System LSND Gel/Water System LSND Gel/Water System LSND Gel/Water System LSND Gel/Water System Mud Type LSND Gel/Water System 1 0/13/92 PRUDHOE BAY DRILLING Sfrucfure : D.S. 14 Field : Prudhoe Bay Well: 43 LocafJon : Norfh Slope, Alaska SCALE 1 : 10.00 <---- Left 360 3'~-0 320 300 280 260 2~-0 220 200 ! 80 160 140 120 1 O0 80 60 40 20 40a _ Righf --> 0 20 4-0 60 80 100 120 140 160 180 200 220 24.0 260 280 300 320 340 360 . 380 . 020 · 200 4o: _ ~o~ ~o. · 8o ~o - -20 ii 20 ~,~o ~,~o /x I I 360 340 320 300 280 260 240 220 200 lO0 160 $ 40 120 100 80 60 40 20 0 SCALE 1 : 10.00 <-- -- Le ff · . " 400 20 ¢0 60 80 100 120 140 160 180 200 220 240 260 200 300 320 340 360 Right --> DOYON 9 13 5/8" 5,000 psi Stack .33 7.75 4.30 F RKB I I I HYDRIL 5.11 2.00 2.50 3.13 2.33 GROUND LEVEL I I PIPE RAM BLIND RAM KR TO RF RI~ ~ FI 9.58 13.86 R 15.88 MUD CROSS PIPE RAM 20.41 I24.79 MUD CROSS TBG SPOOL ~ASE FLG ~ 27.12 28.45 30YON DRILLING RIC '#9 MUD SYSTEM BBLS TRIP TANKS .- DESILTER PIT 97 BBLS 97 BBLS PITJ. PIT 36 BBLS 36 BBLS SHAKER .... DESANDER SHAKER MUD C LW. ANER SUCTION PIT 448 BBLS MIX PIT 122 BBLS -- DOYON 9 DIVERTER SYSTEM ARCO ALASKA, INC. FILL-UP LINE f' RISER FL. OWi INE 20" 20(~ PSi DIVERTER 1~' BAIL VALVE 1Ct' BALL VALVE ! J c6~oudroR ! NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS THIS IS A VARIANCE FROM 20AAC25.035. RIG MODULES RESERVE PIT DIVERTER LINES DISCHARGE 100 Fr. FROM RIG IGNITION SOURCE. ALL TURNS ARE TARGETED TEES. DS14-43 Casing Design Specifications SURFACE CASING 10-3/4", 45.5# NT80LHE BTC CASING BURST COLLAPSE PaYS (#) TJYS (#) 5,510 3,390 1,040,000 1,063,000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. LOT (ppg) TVD (FT) SIPRESSURE 1 4 3270 2381 Burst S.F. 2.31 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 3270 1615 Collapse S.F. 2.10 Tension Calculation Based on full string weight-NO BUOYANCY CONSIDERED. Casg Wt. (#/ft) MD (FT) Mud Wt. String Wt. (#) 45.5 3270 9.5 ppg 148,785 PaYS TJYS Tension S.F. 6.99 7.14 CKH 10/13/92 3:01 PM DS14-43 Casing Design Specifications Intermediate Casing 7-5/8", 29.7#, NT-95HS, NSCC Casing GRADE BURST COLLAPSE PBYS (#) TJYS (#) NT-95HS 8,640 7,520 811,000 813,000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SFFP 2900 Burst S.F. 2.98 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.5 ppg Gas Grad. Mud Wt, (ppg) TVD (FT) (psi/ft) Collapse press 10.5 8640 0.1 3853 Collapse S.F. 1.95 :Tension Calculation Based on full string weight in mud-NO BUOYANCY CONSIDERED. Casg Wt. (#/ft) MD (FT) Mud Wt. String Wt. (#) 29.7 9144 10.0 271,577 PBYS TJYS Tension S.F. 2.99 2.99 CKH 10/13/92 3:01 PM . . 2 5 0-=-'.-"i 2 0 0 · , I 7600 W e_s.f 0 5200 1 50 .... 1 00 50 0' I I I I I I 6000 O0 PRUDHOE Slru(~tr~ : D.S. 14 . SCALE 1 :. 50.00 50 100 150 200- I ! ! I I I 3200 ~ooo . _ 5400 200 ~5000 O0 ~000 BAY' DRILLING.- Well: 45 350. _300 _25O .200- ........ O 1 5:0- - 100 5O DS14,43.Xl..$ il)ate 10/1 ~,92 Ehr~ffi~: M. Minder Casing Interval Interval Size Bottom Tap Length 1A 10.'75 3.2..10 35 3175 2.A '7.62.5 8685 85 3A 5.5 9223 838CI 761 4A 0 0 0 0 ~;A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 1 aA 0 O O O Description :)escription :)esariptior~ "Tension Lb s C;rade Thread I...~bs 45.5 N'f'80L.HE BTC; 0 2.,.9.7 NT'95F.I$ 1 '7 NTS0$ FL.4.$ O 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O 0 Mud Hydrolytic Wieght Gradient ppg psi/ft 1 B 9.5 0.4,94. MB 't 0.0 0.52~7J DB 9. 'f 0.473 4.D 0.0 0.000 ~B 0.0 0,000 6B 0.0 0.000 7B 0,0 0,000 8B 0.0 o.acIo 9B 0,0 0,000 1 OB 0.0 O. 000 Maximum Minimum Pressure C~t~o ged psi Yield BII)F $'718 5510 '1 ..lB 3'7'! 8 8640 3718 7740 ~,, 0 0 0 O ~g~ 0 0 0 0 O 0 ~DIVlO! 0 0 Tension Strength K/Dos K/Lbs 1C 144..4.62~ 1040 20 268.75~3 30 1 -~" ..... 937 4.C O ~C 0 60 0 70 0 8C 9C 0 'fac 0 Collapse Collapse Pr...Bot-.Psi Resist. CDF 1586 3390 2.'1 ~ 44~ 16 7520 1.6~ 4364 6280 1.4~ 0 0 # DlVlO! 0 0 #D~IOi 0 0 0 0 0 0 ~DIVtO~ Page I ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** ..ROVE DATE '[~ ~ru (3) Adm i n_ ./?~t /~//~//G 2_ 9. ~.~,~13']' -' ' 10. [ 10 & 13] 12. 13. 14. [14 thru 22] 15. [23 thru 28] (5) BOPE Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. [29 th 30. (7) Contact 32. (8) Addl ]~i,.~-~-~,.. 33. geology' engineering: DWJ MllVl~, LAG Lease & Well £ R~MARKS rev 08/18/92 jo/6.011 Does operator have a bond in force ................................... ~ Is a conservation order needed ....................................... _~_ Is administrative approval needed .................................... Is lease nLmber appropriate .......................................... .