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199-010
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-308 KUPARUK RIV U TARN 2N-308 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 2N-308 50-103-20288-00-00 199-010-0 W SPT 5059 1990100 1500 1850 1850 1850 1850 270 450 450 450 4YRTST P Adam Earl 8/1/2022 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U TARN 2N-308 Inspection Date: Tubing OA Packer Depth 530 2500 2435 2430IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803204643 BBL Pumped:1.2 BBL Returned:1.2 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 15:45:36 -08'00' • • �w�\ IF//7;6. THE STATE Alaska Oil and Gas of�LA V Kl 1 Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue + Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 Monty Myers N \! 3 ZO1r, Wells Engineer � �� � I� ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2N-308 Sundry Number: 313-526 Dear Mr. Myers: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair, Commissioner DATED this i'1 day of October, 2013. Encl. STATE OF ALASKA � y � /it Pi pp • A KA OIL AND GAS CONSERVATION COMMISSION At/ n OCT 20 13 APPLICATION FOR SUNDRY APPROVALS 1° 20 AAC 25.280 I 1.Type of Request: Abandon r Rug for Redrill fl Perforate New Pool fl Repair w ell Change Aprir d o ram Suspend r Rug Perforations r Perforate r Pull Tubing 1 Time Extension Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing E Other: r- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development fl 199-010- 3.Address: 6.API Number: Stratigraphic r Service P.O. Box 100360,Anchorage,Alaska 99510 50-103-20288-00. 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 2N-308• 9.Property Designation(Lease Number): ?/(1*,, 10.Field/Pool(s): ADL 380953. 98OOSY ioti3 Kuparuk River Field/Tarn Oil Pool- 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Death TVD(ft:('' Plugs(measured): Junk(measured): 10520• 5546 ,, fj 9 S ` -11 i°I 9634', Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 118' 118' SURFACE 3006 7.625 3041' 2319' PRODUCTION 10467 5.5 10500' 5535' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9946-9986 5230-5253 3.5 L-80 9660 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer NIPPLE-CAMCO DS NIPPLE MD=503 TVD=503 12.Attachments: Description Suninary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Stratigraphic n Development r Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/1/2013 Oil fl Gas r WDSPL I- Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG 17 Abandoned Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Myers©265-6318 Email: Monty.M.MyersAconocophillips.com Printed Name Monty Myers Title: Wells Engineer Signature < ^ . . s Phone:265-6318 Date (0. 3, 7 013 Commission Use Only Sundry Number: 1 Conditions of approval: Notify Commission so that a representative may witness 3`j--524 I Plug Integrity r BOP Test V Mechanical Integrity Test );/' Clearance r Other: ,,lo P �S f 1-0 ...G'G l) 51 . 1 r - vi r't ci �� r' �a / d /wGJtL/ Co'l1 Spacing Exception Required? Yes ❑ No CY Subsequent Form Required: ! 4-0 4 APPROVED BY Approved by. COMMISSIONER THE COMMISSION Date:�d �l �'�Ap?.€1,.71-1,,--. ed application is valid tor 12 months trom the date of approval. 6..--4 Form 10-403(Revised 0/2012) I I N A L /f p1 l m't Form and Attach m nt in lica e 1 e r/di�il i3 0 R G R � U 7171 • • Conoco Phillips E C IvED Alaska P.O. BOX 100360 0 C! 0 4 2013 ANCHORAGE,ALASKA 99510-0360 September 27, 2013 G Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc.hereby submits an Application for Sundry Approval to workover Kuparuk Well 2N-308 (PTD# 199-010). Tarn well 2N-308 was drilled in February 1999 to a total depth of 10,520 ft MD to develop the Bermuda reservoir of the 2N accumulation. 2N-308 was converted to miscible water alternating gas injection in July 2013. Upon preparing to activate the we to infection service, mu tip e ea s in the tubing were identified and the well was shut- in. The production casing passed a tubing by casing combination mechanical integrity test (CMITIA) in August 2013. Tubing condition diagnostic work indicates that internal corrosion is the primary cause of failed mechanical integrity. A caliper log,run July 2013, shows the 3.5" tubing to be in poor condition. There were four possible holes reported from the recorded data. There are numerous additional joints that have very high reported damage above 40%. The uncentered 3D log-Wows some significant kinks in the tubing from 2,400 to 4,300 ft MD. The recorded damage ranges from light to moderate pitting in the vertical section of the well The proposed plan is to utilize the Nordic 3 rig to pull and replace the prduc otion tubing and plac; the well in MWAG injection service If you have any questions or require any further information,please contact me at 265-6318. Sincerely, o yers Wells Engineer CPAI Drilling and Wells • • 2N-308 Rig Workover Pull and Replace Tubing (PTD #: 199-010) Current Status: This well is currently shut in awaiting a workover. Scope of Work: Pull the 3' "9.3#L-80 EUE 8rd tubing above the seal assembly,run new 3 '/""9.3#L-80 EUE tubing string. General Well info: Well Type: Injector ✓ MPSP: 1,879 psi using 0.1 psi/ft gradient 8/ Reservoir Pressure/TVD: 2,387 psi/5,085' TVD(8.8 ppg)from Panex gauges on 6/22/12. Wellhead type/pressure rating: FMC Gen 3, 11"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: CMIT-TXIA passed on 8/7/13,T-POT,T-PPPOT,IC-POT,IC-PPPOT passed on 8/30/13 Earliest Estimated Start Date: November 1,2013 Production Engineer: Deanna Van Dam/Mike Balog Workover Engineer: Monty Myers(265-6318/monty.m.myers @cop.com) Pre-Rig Work 1. RU Slickline 2. Pull DV in GLM#2 and leave open 3. Pull CA-2 plug from D nipple. 4. Obtain SBHP across perforations 5. Set WRP in 3 l/"production casing above perforations 6. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Reverse circulate sweater in wellbore. Obtain SITP&SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug,ND tree,NU BOPE&test to 250/3,000 psi. 4. Pull blanking plug&BPV,screw in landing joint,BOLDS's, unland tubing hanger. 5. POOH laying down 3' "tubing. 6. MU new 3 ' "completions,RIH to just above casing seal receptacle. 7. Swap entire well over to corrosion inhibited seawater. 8. Engage seal assembly until fully engaged into casing seal receptacle.Pick up and space out 7'. Mark the pipe. 9. Space out w/pups,MU hanger. Land the hanger,RILDS. 10. PT the tubing to 3,500 psi,bleed tubing to 2,500 psi,PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero,then the tubing. Ramp up the IA pressure quickly to shear the SOV. Bleed tbg to zero, then IA. 11. Pull the landing joint,install BPV. 12. ND BOPE,NU tree. Pull BPV, install tree test plug. Test tree. Pull tree test plug. 13. Freeze protect through the SOV,set BPV. 14. RDMO. . •, • • 2N-308 Rig Workover Pull and Replace Tubing (PTD #: 199-010) Post-Rig Work 1. Pull BPV 2. RU Slickline: a. Pull SOV,replace w/DV. b. Pull WRP. 3. Handoff to operations. F KUP PROD 2N-308 Conoc©Phillips Well Attributes Max Angle&MD TD A7:3& .1({ Wellbore API/UWI Field Name Welibore Status Inc!('I MO(ftKB) Act Btrn(ftKB) CLno Isps Comment H s e AREA Annotation 67.92 I 4,217 81 10520.0 501032028800 TARN PARTICIPATING `^'' (ppm) nnotation End Date KB-Get(ft) Rig Release Data Well:O fq 2N308,;&$(20138:05:59 AM - SSSV:NIPPLE 60 12/11/2012 Last WO: 43.51 2/26/1999 Schemapc Actual--_. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,954.0 7/24/2013 Rev Reason:TAG,Glv do,Set Plug/ISO Sleeve, haggea 8/7/2013 close CMU,Add Note HANGER,29 - Casing Strings ate-_- Casing Description String 0... String ID...Top(ftKB) Set Depth(f..Set Depth(TVD)...Stung Wt...String String Top Thrd , CONDUCTOR 16 15.062 34.6 118.0 118.0 62.58 H-40 WELDED Casing Deseription String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)..String Wt...Sting...String Top Thrd SURFACE 7 5/8 6.875 34.6 . 3,040.9 2,318.6 29.70 L-80 BTC-MOD•1' °� Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd PRODUCTION 51/2 4.950 33.0 10,499.5 5,534.8 15.50 L-80 ETC-MOD 5.5"x3.5" Tubing Strings :r" Tubing Description 'string 0. 'String ID. Top(ftKB) Set Depth(f Set Depth(ND)...String Wt...Sting. String Top Thrd TUBING 1-3 1/2 1 2992 I 28 7 9,659 5 1 5,069 8 9.30 [-80 EUE8RDMOD s.+ - 2 Completion Details Top Depth CONDUCTOR, (TVD) Top Inc! P ) N i... ~ 1 28.7!. (ftKB) (°) Kem Description Comment ID(in) 35118 To IftKB 28.6 0.14 HANGER FMC GEN V S TUBING HANGER 3.500 NIPPLE,503 503.1 502.7 2.66 NIPPLE PPLE 2.875 4 9,531.8 4,997.6 55.20 SLEEVE-C BAKER CMU SLIDING SLEEVE w/CAMCO PROFILE-CLOSED 2.813 , 7/30/13 9,634.1 5,055.5 55.86 NIPPLE CAMCO D NIPPLE 2.750 9,641.5 5,059.7 55.91 LOCATOR BAKER LOCATOR 1 2.985 9,642.1, 5,060.0 55.92 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY -'3.000 Other in Hole(Wireline retrievable plugs valves pumps,fish,'etc.) Top Depth (ND) Top Inc! Top(ftKB) (Mks) (°) Description Comment Run Date ID fin) 9,531.8 4,997.6 55.20 SLEEVE 2.81"ISO SLEEVE(OAL=52"10.2.31)IN CMU 7/30/2013 2.310 SURFACE._ 5,055.5 X001 9,634.0 55.86 PLUG 2.75"CA-2 PLUG 7/25/2013 0.000 1 Perforations&Slots Shot GAS LIFT, To ftKB Btrn ftKB (ftKB)) (ftKB) )' Zone Date Dens Type Comment Top D elm ND IPERF 2.5"HC BH charges;180 deg pl 1 (ftKB) ) 1 sn s,9T6 9,946.0 9,986.0 5,229.8 5,252.711 S-3,2N-308 3/27/1999 4.0, 1 9,961.0 5,229.8 5,238.4� _-- '-0hasing,un-oriented ._-9,946.0' ---- S-3,2N-308 1/27/2006 6 0'RPERF 2.5"HC BH charges Stimulations &Treatments Bottom SLEEVE,9.532 _.- Min Top Max Btm Top Depth Depth SLEEVE-C,- Depth Depth (TVO) (TVO) 9'532 (ftKS) (ftKB) (ftKB) (ftKB) Type Date Comment ... 9,946.01 9,986.0 5,229.8 5,252.7'RE-FRAC 1/29/2006 Re-Frac completed through flush,placed 1861258 of 16/20 prop in the formation w/10#ppa @ the perfs. Notes:General&Safety End Date Annotation 11/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LI,582 FT � _. 7/31/2013 NOTE:FOUND LEAK @4660'8 4567' ..._ NIPPL E 9,634 - 1 IA LOCATOR, 9.641._ --_. \[ SEAL ASSY. 1 9,642 Mandrel Details Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run ) Model (n) Sery Type Type (in) _ (_psi) Run Date Corn... 9,946-9,961 N T 1 5,978. 2 3,504.2 66.16 CAMCO KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0.5/19/1999 L� IPERF 9,9469,986 5'°='- 2 9,581.81 5,026.1 55.52 CAMCO KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 7/27/2013 RE-FRAC, 9946 ( PRODUCTION 5.5'535", 3310,499 L_;1 Casing 4, 10,500 TO 10.520 -- _. --.....---. • yw' \ OF 74 \ I ■ THE STATE Aiaska 011 and Gas - = 311 s nation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS'" Main: 907.279.1433 SCONE 4 `�� Fax: 907.276.7542 A Darrell R. Humphrey v NSK Production Engineering Specialist u ConocoPhillips Alaska, Inc. aI,, 0 / P.O. Box 100360 1 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2N -308 Sundry Number: 313 -285 Dear Mr. Humphrey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i Daniel T. Seamount, Jr. Commissioner DATED thid d day of June, 2013. Encl. ' STATE OF ALASKA ,. ` r pp , WKA OIL AND GAS CONSERVATION COMMI N i ���p APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon [ Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension [ Operational Shutdow n r Re -enter Susp. Well r Stimulate Alter casing [ r Other: Prod to WAG E' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r; , Exploratory r 199 -010 , 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20288 -00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No J 2N - 308 ,. 