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Home My WebLink About195-141 WELL LOG TRANSMITTAL DATA LOGGED Ce NIP/201 g M.K.BENDER To: Alaska Oil and Gas Conservation Comm. May 27, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 E CF D JUN 04 201J RE: Leak Detect Log with TMD3D: 1Q-23 � , Run Date: 5/20/2015 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 FRS_ANC@halliburton.com 10-23 Digital Data in LAS format, Digital Log file 1 CD Rom 50-029-22596-00 SCANNEDJUL 2.01 Leak Detect Log with TMD3D (Field print) 1 Color Log 50-029-22596-00 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 Signed: Date: 1))444414L1 195141 25 476 WELL LOG TRANSMITTAL DATA LOGGED /G/2O15 M K.BENDER To: Alaska Oil and Gas Conservation Comm. February 26, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAR 0 6 2015 RE: Multi Finger Caliper(MFC)/Leak Detect Log: 1Q-23 AOGCC Run Date: 2/15/2015 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 FRS_ANC@halliburton.com 10-23 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22596-00 Leak Detect Log 1 Color Log 50-029-22596-00 SEWED 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: ..E:4"_""C Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ¢~-/~/ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Diann~athan Lowell Is/ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl • COI'IOCOP~'l l l I I p5 Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 4, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • tq` ~~~~3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 20, 2008 and the corrosion inhibitor/sealant was pumped December 2-3, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, t~~ {~ ~ ~~~~ ~~' 20U8 Perry Klei ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Well Name PTD # 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 al 1 Q-01 184-231 10' 1.25 22" 11 /20/2008 6.80 12/2/2008 1 Q-04 184-234 10' 1.25 22" 11 /20/2008 3.40 12/3/2008 1 Q-07A 198-234 9' 1.10 24" 11 /20/2008 2.95 12/3/2008 1 Q-08A 197-093 8' 1.00 22" 11 /20/2008 3.40 12/3/2008 1 Q-09 184-192 2" NA 2" NA 4.25 12/2/2008 1Q-11 184-199 4'5" 0.50 22" 11/20/2008 4.25 12/2/2008 1Q-12 184-193 21" NA 21" NA 6.80 12/2/2008 1 Q-13 185-044 18" NA 18" NA 5.10 12/2/2008 1 Q-14 185-045 24" NA 24" NA 4.25 12/2/2008 1 Q-23 195-141 24" NA 24" NA 3.40 12/3/2008 ARCO Alaska, Inc. Date' December 26, 1995 Transmittal Cf' 9311 RETURN TO: ARCO Alaska, inc. Attn.' Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. ctj:: ~"? All items below include BOTH Blueline and Sepia. ~ ~, 2A- 18 CBL 10/15/95 ,~'-~'~'f 2T-32 CBL 10/19/95 ,].r- t~-. 2T-36 CBL 10/20/95 qb'-~;z. 1Q-26 CBL 10/24/95 ct~--~ ~1 1 Q-23 CBL 10/24/95 5800-6655 13130-13636 14990-15325 5900-6885 87O0-9866 Acknowledge' Date' · DISTRIBUTION' Sharon AIIsup-Drake DS Development ATO-1205 Larry Grant (+sepia) -AOGCC :3001~ Porcupine Drive ~Ancho'_r-age,: AK 99501 Erickson/Zuspan NSK Central Files NSK-box 69 .o Oil & Gas Cons. Commission ARCO Alaska, Inc. Date: December 26, 1995 Transmittal #: 9310 RETURN TO: ARCO Alaska, Inc. Attn · Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-27 r 2T-32 2T-30 2V-06 2T-31 f2T-36 ~-2T-36 /?2%38 }_2.T-38 2%37 1 Q-24 1 Q-26 1Q-23 CDR 04/17/95 REF CDN 04/30/95 REF CDR 04/30/95 REF CDR 05/12/95 REF TDTP 06/11/95 REF CDR 0713/95 REF CDR 07/25/95 REF CDN 07/25/95 REF CDR 08/03/95 REF CDN 08/03/95 REF CDR 08/10/95 REF ARC5 Array Resistivity Comp. 08/30/95 ARC5 Array Resistivity Comp. 09/22/95 ARC5 Array Resistivity Comp. 09/30/95 Acknowledged: DISTRIBUTION' Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Erickson/Zuspan NSK Central Files NSK 69 Sharon AIIsupoDrake DS Development ATO - 12O5 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Date' #50-103-20217 #50-103-20218-00 ¢50-103-20218-00 ¢50-103-20219-00 #95219 ¢50-103-20226-00 ¢50-103-20228-00 ¢50-103-20228-00 ¢50-103-20229-00 ¢50-103-20229-00 ¢50-103-20227-00 4206-7270 3820-7010 5156-9982 RECEIVED DEC 2 7 1995 Clifton Posey Geology ATO - 1251 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner DATE: May 17, 2001 THRU: Tom Maunder, P. !. Supervisor FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit lQ Pad May 17,2001: i traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, the SSV on 1Q-05 would not pass the DP test. The valve was serviced & would not pass the re-test. Well 1Q-05 is shut in until repaired & re-tested. The AOGCC test report is attached for reference. I inspected 20 well houses on lQ Pad w/no problems witnessed. SUMMARY: I witnessed SVS testing in Kuparuk River Field. 15 wells, 30 components tested. 1 failure witnessed. 3.33% failure rate. 20 well houses inspected. Attachmeqts.: SVS KRU lQ 5-17-01jc CC; N.ON-CONFIDENTIAL SVS KRU lQ 5-17-01jc Alaska Oil and Gas Conservation Commiss.on Safety Valve System Test Report Operator: Phil!ips Alaska Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Kup., ,a~ River Unit lQ p.ad...~ Separator psi: LPS 85 HPS 5/17/01 Well permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, ,~umber Numbe? , PSI PSI TriP , Code Code Code Passed GASorCYCLE 1Q-02A 1951940 lQ-03 ,11842}30 85 . ,. 70 ,. "65 ~ P'. P ........... OIL lQ-04 1842340 85 , 60 ..5~ P .. ~ .... ' i OIL lQ-05 1842170 85 ., 70 ,54 P 4... .......... OIL 1Qr06 ,, 1842080 85 60 55 p p OIL lQ-09 '1841920 "'3750 .... 2000~ 1900 'P" ' ~ .... WAG 1Q~lO ....... 1841980 85 ,7Q ~ P .. , P....... OIL lQ-11 1841990 1Q_12" ' 1841930 ......... 1Q7!5,, 1850460 ............ ,1Q71,6 , 18504~0 ' 85 70 ~4 'P" e OIL 1Q-20A 19~1560 85 70 ' ~0 P e OIL ,3Q-21 ,1951330 .... 