~ Does well have a unique name & number ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to~psig ..... Does choke manifold comply w/API RP-53 (May 84) '. ............ Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions p~osented... Name and phone ntmber of contact to supply weekly progress data ...... Add i t i ona 1 requ i rements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLJkSS STATUS AREA ~ SHORE .\ Additional remarks' 0 -rz ~-~0 m z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIx. No special 'effort has been made to chronologically organize this category of information. -.. · ., RECEIVED MAY ~ 1 1995 * ..... -- ~CNL, d~BERGER ...... -* ******************************* ,15 Tape Veri. ficati, on ;chZt]n~ber,:!er ;~l, asKa Cor~'~pt]tir~q Center PAGE: ARCO ALASKa Ii~!C~ D$ lt-i3~ P~UDHOE BaY, 50-029-22296-00 ! 5~I' ]a,.r) ,STRING D,S. 1.4 - 43 500292229800 ARCO AbASKA Ii!C. SC'I,IL, Ui~iBEP, G~]R :,~Ehb SERVICES 95171 B ll, L~ aOXLOk~ 9 I" 19 1280 38.90 ~IT SIZE (I~) SI:Z~ (IN) DEPT~! (MT) ~EIGHT {L6/FT) 10,750 3193.0 45,50 7.625 9094.0 29.70 5.500 9700.:) 17.00 4,5o0 ~934.0 C!,'RvE 5:'II.~':'T L,,,~ ~ t.,LL PAoSF:¥ Ti) $TA;,,iDAPb{,~SEAStJ~ED Di,T, PTi,t) I$ Taee v' erificati, on I, istlna er AlasKa ¢omputinq Center 94 30.0 940 ,:a, 5 94 ~59, 937'~, (} 9371, 9357,n 9358.. 935i) , 5 9339,0 9340.5 9 ] 2 !. (, q 3 i. 4, ~ q 32 n l~ ~. ,,,~ ~ ,,, 931. 5,0 945@,n 9434,0 9406,5 9331.5 9358.5 9353,0 9322.5 931,~.0 °30~ 9 2 ~ 7.0 9247.5 9 ! 96.5 9 !. 9 6.0 !~ 17 a. 5 9!62.5 9157,f} 9! 53.5 9!5~ .e ~125.5 - c~ 1 0 9,5 ! 0 n · n 9309,5 930~. 5 93{)3.0 928a,o 9265,0 9264,5 924g,o 9249,o 9226.5 q!.97.5 ~:~!. 97,0 9164..5 9!5~.5 9156.5 91~3.5 9147.0 ql3R.O 9!2A.5 9!,1a.5 91i0.5 9!, 11 ll)l eS !00.5 09:24 The ~'teptt~ ,3. dj~$t.m~nt$ Shown above reflect cased !~ole GR ~o open. hole Gi~ ant caseo i',oie S'lC",~ to opeD hole GR. ~!]. ot~',,er Tr''~p . . - .. :. .... curves ?iez"e carriect witl> the $IG~i shifts, PAGE: .,IS T~c,~ ~?eri. ficatior~ ~ist.in<~ :-.chl. U~ber:;er i~.l, asKa. C'o~putlr~a tempter $ r'eut.~ shi, fteo and clipped curves ~or each oass in separate ~iles. ~:: .~ ..... O, TO"CP 947 i, , 0 9100,0 C~RvE f;:.~lVT Da'fa - P~::,Sa To PaSS(~,~EtgSU~Sr) DE~TH) ~hSELIP,~E CURVE F'[)~< SHIFTS PE?~;,RKS: Tb!.s file contains TDTP Pass ~i, No pass to pass shifts were ap:.:lie<:l to this data. LIS F::)f~,~r ~A'C!~ ..... e verification bistina :'chlum. h, er<ier ~!as~a C'o~uut~ng Center -,,A¥,,! q95 nq:~4 3 7! 92 4 6~ I. SE;T '~Y~E- CNAt4 ** ORI')E~'~ # bOG TYPE Cb.hSS FT 489160 O0 000 O0 0 C~) 488160 O0 000 O0 0 PU-8-~$88 t 60 O0 000 OD 0 CU 488160 O0 O0(', O0 0 CU 48~2 i 60 OO 0 On O0 0 CU 43~ ! ~0 O0 000 O0 C l.~ a: ~ ~5 i 6 u o o 000 0 O 0 CPS 4g~ 160 O0 000 O0 0 CPS 48g166 O0 000 O0 CPS 4.88160 (.')0 000 O0 0 CPS 48~!60 go 0{.)0 OC: 0 CvS 4~ 169 <)0 ()O0 O~ 0 CPS 48 ~ 1.6~) Oo 000 O0 O C ~ :> 4 8 9 1 6 () 0 0 t) 9 0 0 0 CF6 48~ ! 60 OO 000 OO 0 {,'~, ~ 8 F~ 169 O 0 ,) t) l) O O 0 V .:18Si 60 O0 000 OO 0 D ~ U,~ B $ ~,5~4 P EbL~ CODE ! ! 1 4 68 0000000000 ! I !. 4 68 0000000000 I I 1 4 68 0000000000 I 1 I 4 68 0000000000 1 1 1 4 68 0000000000 1 ! !. 4 68 0000000000 ! 1 ! 4 68 0o00000000 I 1 1, 4 68 0000000000 1 1 1 4 68 0000000000 1 1 ! 4 68 0000000000 1 ! 1 4 68 0000000000 1 I ! 4 68 0000000000 1 1 1 4 68 0000000000 I 1 1 4 68 0000000000 1 ! ! 4 68 0000000000 1 I ! 4 68 0000000000 1 1 I 4 68 o000000000 ! 1 1. 4 68 0000000000 1 ! 1 4 68 000000000o i 1 1 4 68 0000000000 I 1 1 4 68 0000000000 1 I I 4 68 0000000000 I 1 l. 4 68 0000000000 DATA 26-~^¥-1995 09124 13. 696 TPHi . TDT-P 1..728 S!rBH. TDTP 166.905 FbAC,,, TDTP ~5867' 926 TCF.i~. TDTP T D T P 21,~6.9~)I INFD. . O. 000 GR.~C8 -999.250 -999.250 -999o250 -999.250 -999.250 TPHIoTDTP SIBH.TD~P FBAC.'fDTP TCFDoTDTP INFD.TDTP GR,~CS 27 200 49 I13 8495i914 343 817 19 153 -999.250 -999.250 -999..250 -999,250 -999.250 57,923 SBHF.TDTP TRAT.TDTP TCAN.TDTP TSCM.TDTP GRCH.TQTP SBHF.TDTP TRAT.TOTP TCAM.TDTP TSCN.TDTP GRCH.TDTP PAGE: 31,153 1.897 471!2,414 9133,!95 -999,250 -999.250 .-999.250 -999.250 -999,250 -999,250 FILE ~'.!A~':'M : EDIT ,00 V E a ~ I C (') 0 ' <'' 0 ! D A'T ?T : 95/05126 ~;~AX RFC. 5TZE : !024: FILr,' TYPE : l,O ~,). SoO Ct,ir VP$ 9471 , a S'i'OP DEPT~ 9O90, n separate files. ;cblumberger alaska ,"~,,,r'~'.,t.j..n,"~ Center 9459. ~ 9445.0 9446.0 94, 30.5 94 {..~ 5.5 94 (') 5,5 94O5.0 9370,5 937i,5 937f:~. 0 937 i. 0 q357 0 935~ 5 ~;35,~. n 9355,5 93TM, ...... n 9330 5 9329, ..... 