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 380054, ALK 4602 Kuparuk River Field / Tarn Oil Pool w 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 10520 ∎5546 10372' 5466' None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 118' 118' SURFACE 3006 10 3041' 2318' PRODUCTION 5534' 10466 8 10499' Perforation DepthyD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9946 9986,9946 - 9961 5230 - 5253,5230 - 5238 3.5 L - 9641 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) HANGER - FMC GEN V 5M TUBING HANGER MD= 29 TVD= 29 SLEEVE -C - BAKER CMU SLIDING SLEEVE W/ CAMCO PROFILE - MD= 9532 TVD= 4998 NIPPLE - CAMCO D NIPPLE MD= 9634 TVD= 5056 t LOCATOR - BAKER LOCATOR MD= 9641 TVD= 5060 • SEAL ASSY - BAKER 80-40 SEAL ASSEMBLY MD= 9642 ND= 5060 ' 12. Attachments: Description Summary of R p • 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service E • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/15/2013 oil r Gas r WDSPL Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG C . Abandoned r Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Darrell Humphrey Email: N1139 @conocophillips.com Printed Name t77tccccJJJJ Darrell R. Humphrey Title: NSK Production Engineering Specialist Signature t•{ Phone: 659 -7535 Date 4e, 5• `3 Commission Use Only Sundry Number)•A J Conditions of approval: Notify Commission so that a representative may witness ✓✓ 9 Plug Integrity r BOP Test r Mechanical Integrity Test ' Location Clearance Other: i t� Wl rSSrCI ll/t 1 r — / h} t"-r vi fr'"ed 4 Fir r S fa h, 1 3 rCI' `'1 / lam (I / f/rv) at/ ivy C'e /7 1-1 vG1 AI - a lb , Spacing Exception Required? Yes ❑ No [II] Subsequent Form Required: ./0 4 6 APPROVED BY / 1 / Approved by: COMMISSIONER THE COMMISSION Date: ���!!! J (> Approved a plication is valid for 12 months from the date of approval. R1G1NAL Submit Form ttachments in Duplicate 0 Form 10 -403 (Revised 10/2012) RBDMS JUN 2 0 201 �/ J ` 4 ■ ��`G 6,06113 • • 2N -308 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska-Inc. requests approval to convert Tarn Well 2N -308 from Oil Production service to MWAG Injection service. Well 2N -308 was completed as a Tarn Oil Pool, Bermuda sand, and producer. The pattern oil production rate and sweep efficiency have suffered due to the water and gas cycling between producer 2N -308 and injector 2N -307 and warrant converting well 2N -308 to a service injector. The conversion of the 2N -308 to MWAG injection service will eliminate inefficient water cycling along an injection conduit from well 2N -307 to well 2N -308, and improve sweep to offset producers 2N -315, 2N -313, and 2L- 326 The 16" Conductor was cemented with 9 cu yds of High Early(118' MD & TVD). The 7- 5/8" Surface casing (3041' and / 2318' tvd) was cemented with 381 sx AS III & 235 sx Class G. The 5.5" Production casing (10499' and / 5534' tvd) was cemented with 272 sx Class "G ". The Top of the Tarn "Bermuda" Sand is 9817' and / 5157' tvd l CO �Gvr. Wel p t rS � A-3) 7401/ /00 Bo w; � y C� w et f G✓" c "F- 0 v L /eCd vc .tt r0 OO r'rr'D4 O ,c C c te• f io okr , •.MQro y c y j &e poop • 644) JA141OL • • • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 ConoeoPh i I lips Anchorage, AK 99519 -6105 Phone: (907) 659-7535 Fax: 659 -7314 June 5, 2013 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit well 2N- 308 from Oil production to WAG injection service. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2L -310 (PTD 199 -010). If you have any questions regarding this matter, please contact myself or Bob Christensen at 659 -7535. Sincerely, Darrell Humphrey Attachments Sundry application Well schematic r ,. KUP 2N -308 • ConocoPhillips 4 1 Weliborerr WI Fi el d Na me ✓ L W ell St atus Inc! H � p �� Alaska. Ino. FleId a ',• r ° , (°) MD (ftKB) Act Btm (ftKB) 501032028800 TARN PARTICIPATING AREA PROD 67.92 4,217.81 10,520.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV: NIPPLE 43 10/17/2011 Last WO: 43.51 2/26/1999 Well Confi9: -2N -308, 6/23/20129: 14: 42 AM - Schematm- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,987.0 6/22/2012 Rev Reason TAG ninam 6/23/2012 aaaing Strings HANGER. 29 C• Casing Description String 0... String ID ... Top (ftKB) Set Depth (f...'Set Depth (TVD) . String Wt... l String ... String Top Thrd CONDUCTOR 16 15062 34.6 118.0 118.0 62.58 H - 40 WELDED Casing Description String 0... String ID ,.. Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.875 34.6 3,040.9 2,318.6 29.70 L BTC - MOD Casing Description String 0... String ID ... Top (PoCB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 33.0 10,499.5 5,534.8 15.50 L -80 BTC -MOD 5.5 "x3 as Tubi ng i Tubing De Str pt on ngs String 0 String ID ... 'Top (1166) Set Depth (f... Set Depth (TVD) String Wt... String ... String Top Thrd TUBING 31/2 2.992 28.7 9.659.5 5,069.8 9.30 L -80 EUE8RDMOD Completion Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (069) (°) item Description Comment ID (In) CONDUCTOR, 28.7 28.6 0.14 HANGER FMC GEN V 5M TUBING HANGER 3.500 35-118 503.1 502.7 2.66 NIPPLE CAMCO DS NIPPLE 2.875 ' I 9,531.8 4,997.6 55.20 SLEEVE -C BAKER CMU SLIDING SLEEVE w/ CAMCO PROFILE - CLOSED 2.813 NIPPLE. 503 1 _ice 5/19/1999 ; 9,634.1 5,055.5 55.86 NIPPLE CAMCO D NIPPLE 2.750 Illt I 9,641.5 5,059.7 55.91 LOCATOR BAKER LOCATOR 2.985 9,642.1 5,060.0 55.92 SEAL ASSY BAKER 80 -40 SEAL ASSEMBLY 3.000 $ & Slots Shot Top (TVD) Btm (TVD) Dens Top (ttKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (ch..• Type Comment 9,946 9,986 5,229.8 5,252.7 S -3, 2N- 308 3/27/1999 4.0 IPERF 2.5 HC BH charges; 180 deg I phasing, un-oriented I 9,946 9,961 5,229.8 5,238.4 S -3, 2N -308 1/27/2006 6.0 RPERF 2.5" HC BH charges SURFACE, . • - - - - -- Stimulations & Treatments 359941 Min Top Max Btm Top Depth Depth lit Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (RKB) Type Date Comment 9,946.0 9,986.0 5,229.8 5,252.7 RE -FRAC 1/29/2006 Re -Frac completed through flush, placed 186125# of 16/20 prop in the formation w/ 10# ppa @ the peas. Gns LIFT, 5.978 + .- Notes: General & Safety It It End Date Annotation 11/192010 NOTE: View Schematic w/ Alaska Schematic9.0 SLEEVE-C 9,532 I II t GAS LIFT 9582 II NIPPLE, 9,634 k 1 £ LOCATOR, 1 9641 SEAL ASSY, le 9.642 1 Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run 9.9.46-9,961 Stn Top (ftKB) (ftKB) ( °) Make Model (in) son, Type Type lint (psi) Run Date Com... IP \ 1 5,978.2 3,504.2 66.16 CAMCO KBG - 2 - 9 1 GAS LIFT DMY BTM 0.000 0.0 5/19/1999 99469,986 ,986 RE - FRAC, 2 9,581.8 5,026.1 55.52 CAMCO KBG - 2 - 9 1 GAS LIFT OV BTM 0.313 0.0 6252009 w /Ch... 9,946 PRODUCTION 5.5 "x3.5', 3310,499 Casing 4. 10,500 l TD. 10,520 • • • Tarn well 2N -308 Conversion from production to MWAG injection Area of Review Well Summary Tarn well 2N -308 was drilled in 1999 and placed in service as a producer of the Bermuda interval. Well 2N -308 has produced 3,239 MBO through April 2013. The conversion of the 2N -308 to MWAG injection service will eliminate inefficient flood cycling from injection well 2N -307 to well 2N -308, and improve sweep to offset producers 2N -315, 2N -313, and 2L -326 Below, the Area of Review includes the following: • Map with 1/4 mile radius shown around the target injection zone; • 2N -308 welibore schematic; • The mechanical condition of the proposed injection well; • MIT -IA history; and • 2N -308 cementing history and interpretation of the cement quality of the subject well (no other wells are located within 1 /4 mile radius). A CBL was not acquired in well 2N -308. Area Map with % mile radius around target injection zone Tarn well 2N -308 is located on the Northeast side of the Drilisite 2N Tarn development. The map below shows that there are no other wells located within 1 /4 mile radius of the 2N -308 penetration of the Bermuda interval. 2N -308 Quarter Mile Radius. pdf . S 0 CD AaPPAGAaNsa : . ; ..., Unt , :Oft 4....... ,......aramo .-..... Amu* At Psy TWItsea = ” ' .L .. = % . M . x ) i ... \ N., E.] * * = *.1 -' 555 [ a. = *'1* ■ - \ . , '.... IIIIIII \ MN ft- im c 4W ax law ,=est \----...:72) I Mil te *-A - ) / ,.....----_,'---::', ..- ,,.. •"- - MI + '. • , MO , x • .. ,- 5 .4....122fiSla_32 - • . . , . .. , . ..- . - 'I 326- • . , .. 4 —•— ■ . • •• •, . „ ......._. . ,. — -- • - . . , + • : , , •, : • . ...., s s. • .,- --- '.. _. , , . , ___...• _ . '-,-- --.. ■ '- 's ',... 2N-3115 -,..,, ) (, 1 r ' "-3/5 ' ..„.../' 2N-308 r , t • ' , .- - 5- '''` ' '.. , ' — A , ( _ , . ........- .. _. TA4 „ _ . . . ' .. . . .. .. ' - — 18 2N-311 1 , ' ''. ' •I'7' ... „,7".•. '.' • . -i °,fh ' I P ---\...„ '' - ' I f. ;•• ''! riviiiA .1 . , . i ., r. ( , ' 1 ',. — „ .....„-------- RN3 ,,..- _ ..,- .. _...,_ , 7 --..,....„...',/ .,.., , - , ....., , . . , :- . .... _ .-. Tarn well 2N -308 Wellbore Schematic Tarn well 2N -308 was completed with 3 -1/2" 9.3 Ibs /ft L -80 tubing and 5 -1/2" 15.5 Ibs /ft L -80 by 3- 1/2" 9.3 Ibs /ft L -80 tapered production casing. The surface hole was completed with 7 -5/8" 29.7 Ibs /ft L -80 casing. The well is perforated in the Bermuda formation from 9,946 — 9,986 ft KB. The top of the Bermuda interval is located at 9,817 ft MD. The schematic is attached below. 2N -308 Wellbor Schematic. pdf Mechanical Condition of Well to be Converted to Injection and MIT History (2N- 308) The mechanical condition of Tarn well 2N -308 is good. The well is classified as a "Normal Well" meaning that the most recent mechanical integrity and tubing integrity fluid level tests have passed. The most recent tubing integrity fluid level passed on July 14, 2009 and the most recent MITT was tested to 3,500 psi on January 26, 2006. A new State witnessed MIT -IA will be performed once well 2N -308 is converted, online, and stabilized. 2N -308 Cement Evaluation (no other wells are located within % mile radius) As stated above, well 2N -308 was drilled and completed as a producer in 1999. Because the well was not originally intended to be an injector a cement bond log was not run. The production casing cement job was designed to place cement at least 500 ft above significant hydrocarbon bearing zones. The cement job was designed for a calculated top of cement to be located at 9,134 ft MD (using a 50% excess factor) — approximately 683 ft above the top of the Bermuda interval (target injection interval). The actual production casing cement job pumped 272 sacks of Class G, 15.8 ppg, with a yield of 1.2 cf /sack. The cement was pumped at 3 bpm at a surface pressure of approximately 550 psig. The pipe was rotated and reciprocated. The production casing cement job summary from drilling and cementing reports follows: Daily Drilling Report (2/25/99) Rig up cementing head. Break circulation. Slow to minimize losses. Worked up to 3 bpm at 525 psi to condition hole — full returns. Pumped 5 bbls fresh water to clear lines. Pumped 20 bbls wash , 40 bbls spacer. Shut down. Dropped bottom plug. Pumped 58 bbls cement slurry. Washed lines up to cement head. Dropped top plug. Displace with 219 bbls seawater at 3 bpm. Bumped plug. Checked floats — OK. Cementing Details Report (2/25/99) Staged up pumps until full returns at 3 bpm. Conditioned mud. Pumped 20 bbls of pre - flush, 40 bbls of spacer, and 58 bbls of cement. Displaced with 20 bbls of fresh water and 219 bbls of seawater. Bumped plugs to 2,000 psi — floats held. Reciprocate pipe until last 20 bbls of displacement. Had 90% returns while cementing. f • • After evaluating the production casing cement job, the top of cement (TOC) is calculated at 8,966 ft MD (using a 50% excess factor). This calculated TOC suggests that 851 ft MD of cement is present above the Bermuda Interval. II From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, June 20, 2009 10:21 AM j`~~G ~il Z~~~f ( To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: NSK Well Integrity Proj; NSK Problem Weii Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK Subject: KRU 2N-308 (PTD# 199-010) Report of TxIA Communication Attachments: 2N-308 Wellbore Schematic.pdf; 2N-308 TIO Plot.pdf Jim/Tom, / Tarn gasiifted producer 2N-308 (PTD# 199-010) is suspected of TxIA communication based upon a failing TIFL. A leaking gaslift vaive is suspected, so ConocoPhillips intends to troubleshoot and repair with slickline if possible. The well will be added to the SCP report and will be repaired of shut in by 7/17/09. Attached is a welibore schematic and 90 day TIO plot. «2N-308 Wellbore Schematic.pdf» «2N-308 TIO Plot.pdf» ~ Piease contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 °;':, `3`~ .~i'12i.#^- ~~,~(~ ~ ~~~_ ~~~~v< . t::~ 6 V~ Jb_•a.- 8/6/2009 c ( z~~~~ ~ i`t~t-c~~ Well Name 2N-308 Notes: End Date 7/1/2009 Days 90 Start Date 4!2~2009 Annular Communicaton Surveillance ~soo 1400 1200 1000 ~Q 800 soo 400 200 0 WHP IAP OAP WHT Apr-09 3000 zsoo 0 2000 a 0 1500 LL U ~ lODO 500 0 May-09 Jun-09 ~DGI ~MGI ~PWI ~SW~ Apr-09 May-09 Jun-09 Date ~20 100 80 LL 60 ~ a 40 20 0 ~ • ~" ~ _ ~ KUP ~ 2N-308 '~tJCt~Cb~"11~~Ips £~' . , tf~Rttri~~°°~ r ~ i~~ ~ ~,~ : , F ~ ':' ,_~ ~ ~~ ' ~ y~_ _ z. ~~,~ ~xk~ ~C~, ~ ~ . t~ WNibore API/UWI Field Name Well Status ProdAnj Type Inal (°) MD ~ttKB) Act Btm (RKB) ~. ~ 501032028800 TARN PARTICIPATING AREA PROD 67.92 4,217.81 10,520.0 Comment H2S (ppm) Date An~otatlon End Oate K81ird (/l) Rig Releau Date ~~~ ~b ,.... y , SSSV: NIPPLE 75 7/1/2008 Last W0: 43.51 2/26/1999 ape. w z!. ~ MnMatlon Dapth (ttKB) End Date AnnMation Entl Date Last Tag: SLM 9,983.0 1 2/272008 Rev Reason: TAG FILL 12/28/2008 ~$$~t1 '_. ~s ~ '~~ ~ ~v k _ ~ ' T ,~ ~ t "~ ~ ~F =-= 9tring OD 9trinp 10 Set Depth Set Deptti (ND) 6trl~g Wt String Casing Descripdon (~~) l~~) Top (ttiCO) (ftNB) (ftKB) (Ibs/ft) 6rade String Top Thrd ~~ ~ ~~~~~ ~~ CONDUCTOR 16 15.062 0.0 118.0 718.0 62.58 H-00 WELDED ` ° ~ - "'~`°~'''~ SURFACE 7 5/8 6.750 0.0 3,041.0 2,318.6 29.70 L-80 BTC-MOD ~ "~~ PRODUCTION 51/2 4.950 0.0 9,665.0 ~ 5,072.9 15.50 L-80 BTC-MOD CONDUCTOR, 11e ~ PRODUCTION 31/2 2.992 9,665.0 10,500.0 5,535.1 9.30 L-80 EUE8rd ' ~:# i~i S I~ ~°„~, r'~.~i ~~ _ G ~ ~i ' i ~a 4'm : t, ~;, ~_ a ~ ~~ ,~~,: ~ ~ - String OD SMng 10 Sat Dapth Set Oepth (ND) String Wt Strinp Tubing Descri tion (~~) (~~) To ftKB (RKB) (ftKB) (IbcM) Ontle Strin To Thrd TUBING 3 1/2 2.992 0.0 9,660.0 5,070.1 9.30 L-80 EUE 8rd ~~ic~~~ i.' ~, Q' i~:~~~M.l ~ ~..iT4S2#~~u~4~~.'..