1Q-22 1951400 85 ..... 76'" ~5 p e OIL ~1Q-23 "1951410 " '85 .... 70 50 P P .... 0I~ 1.Q-26. 1951320 '" 85 " 70 52 P' P .... oIL ilQ-08 1970930 '3750 "'2000 1850 " ~' P ....... WAG lQ-13 1850440 3750 2000 " 1850 e P ....... WAG lQ-14 1850450 3750 2000 185° ,e I, P ,,. WAG 1Q-~4 ,1951210.. 3750 2000 2100 ,P ,.P .... . WAG Wells: 15 Components: 30 Failures: 1 Failure Rate: 3.33% [3 9o oar Remarks: 1Q-05 was serviced & re-tested, re-test failed & well was shut in for repairs. . RJF 1/16/01 Page 1 ofl SVS KRU lQ 5-17-01jc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 94 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 1563' FNL, 1225' FEL, Sec. 26, T12N, R9E, UM (asp'$ 528398, 5984312) 1Q-23 At top of productive interval 9. Permit number / approval number 602' FNL, 630' FEL, Sec. 25, T12N, R9E, UM (asp's 534270, 5985298) 195-141 At effective depth 10. APl number 50-029-22596 At total depth 11. Field / Pool 500' FNL, 95' FEL, Sec. 25, T12N, R9E, UM (asp's 534803, 5985397) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9982 feet Plugs (measured) Tagged PBTD (2/17/00) @ 9621' MD. true vertical 6862 feet Effective depth: measured 9621 feet Junk (measured) true vertical 6579 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 100 Sx AS I 121' 121' SURF CASING 5058' 7-5/8" 840 Sx AS II, 440 Sx G 5152' 3886' PROD CASING 9878' 5-1/2" 170 SX Class G 9972' 6784' Perforation depth: measured 9202 - 9227'; 9322 - 9354'; 9624 - 9654' RECEIVED true vertical 6250- 6270'; 6345- 6370'; 6582- 6605' ~' E~ E~ ~_ 6 2 0 0 t Tubing (size, grade, and measured depth) 3.5 / 2.875", 9.3# / 6.5#, L-80 Tubing @ 9135' MD. Alaska 0il & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) Baker 'SABL-3' Packer w/K-22 Anchor Seal Assy @ 9111' MD. Camco 'DS' Landing Nipple 2.856" No-Go 2.812" ID @ 498' 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-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 664 1930 2021 223 Subsequent to operation 1219 3437 2218 249 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations .__X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. · Prepared by John Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1Q-23 DESCRIPTION OF WORK COMPLETED PERFORATING & HYDRAULIC FRACTURE TREATMENT 2/4/00: MIRU & PT equipment. RIH w/perforating guns & shot 25' of perforations in the 'C4' sand as follows: Added perforations at: 9202- 9227' MD Used 2-1/8" Enerjet BH carriers & shot the perfs at 2 spf at 90 degrees CCW. POOH w/guns. RD. 2/6/00: MIRU & PT equipment. RIH w/perforating guns & shot perforations in the 'C4' sand as follows: Reperforated at: 9202 - 9212' MD, and 9212 - 9227' MD Used 2-1/8" Enerjet carriers & shot the upper 10' of perfs at 4 spf at 180 degree phasing, and the bottom 15' of perfs at 2 spf at 90 degrees CCW. POOH w/guns. RD. 2_J7/00 - 2/9/00: Pumped 3 batches of gelled sand slurry to place an isolation sand plug across the lower 'C1' & 'A3' open perforation intervals located at: 9322-9354' MD 9624- 9654' MD Tagged final top of isolation plug (2-9-00) at 9290' MD. 2/9/00: MIRU & PT equipment to 9200 psi. Pumped a 'C4' Sand Hydraulic Fracture Treatment using 16/20 mesh proppant, through the perforation interval located above the isolation plug at: 9202- 9227' MD Pumped Breakdown: a) 150 bbls 20# Linear Gel @ 25 bpm, followed by b) Shutdown. Resumed pumping Scour Stage: c) 75 bbls Gelled Pad, followed by d) 40 bbls Scour Stage w/1 ppa proppant concentration, followed by e) 126 bbls Flush @ 18 bpm, followed by f) Shutdown. Resumed pumping Data Frac: g) 200 bbls Pad @ 18 bpm, followed by h) Shutdown. ISIP @ 2035. Resumed pumping Frac Treatment: RECEIVED FEB I 6 Z001 Alaska 0il & Gas Cons. Commission Anchorage i) 80 bbls Pad, followed by j) Crosslinked Slurry stages w/proppant ramped up from 1 to 10 ppa, followed by k) 57 bbls Flush, followed by I) Shutdown. Placed a total of 75,000 lbs of proppant into the formation. RD. 2/10/00: Performed a CT proppant & isolation plug fill cleanout to 9851' MD. Returned the well to production & obtained a valid well test. oN oR BEFO c:t.o~~D°c --- STATE OF ALASKA ~: ALA'_ . OILAND GAS CONSERVATION COMIc. 31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 41' RKE 3. Address: Exploratory __~ 7. Unit or Property: P.O. Box 100360 Stratagrapic __, Anchorage, AK 99510-0360 Service ._~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1563' FNL, 1225' FEL, Sec 26, T12N, R91=, UM 1Q-23 At top of productive interval: 9. Permit number/approval number: 576' FNL, 493' FEL, Sec 25, T12N, R9E, UM 95-141 At effective depth: 10. APl number: 512' FNL, 156' FEL, Sec 25, T12N, R9E, UM 50-029-22596-00 At total depth: 11. Field/Pool: 500' FNL, 95' FEL, Sec 25, T12N, R9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 9982 feet Plugs (measured) None true vertical 6862 feet Effective Deptt measured 9882 feet Junk (measured) None true vertical 6784 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 100 Sx AS I 121' 121' Surface 5125' 7.625" 840 Sx AS III & 5152' 3914' 440 Sx Class G Production 9942' 5.5" 170 Sx Class G 9972' 6854' Uner Perforation Depth measured 9322'-9354'; 9624'-9654' true vertical 6345'-6370'; 6582'-6605' . Tubing (size, grade, and measured depth) Mixed 3.5", 9,3 Ib/ft & 2.875, 6.5 lb/fi, L-80 @ 9148 ~.... Packers and SSSV (type and measured depth) ~ ,: Packer: Baker SABL-3 @ 9124'; SSSV: None, nipple @ 511' ....:..:i::~ :.. ' .... · '" 13. Stimulotion or cement squeeze summory Perforate "C-1" sand on 4/6/98, Intervals treated (measured) ~"'~'~ ."`,% i ~''': ~ ~ '"' /~!