93 i 9.5 9319,5 93i'7,0 9317,5 u315,5 93!6,5 930~' 0 9308.5 · .- ~ .. ~. ~ ~ !~26,3. ~ 9264.5 924.7.5 (,249.0 9249.0 9 ! 9~. 5 9 I97. () 9197.0 o I ~ ~. 0 t:~ 1 ~ ('~. 5 9l':,;5.0 9167.5 , ~ . .,, , 91 5~.5 91 58.5 91 4 ~. a 9147.0 -~ 1 3'?. ~" 9 ! 3~. 0 9 ! 2 ~. 5 9! 30.5 '~ 1 2' 4, fi 9 1 2 .:i. 5 ql io 5 ql 1o 5 1(,,"~.0. !01. .0.. 100.5 t,: £.. h T i) T i; 9462.0 9434,0 94:25.0 9 40 6.0 T.~ls file coats' ns TDTP Pass sho~,,p ,~OVe re!ect CRC{'I pass Uff;P'i'N ) 'i""SH I F~ED t,)EPT ii:- ......... #2. The depth shifts .2 to GRCH PaSS #! and PAGE: .,I$ Ta~e verification l.,ist, lno ;ch~lUa';ber(~er Alaska Cot'.put!hq Center 26-~A¥-!.gg5 00:'24 PAGE: > ........ ~ BaSS $ L!'~5 F'I'ii[:~"f;,~T DATA I AP I . N {}i4B NUMB SIZE RE. R PROCESS LOG TYPE CBASS NOD r~U~B SA~'~P ElaE~q CODE (HEX) .......... ~,,.... o~. . o;'"1o ..... o ;""[ .... ; ..... i ..... X ..... ;;'"'"'""'oooooooooo. ..... . 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 OOO0000000 0000000000 V'eriiicattor,, r.~istir~.q 26-f.~AY-t995 09:2.4 AlasKa Co,purina Center DaTA ** 1!, .B20 TPNi.TDTP 17.992 SBHF.TDTP .... f!Tp 1 42~ sI6~,t TDTP 77,400 TRAT,TOTP 903,500,,~ ~6AC,TDTP. 64,627 TCAN,TDTP 06 7,t6 O,TDTP 8294,475 TSCN TOTP R83, ~ 16 IHFO, TDTP 292. 922 GRCH,TDTP 0. O 00 . .? . v S!(;~q.T[)'r'P 21 727 TPHI 'rDTP 3].22B SBHF.TDTP SDS'r mDTP 1.,~,12 r~!~(.'~K,I'DTP t61 8~5 FBAC,T~T~ 35,25.] TCAN,TDTP TCAF. Ti'~TP 74~7.i67 TCNO. '.rDTP 20973.051 TCFO.T97rP 58~2.918 TSCN.TDTP TSC~, *~;~TP !.5-~2.246 ! :~5 ~txtD. 'fDT P 1834.29i IHFO,T,OTP 291,641 GRCH,TDTP T F'i~ 5, TD"P P 1 !. 45, i) ~ t,'~ C(]~[~, Ti)TP 0,060 48,627 i,581 36349;523 72140'076 -999,250 34.558 1'852 20995.090 4353,752 -999., 250 995 09; 24 f~ept, h sh,!.~ited and cl~ppe¢ i)EPTS' I~CRE~'4Et,~T: 0,5000 6 R C h 9 ,i 46,0 Ti)Tp 947 ~ , 0 C U R v Fl 5 ~"-~ l F T O ~:. T A curves ~ 44.. 4 942 7,5 9411.5 940 ~:). O 94O2.5 93eh 937! .5 937 !. (} 935g.5 915~. 0 9354.5 9349,5 934O, 5 9333.O 93!~.5 9 ? 0 q. (, 9303,0 q26'.~ , 5 c 2 ~ ~ C ?22 i. 5 9!.7~,5 q 1 49 , 0 for' each pass in separate fl, les, STOP DEPTH 9 090,0 ~090,0 .......... EQUIVAI, Er',!T U?-~'SHIFTED DEPTH---- ..... - GRC~ TDTP 94%2°5 9434,0 942S,5 9412.5 9403.0 939i.0 937!.5 9371,5 935R,0 9~5~.0 9355,0 934~,5 9340.5 9333.5 9325.5 9310.5 930°.0 9308.5 ~3o3,0 9292.n 928q,0 9265.o 0264.5 924. q,0 9249,0 ~230,5 9222.0 9~97.0 9197.0 917~.n 9!59.5 9156.5 ~49.5 PAGE 26-aA¥-1995 99:~4 9!,47,0 91,19,0 910~.5 99,5 t'~;~,'~APKS; This file contains TDT? Pass ~3, The depth shifts sbowr~ a~ove relect GRC},f pass ~3 to GRCi4 ~ass ~l and P~GE: !0 APl . . APl APl ~.~tt i'~ gE .~j 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 bls Ta[,e ',;erIficat!on I, istinq 5chlu¢~',ber,ger AlasKa Comp{.]ti. nq Center 26-:AY-i995 09:24 PAGE: SDsT 'T'D?? Ci~ 488t60 O0 Oi')O O0 Fr},AC Y C A ~' T [} T P C P S 4, S 816 () C, 9 0 () 0 00 T C ~',a $', T D ? P C P 5 48 $160 00 000 00 T C F P 't' D :? P C P 5 4 8 ~l t 6 0 O 0 0 0 0 0 0 ?S C a~ ~r'9 q' P C P 8 488 t 60 00 () ~') 6 00 T 8 C ~ 1 N ~x~h T ~ )"'I' P CPS 488160 O0 O00 O0 i ~ FF) mr)rap CPS 48a160 O0 000 O0 GRCF~ T[)'.f'~) GAPT 48a160 O0 O00 O0 'i'E ~.~ S TD?P LB 48:3i6o Or) O00 O0 COb hOG TYPE CLASS ~C~D NUNE! SA~IP g~ga CODE (HEX) 0 ] 1 i 4 68 0000000000 0 3 1 1 4 68 0000000000 () 3 ! I 4 68 0000000000 0 3 I I 4 68 0000000000 0 3 1 t 4 68 0000000000 0 3 1. 1 4 68 0000000000 0 3 I 1 4 68 0000000000 0 3 i I 4 68 0000000000 0 3 ! I 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 ! I 4 68 0000000000 0 3 J i 4 68 0000000000 0 3 1 1 4 68 0000000000 0 ~ I 1 4 68 0000000000 DgPT. 9460. OOU SIGN.TOTP 8~HN.TDTP 48.625 SIGC.TDTP 8!)51', l'!.)'~' P 0,244 BACK.TDTP TCAF.'rF)TP i'80.~B .941 'I' SCF, Ti.)T P 3667.034 TENS. q'DTP 1180.0¢)0 CCh. TT)TP DEPT. qO89,50u S!G;4,TDTP SDST, ?i)TP 1,205 13ACK. TDTP TCAW.'?OTP 6897.767 'rCF}O. TDTP TACr;' 't' ~ ....... , o ~, P ~ 428. 427 I i,~'.~D I'"~'I.'P T ~ :: 8, q' i) T P 12 f'~ 5. O 0 ~.~ C C b. T i> Y P 13.532 TPHI.TDTP 25.g93 0.631 $IBd.TOTP 64. 101 , , .. ~'~ ~ ..l ~ 6 8~4 F'BAC, TO1. ~ 36,615 26377.914 TCFD. ::~DTP 8575.555 2054.1'i5 INFD.TOTP 321.849 0.000 21.923 TPN,I. Ti)TP 36.881 3.5'13 ~IB,q.TDTP 36 965 2.6 03 r B A C. T D T P 3 5: 3 7 0 20933.219 TC~D.TDTP 5626 245 I~76.026 INFD.TDTP 318:468 0.000 SBHF.TDTP TRAT.TDTP TCAN.TDTP TSCN.TDTP GRCH.TDTP SBHF.TDTP TRAT.TDTP TCAN.TDTP TSCN.TDTP GRCH.TDTP 39,246 1,861 43048,586 8746.254 999,250 24.993 .1.946 20847.082 4317.128 -999.250 12¸ ~'~].lsea ?