~ QLVi r. # K- i `e;Ii i~~5'. NIPPLE, 5IXi Top Depth (ND) 7op Incl Top (ftK8) (ftNB) (°) Descriptlon Commant Run Oata ID Qn) 503.0 502.6 2.66 NIPPLE CAMCO DS NIPPLE 2/26/1999 2.875 = 5,976.0 3,504.1 66.16 GAS LIFT CAMCO/KGB-2-9/1/DMY/BTM//I Comment: STA 1 5/19/1999 2.900 9,53Z.O 4,997.7 5520 SLEEVE-C Baker CMU cliding sleeve w/CAMCO profile. - CLOSED 2l26/1999 2.813 SURFACE, a.oat 5/19/1999 ~ 9,582.0 5,026.2 55.52 GAS LIFT CAMCO/KGB-2-9/t/OV/BTM W/CHECK/.313// Comment: ?142006 2.900 STA 2 9,634.0 5,055.5 55.86 NIPPLE CAMCO NIPPLE ?l26/1999 2.750 ~ GAS LIFf ` 9,641.0 5,059.4 55.91 SEAL BAKER 5.5" 8o-40 casing seal assembly 2/26/1999 2.985 , 5,978 9,660.0 5,070.1 56.03 TTL 2/26/1999 2.992 ~A ~ = -_,. ~ yt;~„ +~ ~..=; _ , _ -- - ~ ~~Aix~w r~i, ~ ~ ~ _ ~~~,~ ~~,._~~~Ia ~ shot Top (ND) Btm (TVD) Dens "~ Top(ttKB) Btm~ftKB) (ftKB) (ftKB) 2one Date (ah••• Type Comment 4 9,946.0 9,986.0 5,229.8 5,252.7 3/27/1999 4.0 IPERF 2.5" HC BH charges; 180 deg ~ . phasing, un-oriented SLEEVE-C, J 946 0 229 9 961 0 5 6 238 4 5 1/27/2006 0 RPERF 2 5" HC BH charges 6 9,532 , . , . , . , . . . ~rrrula ~~ ~ t~a#~rr~ n`~.~, ~ d s,~ i~ '~u~ ~~ ~.~ '_ ~; , ,~ K ~~:; <~ Bottom Min Top Max Btm Top Depth Depth Dapth Depth (ND) (ND) (ftKB) (ftKB~ (ftK8) (ftKB) Typa Date CommeM ~: '~~:1. 9,946.0 9,986.0 5,229.8 5,252J RE-FRAC t/29/2006 Re-Frac completed through flush, placed 186125M of 16I20 prop in the formation wl 10# ppa @ the peris. GAS UFT, 9,582 ~. "~ I-. ~~. . NIPPLE,9,634 . SEAI. 9.6a1 t TTL. 9.6fi0 PRODUCTION, 8,6fi5 RPERF, T~:. . ; ' : ....:...:..: 9,94fi-9,%1 IPERF~ ......... ............ 9,946-9.986 . RE.FRAC. ...........: :..::.:.. - 9.94fi •••••`:: PRODUCTION, 10,SW TD, 10,520 • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~~! Nt~~ Q 7 2ti07 • o~~ \~~. Enclosed please find a (revised 10/3/07)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 a 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 top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9/28/07 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, ~ __ -1=--._~ on Arend ConocoPhillips Well Integrity Field Supervisor • r: ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/28/2007 Well Name PTD # initial top of cement Vo{. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sea{ant date ft bbls ft al 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9!16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16!2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 20" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 18" n/a 18" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 • • ConocoPhiilips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 28, 2007 Mr. Tom Maunder ~~~~~~ NOV ~ `~ 2007 Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: R~c~~ ocr ~VF4 AJa$k~ ~i1~ Ga ~ 2 ?~O j a~eh0 a8'e C~issr an D~0 `~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRl.l). Each of these wells was found to have a void in the conductor. These voids were filled with a 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 top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, ~~ ~- M.J. vel d ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Tap-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/28/2007 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 2L-~03 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16{2007 2N-313 198-091 5' 0.75 18" 919/2007 2N-335 198-204 9" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9!2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9!27!2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" nla 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n!a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 19&091 5" n/a 5" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 19&143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n!a 1 9/27/2007 2N-319 198-197 5" n/a 5" nIa 9.5 9/27/2007 Schlumbepgel' 10)0, - ot Ö sCANNED JUN 2 1 2007 06/14/07 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 4300 s~ 0 zmn .~mpany: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Log Description Color CD Date BL Job# 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07/07 1 2N-323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08/07 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1 G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10/07 1 1 A-27 11638876 PRODUCTION PROFILE 06/10/07 1 2M-12 11629030 SBHP SURVEY 06/10/07 1 2L·311 11638881 SBHP SURVEY 06/11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 2B-08 11629032 INJECTION PROFILE 06/11/07 1 1 H-08 11638882 INJECTION PROFILE 06/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . e Conoc6Phillips e Mike Mooney Wells Group Team Leader Drilling & Wells February 22, 2006 P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 RECE\VED MÞO.R a 6 LQOo conwriss\on O'~ " Gas Cons. ~'a$~' t ~nt\\Ot8ge Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2N-308 (APD # 199-010) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation and stimulation operations on the Kuparuk well 2N-308. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )/I , }/( b~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells c " MM/skad e e RECEIVED 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate [] Other Ow Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownO Perforate [] Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [] Exploratory 0 199-0101 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20288-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 34' 2N-308 8. Property Designation: 10. Field/Pool(s): ADL 380054, ALK 4602 Kuparuk River Field 1 Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 10520' feet true vertical 5546' feet Plugs (measured) Effective Depth measured 9993' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 84' 16" 118' 118' SURFACE 3007' 7-518" 3041' 2319' PRODUCTION 9631' 5-1/2" 9665' 5073' PRODUCTION 835' 3-1/2" 1 0500' 5535' Perforation depth: Measured depth: 9946'-9986' true vertical depth: 5230'-5253' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 9660' MD. Packers & SSSV (type & measured depth) no packer Cameo OS nipple @ 503' 12. Stimulation or cement squeeze summary: Intervals treated (measured) refer to attachment RBDMS BFt MAR () 6 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 580 1734 622 -- 245 Subsequent to operation 268 3004 1789 -- 255 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development [] Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil[] GasO WAG 0 GINJO WINJO WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Lead Signature NI. AIl'n/~ Phone Date 3/¡;/O~ Prenared bv Sharon AI/sun-Drake 263-4612 j ðfr1 Rlj~A1 5' it':; .."£, . . MAR 0 6 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIO~ska Oil & Gas Cons. Commission STATE OF ALASKA Form 10-404 Revised 04/2004 OR\G\NAL A't> ~~.,~ Submit Onglnal Only e e 2N-308 Well Events Summary DATE Summary 1/9/2006 CUT LIGHT/SOFT PARAFFIN FROM SURFACE TO 4500' SLM. GAUGED TBG TO 2.85" TO 4500'. TAGGED @ 9996' RKB, EST. 10' RATHOLE. 1/19/2006 WASHED TUBING TO 9900' CTM W/ 150 DEG DIESEL @ 1.5 BPM USING 2.20 SIDE- JET NOZZLE. WELL LEFT FLOWING DURING JOB; ALL RETURNS TAKEN DOWN FLOWLINE. 1/21/2006 TAGGED FILL @ 9984' RKB, 2' OF FILL, IN PROGRESS 1/24/2006 DRIFTED TBG W/ 23.5' OF 2.5" DUMMY GUNS, TOOLSTRING STOPPED FALLING AT 9984' RKB. PUMPED DOWN, SET CAT SV @ 9634' RKB, FAILD PT, IN PROGRESS. 1/25/2006 PULLED OV @ 9582' RKB, VALVE WAS SLIGHTLY BENT. JOB STILL IN-PROGRESS. 1/26/2006 PUMPED 200 BBLS OF DIESEL DOWN TBG TAKING RETURNS UP THE lA, SET DV @ 9582' RKB & PT'D TUBING TO 3500 PSI. PULLED CAT SV @ 9634' RKB. 1/27/2006 PERFORATED 9946' - 9961' RKB WITH 2.5" HSD GUN. 6 SPF, WITH HYPERJET BIG HOLE CHARGES. TAGGED TO @ 9980'. 1/29/2006 Re-Frac completed through flush, placed 186125# of 16/20 prop in the formation w/ 10# ppa @ the perfs. Frac was completed per design using 50# XL Gel and a Bracket Frac was pumped in front of the Frac stage. 200 psi of net pressure gain was seen. 2083# of prop was left in wellbore. Well is freeze protected with diesel down to 3800'. 1/31/2006 PERFORMED A NITRIFED FILL CLEAN OUT TO 10,100' CTD IN 3.5" LINER WITH A 2.0" JET SWIRL NZL. PUMPED DIESEL & DIESEL GEL. CT STUCK MID PERFS FROM 9939' - 9956' CTD, ABLE TO WORK FREE PUMPING AT VARIOUS RATES & CIRCULATING FLUIDS. WELL SI AND FREEZE PROTECTED. 2/3/2006 TAGGED FILL @ 9992' RKB, EST. 6' RATHOLE. SET 2.80 CATCHER SUB @ 9634' RKB. IN PROGRESS. 2/4/2006 SET 5/16" OV @ 9582' RKB. PULLED CATCHER SUB @ 9634' RKB. 'ROOUCTION (0-9665. 00:5.500. Wt:15.50) SLEEVE-O (9532-9533, 00:3.500) Gas Lift MandrelNalve 2 (9582-9583, NIP (9634-9635. 00:3.500) SEAL (9641-9642. 00:4.000) 'ROOUCTlON (9665-10500. 00:3.500, Wt:9.30) Perf (9946-9986) NIP (503-504, 00:3.500) TUBING (0-9660, 00:3.500. 10:2.992) lugs. equip.. TVD Type 503 NIP CAMCO DS 4998 SLEEVE-O Baker CMU clidin 5055 NIP CAMCO 5059 SEAL BAKER 5.5" 80-40 casin 5070 TTL ID 2.875 . . .....----"- 2.813 2.750 -------.-- __~.~.9~ 2.992 MandrelslValV'êš MD TVD M,Jn Mfr CAMC CAMC 3504 5026 Descri = ~._--- Man Type' V Mfr V Type ' VOD Latch 0 KGB-2-9 CAMCO DMY 1.0 BTM 0 KGB-2-9 CAMCO OV 1.0 BTM ,tion ort TRO 000 I 0 31~3I~ Date Run 5/19/1999 ,5/17/1999 Vlv Cmnt Intervi11 9946 - 9986 Size 3.500 Descri Annular Fluid: Reference Log: Last Tag: Last Tag Date: fype~l--::---:~_ Comment PERF ¡ 2.5" HC BH charges; 180 __º~g p~asing, un-oriented TVD 5230 - 5253 Zone Status Ft 40 SPF I Date 413/27/1999 Bottom i __._~_t?~~ Size To ----- - 16.000 0 ··r------- 7.625, 0 S:SOÕ---r------o- .d..·· ______ 3.500 9665 TVD 5070 Bottom 118 3041 9665 10500 Wt 9.30 Grade L-80 TVD-....-..·-nwt-¡ Grade 118-6:i:5~L l.:8~40_ ~~j~ ~~ig -f--t~~ - ---- --..... .-- 5535 9.30 L-ª-º__ Thread EUE 8rd Thread WELDED BTC-MOD BTC-MOD EUE 8rd _-','Y~!!__Iyp~.:~pROD .. Orig' 2/26/1999 Completion:' _n___. Last W/O: ' --.-----... --..- .-- .---.-.. ......--.- Ref Log Date: ¡ .._ __.__ TD: ¡ 10520 ftKB ax HOlel ''S8 dëg-@i 4218 Anale: API: 501032028800 SSSV Type: NIPPLE 10520 ConocoPhUlips Ala_a, Inc. e KRU ~-308 Schlumbergep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well j"" 2N-305 J.ð 0- ì jS- J .2N-308 I q~ -O¡r:. .I2N-317 ,q S .~ p(~ U2G-06 13 "'( - c.~). ../ 1 Y -04 ¡ 8 ') - û ~ l '-/.3J-10 i ~ i ....J..Ç"Ò J2U-10 'Ji-t)i:{ ""'1C-178 ~3- lett Job# 11047348 11047344 11047345 11022913 11047351 11058227 11047352 11022908 f-, r" i'· r ':. , :=-- i:-'. '"" ~ ?>- ~'. '"' n f" .. ¡)~f1à\H\! t;L; ;) rj'" 0 D L LJ U J Log Description SBHP SURVEY SBHP SURVEY SBHP SURVEY FLOWING BHP INJECTION PROFILE V í (. MULTI-FINGER CALIPER LOG PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE WIDEFT /,'1 / ~"j! tll / /1 i: ,l I /jtt,'V""fIr-t-- (/ /i¡¿,¿--d SIGNED: Date 07/25/05 07/24/05 07/24/05 07/20/05 07/27/05 07/18/05 07/28/05 07/14/05 08/03/05 NO. 3443 I qq-Ð 10 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color - CD 1 1 1 1 1 1 1 1 --- ~s.".'" ~"'Ä1~ DATE: v"7:-_~- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Schlumberger NO. 3357 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth /?9 -cfJ/O 02/28/05 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~c ~"N~iE:Sj 'UN· c¡ tï 200~ t) Pi ~~ w v . ~ 0 ;) Field: Well Job # Log Description Date BL i'ð5 -û5C 2V-12 10942845 PROD PROFILE/DEFT 02/16/05 1 t8'-1--153 20-03 10922538 PROD PROFILE/DEFT 02/06/05 1 ;¿ &0 '2.1 &? 10-39 10942838 INJECTION PROFILE 02/11/05 1 1ri'5 -DlC:¿~ 2V-10 10942846 PROD PROFILE/DEFT 02/17/05 1 ~O(- FB5 1 C-131 10942848 INJECTION PROFILE 02/19/05 1 170 - jrjp/ 1A-19 10942839 PRODUCTION PROFILE 02/12/05 1 /79 -c/o 2N-308 10942843 PRODUCTION PROFILE 02/14/05 1 ~~~~~b 1 L-17 10942850 INJECTION PROFILE 02/21/05 1 1 B-15A 10922540 SCMT 02124/05 ~ [ 1 L-24 (REDO) 10942834 RST WFL & PPROF 01/26/05 1 tl/..-IJfvtp SIGNd4~¡ /J£h~ Please sign and returi~ copy of this transmittal to Beth at the above address or fax to (907) 561-8317. DATE: Thank you. Kuparuk Color --/ CD 1 ~ ~þ- Page 1 of 1 ( ¡{ I, PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Transmittal #72 Detail Date: 11/2/01 To (External Party): Email: Okland First Name: Howard Last Name: Okland From (PAl Contact): Email: cworley@ppco.com First Name: Catherine Last Name: Worley Phone (907)793-1235 Number: Company: AOGCC Address: 333 W.7th Phone Number: (907) 265-1129 City: Anchorage State: AK Zip Code: 99510 Company: Phillips Alaska Add A TO 1490 700 G ress: Street City: Anchorage State: AK Zip Code: 99510 Transmittal Info: Sent Via: Hand Delivery Justification: Compliance - replacement Tracking #: Data Detail: Quantity Description Type ;9q- /6:;,1 J~d9'{t'Phillips NV -18 digital well log data: Baker Hughes logged 3" floppy disk 27DEC99; Sperry Sun logged 27DEC99. fie¡ 10 1 Phillips 2N-308 digital well log data by Sperry Sun logged 3" floppy disk J8d1S . 