~ i Treatment description including volumes used ond finol pressure Perforate using 2,125" Enerjet guns w/DP charges @ 4spf. fp was 1800 psi, 14. Represenfitive Doily Averoge Production or Injection Doto Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 166 '34 294 1400 231 Subsequent to operation 264 70 606 1395 226 15'. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~ Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Production Engineering Supervisor Date Form 10-404 Rev SUBMIT IN DUPUCATE~~ .,aska, Inc. i~.. ~- KUPARUK RIVER UNIT 'R, K1(1Q-23(W4-6)) WELL JOB SCOPE JOB NUMBER 1 Q-23 PERFORATE, PERF SUPPORT 0328981843.2 , ' DATE DAILY WORK UNIT NUMBER 04/06/98 PERFORATE DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON 'SUPERVISOI~ " 2 (~) Yes O No! (~) Yes O No BARTZ . JONE,.S/1/I /) /~ . FIELD AFC# CC# DALLY COST ACCUM COST ESTIMATE KAWWRK 230DS10QL $14,914 $22,407 Initial Tbg Press 'Final Tbg Press Initial Inner Ann Final Inner Ahn ~ Initial Outer,~flh- ~ Final Out6r A'~in 1400 PSI 1800 PSI 1400 PSI 1400 PSII 200 PSI! 200 PSI DAILY SUMMARY PERFORATED C-1 SANDS WITH 32'2 1/8' ENERJET DP FROM 9322' TO 9354'. I TIME LOG ENTRY 10:30 SWS MIRU (BARTZ & CREW). TGSM (PERFORATING SAFETY), MU GUNS & REWIRE FIRING HEAD. RU & TESTED LUB & BOP TO 3000#. 13:30 RIH W/20' 2 1/8" ENERJET DP 4 SPF STRAIGHT DOWN SHOT, CORRILATED TO GR/CBT (10/24/95). PERFED FROM 9334' TO 9354'. 16:45 POH & LAY DOWN GUN, ALL SHOTS FIRED. 18:30 MU 12' GUN AS ABOVE. RU & TEST LUB & BOP. 19:00 RIH W/12' GUN AS ABOVE, CORRILATED TO ABOVE LOG & PERFED FROM 9322' TO 9334'. 21:15 POH & LAY DOWN GUN, ALL SHOTS FIRED. 23:30 RIG DOWN MOVE OFF. . SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $1,000.00 $2,500.00 DIESEL $0.00 $714.00 HALLIBURTON $0.00 $4,019.07 LITTLE RED $0.00 $1,260.00 SCHLUMBERGER $13,914.50 $13,914.50 I[OTAL FIELD ESTIMATE $14,914.50 $22,407.57 /:~PC: b L. Bi./_,r~F/,.,,. ~t£(,,,--, ~'i'?,k 95 .... '!a. 1 ,3EJ, L ~ SEF'IA $7d0--'-- ~,~ 'j A F' e d F" ::,/ W a s i: h e d "¥ t:: c h s a rn p 'i e ~ ',^/e i i c o r" e d ? WeJ 1 'is "i:t'~ c,:::,rnpl'¥ance ....... .~. ., I r-, '¥ 't i'a'i DAILY WELL ()PS ~ ~/26"!ql-/' TO 1i15 [f'% / ~"/,~1 /,'c(,~/' r" e q u 'Y ~'" e ,.'J ? y e s ~/:,, i", d r' e c e i' v e. ,'.:::! ? ';.' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X__ Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1563' FNL, 1225' FEL, Sec 26, T12N, R9E, UM At top of productive interval 576' FNL, 493' FEL, Sec 25, T12N, R9E, UM At effective depth 512' FNL, 156' FEL, Sec 25, T12N, R9E, UM At total depth 500' FNL, 95' FEL, Sec 25, T12N, R9E, UM i12. Present well condition summary Total Depth: measured true vertical 9982 6862. 6. Datum elevation (DF or KB) RKB 41 7. Unit or Property name Kuparuk River Unit 8. Well number 1 Q-23 9. Permit number/approval number 95-141 10. APl number 50-029-22596-00 11. Field/Pool feet feet feet Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 9 8 8 2 true vertical 6 7 8 4 feet feet Junk (measured) None 13. 14. Casing Length Structural Conductor 8 O' Surface 51 2 5' Intermediate Production 9 9 4 2' Liner Perforation depth: measured 9329'-9349', true vertical 6350'-6366', Tubing (size, grade, and measured depth) Mixed 3.5", 9.3#/ft. & 2.875", 6.5#/ft. Packers and SSSV (type and measured depth) Packer: Baker SABL-3 @ 9124; SSSV: Stimulation or cement squeeze summary Perforate 'C' sand interval on 4/11/97. Intervals treated (measured) 9329'-9349' Size Cemented 16" 100SxAS I 7.625" 840 Sx AS III & 440 Sx Class G 5.5" 170 Sx Class G Measured depth True vertical depth 121' 1'21' 5152' 3914' 9972' 6854' 9624'-9654' 6582'-6605' L-80 @ 9148' None, nipple @ 511' Alas~_a_ .Oi! & Gas Cons. Treatment description including volumes used and final pressure Perforated using 2-1/8" EJ guns w/ BH charges @ 4 SPF, fp = 1200 psi. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 262 213 0 1010 226 Subsequent to operation 461 271 187 1026 220 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations I16. Status of well classification as: Oil X__ Gas Suspended Service 17. I her~/~certify that the foregoing Signed Form ~"0:-~2, d4- ,R/e v ~'6 e/ff'~/88 is true and correct to the best of my knowledge. Title Wells Superintendent Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,4~, WELL SERVICE REPORT '~ K1(1Q-23(W4-6)) WELL JOB SCOPE JOB NUMBER 1 Q-23 PERFORATE, PERF SUPPORT 0409971633.3 DATE DAILY WORK UNIT NUMBER 04/11/97 PERFORATE "C" SANDS F/9329- 9349' ELM UNIT #1 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O NoI (~) Yes O No SWS-BAILEY BLAC,.~. FIELD AFC_~ CC# DAILY COST ACCUM COST e~"-'~'~~r~n~~i~--- ESTIMATE KAWWRK 230DS10QL $10,785 $10,785 I I Final Ann Initial Tb.q Press Final Tb_q Press Initial Inner Ann Final Inner Ann Initial Out Outer 1200 PSI 1 200 PSI 1350 PSI 1350 PSI 250 PSI 250 PSI DAILY SUMMARY PERFORATE F/9329 - 9349' ELM W/2-1/8" EJ BH @ 2 SPF +/- 90 DEG F/LOW SIDE 180 DEG PHASED (4 SPF TOTAL/ TIME 11:00 12:30 14:30 16:30 LOG ENTRY MIRU SWS (BAILEY & CREW). MU GA#1 (2-1/8" EJ/CCL/VVT) TL-34.5'. PT BOPE TO 3000 PSI. RIH W/GA#1 TO 9600' ELM. TIE IN TO 10/24/95 SWS GR/CBT. PERFORATE F/9329 - 9349' ELM W/2-1/8" EJ BH @ 2 SPF (+90 DEG F/LOW SIDE). POOH. ALL SHOTS FIRED. MU GA#2 (SAME AS BEFORE). PT. RIH, TIE IN & PERFORATE F/9329 -9349' ELM W/ SAME AS ABOVE (-90 DEG F/LOW SIDE). POOH OOH. ALL SHOTS FIRED. RD SWS. 18:00 OFF LOCATION. TURN OVER TO PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $700.00 $700.00 LITTLE RED $440.00 $440.00 SCHLUMBERGER $9,645.00 $9,645.00 TOTAL FIELD ESTIMATE $1 0,785.00 $10,785.00 STATE OF ALASKA AU-,,SKA OIL AND GAS CONSERVATION CON,,,,,:SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS i---] SUSPENDED [~] ABANDONED [] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-141 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22596 4 Location of well at surface 9 Unit or Lease Name 1563' FNL, 1225' FEL, Sec. 26, T12N, RDE, UM! i;"~,~'i';:~'¥:':::; ! Kuparuk River Unit ~ ,/ %'t, ~ ' LV~h lO WellNumber At Top Producing Interval ~. ~ ~,~,~ At Total Depth ~' 11 Field and Pool 500' FNL, 95' FEL, Sec. 25, T12N, RDE, UM "~'~ ~'~.