~eut. ro'r~ O~"~averaG~ed edite~ Pass i Gamma ~ay a~d backroun~ count~; arithmetic averaqe o:~ e~ite~ static oaseline c~asses for all otb. er curves. ~i;,a.,~?($: 'i:he a~.tt~met, ic averaqe of passes 1,2,3 was compt~ted after all. eJe{':'~t~% shifts and cliPPln9 was applied. 2 66 0 4 66 ! 7 65 ~ 68 0.5 9 65 .~IS Ta~e ueri. fication t, istino 26-~A¥-!995 Og:~{l ~chlurr~berqer Alaska Compu~inq Cent:er PAGE 13 O ~ P ~ F T 48 ~ l, 6 u 00 00 ~ o 0 0 4 1 1 4 68 0000000000 T P}'.{~i PLiI~V 'PIJ-S 4~8i, 69 O0 Oi)() O0 0 4 ! i 4 68 0000000000 SaaF ~'.,; a V CO 48~160 O0 00o O0 0 4 1 ! i 68 0000000000 SB~i~.~ P?.~ ,a V CU 43~!60 O0 OOO O0 0 4 1 1 4 68 OOOO000000 5IGC P~; a V CU 488169 (~0 OeO O0 0 4 1 t 4 68 0000000000 8ia~! P?,: aY C!:~ 48a i 6(., O0 090 O0 0 4 i I 4 68 0000000000 TRA? P i~,a '¢ 48(1160 0t) 000 00 0 4 I 1. 4 68 0000000000 SP[¢I P?hi/ Ct.J ,.!.8 ~ 160 00 000 O0 0 4 1 I 4 68 0000000000 B~C~: ~"I)T i? CPS ~}8~ 160 OO 0,'~0 00 0 4 1 I 4 68 00O000000 FBAC TDTF CPS 48~160 09 OOO O0 O 4 1, 1 4 68 0000000000 TCA? P?~ A V CPS 48:a'16u O0 00() 00 0 4 1 1 4 68 0000000000 TCaF~ Pi~a v CPS 4S~,t60 (')o ()00 O0 0 4 I 1 4 68 0000000000 T C'a f',' Pt,~ A. V CPS 4S8~60 Or) OOO O0 0 4 1 1 4 68 0000000000 TCF~ Pi,~ aV CP~ 4:8~160 ()~ OOO O0 O 4 i 1 4 68 0000go0000 TSCX P~,~V CPS 4~ ~60 00 o00 O0 0 4 1 I 4 6~t 0000000000 TSCF Pt~, h V CPS 488~60 00 O0O O0 0 4 I 1 4 68 0000000000 ! ~':~ ~l r> p ~ v C ~ o 4881, 60 o o <'> 0 ,'o 00 0 4 I I 4 68 0000000000 INFO Pi~ a V' CPS 48ai. 60 Oo 000 O0 0 4 I I 4 68 0000000000 (;~CF T[)7'~F., GAP! ,168160 O0 000 00 0 4 1 t 4 6B 0000000000 1)EP:T'. t~475.0',)0 SIG~!. Pi4AV -999.250 TP?tI. P;~!AV -999 ~50 SBHF.PNAV SBi4t;. pi~ ~, V -999.25u Si(;C. P~,~AV -g99.250 SI BM. P~,~AV -999~250 TRAT.PNAV SDST.P~hV 999.25i~ BACK. Ti)TP !66.905 FE. AL.TOTP 49 113 TCAN.PNAV . TCA~'. Pr,~ hV -999.250 TCND.PNgV -999.P50 TCF'D. PNA. V -999.250 TSCN.PigAV ~SC~, .. . P~,AV. -9q9.250. .. . JN:'ITM~, . ~:~ ~"~ a V.., -qgo. , .250. I NFD. CNAV. -999.250 GRCH. TOTP Q097 .Sou $1 (;:,I. P~:'~, a U 35.756 TPHI. P~AV 54.256 8BItF.PNAV 46.323 $1(;C. P~:~av 0.969 SI~i~.Pq~V 60.907 TRAT.PNAV ~. 9~'i i%.ACK. T[)TP 130.678 FBAC.TOIP 30.908 TCAN.PNIV 6441.313 TCNi). P~::hV 19114 1~0 TC~D.PNAV 4655.452 TSCN.PNAV '/39.591 I ~,~.;D. Pi, A V 21.14.329 INFD.P;~AV 314.859 GRCH.TDTP -99g,250 -999.,250 .-999,250 -999,250 -999'250 41.389 1..891 23180.492 2526.973 -999.250 PAGE: !4 F T, b[!i H E.~k DER Curves and loq header data i~or each pass in separate ~l,les; raw backorou, nfl pass in last file ~', ,, ~.~, ~.... ]'~ bOGGED P l [, I,j ~ R q~';c. LOG IN~EPVhL 0 ,-', b ri G ' 7itTP TgTP 0 !' ~ STOP DEPTH 9I 0 27-APR-95 42.2 !7!4 04-APR-95 0.0 9090.0 9470.3 ,9.0 ~0 ;chlUmher~'~er ~l.].as.Ka (,o~:putl. ng Cer~ter 26-~a¥-1995 09~24 8'729 31 93,0 40,0 194 ,, 0 ......... o,.. ALE (CPS) 0 FAR C(]i.I?.~T aATF; H[(;l..i SCAbE'~ (CP5): 13000 ~,~'aa Cn~:'.[. ~:~tvF" t, Ot~ SCALE [CP~;)' STANDf'}FF~ (Iii): P3TI~ J'.',~JT T ~ TO:rib '~O],~MES PiI>~P~jD: 202 ~BLS CR[.IDE~ 8 t-JBhS DIESEL GOC PICKED AT 9254' [.,TS FOP:4!~T DaTA PAGE: 15 ;cblumt~err,:i~er AlasKa f!ort:putin~ Center 26-~AY 19°5 0Q'24 PAGE' ** SET ?'¥[-E - CHAr~ ** m A ~t V d N I 7 C I I P . ~ .~ O g a N t i' M B S I Z.E R E P R P. 0 C E $ S ID ~RDER ~ bO(; TYPE CLASS ~I(3D NUMB SAr,{P ELEM CODE (HEX) t) F P T F T 4857:160 00 0 (, 0 00 C. 5 I 1 4 68 TP~I PSI PO 48¢160 O0 o00 oo 0 5 1 i 4 68 5B?-~' PS1 CO 4~160 O0 o00 O0 (} 5 1 i 4 68 S~~,~ PS! CU !8~i60 O0 UO0 O0 0 5 I I 4 08 ST"C. ~, ..... P,S1 CU 48~16{) O0 00~). OO 0 5 1 I 4 68 $ISN Pill CiJ 4.8 [~ 16{} nO 000 O0 0 5 I 1 4 68 TPAa' ¢S1. 48[~160 O0 OCO O0 0 5 I i 4 68 SDS! PS! Ct.~ 48~160 ou ~) () ~ O0 0 5 1 !. 4 68 B~C~: PS! CPS ,t. ~]I [¢i 6 (,O0 0(?0 O0 0 5 ! l 4 68 FBAC PSi CPS 48~160 O0 t, O0 O0 0 5 I I 4 68 !:C.~ N P~l. CPS ..&8 ;~ 160 O0 t:) (~ L~ O0 (') 5 1 I 4 68 TCAF PSI CPS 4St{l 6~ O0 0o0 09 0 5 i 1 4 68 T C i'..; g PS1 CPS 4a~i6o O0 009 O0 0 5 i 1 4 68 TCFP PS1 CPS 45E16{) O0 Onu oO 0 5 1 1 4 68 TSC~. PSi CPS 48816o Or; 000 O0 0 5 I 1 4 68 TSC/' PSi CP$ 4b[~l 6() O0 O00 O0 0 5 1 I 4 68 I ~,;; C~ PS~ CPS 4~i ~(, O0 0{~o O0 r', 5 1 1 4 b8 I t',~ F r' PS1 CPS 48n160 O0 O(~O O0 {~ 5 1 1 4 08 T F ~'.,; S 0S1 La 48~i&,) ")~) 000 00 0 5 1 1 4 69 GP PS! G2PI; 4~:!60 O0 (~0(, OU ,.) 5 1 I 4 68 CCI, ~SI V 48F;i60 0~) ~30{) O0 0 5 i 1 4 b8 OOO0000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000o00000 0000000000 0000000000 0000000000 0000000000 0000000000 O0000000OO 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 mmmmmmmmm~mmmmmm~m~m~mmm~mmm~mmmm~mmmmmm~m#mmmmmmm~mm~mmm~mmmm#m#mmmmm#mmmmmmmmmmmm! !6¸ ,~15 wa~,e 'veri. f!catlon Listinq ~chlu~berf~er q].,asKa CJomputinq Center 26-~!AY-!995 ()9:.74 26.054 TPH!.PS! !.7o0 SIBYl,PSI 1,06,905 FBAC,P.S1 25867.914 TCPD.P$1 2146.993 INF[).PS1 O .000 DFPT. 9,~97.