23FEB99 Attachments: Filename: None Filesizec. ~!PE. [...,,", R' E 'J .m ,. ): . . . ",.. -'. Receiv~ By: ~ fI1 J J If SIgnature: UJW NOV 0 2 ("iil': Date: ¡Alaska Oil & Gas Cons. Commission Anchorage Approver: Signature: Date: ~Oy ~~~(\\~ http://www .ak. ppco.com/transmi ttal/printasp ?transno=72 11/2/01 " .t - .1';1.' ~ if JCf9-ol D MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, LCè:J DATE: July 20, 2000 Commissioner d' / / /' Q cv co THRU: Blair Wondzell, ~.. P. I. Supervisor ø FROM: John crisP~.fv.. c. SUBJECT: Safety Valve Tests Petroleum I pector Kuparuk River Unit Tarn Field 2N & 2L Pads Julv 20. 2000: I traveled to Phillips Alaska's Kuparuk River Unit Tarn Field to witness the semi-annual Safety Valve System tests on Pads 2N & 2L. Testing went well with only one failure on 2L Pad witnessed. No failures were witnessed on 2N Pad. The AOGCC test report is attached for reference. SUMMARY: I witnessed the semi-annual SVS tests on KRU's Tarn Pads 2N & 2L. 2N Pad, 9 wells, 18 components tested. No failures. 2L Pad, 6 wells, 12 components tested. 1 failure. 8% failure rate. Attachments: SVS Tarn KRU 2N & 2L 7 -20-00jc cc. ~ NON-CONFIDENTIAL SVS Tam KRU 2N & 2L 7-20-00jc.doc ..1 - ( ~, Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: FieldiUnitlPad: Tam, Kuparuk. River, 2N Separator psi: LPS 94 HPS 7/20/00 I':':;~;:_.:::'.~~n~~,;~~~~.~~;::~";!::;.':. :;..f_~~~:~.: ~.:.~:~: .:~.~~~.:..~.'~~~~~~L~~'.'~.._:~,.:~C~':.:'~::: :'~.'.~;~.,r::.~:,:~:.~.:~,,~.~._, :....:::.~:.'~~.:~'~~ }~.~~~::~ LB¿~1:~~~:.:~' ='\'::.~~~~._~.~:i~::~ -~~!~ .'Tjp.~.;::~:J -. - . --- -.-..-.-- Well Number Test Oil, WAG, GINJ, . I ..- ..- -... - - -.. --. --- -.... ..-... 2N-307 1990170 ~ ~~\\\f':"""'I'~t <,~.# 1990 1 00 94 70 65 P P OIL 1,,1I.J"'l£"" 2N-309 1990210 2N-313 1980910 94 70 70 P P OIL 2N-315 1981900 2N-317 1981430 94 70 70 P P OIL 2N-319 1981970 2N-320 1990010 94 70 65 P P OIL 2N-321A 1981730 2N-323 1980710 94 70 70 P P OIL 2N-325 1981630 2N-329 1980670 94 70 70 P P OIL 2N-331 1981170 2N-335 1982040 94 70 70 P P OIL 2N-337A 1981220 2N-339 1981000 2N-341 1981030 94 70 65 P P OIL 2N-343 1980920 2N-345 1981130 2N-347 2000630 94 70 60 P P OIL Wells: 9 Components: 18 Failures: 0 Failure Rate: 0.0% 090 Day Remarks: 7/27/00 Page 1 of 1 SVS Tarn KRU 2N 7-20-00jc.xls ~ -. , - ~ ( Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: FieldlUnitlPad: Tarn, Kuparuk River, 2L Separator psi: LPS 94 HPS 7/20/00 Permit Separ Set Test Test Test Oil, WAG, GINJ, Number PSI PSI Code Code Code GAS or CYCLE 2L-305 1982400 94 70 60 P 4 OIL 2L-307 1982560 94 70 70 P P OIL 2L-313 1982190 94 70 65 P P OIL 2L-315 1982180 94 70 70 P P OIL 2L-321 1982620 2L-323 1982510 2L-325 1982090 94 70 65 P P OIL 2L-329A 1982250 800 700 700 P P GAS Well Number . Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% 090 Day Remarks: 7/27/00 Page 1 of 1 SVS Tarn KRU 2L 7-20-00jc.xls (' 5pe~~Y-5Un CRILLING seRVIc:es ( WELL LOG TRANSMrrrAL To: State of Alaska Alaska Oil and Gas ConselVation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 July 20, 1999 cfi -01 Ù RE: MWD Fonnation Evaluation Logs 2N-308, AK-:MM-90084 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Jim GalviI\ Sperry-Sun Drilling SeIVÍces, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-308: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20288-00 1 Blueline 1 Folded Sepia 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20288-00 1 Blueline 1 Folded Sepia 2" x 5" MD Neutron & Density Logs: 50-103-20288-00 1 Blueline 1 Folded Sepia 2" x 5" TVD Neutron & Density Logs: 50-103-20288-00 1 Blueline 1 Folded Sepia ;, q",i~ -¡qgq , , \i L,. '..' ,. . ':,,~r:\ nrau'.:: }.~b \ ~~ {\f("J!.- y<) 3> \)( l~'> -It:: I 0 ~ b ~\l\- ~ . ';'315\~~ ~..:;;¡;& (;;:>3" '.:~ :.i;~'(:-:~¡i~:!C~' 5631 Silverado Way, Suite G . Anchorage, Alaska 99518 . (907) 273-3500 . Fax (907) 273-3535 A Halliburton Company ( ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 2761215 May 20, 1999 Mr. Robert N. Christenson Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 (¡ Subject: 2N-308 (Permit No. 99-10/399-027) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on 2N-308. If there are any questions, please call 263-4603. Sincerely, '~fJ1~ P. Mazzolini Drilling Team Leader PMlskad , \" J'-' '~'-"'" """ .J<"'" ,,'- !' ~11 IL,' il ¡,':I'" ~' \",1\/ ',\',,',,~ '" ,,',- r~ \1 ,'" , II ,- " ~"V' ~ \ì....,.' ,ð ': ,", . II , . 1('1 ,~, .", , ~'I . '" ,- I' "", '.." I ,(,~~I:,:,:::i -i- ¡,¡j,î~'E'ka Oil ~~~ Gas Co, n~J', 1,1 .,~'¡J "' Anchorag:;;. ~~ ~~ "'.::"" COJ" ~ ,~ It" ~ ~~ J, A,' ", I: \~, '" II; (,t, I 'f" (i "~i",(\,!!,,>f)!:,!::,',i""':~_'" ¡: ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~' 1. Status of well Classification of Service Well Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 0 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-1 0 / 399-027 3. Address 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20288 4. Location of well at surface ~'o.. "_"",,.,-,.,,~,."~'- 9. Unit or Lease Name 16' FNL, 573' FEL, Sec. 3, T9N, R7E, UM ';J~ - .. , ., . Kuparuk River Unit At Top Producing Interval E 10. Well Number 2015' FSL, 2329' FWL, SEC 27, T10N, R7E, UM . .: ~ ,,' ,~ 2N-308 ;~D¡ At Total Depth . --" :, ~~~ 11. Field and Pool " " 2555' FSL, 2120' FWL, SEC 27, T10N, R7E, UM - -I "~.$:8 Kuparuk River Field '~"'~""'."'-'-'.co""'--"'~'~-- 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. -"... ~,p(j ": "".~.._~:,.,-- 34 RKB feet ADL 380054, ALK 4602 Tarn Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions February 13, 1999 February 23, 1999 February 26, 1999 N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10520' MD I 5546' TVD 10372' MD I 5466' TVD YES 0 No 0 N/A feetMD 1238' (approx) 22. Type Electric or Other Logs Run GRICCL, GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER Fr. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 118' 24" 9 cu yds High Early 7-5/8" 29.7# L-80 Surface 3041' 9.875" 381 sx AS III & 235 sx Class G 5.5" x 15.5# L-80 Surface 9665' 6.75" 272 sx Class G 3.5" 9.3# L-80 9665' 10500' 6.75" (included above) 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) 3-1/2" 9660' 9644' (CSR) 9946'-9986' MD; 5230' -5253' TVD @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9946'-9986' 83989# of prop behind pipe, 5.5 ppa on perfs 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 6, 1999 Flowing Date otTest Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 5/9/1999 12.0 Test Period> 1383 1647 21 100 1601 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) Press. 400 psi 0 24-Hour Rate> 2356 3772 42 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved (Permit #99-10 /399-027) ¡DECE'V~D ORIGINAL ;'I~, , " ,Þ' !¥\. , L -"'" ¡;' \\1" ? r,; 19991 1\".1,'- ~ ...~ '1,.-' Form 10-407 Rev. 7-1-80 CONTINUED ON RE,VERSE §,IDEC (\ mml,~slo\"" ~A.!aska 011 & Üas ons. \.,0, "'.~" I ' Anchorage Submit in duplicate 29. ( 30. { t GEOLOGIC MARKERS FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. T-3 9828' 5163' T-2 10071 ' 5301' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations and Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~ Paul Mazzolini , '\ Title Tarn Drillina Team Leader -5" Date 124 I qq , Prepared by Sharon Allsup-Drake 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 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 (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ( ( Date: 4/16/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 RIG:POOL 6 WI: -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- SECURITY: 0 WELL: 2N-3 0 8 WELL_ID: AK9781 AFC: AK9781 API NUMBER: 50-103-20288-00 AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:02/13/99 START COMP: TYPE: STATE:ALASKA BLOCK: FINAL: 0% 02/12/99 (D1) MW: 0.0 VISC: 0 PV/YP: TD: 0' ( 0) NU DIVERTER SUPV:FRED HERBERT / RICK OVERSTREET Moving rig from 2N-320 to 2N-308. 0/0 -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- APIWL: 0.0 02/13/99 (D2) TD: 125' ( 125) SUPV:FRED HERBERT MW: 9 . 8 VI SC : 93 PV / YP: 23 /26 . DRILLING @ 425'. & RICK OVERSTREET Move rig from 2N-321 to 2N-308. Accept rig @ diverter and test. Drill from 118' to 125'. 02/14/99 (D3) MW: 10.2 VISC: 60 PV/YP: 27/26 TD: 2020' (1895) DRILLING @ 2666'. SUPV:FRED HERBERT & RICK OVERSTREET Drill from 125' to 2020'. Pump dry job. 02/15/99 (D4) TD: 3 0 5 5' (1 0 3 5 ) SUPV:FRED HERBERT MW: 10.2 VISC: 72 PV/YP: CIRC & WORK THRU TIGHT SPOT @ 920' & RICK OVERSTREET Drilling 9-7/8" hole could not work pipe. Drilling 9-7/8" hole condition for casing casing. 36/37 APIWL: 10.0 0400 hrs. N/U APIWL: 6.6 APIWL: 6.5 from 2020' to 2677'. Hole packed off, Work pipe free and regain circ. from 2677' to 3055'. Circ and job. Pump dry job and POOH to run 02/16/99 (D5) TD: 3055' (0) NU BOPE SUPV:FRED HERBERT & SCOTT REYNOLDS Run 7-5/8" casing. Tight @ 920'; cement job. Clean out cement and MW: 10.3 VISC: 48 PV/YP: 17/13 APIWL: 7.4 wash thru tight spot. Pump contaminated mud. MW: 10.2 VISC: 54 PV/YP: 27/18 RUNNING IN HOLE SCOTT REYNOLDS Remove bell nipple to clean cement out of Hydril and function test. ND diverter. NU BOPE and test to 3500 psi. 02/17/99 (D6) TD: 3 055 ' ( 0 ) SUPV:FRED HERBERT & APIWL: 7.2 Date: 4/16/99 02/18/99 (D7) TD : 3 63 5' ( 58 0 ) SUPV:FRED HERBERT & 02/19/99 (D8) TD: 5425' (1790) SUPV:FRED HERBERT & 02/20/99 (D9) TD: 72 93 ' (18 68 ) SUPV:FRED HERBERT & ( (" ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 MW: 9.6 VISC: 39 PV/YP: 13/16 APIWL: 6.2 CHANGE OUT KELLY HOSE. DEPTH 4102 MD/2754 TVD. PROGRESS 104 SCOTT REYNOLDS Drill out float collar, cement, circ out contaminated mud. Drill out cement, shoe and 20' new hole. Performed LOT. Drill from 3075' to 3635'. MW: 9.6 VISC: 42 PV/YP: 14/19 DRILLING @ 6002' SCOTT REYNOLDS Drill from 3635' to 4102'. Kelly hose sprung a leak. RU to circ thru cement hose. POOH to shoe. Check for flow several times, well static. Drilling from 4102' to 5245'. APIWL: 6.8 MW: 9.6 VISC: 46 PV/YP: 16/23 MAKING HOLE SCOTT REYNOLDS Drill from 5245' to 6165'. Circ lo/hi vis sweep in preparation for wiper trip. Observe well, static. Pump dry job. POOH to 3920'. Tight @ 5451'-4606'-4140'. Observe well, static. CBU to check for gas. Drill from 6165' to 7293'. APIWL: 6.2 02/21/99 (D10) MW: 9.6 VISC: 41 PV/YP: 11/17 TD: 9174' (1881) MAKING HOLE, DROPPING ANGLE. SUPV:FRED HERBERT & SCOTT REYNOLDS Drill from 7293' to 9174'. 02/22/99 (D11) TD: 10099' ( 925) SUPV:FRED HERBERT & 02/23/99 (D12) TD:10520' ( 421) SUPV:D.P. BURLEY / APIWL: 5.4 MW: 9.6 VISC: 43 PV/YP: 12/21 CIRCULATING SWEEP @ TD OF 10510' MD. SCOTT REYNOLDS Drill from 9174' to 9835'. Circulate sweep around. Check for flow, well static. Pump dry job. Drill from 9835' to 10099' . 5.1 APIWL: MW: 9.7 VISC: APIWL: 4.8 46 PV/YP: 12/19 POH. RICK OVERSTREET Drill from 10099' to 10510'. Pumped low/high vis sweeps and circ clean, monitor well, pump dry job. Wiped hole to shoe, tight spots at 8050' and 7494'. RIH to 10510' no problems. drill additional 10' of rathole, TD @ 10520'. 02/24/99 (D13) MW: 9.8 VISC: 48 PV/YP: 14/19 TD:10520' (0) ON BOTTOM W/CASING. SUPV:D.P. BURLEY / RICK OVERSTREET Run. 3.511 casing. Run 5.511 casing. APIWL: 4.4 02/25/99 (D14) MW: 9.7 VISC: 44 PV/YP: 15/15 APIWL: 5.6 TD:10520' (0) RUNNING 3-1/211 COMPLETION. ACTUAL CUMMULATLIVE COST = $1,48 SUPV:D.P. BURLEY / RICK OVERSTREET Run 5.511 casing. Pump cement. Run seal assy and 3.511 tubing. 02/26/99 (D15) MW: 8.6 VISC: APIWL: 0.0 28 PV/YP: 0/0 (, ( TD:l0520' (0) NU ON 2N-307. SUPV:D.P. BURLEY 1 RICK OVERSTREET Run 3.5" tubing. Freeze protect. NIU tree and test to 5000 psi. Release rig @ midnight 2/26/99. ( (' ~ ARca Alaska, Inc. ~-.... ~". KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (2N-308(W4-6» WELL JOB SCOPE JOB NUMBER 2N-308 PERFORATIONS-E-LiNE 0322991844.5 DATE DAILY WORK UNIT NUMBER 03/27/99 INITIAL PERFORATIONS DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 YES YES 8WS-JOHNSON CHANEY FIELD AFC# CC# Signed ESTI MATE AK9789 35TN2N 1 NG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI DAILY SUMMARY INITIAL PERF'S SHOT @ 9946'-9986' RKB USING 2.5" HC--> BH CHGS--> 4 JSPF--> 180 DEGREE PHASING--> UN-ORIENTED GUNS. SHOT SLIGHTLY OVER BALANCED. WHTP DROPPED TO 0 PSI AFTER PERFING.rPerfl TIME LOG ENTRY 08:00 MIRU SWS E/LiNE. HELD SAFETY MEETING (4 PEOPLE ON LOCATION). 08:45 PT'D EQUIPMENT TO 3000 PSI. 09:45 RIH W/ 1-3/8" HEAD, 1-11/16" SWIVEL, 2-1/8" WEIGHT BAR (5'),1-11/16" CCL, 2.5" ESIC, & (20') OF 2.5" HC--> BH CHGS--> 4 JSPF-->180 DEGREE PHASING--> NO ORIENTATION. 11 :00 @ 7000' CCL STARTED ACTING UP. TROUBLESHOOT TOOLS AND CONTINUED JOB. 11 :30 TIED IN. 12:00 POSTIONED GUNS TO PERF 9966' - 9986'. WHTP @ 200 PSI. WHTP DROPPED TO 150 PSI WHEN THE GUNS WERE FIRED. 12:10 STARTED OOH 13:00 ON SURFACE, ASF 14:10 PICKED UP NEXT GUN. 14:20 RE-PT'D EQUIPMENT TO 3000 PSI. 14:30 RIH W/ 1-3/8" HEAD, 1-11/16" SWIVEL, 2-1/8" WEIGHT BAR (5'), 1-11/16" CCL, 2.5" ESIC, & (20') OF 2.5" HC--> BH CHGS--> 4 JSPF-->180 DEGREE PHASING--> NO ORIENTATION. 15:30 @ 9800' STARTED HAVING PROBLEMS WITH THE CCL AGAIN. TROUBLESHOOT TOOLS. APPEARED TO CORRECT ITSELF. 