~-~: ........ ,~,~; KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. RKB 41', Pad 53' ADL 25641 ALK 2572 12 Date Spudded 13DateT. D. Reached 14 DateComp.,Susp. orAband. 115 Water Depth, ifoffshore 116 No. of Oompletions September 24, 1995 September 30, 1995 13-Jan-96 (perf'd) NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey J20 Depth where SSSV set 21 Thickness of permafrost 9982' MD & 6862' TVD 9882'MD&6784'TVD YES xL~ NO L_]I NA feetMD =1380'ss APPROX 22 Type Electric or Other Logs Run ARC5/GR, GR/CCL/CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT R~CORD 16" 151.53# X-65 SURF. 121' 24" 100 sx AS 7.625" 29.7# L-80 SURF. 5152' 9.875" 840 sx AS III Lead, 440 sx Class G Tail 5.5" 15.5# L-80 SURF. 9972' 6.75" 170 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" X 2-7/8" 9148' 9124' 9624'-9654' MD 4spf 6582'-6605'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9624-9654' 7#PPA 12/18 Prop. at perfs, 21441 # proppant in pipe, 64700# proppant to formation 27 PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) 4/15/96] Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 4/"30/96 24 TEST PERIOD I~ 344 382 0 209I 1111 FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 223: 563 24-HOUR RATE I~ 344 382 0 =24° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 0RIGINAL ~ : Alaaka Oil & Cas Certs. commission ^nchora~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 9195' 6245' Bottom Kuparuk C 9368' 6381' Top Kuparuk A 9581' 6548' Bottom Kuparuk A 9738' 6671' 31. LIST OF A]-I-ACHMENTS Daily Drilling History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed J~-.~ '~~' ~. ~ ~., ~ ~_.._~._ Title 0 I~. t.l.'Cr,.I (.,-E~,'/.N ,E ~. DATE ~' "Z0 ' q6 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~e' 2/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 1 WELL'lQ-23 RIG:PARKER 245 WELL ID' AK8301 AFC' AK8301 TYPE: -- STATE'ALASKA AREA/CNTY' NORTH SLOPE EAST FIELD' KUPARUK RIVER UNIT SPUD:09/24/95 START COMP: BLOCK: FINAL: WI' 0% SECURITY:0 AFC EST/UL:$ 1310M/ API NUMBER: 50-029-22596-00 OM 09/24/95 ( 1) TD: 790' (790) SUPV'RLM DAILY' 09/25/95 ( 2) TD: 5134' (4344) SUPV'RLM DAILY: 09/26/95 (3) TD' 5165' ( 31) SUPV' RLH DAILY: 09/27/95 (4) TD. 5165' ( O) SUPV' RLM DAILY' 09/28/95 (5) TD' 6898' (1733) SUPV'RLH DAILY: 09/29/95 ( 6) TD: 9485' (2587) SUPV'RLH DAILY' 09/30/95 ( 7) TD: 9842' (357) SUPV'RLM DAILY' 10/01/95 ( 8) TD' 9982' ( 140) SUPV'RLH DAILY' 10/02/95 ( 9) TD' 9982' ( 0) S UPV' RLH DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING Move rig from 1Q-26 to 1Q-23. Accept rig at 2230 on 9/23/95. Directional drill 9-7/8" hole from 121' to 790' $84,245 CUM: $84,245 ETD: $0 EFC: $1,394,245 MW: 10.1 PV/YP: 22/20 APIWL' 7.3 DRILLING Directional drill 9-7/8" hole from 790' to 5134'. $78,782 CUM: $163,027 ETD: $0 EFC: $1,473,027 MW: 10.0 PV/YP: 15/ 8 APIWL: 8.8 LIFT DIVERTER Directional drill 9-7/8" hole from 5134' to 5165' Run 7-5/8" casing. Cement casing. CIP at 0500 hfs 9/26/95. $164,381 CUM: $327,408 ETD: $0 EFC: $1,637,408 MW' 8.7 PV/YP' 3/ 2 APIWL' 20.0 POOH Top job casing with AS III. CIP at 0650 hfs 9/26/95.Test all BOPE. $108,389 CUM' $435,797 ETD' $0 EFC' $1,745,797 MW: 9.0 PV/YP: 6/ 4 APIWL: 14.4 DRILLING Drill cement from 5045', float collar at 5065', cement, float shoe at 5152' and 10' new hole to 5175' Directional drill 6.75" hole from 5175' to 6898' $87,722 CUM' $523,519 ETD: $0 EFC' $1,833,519 MW: 11.3 PV/YP: 21/16 APIWL: 4.0 DRILLING Directional drill 6.75" hole from 6898' to 9485' $96,142 CUM' $619,661 ETD' $0 EFC' $1,929,661 MW: 11.5 PV/YP' 22/20 APIWL' 4.2 DRILLING Directional drill 6.75" hole from 9485' to 9842'. $80,665 CUM: $700,326 ETD: $0 EFC: $2,010,326 MW: 11.6 PV/YP: 19/15 APIWL: 4.4 RUNNING CASING Directional drill 6.75" hole from 9842' to 9982' Run 5.5" casing. $79,224 CUM: $779,550 ETD: $0 EFC: $2,089,550 MW' 11.6 PV/YP' 20/15 APIWL- 4.4 FLANGE UP 7" VALVE Run 5.5" casing. Cement casing. CIP at 0042 hrs. 10/2/95. $145,501 CUM' $925,051 ETD' $0 EFC' $2,235,051 2/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 10/03/95 (10) TD: 9982' ( 0) SUPV:RLM DAILY: RIG RELEASED Freeze protect hfs 10/2/95. $29,964 CUM: MW: 0.0 PV/YP: 7-5/8" x 5.5" annulus. $955,015 ETD: 0/ 0 APIWL: 0.0 Rig released @ 1200 $0 EFC: $2,265,015 RECEIVED bt, AY ?. 