()n0 SIGt.'I. PS I 34.093 TPHI.PS1 SBH~<.PS1 43,,650 $IGC.PSi 1.4t6 SIBd. PSt 8PSI.PSt i;.96o aaca.PSl 130.676 FBAC.PSI TCAF.PS! 663~.326 TCNO.PSI ~0016.~30 TCFD.PSI TSCF.PSI 77b. Sa7 I t.iNi'). PS 1 21~5.212 I61FD.PS1 ** !.E 0 O? t?;ATA ** (* 39.980 SBHF.Pol 35.520 TRAT.P$1 49 113 TCAN.PS1 8495~912 TSCNoPSl 343.817 TENS.PS1 52.371 .,SBHF.PSI 53. 163 TRAT.P$1 30,908 TCAN.P$I 4827 ~223 T$CN.P$! 330.596 TENS,P,5i PAGE: 17 ,897 46523,523 133 195 175 000 2437{., 952 840 268:9 ' 676 1135,000 **** F I'L.t,'' SFRwICE : FblC DA'l?[' : 05!05/26 ~.~IX R~;~C SIZE : ~024 FTLF' TYPE L ~, s'r F~LE · FIL FIL Fib Ci] R V Curves and 1o~:~ header d¢it.a for 94'! ] each pdss in separate STOP DEPTH ..... filesl raw background pass in last file 26-~AY-1 995 09:24 PAGE: 18 LOGGERCFT) ~ I:,OGG~[f:'~G SPF'.~D (FPdR): VE~POR TOOL C[)DE TOOL TYPE [.-;-- ........... ;....... h T T ~'; R ~'~i A b g E C .A Y T D T P G ~. ~ ~'~ a R A Y Tf.)TP T~ e2R ~4.A b DECAY' '.i' G T P T?ICR~'~ ~b DECAY TDTP T H ~7, P. i',~ A b DECAY $ 27-APR-95 .42,2 1.714 9573,0 0,0 9090,0 9470,0 0.0 N 0 04-APR-95 TOOL A,I.!AB ATC 644 TNC-C3 TND-C 395 TNH-~A 396 TaG-5 400 ~NTRN 8729 3193,O C R U r} g 40.0 !94.0 ~'AR COI)~.~T Pa'I'f~ b~;)~ 5CAi,E (CPS): O ~'aP COU~';T RAT~.; bI(5~ SCALE (CPS); 13000 .'~g~k CO,..J:,}'I' ~ATE i.,GW SCAI~F~ (CPS): 0 .!IS Tape Veriflcatioq k, istiDg ;cDlumber(.~ar AlasKa Compotlno. Center 26-MAY-1995 09:24 T:)OL, STA~',!DOFF (Z!;;~): 3 000 0 P!.;;:4, AP}',;$: COR.,r'~i{;LATt';P TO S~,~S USIT LOG' OF 11/!I,/92, hOGqt!;D 0t~,,; SA",.,!DSTONE MAT~lX PAGE.* ** ng?A F'SR~A? SPECIFIC-~T!O% ~ECORD ** SET ?YPff - C!qAN ** A'~r $ V t;R 'ICE APl AP! APl, ALI FiLE [}UM~ ,~U~B SIZE REP,R Ti.> O~,ne;q ~ hOG TYPE CLASS ~;,)P ~U~B SAMP ELEi4 CODE (HEX) ;c~lu~t:er,:'!er ~las~a Com[~t.!tJnO 26-t, iAY-l. 995 09124 2O TCAF' PS?, CPB 48~i60 O0 TCNr, PS2 CPB 488~60 O0 TCFm PS2 CP& 4~I60 TSC,',: P52 CPS 48~i60 O0 TSC~ P52 CPS 488160 0O I Fluid PS:2 CPS ':I~ 8 [ 60 O0 I~Fr~ PS2 CPS 48~t60 09 A I v,ILE ~:UM5 NUMB SIZE REPR OCE TYPE CHASM ~I{:}P ;'4UHB 8AF:P EbE~4 CODE (flEX) 0 0 I 1 4 6 0 000 00 0 6 ! 1 4 68 0000000000 000 00 0 6 1 ! 4 68 0000000000 000 00 0 6 I I 4 68 0000000000 000 O0 0 6 I I q 68 0000000000 000 O0 0 6 1 i 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 i 1 4 6~ 0000000000 OeO O0 0 6 1 I 4 68 0000000000 .!:)EP~'. :"2 9475,0n0 $[G~.p'$2 34.37~ TP~I,PS2 38,044 SBHF.PS2 SBHN' P~, .... 47.025 $:IGC.PS2 2,034 SlaM.PS2 62'932 T.RAT'P82 c:DSr ~S9 0.792 ~:~ACK, PS2 203'074 FBAC,PS2 264,627 TCAN,PS2 TC.AF. PS:~ 2299o,797 TCNO.PS2 23112.727 TCFD.PS2 8 94.467 TSCN.P82 TSC~', PS2 '~659.585 ! ~'~,~ O. ps 2 1~83.342 INFD.PS2 292.920 TENS.PS2 G?. PS? 5 i. 500 CCh. PS2 O. 000 582 5038 34 734 ~37 2o :ooo DMPT. 9i)87.0~)0 SIlGi~:.ps2 24. 04.7 TP~I,PS2 43.611 SBHF,PS2 5BH~;.PS2 36.~28 SIGC,PS2 2:951 S1BH.PS2 36,828 TRAT.PS2 DST ~82 0.6~3 BACK.PS~ !58'225 FBAC.PS2 34 666 TCAN,P$~ ~CAP:PS2 7o65.~3(2 TCND'PS2 20!b2.~50 TCFD,PS2 5307:156 TSCN,P$2 TSCF'.PS2 1282.076 [i~0.P$2 i802'930 INFD.PS2 313.065 TENS.PS2 GP.PS2 72.563 CCh,PS2 0.000 31, 1.03 22931 676 4078!544 1150 000 END OF DiTA ** **** FIL~ TRA l [,~P. **** FILF' ~',:A,~-~?: : Ei")llr ,006 S~':RV ! C~i : FLIC VF~SIO;'< : OOlCOI D~'FF : 95105/26 i,~sX R~?C SIZE : !024 Fl LF TY P~: : b~Sr PILi; ~IS 'rar~e YerJffcatIo.n List, lno ;chlumberger AlasKa Computf...~q CeDter Sg~v,ICg : FblC V 5~RSIO?'~ : OOlCOI ~'¢~.~X REC SIZE L~5~ FILE 26-'~AY-! 995 09:24 PAGE: :2! Cqrves and log ~eader data for each pass in separate files$ raw baCKground pass in last file D~:PT' ~ I i'~iCR E?~EN T: 0,5000 FILE VF;~',iDOR TOOL CODE START DEPTH ~, A'r ~; LOGGED: $O~T~ARE VERSION ~D DR Z L,L, BR TOP bOG INTE~V.At.,~ PtJT'~F,~/, LOG .INTERVAL (FT): LOG<;I;~4¢ SPF:En (FPHR): DEPT~,~ C~)r.,JTROL USED J~T?:~UOR TOO[, CO[)~ TOO[, TYPE RAY THE~4AL DEC~Y DORE!-~{;LE C.O.h~ P I T I O~-~S STOP DEPTH ..... 27-APR-g5 42,2 1714 04-APR-95 9573,0 0.0 9090 0 9470~0 0.0 TOO[, ~[JMBER AT~-AB 284 ATC 64~ TNC-C 3 TND-C 395 TEH-MA 396 Tb~G-~ 40O ~TRN ~729 3~93,0 CRUDE Tape"or .ri~ication. Listln~. ;c~l,.~mberc]er hlas~a Co~,~uCIn~ Cer~ter 26-~AY-1995 00:~4 40 . 0 t9~.,. 0 ::4ATR IX DENSITY: Bb[tELINE COUNT P, ATE SCALES SET Bt FIELD ENG!NEEB ~AP COUNT R~,',rE LO;'~ SCALE (CPS)~ 0 FAR COUNT R~,TE HIGH SCALE (CPS): 13000 WE:AR COU~i RATE LOw SCALE (CPS): C) ~,~E~R COUNT F;ATE ?llG~.i SCALE (CPS): ]OOOO q'C~Ob STA}~DCFF (i~.