15:40 TIED IN. 15:45 POSITIONED GUNS TO SHOOT PERF'S @ 9946'-9966'. WHTP WAS 0 PSI. FIRED GUNS, NO WHTP CHANGE IT REMAINED 0 PSI. 16:00 STARTED OOH. 17:15 ON SURFACE, ASF. 19:15 RDMO SWS E/LiNE UNIT. WELL SECURED AND NOTIFIED DSO OF STATUS. r,'"j,,',~,~j E",' (, ' E-.. , '\" F""" [,"\ ,..,~:¡ '" I I 0, ,'I,: "~, ... """I, : ~ ¿...., ,ï. "l' .. I ',' I, . V il'"¡"'" 1 a. :, n ) , t,t' I"~ , ' ;~J <,.;, " .' ,'.." '".. "'.' I\!II/ ~NaSka tm l~ Gas Cons, Corß!n~s~Þìô~) Anchorage ( ð ~ ARCO Alaska, Inc. ~-... ~". KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (2N-308(W4-6» WELL JOB SCOPE JOB NUMBER 2N-308 PERFORA TIONS-E-LiNE 0322991844.5 DATE DAILY WORK UNIT NUMBER 03/26/99 INITIAL PERFORATIONS DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 NO YES SWS-JOHNSON CHANEY FIELD AFC# CC# Signed ESTIMATE AK9789 35TN2N1 NG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI CAlLY SUMMARY I TAGGED BTM A 10331' RKB, TIED IN TO MWD LOG WI GRICCL THEN LOGGED JEWERLY.~ TIME LOG ENTRY 15:00 ARRIVE AT LOCATION AND STOOD-BY FOR ACCESS TO THE PAD. 16:00 MIRU SWS E/LINE UNIT. HELD SAFETY MEETING (4 PEOPLE ON LOCATION). 17:30 PT'D EQUIPMENT TO 3000 PSI. 18:00 RIH WI WEIGHT BAR 5', ROLLER, WEIGHT BAR 5', ROLLER, GR, CCL, & ROLLER. FN=1-3/8", MAX 00 OF TOOLSTRING 1-11/16". 20:00 TAGGED BTM @ 10331' RKB. 20:30 TIED IN TO MWD LOG WI GR PER REQUEST AND OBTAINED A JEWERL Y LOG. 20:45 STARTED OOH. 21:45 ON SURFACE. 23:00 RDFN SWS E/LINE UNIT. WELL SECURED & DSO NOTIFIED OF STATUS. ( { ARca Alaska, Inc. ~~ ~". KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (2N-308(W4-6» WELL JOB SCOPE JOB NUMBER 2N-308 FRACTURING. 0420990652.4 DATE DAILY WORK UNIT NUMBER 04/29/99 FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 YES YES OS-YOAKUM ODELL FIELD AFC# CC# Signed ESTIMATE AK9781 35TN2N1 NG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI DAILY SUMMARY PUMPED FRACTURE TREATMENT, NWB SCREEN OUT - 83989 LBS OF PROP BEHIND PIPE - 5.5 PPA ON PERFS. ALL TREESAVER RUBBERS RECOVERED.rFrac-Refracl TIME LOG ENTRY 07:00 MIRU DS PUMPING SERVICES 08:15 HOLD TG SAFETY MEETING 08:45 PRESSURE TEST TO 9500 PSI 09:15 PUMP BREAKDOWN 250 BBL 20# GEL AT 30 BBUMIN 8000 PSI - PERFORM STEP DOWN TEST AT END OF STAGE. TREATING PRESSURE = 8540 PSI. NWB FRICTION = 5392 PSI. EXTREMELY HIGH. 09:50 START SCOUR STAGE, ACTIVATOR PUMP PROBLEMS, PUMP 100 BBLS PRE-PAD AT LOW RATE WHILE GETTING ACTIVATOR LINED OUT. PUMP 100 BBLS 40# XL GEL PAD, 75 BBLS 40# XL GEL WI 1 PPA SCOUR, FLUSH WITH 139 BBLS 20# LINEAR GEL. PERFORM STEP DOWN TEST, NWB FRICTION DROPPED -300 PSI. 10:30 PUMP 300 BBL XL GEL DATA FRAC AT 20 BBUMIN 2150 PSI, BUILT TO 3400 PSI AT END OF DF. 10:40 PUMP 89 BBL SLICK WATER FLUSH - SHUT DOWN - WAIT FOR FRAC CLOSURE 11 :27 PUMP PULSE - CHANGE PAD TO 550 BBL 11 :45 PUMP 550 BBL PAD 40# XL GEL AT 20 BBUMIN AT 2270 PSI 12:25 START 104.4 BBL OF 1 LB PROPPANT - 109 BBL OF 2 LB AT 20 BPM 1950 PSI - 519 BBL RAMPING TO 6 PPA 12:55 PRESSURE INCREASED INSTANTANEOUSLY TO APPROX 4000 PSI AT 450 BBLS PUMPED, CUT SAND, PRESSURE STABILIZED AT 4000, BROUGHT SAND BACK UP TO 5 PPA. 13:05 NEAR WELL BORE SCREEN OUT - 98.8 BBL PUMPED OUT OF 388.8 BBL SLURRY STAGE - BH PROP CONC=5.5 PPA - 83,989 LBS PROP IN FORMATION - 102,549 LBS TOTAL PROP PUMPED, 18,560 LBS IN WELLBORE. 13:15 RIG DOWN DOWELL, ALL TREE SAVER RUBBERS RECOVERED. 15:30 DOWELL RIGGED DOWN, WELL SECURE. ... Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2N, Slot 2N-30B 2N-30B Job No. AKMM90084 Surveyed: 23 February 1999 c::r9.0\0 ~. OR I GINAL SURVEY REPORT 4 March, 1999 -".'. Your Ref: API-501032028800 KBE-156.77 Surface Coordinates: 5911990.49 N 461020.11 E (70010' 13.8000" N 150018' 49.3775" W) s pe!r""" y - S un DRILLING SERVices A HALLIllURTOI'I CONPAHY Survey Ref: svy8359 z m ã" 0 ::. ~ ~m g- ee" -° ~~ CD(=.. ~ S w' ~. g . Prudhoe Bay Unit Measured Depth (ft) 0.00 201.66 294.75 384.18 474.15 562.63 653.00 742.00 830.00 911.00 1011.00 1101.00 1192.00 1286.00 1379.00 1473.00 1566.00 1661.00 !1~.50 ;?-::~ M6O ,.J.~~' " ~~ ~38 f'.) aouì50 Cï 2'tS5';'0 1 ¿~ ~69 ~ 2'~~ 6 ~-1 't~"ø' 4 March, 1999 - 9:20 Incl. 0.000 1.000 1.460 2.770 3.070 4.810 8.070 11.730 14.820 18.460 23.080 25.560 26.290 28.280 30.330 32.680 35.830 38.280 40.780 43.900 46.010 47.830 50.640 53.660 56.660 Azim. 0.000 2.530 12.980 21.690 17.880 14.480 13.910 12.530 9.700 8.940 7.190 7.370 5.950 0.180 354.480 351.190 347.670 346.060 343.850 342.640 342.120 341.750 343.190 341.690 340.590 Sperry-Sun Drilling Services Survey Report for 2N-30B Your Ref: A PI-50 1032028800 Job No. AKMM90084, Surveyed: 23 February, 1999 Sub-Sea Depth (ft) -156.77 44.88 137.95 227.32 317.17 405.44 495.22 582.88 668.52 746.12 839.59 921.60 1003.44 1087.00 1168.11 1248.25 1325.12 1400.93 1473.81 1543.36 1612.55 1676.84 1737.89 1794.75 1848.15 Vertical Depth (ft) 0.00 201.65 2!:}4.72 384.09 473.94 562.21 651.99 739.65 , 825.29 902.89 996.36 1078.37 1160.21 1243.77 1324.88 1405.02 1481.89 1557.70 1630.58 1700.13 1769.32 1833.61 1894.66 1951.52 2004.92 Local Coordinates Northings Eastings (ft) . (ft) O.OON 1.76 N 3.73N 6.84N 11.16 N 17.00 N 26.83 N 41.73 N 61.56 N 84.45 N 119.56 N 156.32 N . 195.83 N 238.82 N 284.23 N 332.95 N 384.37 N 440.10 N 498.17 N 558.84 N 624.68 N 690.03 N 757.56 N 827.32 N 899.90 N 0.00 E 0.08 E 0.38 E 1.43 E 2.98 E 4.63 E 7.11 E 10.57 E 14.41 E 18.15 E 23.07 E 27.76 E 32.37 E 34.60 E 32.41 E 26.24 E 16.58 E 3.55 E 12.09 W 30.38 W 51.29 W 72.61 W 93~93 W 116.02 W 140.83 W -2- Global Coordinates Northlngs Eastlngs (ft) (ft) 5911990.49 N 5911992.25 N 5911994.21 N 5911997.33 N 5912001.63 N 5912007.47 N 5912017.28 N 5912032.17 N 5912051.98 N 5912074.85 N 5912109.93 N 5912146.66 N 5912186.15 N 5912229.13 N 5912274.55 N 5912323.30 N 5912374.77 N 5912430.57 N 5912488.71 N 5912549.48 N 5912615.43 N 5912680.89 N 5912748.53 N 5912818.39 N 5912891.10 N 461020.11 E 461020.20 E 461020.51 E 461021.58 E 461023.15 E 461024.83 E 461027.35 E 461030.90 E 461034.84 E 461038.691; 461043.79 E 461048.68 E 461053.49 E 461055.94 E 461053.98 E 461048.06 E 461038.67 E 461025.93 E 461010.59 E 460992.61 E 460972.03 E 460951.05 E 460930.09 E 460908.35 E 460883.92 E Alaska State Plane Zone 4 Kuparuk 2N Dogleg Vertical Rate Section (°/1000) (ft) 0.496 0.548 1.504 0.397 1.983 3.608 4.121 3.587 4.502 4.661 2.757 1.053 3.519 3.721 3.097 4.000 2.774 3.035 3.427 2.190 1.955 3.223 3.500 3.352 Comment .-. 0.00 1.65 3.43 6.07 9.69 14.74 23.33 36.43 54.11 74.73 106.61 140.13 176.29 216.49 260.37 308.61 360.50 417.54 477.60 540.95 ~-, 610.03 678.77 749.59 822.75 899.45 Conffnued... DrlllQuest . Sperry-Sun Drilling Services Survey Report for 2N-30B Your Ref: A PI-50 1032028800 Job No. AKMM900B4, Surveyed: 23 February, 1999 Alaska State Plane Zone 4 Prudhoe Bay Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft) --~~. 2418.26 59.820 339.280 1899.25 2056.02 977.43 N 169.16 W 5912968.78 N 460855.98 E 3.451 981.94 2512.32 62.800 337.910 1944.40 2101.17 1054.24 N 199.29 W 5913045.74 N 460826.26 E 3.416 1064.29 2607.66 64.650 338.820 1986.61 2143.38 1133.70 N 230.80 W 5913125.36 N 460795.15 E 2.121 1149.60 2698.50 66.220 337.810 2024.37 2181.14 1210.47 N 261.33 W 5913202.29 N 460765.02 E 2.002 1232.04 2793.09 66.060 336.940 2062.63 2219.40 1290.31 N 294.61 W 5913282.30 N 460732.15 E 0.856 1316.26 2886.30 66.590 337.060 2100.06 2256.83 1368.89 N 327.96 W 5913361.05 N 460699.20 E 0.581 1403.30 2961.74 66.710 338.920 2137.89 2294.66 1450.12 N 360.80 W 5913442.45 N 460666.79 E 1.794 1490.70 3093.56 65.600 339.000 2183.10 2339.87 1545.58 N 397.52 W 5913538.10 N 460630.56 E 0.995 1592.83 3186.54 65.560 339.360 2222.36 2379.13 1626.42 N 428.26 W . 5913619.09 N 460600.24 E 0.348 1679.20 3284.58 65.970 338.600 2261.79 2418.56 1708.16 N 459.67 W 5913701.00 N 460569.25 E 0.838 1766.65 3376.81 65.260 343.300 2299.86 2456.65 1767.53 N 487.09 W 5913780.51 N 460542.24 E 4.704 1850.61 3470.65 65.560 344.680 2338.93 2495.70 1869.55 N 510.62 W 5913862.64 N 460519.13 E 1.375 1935.88 3563.20 65.640 343.460 2377.17 2533.94 1950.59 N 533.75 W 5913943.81 N 460496.41 E 1.204 2020.11 3656.14 65.570 344.120 2415.55 2572.32 2031.87 N 557.38 W 5914025.20 N 460473.20 E 0.651 2104.71 3753.61 65.700 342.670 2455.77 2612.54 2116.95 N 582.75 W 5914110.42 N 460448.27 E 1.362 2193.47 3846.42 65.780 345.390 2493.91 2650.66 2198.29 N 606.03 W 5914191.87 N 460425.41 E 2.673 2278.03 3938.51 66.210 343.780 2531.37 2688.14 2279.39 N 628.39 W 5914273.08 N 460403.47 E 1.664 2362.06 -~, 4028.42 66.490 344.400 2567.44 2724.21 2358.59 N 650.97 W 5914352.40 N 460381.30 E 0.704 2444.37 4123.62 67.160 343.330 2604.90 2761.67 2442.66 N 675.29 W 5914436.59 N 460357.41 E 1.250 2531.84 4217.82 67.920 . 342.820 2640.89 2797.66 2525.94 N 700.63 W 5914520.00 N 460332.50 E 0.949 2618.88 4311.28 66.360 341.760 2677.20 2833.97 2607.98 N 726.83 W 5914602.17 N 460306.73 E 1.969 2704.99 4403.02 66.940 343.150 2713.56 2870.33 2688.28 N 752.21 W 5914682.61 N 460281.75 E 1.528 2789.21 4498.48 67.700 343.980 2750.37 2907.14 2772.76 N 777.13 W 5914767.22 N 460257.27 E 1.130 2877.26 4589.96 67.290 342.450 2785.39 2942.16 2853.67 N 801.53 W 5914848.25 N 460233.29 E 1.609 2961.75 4685.29 66.280 343.170 2822.96 2979.73 2937.37 N 827.43 W 5914932.08 N 460207.82 E 1.267 3049.35 Conffnusd... 4 March, 1999 - 9:20 -3- DrlllQuest . Sperry-Sun Drilling Services Survey Report for 2N-30B Your Ref: API-501032028800 Job No. AKMM90084, Surveyed: 23 February, 1999 Alaska State Plane Zone 4 Prudhoe Bay Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) (ft) '-'~<" 4779.57 66.560. 341.960 2860.68 3017.45 3019.80 N 853.32 W 5915014.65 N 460182.36 E 1.213 3135.75 4872.39 66.770 340.250 2897.45 3054.22 3100.43 N 880.92 W 5915095.42 N 460155.17 E 1.701 3220.97 4967.08 67.400 341.290 2934.32 3091.09 3182.78 N 909.64 W 5915177.91 N 460126.87 E 1.211 3308.16 5061.41 65.140 340.250 2972.28 3129.05 3264.31 N 938.07 W 5915259.59 N 460098.86 E 2.600 3394.49 5154.34 65.200 338.460 3011.30 3168.07 3343.23 N 967.81 W 5915338.66 N 460069.53 E 1.749 3478.73 5249.90 66.110 338.370 3050.70 3207.47 3424.19 N 999.84 W 5915419.78 N 460037.92 E 0.956 3565.62 5342.30 66.810 339.250 3087.60 3244.37 3503.17 N 1030.45 W 5915498.92 N 460007.71 E 1.156 3650.19 5437.68 65.290 337.090 3126.32 3283.09 3584.08 N 1062.86 W 5915580.00 N 459975.73 E 2.612 3737.16 5530.85 65.410 336.350 3165.18 3321.95 3661.87 N 1096.32 W 5915657.96 N 459942.66 E 0.733 3821.47 5627.55 66.130 335.980 3204.87 3361.64 3742.53 N 1131.96W 5915738.80 N 459907.44 E 0.822 3909.19 5720.26 66.850 335.380 3241.85 3398.62 3819.99 N 1166.97 W 5915816.45 N 459872.83 E 0.977 3993.68 5813.38 65.970 337.200 3279.12 3435.89 3898.12 N 1201.29 W 5915894.75 N 459838.92 E 2.025 4078.59 5909.30 65.230 336.580 3318.74 3475.51 3978.47N 1235.57 W 5915975.27 N 459805.05 E 0.970 4165.59 6000.61 65.930 336.670 3356.49 3513.26 4054.78 N 1268.56 W 5916051.75 N 459772.45 E 0.772 4248.36 6094.47 64.960 339.150 3395.50 3552.27 4133.88 N 1300.67 W 5916131.01 N 459740.75 E 2.616 4333.50 6188.03 65.240 339.480 3434.89 3591.66 4213.27 N 1330.64 W 5916210.56 N 459711.19 E 0.438 4418.27 6283.92 65.840 338.390 3474.60 3631.37 4294.72 N 1362.01 W 5916292.16 N 459680.23 E 1.209 4505.42 -~, 6376.56 64.940 339.350 3513.18 3669.95 .4373.28 N 1392.38 W 5916370.88 N 459650.28 E 1.353 4589.51 6469.32 65.340 341.210 3552.18 3708.95 4452.50 N 1420.77 W 5916450.25 N 459622.29 E 1.870 4673.63 6563.54 65.660 340.800. 3591.25 3748.02 4533.57 N 1448.68 W 5916531.46 N 459594.80 E 0.522 4759.36 6656.56 66.140 342.370 3629.23 3786.00 4614.13 N 1475.50 W 5916612.16 N 459568.40 E 1.625 4844.26 6751.49 66.340 340.720 3667.48 3824.25 4696.54 N 1503.00 W 5916694.71 N 459541.32 E 1.605 4931.14 6847.83 66.310 343.030 3706.17 3862.94 4780.39 N 1530.45 W 5916778.70 N 459514.30 E 2.196 5019.36 6941.06 66.490 342.130 3743.50 3900.27 4861.90 N 1556.03 W 5916860.34 N 459489.15 E 0.905 5104.79 7036.12 66.510 342.440 3781.40 3938.17 4944.94 N 1582.55 W 5916943.52 N . 459463.05 E 0.300 5191.96 ContInued... 4 March, 1999 - 9:20 -4- Or/llQuÐst Sperry-Sun Drilling Services Survey Report for 2N-30B . Your Ref: A PI-SO 1032028800 Job No. AKMM90084, Surveyed: 23 February, 1999 Alaska State Plane Zone 4 Prudhoe Bay Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) (ft) '-"-'-, 7129.48 66.560 341.670 3818.58 3975.35 5026.41 N 1608.94 W 5917025.12 N 459437.08 E 0.758 5277.60 7222.61 66.720 342.340 3855.51 4012.28 5107.73 N. 1635.35 W 5917106.57 N 459411.09 E 0.682 5363.10 7315.75 67.730 343.100 3891.56 4048.33 5189.73 N 1660.86 W 5917188.70 N 459386.01 E 1.320 5448.97 7408.66 66.160 342.650 3927.95 4084.72 5271.42 N 1686.03 W 5917270.53 N 459361.26 E 1.748 5534.45 7504.73 65.680 342.720 3967.14 4123.91 5355.16 N 1712.13 W 5917354.40 N 459335.59 E 0.504 5622.15 7602.94 66.480 341.560 4006.97 4163.74 5440.60 N 1739.67 W 5917439.98 N 459308.49 E 1.352 5711.92 7694.90 66.850 341.840 4043.39 4200.16 5520.77 N 1766.18 W 5917520.29 N - 459282.39 E 0.490 5796.36 7786.44 67.440 341.470 4078.95 4235.72 5600.84 N 1792.73 W 5917600.49 N 459256.25 E 0.744 5880.71 7882.88 66.100 341.750 4116.98 4273.75 5684.93 N 1820.69 W 5917684.72 N 459228.73 E 1.415 5969.33 7978.43 65.460 342.710 4156.18 4312.95 5767.91 N 1847.28 W 5917767.84 N 459202.56 E 1.135 6056.46 8068.54 65.840 342.560 4193.34 4350.11 5846.26 N 1871.78 W 5917846.32 N 459178.46 E 0.448 6138.55 8162.12 66.790 342.940 4230.93 4387.70 5928.10 N 1897.20 W 5917928.29 N 459153.47 E 1.081 6224.24 8257.52 66.240 341.560 4268.95 4425.72 6011.43 N 1923.87 W 5918011.75 N 459127.23 E 1.447 6311.74 8351.48 66.030 342.850 4306.96 4463.73 6093.25 N 1950.13 W 5918093.70 N 459101.39 E 1.275 6397.66 8445.20 66.610 341.780 4344.60 4501.37 6175.02 N 1976.20 W 5918175.60 N 459075.74 E 1.215 6483.49 8540.95 67.070 341.260 4382.26 4539.03 6258.51 N 2004.11 W 5918259.24 N 459048.27 E 0.693 6571.51 8633.85 65.890 340.150 4419.34 4576.11 6338.91 N 2032.25 W 5918339.78 N 459020.54 E 1.677 6656.67 .-.~~-- 8726.20 66.550 -341.360 4456.57 4613.34 6418.69 N 2060.10 W 5918419.71 N 458993.10 E 1.396 6741.16 8821.62 65.580 340.040 4495.29 4652.06 6501.00 N 2088.92 W 5918502.17 N 458964.70 E 1.622 6828.34 8916.37 64.940 340.610 4534.94 4691.71 6582.03 N 2117.90 W 5918583.34 N 458936.14 E 0.869 6914.36 9009.98 63.260 338.980 4575.83 4732.60 6661.05 N 2146.97 W 5918662.51 N 458907.48 E 2.382 6998.50 9103.92 63.210 338.620 4618.13 4774.90 6739.25 N 2177.30 W 5918740.87 N 458877.55 E 0.346 7082.24 9196.78 61.360 340.390 4661.32 4818.09 6816.24 N 2206.09 W 5918818.01 N 458849.16 E 2.611 7164.36 9293.76 58.720 340.710 4709.75 4866.52 6895.46 N 2234.07 W 5918897.37 N 458821.59 E 2.737 7248.34 9387.46 56.830 340.010 4759.71 4916.48 6970.11 N 2260.70 W 5918972.16 N 458795.34 E 2.114 7327.57 . ContInued.. . 4 March, 1999 - 9:20 -5- DrlllQu8st . . Sperry-Sun Drilling Services Survey Report for 2N-30B Your Ref: A PI-SO 1 032028800 Job No. AKMM90084, Surveyed: 23 February, 1999 Alaska State Plane Zone 4 Prudhoe Bay Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) (ft) ~"" 9478.51 55.200 340.440 4810.61 4967.38 7041.16 N 2286.25 W 5919043.33 N 458770.16 E 1.833 7403.03 9575.13 55.480 339.830 4865.55 5022.32 7115.90 N 2313.25 W 5919118.21 N 458743.54 E 0.595 7482.46 9670.51 56.100 337.820 4919.18 5075.95 7189.44 N 2341.75 W 5919191.90 N 458715.42 E 1.860 7561 .20 9764.36 56.930 339.290 4970.96 5127.73 7262.30 N 2370.36 W 5919264.90 N 458687.19 E 1.578 7639.33 9859.18 55.650 339.870 5023.59 5180.36 7336.21 N 2397.88 W 5919338.96 N 458660.05 E 1.443 7718.13 9953.58 54.860 339.610 5077.39 5234.16 7408.98 N 2424.74 W 5919411.86 N 458633.56 E 0.867 7795.64 10043.74 55.800 338.950 5128.67 5285.44 7478.33 N 2450.98W 5919481.35 N 458607.68 E 1.204 7869.70 10137.77 56.530 339.980 5181.03 5337.80 7551.48 N 2478.37 W 5919554.63 N 458580.67 E 1.196 7947.73 10231.05 56.930 339.650 5232.20 5388.97 7624.68 N 2505.28 W 5919627.97 N 458554.13 E 0.521 8025.66 10327.12 57.130 338.610 5284.49 5441.26 7699.98 N 2534.00 W 5919703.42 N 458525.81 E 0.932 8106.15 10420.66 57.110 340.490 5335.27 5492.04 7773.58 N 2561.44 W 5919777.16 N 458498.74 E 1.688 8184.63 10440.22 57.160 339.990 5345.88 5502.65 7789.05 N 2567.00 W 5919792.65 N 458493.27 E 2.162 8201.05 10520.00 57.160 339.990 5389.15 5545.92 7852.03 N 2589.93 W 5919855.76 N 458470.65 E 0.000 8268.04 PROJECTED SURVEY All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. ~, Magnetic Declination at Surface is 26.695° (23-Feb-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 342.030° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10520.000., The Bottom Hole Displacement is 8268.14ft., in theOirection of 341.745° (True). Continued.. . 4 March, 1999 - 9:20 -6- DrlllQuÐst ~ . Sperry-Sun Drilling Services , Survey Report for 2N-30B Your Ref: A PI-SO 1 032028800 Job No. AKMM90084, Surveyed: 23 February, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2N Comments Measured Depth (ft) 10520.00 ~.. Station Coordinates TvD Northings Eastings (ft) (ft) (ft) Comment 5545.92 7852.03 N 2589.93 W PROJECTED SURVEY ,.-.Ä, 4 March, 1999 - 9:20 .7- DrlllQuest ( l i( ~~ ~~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 2761215 February 12, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Dri ve Anchorage, Alaska 99501 Subject: 2N-308 Application for Sundry Dear Mr. Commissioner: , Please find enclosed an application for sundry to change the well name from the previously well name of 2N-309 to 2N-308. ' If there are any questions, please call 263-4603. Sincerely, ~~rr¡~ I' .." '" P. Mazzolini Tarn Drilling Team Leader ," , ,v ' ,,' (,:." ': ,,' PM! skad (' STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program - 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 16' FNL, 573' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 2070' FSL, 2317' FWL, Sec. 27, T10N, R7E, UM At effective depth At total depth 2507' FSL, 2171' FWL, Sec. 27, T10N, R7E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Production Length 84' 3025' 9465' Size 16" 7-5/8" 5.5" x 3.5" Liner Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth NIA Packers & SSSV (type & measured depth) N/A Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service - 10412 feet 5511 feet 10412 feet 5511 feet Plugs (measured) Junk (measured) Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (OF or KB feet) RKB 34 feet 7. Unit or Property name ~'~ (NQ..\~ Other - Cemented 9 cu yds High Early 430 Sx AS III & 240 Sx Class G 360 Sx Class G ORIG'NAl Kuparuk River Unit 8. Well number 2N-308 9. Permit number I approval number 99-1 0 10. API number 50-103-20288 11. Field I Pool Kuparuk River FieldlTarn Oil Pool Measured Depth 118' 3059' 9499' 1 0412' True vertical Depth 118' 2300' 4988' 5511' p ,,~:' s ",. f,:. ".' }!)'. f.~, ' '. .11 .\J~~,;;,:.i'C:i' .:', "..:" i~",,",,~, ,!,;-""',).. "¡"N('¡"'.', , "'-'",ll"r,II"'-" 'i'd,j'e ".':"':I':;'.1:;)n BOP sketch _X to 13. Attachments Description summary, of proposal- 14. Estimated date for commencing operation February 16, 1999 16. If proposal was verbally approved Oil_X Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity- BOP Test - Location clearance - Mechanical Integrity Test - fJ A ORIGINAL SIGNED, BY Robert N. Christenson Approved by order of the Commìsšlon Signed ~ fY1~~.-L.~~ . Paul Mazzolini ........ 0 U' -- Form 10-403 Rev 06/15/88 . Title: Tarn Drilling Team Leader 08 Gas- Suspended - Questions? Call Paul Mazzolini 263-4603 Date Z//I/qc, Prepared by Sharon Allsup-Drake Commissioner Date SUBMIT IN, TRI PLICATE . ~ OA TE I BY I tK I APP I SCRIPnON 1 2/11/99 BGIJ DCS Per KS~. '}90OBACS NO rES: 1. COORDINA 1£5 SHOWN ARE A.S.P. ZONE 4, N.A.D. 2Z ELEVATIONS SHO'MJ ARE BRITISH' PE TROLEUM MEAN SE:A LEVEL DA ruM. ALL DISTANCES ARE TRUE. 2. BASIS OF LDCA TlON AND ELEVA TlON ARE DRILL Sl1£ MONUU£NTATION PER LOUNSBURY ct ASSOCIA 1£5. 3. CONDUCTOR IS LDCA TED WITHIN PRQTRACTED SECTION 3, TO'MJSHIP 9 NORTH, RANGE 7 EAST, UMIA T AlERIDIAN, ALASKA. 4. DA Té OF SURVEY: 2/09/1999. REF: FIELD BOOK L99- 2, PC: 54. S. DRILL SlT£ 2-N GRID NORTH 15 ROTA TED 1.3' ~ST FROM A.S.P. GRID NORTH. 6. REF: CEA-D2NX-6214D9 FOR AS-BUlL T LOC'N. OF M£LLS 31.3. 321, 323, J2S AND 329. REF: C£A-D2NX-6214D10 FOR AS-BUlL T LOCN. OF M£LLS 337. 339. 341 AND 34J. REF: CEA-D2NX-6214D14 FOR AS-BUlL T Loe'N. OF M£LLS 315. 317. 319. 3.11 AND .145. REF: CEA-D2NX-6214D20 FOR AS-BUlL T LDC'N. OF M£LLS 3.3~ .135 AND .147. REF: CEA-D2NX-6214D22 FOR AS-BUlL T LOCN. OF K£LLS 3DJ. 307, 309, 320 AND 3.34. REF: CEA-D2NX-6214D24 FOR' AS-BUlL T LOeN. OF K£LL 349. R V DATE BY ( APP (' SCRI P lION <) ., ., ., ,... Conductor is Located in: Sec. 3, T. 9 N.. R. 7 £ SURVEYOR'S CERTIFICATE I HEREBY CER TIFY THA T I AM PROPERL Y REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STA TE OF ALASKA AND THA T THIS PLA T REPRESEN TS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF, F ebruory 10. 1999. IttrII No. .Y' A.5.P.s 'X' LA 11 TUDE: . 0308 461.020.11 70' 10' 13.800. 5,911,990.49 ."'~~'-." ' ~~ t CF LlJ -" ..~~:\ ..........:.~, ~~ . .-' '..""" -C;J .e. '..""" . ~ ~~ ~ . ~ ~ , ¡ ~:~l 49th \.~ J} ~ "'- ... e........................... .......'to.... . . ..:....'.~... ...... .......'" , ~ \,' BRIAN , G.. MANGOL ~¡ : Yl6.""'. : - '!"... ~ -'. LS- 8626 ... . '!"t ~'. L 1 ,." . ".~ ......~ !! .?.....~~ .' "~F"E:SSION~\. \. ~.. ,..."",~ ' tONG/TUDE: 150. 18' 49.378" LOUNSBURY &, ASSOCIATES, INC. ENGINEERS PLANNERS SURVEYORS , AREA: 2N ARca Alaska, Inc. ~> CADD FILE NO. I LK621426 UOOULE: XXXX DS2N WELL CONDUCTOR' 308 AS-BUILT LOCA 1100 CEA-D2NX-6214D26 , I SHEET:2 ~F 21 REV: 1 2/11/99 I DRAWING NO: UNIT:, 02 APP CRIPTION p~ (~~f 190OBA CS REV DA BY CI< APP ( '. PT\~ 1 2/11/99 8CM DCS LEGEND t3 . PROPOSED CON Due TOR L OCA TlON . AS-BUlL T CONDUCTOR LDCA TlON . EXISTING CONDUCTOR LDCA TlON Conductor is Located in: Sec. 3, T. 9 N., R. 7 £ ~ 't~ ~ - ~ - ... ~ '4 \1 ~ -.. ~....:".""'1- 'to ~ '4 '4 \. \It ..... ~ ~ ô 0 ...... \1&... -.. ... ~ ~ ':S .. N CD ~ ~ v. ;......~ ~ 'ð . G' " ~ t. ~ Wa::,....~ ~ 'i \ .. . '& ~.r:....~....... 't¿ ~ ~ N ... " ï. 't Q ti T£ 2 ' \ '& , DR ILL SI T '° If T81f .34 .J5 oJ 2 N Hof Ie ..... CONDUCTOR STAKED: I JOB SE£ PAGE 2 OF 2 FOR NOTES AND tDCA T1ON5. LOUNSBURY & ASSOCIATES, INC. ENGINBERS PLANNERS SURVEYORS , AREA: 2N UNIT: 02 CADD FILE NO. LK621426 DRAWING NO: MODULE: XXXX DS2N WELL CONDUCTOR' 308 AS-BUILT LOCATION CEA-D2NX-6'214D26 SHEET: 1 OF 2 REV: , 1 ARCOA'aska, Inc. <> 2 1199 . _. - ---... '~ 'I. .- -- . -- , -.- .. -. - ~ -, \ ,í .' \ - -.-- - . - - - - ' TONY KNOWLES. GOVERNOR ._- . ~ ALAS IiA. 0 IL A5D GAS CONSERVATION COMMISSION February 5, 1999 Paul Mazzonlini Tam Drilling Team Leader ARCO Alaska, Inc. POBox 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Kuparuk River Unit 2N-309 ARCa Alaska, Inc. Permit No: 99-10 Sur Loc: 19'FNL, 588'FEL, Sec. 3, T9N, R7E, UM Btmhole Loc. 2507'FSL, 2171'FWL, Sec. 27, TION, R7E, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface cas,ing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2N must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. 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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P. E. Chairman BY ORDER OF THE COMMISSION dlflEnclosures cc: Department ofFish & Game, I Iabitat Section w/o encl. Department of Environmental Conservation \Vlo encl. ARGO Alaska, Inc. (" Post Office Box 100360 Anchorage, Alaska 99510-0360 f ~~ ~~ January 25, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 RECEIVED Re: Application for Permit to Drill KRU 2N-309 Surface Location: 19' FNL 588' FEL See 3 T9N R7E, UM Target Location: 2070' FSL, 2317' FWL Sec. 27, T10N, R7E, UM Bottom Hole Location: 2507' FSL, 2171' FWL Sec. 27, T10N, R7E, UM ,JAN !2C 1999 Alaska Oil & Gas Cons. Commission Anchorage Dear Commissioner Christenson, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-309, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Pool #6 will drill the well. If commercial, the well will also completed with Pool #6. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be preferentially ground at the on-site ball mill and injected down an approved, existing well annulus on 2N pad or stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany Robert Christen( ,I Application for Permit to Drill Page 2 ( KRU 2N-309 If you have questions or require additional information, please contact Bill Lloyd at 265-6531 or me at 263-4603 in our Anchorage office. Sincerely 7~Yfl~ Paul Mazzolini Drilling Team leader Exploration / Tarn Development Group Attachments cc: KRU 2N-309 Well File 1a. Type of Work Drill X Redrill 1b Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 34', Pad 120' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, AnchoraQe, AK 99510-0360 ADL 380054, ALK 4602 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 19'FNL, 588'FEL, Sec. 3,T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2070' FSL, 2317' FWL, Sec. 27, T10N, R7E, UM 2N-309 #U-63061 0 At total depth 9. Approximate spud date Amount 2507' FSL, 2171' FWL, Sec. 27, T10N, R7E, UM 2/6/99 $200,000 12, Distance to nearest 13. Distance to nearest well 14, Number of acres in property 15. Proposed depth (MD and TV D) property line 2N-313 10412' MD 2070' @ Tarqet feet 59.9' @ 100' feet 2560 5511' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25,035(e)(2» Kickoff depth 300' feet Maximum hole angle 65.59° Maximum surface 1357 psig At total depth (TVD) 2300 psig 18. Casing program Setting Depth size Scecifications Top Bottom Quantity of cement Hole Casino Weiaht Grade Couclina Lenath MD TVD MD TVD (include staae data) 24" 16" 62.5# H-40 Weld 84' 34' 34' 118' 118' :t200 C F 9.875" 7.625" 29.7# L-80 BTC 3025' 34' 34' 3059' 2300' 430 Sx Arcticset III & 240 Sx Class G 6.75" 5.5" 15.5# L-80 L TC-M 9465' 34' 34' 9499' 4988' 360 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 913' 9499' 4988' 10412' 5511' (included above) 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 RECE~VED Conductor Surface Intermediate Production ORIGINAL ~iAN 2 G 1999 Liner Perforation depth: measured true vertical Alaska Oil 8t Gas COilS. Commission " ,. 20. Attachments Filing fee X Property plat D BOP Sketch X Diverter Sketch X "'E>frlllll\: J.l'Pugram X Drilling fluid program X Time vs depth plot D Refraction analysis 0 Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ?n.~. p yYJ Q/7/l ~~---'~ Title Tarn Drillina Team Leader Date 1/21. Iqc¡ t 0 /J Commission Use Only permi~q.b:; /6 I API /;j'e~ ~?? I Approval dat:.~_.6 - ? c¡ See cover letter for 50- - ..2.. 0.2 other reQuirements Conditions of approval Samples required D Yes ~ No Mud log required D Yes m No Hydrogen sulfide measures 0 Yes ~ No Directional survey required S Yes D No Required working pressure for BOPE 0 2M D@)D 5M D 10M D 15M Other: ORIGINAL SiGNED' BY by order of Date d-. - 6-- 77' Accroved bv Robert N. Christenson Commissioner the commission Form 10-401 Rev. 7-24-89 ( STATE OF ALASKA ( ALA;:,t\A OIL AND GAS CONSERVATION COMrvll..:SION PERMIT TO DRILL 20 AAC 25.005 Submit in triplicate 21 %" 2,000 psi WP DRILLING SPOOL wI 16" Outlet { ARca Alaska, Inc. Diverter Schematic Pool #6 ,i" , L Flowline þ 21 %" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ,~, ARca Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS :l 13-5/811 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER wI companion flange to bell nipple 3" 5,000 psi WP OCT MANUAL GATE VALVE KILL LINE CHOKE LINE ~ . 3"5,000psiWPOCT ~ MANUAL GATE VALVE 13-5/811 5,000 psi WP DRILLING SPOOL wI two 311 5M psi WP outlets 3" 5,000 psi WP Shaffer GATE VALVE wI hydraulic actuator DOUBLE 13-5/811 5,000 psi WP, HYDRIL Magnum BOP wI pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE w hydraulic actuator I DSA 13-5/8" 5,000 psi WP ~ X 11" 3,000 psi WP I~ SINGLE 13-5/811 5,000 psi WP, HYDRIL MPL BOP wI pipe rams I ' . .( ARC a Alaska, Inc. (: GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 309 1. Move in and rig up Pool #6. 2. Install diverter system. 3. Drill 9.87511 hole to 7-5/811 surface casing point according to directional plan. 4. Run and cement 7-5/811 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/8" casing +1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. 6. Drill out cement and 20. of new hole. Perform formation integrity test not to exceed 1~W. This establishes a maximum allowed drilling mud weight below ttle casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6-3/411 hole to TO according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 8. Run and cement 5-1/2" L-80 LTC Csg X 3-1/211 L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/211 L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. Set TWC, ND BOPE and install production tree. ( ~. ARCa Alaska, Inc. 12. Secure well. Rig down and move out. 13. Hydrocarbon intervals will be tested after the rig move. (: ARCa Alaska, Inc. ( DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 309 Drillin~ Fluid Properties: Density PV yp Funnel Vis Initial Gel 10 Minute Gel API Filtrate pH % Solids DrillinQ Fluid System: Spud to surface casin oint 9.5-10.2 ppg 16-26 25-35 50-120* 1 0-20 15-40 7-15 9.5-1 0 + 1 0% Tri Ie Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifu e De asser Drill out to TD 9.1 -10.0 ppg 6-20 5-20 35-50 2-6 4-8 <6 through Tarn 9.0-1 0 <11 % Pit Level Indicator Visual and Audio Alarm Tri Tank Fluid Flow Sensor Fluid A itators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(O.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. {" , ARca Alaska, Inc. ( Well Proximity Risks: The nearest well to 2N-309 is 2N-313. The wells are 59.9' from each other at a depth of 1 00' . Drillin~ Area Risks: The primary risk in the 2N-309 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.5 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.5-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/811 casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pum~erations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.), The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N..309 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2N-309 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous 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 barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi l ARCa Alaska, Inc. ( This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85 % of CD I (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ,......... 1600 ...- Q) Q) "t- '-' 2000 ..c: ...- a. Q) 2400 C 0 2600 0 0- "t: Q) > 3200 Q) :J .... 3600 l- I V 4000 400 BOO 1200 4400 4BOO 5200 5500 ARC a Alaska, Inc. CrllVlwd IIy rLcn FOR: u.oYD Dol. Ivlln : 22-.1on-n Plot "-'-- 18 D ¥8r8Ion " . c-d1nøIw II,. 'n 'wt "'- IIøt '!OIl. Trw Vwtlcal Dept/18 - rwf-C8 RICØ (Pool 18). arE IImQ Structure: Tam Drill SIte 2N Well: 309 FIeld: Tam Development FIeld LoGaffon : North Slope, Alaska 0 RKB ELEVATION: 154' KOP - 0.00 Inè, 300.00 Md, 300.00 Tvd, 0.00 VS 3.00 Begin Turn to Target - 6.00 Inc, 500.00 Md, 499.63 Tvd. 8.26 Va 8.51 11.26 14.11 17.01 1~~~ Port Collar - 20.38 Inc. 1014.86 Md. 1000.00 Tvd, 118.92 Vs 25.85 Base of Permafrost - 26.97 Inc, 1237.72 Md, 1204.00 Tvd, 207.76 Vs 2!,.~19 Top of West Sok Sands - 28.45 Inc. 1287.42 Md, 1248.00 Tvd, 230.77 Va 34.77 40.73 46.70 52.68 58.66 Bose of West Sak Sands - 60.58 Inc, 2364.09 Md, 2006.00 Tvd, 974.98 Vs 64.64 EOC - 65.59 Inc. 2531.64 Md, 2061.63 Tvd. 1124.32 Vs 7 5/6 Casing Pt. - 65.59 Inc, 3059.49 Md. 2300.00 Tvd. 1604.95 Vs ceo - 65.59 Inc, 3494.99 Md, 2480.00 Tvd, 2001.48 Vs Camp Sat - 65.59 Inc, 3615.96 Md, 2530.00 Tvd, 2111.63 Va DLS: 3.00 deg per 100 ft 342.14 AZIMUTH 7743' (TO TARGET) ~~-- ***Plane of Proposal*.* MAXIMUM AN G LE 65.59 DEG ~-,- C50 - 65.59 Inc. 6642.66 Md, 3781.00 Tvd, 4867.56 Va C40 - 65.59 Inc, 7216.06 Md, 4018.00 Tvd, 5389.66 Vs TARGET ANGLE 55 DEG Begin Angle Drop - 65.59 Inc, 9164.78 Md, 4823.45 Tvd, 7164.04 Va ............. 64.54 End of Angle Drop - 55.00 Inc, 9518.17 Md, 4998.28 Tvd. 7470.55 Va u ."",58.54 T3.1 - 55.00 Inc, 9671.1 0 M~l 5086.00 Tvd, 7595.82 Va T3 - 55.00 Inc, 9718.17 Md, 5113.00 Tvd. 7634.38 Va TARGET - MID BERMUDA - 55.00 Inc. 9850.68 Md, 5189.00 Tvd, 7742.9 V8 T2 - Bose of Bermuda - 55.00 Inc. 9976.20 Md. 5261.00 Tvd, 1845.74 Va C35 - 55.00 Inc, 10112.19 Md, 5339.00 Tvd, 7957.12 Vs ~ TD - Casing Pt - 55.00 Inc. 10412.19 Md. 5511.07 TVD, 8202.85 VI v 0 400 600 1200 1600 2000 2400 2800 3200 3600 4000 8400 4400 4800 5200 5600 6000 6400 5800 7200 7600 8000 Vertical Section (feet) -> Azimuth 342.14 wrth reference 0.00 N, 0.00 E from slot #309 o-t8d.., ñ- FOR: LLOYD Dc* pIott8cI : 22-Jart-18 Plot ~ .. JCII YwwIoIt 15 . CaaodInol88 0" In r.t ...-..c. IIat IX». r",. VwticaI DIph - rer- AIC8 (PvoI II). ..a: IHftQ TO LOCATION: 2507' FSL. 2171' FWL SEC. 27, nON, R7E , "~ ~ ReO Alaska, Irl_. . Structure: Tarn Drill SIte 2N Well: 309 Field: Tam Development Reid location: North Slope, Alaska <- 2800 1600 1200 2400 2000 800 400 0 '"'\ ~ TO - Casing Pt.. - 5511.07 TYd, 7805.97 N. 2520.63 W C.35 - 5.3.39.00 Tvd, 7572.86 N, 2#2.86 W - Baae of Bermuda - 5261.00 TYd, 7467.19 N, 2407.61 W TARGET - 5189.00 TYd, 7389.65 N, 2375.07 1f T3 - 511.3.00 TYd, 7266.69 N, 2.340.72 W T.3.1 - 5086.00 Tyd, 72.30.11 N, 2328.51 W End of Angle Drop - 4998.28 TYd. 7111.28 N. 2288.87 W TARGET LOCATION: 2070' FSl, 2317' FWL SEC. 27, nON, R7E T\ID::z 5189 TMD = 9851 DEP = 771,..3 NORTH 7.370 WEST 2375 Begin Angle Drop - 4-823.45 TYd. 6820.51 N, 2191.85 W C4O - 4Ota.oo fwd, 5tJ7.28 N, 18JO.22 W 342.14 AZIMUTH 7743' (TO TARGET) ...Plane of Proposal... Camp Sst - 2530.00 Tyd. 2027.58 N, 592.65 W C80 - 2480.00 TYd, 1923.09 N, 557.79 W 7 5/8 Casing Pt. - 2.300.00 TYd, 1546.92 N, 4.32.28 W '" ~ EOC - 2081.83 TYd, 1090.98 N, 280.15 W Base of West Sok Sands - 2006.00 TYd, 949.14 N, 233.40 W Top af West Sak Sands - 1248.00 Tyd, 2.34.40 N, 25.00 W Bose of Permafrost - 1204.00 Tyd, 211.87 N, 19.89 Begin Turn to Target - 499.63 Tyd, 9.83 N, 3.58 E SURFACE LOCATION: 19' FNL, 588' FEL SEC. 3, T9N, R1E 400 8000 7600 7200 6800 6400 6000 5600 5200 4800 ^ 4400 I z .4000 0 ::J,. ::T ......... 3600 ~ CD CD - '-"" .:5200 2800 2400 2000 1600 1200 BOO 4-00 0 4-00 ~~ ~~ Cr8a*lIlr... FOR: LLOYD DcII8 piottIecI : 22-.I0Il-" Plot .w- . 3011 \/wwIon f5 . c:-d"onaIa - in ,. '"'- .. IJ08. TN8I Yerticlal 08IItt8 0" .......... RIC8 (PaoI Ie), .. .... IN'nQ 240 220 200 180 160 ^ I 140 '"'" +- Q) Q) 120 ~ '-" ..c: +- .... 100 0 Z eo ~ ~ ~ \ \ I I \ \ , , \ \ I , \ \ 1300 I I \ , , , , 1600 \ I r 1500 ~ \ \ I J \ \ , \ \ \ . 1200 ' \ \ \ , ' \ 1500 \ \ I : \ \ I \ \ , 1200 I \ ~ 1500 \ I l1400 \ I \ \ \ I I \ I \ \ \ I I \ \ \ I \ \ \ r 1100 I " 1400 \ \ 1100 I ' \ 1 , \ \ 1400 I + 1300 \ \ \ , , \ \ \ , , \" " I I \ " , 1300 \ \ + 1000 \ \ 1300 \ I : 1200 \ \, I \ \ \ , \ \, , \ I, \ 1200 \ \ 900 I I \ ~ 1200 ~ ~ 900 , 1100 \ \ \ \ \ I / \ \ \ I / ~ \1100 \ ,BOO I /1000 / \ \ 1100 , ' 800' ...600 \ \ I' I ,. \ \ I I ,." 1200 \ 1000 \ L 700 I J 900 120~,. /0'" \ It 1000 I '700 I ,. 1100..... /10gsJ 3C):!t \ \ I' /800 11 00.. 1"000 "'.f40t1Õ_B- :1 \ '600'- 1000 '" ~~ -- -- 900 \ I 7 /' ~;;~- 500 20 , , 900 I 500 ¿600 ,. 00 90q,... ... ,.. ~ 900"" BOO 500 JO I \ \ , , @500 ~08"'500 500 ,,800 ,800 é ë5OO \ 700 8500 -$- 8500 140 120 300 280 260 1" ~ ARC a Alaska, ( Inc. Structure: Torn Drill SIte 2N Well: 309 Field: Tom Development Field Location: North Slope. Alaska <- West (feet) : East (feet) -> 100 100 120 0 20 40 80 60 40 20 60 80 60 40 20 0 20 e -$- 40 60 140 120 100 120 20 0 BO 100 80 60 40 20 40 60 <- West (feet) : East (feet) -> ~~ ~~ 140 JOO 280 260 240 220 200 180 160 ^ 140 I Z 0 -, 120 5= ,....... ~ 100 CD CD - ......... 80 60 40 0 20 40 6<1 140 ---( ( ARC a Alaska, Inc. ~~ Cnla8d !lor "- PO R: LLO YD DcrI8 pIottId : 12-.1an-ø Structure: Tarn Drill SIte 2N Well: 309 Plot "-'-- 18 301 v..ïon Ið. ~~ c.... £ ...11- ... in fwt ~ 8Iat I3Þ8. Field: Tarn Development Field Location: North Slope, Alaska r".. ¥IIrtIco1 D8ph - ..-- RIC8 (PoaI.-J. .. ..... IN'nQ <- West (feet) 400 J60 0320 280 2<C.O 200 160 120 80 40 0 <C.O BO 120 160 920 920 t!; .... \ ~ 1 BOO L 2200 BBO \ 880 \ I \ \ I ~ \ \ I 840 \ B4O \ I ~ \ ;.I" \ \ I ~ 2200 \ \ I 800 BOO \ \ ~ 1900 \ I \ \ \ \ ~ 2100 \ \ \ 760 ~~2200 \ ~ 1700 760 I \ \ I \ \ \ 720 \ \ \ I 720 \ 2100 \ \ I \\ \ \ I 680 \\ \ \ I 680 \\ , 1800 \ I \\ \ \ ~ 2000 640 \ 'It 2100 \ \ I 640 \ \ \ \ I ^ \ \ \ ~ 1600 I ^ , \ \ , 600 ~ 2Q00 \ \ I 600 ........... \ \ I Z -+- \ \ CD \ \ \ \ I 0 CD ~ 1700 ..., 560 \ \ \ I 560 - -- ':J .......... \ \2000 \ \ T 1900 ..t: \ \ I ........... \ \ -tot t: 520 \ \ \ \ I 520 CD 0 \ CD z \. 19&0 \ , -+- \ ~ \ \ \ \ 1500 I 480 \ \ ~ 1600 I 480 \ "'900 , \ l1800 \ I 440 \ \ \ \ I 440 \ \ \ \ , \ 1sob \ , \ \ \ I 400 \ \ . 1500 , , 400 \ \ 1800 \ + 1400 ~ 1700 \ \ \ I I 360 \ \ \ I , .360 \ 1700\ , \ , ,\ \ 1400 I , 3Z0 \ \ 1700 \ I J 1600 .320 \ \ ~ 1300 , \ \ \ \ \ I , " 1600 \ \ I , zao \ \ 1600 ~ 1300 I : 1500 \ \ \ I 240 \ \ \ 11200 ' 240 200 200 400 0360 0320 280 240 200 160 120 80 40 0 40 BO 120 160 <- West (feet) -( ARCa Alaska, f Inc. Cr8oI8d br"'" FOR: UOYD DcII8 pIottId : 22-.I0Il-11 Plot w...- . - ~ 115 . CoonIInat88 - ... r.t ..--- 8IIIt 1308. TI\I8 \I8rtIcg DIpttI8 - ~ RIC8 cP-I 18). .r£ IN'IIQ Structure: Tarn Drill Site 2N Well: 309 Field: Tarn Development Field Location: North Slope. Alaska <- West (feet) 2200 2000 1000 a 1800 800 1600 1400 1200 600 .00 200 4200 4000 ~ ~.~ W 3500 \ , \ I \ m \ \ t~ \~oo ~ \ L~oo I 3700 \ 5100 \ \ I \ \ \ \ ,\ \ 1 4700 \ 4700 \ \ 3.300 \ I , . , 4900 \ \ .3700 I .3SOO \ \ \ I 4500 ,\ \ T ~ 4500 " 4700 \ \ I ,\ \\ I '\ \ ~3500 .4300 3.:n10 4300 \ 4500 , .31 00 \ I '\ \ \ I \ \ \ \ \ \ ~ 3.300 14100 \ 4100 ~ 4300 \ 31\10 \ \ \ I \ \ \ \ I \ \ 4100 \. 2900 \ f 3900 \ 3900 \ \ \ 3100 I \ \ , 29'00 \ \ \ I , , 3900 \ \ 1 3700 \ 3700 \ \ \ I \ \ \ , 2900 ~ " 3700 It 2700 \ I .3500 2ruO T , 350~ \ \ \ \ \ \ I , \,3500 \ ~ 2700 I , \ \ + 3300 5OQ 330~ \ \ I \ \ \ 3300 \ 2500 \ I \ \ \ ~ 2500 1 3100 \ \ I , .31ðo \ 2~ \ 3100 \ \ : , \ \ " T 2900 '29~0 \ ~ 2300 I \ ,2900 \ \ t 21'()0 \ \ \ ¡ 2700 \ 2'(00 \ \ I \, ,,2700 \ ~ 2100 I \ \ I , ~ \ \ r 2500 19bo \ \ \ \.2500 '2100 \ I , x500 , \ \ ~ 1900 I 2300 ~ \ \ t ~ ~3B8 \ \ I ~ \ \ I \ \ 190q ! 2100 ~ .3800 .3600 3200 .3000 2800 ^ I 2600 ........... +- CD ~ 2400 '-' .!: +- ~ 2200 0 Z 1800 1600 1200 1000 800 600 2200 1600 200 1200 1000 800 600 0 200 1 BOO 1400 400 2000 <- West (feet) ~~ ~~ 200 400 600 .4200 4000 .3800 .3 600 3400 3200 3000 2800 ^ 2600 I Z 0 .., 2400 -+ ;j' ........... ~ 2200 CD CD -+ ........ 2000 1800 1500 1400 1200 2500 IfJ I I 1000 BOO ~ 600 400 600 CrIa'-d lip ~ FOR: LLOYD DøI8 pIoIt8d : 22-.1at1-1t Plot w..- . JOt Y8nian Ið . eo. dIo..AI.- - .. fMt ~ 8Iat I3G8. T 11\18 YwtIo:aI D8ptII8 - rwr-- AIC8 (F'aaI ~ .. lflii. IN'nQ 4500 8700 4200 .3900 8400 8100 7800 7500 7200 6900 6600 ^ I 6J00 ~ - CD ~ 6000 '-" ..r:; - .... 0 Z 5700 5400 5100 4800 4500 4-200 J600 .3.300 4500 4200 .3900 rl ARC a ( Inc. Alaska, Structure: Torn Drlll Site 2N Well: 309 Field: Tarn Development Field Location: North Slope. Alaska <- West (feet) .3600 2700 1500 1200 2400 .3.300 .3000 2100 1800 ~ 5500 \ \ 5300 \ \ 5100 \ \ 4900 \ \ \ 4700 \ \ \ ~ 4500 \ \ \ \4300 \ \ \ \ ~ 4100 \ \ \ \. 3900 \ \ \ \ 3700 3500 \ 3300 2900 \ 100 ~ 3500 \ \ \ " 3300 \ 900 600 ~ ,5100 \ ~ 4900 \ \ 4700 \ \ 4500 \ ~ 4300 \ \ ~ 4100 \ \ ; 3900 \ \ , 3700 4300 310 II 5500 , 4,"00 , 5300 , \L51 0O 3!roO , rEfl ... 4900 \ 510° 3100 3v~0 , ,470° \ 4900 ~oo \ .3600 2400 1800 2100 1500 1200 .3.300 .3000 2700 <- West (feet) 900 600 ~~ ~r .300 0 8700 8400 8100 7800 7500 7200 6900 6600 6300 ^ I Z 0 ., - :J 6000 ,-." ...., 5700 CD CD - '-" 5400 5100 4800 4500 4200 .3900 .3600 .300 .3.300 0 CnIoI8d b1 "'- DoI8 pIottIId : 22-Jarl-" PIøt ""-- .. 308 VwwIon Ie . ~.. - in '- ...r-. .. h1J8. "- Vw1lc:oI 08pöw - .-.- AK8 (Pool 18). ,¡: orno Æ~<CO Alaska, Í.dC. ~~ ~~ Structure: Tarn Drfll Site 2N Well: 309 FIeld: Tarn Deyelopment F1eld Locatron : North Slope. Alaska ---- WELL PROFILE DATA ---- ---- ....... ----- ID n... CIJICI !ClIP 3OOJII ..... 1\Irft ID TOftJIIt -.all 2UI.I' DIll ", NoIé IIIIL2I ÐIII ", ØIwp/IIonI lOlL" Ioc lit MI NoriIo 0.00 0.00 0.00 0.00 0.00 .æ.oo .!OII.GO 0.00 LIIO 2AIIQ -.as IUI3 &It \I. .. DotIIOCI 0.00 Q.OCI Q.OCI IUIØ IUIØ Q.OCI .uII IL2I .1.IIØ IIILIIII 34t.s5 2I8t..lZ tlllllUl8 -28Q.t£ H2'..JD .1.IIØ IIILIIII 34UII 4IZUa - -2ta.oo "14.IICI Q.OCI atUIO 34t.M -.a "H~ -228&.87 7£- .1.IIØ TRUE NORTH Q.OCI ~ Q.OCI c::::J 350 0 10 ,... 2M-JDI tl........... IIOCI.8I atUIO 34t.. IItllUlD 7'-" -25711.07 77Q.1' T.D.. aDd.,- t_,2.11 atUIO 34t.M IIIItt.D7 ~7 -211211.as II3IZJII 340 20 32\ 321 26 (j~ 330 30 40 300 _2300 11".""" 50 I 10 '....2500 /1 0 ""'..... r ',60 ...... 2700 , . " 2900 7~~ 80 290 90 100 ~~900 & 200 , .... 900 ,', ' ,', .,.,¡~ " " , ' ß;:.;: ~O 170Ò' ,~ ..... -- --1.2D ~ ,1100 -IJ§!> , ..... , , '- 1 30 ' " '~ ,"'" ~ " ' '1-10 ""'..... ..... ..... ~~ 150 250 / / /goo I' ,2'40 ~ 190 180 170 160 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well // po' ,if/' (" f ARCO A1aska, Znc. Tarn Drill Site 2N 309 dot t309 Tarn Development Pield North Slope, A1aska SUMMARY CLBARANCB R B P 0 R T by Baker Hughes ZNTBQ Your ref: 309 Version #5 Our ref: prop2835 License: Date printed: 22-Jan-99 Date created: 23-Peh-98 Last revised I 22-Jan-99 pield is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.9S5,w150 18 32.772 Slot location is n70 10 13.766,w150 18 49.803 Slot Grid coordinates are N 5911987.115, B 461005.406 Slot local coordinates are 19.19 S 587.88 W projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel1path PMSS <0-9134'>,,313,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PHSS <0-10655'>,,337,Tarn Drill Site 2N PMSS <7090-10245'>,,337A,Tarn Drill site 2N PHSS <0-11197'>,,315,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <10920 - 11225'>,,331,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PHSS <0-12077'>,,335,Tarn Drill Site 2N PHSS <8085-8239'>,,339,Tarn Drill Site 2N PHSS <0-7039'>,,319,Tarn Drill Site 2N PHSS <0-8500'>,,317,Tarn Drill Site 2N PHSS <5303 - 11526'>,,321,Tarn Drill Site 2N PGHS <0-9175'>,,321A,Tarn Drill Site 2N PMSS <9235 - 10028'>,,321A,Tarn Drill Site 2N PHSS <7387 - 8182'>,,325,Tarn Drill Site 2N PHSS <0-9690'>,,329,Tarn Drill Site 2N PHSS <0-9553'>,,323,Tarn Drill Site 2N PHSS <0-6864'>"Arete,Tarn Drill Site 2L 329A PHSS <2506 - 6190'),,329A,Tarn Drill Site PMSS <0-11140>,,313,Tarn Drill Site 2L PHSS <0-9210'>,,305,Tarn Drill Site 2L PHSS <0-9200'>,,325,Tarn Drill Site 2L 315 PHSS <0-8236'>,,315,Tarn Drill Site 2L 323 PHSS <0-10400'>,,323,Tarn Drill Site 2L PMSS <0-12403'>,,321,TarnDrill Site 2L PMSS < 2250 - 7162'>,,3A,TARN #3 PHSS < 0 - 6150'>"TARN#4,TARN #4 Closest approach with 3-D Hinimum Distance method Last revised Distance M.D. Diverging from H.D. 4-Aug-98 59.9 100.0 100.0 21-Jul-98 539.9 100.0 100.0 18-Jun-98 419.3 300.0 300.0 29-JUl-98 419.3 300.0 300.0 30-Sep-98 89.9 100.0 100.0 30-Sep-98 480.4 100.0 100.0 9-0ct-98 330.0 0.0 0.0 9-0ct-98 509.3 300.0 300.0 27-0ct-98 388.9 322.2 322.2 9-0ct-98 447.0 322.2 322.2 9-0ct-98 150.0 100.0 100.0 14-Aug-98 119.9 200.0 200.0 21-Dec-98 180.3 0.0 0.0 21-Dec-98 180.3 0.0 0.0 21-Dec-98 180.3 0.0 0.0 21-Dec-98 240.0 0.0 0.0 28-May-98 299.2 311.1 311.1 23-JUl-98 210.1 0.0 0.0 16-Nov-98 8485.7 10412.2 10412.2 16-Nov-98 7301.6 10412.2 10412.2 15-Dec-98 8586.9 10412.2 10412.2 15-Dec-98 9756.3 10412.2 10412.2 19-Nov-98 6440.5 10412.2 10412.2 29-Dec-98 7733.7 10412.2 10412.2 29-Dec-98 7685.2 10412.2 10412.2 I1-Jan-99 7831.3 10412.2 10412.2 13-Jul-98 206.3 6460.0 6460.0 13-Nov-98 6455.6 611.1 611.1 ð~~~~~~305087498 ~., ~ ..".. \:0.10 ~ " -I '1 :) :-:\~~::j DECEMBER 29, 1998 '. ;,. I\!. ,- '..' ALASKA DEPT OF REVENUE : .:'<.'\ûl\' ALASKA OIL & GAS CONSERVATION COMMI .' ,',.,.~ ,:,:vr.', ',j1\mU:'J . . ¡ . "r'" ',," 3001 PORCUPINE DRIVE' ~.i~í3.S\.(~l L;' ,',; ':~~~;';*~::;:,~,:(;YOID AFTER 90 DAYS ,; It <{ """"--" -----."""-----'.----, --"-.-...-..-.---.-.--,.-- ARca Alaska, Inc. <> AAI PAY ABLES P.o. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: *** 73-426 839 0997579 EXACTLY *********** 100 DOLLARS AND 00 CENTS $*********** 100.00 The First National Bank of Chicago-O710 Chicago; III ¡nois Payable Through Republic Bank Shelbyvi lie. Kentucky TRACE NUMBER: 205087498 II. 2 0 50 a 7 I. 11 a II. I: 0 a ~ q 0 ~ 2 b 21: 0 q'c:¡ 7 5 7 qu. ~.~ 04L COMPANY WELL NAME .:z.IV -3e> PROGRAM: exp - dev Óe.J,/ /-0.// GEOLAREA ~~O WELL PERMIT CHECKLIST FIELD & POOL APPR- DAlE ~~, GEOLOGY ~! ¡;;J ì ANNULAR DISPOSAL APPR DATE WM ~~9 INIT CLASS 1.Permlteeattache....................... 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14.Conductorstnngprovied ................... 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to -3 ~ psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . 34. Contact name/phone for weekly progress reports [exploratory ani 35. With proper cementing records, this plan, pl. (2.q1f<J,@'..f-eó (A) will contain waste in a suitable receiving zone; . . . . . v. . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. GE~; ENGINEERltiG: UIC/Annuiar COMMISSION: RP BEW£,O~.u. ill( WMWM 2/4f9~ DWJ~ JDH -1-- RNC . CO to :ý 5"/1~ c: \m soffi ce \ word i a n \d i a na \check list redrll well bore seg ~ serv ann. disposal para req ONIOFF SHORE ~ N UNIT# y Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N N N (¥)N Y N (Ý)N cf)N <!)N -¥ þ..þ IV f4. ~~ ~~ ~~ V@ Y N Y '(¡ " \ t:' 0 Z 0 ~ ~ ~ ~ t-I Z .., == t-I 00 00 I"C > n tfj ( N Aj /1 N' , Y N Y N Y N L\W-~Q.V\~ IN ~£..ÙÐ<f.Mf'1.£D ß~ tPA 'f<.£61oA.J 10 - ~tCQ.u'éS1' To lj\Jù~,(..,-r \N~ S T f:., FP-o /VI 71-\ ":> £"oJ t. L.L. I ,/'J í 0 A N ð 7 ~ t:.L A P P r:a.cv U) AN N UUI S. AN::D fõe.. fìJ r u ~~ Y N Uc,b of=" 71-115 LùE..~. Y N -- Y N Comments/Instructions: t TV M-{ ~ ~ i-, &t.-.o tt..--- ~ ~ ~ F-'- 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. F, p\D \r>..o.. It Sperry-Sun Drilling Services LIS Scan Utility Tue Jul 13 13:35:29 1999 Reel Header Service name............ .LISTPE Date.....................99/07/13 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Technical Services Tape Header Service name............ .LISTPE Date.....................99/07/13 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TARN POOL MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-90084 M. HANIK F. HERBERT # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD Writing Library. Scientific Writing Library. Scientific 2N-308 501032028800 ARCO ALASKA, INC. SPERRY-SUN DRILLING 13-JUL-99 SERVICES 3 09N 007 57 746 156.80 156.80 120.90 .' Ii! \ i ,',1 'I] \. OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 9.875 6.750 16.000 7.625 108.0 3040.0 10520.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4),COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON OS/23/99. MWD DATA IS PDC. 5. MWD RUN 2 REPRESENTs WELL 2N-308 WITH AN API# 50-103-20288-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10520'MD, 5546'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY, SANDSTONE MATRIX, FIXED HOLE SIZE CTFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC APSORTION FACTOR (BEST BIN) .1 POROSITY LOG PROCESSING PARAMETERS: HOLE SIZE: 6.75" MUD WEIGHT: 9.6 TO 9.7 PPG MUD SALINITY: 100-250 PPM CHLORIDES WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .99/07/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX PEF NCNT FCNT NPHI DRHO RHOB FET ROP $ ( 1 It 1. clipped curves; all bit runs merged. .5000 START DEPTH 3000.0 3030.0 3030.0 3030.0 3030.0 3030.5 3038.5 3038.5 3038.5 3040.5 3040.5 3050.5 3055.0 STOP DEPTH 10466.0 10473.0 10473.0 10473.0 10473.0 10434.0 10428.5 10428.5 10428.5 10434.0 10434.0 10473.0 10520.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ---- BASELINE DEPTH $ # MERGED PBU MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 2 MERGED MAIN PASS. $ MERGE TOP 3055.0 MERGE BASE 10520.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.....................60 .1IN Max frames per record............ . Undefined Absent value......................-999.25 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 FET MWD HOUR 4 1 68 8 3 GR MWD API 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 RPS MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPD MWD OHMM 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 (' \~ FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD CNTS CNTS G/CM G/CM BARN 4 4 4 4 4 1 1 1 1 1 68 68 68 68 68 36 40 44 48 52 10 11 12 13 14 First Last Name Min Max Mean Nsam Reading Reading DEPT 3000 10520 6760 15041 3000 10520 ROP 0.07 1473.03 163.853 14931 3055 10520 FET 0.14 40.96 0.750352 14846 3050.5 10473 GR 39.55 224.76 122.196 14933 3000 10466 RPX 1.27 1684.65 4.90587 14887 3030 10473 RPS 0.91 1664.02 5.04354 14887 3030 10473 RPM 0.84 2000 6.71414 14887 3030 10473 RPD 1.21 2000 7.33616 14887 3030 10473 NPHI 11.01 55.12 34.7585 14781 3038.5 10428.5 FCNT 130.49 1106.63 268.857 14781 3038.5 10428.5 NCNT 13638.9 32678.3 19223 14781 3038.5 10428.5 RHOB 1.73 3.81 2.29754 14788 3040.5 10434 DRHO -0.24 1.39 0.0143075 14788 3040.5 10434 PEF 1.83 12.58 2.75487 14808 3030.5 10434 First Reading For Entire File......... .3000 Last Reading For Entire File.......... .10520 File Trailer Service name............ .STSLIB.OOI Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .99/07/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .99/07/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 2 header data for each bit run in separate files. 2 .5000 If VENDOR GR RPD RPM RPS RPX PEF NCNT FCNT NPHI DRHO RHOB FET ROP $ STOP DEPTH 10466.0 10473.0 10473.0 10473.0 10473.0 10434.0 10428.5 10428.5 10428.5 10434.0 10434.0 10473.0 10520.0 TOOL CODE START DEPTH 3000.0 3030.0 3030.0 3030.0 3030.0 3030.5 3038.5 3038.5 3038.5 3040.5 3040.5 3050.5 3055.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 10.87 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERM NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUI D LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # I( 23-FEB-99 INSITE 3.2. (UPGRADE 3) CIM 5.46,SP4 5.16,SLD MEMORY 10520.0 3055.0 10520.0 54.9 67.7 TOOL NUMBER P1240GR4 P1240GR4 P1240GR4 P1240GR4 6.750 6.8 LSND 9.70 41.0 9.4 100 4.5 3.300 1.411 2.600 4.900 52.2 ( { TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .5 # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.....................60 .1IN Max frames per record............ .Undefined Absent value..................... .-999.25 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 PU-S 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 CNTS 4 1 68 40 11 RHOB MWD 2 G/CM 4 1 68 44 12 DRHO MWD 2 G/CM 4 1 68 48 13 PEF MWD 2 BARN 4 1 68 52 14 First Last Name Min Max Mean Nsam Reading Reading DEPT 3000 10520 6760 15041 3000 10520 ROP 0.07 1473.03 163.853 14931 3055 10520 GR 39.55 224.76 122.196 14933 3000 10466 RPX 1.27 1684.65 4.90587 14887 3030 10473 RPS 0.91 1664.02 5.04354 14887 3030 10473 RPM 0.84 2000 6.71414 14887 3030 10473 RPD 1.21 2000 7.33616 14887 3030 10473 FET 0.14 40.96 0.750352 14846 3050.5 10473 NPHI 11.01 55.12 34.7585 14781 3038.5 10428.5 FCNT 130.49 1106.63 268.857 14781 3038.5 10428.5 NCNT 13638.9 32678.3 19223 14781 3038.5 10428.5 RHOB 1.73 3.81 2.29754 14788 3040.5 10434 DRHO -0.24 1.39 0.0143075 14788 3040.5 10434 PEF 1.83 12.58 2.75487 14808 3030.5 10434 First Reading For Entire File......... .3000 Last Reading For Entire File.......... .10520 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... ~ Version Number.......... .1.0.0 Date of Generation...... .99/07/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................99/07/13 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Technical Services Writing Library. Reel Trailer Service name............ .LISTPE Date.....................99/07/13 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Technical Services Writing Library. Physical EOF Physical EOF End Of LIS File ¡Ii , Scientific Scientific