'i '1996 Alaska Oil & C~,a [1on,~. Co~nmission Anchorage 2/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 3 REMEDIAL AND COMPLETION OPERATIONS WELL'lQ-23 RIG'PARKER 245 WELL ID' AK8301 AFC' AK8301 TYPE' -- STATE'ALASKA AREA/CNTY' NORTH SLOPE EAST FIELD' KUPARUK RIVER UNIT SPUD'09/24/95 START COMP' BLOCK' FINAL' WI: 0% SECURITY'0 AFC EST/UL'$ 1310M/ OM AP1 NUMBER: 50-029-22596-00 12/24/95 (11) TD' 9982' PB' 9882' SUPV'BP DAILY: 12/25/95 ( 12} TD' 9982' PB' 9882' SUPV'BP DAILY' R/U TO RUN COMPLETION MW: 0.0 SW Move rig from 3C pad to lQ pad. Accept rig @ 1200 hrs., 12/23/95. Function test BOPE. Test rams & choke manifold to 250/3500 psi, annular to 250/3000 psi, all floor valves to 3500 psi. Test 5-1/2" casing to 3500 psi for 30 min., OK. $43,400 CUM: $998,415 ETD: $0 EFC: $2,308,415 RIG RELEASED MW: 0.0 Run 2-7/8" x 3-1/2" completion assembly. Pressure tubing to 2500 psi for 30 min. to set packer and test tubing. Bleed tbg pressure to 500 psi and pressure annulus for annulus test - showed communication to tbg. Pressured tbg to 3000 psi for 10 min to set pkr, then repeated annulus test to 2500 psi w/500 psi on tbg for 15 min., OK. Pressure tbg several times to 4200 psi w/no indication of shear-out sub shearing. Bleed off tbg pressure and pressure annulus to shear dump-kill valve - sheared at 2800 psi. Freeze protect annulus. Test packoff to 5000 psi for 15 min., OK. Test tree to 250/5000 psi. Secure well, RDMO. Rig released @ 0330 hrs., 12/25/95. $123,001 CUM: $1,121,416 ETD: $0 EFC: $2,431,416 End of WellSummary for Well.AK8301 Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1Q-23(W4-6)) WELL JOB SCOPE JOB NUMBER 1Q-23 PERFORATE, PERF SUPPORT 1 228951 621.5 UNIT NUMBER DATE 01/13/96 DAY 2 DALLY WORK PERFORATE 'A' SAND OPERATION COMPLETE I SUCCESSFUL I KEY PERSON YES YES SCHWARTZ SUPERVISOR PAIGE DAILY SUMMARY PERFORATED 'A' SAND INTERVAL 9224'-9254' (REF GR DATED 9/30/95) USING 2-1/8" EJ W/BH CHARGES, 4 SPF, ORIENTED +/- 90 I DEG F/LOWSIDE, 180 DEG PH. WELL WAS SHOT W/0 PSI ON WELLHEAD; PRESSURE INCR TO 150#. I TIME LOG ENTRY 20:00 MIRU SWS. HELD SAFETY MTG. 22:00 23:00 23:15 23:45 01:00 01:30 02:00 03:00 PT LUB TO 3000#; TEST OK. RIH W/CCL, GUN#1 - 2-1/8" EJ W/BH CHARGES, 2 SPF, ORIENTED 90 DEG CCW F/ LOWSIDE, 0 DEG PH TO SHOOT 9624'-9654' (REF GR DATED 9/30/95) HAVING TROUBLE GETTING DOWN; POH TO ADD ADD'L WGT. AT SURF W/GUN#1 PT LUB TO 3000#; TEST OK. RIH W/WGT. BAR, CCL, GUN#1 - 2-1/8" EJ W/BH CHARGES, 2 SPF, ORIENTED 90 DEG CCW F/LOWSlDE, 0 DEG PH TO SHOOT 9624'-9654' PER GR DATED 9/30/95 FIRED GUN#1 TO SHOOT 9624'-9654' (REF GR DATED 9/30/95); POH AT SURF W/GUN#1; ALL SHOTS FIRED. 03:30 05:00 RDFN. PT LUB TO 3000#; TEST OK. RIH W/WGT. BAR, CCL, GUN#1 - 2-1/8" EJ W/BH CHARGES, 4 SPF, ORIENTED 90 DEG CW F/LOWSlDE, 0 DEG PH TO SHOOT 9624'-9654' (REF GR DATED 9/30/95/ FIRED GUN#2 TO SHOOT 9624'-9654' (REF GR DATED 9/30/95); POH AT SURF W/GUN#2; ALL SHOTS FIRED. PA~E NO, *********************************************************** ********* ANA~K~.~ ********** *********** SURVEY PROGRAM ********~** COMPANY WELL NAME !0-23 LOCATION ! XUPARU~ LOCATION 2 ALASKA MAGNETIC DECL!NAT!~JN BATE: WELL NUMBER 0 AP! WELL ~: 50-02~-22596-00 A~E AK830! ~ELL HEAD LOCATION: AZIMUTH FROM ROTARY ?ABLE TO TARGET TIE !N POiNT(TiP) MEASURE~ DEPTH 121,00 TRUE VERT DEPTH 12!,00 INCLINATION AZIMUTH LA~!?UDE(N/-S) 0,00 DEPARTURE(~/-W) OEP(E/-~) 0,00 80,58 RECEIVED i996 =- DEPTH DEPTH ft ft ft 121.00 0,0 121,00 460.00 339,0 4-59,96 o6~,24 201,~ .., S46,1Z 184.9 ~46,00 ?35,52 ~9,4 935,37 1029,31 1123,34 !214,99 !308,83 !400~5 !4¢0,4~ 1578.77 !672,x~ 1763,19 1~54,08 1949,75 2039,75 2130,55 2223,59 '2315,24 2409,59 2501,20 2596.17 2691.45 3063,39 3337,66 3614.93 3894,78 4445,3~ 4723.6? 4997,11 5080,4~ 56i0,61 5892,23 6!65.86 h444.28 67!8.55 93,8 !029.09 94,0 !122~79 91,6 12!3.72 93,8 !306,33 92,! 1396,32 ~?.5 i482,60 88,3 1566,20 93,8 1052,84 90,6 1734,46 90,9 1814,93 95,7 1897,84 90,0 !973,52 90.8 2047,42 93.0 2120,23 91,7 2188,85 94,4 2256,36 9!,6 2318,7t 95,0 2379,72 95,3 2436,88 91,2 2~89,08 2~0,8 2653,57 274,3 2818,17 277.3 29)1,93 279.9 3149,14 _~7/.q 3316,05 278,3 3639,79 ~., 4 3799,72 83,3 3846,49 247,8 39~4,88 282,3 4!41.56 28!.6 4294.95 273,6 4440,82 278,4 4589,90 274,3 4736,72 TARGET STATZ[!N AZIMUTH · T~ ~" ECT~uN T. NCLN, ft deg de9 ft 0,00 ~ v,vv 0,00 0~00 -3,4~ 1,50 2~9,00 2,!5 -.,.0 1,37 31,.~'~ 8,43. ft ft deg 0,00 0,00 0,00 -3,~ 4,~4 299,00 -4,87 7,02 316,03 -2.5i 8,60 343,4i -1,36 10.51 352,57 DLS ~eg/ lOOf~ 0,00 0,44 1,03 0,13 0,24 3,49 2,99 62.82 i2,67 i,44 12,75 6,48 2,03 !!.07 6,42 75,53 15,t! 8,71 !7,44 29,97 3,79 22,49 7,93 78,87 17,61 19,~8 26,56 48,46 1,11 37,59 10,60 8!.07 20,20 34,75 40,20 59,83 2,87 57,22 !4,02 Sl,89 23.05' 54,!8 58,69 66.92 3,72 6!,02 !6,83 ~2,44 2~,32 77,76 82,0? 109,39 20,70 83.62 29,73 !05,95 110.05 .... 4,4~ ,6? 34,, . 1 , 145 ., 184,59 26,96 83,23 3B,65 t80,67 184,B0 226,80 28,44 82,46 44,!i 222,58 226.?I 274+49 31,40 82,03 50,56 269,$5 274,55 323,15 34,10 82,46 57,12 318,09 323,18 375,84 36,94 83,81 63,4'0 370,46 375,85 433,66 40,05 83,58 69,76 428,01 433,66 494,33 42,99 83,42 76,64 488.37 494.35 560.13 45,64 84,20 83.74 553,90 560,19 627,10 48,56 84,15 90,54 620,65 627.22 699,75 ..,"' 48 83,45 98,41. 692,99 699,94 775,86 54.77 83,29 !07.2! 768,68 776,12 850,53 55,38 83,04 116,1I 842,90 850.86 1077,6! 52,S9 83.47 142,86 1296,(8 53.35 83,80 167,!6 I520,49 54,26 80,95 196,89 ~,67 52,36 99.61 234,73 .t,l '3"r ; · 2!88,23 54,99 ~!,06 307,93 2412,86 52,67 79,53 345,75 2634,58 r5,72 80,67 363,84 2703,56 56,01 90,37 395,20 ~oOO,i~ ~ 10 ~!,55 !068,S4 1078,34 !286,87 1297,68 1508,60 1521,40 1729,78 1745,63 1947,91 1966.?0 2!67.05 2188.82 2388.48 2413,38 2606.91 2635.0~ 2674,95 2703,98 9~77,'97_ . 2909,~.. 3!09,79 3144,39 3S42,04 33~0,44 3565,7~.. 3A!O+S4. _. 379!,69 3843,97 4016,27 4074,S6 74,~3 76,49 77,~7 78,79 79,39 79,82 80.29 ~0,74 81,0~ 81.40 81,70 e1.92 82,06 82,16 02,39 82,6O 82.5~ 82,29 82,03 ~!,?! 81.7~. ~1,60 ~1,55 81.49 ~0,97 ~0,54 80,27 3143,99 ,~,49 79,97 465,z2 3380,13 57,5t 79,13 508,07 3610.46 58,14 71.39 566,97 -' . .al.80 3843,?7 )/,~4 76,h2 A~ 3,14 4,41 3,99 2,80 1,68 3,11 3,01 3,25 3,34 3,21 2,87 3,18 3,13 3,46 0,70 0,89 0,19 0,89 0,78 0,54 0,52 0,94 1,!7 0,45 0,40 0.49 0,44 2,41 1,63 0,61 _. v£F~H ~PTH f~ f~ f~ 6998,10 279,5 4885,55 7272,29 274,2 5029,29. 