~): Pf:~TD '~['~'r T~GGED TPIS rOllb VOLU?;E8 PI.,}~'~Pf]DI 202 BBLS CRUDE, 6 [:~hS DIESEL {'JO("/ PTC;KED ~-r 925~' ¸22 ** PA:'?A FnR~,~AT $.F?~iCI'FICaTICii',i .~E;C{.iPD ** ** ,.SET T¥'P6 - 64ER ! 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 8 6g 0,5 1l 66 'IS Tape Verificatl, on Listinq ~chlum~eroer AlasKe Comput,i. nq Center 26-r,~AY-1995 09:24 PAGE: 23 "I'D H l PS3 PU SDSI PSI CU I C r~ ~.~P8'~ CPS TC~ PS3 CPS TCaP PS 3 CPS TCF~, PS3 CPS TSC~; PS3 CPS TSC~' PS3 CPS I N ~,] T3, P53 CPS I~En PSI CPS PS3 PS3 CLASS ~'iOD NU~e 8A~P EbE~a CODE --;;----; ..... .. ............ -.-...-...-....--,,,,-.-. :, 7 1 I 4 6~ 0000 O0 O0 0 7 1 I 4 68 0000000000 O0 0 7 1 1 4 68 0000000000 00 0 7 I i 4 68 0000000000 06 0 7 I 1 4 68 0000000000 O0 O 7 1 t 4 68 0000000000 O0 0 7 1 .I 4 68 0000000000 O0 0 7 1 I 4 68 0000000000 O0 0 7 I 1 4 68 0000000000 O0 6 7 l I 4 68 0000000000 O0 0 7 1 ! 4 68 0000000000 O0 0 7 1 I 4 68 00OO000000 O0 0 7 1 1 4 68 0000000000 00 O 7 1 1 4 68 0000000000 O0 0 7 1 1 4 68 0000000000 00 O 7 I 1 4 68 O000000000 O0 0 7 1 i 4 68 0000000000 O0 0 7 i 1 4 68 0000000000 O0 0 7 ]. 1 4 68 0000000000 O0 0 7 1 1 4 ,68 O00OO00000 OO 0 7 1 1 4 68 0000000000 O0 0 7 1 1 4 68 O000OO0000 DEPT, 9475. SDST.P$3 O. TCAF,PSI 23~¢9, TSCF.PS~ 389?. GP,P5~ 11i, D=PT. 9U89. 5Pdt.PS3 37. TCAT.PS~ 6700, ~'SCV.P5~ 1388, OOC SIG~,PS3 591 SIGC.PS3 571 ~ACK.FS3 305 TCaO.P$3 q6~ 063 CCh. PS3 27.122 TPlt!.PS3 40.202 SBMF.PS3 2.296 SIRH.PS3 35.591 TRAT.P$3 !b4.983 FSAC.P$3 41 359 TCAN.P$3 26344.1~4 TCFD.PS3 8788~742 T$CN.PS3 2240.9~2 INFO.PS3 293.713 TENS.PS] O.OOO 23.093 TPHI.PS3 38.662 SB~F.P83 3.191 SIgH.PS3 37.868 TRAT.F$3 !.71.605 FB~C.PS3 36.310 TCAN.P$3 20,q57.035 TC~'D.PS3 5565.521 TSCN.PS3 !.~76.0~6 INFD.FS3 323.530 TENS.P53 32,589 1,872 60408,563 9142.434 1180.000 23.427 20716.234 4292.702 1120.000 ...,,,dz~ar:,e VerifJ.,catio. blstln9 tuber'ocr AlasKa ¢o~Putlncx (:'enter · 26-~¥-1995 09:24 PAGE~ 24 0. DATA SgRV,ICa; ~,~A~E : E:O!T DATE : 95/05/26 ORIgIlu : F,~!C CO~'~T!Nij~ITION ~ : ! PPfi;Vi09S TAPE COM~,~[5'?4T : aRCO ALASiiA ]:/,~C, DS 14-43, PRiJDHOE BA'Y, 50-029-22296-00 **** REEL D ,~, 't' g : 95/05/26 OR I g I ~,:i : WLrC RE[:I, ~a~'~E : 95171, PREVIOUS REEL : CO~,*~E,i~'l' : ~RCC; ALASKA I~;C, DS 1~-43, PRUDHOE BAY, 50-029-22296-00 ARCO ALASKA INC D.S. 14 - 43 PRUDHOE BAY MICI OFILME Run 1' 03 - Nov - 1992 DIFLIACICNIGR ~194 1696 1992 Alaska Oil & Gas Cons. Comrni$$k Anchorage Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: D.S. 14 - 43 500292229600 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 09-NOV-92 RUN1 5745.00 J. DAHL T.RUT/L.PEAK RUN2 RUN3 9 i0N 14E 19 1280 74.00 74.00 38.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 9083.0 DIFL/AC/CN/GR CIRCULATION STOPPED: 21:30 02-NOV-92. BY CUSTOMERS REQUEST, REPEAT SECTION DONE OVER ZONE OF INTEREST. GAMMA RAY RESPONSE ON MAIN PASS FROM 9610 TO 9640 READ- ING HIGH DUE TO NEUTRON CREATING A SLIGHT HOT SPOT WHEN GETTING TO TD. CNC CORRECTED FOR CASING FROM 9082 TO 8000; CASING THICKNESS = 0.375", CEMENT THICKNESS 1.125", & CHISM FILTERING ACTIVE. GAMMA RAY RUN TO 10 3/4" SURFACE CASING POINT (3194). $ NOV 1 9 AI~ 011 & G~ Gons. ~mmission FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BHC DIL 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 BASELI 9082. 9085. 9090. 9091. 9092. 9105. 9111. 9120. 9123. 9130. 9131. 9131. 9132. 9144. 9145. 9146. 9147. 9147. 9149. 9150.5 9151.0 9156.5 9157.0 9164.0 9166.5 9172.0 9178.5 9182.5 9196.5 9197.5 9205.5 9210.0 9210.5 9221.0 9223.5 9224.5 9226.5 9231.5 9245.0 9248.0 START DEPTH STOP DEPTH 9082.0 9632.0 9082.0 9667.0 9082.0 9696.0 9082.0 9639.0 GR (MEASURED DEPTH) NE DEPTH DT 0 9082.0 0 0 9090.0 0 5 0 0 5 5 0 9130.0 0 5 0 5 0 5 0 9147.0 5 5 9150.5 9172.0 9178.0 9197.0 9226.0 EQUIVALENT UNSHIFTED DEPTH NPHI LL8 ILM 9082.0 9082.0 9082.0 9090.5 9090.5 9093.5 9110.5 9123.5 9121.5 9132.5 9132.5 9145.0 9145.0 9147.0 9147.5 9149.5 9156.0 9156.0 9166.5 9164.0 9197.5 9197.5 9206.0 9221.0 9183.0 9197.5 9211.0 9224.0 9231.5 9246.5 9249.0 all runs merged; ILD 9082.0 9085.5 9105.5 9132.5 9151.0 9156.0 9211.0 9224.5 9248.5 no case 9248. 9249. 9249. 9253. 9257. 9261. 9264. 9264. 9265. 9267. 9281. 9285. 9288. 9288. 9302. 9303. 9303. 9304. 9305. 9307. 9311. 9315. 9316. 9318. 9322. 9323. 9332. 9338. 9339. 9340. 9341. 9355. 9357. 9357. 9358. 9367. 9371. 9371. 9372. 9380. 9394. 9399. 9400. 9406. 9406. 9409. 9416. 9416. 9425. 9465. 9479. 9484. 9491. 9492. 9506. 9509. 9521. 9534. 9536. 9537. 9248.5 9257.0 9261.5 9281.5 9288.0 9311.0 9318.5 9322.5 9338.0 9357.5 9371.0 9416.5 ,9478.5 9492.5 9536.0 9249.0 9267.0 9287.5 9303.0 9311.0 9322.0 9340.5 9371.0 9399.5 9407.0 9416.0 9533.5 9249.0 9265.0 9288.0 9303.0 9323.5 9340.5 9358.5 9371.0 9406.0 9265.0 9286.0 9303.0 9305.5 9308.0 9316.5 9340.5 9358.0 9374.0 9381.5 9395.5 9416.5 9485.5 9510.0 9522.0 9254.0 9265.0 9306.0 9316.5 9332.0 9355.5 9367.5 9399.5 9409.5 9425.0 9465.5 9485.0 9491.0 9506.0 9521.5 9537.0 9 9 9 9 9 9 9 9 9 9 9 $ 9552.0 9552.5 9554.5 9560.5 9563.0 9565.0 9566.5 9567.0 9568.5 9585.0 9585.5 586.5 590.5 611.0 612.0 614.5 618.0 618.5 646.5 647.0 677.5 713.0 MERGED DATA SOURCE PBU TOOL CODE GR BHC DIL 2435 $ REMARKS: CN WN FN COUN STAT 9552.0 9552.5 9555.0 9560.5 9560.5 9567.0 9567.0 9567.5 9585.0 9585.5 9590.5 9611.5 9612.0 9614.5 9614.5 9713.0 9713.0 9713.0 9564.5 9567.0 9586.0 9618.5 9648.0 9713.0 RUN NO. PASS NO. MERGE TOP 1 2 9082.0 1 2 9082.0 1 2 9082.0 1 2 9082.0 MAIN PASS. FUCT & NUCT WERE SHIFTED WITH NPHI. TENS, TEND, & MTEM WERE SHIFTED WITH LL8. SP WAS SHIFTED WITH ILD. $ : ARCO ALASKA INCORPORATED : D.S. 14 - 43 : PRUDHOE BAY : NORTH SLOPE : ALASKA 9563.5 9587.0 9618.5 9647.0 9677.5 9713.0 MERGE BASE 9632.0 9667.0 9696.0 9639.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GR BCS 68 2 DT BCS 68 3 TEND BCS 68 4 TENS BCS 68 1 GAPI 1 US/F 1 LB 1 LB 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 5 LL8 DIL 68 1 6 ILM DIL 68 1 7 ILD DIL 68 1 8 SP DIL 68 1 9 MTEM DIL 68 1 10 NPHI 2435 68 1 11 FUCT 2435 68 1 12 NUCT 2435 68 1 * DATA RECORD (TYPE# 0) Total Data Records: 67 OHMM 4 OHMM 4 OHMM 4 MV 4 DEGF 4 PU-S 4 CPS 4 CPS 4 994 BYTES * 4 50 746 76 4 50 746 76 4 50 746 76 4 50 746 76 4 50 746 76 4 98 211 23 4 98 211 23 4 98 211 23 48 Tape File Start Depth = 9713.000000 Tape File End Depth = 9082.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16420 datums Tape Subfile: 2 277 records... Minimum record length: Maximum record length: 62 bytes 994 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 3194.0 2435 8000.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH NPHI 3194.0 3194.0 3194.5 3194.5 8012.5 8012.5 8015.0 8014.5 8016.5 8015.5 8029.5 8029.5 8054.0 8054.0 8068.5 8069.0 8081.0 8081.0 8108.5 8108.5 8125.5 8125.5 8157.0 8156.5 8183.0 8182.5 8190.0 8190.0 8215.0 8216.0 8224.0 8224.5 8263.5 8263.5 8318.5 8318.5 8329.0 8329.5 8340.0 8340.5 8356.0 8356.0 8367.5 8367.5 8380.0 8379.5 8405.5 8405.0 8417.0 8417.0 8423.0 8423.0 8454.0 8454.0 8473.5 8474.0 8486.5 8486.5 8494.0 8494.0 8503.0 8503.0 8533.5 8533.5 8544.0 8544.5 8546.5 8546.5 8550.0 8549.5 8599.0 8599.0 8620.0 8620.0 8629.0 8629.5 8651.5 8651.5 8690.5 8690.5 for open hole logs run into casing. STOP DEPTH 9080.0 9082.0 EQUIVALENT UNSHIFTED DEPTH 8729.5 8744.0 8767.5 8780.0 8794.0 8821.5 8849.5 8864.5 8880.0 8886.5 8902.5 8924.5 8940.0 8960.0 8971.5 8986.5 9006.5 9012.5 9040.5 9067.0 9071.0 9082.0 $ REMARKS: CN WN FN COUN STAT 8729.5 8744.0 8767.5 8780.0 8794.0 8821.5 8849.5 8865.0 8880.5 8886.5 8902.0 8924.5 8940.0 8960.0 8971.0 8986.5 9006.5 9012.5 9040.5 9067.0 9070.5 9082.0 CASED HOLE MAIN PASS. FUCT, NUCT, TENS, & TEND WERE SHIFTED WITH NPHI. $ : ARCO ALASKA INCORPORATED : D.S. 14 - 43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 4 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 5 TEND 2435 68 1 LB 4 6 TENS 2435 68 1 LB 4 4 08 501 10 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 328 Tape File Start Depth = 9082.000000 Tape File End Depth = 3194.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 82440 datums Tape Subfile: 3 417 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS 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 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 2 0.2500 VENDOR TOOL CODE START DEPTH GR' 9018.0 AC 9080.0 DIFL 9018.0 2435 9018.0 $ 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) : STOP DEPTH 9639.0 9674.0 9703.0 9646.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP GR CN PCM KNJT KNJT AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT BHC-ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 03-NOV-92 FSYS REV. J001 VER. 1.1 2130 02-NOV-92 313 03-NOV-92 9700.0 9699.0 3200.0 9696.0 1800.0 TOOL NUMBER 3974XA 3967XA 2806XA 1309XA 2435XA 3506XA 3921XA 3921XA 1609EB/1603MA 1503XA 6.750 9083.0 9082.0 LOW SOLIDS LITE DISP 8.70 37.0 9.0 6.0 178.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 14 - 43 : PRUDHOE BAY : NORTH SLOPE : ALASKA 1.920 0.733 1.830 0.000 2.140 0.000 THERMAL SANDSTONE 0.00 6.75 1.5 68.0 178.0 68.0 0.0 68.