7553,26 281,0 5!80,47 7828,91 275.7 5335.5~ 8106,~5 277,9 5491,77 8381.24 8476,45 8842,98 ?027,70 9305,83 ?982,00 92.8 5650,24 ?5,2 5707,58 88.6 5763+74 92,? 5827,13 185,1 5965,73 184,7 61t2,04 228,1 6332,34 PROJECTED 676.2 6862,33 TARGET ~TATION ~ZIMUTH LATITUDE SECTIOH iHCLH, H/'~ ft ~e9 de9 ft 43!1,0! 4544,46 5?,20 82,0? 777.52 4781,2! 55,70 78,8! 816,67 5009.00 55,84 83,68 851,33 5238,58 55,77 83,53 876.?3 5387,32 54,30 79,01 899,46 5462,46 53,96 77,95 914,47 5538,45 52,00 80,3& 928,7? 560&.91 49.28 81,93 939,34 5674,48 44,63 38,37 945,21 5796.15 38,34 86,43 5908,40 36,90 85,50 6078,00 38,39 79,17 981,34 TO TD 6497,78 38,39 79,17 1060,24 [./-W ft ft 4247,08 4311,15 80,ii 4477,58 4544,59 ~0,15 47ii,07 478!,34 .~0,17 4936,22 5009.10 5164,69 5236,61 80,36 deo/ lOOft 1,42 0,96 1,59 1,46 0,05 5717,zz,,,, 579(,,15 80,5~. 3,47 58S0,I3 5908,41 .~0,66 0,84 ~/ 6078,02 50,7! 1,49 .S410,70 6497,78 ~0,61 0,00 5311,~4 5387,35 80,3? 2,20 5385,4I 5462,50 80,36 0.99 5460,06 5538,49 ~0,35 2,88 5527,7! 5606.96 80,36 3,36 5595,23 5674,5! ~0,41 7,12 11/1 5/95 NO. 9886 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I'TN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Wel,~ Job # Log Description Date BL RF Sepia DIR MWD Kuparuk (Open Hole) LIS Tape 1Q-23 ~" 95339 ARC5 950930 I I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ALASKA OIL A~N~ GAS CONSERYATION CO]~IMISSION / ./ TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 7, 1995 Mike Zanghi, Drlg Engr Supv ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99519-6612 Re: Kuparuk River Unit 1Q-23 ARCO Alaska Inc. - - Permit No 95-141 Surf Loc 1563'FNL, 1225'FEL, Sec. 26, T12N, R09E, UM Btmhole Loc 504'FNL, 123'FEL, Sec. 25, T12N, R09E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to ddll 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 permittirig determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with'20 ~,AC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before ddlling 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 659-3607. ~ _ - Chairma - BY ORDER OF THE COMMISSION /enci c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o enct STATE OF ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r-~ I b Type of Well Exploratory I-1 Stratigraphic Test r-~ Deveiopmant Oil X Re-Entry I-! D~ I-1 Ser~ce I--1 Deve~opmentGas I--1 Sing~eZone X UultipleZone I'1 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 53' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360~ Anchorage, AK 99510-0360 ADL 25641, ALK 2572 4. Loca~on of wail at surface 7. Unit or property Name 1 1. Type Bond (~ee 20 AAC 2S.025) 1563' FNL, 1225' FEL, Sec. 26, T12N, RgE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. -Well numbe~ Number 586' FNL, 617' FEL, Sec. 25, T12N, RgE, UM 1Q-23 #U-630610 At total depth 9. Approximate spud date Amount 504' FNL, 123' FEL, Sec. 25, T12N, R9E, UM 9/1 8/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed dep{h (MD and TVD) property line 1Q-07 " 9926' MD 123'@ TD feet 14.1' ~ 1000' MD feet 2560 6792' TVD feet 16. To be completed for deviated wells 17, Anticipated pressure (see 20 AAC 25,035(e)(2)) Kickoff depth 1 000' feet Maximum holeangle 55,82° Max~nurn~urface 2299 ps~g At total depth (TVD) 3600 pstg 18. Casing program Settinc~ Depth size Specifications Top Bottom Quanfi~ of cement Hole Casir~l Weight Grade Coupling Length MD '[VD MD TVD linclude stage data! 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +P00 CF 9.875" 7.625" 29.7# L-80 LTC 5141' 41' 41' 5182' 3884' 740 Sx Arcticset III & HF-ERW 440 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 9069' 41' 41' 9110' 61 68' HF-ERW 6.75" 3.5" 9.3# L-80 EUE8rdU 816' 9110' 6168' 9926' 6792' 270SxClassG Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True VertlcaJ depth Structural Conductor F ...... Surface . . ~ ~ ~ . Intermediate Production Liner S E? (.-'), 5 Perforation depth: measured ~a~ Co~s. Con'~missio~ true vertical &[p~$~-L~ U[[ & "' ~ Anchorage 20. Attachments Filing fee X Property plat I-1 BOP Skel~ X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [~ Refraction analysis [~ Seabed report ~] 20 AAC 25.050 requirements X 21. I hereby certify that ~e foregoing is true and correct to the best of my knowledge Signed ~.~/ Title Drill Site Develop. Supv. Date ' (~' '~ Commission Use Only Permi. jt.,t N~mber.. , , "~ ~A__~l~umber .... ... I Approval date/~..~ ..,../ I See cover letter for -I Y/ 1 50- - I Y- I other recluirements Conditions of approval Samples required r-] Yes ~ No Mu~J log required r"l Yes ~ No Hydrogen sulfide measures ~ Yes E] No Directional ,urvey-r.equired ~' Yes r'l No Required working pressure forBOPE E] 2M ~. 3M E] 5M F'~ 10M ["=~ 15M Other: Original Signed By David W. Johnston by oraer of - Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-8g Sub~it in triolicate GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 1Q-23 · 1 1 · 1 Si . 1 9, 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (5,182')according to directional plan. -- Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (9,926') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement tapered 5-1/2" x 3-1/2" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test tapered 5-1/2" x 3-1/2" casing to 3500 psi. Run completion assembly. Pressure test SBE/XO. ND BOPE and install production tree. Shut in and secure well. · Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well 1Q-23 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Weight up to TD 11.