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 CHT AC 68 1 LB 4 5 TTEN AC 68 1 LB 4 6 SPD AC 68 1 F/MN 4 7 RFOC DIFL 68 1 OHMM 4 8 RILM DIFL 68 1 OHMM 4 9 RILD DIFL 68 1 OHMM 4 10 SP DIFL 68 1 MV 4 11 VILM DIFL 68 1 MV 4 12 VILD DIFL 68 1 MV 4 13 CILD DIFL 68 1 MMHO 4 14 TEMP DIFL 68 1 DEGF 4 15 CNC 2435 68 1 PU-S 4 16 CN 2435 68 1 PU-L 4 17 CLSN 2435 68 1 CPS 4 18 CSSN 2435 68 1 CPS 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 53 419 67 0 4 04 522 10 6 4 04 522 10 6 4 34 704 23 6 4 40 467 34 0 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 72 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 215 Tape File Start Depth = 9713.000000 Tape File End Depth = 9017.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 69336 datums Tape Subfile: 4 295 records... Minimum record length: 62 bytes Maximum record length: 994 bytes 0'89 0g6'I 0'8£I 0'9 0'6 0'££ 0£'8 dSIG Milq SGIqOS MO~ 0'E806 0'[806 0§£ '9 0'008I 0'9696 0'00g£ 0'6696 0'00£6 E6-AON-£0 I0~ E6-AON-E0 0lie I'I 'MMA I00£ 'AMM SASd E6-AON-£0 0'09~6 0'8I§6 0'9£~6 ~'g§~6 :(CD) SSO~ :(S) RIISOOSIA : (s/~) XiisN~ SNOIIIGNOD : (Id) HidMg DNISVD S,MMDDO% : (Id) HidMg DNISVD :(NI)MZIS II~ M%OH NMdO ~i~g DNIS~D GN~ ~qOH~O~ O~ NO SI~ MdXi ~OOi MGOD %001 MOGNMA (~Oii08 Oi dOi) DNIMIS %001 : (MHdd) (I.q,qdS DNIDDO~I : (Id) %¥AM~qINI DO% : (Id) M,wsso~ ~i :~IOiiO~ NO %i,qOOO~I ,ql4Ii :G,~(]N,q NOIIYqflDMID .ql4Ii : NOIS%LqA ,qMYMidOS eSeaedes uTuna pue '6uTa~s IOO$ 'ss~d qoee zog e%ep zepeeq 6oi pue SeAanO SMSS~d IV.qd.qM M%OH N.qdO MYM 0£ EEO ~8 $ GE IIE 86 $ $£ £95 05 $ 0I EES ~0 ~ OI EE§ ~0 ~ £9 6I~ C§ ~ 90 C06 ~0 ~ 8£ CIE 90 ~ OC ~60 I9 ~ OC 8~ §6 ~ OC 8~§ ~6 ~ L~ ~SE I8 ~ 68 E§8 8~ ~ 6~ 696 90 $ SdO SdO q-ad S-nd OHN/4 AN AN AN NNHO NNHO N /a a/sn Id~D I 89 GC~E NSSD 8I I 89 §C~g NS%D £I I 89 5C~E ND 9I I 89 §CPC DND I 89 ~IQ dN~ I 89 q~IG G~ID I 89 ~IG G~iA I 89 q~IG dS 0I I 89 ~IQ Q~IM 6 I 89 ~IQ N~I~ 8 I 89 q~IQ OOg~ I 89 D~ Q~S 9 I 89 O~ N~&~ I 89 O~ iHO I 89 O~ bO~ I 89 O~ O~ I 89 O~ ~0 t ss!uR saldm~s apoo tool SmeN :SaAInO 8I ~ :GI qsdap adw& ~~ ~d HAd~Q ~NO (~9 ~dA~) QHOD~ ~tfkP~O~ ~ 0'0 0'89 0'0 0'89 0'SLI §L'9 00 '0 .qNOJ, SQNVS ~IVk~,qHJ, 000 '0 0~I 'E 000 '0 0C8 'I CC/_,'O ~MS~ : MdO~S H&HON : A~ MOHQ~Hd : £~ - 9I 'S'Q : QHAYMOdHODNI %Q{S~ ODH~ : i~S NROD NM ND ' SSVd ,T,V~[d~[%{ : SM%Ik54,qM : (ai) aaoaNws qooz Tape File Start Depth = 9527.000000 Tape File End Depth = 9143.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 111644 datums Tape Subfile: 5 197 records... Minimum record length: Maximum record length: 62 bytes 994 bytes 0 '0 000 '0 0 ' 89 0~I ' E 0 '0 000 '0 0'89 0£9'I 0'8£I ££L'0 0'89 0E6'I 0'8£I 0'9 0'6 0'££ 0£'8 dSIG Milq SGI%OS MO% 0'E806 0'~806 0§£'9 ~X£0§I v~o9t/~6o9t ~XIE6~ ~XIE6£ ~X90~ ~X60£I ~X908E ~X£96£ ~X~£6£ 0'008I 0'9696 0'00Eg 0'6696 0'00£6 E6-AON-g0 E6-AON-E0 0gIE I'I '~ZA I00£ 'A~ SASt E6-AON-g0 :(At) HAdMG DNIS~D :(At) HAdZG 9NIS~D S,~M~%IMG :(NI)MZIS AIG Z%OH NOI,I, DfIGNI ~ItfflG DO%IJ, SflOOtf-OH~ ,I, NIO£ ,q%5{OflNM J,NIO£ ,q~IMDflNM HOA~f~IflGON ,gGOO ,qS~Ifld NOtI,I, fIZN G,g,I,¥SNZdNOD ~flS NOI,I,%f~OSI SS¥~4 NOI SN.~,L Gtf,~H~i~tfD NOd ND SIN 0'E806 0'0806 :(At) %~AHZANI :NOAAO~ NO ~Z990~ :GZGNZ NOIA~%~D~ID :NOIS~ZA :G~DDO~ 0'0008 0'~6I[ HAd~G A~AS ~GOD %00A ~OGN~A 00§E'0 § :~R~IN SS~d · 6u!seo osu! una s6oI aIOg uado ao~ ~$ep a~p~ag 6oi pu~ SaAanO SS~ NI%fN ~OH G~S~D M~ :~Wi1N Z~I~ ~G~H ~I~ SIq :adX$ s! 9 at!~qns admA NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: CASED HOLE MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 14 - 43 : PRUDHOE BAY : NORTH SLOPE : ALASKA THERMAL SANDSTONE 0.00 9.875 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNC 2435 68 1 PU-S 4 3 CN 2435 68 1 PU-L 4 4 CLSN 2435 68 1 CPS 4 5 CSSN 2435 68 1 CPS 4 6 CHT 2435 68 1 LB 4 7 TTEN 2435 68 1 LB 4 8 SPD 2435 68 1 F/MN 4 9 TEMP 2435 68 1 DEGF 4 4 08 501 10 0 4 98 211 23 1 4 52 326 75~ 5 4 84 023 70 1 4 83 368 34 1 4 19 912 29 5 4 19 912 29 5 4 54 376 29 5 4 18 487 70 6 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 954 Tape File Start Depth = 9154.000000 Tape File End Depth = 3194.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 307747 datums Tape Subfile: 6 1027 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 7 is type: LIS 92/11/ 7 01 **** REEL TRAILER **** 92/11/10 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 10 NOV 92 9:08a Elapsed execution time = 1 minute , 36.7 seconds. SYSTEM RETURN CODE = 0