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Notes- · Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2,299 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 1Q-23 is 1Q-07. As designed, the minimum distance between the two wells would be 14.1' @ 1000' MD. Annular Pumping Activities: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1Q-23 surface/production casing annulus will be filled with diesel after setting the 5-1/2" x 3-1/2" tapered casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be-pumped during the production cement job to cover the formation. -. It is requested that 1Q-23 be permitted for annular pumping occurring as a result of the ddlling project on DS lQ, per proposed regulations 20 AAC 25.005 (k). Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Surface casing will be set in the Creatceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barders to fluid flow. Generally, the surface casing shoe is set 200' vertical below the base of the West Sak into the heart of the shales. Drilling Area Risks: Risks in the 1Q-23 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. Scale 1 · 200.00 ARCO ALASKA Inc. JCreated by : jones For: D PETRASH jOate plotted : 11-Aug-95 Structure : Pad lQ Well : 23 ~lmot Reference is 23 Version #5. J Field : Kuparuk River Unif Location : North Slope, Alaskai tCoordinotes, ora in feet reference glot J23. True Vertical DeDtha ore reference RKfl (Porker 1245). Easf > 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 I I I I I I I I I I I I II II II Ii' I I II I I II II II I I I I . SURFACE LOCATION: J 156Y FNL, 1225' FEL SEC. 26, T12N, RgE Q_) 500 _ o c) co - 1000_ 1500_ (3 - CD 2000_ r-h _ 2500_ _ o · ~ 3000_ 3500_ 4000_ 4500_ I 5O00_ V 6000. 6500. TARGET LOCATION: 586' FNL, 617' FEL SEC. 25, T12N, R9E TARGET TVD=6196 TMD=9147 DEP=5969 NORTH 977 FAST 5888 N 80.58 DEG E 5969' (TO TARGET) _1200 _ _800 _ _ 400 TD LOCATION: KOP 'Pv'D=lO00 TMD=IO00 DEP=O 504' FNL, 123' FEL 6.00 8U~LD 3 OEO / lO0' SEC. 25, T12N, R9E 12.00 18.00 B/ PERMAFROST TVD=1594 TMD=1604 DEP=95 kh~24'00 36.00 EOC TVD=2580 TMD=2861 OEP=837 MAXIMUM ANGLE ~ 55.82 DEC AK SNDS TVD=3059 TMD=3713 0EP=1542 ~ B/ WSAK ENDS '1VD=3684 TMD=4826 DEP=2465 _, ~ 7 K-la TVD=5019 TMD=7202 8 . ~ K-5 TVD=5494 TMD=8048 DEP=5128 BEGIN ANGLE DROP TVD=5667 TMD=8~56 DEP=SZ83 '-,.. 54.00 50.00 DROP 2 DEG / 100' HRZ Midpoint 'r'v'D=5984 TMD=8858 DEP=5772 "-~ 46.00 3 500 0 500 1000 1500 2000 2500 3000 ,.3500 4000 4500 5000 5500 6000 6500 7000 Scale 1 · 250.00 Vertical Section on 80.58 azimuth with reference 0.00 N, 0.00 E from slot #23 7000_ A I I 0 0 0 d .. ~ 140 __ ~ 120 100 8O 60 2O J 40 ARCO ALASKA, Inc. Struclure : Pod lQ Well : 25 Field : Kuporuk River Unif Locofion : North Slope, Alasko jCreot~l by : jonos For: D PETRASH JDote plotted : Il-Aug-g5 iPIot Reference is 2,5 Version #5. ;~Coordinotes are in feet reference slot il2& iTrue verticol Oeotha ore reference RKB (Pocket !J245). Scale 1 · 10.00 E asf -- -- > -. 60 40 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 2 40 260 2100 2200 2300 25O0 8o ~ 2~o lO0 _ 160 Q _ 140 ' ' 0 120 0 100 _ 8,0 _ 60 _ _ 40 _ _ 20 (j~ - O _ o ('- 20 ~J- -- ~o I - I _ t50 V 80 _ 100 120 120 2700 140 140 160 2800 60 '._) l-.l . ~ ~nc~0r~go ,~o ~so ~, Alaska Od &-Gas, Cons. 200 200 I I I I I I I I I I I I I I I I I I I I I I I i.. I I I I I I I I I 60 40 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 240 260 ,o.oo East -- > iARCO ALASKA, iCreoted by : jones For: D PETI~,SH I ]Dote plotted : 11-A,Jg-95 S~rucfure : Pod lQ Well : 25 i I i iPIot Reference is 2.$ Version ~5, ~ ;,Coordinates ore in f~t r~f~rence slot Field : Kuparuk River Unit Location : Nodh Slope, Alaska i ~ True V~dicol O~pths are r~r~nc~ RKB (P~er ~245). i 200 100 100 ~oo,~ ~ · ~o.oo E a s f - - > 300 400 .500 600 700 800 900 1000 11 O0 1200 1 $00 1400 1500 1600 1700 1800 1900 600 J I I I I I I I I I I I I ! I I I i I I I I I I I I I I I I I I I I J 600 ~o0_ .& ~~ ~oo J _ I I I I I I I I ~fl°~l- ~ I I I I I I I I I I I I I I I I I I I I I I ~00 400 500 600 700 800 900 1000 11 O0 1200 1500 1400 1500 1600 1700 1800 1900 o.oo Easf 300 400 200 I 100 0 O _ 100 _ 300 ~- 4o0 ~ 0 5 '"°'~' Gas C;ons, AnGhorage, KUPARUK RIVER UN,,' 20" DIVERTER SCHEMATIC I 5 3 DO NOT SHUT IN DIVERTER --AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIPqDN WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. Anchorage 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 7 5 4 13 5/8" 5000BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2- ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ONTHE IADC REPORT, THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2- CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. 6.CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7.TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE, 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE, CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. B/FFD TO 7ERO PSI. 10, OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULLOF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12_ TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14, PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" PIPE ODS. 1. 16" - 2000 PSI STARTING HEAD P_ 11 "- 3000 PSI CASING HEAD 3. 11"- 3000 PSI X 13,5/8"- 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8"- 5(:XX) PSI DRLG SPOOL W/ CHOKE AND KILL UNES 6. 13-5/8" - 5(XX) PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR __.-- PERMIT CHECKLIST WELL NAME GEOL AREA UNIT# ,,, PROGRAM: exp [] dev~ redrll [] aery [] ADMINISTRATION ENGINEERING GEOLOGY 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............ 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... ' 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ............... ~ i Surface casing protects all known USDWs ........ CMT vol adequate to circulate on conductor & surf csg. CMT vol adequate to tie-in long string to surf csg . . . Y ~ CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... .~ N Adequate tankage or reserve pit ............ N If a re-drill, has a 10-403 for abndnmnt been approved..Y N Adequate wellbore separation proposed ......... .~ N If diverter required, is it adequate .......... ~ N Drilling fluid program schematic & equip list adequate ~ N BOPEs adequate ..................... ~ N BOPE press rating adequate; test to ~~ psig.~ N Choke manifold complies w/API RP-53 (M~y 84) ...... ~ ~ Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............ N 30. Permit can be issued w/o hydrogen sulfide measures 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ....... 34. Contact name/phone for weekly progress reports . . [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: ¥ - Comments/Instructions: HOW~o - A:~ORMS~cheklist rev 03/94 O 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. ALASKA COMPUTING CENTER * SCHLUMBERGER COMPANY NAME : ARCO ALASKA, INC. WELL NAME : lQ - 23 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 5~-029-22596-0~ REFERENCE NO : 95339 ~ov ~ 7 ~ _, . _kS Tape Verification Listing Schlumberger Alaska Computing Center 9-NOV-1995 09:01 **** REEL HEADER SERVICE NAME : EDIT DATE : 95/11/ 9 ORIGIN : FLIC REEL NAME : 95339 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 1~-23, API #50-029-22596-00 **** TAPE HEADER SERVICE NAME : EDIT DATE : 95/11/ 9 ORIGIN : FLIC TAPE NAME : 95339 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 1~-23, API #50-029-22596-00 TAPE HEADER KUPARUK RIVER MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 5002922596~0 ARCO ALASKA~ INC. SCHLUMBERGER WELL SERVICES 9-NOV-95 BIT RUN 1 BIT RUN 2 BIT RUN 3 SURFACE LOCATION SECTION: 26 TOWNSHIP: RANGE: 9E FNL: 1563 FSL: FEL: 1225 FWL: ELEVATION(FT FROM MSL KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 26 9E 1563 1225 94.00 94.00 53.10 26 12N 9E 1563 1225 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 5152.0 PAGE: _£S Tape Verification Listing g-NOV-lMM5 09:01 Schlumberger Alaska Computing Center REMARKS: Well drilled 27-SEP through 01-0CT-95 with ARC5 only. All data was collected in three bit runs. There was no MAD data collected. Data processed using modified LDWG scope, depth shifted to SWS CBT 24-0CT-95. $ $ **** FILE HEADER FILE NAME : EDIT SERVICE : FLIC VERSION : 991C91 DATE : 95/11/ MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 9.5999 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 9982.9 5941.5 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MWD 88888.9 9895.5 9777.5 9779.9 9733.5 9716.5 9691.9 9651.9 9618.9 9607.9 9595.9 9575.9 9552.5 9595.5 9493.9 9487.5 9431.5 9495.5 9368.9 9354.9 88886.5 9894.9 9775.5 9767.5 9739.5 9714.9 9687.9 9647.5 9614.5 9694.9 9593 5 9571 9 9548 5 9591 5 9488 9 9482 5 9426 9 9499.9 9364.5 9349.5 _±S Tape Verifica%ion Lis%ing Schlumberger Alaska Compu%ing Cen%er 9-NOV-1995 09:01 9321.0 9316.5 9268.0 9263.0 9245.0 9238.5 9194.0 9188.9 9168.5 9162.5 9146.9 9143.9 9131.9 9128.9 9194.9 9199.5 9971.9 9967.5 9952.5 9947.5 9949.0 9935.5 9913.5 9999.9 8991.5 8987.9 8951.5 8945.5 8934.~ 8928.9 8845.5 8849.5 8831.5 8826.9 8897.~ 8892.9 8776.5 8779.5 199.9 94.9 $ MERGED DATA SOURCE LDWG TOOL CODE MWD MWD MWD $ REMARKS: BIT RUN NO. MERGE TOP MERGE BASE 1 5941.5 5413.0 2 5413.9 9637.9 3 9637.9 9982.9 The dep%h adjus%men%s shown above re~lec% %he MWD GR %0 %he CBT GR logged by SWS. All o%her MWD curves were carried wi%h %he GR. No MAD pass da%a was used. The da%a was processed using %he modified LDWG scope. $ LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 9 2 66 9 3 73 36 4 66 5 66 6 73 7 65 8 68 9.5 _£S Tape Verifica%ion Lis%lng Schlumberger Alaska Compu%ing Cen%er 9-NOV-1995 09:01 PAGE: TYPE REPR CODE VALUE 9 6S FT 11 66 28 0 66 0 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 000 09 9 1 1 1 4 68 9999999999 ROP MWD F/HR 99 999 99 9 1 1 1 4 68 9999999999 FET MWD HR 99 999 99 9 1 1 1 4 68 9990999999 GR MWD GAPI 99 999 99 9 1 1 1 4 68 9999999999 RPXX MWD OHMM 99 999 99 9 1 1 1 4 68 9999999999 RPX MWD OHMM 99 999 99 9 1 1 1 4 68 9999999999 RPS MWD OHMM 99 999 99 9 1 1 i 4 68 9999999999 RPM MWD OHMM 99 999 99 9 1 1 1 4 68 9999999999 RPD MWD OHMM 99 999 99 9 1 1 1 4 68 9999999999 ** DATA ** DEPT. 9979.999 RPXX.MWD 2.311 RPD.MWD 2.293 DEPT. 5949.999 RPXX.MWD 1999.~99 RPD.MWD 1999.999 ROP.MWD 7.416 FET.MWD 4.494 GR.MWD RPX.MWD 2.396 RPS.MWD 2.393 RPM.MWD ROP.MWD i80.990 FET.MWD 0.099 GR.MWD RPX.MWD 1909.099 RPS.MWD 1999.999 RPM.MWD 86.677 2.298 6.958 1909.990 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .991 SERVICE : FLIC VERSION : 991C91 DATE : 95/11/ g MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : _-S Tape Verii~icat;ion Lis~,ing Schlumberger Alaska Compu~,ing Cent, er 9-NOV-1995 09:01 **** TAPE TRAILER SERVICE NAME : EDIT DATE : 95/11/ 9 ORIGIN : FLIC TAPE NAME : 95339 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.~ KUPARUK ~Q-23~ API #50-029-22596-00 *~** REEL TRAILER SERVICE NAME : EDIT DATE : 95/~/ 9 ORIGIN : FLIC REEL NAME : 95339 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC.~ KUPARUK ~Q-23~ API #50-029-22596-00 PAGE: