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186-128
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. J ~/~- ~<~_~/ Well History File Identifier Organization(aone) TE~wo-Sided Illl[llllllll[lllll r'l RescanNeeded IIIIIIIIIIIIIIIIIII RESCAN [] Color items: Grayscale items: [] Poor Quality Originals: Other: DIGITAL DATA [] Diskettes No, [] Other, No/Type TOTAL PAGES'~7 NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Other lei Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: ~ ~7 (at the time of scanning) SCANNED BY: BEVERLY BREN VINCENT SHERYL~ LOWELL DATE: ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ General Notes or Comments about this file: Quality Checked (done) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg � I izq DATE: September 12, 2013 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Wellbore Plug Verification Petroleum Inspector KRU 2T-12A PTD #1861280 scow DEC 10 2.013 Sundry #313-192 .- Conoco Phillips Alaska Inc. Kuparuk River Field/Unit Thursday, September 12, 2013; I witnessed the verification by Wireline and Pressure Test of a wellbore plug in well 2T-12A, in the Kuparuk River Field. I arrived to find the wireline unit and pump truck rigged up to the well. The Halliburton wireline operator, Sonny Caswell, was in charge of the job. They had already made a few bailer runs between yesterday and when I arrived today and had bailed down only a few feet to 3957 ft measured from tubing hanger flange (THF) where the material seemed to be packing off the flapper style bailer bottom. This was done before I arrived and was reported to me. The Little Red Services pumping crew was rigged up and prepared to perform a "Combo" pressure test of the plug in the tubing and annulus; there was a gas lift valve out of the pocket above the cement plug. The tubing/casing pressure was at approximately 800 psi which was well above the 140 psi where it was left after the cement had been pumped last week. There was a small gas head on both the tubing and inner annulus which was bled down to fluid quickly at approximately 700 psi. Little Red Services then lined up for the pressure test on the tubing/inner annulus which was pumped up with one bbl to 1700 psi and lost 90 psi in thirty minutes (non-linear). v Upon bleed back nearly all pumped fluid was recovered. (Test chart attached) - Halliburton picked up a 4' x 2.25" bailer with a mule-shoed flapper bottom to RIH and tag. They got down to 3956 ft THF and tagged. They jarred down numerous times and had to over pull to come free from 3958 ft. They pulled out of the hole and the bailer was partially (one foot)filled with contaminated cement which had a strong urea odor to it. The bailer bottom was hard packed with this material and it was evident that bailing this cement would not work as it had packed off the bailer bottom at the flapper and had to be extracted with a putty knife. I requested that a sample of the material bailed be secured and evaluated for the reason it had not set up. (Photo attached) ' A combination negative pressure test at 110 psi was next performed on the tubing and inner annulus - I observed it for one hour without any increase. This was recorded on a 2013-09122013-091 2_W ellbore_Plug_KRU_2T-12A_lg.docx 1 of—2, . • • 4 hour 6K chart (attached). I requested that the test be held for the remainder of the chart and the chart be scanned and sent to me. . I left location at this time leaving instructions requiring approval from the AOGCC to proceed with any further cement work or severing of the tubing. I have strong reservations approving this plug even though it marginally passed the downward pressure test and seemed to hold well during the negative pressure test. This is due to the fact that there is no indication of good cured cement and that in itself would fail a rig tag of cement plug as we would require the pumps to be rolled slowly and wash down to hard cement. This type cement job and verification should be scrutinized and its validity questioned. Attachments: Photo of cement sample Pressure Test Chart — Positive Test of Tubing and Inner Annulus Pressure Test Chart — Negative Test of Tubing and Inner Annulus Photo of Sample Recovered from Bailer R •., 0,'s 7R #` ti. w .. x t * . q > + s • ,.,,,,i .. * ,,,,, Ai A . • k ' - : 1.. ,,.' ',41t4 . 0 At b 1,, 14' 4. s •.* v, 2013-09122013-0912_W ellbore_Plug_KRU_2T-12A_lg.docx 2of2 • Regg, James B (DOA) From: Fitzpatrick, Charles J (SolstenXP) [Charles.J.Fitzpatrick @contractor.conocophillips.com] Sent: Sunday, September 15, 2013 9:50 AM � �Il�(�,3 To: DOA AOGCC Prudhoe Bay Subject: 2T-12A MIT on cmt plug Attachments: 2013091512124710.pdf Lou, Attached is a copy of the chart recording of the 1700 psi MIT on 2T-12A conducted 9/12/13. ./ Chuck From: Fitzpatrick, Charles 3 (SolstenXP) Sent: Sunday, September 15, 2013 9:13 AM To: Fitzpatrick, Charles 3 (SolstenXP) Subject: 2T-12A MIT on cmt plug 1 . . 0 ____ _.___........_., kilYr ----TYT-A- CeivA,6° ,..v si tloi.4,,...•.•,.......... ...•oi . .,, , , w.lowo.. pa-—------—---":=.7=1=5 M. a ri............a rw7...•.m i t i pitim to.piwaik:... 4 4 i iiiiii%kiii,..0 ..,,, '0413 ..//,-/ 0/110_.0 0%0 011 ligilliii to 101111irmilimiiiirk)041111111 °' ‘./ 000000 . 6.. ii-Wili =7......w=i111141441111111411111111%1,:iii.._ isso‘14104Not‘ - . 101) 000000 1.7101 II illin/ININtriniiiiiilitralaio 101A171--6=ensirL__4114ftiiii iirliftkii ip,4714P 4\11/4N\ 1000111011 /mm,ii..._ PO.JAITIONTIATIWWW / imorleSIZanivar.,,... _ likiii a OOP 11 MI 0 0 0 V eft;r iminillEaMligasee . 7\laff /WA / /ii ;%7N(341' t gikk WIMUNi■,_114. 00 000G 018/01111/ 1 1 i il //11 C)/N Nj /eta 1 I ill! i ll ioit 8 oinrimoss, tivominut v000. .1.0 w‘lu i oil III, .1 ! , 1 ,0 4, IAA .0 ..... i iiit "tit 11, . iii „ kr to iltil I, 4 "eck- 0'' " 4 4 40000611 MIMI 1 1 " 1 Ili 1 lotiblitlesfM - I' v tosiattli ltallinill 511 I H 411601Thtn;innut alinno -;i5,, __.• ) 5. : Lowtomp,„„gmq 1 0. • 1 ; 1 HI , , , \\ , , „ \ \ 1, \ \\ \ , , , ,mummitutswo,,, ,t.b.,, 0 illskirmidpilhi.,_01 \ \\Y\\\\\\ V\ \ \\ \ \MUM 4. --4Y63. i 4 '"qpilqiNgh \ tut.. \ ItUns \ IS\V Arairsoloak all'114,01.051 1.1114101011111 ;19 issallillirallIi=0111101111 qtb,I 4 ,,,:\ v't _ ....„.,.....„ 1.....c?,WWww- 4411.148/11111,* 4000 11111111111:1..01,01 • \ AreasturaMM, \ ,4N■Wmimmu,==.1011_.00,000_do. 411171 141114111•MmMlnaliagi ftwirigastemIllgjoitildiji 44&048._ , ./a44,,ftrargaraim 4~, IIIMIAllegri="11.0 1,■1:iiiiinyzarvims■,,t'SNERI,IMIAZ)c,‘ ....• ' 1/z. __------ • • - -- 0 0 t-4 • . •. •• .• 1'1 7(z-- • • • Regg, James B (DOA) From: Fitzpatrick, Charles J (SolstenXP) [Charles.J.Fitzpatrick @contractor.conocophillips.com] Sent: Sunday, September 15, 2013 10:07 AM To: DOA AOGCC Prudhoe Bay 'c C(f Ct 13 Subject: 2T-12A Drawdown test ( Attachments: 2013091512592438.pdf Lou, Attached is a copy of the chart recording of the drawdown test. 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Ist \ !. ,„„mrki,,,,piao, „%). - ,4,iyibratunt • um mnin il /73. 1 \\ I 1 MI \\ litaarlindningla t4_,t 0 11114111111111. 111 11/811111411biabilitilit 1 \ 11\\ , ' 111 till k ' \\IOW 111% -it _ -*/,/. .7118`46 . 04 -■ -.4 "wig igowl 1 U % "r4**-mmusisolli • • ■ Ono, eo 1, 4 / kph 1 tat v 5'00„, vier .00 v vq# 411110a101■111011 00 11114rAtte t), \ \ :\. Q1000 4101*INNVIIMENCIPII)„, 0 al 11;Mtn iiir00 4,.. 17,1,"&raligarl/e." \ 4,4%.7:41,4,4„....„....x., „, cOet .4%411%%411111111":".P.P.4mmonamrAellearOlaMiWailisoll 0011111 , �� _ __ � .' - | [� ^? � ---'"1-. - I 1 .. ...,, ,.. • --- -''''------_____......... ... . . ...._., , . , , ... . ,1. . • X, 1 • A s Pe' 3/ ' R • w \� 4 ' T HE STATE Alaska a i and Gas 7 0, `� 1/4 °f A LASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue * *h Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Tyson Wiese SCANNED MAY 0 6 2013 Wells Engineer �' f ConocoPhillips Alaska, Inc. 1 66 P.O. Box 100360 Anchorage, AK 99510 �. Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -12A Sundry Number: 313 -192 Dear Mr. Wiese: 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, Daniel T. Seamount, Jr. Commissioner r DATED this day of May, 2013. Encl. fo g ilissA NErc., Waft 5 if STATE OF ALASKA APR 1 9 2013 OSKA OIL AND GAS CONSERVATION CO SION i • APPLICATION FOR SUNDRY APPROVALS AU 20 AAC 25.280 1. Type of Request: Abandon /"' )11;c4) Plug for Redrill E Perforate New Pool E Repair w ell E Change Approved Program j""' Suspend ' P' Flug Perforations I:, Perforate [ Pull Tubing i"" Time Extension r Operational Shutdow n r Re -enter Susp. Well 1--- Stimulate r Alter casing r Other: .... 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I✓ . Exploratory r 186 - 128 ' 3. Address: Stratigraphic (" Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20066 - 01 • 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 I — No I✓ 2T - 12A • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25569 • Kuparuk River Field / Kuparuk River Oil Pool • 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): 6734 6211 6640' 6131' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 110' 110' SURFACE 2858 9.625 2893' 2813' PRODUCTION 6268 7 6302' 5829' LINER 2021 5 6725' 6203' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 6310' 6339', 6413' - 6448' 5837' 5863', 5928' - 5959' 4.5 L - 80 4504 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BROWN HB -1 PACKER • MD= 4508 TVD= 4216 PACKER - BAKER DB PACKER • MD= 6352 TVD= 5874 NIPPLE - CAMCO DB NIPPLE • MD =500 TVD =500 12. Attachments: Description Summary of Proposal iv 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch ( Exploratory E Stratigraphic E Development 9' Service I — 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2013 Oil E Gas E WDSPL [ Suspended E 16. Verbal Approval: Date: WINJ 1 GINJ (" WAG I Abandoned Commission Representative: GSTOR E SPLUG E 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Email: Tyson.M.WieseC5 conocoohillios.com Printed Name Xon Wies Title: Wells Engineer Signature Phone: 263 -4250 Date ii -11, — 1 Commission Use Only Sundry Number: 5 f 2 _df q 2 Conditions of approval: Notify Commission so that a representative may witness J! J Plug Integrity VB0P Test r Mechanical Integrity Test I Location Clearance 1 !12 (C) (1�t(0) ¢' 4 110 c.v A WQ /` ✓Y Y" 15 gru v�.�r4' / a� .1--Ac Z S- d U a ter cf p ro d ve 1 _, p a_ c Jc t ,_ f"° b .c /o c 4 1-7 R. C �C wt T v) t I Y f a i yr <r > 50 0 a b 0 v t lv p P e✓ f. ra. f io-n . pQ Spacing Exception Required? Yes 0 No g Subsequent Form Required: �/19 — 4.07. , `VDMS MAY - 6 ?O13 , APPROVED BY .5 3 /1 3 Approved by: COMMISSIONER THE COMMISSION Date: ■ pprove • app 'cation is vat • or mont s rom t e • ate o approva . Form 10 -403 (Revised ( �0 /20 r�, If 44 S Form and Attachments in Duplicate ' ORIGINAL • RECEIVED ConocoPhillips APR 192013 Alaska P.O. BOX 100360 AOGCO ANCHORAGE, ALASKA 99510 -0360 April 18th, 2013 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to P &A well 2T- 12A (PTD #: 186 -128), in order to allow grass roots well 2T-41 to utilize the well space. 2T -12 was sidetracked and completed as an A and C sand producer in 1986. In 2003, 2T -12A was worked over and recompleted with 4.5" tubing above the top packer. A surface casing leak was found @ 360' KB in 2009. The latest passing MIT -IA was last done in 2008. The latest passing MIT -T was performed in 2009. In 2010, the well passed a drawdown test on the IA, but earlier testing had indicated a possible IA leak on gas. The objective of the proposed 2T -12A P &A is to allow well space for grass roots well 2T -41 to be drilled, in order to capture the remaining A -sand resource in the area with potential for future CTD sidetracks. A -sand Injection support will be provided by neighboring well 2T -15, as well as 2T -10 in the future. The attached P &A proposal illustrates the plan forward. In order to proceed, variances to Section 20 AAC 25.112 (c) (1) (E) will be required. This section states a mechanical bridge plug will be set no more than 50' above the top of the perforated interval with 75' of cement on top of the plug by the displacement method. ConocoPhillips requests the following variances: 1.) A cement retainer will be set in the first full joint of tubing above the production packer. ConocoPhillips requests the production packer and cement retainer combination to be substituted for the mechanical bridge plug. 2.) The production packer is located 1802' above the top perforation. ConocoPhillips requests a variance to the 50' max footage above the top perforation. If you have any questions or require any further information, please contact me at 1- 907 -263- 4250. Sincerely, Tyson Wiese Wells Engineer CPAI Drilling and Wells of T (eel cv✓, a.e // liaeciX qT 4 a of ii keedarcvr if on (f, v(G r 1rooto Crean NIT 4 &yore ovr A ckef /r a/,'f , ar 7 ° Jvst Q t e 111#` 719 T;s Awl d • • 2T -12A Plug and Abandon Permit to Drill #: 186 -128 The objective of the proposed 2T -12A Plug and Abandon is to free up the space on the pad to allow grass roots well 2T -41 to be drilled, in order to capture the remaining resource in the area. 2T -12A has experienced subsidence damage and presents environmental and economic risks associated with the original RST option, as the wellbore continues to subside. Plug and Abandon Procedure: Slick Line / Little Red: 1. RIH with cement retainer dummy drift (3.6" x 2.5' retainer with 3.6" OD x 8' setting tool) and drift 4.5" tubing to the Baker locator @ 4,493' KB. 2. RIH with memory caliper log from AVA nipple @ 4,584' KB to surface. 3. Set catcher in nipple @ 4,584' KB. Pull DMY from mandrel @ 4,546' KB. Pull catcher. 4. Perform a step rate test w/ 50 bbls diesel, to ensure +/- 2 BPM into the A and C Sands. 5. Set plug w/ catcher in nipple @ 4,449' KB. 6. MIT -IA to 1,500 psi. MIT -T to 1,500 psi. Record T /I /O Pressures. 7. Pull DMY from GLM #3 @ 4,392' KB. Pump 150 bbls diesel down tubing and up the IA. Confirm +/- 2 BPM rate @ <= 2,000 psi through GLM #3. 8. Pull DMY from GLM #2 @ 3,810' KB. 9. Pull catcher/ plug from nipple @ 4,449' KB. Coil Tubing: 1. Ensure that the 10 -403 Sundry and Variance has been approved by the AOGCC. 2. RIH and locate the 4.5" DB nipple (3.75" ID) @ 4,449' KB. Flag pipe. 3. RIH and set cement retainer @ approx. 4,475' KB. (middle of 1 full joint above packer) 4. Perform Injectivity test to ensure adequate rates for cementing operations. ( +/- 2 BPM) 5. Pump 49 bbls of 15.8# cement into the A -Sand and C -Sand perfs, below the retainer. 6. Unsting from retainer and lay in 2 bbls of 15.8# cement to GLM #3 @ 4,392' KB. 7. Fill /Lay in 16 bbls of 15.8# cement into Tubing and IA, to a planned TOC of 4,000' KB. 8. Circulate 100 bbls diesel through the open mandrel @ 3,810' KB to ensure free of cement stringers and IA is loaded with diesel. 9. While POOH, freeze protect tubing from 3,810' KB to surface. Slick Line / Little Red: 1. WOC at least 24 hours prior to tag and test. 2. _ Notify the AOGCC (AOGCC . c ectors@alaska ov of the timing of the cement plug �, _tag and PT. Provide at least 24 hour notice. 3. Tag TOC @ approx. 4,000' KB. (508' cement plug above top packer) 4. Test cement plug to 1,500 psi. Record Results. 5. Perform a drawdown test on the tubing and IA. Record Results. Schlumberger Pumping Services / Conoco Drilling Tool House: 1. Pump 156 bbls AS1 cement through open pocket @ 3,810' KB, bringing cement to surface in Tubing and IA. Obtain sample to ensure good 15.7# cement at surface. 2. Pump 51 bbls AS1 cement down OA through leak © 360' to complete surface plugs. 3. WOC for at least 24 hours after cemented to surface. 4. Contact COP Tool House to begin Surface Excavation and Final Wellhead P&A. TW • • • 2T -12A Plug and Abandon PTD #: 186 -128 Current Completion Proposed P&A L ..„.. SCL @ approx. 360' KB..,,, Camco DS Nipple @ 500' KB 1.) Pull GLM #3 @ 4,392' Nst4 1 §4 4 Ss IliS KB, and GLM #2 @ 3,810' KB 9 518" 36# J -55 Casing _ (e- 2,893' KB 2.) Set CMT Retainer ~ @ 4 KB NIlli r 1 GLM: 3.) Squeeze 49 bbis °- ) / ., DMY @ 2 KB 15.8# cement through - ir- \ retainer into A and C . b3i5 DMY (pre) - Open (post) @ 3,810' KB �' \ Sands Yk DMY (pre) - Open (post) @ 4,392' KB 5 I w^ ` 4.) Stl? out, lay in 2 9�y (plot y p J u vw bbi GLM #3 @ s 1 5 cement 4392' u K p B t I /WI' 4.5" Camco DB Nipple (t? 4,449' KB y� 5.) Lay in /Fill Tubing and r S G¢" '� IA with 16 Obis of 15.8# - „- 41_75- J cement, th GLM 2re;�Am /i 392' KB. Planned rough TOC . r • � =� O r % r to be al 4.000' KB. 1..., } q10 q N U J L.—=1 . Mown HB - 1 Packer w/ PBR @ 4,508' KB =� 6.) Tag TOC @ approx. IA l — — 4.000' KB and test 0 383 { � = , ° cement plug to 1,500 psi. �Wr N� w/ AOGCC witness. cement b is \ fbMY in Prod Mandrel @ 4,546' KB IM t AVA Ported Nipple (No Sleeve 7.) Cement Tubing , (,J- Currently Installed) @ 4,584' KB /111E/Ff a nd IA to surface iL r / with 156 bbis of AS1 (\ 2 7.8" 6.5# J -55 Tubin 4,587 KB cement, circulating g @ through GLM #2 @ 3.810' KB. , �� �, ' / 5" Prod Liner Top @ 4,704' KB E" ! 8.) Cement OA to surface � = • f with 51 bbls of AS1 cement M, g ) L ` 7 26# J -55 Casing @ 6,302' KB f t , r 9.) h P &A final I' C Sand Perfs �: - �� excavation wellw/ LCead work as 430,(o 615 "_"� „=� per required. r. ITC 6,310'- 6,339'KB ! %!! Baker DB Packer w/ SBE (a) .'�' 6,352' KB - T 2 3 /8" Camco D Nipple @ I 6.366' KB / J-55 SOS 6,374' KB 2 �.8 4.7# J 5. Tubing w. SO_ (a� 6,. 3 B A Sand Perfs. IV j ° � = 6,413' - 6,448' KB `i Tag .ig:t«o : " ;6,i{23' $8:: .41 5' Prod Liner TD @ 6,725 KB TW 4 -10 -2013 TW • ' [� KUP • 2T -12A ConoccPhiIkkps Well Attributes Max Angle & MD TD Alaska, InC. $. Ac Wellbore APUUWI Field Name Well Status Ind ( °) MD (ftKB) Act Btm (ftKB) conoc oPhahps : 501032006601 KUPARUK RIVER UNIT PROD 32.32 3,025.00 6,734.0 Comment H2S (ppm) Date Annotation End Date KBGrd (ft) Rig Release Date "' SSSV: NIPPLE 210 11/12/2005 Last WO: 10/16/2003 41.31 5/26/1986 Wet conriu: - 2i -2A. Adder An notation Depth (ftKB) 0138JS:27 AM Schematic End Date Annotation Last Mod ... End Date 1 Last Tag 6,424.0 3/16/2013 Rev Reason: TAG, PULL PLUG haggea 4/5/2013 Casing Strings Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd HANGER, 28 . = CONDUCTOR 16 15.062 37.0 110.0 110.0 62.50 H - 40 Casing Description String 0... String ID ... Top (ftKB) Set Depth (r... Set Depth (TVD) ... String Wt... String ... String Top Thrd )) SURFACE 9 5/8 8.765 34.4 2,892.8 2,812.7 36.00 J - 55 BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd li .1, PRODUCTION 7 6.276 34.2 6,301.7 5,829.1 26.00 J - 55 BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth (t.. Set Depth (ND) ... String Wt... String ... String Top Thrd LINER 5 4.151 4,703.6 6,725.0 6,202.8 18.00 S -140 SFJ Liner Details Top Depth (TVD) Top Inel Nomi... CONDUCTOR, Top (ftKB) (ftKB) I° I Item Description Comment ID (in) 37 - 110 4,703.6 4,385.1 30.15 HANGER BAKER SIMPLEX LINER HANGER 5.000 NIPPLE, 500 ' t is Tubing Strings Tubing Description String 0.. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO 4 1/2 3.958 28.3 4,503.9 4,212.8 12.60 L -80 IBT Completion Details Top Depth GAS LIFT, (TVD) Top Inc! Nomi... 2.486 Top (ftKB) (ftKB) ( Item Description Comment ID (!n) 28.3 28.3 -0.55 HANGER CAMERON TUBING HANGER 4.500 r 499.6 499.6 0.69 NIPPLE CAMCO DB NIPPLE 3.812 1 4,449.2 4,165.3 29.44 NIPPLE CAMCO DB NIPPLE 3.750 4,493.2 4,203.4 29.81 LOCATOR BAKER LOCATOR 2.430 4,493.7 4,203.9 29.81 SEAL BAKER SEAL ASSY 2.450 SURFACE, T ubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 30.2,59 - _........_ --; TUBING Original 23/8 1.995 4,491.3 6,375.2 5,894.9 4.70 J -55 EUE -8rd Completion Details GAS LIFT, Top Depth 3,810 (TVD) Top Mel Noon... Tap(ftKB) (ftKB) r) Item Description Comment ID (in) 4,491.3 4,201.8 29.80 PBR BROWN PBR 2.500 4,507.9 4,216.2 29.88 PACKER BROWN HB-1 PACKER 2.441 GAS LIFT. _ - ' - 4,584.3 4,282.3 30.15 NIPPLE AVA BPL PORTED NIPPLE 2.250 4.392 ^?J 4,587.2 4 30.16 XO Reducing CROSSOVER 2.875 x 2.375, 4.708, 1.995 2. �_ _ 6,272.7 5 25.82 BLAST RINGS 1. 995 375 6,350.4 5,872.6 26.52 LOCATOR BAKER LOCATOR 1. 995 NIPPLE, 4,049 6, 5,873.4 26.53 1. 995 ® 6,352.3 5,874.3 26.54 PACKER BAKER DB PACKER 3. 250 6,355.2 5,877.0 26.57 SBE BAKER SBE BROWN SHEAR OUT 2.992 MIME 2. 450 LOCATOR. 6,366.3 5,886.9 26.67 NIPPLE SPACE -OUT CAMCO D NIPPLE 1. 812 4 I 6,374.3 5,894.1 26.74 SOS SEAL, 4,494 PBR, 4,491 - � ,Perforations & Slots PACKER, 4,508 Shot Top (ND) Btm (TVD) Top (ftKB) Bkn (R Dens KB) (ftKB) (ftKB) Zone Date Oh- Type CommeM '!1 PRODUCTION, � ' . 6,310.0 6,339.0 5,836.5 5,862.5 C-4, 2T -12A 9/29/1986 12.0 IPERF 3 3/8" Casing HyperJ, 60 deg. 4.546 Phasing NIPPLE. 4,584 6,413.0 6,448.0 5,927.7 5,959.4 A-4, A -3, 2T -12A 9/29/1986 4.0 IPERF 33/8" Casing HyperJ, 60 deg. Phasing II WM Notes: General & Safety End Date Annotation tt 2/6/2006 NOTE: CONFIRMED PACKER LEAK @ 4508' w/PONYTAIL 10/2/2007 NOTE: LEAKS FOUND @ 4508', 4584', 4803' ELM 12/2/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PRODUCTION. 4 I 4 348,302 IPERF, 6,310-6,339 la LOCATOR, ;! 8,350 III PACKER. 8.352 SSE,6,355 >♦ NIPPLE, 8,386 lB Mandrel Details Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run SOS, 6,374 '.. N... Top (ftKB) (ftKB) ( ° 1 Make Model (in) Sere Type Type On) (psi) Run Date Corn... 1 2,485.6 2,458.9 23.13 CAMCO KBG-2 1 GAS LIFT DMY BK5 0.000 0.0 8/24/2008 2 3,809.6 3,599.4 27.51 CAMCO KBG-2 1 GAS LIFT DMY BK5 0.000 0.0 8/24/2008 ® 3 4,392.4 4,115.7 29.02 CAMCO KBG -2 1 GAS LIFT DMY BK 0.000 0.0 11/15/2009 IPERF, 4 4,546.4 4,249.6 30.01 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 9/30/1986 6,413$448 LINER, 4,7048,725 TD (2T -12A), 6,734 • • Fisher, Samantha J (DOA) \ -Ira From: Schwartz, Guy L (DOA) Sent: Wednesday, April 03, 2013 3:25 PM To: Wiese, Tyson M; Ferguson, Victoria L (DOA) Cc: Fisher, Samantha J (DOA) Subject: RE: 2T -12A Plugback for Redrill - PTD #186 -128 Tyson, We will retract sundry 312 -465 for "plug back for redrill" as you request below. This email is all that is required. Guy Schwartz Senior Petroleum Engineer AOGCC NNE APR 1 7 2013 907- 444 -3433 cell 907 - 793 -1226 office From: Wiese, Tyson M [mailto: Tyson .M.Wiese(aconocophillips.com] Sent: Wednesday, April 03, 2013 2:27 PM «- To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA) Subject: 2T -12A Plugback for Redrill - PTD #186 -128 Victoria, Guy I have an approved sundry for the 2T -12A Plugback for Redrill, 10 -403 Sundry #312 -465. Due to completion complexity and the potential RST cost, we have decided to pursue a Grassroots well (2T -41), rather than perform the RST out of 2T -12A. This email is to verify that I would like to retract /cancel the 10 -403 that I had requested for the 2T -12A plug back and RST prep. I will put together an updated summary for the 2T -12A P &A and request a separate 10 -403 for that work. Let me know if there is anything else that you need from me in order to retract the RST 10 -403 sundry. Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1- 907 - 263 -4250 Cell:1- 907 - 230 -5388 1 • • 1 i %i w ', s� THE STATE Alaska Oil and Gas F /�Ce1 0 " LAS Conservation Commission GOVERNOR SEAN PARNELL ,, 333 West Seventh Avenue O Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Tyson Wiese Wells Engineer ConocoPhillips Alaska, Inc. r 1.2. P.O. Box 100360 I Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -12A Sundry Number: 312 -465 Dear Mr. Wiese: 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 Cathy . Foerster f/ Chair DATED this / I d Y of December, 2012. 1 Encl. RI C CI Y CAI STATE OF ALASKA , KA OIL AND GAS CONSERVATION COM•ION r ® 7 z01 APRLICATION FOR SUNDRY APPROVALS ^ / 20 AAC 25.280 ` k AO GCC 1. Type of Request: Abandon r Rug for Redrill F • Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension f""` Operational Shutdow n r Re -enter Susp. Well r Stimulate After casing 9 r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 , Exploratory r 186 -128 • 3. Address: Stratigraphic r Service C"` 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20066 - 01 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Wilt planned perforations require spacing exception? Yes r No fq 2T -12A • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25569 • Kuparuk River Field / Kuparuk River Oil Pool • 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): 6734 • 6211 6640' 6131' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 110' 110' SURFACE 2858 9.625 2893' 2813' PRODUCTION 6268 7 6302' 5829' LINER 2021 5 6725' 6203' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6310' 6339', 6413' - 6448' 5837' 5863', 5928' - 5959' 4.5 L - 80 4504 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BROWN HB -1 PACKER ' MD= 4508 TVD= 4216 PACKER - BAKER DB PACKER • MD= 6352 TVD= 5874 SSSV - CAMCO DB NIPPLE MD =500 TVD =500 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory r Stratigraphic r Development P". Service r 14. Estimated Date for Commencing Operations: 15. Well Status after pro osed work: f /2— 1/15/2013 - Oil , - r Gas r WDSPL r Suspended 16. Verbal Approval: Date: WINJ r 12 .1 1.1 G INJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Email: Tvson .M.Wieseeconocoohillips.com Printed Name 3 ' se Title: Wells Engineer Signature Phone: 263-4250 Date 17 6 — 14 011 Commission Use Only Sundry Number: 3 2-(--A j Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test r ✓Mechanical Integrity Test r Location Clearance r Other 3400 pSc, eO/' 7 -Cam` 5, A Al -t.-- fly P ff: ci_p p,,r Zo A-A-e- zs-: / /Z6.°) Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /0 — il 07 APPROVED BY i Approved by: A i COMMISSIONER THE COMMISSION Date:) Z - / 7 ' 6 ' ALAAproDved IIDEC 11S V81 ;or % montns tr /m ; 7 e aate or S F orm and Att hments in Duplicate ��''9 \4 • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 November 26th, 2012 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: , ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to plug back - well 2T -12A (PTD#: 186 -128) in order to prepare the well for an upcoming rotary sidetrack. 2T -12 was sidetracked and completed as an A and C sand producer in 1986. In 2003, 2T -12A was worked over and recompleted with 4.5" tubing above the top packer. A surface casing leak was found @ 360' KB in 2009. The latest passing MIT -IA was last done in 2008. The latest passing MIT -T was performed in 2009. In 2010, the well passed a drawdown test on the IA, but earlier testing had indicated a possible IA leak on gas.,/ The objective of the proposed 2T -12A Plug Back is to prepare the well for a rotary side track planned for 2012, in efforts to recover A -sand resources, as the C -sand in the area appears to have watered out. There is potentially un -swept resource to the West of a NS fault that the RST would attempt to access. A -sand Injection support will be provided by neighboring well 2T -15, as well as 2T -10 in the future. The attached plug back for redrill proposal illustrates the plan forward. In order to proceed, variances to Section 20 AAC 25.112 (c) (1) (E) will be required. This section states a mechanical bridge plug will be set no more than 50' above the top of the perforated interval with 75' of cement on top of the plug by the displacement method. ConocoPhillips requests the following variances: 1.) A cement retainer will be set in the first full joint of tubing above the production packer. ConocoPhillips requests the production packer and cement retainer combination to be substituted for the mechanical bridge plug. 2.) The production packer is located 1802' above the top perforation. ConocoPhillips requests a variance to the 50' max footage above the top perforation. If you have any questions or require any further information, please contact me at 1- 907 -263- 4250. Sincerely, Tyson Wiese 7 Wells Engineer `N pn -c�l�� CPAI Drilling and Wells be "ny Aot / 4 for ,"ech4,1 C,f/ /ll y/ « 4Cli,> pits /! � Co" off. vr'� O Q / a �f +'f 7rf�e Tit n_ {et, gvolke 000 t Q I / 9 v "'eel iv 4 qr Wes 70 aver f c. 44snreb► , fi 0 411 70 4 lld.. 4 s,�el��rr � � f Per n ®0 of T / d'/. 6� vn t'5't f, i ,•ifl) 6,t `ecove►/ I` / '' /x/,3/,7 • 2T -12A Pre Rig Plug Back for Redrill Permit to Drill #: 186 -128 The objective of the proposed 2T -12A Plug Back is to prepare the well for a rotary side track planned for 2012, in efforts to recover A -sand resources, as the C -sand in the area appears to have watered out. There is potentially un -swept resource to the West of a NS fault that this RST would attempt to access. A -sand Injection support will be provided by neighboring well 2T -15, as well as 2T -10 in the future. Proposed Plug back Procedure: (Pre Rig) Slick Line / Little Red: 1. RIH with cement retainer dummy drift (3.6" x 2.5' retainer with 3.6" OD x 8' setting tool) and drift 4.5" tubing to the Baker locator @ 4,493' KB. 2. RIH with memory caliper tog from AVA nipple @ 4,584' KB to surface. 3. Set catcher in nipple @ 4,584' KB. Pull DMY from mandrel @ 4,546' KB. Pull catcher. 4. Perform a step rate test w/ 50 bbls diesel, to ensure +/- 2 BPM into the A and C Sands. 5. Set plug w/ catcher in nipple @ 4,449' KB. 6. MIT -IA to 1,500 psi. MIT -T to 1,500 psi. Record T /I /O Pressures. 7. Pull DMY from GLM #3 @ 4,392' KB. Pump 100 bbls diesel down tubing and up the IA. Confirm +/- 2 BPM rate @ <= 2,000 psi through GLM #3. 8. Pull catcher/ plug from nipple @ 4,449' KB. Coil Tubing: 1. Ensure that the 10 -403 Sundry has been approved by the AOGCC. 2. RIH and locate the 4.5" DB nipple (3.75" ID) @ 4,449' KB. Flag pipe. 3. RIH and set cement retainer @ approx. 4,475' KB. (middle of 1 full joint above packer) 4. Perform Injectivity test to ensure adequate rates for cementing operations. ( +/- 2 BPM) 5. Pump 49 bbls of 15.8# cement into the A -Sand and C -Sand perfs, below the retainer. 6. Unsting from retainer and lay in 1.3 bbts cement to just above GLM #3 @ 4,392' KB. 7. Open the IA and Pump 3.7 bbls of 15.8# cement into the annulus above the top packer. 8. Close the IA, and lay in remaining cement (1.3 bbts) in tubing to 4,308' KB. 9. While POOH, clean out excess cement and freeze protect from 2,500' KB to surface. Slick Line / Little Red: 1. WOC at least 24 hours prior to tag and test. 2. Notify AOGCC Inspector (659 -2714; 659 -3607 pager) of the timing of the post- cement plug tag and PT. Provide at least 24 hour notice. 3. Tag TOC © approx. 4,308' KB. (200' cement plug above top packer) 4. Test cement plug to 1,500 psi. MIT -IA to 1,500 psi. Record Results. 5. Perform a drawdown test on the tubing and IA. ac�- E -line / LRS: 1. RIH w/ 4.5" Jet Cutter and cut tubing mid joint at approx. 4,087' KB. 2. Pump 54 bbls of 11# corr. inhibited brine (KWF), followed by 78 bbls of Diesel. 3. Jumper IA and Tubing at Surface and allow diesel to U -tube for freeze protect. 4. RD E -line and LRS, RU FMC to set BPV. TW • • 2T -12B Rotary Sidetrack Program Outline (up to cutting window) 1. MIRU Nordic 3 on 2T -12A. Pull BPV and VR plugs. Record tubing, IA, and OA pressures. Circulate out freeze protect through tubing cut and monitor well for pressure. 2. Set BPV and nipple down tree. M/U blanking plug in tubing hanger and nipple up BOPE. • Notify AOGCC field inspector 24 hours prior to BOPE test. • Test BOPE to 250 psi low / 3,500 psi high. 3. Pull blanking plug and BPV. Pull tubing hanger. lay down 3 -1/2" completion to cut @ – 4,087'. 4. Run 7" casing scraper to cut @ – 4,087' MD. 5. Rig up E -line and run CBL in 7" casing to determine TOC. Using E -line, fire string shot in 2nd free collar up from TOC. RD E -line 6. Nipple down BOP stack and tubing head using Hydra -tight system. Pull 7" packoff and expect casing growth. 7. Run 7" casing spear and engage 7" casing with overpull. Cut excess casing and reset slips with casing in tension. "—pi. lee .. 8. NU 11" 5M BOP on casing head. BOPE is now conside err., a diverter due to urface casing leak suspected to be at –360' RKB. A pressure test cannot be performed at this time. 9. RLH w/ multi- string cutter and cut 7" casing above TOC. 10. Spear casing and circulate out Arctic Pack in the 9 %" x 7" annulus using hot diesel followed by hot seawater. 11. POOH laying down 7" casing. Set test plug and test BOP to 250/3000 psi. ( ? i ) 12. Run back off tool and back off casing stub. 13. Run tandem string mills to gauge the 9 %" csg for the ES cementer. 14. Make a dummy drift run for the 7" casing & ES cementer. 15. Spear and recover backed off 7" casing stub. 16. Change lower pipe rams to 7 ". Pressure test BOP to 250/3000 psi. 17. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. PT casing to 3000 psi. 18. Open ES cementer and pump cement into 9 -5/8" x 7" annulus. Close the IA once cement returns at surface and squeeze cement into SC leak. Continue to pump cement until plug closes cementer. WOC. 19. ND BOP, pull 7" casing in tension and land in slips. Cut excess 7" casing and install packoff. NU new tubing head. 20. NU 11" 5M BOP, change out lower pipe rams to VBR's. PT rams and break to 250/3000 psi. 21. Drill out cement and ES cementer down to TOC from pre -rig P&A. Pressure test casing to 3500 psi for 30 minutes. This will be used as a baseline for the FIT /LOT. 22. Pick up 7" whipstock/milling assembly. Run in hole and displace casing to milling fluid. 23. Set whipstock and mill window in 7" plus 20' of new formation for FIT /LOT. TW PT° KUP • 2T -12A Conoco Phillips /$ Well Attributes Max Angle & MD TD Well bore APIIUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) � 501032006601 KUPARUK RIVER UNIT PROD 32.32 3,025.00 6,734.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date Well conn9 - 2r- 161s 2o1z 9 1s.39 AM SSSV NIPPLE 210 11/12/2005 Last WO: 10/16/2003 41.31 5/26/1986 Schemati -L Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 6,414.0 10/12/2008 Rev Reason: PULL PLUG ninam 6/19/2012 Casing Strings HANGER. 28 S Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 37.0 1100 110.0 62.50 H -40 • Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.765 34.4 2,892.8 2,812.7 36.00 J - 55 BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 4 I ' c PRODUCTION 7 6.276 34.2 6,301.7 5,829.1 26.00 J - 55 BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd LINER 5 4.151 4,703.6 6,725.0 6,202.8 18.00 S -140 SFJ Liner Details Top Depth (TVD) Top Inc' Nomi... CONDUCTOR, Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 37 4,703.6 4,385.1 30.15 HANGER BAKER SIMPLEX LINER HANGER 5.000 NIPPLE, 500 I::::: Tubing Strings Ell Tubing Description String 0... String ID .., (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO 1 4 1/2 I 3.958 I Top 28.3 I 4,503.9 I 4,212.8 I 12.60 I L -80 I IBT In Completion Details Top Depth GAS LIFT, (T Top Inc! Noml... 2,486 Top (ftKB) OMB) CI Item Description Comment ID (in) 28.3 28.3 -0.55 HANGER CAMERON TUBING HANGER 4.500 L- -- 499.6 499.6 0.69 NIPPLE CAMCO DB NIPPLE 3.812 4,449.2 4,165.3 29.44 NIPPLE CAMCO DB NIPPLE 3.750 • 4,493.2 4,203.4 29.81 LOCATOR BAKER LOCATOR 2.430 SU J l 4,493.7 4,203.9 29.81 SEAL BAKER SEAL ASSY 2.450 RFACE, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 34 -2,893 TUBING Original 2 3/8 1.995 4,491.3 6,375.2 5,894.9 4.70 , J -55 EUE -8rd Completion Details GAS LIFT, i � Top Depth 3,870 L (TVD) Top Intl Nomi... i............ Top (ftKB) (ftKB) (°) Item Description Comment ID (In) 4,491.3 4,201.8 29.80 PBR BROWN PBR 2.500 4,507.9 4,216.2 29.88 PACKER BROWN FIB-1 PACKER 2.441 GAS LIFT, 4.392 2 I 4,584.3 4,282.3 30.15 NIPPLE AVA BPL PORTED NIPPLE 2.250 4,587.2 4,284.8 30.16 XO Reducing ' CROSSOVER 2.875 x 2.375, 4.70#, 1.995 2.375 ® 6,272.7 5,802.9 25.82 BLAST RINGS 1.995 6,350.4 5,872.6 26.52 LOCATOR BAKER LOCATOR 1.995 NIPPLE. 4,449 I 6,351.3 5,873.4 26.53 SPACE -OUT 1.995 6,352.3 5,874.3 26.54 PACKER BAKER DB PACKER 3.250 6,355.2 5,877.0 26.57 SBE BAKER SBE 2.450 LOCATOR. 6,366.3 5,886.9 26.67 NIPPLE CAMCO D NIPPLE 1.812 4 SEAL, 4,494 6,374.3 5,894.1 26.74 SOS BROWN SHEAR OUT 2.992 PBR, 4,491 Perforations & Slots PACKER, 4.508 _ Shot Top (TVD) Btm (TVD) Dens [ 1 Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment PRODUCTION, 6,310 6,339 5,836.5 5,862.5 C 2T - 12A 9/29/1986 12.0 IPERF 3 3/8" Casing HyperJ, 60 deg. 4,546 I I Phasing 6,413 6,448 5,927.7 5,959.4 A-4, A -3, 2T -12A 9/29/1986 4.0 IPERF 3 3/8" Casing Hyper/, 60 deg. NIPPLE. 4.584 - Phasing V Notes: General & Safety End Date Annotation 2/6/2006 NOTE: CONFIRMED PACKER LEAK @ 4508' w/PONYTAIL 10/2/2007 NOTE: LEAKS FOUND @ 4508', 4584', 4803' ELM I i 12/2/2010 NOTE: View Schematic w/ Alaska Schematic9.0 IMF II PRODUCTION, 4 , 4 34-6,302 IPERF, -. 8,310-6,339 _ LOCATOR, 6,350 I■ PACKER, 8,352 SBE, 6,355 .._ NIPPLE, 6,366 i_ Mandrel Details III Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run !�¢ SOS. 6,374 II:C. Stn Top (ftKB) (ftKB) el Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,485.6 2,458.9 23.13 CAMCO KBG-2 1 GAS LIFT DMY BK5 0.000 0.0 8/24/2008 2 3,809.6 3,599.4 27.51 CAMCO KBG-2 1 GAS LIFT DMY BK5 0.000 0.0 8/24/2008 3 4,392.4 4,115.7 29.02 CAMCO KBG -2 1 GAS LIFT DMY BK 0.000 0.0 11/15/2009 IPERF, 4 4,546.4 4,249.6 30.01 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 9/30/1986 6,413 -6,448 I LINER, 4,7048,725 TD (2T -12A), 6,734 r • • 2T -12B ' Pre and Post Plug Back for Redrill Current Comp'.etian Proposed Pre Rill ST F &A ..] 8.) Circ.in114KWF. M 1 Camcc D. r pple `•03' , Freeze Protect, Set BPV �� S i 5.8' 38* J -55 Casing 2.$83' KB OINK 7 .) Cut tubing 0 M approx. 4.087' KB 5.) Pump approx. 6 bbls GLM: cement (200') into IA DMY 0 2,485 KB and tubing, above 6 } Tag !Test TUC DMY 0 3.810' KB packer j a pprox_ 4,348' KB, wt DMY ' 4.392' KB ,' stness 4.) Sting out, lay in % 1.) Pul GLM 3 (4.14,392' KB cement up to GLM 41 A M q 4 5' Cameo DB Rippe 04449'KB / f INA 2 ) Set CMT Retainer 0 r AV ..1 4,475' KB ), -, _ 1T 110911 orsienuisidT 1..-, 1= a} _',4" -E -1 F'ackerwt PER 04,508 KB r� 1—i 3.) Squeeze 49 bbls Aisere arien' thrcugh retainer in A and C Sands C `AY in Prod. Mandrel $' 4.F4e KE AVA Pored V o ipp a (t c save e/, C.; trent y Insta ed) g 4 584' KB S iii_ 1,., 2 8 54 J -55 T -bing 0 4,587' KB ' 5' Prod L -_- Top 0 4.704' KB a, k Al ` 7' 254 J -55 Casing 0 5 .302' KB C Sand Peed - °- e .310' - 5 339' KB r l ; Baker DB Packer w,' SBE 0 �- nwaramt 1 __ 5.3,52' KB - amme Prz I 2 Sr ' .amx D Nipple 0 I /7 e 356' KB / 2 II 4.74 J -55 - ub ng w SOS (g e.374 KB m / 4 A Sand Pees /' _ nom 5.413' —e 448' KB `. A .. :k.. 5' Prcc. liner TD 4 a 725' K2 • • TW 64-2012 TW • • Roby, David S (DOA) From: Wiese, Tyson M < Tyson .M.Wiese @conocophillips.com> Sent: Wednesday, December 12, 2012 9:09 AM To: Roby, David S (DOA) Subject: RE: Sundry application for KRU 2T -12A David, Tommy Nenahlo responded to your questions below,in blue. Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1- 907 - 263 -4250 Ce11:1- 907 - 230 -5388 From: Nenahlo, Thomas L Sent: Wednesday, December 12, 2012 8:46 AM To: Wiese, Tyson M Cc: Baca, Hank Subject: RE: Sundry application for KRU 2T -12A Tyson - See below for the answers to David's questions. Please let me know if you need anything further! Thanks, Tommy Nenahlo From: Baca, Hank Sent: Wednesday, December 12, 2012 7:08 AM To: Wiese, Tyson M Cc: Nenahlo, Thomas L Subject: RE: Sundry application for KRU 2T -12A Tyson, I think Tom is the person who can help us with this. Hank Baca Drilling Engineer 907 - 263 -4180 office 907 - 229 -6235 cell From: Wiese, Tyson M Sent: Wednesday, December 12, 2012 7:02 AM 1 • • To: Baca, Hank Subject: FW: Sundry application for KRU 2T -12A Hank, Can you pass these questions onto the DPE or Asset Engineer in charge or this project. I can't remember who that is right now with the people moving around. AOGCC (David Roby) has the questions below he would like to have answered before they can approve my Sundry to plug back for Redrill. Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1- 907 - 263 -4250 Cell:1- 907 - 230 -5388 From: Roby, David S (DOA) [mailto:dave.robv@alaska.gov] Sent: Tuesday, December 11, 2012 5:28 PM To: Wiese, Tyson M Subject: [EXTERNAL]Sundry application for KRU 2T -12A Tyson, I am reviewing your application to plug the subject well for redrill and I have a couple of questions on your proposed activities. Since the existing wellbore will be abandoned I have to review the application from the standpoint of whether or not any reserves will be lost. The production history for this well is a bit erratic, but before the well was shut in for mechanical issues it looks like the well was a decent oil producer but had a water cut in excess of 90% and a GOR much higher than the drillsite average. Your application indicates the new well will target reserves to the A Sand to the west of a N/S trending fault. Here are the questions I have: 1) Is the reason for the planned redrill because you do not think that this well is a viable candidate, due to the high GOR and water cut, for repair? The 2T -12A penetration location lies just to the east of a large north -south sealing fault. It is believed that the east side of this fault has been well swept in the vicinity of the 2T -12A penetration location, as indicated by well test water cuts prior to 2T -12A being shut in. As part of the 2T re- development program a rotary sidetrack (vertical producer) will be drilled out of the existing 2T -12A well bore and in to the block on the west side of the large north -south sealing fault. From reservoir surveillance and geologic features, it appears that the A sand in the block to the west of this fault has not been well swept. 2) I assume that like a lot of other redrills that have occurred at Kuparuk in recent years that the new well will be a horizontal well, is this a correct assumption? The 2T -12B well will be a vertical producer that will be set up for future CTD sidetracks. a. Will it also be a multilateral? As part of the 2T redevelopment program, we are currently planning on drilling multiple horizontal CTD sidetracks out of the 2T -12B mother bore. 3) Will the planned well target only the reserves to the west of the fault, or reserves on both sides of the fault? The 2T -12B rotary sidetrack well only target reserves to the west of the fault; however, one of the planned future CTD sidetracks will target remaining reserves on the east side of the large north -south fault in the area immediately south of the existing 2T -12A bottom hole location. The large north -south fault is downthrown to the east /up thrown to the west. From a coiled tubing drilling perspective it is easier to drill down- throw, rather than 2 • • up-throw. This is another reason behind landing the 2T -12B producer in the up thrown block. This will allow us to drill multiple sidetracks along both the up thrown and downthrown sides of the fault. a. Is the east side of the N/S trending fault the fault block in which 12A was completed? Yes. Thanks in advance, Dave Roby Reservoir Engineer AOGGC 907 - 793 -1232 3 Scblumbel'gep NO. 4468 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth :/5~~NED OCT 3 1 2007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD 2N-327 11839673 PERF/SBHP "')()~ ~ {"¡(~q 10/24/07 1 2T-201 (REPLACES 11839656 INJECTION PROFILE l )-¡:Œ.. 1'15"""-/.=1 ~ 09/03/07 1 1A-23 11837520 PRODUCTION PROFILE IO¡ I -()(::l\ 10/04/07 1 2M-09A 11846446 WFL O:t..Q.. lq(A -(--At) 10/04/07 1 31-08 11837517 LDL ,<t~ - (WI) 10/02/07 1 2M-24 11839670 PRODUCTION PROFILE lOt '::) -os-D 10/03/07 1 1J-102 11846451 INJECTION PROFILE 0-:r.c.... ~ - /l,ò 10/10/07 1 1Y-02 11837516 INJECTION PROFILE i JTf' I èj(~ - ~ 10/01/07 1 1 E-112 11846450 INJECTION PROFILE u:r~ 6"u -cA { 10/10/07 1 2T-12A 11839669 LDL j~v - I ~ '5<" 10/02/07 1 2B-07 11837522 INJECTION PROFILE Uï C. I '5\l.f -,-..,;Jc..{ 10/05/07 1 1 E-12 11846447 DDL I .l¡( .:l - ^{~ Ö 10/08/07 1 2N-327 11839671 SCMT .:1-n ~ - ()ç, '9 10/23/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. t3 10/25/07 . . Schlurnberger 1/19/05 NO. 3313 1 <ùb- ¡2J(. Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL f9() .. /b 7 1 A-25 10942816 PRODUCTION PROFILE/DEFT 12/25/04 1 1,"..~D-10 10942818 LDL & MUL TIFINGER CALIPER 12/27/04 1 .20 'I..,~f( 1 E-112 10715441 MPSP PRODUCTION PROFILE 11/12/04 1 ;OI.../$'11C-119 10942819 INJECTION PROFILE 12/28/04 1 ~4..1.' '7 1 E-1 04 10942821 PERF RECORD W/SBHP 12/30/04 1 /ih- 12 Y' 2T -12A 10922519 PRODUCTION PROFILE/DEFT 01/03/05 1 ,,%04"1.2.1 _1 E-1 04 10942821 SCMT 12/29/04 2-() '/.2,' I 1 E-1 02 10942815 USIT 12/24/04 SIGNED: . ~~~ SCANNED APR :1 8 2005 DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk --/ Color CD 1 1 ~ 1-('1- 05 ConocoPhillips Mike Mooney Wells Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 12, 2003 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 2T-12A (186-128) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 2T-12A. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader CPAI Drilling MM/skad RECEIVED 200,3 STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ~] Suspend [] Operation Shutdown ~] Perforate ~ Variance ~] Annular Disp. r'-] Alter casing [] Repair Well [] Plug Perforations r-~ Stimulate Change Approved Program r"-] Pull Tubing [~] Perforate New Pool [--] Re-enter Suspended Well [~] 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~] Exploratory [] 186-128 / 3. Address: Stratigraphic r-~ Service ~] 6. APl Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20066-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 117' 2T-12A 8. Property Designation: 10. Field/Pool(s): ADL 25569, ALK 2667 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 6725' feet true vertical 6205' feet Plugs (measured) 6366' Effective Depth measured 6421' feet Junk (measured) true vertical 5938' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 2774' 9-5/8" 2891' 2813' PROD. CASING 4587' 7" 4704' 4388' LINER 2021' 5" 6725' 6205' RECEIVED Perforation depth: Measured depth: 6310'-6339', 6413'-6448' true vertical depth: 5839'-5865', 5931'-5962',I""~"r;~',J ~.,"'1. ,.-~' 200~ Tubing (size, grade, and measured depth) 4.5" / 2-7/8" / 2-3/8", L-80 / J-55, 4491' / 4587' / 6375' MD, ,Alaska 0i~ & Gas Cons. C0mm~ior~ Packers & SSSV (type & measured depth) Brown 'HB-I' pkr, Baker 'DB' pkr 4508', 6352' SSSV= NIP SSSV= 500' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casin,q Pressure Tubing Pressure Prior to well operation 987 7223 1185 371 Subsequent to operation 1045 2646 2689 328 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ~ Development [-~ Service r'-'] Daily Report of Well Operations _X 16. Well Status after proposed work: Oilr-~ Gas ['1 WAG r---~ GINJ r--] WINJ [-1 WDSPLE~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: I Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Leader Signature lJ-../-_, ~//_.~...~ Phone Date /~,~ ......... I~ '~ ~;v ~/~{ Prepared bY Sh~ron, AIl~up~.Drak~ 263r-4~12 Form 10-404 Revised 2/2003 · SUBMIT IN DUPLICATE ::C nOCOph ip a : i o ill s Alask · · ~ Page.1 of 3 _,_______on.'_ooerati sS'um ay --m r Re ortlP · · : Legal Well Name: 2T-12 Common Well Name: 2T-12 Spud Date: 5/13/1986 Event Name: WORKOVER/RECOMP Start: 10/11/2003 End: 10/16/2003 Contractor Name: Nabors3sCompanyM@conocop Rig Release: 10/16/2003 Group: Rig Name: Nabors 3S Rig Number: ~ Date From:~Tol Hours COde: SUb :PhaSe i: :De~Cripti°n0fOperations i: : i~: ,,, ;;. :;:, :':.: ;: 10/11/2003 00:00- 02:30 2.50 MOVE MOVE MOVE Prep rig for move. 02:30 - 04:00 1.50 MOVE MOVE MOVE Move rig and camp from 2F-08 to 2T-12A 04:00 - 14:00 10.00 MOVE RURD RIGUP MIRU Nabors 3S. BOP test waived by AOGCC Jeff Jones @ 0700 on 10/11/03. 14:00 - 16:00 2.00 WELLSF NUND DECOMP Accepted rig @ 1400 hrs. on 10/11/03. Check annulus and tubing for )ressure. 150 psi on annulus. Call out valve crew. 16:00 - 17:45 1.75 WELCTL COND DECOMP Rig upto circulate through tree. Rig up lubricator to pull BPVto circulate. Pull BPV using APC valve crew. Shoot fluid levels on tbg (2520') and csg (450'). Weight up mud to 10.5# from 10.2#. 17:45 - 20:00 2.25 WELCTL CIRC DECOMP Circulate 10.5 ppg mud down tubing thru GLM @ 2595' and taking returns thru choke and gas buster. Starting tubing press = 1000 psi Ann. press.= 220 psi. Pumped 95 bbls (hole volume) shut dwn. monitor well. 10.5 ppg going in 10.5 out. Tbg press=0 Ann press= 180. Returns gased up. After one hour tbg = 220 ann.= 220. Loaded 130 bbls new mud from Deadhorse 10.4 weighted up to 10.5 ppg. Lost 11 bbls. 20:00 - 22:00 2.00 WELCTL CIRC DECOMP Circulated 10.5 ppg around again 95 bbls. Shut choke and bullheaded 15 bbls to fill tbg with 10.5 ppg. Shut down. Press on both tbg & annulus bled to 0. Loss on this circulation =10 bbls. 22:00 - 00:00 2.00 WELCTL KILL DECOMP :Monitored well. tbg =20 ann= 0. Cleaned up mud and got weight back up to 10.5. Very gased up mud. 10/12/2003 00:00 - 01:00 1.00 WELCTL OBSV DECOMP Continue to monitor well. Tbg = 20 psi Ann = 20 psi 01:00 - 02:00 1.00 WELCTL CIRC , DECOMP Circulated another hole volume + 20 bbls. Getting 10.3 ppg returns with gas cut mud. Shut down monitor well. Loss on this circulation 23 bbls. 02:00 - 03:30 1.50 WELCTL OBSV DECOMP Monitor well. After 1 hr tbg press 0 ann press 0. Not comfortable with continuous gas in mud not having KWM around. Bring MW in pits back up to 10.5 ppg. 03:30 - 04:15 0.75 WELCTL CIRC DECOMP Circulated another hole volume 95 bbls. Gas cut mud returns 9.0 on gravity scales. Each circulation has taken approximately 13 bbls before getting returns. Loss on this circulation = 16 bbls. total losses = 60 bbls. 04:15 - 08:15 4.00 WELCTL OBSV DECOMP Weight up mud and lower YP to 18. Wait on mud from Prudhoe. Annulus on a vac - tubing has positive pressure. 08:15 - 10:00 1.75 WELCTL CIRC DECOMP Started reverse circulation w/10.5# mud - 23 bbls pumped before returns to surface. Averaged 9.8# returns with gas cut mud (balance scale). Total loss this 95 bbl circulation was 27 bbls (87 bbls to formation so far). Tbg and csg on a heavy vacuum. ! 10:00 - 13:00 3.00 WELCTL OBSV DECOMP Monitor well - continues to be on heavy vacuum. Call for slickline unit and seawater truck displace well and set Baker K-3 plug below top GLM. 13:00 - 14:15 1.25 WELCTL CIRC DECOMP Begin reverse cimulation - pumping seawater to displace mud @ 3 bpm. 15.5 bbls pumped to start getting returns. Total of 102.5 bbls lost mud to formation at this point. Halliburton slickliners on location - safety meeting and start to rig up. Continue to circulate to displace mud. Pumped a total of 130 bbls seawater to clean up mud in tubing. Pumped down tubing for 3 bbls to clean mud out in plug setting area. 14:15 - 00:00 9.75 WELLSR PLGM DECOMP MIRU HES to set slipstop/K-2 packoff/slipstop below mandrel at 2595' RKB. Set @ 2623'. Circulated, took 8 bbls to fill hole. Shut choke and press tested tubing and annulus to 500 psi held for ten min. RD HES. 10/13/2003 00:00 - 02:00 2.00 WELCTL KILL DECOMP Rigged up to circulate. Circulated 80 bbls seawater around thru open GLM at 2595. No gas in returns, small trace of oil. Shut down monitor well. Well dead. tbg 0 ann. 0. Blow down lines, prep to set two way check. Printed: 10/17/2003 4:17:16 PM . Legal Well Name: 2T-12 Common Well Name: 2T-12 Spud Date: 5/13/1986 Event Name: WORKOVER/RECOMP Start: 10/11/2003 End: 10/16/2003 Contractor Name: Nabors3sCompanyM@conocop Rig Release: 10/16/2003 Group: Rig Name: Nabors 3S Rig Number: : Date From~To : .. Code 10/13/2003 02:00 - 04:30 2.50 WELCTL BOPE DECOMP Set two-way check. ND tree and marked alignment before removal. 04:30 - 13:00 8.50 WELCTL BOPE DECOMP NU BOPE test rams, choke manifold to 250 / 4000 psi, annular to 250 / 3500 psi. Test witnessing waived by Jeff Jones. 13:00 - 21:30 8.50 WELLSR PLGM DEOOMP Rig up slickline, safety meeting, pressure test to 1000 psi. RIH to equalize Baker K-2 plug w/prong assb. on knuckle joint. RIH to pull slip stop on top of plug. RIH to pull K-2 plug. RIH to pull bottom slip stop. 21:30 - 00:00 2.50 WELLSl; CIRC DECOMP Hook up lines to circulate hole volume from open GLM @ 2595'. Circulate 112 bbls. Monitor well, well was static, remove circulating hoses. Hole was full did not take any losses. 10/14/2003 00:00 - 01:00 1.00 FISH PULL DECOMP Latched onto landing jt. Pulled from PBR @ 60,000 lbs. String weight after pulling out 38,000 lbs. 01:00 - 04:00 3.00 WELLSF PLGM DECOMP R/U HES slickline again. RIH and set plug in GLM @ 2595'. POH and rig down HES. 04:00 - 05:00 1.00 WELCTL CIRC DECOMP Circulate down tubing taking returns to pill pit and sucking off with vac. truck. Circulating from just above PBR @ 4490. Circulated at 2.5 BPM with 500 psi. Getting signs of oil and gas. After pumping 95 bbls well was trying to flow. Shut In monitor well. Called AOGCC and reported well control to Chuck Scheve. 05:00 - 08:30 3.50 WELCTL ClRC DECOMP Continued circulating a total of 424 bbls seawater @ 2.5 bpm rates. Circulated out to clean seawater. Shut down pumps to monitor well. 08:30 - 09:30 1.00 WELCTI. OBSV DECOMP Monitor well after shutdown. Losing 4 bbl/hour while circulating over the top of the hole. 09:30 - 10:30 1.00 WELCTI. OBSV DECOMP Continued monitoring well. Losses have leveled off to 2 bbl/hour. 10:30 - 16:00 5.50 WELCTI. COND DECOMP Begin to condtion mud in pits will bring weight back to 9.0#. Continued circulating over the the top of the hole and monitoring losses that remain at 2 bbls/hour. Loading pipe shed with 4-1/2" tubing and jewelery. Strap and drift the same. 16:00 - 17:30 1.50 WELCTI. CIRC DECOMP Circulate the wellbore to 9.0# mud, pumping down the tbg @ 3 bpm. Initial circ pressure 480 psi. pumped 184 bbls of mud before seeing mud returns (22 bbl loss during circulation. Continued to circulate 9# in and 9# out circ pressure 370 psi. 17:30 - 20:00 2.50 WELCTL OBSV DECOMP Shut down and monitored well in first 30 minutes losses indicate 7 bbl/hour. Continue to monitor well. Build dry job. Pick-up Camco spooling unit and prepare floor for tripping pipe. 20:00-20:30 0.50 FISH ClRC DEOOMP Pump 14bbl 10.9#dry job. 20:30 - 23:30 3.00 FISH PULL DEOOMP POOH w/56 jts 2-7/8" tbg to SSSV. Found joint #2 bent approximately 10' down from collar. E-line had trouble passing this area with tubing punch. Spool up control line on Camco spooling unit. Recovered 31 of 31 control line bands. LD SSSV with 6' pup jt on top. Tubing is in good shape. Bent one joint breaking it out. 23:30- 00:00 0.50 FISH RURD DEOOMP RD Camco spooling unit. LD SSSV off floor. 10/15/2003 00:00 - 04:00 4.00 FISH PULL DECOMP Continue POOH laying down 2-7/8" tubing, 2 2-7/8" x 1" GLM, 1 2-7/8" x 1.5" GLM and Baker seal assembly. Corrosion pit on top of GLM#2. Otherwise GLM's look to be in good shape. Small amount of scale on tubing beginning with joint below GLM #2. Amount of scale increased !on tubing below GLM #3. Bottom 3 joints and 6' pup above seal assembly were corkscrewed. Hole fill was 26 bbls more than calculated for trip out of hole. 04:00 - 05:30 1.50 FISH RURD DECOMP RD 2-7/8" handling equipment and remove from floor. Unload 2-7/8" !tubing out of pipe shed. 05:30 - 06:30 1.00 CMPLTN RURD CMPLTN :Load 4-1/2" jewelry in pipe shed. RU 4-1/2" handling tools. 06:30 - 06:45 0.25 CMPLTN PULD CMPLTN PU Baker seal assembly and set in slips. PU 1 joint tubing. Attempt to Printed: 10/17/2003 4:17:16 PM ' hillips Alaska page :: ~ :: :onocop : C ;3:of 3: : : · : oPerationS:SummarY RepOrt' : .:.. ' Legal Well Name: 2T-12 Common Well Name: 2T-12 Spud Date: 5/13/1986 Event Name: WORKOVER/RECOMP Start: 10/11/2003 End: 10/16/2003 Contractor Name: Nabors3sCompanyM@conocop Rig Release: 10/16/2003 Group: Rig Name: Nabors 3S Rig Number: :; Date. i ;;::::FrOmm;To ROurs Code ~oUclbe Phase i ; DeScriPtiOnOfOP~rati0ns ; 10/15/2003 06:30- 06:45 0.25 CMPLTN PULD CMPLTN make up tubing. Could not get 4-1/2" tongs around pipe. 06:45 - 07:15 0.50 CMPLTN RURD CMPLTN RD 4-1/2" tongs. RU 7-5/8" tongs with 4-1/2" dies. 07:15 - 16:45 9.50 CMPLTN RUNT CMPLTN Trip 4-1/2" completion string in the hole. Hole losses pretty constant at 1.75 bbl/hour. Rigged up to pump down the tbg. 16:45 - 17:15 0.50 CMPLTN CIRC CMPLTN Circulated @ 2 bpm, circ pressure 200 psi. Circulated for app: 10 bbls. S/D pump and bled tubing pressure back to 0 psi. 17:15 - 17:35 0.33 CMPLTN SOHO CMPLTN Lowered the tubing down and saw seal assembly enter PBR lowered it down 10 more feet the full length of the seal assembly and tagged up with the Iocator. Pressured up on the tubing to 500 psi confirming seal assembly is landed, bled tubing pressure back to 0 psi. Pipe weights 65k up and 49k down. 17:35 - 18:15 0.67 CMPLTN CIRC CMPLTN Pulled tubing back up 12' and circulated bottoms up (84 bbls) with 9.0# mud @ 2.5 bpm, circulating pressure 250 psi. 18:15 - 19:30 1.25 CMPLTI~ SOHO CMPLTN Picked up pups and hanger installed same in completion string per space out. Postioned seal assembly app: 17' above PBR for circulation of seawater. 19:30 - 20:30 1.00 CMPLTN CIRC CMPLTN Begin pumping seawater down the tubing to displace 9.0# mud out of hole. Pumped 200 bbls. Returns clean. SD pump. 20:30 - 21:30 1.00 CMPLTI~ CIRC CMPLTN RU to pump corrosion inhibited seawater. Pump 12 bbls seawater with 11 gal corrosion inhibitor. Displace with 65 bbls seawater. Left 3 bbls inhibited fluid in tubing. 21:30 - 22:00 0.50 CMPLTN SOHO CMPLTN Drain BOP stack. RIH with hanger on landing joint. Land hanger in tubinghead. RILDS 22:00 - 23:00 1.00 CMPLTN DEQT CMPLTN RU to test annulus. Pressure test 4-1/2" x 7" annulus to 1500 psi. Lost 10 psi in 15 min. Pressure up to 2400 psi and shear SOV in GLM #3. RD test equipment. 23:00 - 00:00 1.00 WELLSR PLGM CMPLTN Ready to run 2-way check in well. Cannot find T-bar. Search location to no avail. Call around to locate our T-bar or another one that will work. Valve crew has extensions that will work with Cameron's 10' T-bar. Wait on valve crew to deliver extensions. 10/16/2003 00:00 - 00:45 0.75 WELLSR PLGM CMPLTN Wait on APC to deliver extensions for Cameron T-bar. 00:45 - 01:15 0.50 WELLSR PLGM CMPLTN Set 2-way check in hanger profile. 01:15 - 03:45 2.50 CMPLTN RURD CMPLTN Flush all lines, choke manifold, and gas buster with fresh water. Function BOP's. Flush stack with fresh water. Remove mud from pits. 03:45 - 10:30 6.75 WELCTL NUND CMPLTN Pump fluid out of stack. Blow down lines. ND BOP stack. Cleaning pits. 10:30 - 11:45 1.25 WELCTL NUND CMPLTN NU tree and continue to clean pits. Lined wing valve up with existing flowline. 11:45 - 13:00 1.25 WELCTL NUND CMPLTN Pressure tested Pack-Offs to 5000 psi. Tested tree to 5000 psi. Pulled 2-way check and prepared to pump diesel freeze protection. 13:00 - 16:00 3.00 WELLSI; FRZP CMPLTN Make-up pump in & u-tube manifold. Circulated 80 bbls of diesel down IA @ 2 bpm, initial circulating pressure 800 psi and final circulating pressure 1300 psi. S/D pump and u-tubed diesel from IA back iinto the tubing. Wellbore freeze protected w/diesel tubing & IA down to 2350'. Tubing has 150 psi and IA has 150 psi. 16:00 - 17:00 1.00 WELLSI: PLGM CMPLTN Picked up Lubricator and installed BPV. Secured well and lay down lubricator. 17:00 - 20:00 3.00 MOVE RURD CMPLTN Blow down pump, lines, and associated equipment. Prepare for RD and rig move. Completed cleaning the pits. Release Rig @ 20:00 hrs - Printed: 10/17/2003 4:17:16 PM TUBING (0-4491, OD:4.500, ID:3.833) XO ,'4491-4493, 0D:5.210) TUBING :449,~-4587, OD:2.875, ID:2.441) TUBING ,4587-6375, 0D:2.375, ID:1.995) SOS ',6374-6375, 0D:2.375) Per[ ',6413-6448) ConocoPhillips Alask.a, Inc. 2T-12A APl: 501032006601 SSSV Annular Fluid: Reference Last Ta 6421 10/23/2003 - ALL STRINGS CONDUCTOR Size 16.000 Well T PROD 7/14/1986 Last W/O: 10/16/2003 TD: 6734 ftKB Max Hole An( Top 0 SUR. CASING 9.625 0 PROD. CASING 7.000 0 LINER 5.000 4704 Size Bottom KRU 4.500 0 4491 2.875 4491 4587 2.375 4587 6375 2T-12A Rev Reason: WORKOVER 10/27/2003 KBMG ii~: ~EWEERY PBR BROWN PACKER BROWN 'HB-I' NIP AVA BPL PORTED NIPPLE PACKER BAKER 'DB' NIP CAMCO 'D' NIPPLE~ NO GO SOS BROWN Description ':, JEWELRY. (ADDED'WITH WORKOVER) .... :" ": .' '.. Description HANGER TUBING HANGER set 10/16/2003 NIP CAMCO 'DB' LANDING NIPPLE set 10/16/2003 NIP CAMCO 'DB' LANDING NIPPLE set 10/16/2003 XO CROSSOVER set 10/16/2003 LOCATOR LOCATOR SUB set 10/16/2003 SEAL 80-36 SEAL ASSEMBLY set 10/16/2003 KBG-2 KBG-2 KBG-2 ProductiOnMandrels/Values. · .... :: Man Type Interval TVD Zone Comment 6310 - 6339 5839 - 5865 C-4 3 3/8" Casing HyperJ, 60 6413 - 6448 5931 - 5962 A-4,A-3 3 3/8" Casing HyperJ, 60 GaS'Lift..Mandr~ls/ValVes''. ...... .". · · ." · ..... .' ".' · ........ Man Type Bottom TVD Thread 110 110 2891 2813 47O4 4388 6725 6205 i drifted ~: 3,853% remaining;3~833,,)::: ~ ,: TVD I Wt J Grade J Thread 4204 112.601 L-80 I IBT - New 4287 I 6.50 I J-55 J EUE 8RD AB-MOD -Old 5897 J 4.70 J J-55 J EUE8RDAB-MOD-OId DEPT. OF NATURAL RESOURCES DIVISION OF OIL AND GAS April 12, 1991 D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kupamk River Unit 2T Well Data ! WALTER d. HICKEL, GOVERNOR P.O. BOX 107034 ANCHORAGE, ALASKA 99510-7034 PHONE: (907) 762-2553 .. :, ,,-5:,aou · · - .... ~ b .","f' .._ -. . ' ',".--~: ~., ~! T~. . Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kuparuk River Unit 2T wells. The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and 17 wells were granted extended confidentiality until 90 days after the unleased land in T11N R7E Umiat Meridian could be offered for lease. The unleased land in this township was offered for lease in Sale 70A which was held on January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and the well data should be released on April 30, 1991. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the above listed wells. Sincerely, (J~1.mes E. Eason 121rector cc: J. L. Dees, ARCO Alaska Inc. RECEIVED APR 1 6 199t Alaska.0il & Gas Cons. Commission Anchorage ~:.~ p~,r,(eu o~ r~;c'/c:ed paper DEPAI~T~iENT OF NATUI~AL I~ESOUI~CES August' 5, 1988 Jon Wood, Area Landman ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wood: In your July 8 letter and in our August 3 meeting, you requested extended confidentiality for the data from the Kuparuk River Unit "drill$tte 2T" wells. You indicated that reports and information from these wells contain significant information relating to the valuation of unleased land in Township ll North, Range 7 East, U.M. This unleased land is currently scheduled to be offered for lease in Sale 70A in September 1989. Following your written request, the August 3 meeting and further review of the well data by my staff, I agree to extend the confidentiality of the data from the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, lO, ll, 12, 12A, 13, 14, 15, 16 and 17 wells. The data from these wells will be released after the aforementioned land is offered for lease. In your letter and supporting data, you requested confidentiality for data from a "2T-16A" well. The Alaska Oil and Gas Conservation Commission (AOGCC) has advised the division that they have no record of a "2T-16A" well. The 2T-16 well was side-tracked but no new number was assigned to the well. Therefore, all of the data from the well are filed under 2T-16 at AOGCC. The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988) and the last 2T well release date is the 2T-8 Well (January 15, 1989). The division is making a special exception to our policy of considering extended confidentiality no sooner than 90 days prior to a release date because it is prudent to, in this case, grant the extension of confidentiality for the 2T wells as a group. By copy of this letter I am requesting that AOGCC keep confidential the data from all of the Kuparuk River Unit 2T wells until further notice. Sincerely, ames E. Eason i rector cc: C.V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR i i I I ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 11, 1987 Transmittal # 5933 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-16 2T-12A 2A-11 3A-9 lA-1 3A-9 1H-3 3K-13 3K-14 3I-1 3F-15 CET/CEL 9-15-86 8181-8720 CET/CEL 9-27-86 4595-6644 CET/CEL 3-14-86 5800-6564 CET 7-26-86 2000-6299 CEL/CET 8-29-86 2708-7255 CET/CEL (After Squeeze) 7-31-86 2128-6039 CET 7-16-86 6891-7617 CET/CEL 8-17-86 6849-8455 CET/CEL 8-18-86 7215-8844~ CET/CEL 1-24-86 7588-8887 CET/CEL 1-13-86 6600-7384 CONFIDENTIAL INDE ITELY Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil ~SAPC ! :ib7u 0 ~ate: Unocal Yault (£~1~) . Chevron ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfleldCompany STATE OF ALASKA ALASKA UiL AND GAS CONSERVATION CO~v~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] · , , . , 2. Name of Operator ...................... 7. Permit Number ARCO Alaska, Inc. 86-12~ 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20066-01 4. Location ~f well at surface 9. Unit or Lease Name 102' FSL, 556' FWL, Sec. 1, T11N, R8E, UM ...KupDruk River.U.n~t At Top Producing Interval 10. Well Number 947' FNL, 1063' FEL, Sec. 11, TllN, R8E, UN 2T-12A At Total Depth 11: ~,i~d a~d Pool 1081' FNL, 1205' FEL, Sec. 11, T11N, ESE, UM '' ' Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc,) ~ 6. Lease Designation and Serial .... - ~uparuk River 0i ] Pool 117'RKB~ ADL 25569 ALK 2667 ~'~ "~2. Date Spudded 13. Date T.D. Reached 1¢. Date COmp., susp. 0r A~a~d:TM J~l S: Wa~er Depth, if offshore 'i6. N0. ~f completions 07/11/86 J~2/08/86' ~ N/A feet MSL 07/06/86 [ ~ 1 "20. Depth where Sssv' ~et' 17. Total Depth (MD+TVD) 18. P'l~g Ba'ck bepth ('M~D) 19. DirectiOnal Survey 21~' Thick'ness of permafrost 6725'MD, 6205'TVD .... 6640'MD. 6131 'TVD YES ~ NO U. { ~785' .... fee~.MO . .[ .... 1550'...(.Approx) . 22. Type Electric or Other Logs Run CET,GYRO,DIL/GR~sP/SFL, Cal, ..FDC/CNL 23. CASING, UINER'AND CEMENTING RECORD ..... SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE ~OP . , BOTTOM HOLE SIZE CEMEN~ING.RE~O~ AMOUNT PULLED.. ~ 9-5/8" ,,.36.~¢ , J:55 ~urf 2891' 12-1/~" 900 sx AS I I! & 300 sx :lass C , . . ~ 7" 26.0~ J-55 Surf 4925' 8-1/2" 600 sx Class C & 175 sx 5" .. 18.0~ 5-1~0 ... ~704~ 6725' ..6-1/8" 225 sx Class G Squeeze liner lap w/150 sx Class C ,, . 24. Perforations open to Production (MD+TVD of Top and Bottom and .~:.. TUBING RECORD . , , interval, size and number) SIZE . . DEPTH SET (MD) ~PA~KER SET {MD.) ~:: 6310~-63~9~ND w/~ spf~ 60~ phasing 2-7/~" ~75~ ~508~ 6~1~ ~-6~8 ~ND ~ ........... 26. ACID, FRAC'TURE, CEMENT SQUEEZe, ETC. r ......... 5838'-5864'TVD DEPT~ INTERVAL (~D) ' AMOuN~ & K'IND'oF MA~RIAL USED 5931 ~-5962 ~TVD .......................... 27. PRODUCTION TEST Date~rst Production Method of Operation (Flowing, gas lift, etc.) I ....... '"bate of Test Hours Tested PRODUCTION FOR bI~':B~'L GAs-M~F WA~'R-BBL CHO~E ~¢~E J GA~.01L RATIO ' II ~EST PE~J, OD ~ ....................J Fl°~'~ubi~g Casing Pressure CALCULATED OILIBBL GAS-MC~ WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. ' ............. CORE DATA ............................. Brief description ~f lithology, porosity, fraCtures, apparent dips and presence of oil, gas or water. Submit core chips. ' ' None . .............. jf'~'4 *Note: Drilled RE 07/14/86. Well perforated & tubing ran 10/01/86, ...................................... Form 10-407 WC1:178: DAN i Submit in duplicat~/ Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 3O. /. GEOLOGIC MAi-~KE~S FORMATION TESTS , , , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VENT. DEPTH GOR, and time of each phase. Top Kuparuk C 6308' 5836' N/A Base Kuparuk C 6342' 5867' Top Kuparuk A 6396' 5915' Base' Kuparuk A 6502' 6009' .: ___ 31. LIST OF ATTACHMENTS Addendum (dated 12/15/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~/~i~ _)~~'~/~-J Title Associate Engineer Date J'5-'~'7 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log. on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental ~ecords for this well shou,l~ show the details of any multiple stage cement- ing and'the location of the cementing to°l. " ; · ~ Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 2T-12A 12/08/86 Frac'd Kuparuk "A" sand perfs 6413'-6448' in five stages per 11/19/86 and 11/26/86 revised procedure using Musol, diesel, gelled diesel & 20/40 sand. Press'd ann to 2300 psi w/diesel. Tst lns to 8000 psi; OK. Stage #1 & #2: Pmp'd 30 bbls diesel w/5% Musol & 33 bbls diesel @ 2 BPM, 3200 psi. SI overnight. Stage #3: 27 bbls gelled diesel, 5 BPM, 3610 psi Stage #4A: 7 bbls gelled diesel w/8 ppg 20/40 mesh sand @ 5 BPM, 3490 psi Stage #4B: 20 bbls gelled diesel w/8 ppg 20/40 mesh sand @ 20 BPM, 5160 psi Stage #5: 32 bbls gelled diesel, 6300+ psi @ 20 BPM. Dropped pmp rate to ±15 BPM, 6150 psi. Well started screening out. Pmp'd 6048# in formation leaving 672# sand in tbg & csg. Underflushed by 2 bbls as per procedure. Load to recover 142 bbls of diesel. Job complete @ 1200 hrs, 12/8/86. CONFIDENTIA[ INDEFINITELY Drilling Supervisor ' Date CONFIDENTIAL SUB-SURFACE DIRECTIONAl. SURVEY J~JUIDANCE j~'J ONTINUOUS Cf iDOL Company ARCO ~LASKA? INC. Well Name ,, 2T-12A (102' FSL,~ 556' FWL~ SEC lrTI,IN~R8E,UM) Field/Location KUPAURK~ NORTH SLOPE, ALASKA Jo13 Reference No. 71750 MCBRIDE Date 27-SE?-86 Computed By: HALSTEAD ~r~NiU :NOII~M~d~INI NO!I~I~WOD ~C 5CO~I~W ~qN!l~I] A'A~N$ ]¥NOIiD.~blO IDD CCMPUTATiGN 2AT~: 14-OCT-Sb PAGE 1 ARC3 ALASKA, iNC. 27-12A KUPARUK NORTH SLOPE,ALASKA MEASURED DEPTH 0.00 lO0.O0 2O0.0O 300.00 400.00 500.00 600.00 700.00 400.00 900.00 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3OOO 3100 3200 3300 3400 3500 3600 3700 3800 3900 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .3 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 iNTERPOLATED VALUE.S FOR EVEN 100 FEET TRUE SUB-SEA COURSE VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEG MIN DEG MIN VErTiCAL SECTION FEET 0,00 -117.00 0 0 N 0 O 100.00 -17,00 0 18 N 78 22 200,00 83,00 0 22 N 299,99 182,99 0 28 N 27 55 399.99 282.99 0 37 N 5 6 499.96 382.98 0 36 N 4 4 599.98 432.98 0 51 N 27 44 E 699 96 582 95 ! 1 N ~3 24 799.95 682.95 0 57 N 16 14 899.93 782.93 0 59 N 24 47 0.00 -0.27 -0.77 -1.17 -1.99 -2.57 -3,55 -4.98 -6.34 -7.65 999.91 882.91 1 14 N 33 20 1099.88 982.88 1 19 N 30 44 1199.86 1082.86 1 12 N 28 36 1299.84 11~2.84 1 13 N 29 28 1399.82 1282.82 1 30 N 35 49 1499.77 1382.77 1 46 N 30 34 1599.72 1482.72 1 23 N 24 26 1699.70 1582.70 1 5~ S 81 22 1799.47 1682.47 5 47 S 52 32 1895.46 1781.46 !0 9 S 49 6 -9.45 -11.51 -13.54 -15.37 -17.53 -20.18 -22.88 -22.84 -16.45 -2.60 1996.49 1879.49 11 ~7 S 50 45 W 2094.25 1977.28 12 36 S 5,3 47 W 2191.56 2074.56 1~ 42 S 50 58 ~ 2287.23 2170.23 19 14 S 52 48 W 2380.49 2253.49 21 59 S 53 30 W 2473.00 2356.00 23 19 S 53 34 W 2563.35 2446.35 27 22 S 56 31 ;, 2650.~0 2533.60 31 0 S 59 52 W 2735.42 2613.42 32 12 S ~1 1 W 2820.19 2703.19 31 ~7 S 6~ ~2 W 16.98 37.78 60.79 125.63 1~3.52 206.28 255.07 307.92 3~0.83 2905.05 2785.05 32 13 S 5~ 2989.60 2~72.60 32 9 S 59 3074.43 2957.43 31 46 S 58 315'9.89 3042.89 31 4 S 58 3245.24 312~.24 31 34 S ~0 3330.59 3213.59 30 56 S 6!3 3416.85 3299.85 29 50 S 61 3503.99 3386.99 2~ 51 S 51 3591.96 347~.96 27 59 S 6i 3680.65 3563.65 27 5 S 52 57 W 413.64 5 'w 466.97 6 W 519.90 6 W 571.81 36 W ~23. B7 ¢6 W 67c 35 2 W 726.31 21 W 775.22 57 W 822.62 26 W 858.61 DAT: OF SURVEY: 27 SEP 86 KELLY ~USHING ELEVATION: l17eO0 FI' ENGINEER: MCBRIDE CF MEASURED DEPTH DOGLEG SEVERITY OEG/IO0 RECTANGULAR NORTH/SOUTH mEET COORDINATES E~ST/WEST FEET .00 .39 .21 .38 .51 .28 .42 .11 .19 .48 0,00 N 0,07 S 0.35 N 0.93 N 1.93 N 3.01 N 4,14 N 5.68 N 7.34 N 8.89 N 0,00 0.37 0,70 0,76 1,12 1,10 1,55 2.25 2.78 3.34 .36 .07 .35 .06 .52 .1~ .45 .79 .0~ 10.56 12.53 14.50 16.30 18.23 20.72 23.36 24.36 21.18 12.07 4.40 5.58 6.71 7.72 9.04 0.59 2.09 1.39 5 · .B 3 4.76 .40 .30 .85 .79 .30 .52 .25 .43 .35 .6S 0.55 13.73 28.35 46.25 67.82 90.39 115.11 140.68 166.60 192.39 1 3 5 7 I0 13 17 21 25 30 9.90 6.15 4.07 6.35 5.75 6.28 1.20 2.77 8.96 5.31 .72 .47 .17 .32 .60 .09 .06 .27 .93 .59 218.52 245.67 273.14 300.77 327.38 352.74 377.27 400.95 423.52 445.08 351.31 397.27 442.55 426.51 531.30 576.82 621.06 664.01 705.88 746.72 HORIZ. DIST. FEET DEPARTURE AZIMUTH DEG MIN 0,0'0 N 0 0 E 0,37 S 79 45 E 0,78 N 63 32 E 1.24 N 37 48 E 2,23 N 30 0 -f 3,21 N 20 4 5 4.42 N 20 28 6.10 N 21 35 ~ 7.85 N 20 46 r 9.49 N 20 34 E 11.44 13.71 15.97 18.04 20.35 23.26 26.30 25.89 21.97 12.98 N 22 37 5 N 23 59 E N 24 50 ~ N 25 20 E N 26 23 E N 27 4 ~Z N 27 21 E N 25 3 E N 15 22 ~ N 21 31W 413.73 S 58 7 W 467.10 S 58 16 W 520.05 S 58 19 w 571,97 S 58 16 w 624.06 S 58 21 w 676,12 S 58 33 W 725.67 S 58 43 W 775.67 S 58 52 W 823.19 S 59 2 w 869.30 S 59 12 ~ 19.91 S 88 24 W 38.56 S 59 12 61.06 S 62 19 89.70 S 58 57 125.63 S 57 19 W 163.53 S 56 26 206.30 S 56 5 W 255.07 S 56 3I 307.92 S 57 14 350.87 S 57 46 W COMPUTATION DATE: 14-~CT-86 PAGE 2 ARCO ALASKA, INC. 2T-12A KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR TR MEASURED VERT DEPTH DE UE SUB-SEA COURSE ICAL VERTICAL DEVIATION AZIMUTH PTH DEPTH DEG MIN DEG MZN 4000.00 376 4100.00 385 4200.00 394 4300.00 403 4400.00 412 4500.00 421 4600.00 429 4700.00 438 4800.00 447 4900.00 455 9.95 3652.95 26 36 S 62 36 W 8.91 3741.91 27 36 S 61 53 W 7.50 3830.50 27 38 S 60 25 W 5.89 3918.89 28 10 S 56 30 W 3.79 4006.79 28 52 S 54 57 W 1.00 4094.00 29 37 S 54 41 W 7.65 4180.65 30 12 S 54 45 W 4°06 4267.06 30 10 S 54 36 W 0.20 4353.20 31 0 S 5~ 40 W 5.50 4438.50 31 53 S 52 56 W 5000.00 464 5100.00 472 5200.00 481 5300.00 490 5400.00 499 5500.00 5O9 5600.00 518 5700.00 527 5800.00 537 5900.00 546 0.73 4523.73 30 24 S 55 41 W 8.32 4611.32 27 40 S 60 12 W 7.58 4700.58 25 50 S 52 28 W 8.16 ~791.!6 24 12 S 58 25 W 9.97 4882.97 22 41 S 55 28 W 2.86 4975.86 21 11 S 54 47 W 5.92 5068.92 21 51 S 54 2 W 8.52 5161.52 22 32 S 52 41 W 0.90 5253.9C 22 28 S 51 35 W 3.40 5346.40 22 20 S 50 45 W 600O.O0 555 6100.00 564 6200.00 573 6300.00 582 6400.00 591 6500.00 600 6600.00 609 6700.00 018 6725.00 620 5.75 5~38.76 22 37 S 49 31 w 7.77 5530.77 23 38 S 46 28 W 8.96 5621.96 24 53 S ~7 50 ~ 9.25 5712.25 26 4 $ 47 3 W 8.65 5801.65 20 5~ 5 46 39 W 7.63 5890.63 27 3C S 46 14 ~ 5.85 5978.55 29 17 S 45 1~ W 2.93 ~0~5.93 25 27 S 46 10 ~ 4.70 6087.70 29 27 S 46 10 4 DATE OF SURVEY: 27 SEP 86 KELLY BUSHING ELEVATION: 117.00 PT' ENGINEER: MCBRIDE EVEN I00 FEET OF MEASUREO VEqTICAL DOGLEG RECTANG SECTIGN SEVERITY NGRTH/S FEET DEG/IO0 FEET DEPTH 913.39 0.89 465.7 958.86 0.86 486.9 1005.11 1.34 509.2 1051.86 1.74 533.6 !099.51 1.13 560.7 I14~.41 0.75 588.9 119~.30 0.45 617.7 124~.59 0.63 646.~ 1299.33 1.!1 676.2 1351.46 3.69 706.7 1403.64 3.86 738.0 1451.82 3.01 763.7 1496.73 !.5 1538.95 3.55 805.4 1578.59 1.87 827.3 1615.39 0.42 848.5 1652.13 0.69 869.7 1689.84 0.72 892.3 1727.99 0.11 915.8 1765.79 0.86 939.5 ULAR COORDINATES' HORIZ. DEPARTURE OUTH EAST/WEST DIST. AZIMUTH FEET FEET DEG MIN 5 S 786.70 w 914.23 S 59 22 W 5 S 827.15 W 959.85 S 59 30 W 6 S 867.83 W 1006.21 S 59 35 W 7 S 907.71 W 1052.97 S 59 32 W ! S 946.~6 W 1100.52 S 53 22 W 9 S 986.91 W 1149.30 S 59 10 W 9 S 1027.68 W 1199.08 S 58 59 ~ 8 S 1068.75 W 1249.27 S 58 '4~ ~ 3 S 1110.19 W 1299.92 S 58 39 W 1 S 1152.55 W 1351.97 S 58 29 W 9 S 1194.38 W 1404.04 S 58 17 W 4 S 1233.17 W 1452.22 S 58 16 W 0 S 1274.93 W 1497.22 S 55 22 ~ 2 S 1312.01 W 1539.51 S 58 2'7 W 5 S 1345.02 W 1579.12 S 58 24 W 0 S 1375.41 W 1616.08 S 58 19 W 9 S 1~05.15 W 1652.57 S 58 14 ~ 3 S 1435.48 W 1690.22 S 58 8 W 2 S 1465.71 W 1728.30 S 58 0 W 9 $ 1495.34 W 1766.03 S 57 51 W 1503.86 0.62 964.13 iB42.64 1.07 989.89 1953.18 1.50 1017.28 1925.59 1.37 1046.36 ~96~.5~ 0.39 1077.02 2014.57 1.03 1108.49 2060.89 ~.27 1140.82 2109.18 0.00 1174.85 2121.26 0.00 1183.36 S 1524.76 W 1804.03 S 57 41 W S 1554.29 W 1842.74 S 57 30 W S 1584.82 W 1883.22 S 37 18 W S 1616.50 W 1925.60 S 57 5 W S 1649.16 W 196~.59 S 56 51 W S 1582.21 W 2014.59 S 55 37 W S 1716.43 W 2060.97 S 56 g3 W S 1751.90 W 2109.37 S 56 9 ~ S 1760.77 W 2121.47 S 56 5 W ARCO ALASKA, INC. 2T-12A KUPARUK NORTH SLOPE,ALASKA COMPUTAT~QN OATE: 14-0CT-S6 PAGE 3 DATE OF SURVEY: 27 S=P 86 KELLY BUSHING ELEVATION: 117.00 Fl' ENGINEER: HCBRIDE INTERPOLATED VALUES FOR EVEN lOOO FEET OF MEASURED OEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZiMUTm DEPTH DEPTH DEPTH D'EG MIN DEG MIN 0.00 0.00 -li7.00 0 0 1000.00 999.91 882.91 1 14 2000.00 1996.49 i879.49 11 47 3000.00 2905.05 2788.05 32 13 4000.00 3769.95 3652.95 26 36 5000.00 4640.73 4523.73 30 24 6000.00 5555.76 5438.76 22 37 6725.00 6204.70 6087.70 29 27 VERTICAL DOGLEG RECTANGULAR COORDINATES HORiZ. OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN N 0 0 ~ 0.00 N 33 20 ~ -9.45 S 50 45 W 16.98 S 59 57 W 413.64 S 62 36 l~ 913.39 S 55 41 ,~ 1403.64 S 49 31 W I~03.56 S' 46 !O W 2121.26 0.00 0.36 0.40 0.72 0,89 3,86 0.62 0.00 0.00 N 0.00 E 0.00 N 0 0 E 10.56 N 4.40 E 11.44 N 22 37 E 0.55 S 19.90 W 19.91 S 85 24 ~ 218.52 S 351.31 W 413.73 S 58 7 ~ 4.55.75 S 786.70 ~ 914.23 S 59 22 W 738.09 S 1194.38 W 1404.04 S 58 17 W 964.18 S 1524.76 W 1804.03 S 57 41 1183.36 S 1760.77 W 2121.47 S 56 5 OC,~OOC~OC~OOC.~ 0o00000000 · · · · · · · · · · 0000000000 0000000000 c~O00000000 ZZZZZZZZZZ ZZZZZ~Z~ZZ ITt IT1 Ili rtl Ffl fll ITl ITl m m riln;r rfJ zr-- rTl i'it Z 0 0 f~ C-) I · · · · c~ c..D oo k-, l.~ i--~ i.-.~0 · · · · · · · · · · · · -,400---4 H tit 'l~ I Ill FFI FTi Z r- .-.4 G-~ r- H O, ARCO ALASKA, INC. 2T-12~ KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUP~RUK A BASE KUP'ARUK A PBTD TD C~MPUTATISN O.~TE: 14-0CT-86 INTEqPDLATEO VALUE~ FGR. CHOSEN HORIZONS MEASURE~ DEPTH ~ELOW KB FR3~ ORIGIN: 102' FSL, TVS KB SU~-SEA 6308.00 5835.43 ~719.43 6342.00 5866.89 5749.89 6396.00 5915.09 5778.09 6502.00 6009.41 5592.41 6640.00 6130.69 6013.69 6725.00 6204.70 6057.70 PAGE 6 OATE OF SURVEY: 27 SEP 86 KELLY BUSHING ELEVATION: 117.00 ENGINEER: MCBRIDE SURFACE LOCATION 556' FWL, SEC 1, TllN, RBE, UM RECTANGULAR COORDINATES NORTm/SDUTH EAST/WEST 1048.75 S 1619.08 W 1059.07 S 1630.11 W 1075.77 S 1647.84 W 1109.13 S 1682.87 W 1154.42 S 1730.51 N 1183.36 S 1760.77 W FT~ COMPUTATION gATE: 14-CCT-86 PAGE 7 ARCO ALASKA, INC. DATE DF SURVEY: 27 SEP 86 2T-12A KUPARUK NORTH SLOPE,ALASKA' KELLY BUSHING ELEVATION: ENGINEER: MCBRIDE 117.00 MARKER SRIGiN: 102' FSL, MEASURED DEOT~ TVD BELOW KS FROM KS SU~-SEA 556 ' S FWL, RECT NOR URFACE LOCATION AT S:C~ 1, TllN, RS;, UM ANGULAR COORDINATES TH/SOUTH EAST/WEST TOP BASE TOP BASE PBTD TD KUPARUK C KUPARUK C KUPARUK A KUPARUK A 6308.00 5B36.~3 5719.42 6342.00 5866.89 5749.89 5396.00 5915.09 5798.09 6502.00 6009.41 5:592.41 6640.00 6130.69 6013.69 6725.00 6204.70 60~7.70 10 10 10 11 11 11 ~8.75 S 1619.08 59.07 S 1630.11 75.77 S 1647.84 09.13 S 1682.87 54.42 S 1730.61 83.36 S 1760.77 FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DaPTH DEPTH HORIZONTAL DEPARTURE OiSTaNCE AZIMUTH FEET DEG MIN 6725.00 6204.70 60'97.70 2121.47 S 56 5 M SCHLUME~EROER 0 1RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. 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[-..+...~...-F.-~---¢---~-¢...¢-,..¢...~...~-¢..+-¢.--[..-~-~ ...... ¢.--.F..¢--.¢-+.-4---~-¢----~ ........ ;....~-.¢.-..b+4....~...¢....~..- .... ~.,.~ :::~ :::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::: 236, II PROJECTION ON VERTICAL PLANE 236. - SS. SCALED IN VERTICAL BEP'fHS HORIZ SCALE = I/SO0 IN/FT Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. 'OFERATOR;* WE~L NAME '~D N~ER , ~ ~,=~ ~ Reports and Materials to be received by:Date ~,. Required Date Received Remarks COmpletion Report Well History ..... S amp 1 e s Mua ~og ,, ,~0 ......... ~ d/ ,, ~ ~ ........ Core Chips ~(-"'"~ ...... ~' OK , ., . , , .... r~ , ,, ,, ,, Core Description Registered Survey Plat .................... ~ U.-:~" ~':~' .... ~,, Inclination Survey ,,,~'~ aK , , , Directional Survey Drill Stem Test Reports .............. ~=oau~tio~ r~s~ ~po=t,, Log Run .... ,.~ /~,,~P~-~g ..... O~ ,, Digitized Data ~ (0 ~:',,',~ ...... ................. ARCO Alaska, Inc. Post Office I~ux 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 2, 1986 RETURN TO- ARCO ALASKA, INC. ATTN' Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5844 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Openhole Finals (1 bluel ine of each unless otherwise specified) m~?T-I~5" DIL 7-12-86 4915-6728 5" FDC Porosity 7-12-86 4915-6702 ~5" FDC Raw 7-12-86 4915-6702 '~Cyberlook 7-12-86 6100-6600 2" FDC Porosity 7-12-86 4915-6702 "'"2" FDC Raw 7-12-86 4915-6702 ~"~2" DIL 7-12-86 4915-6702 'C~2T~5" FDC Porosity 7-21-86 5" DIL 7-21-86 ~x"~" Caliper Profile 7-21-86 ~2" DIL 7-22-86 ~"'-5" GR thru casing 7-21-86 5" FDC Raw 7-21-86 ' 2" GR thru casing 7-21-86 Cyberlook 7-21-86 2" FDC Raw 7-21-86 2" FDC Porosity 7-21-86 Receipt Acknowledged' Distribution' 5100-7624 2982-7650 2982-7636 2982-7650 100-2982 5100-7624 100-2982 2982-7656 5100-7624 /~--'~ Alaska Oil & Gas Cons. Commission x/ /// Date: Anchorage. NSK Drilling S~ ate ~ f ~Al. la:sk ~.{-~ !i~it i~ ~:~a~:)!.~ L. Johnston (vendor pkg) TKKW' pg' 0040 (MF) Vault (film) 'AL CONEIDENll Rathmell D&M ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ALA ~, OIL AND GAS CONSERVATION COl .SSION REPORTOF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate~ Pull tubing ~ Alter Casing [] Other:~;: Com_p'lete 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc· RKB 117' Feet 3. Address 6. Unit or Property name P.0. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 7. Well number 102'FSL, 556'FWL, Sec.1, T11N, R8E, UM 2T-12A At top of productive interval 8. Approval number 947'FNL, 1063'FEL, Sec.11, T11N, R8E, UM 302 , At effective depth 9. APl nt~r~)e_r20066_01 1052'FNL, 1175'FEL, Sec.11, T11N, R8E, UM 50-- At ltSt8a,~ l:::l¢l~t/Lh lQ. Pool , 1205'FEL, Sec.11, T11N, R8E, UN r~uparuk River Oil Pool 11. Present well condition summary Total depth: measured 6725'MD feet Plugs(measured) cmt plug from 6150' - 6669' true vertical feet 6205 'TVD Effective depth: measured feet Junk (measured) true vertical 6640 'MD feet Mi 11 ed wi ndow f/4909 ' - 4925 6131 'TVD Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 225 sx CS II 1lO'MD 110'TVD Surface 2858' 9-5/8" 900 sx AS Ill & 2891 'MD 2812'TVD 300 sx Class G Production 4893' 7" 600 sx Class' G & 4925'MD 4577'TVD 1 75 sx AS I Liner 2021' 5" 225 sx Class G 4704'-6725'MD 4387'-6205'TV Perforation depth: measured 6310' - 6339'MD 6413' - 6448'MD true vertical 5838' - 5864'TVD 5931' - 5962'TVD Tubing (size, grade and measured depth) R E C E I V E D 2-7/8" J-55 tbg w/tail ~ 6375' Packers and SSSV (type and measured depth) OCT 2 0 ]98~ HB-1 pkr ~ 4508', DB pkr ~ 6352' & TRDP-1A-SSA 5S5V 8 1785' 12. Stimulation or cement squeeze summary Alalll~ 011 & Gas Cons. Commission Ancl~or~lte Intervals treated (measured) Liner lap (R-3 pkr @ 4450'), 6385' - 6387' Treatment description including volumes used and final pressure 150 sx Class G, 100 sx Class G 13. Representative Daily Average Pr°ducti°n °r Injecti~l~' Ji ;I D~ ~iI~' ~ ~A ]~¢' ~.$ ~~ N/A OiI-Bbl Gas-Mcf Water-Bbl Casing ~r~ ~'~I ~ , i F Prior tO well operation ~ i~'% ~ i" ~ Subsequent to operation ' i '~:~~ '!) ~,omplet~on ~el 1 H~story 14. Attachments Daily Report of Well Operations:4~: Copies of Logs and Surveys Run E~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~(~ ~j.])/~.~ Associate Engineer Signed Title Date Form 10-404 Rev. 12-1-85 fDAM} SW0/108 Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth, or W.O, no, AFE AK0791 Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O, begun Complete 9/19/86 9/20/86 thru 9/22/86 Date and depth as of 8:00 a.m. 9/23/86 ounty, parish or borough North Slope Borough Lease or Unit ADL 25569 itlo Completion API 50-103-20066-0 9/24/86 9/25/86 9/26/86 The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate 9/19/86 IState Alaska Well no. 2T-12A I ARCO w.I. INcur · [Prior status if a W.O. 0100 hrs Complete record for each day reported 5" f/4704'-6725' 11.7+ ppg NaC1 Accept rig @ 0100 hrs, 9/19/86. ND master vlv NU & tst BOPE. RIH w/6-1/8" bit/scrpr, hit bridge @ ±225'. P~ kelly & prep to circ& rotate on bridge. 56.24% 5" f/4704'-6725' 15.2 ppg Gel Mud Drl cmt to 3755', circ. Wt up to 14 ppg. Circ. shut in cond. Thick mud. Wt up to 15.2. Circ thru choke. 5" f/4704'-6725' 13.6 ppg Gel Mud Circ thru choke. RIH, drl cmt, tag TOL @ 4697' WLM, CBU. Att to tst lnr lap, pmp'd away @ 2 BPM. Monitor & fill hole. Reduce mud wt f/15.2 ppg to 13.6 ppg & circ same. POOH f/R-3 sqz pkr. 5" f/4704'-6725' 4697', RIH w/bit 13.6 ppg Gel Mud PU R-3 pkr, RIH, set @ 4450'. RU to sqz well, att same, locked up. Rev out cmt. Est IR @ 2 BPM, 1300 psi, batch mx & pmp 150 sx cmt. Hestitate sqz, rev circ DP, POH w/R-3 pkr. PU bit & RIH. 5" f/4704'-6725' 4699', TOH w/R-3 pkr 13.3+ ppg Gel Mud RIH to 4050', circ & WOC. RIH, tag cmt @ 4510', drl cmt to TOL @ 4696', tst lnr lap to 1800 psi; OK. Circ, TOH. RIH w/R-3 pkr, set @ 4650'. Tst ann; OK. Open by-pass, pmp~5.5 b ~ wtr dn DP, close by-pass & monitor f/30 min - "0"~p~p~ps. by-pass & rev out wtr. TOH w/pkr. ~L~''~'~~' !DENTIA[ TOH w/R-3 pkr. PU BHA, RIH w/7" scrpr on 3½" DP, tag cmt ~' 4699', DO cmt to 6640'. JTitle Drilling Supervisor ,RCO,Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish [State Alaska North Slope Borough Field ILease or Unit Kuparuk River I ADL 25569 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 9127186 thru 9~29/86 9/30/86 Alaska Well no. 2T-12A 5" f/4704'-6725' 6640' PBTD, TOH 12.0 ppg NaC1/NaBr Circ hole cln. Tst lnr to 1800 psi; OK. Rev circ wtr. D£spl well w/12.0 ppg brine. Rev circ & filter brine, POOH. Rn CET, GCT. Perf f/6385'-6387' @ 4 spf. RIH w/pkr, sqz 100 sx Cl "G" cmt w/.12% FL28, .3% CD-31 & .2% A-2. Unseat pkr, TOH. TIH w/4-1/8" bit & 5" scrpr, tag cmt @ 6125', DO cmt to 6455', wsh dn to 6640', circ hole cln, TOH. 5" f/4704'-6725' 6640' PBTD, RIH w/perf'g gun 11.9+ ppg NaC1/NaBr Tst BOPE, TOH w/bit. RIH w/5" retrievamatic & set @ 6300'. Tst perfs to 1500 psi, bled off to 1200 psi/5 min. Add wt on pkr, press ann to 500 psi, retst perfs to 1500 psi; OK. Cont RIH to 6622', filter brine, TOH. Chg out to 2-7/8" rams. RU Schl, perf 6448'-6413' w/4 SPF, 60° phasing. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 jTitle Drilling Supervisor ARco Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska County or Parish Field Lease or Unit Kuparuk River Auth. or W.O. no. IT tie I AFE AK0791 Nordic 1 North Slope Borough Accounting cost center code State Alaska ADL 25569 Completion Well no. 2T-12A API 50-103-20066-0 Operator I A.R.Co. W.I. ARCO Alaska, Inc. t 56.24% Spudded or W.O. begun Date Complete 9/19/86 Date and depth Complete record for each day reported as of 8:00 a.m. 10/01/86 Old TD New TD Released rig Date 0645 hrs. Classifications (oil, gas, etc.) O±l I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our I Prior status if a W.O, I 0100 hrs. 5" f/4704'-6725' 6640' PBTD, RR Diesel Perf f/6339'-6310' twice @ 4 SPF, 60° phasing. Make gage ring/JB rn. RIH, set 5" Bkr pkr @ 6363', RD Schl. Rn 198 jts, 2-7/8", 6.5#, J-55 EUE 8RD AB Mod tbg w/SSSV @ 1785', HB-1 pkr @ 4508', DB pkr @ 6352', TT @ 6375'. Tst pkr & SSSV. ND BOPE, NU & tst tree. Displ w/diesel. RR @ 0645 hrs, 10/1/86. PB Depth 10/1/86 Kindofrg Type completion (single, dual, etc.) Single CONFIDENTIAl] Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 6640 ' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Si g n at u,~~.~~ ~f For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date JTme Drilling Supervisor ..... STATE OF ALASKA : ALAS,.. OIL AND GAS CONSERVATION COM~...SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~' Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ~ Amend order ;.7 Perforate -' Other 2. Name of Operator 5. ARCO Alaska, Inc. 3. Address 6. P. 0. Box 100360 Anchoracler AK 99510 4. Location of well at surface 7. 102'FSL, 556'FWL, Sec.1, T11N, R8E, UN At top of productive interval 8. 980' FNL, 1105' FEL, Sec.11, TllN, RSE, UM (approx.) At effective depth 9. 1022' FNL, 1209' FEL, Sec.ll, TllN, RSE, UM (approx.) At total depth. 1039'FNI', 1229'FEL, Sec.11, TllN, RSE, UM (approx.) Datum elevation (DF or KB) ll7'RKB Unit or Property name Kuparuk River Unit Well number 2T~12A Permit number 86-128 APl number 50-- 103-20066-01 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 6725 feet 6221 feet 6657 ' feet 6158 ' feet Plugs (measured) Junk (measured) Cement plug from 6150' - 6669' Milled window f/4909' - 4925' Casing Length Conductor 80' Surface 2858' Size Cemented Measured depth True Vertical depth 16" 225 sx CS II 110'MD 110'TVD 9-5/8" 900 SX AS I I I & 2891 'MD 2812'TVD 300 sx Class G 7" 600 sx Class G & 4925'MD 4573'TVD 175 sx AS I 5" 225 sx Class G 4704'-6725'MD 4385'-6221'TVD Production 4893' Liner 2021 ' _ Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None RECEIVED AUG 5 1986 Alaska Oil & Gas Cons, Commission Anchorage 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch Well History (including Addendum, dated 7/28/86) 13. Estimated date for commencing operation September, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~ TitleAss°clare Engineer Commission Use Only Date Conditions of approval Approved by Form 10-403 Rev 12-1-85 (DAM) SA/088 Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Commissioner No. ,--~- 0 ~ by order of the commission Date Submit in triplicate ARco Oil and Gas Company Well History- Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0791 Rowan 34 Operator ARCO Alaska, Inc. Spudded or W.O. begun Accepted 7/06/86 thru 7/07/86 County, parish or borough North Slope Borough Lease or Unit ADL 25569 Title Drill API 50-103-20066-01 7/08/86 7/09/86 7/10/86 7/11/86 Date and depth as of 8:00 a.m. State ARCO W.I. IDate 7/06/86 lHour 1030 hrs. Prior status if a W.O. Complete record for each day reported 7" @ 6300 6154' (0') POH w/bit & junk baskets WT 10.6+, PV 20, YP 7, PH 9.5, WL 5.6, Sol 14 Finish skid rig from 2T-9. Replace beams, rathold hydric. Accept Rig @ 1030 hrs 7/06/86. N/U BOPE. Test same to 3000 psi OK. P/U BHA. RIH SLM. Tagged EZSV @ 4165'. Circ B/U & test csg. to 3000 psi OK. Drill EZSV & push to 4290'. RIH to 6154'. Circ B/U & test csg to 3000 psi OK. Pump slug & POH to P/U csg scrapers. 7" @ 6300 4931' PBD L/D start mill & P/U window mill Wt. 10.7, PV 14, YP 12, PH 9.5, WL 5.6, Sol 13 Fin POH. PU csg scrpr, RIH to 6154', C&C, POOH. RU Schl, rn CET log f/ 6080'-3862'. PU gauge ring/junk basket, rn to 5150' w/tight spot @ 3692' when POH. PU Baker DW-1-Perm Packer & set @ 4931', RD SOS. Rn SS Gyro surv. PU Whipstock w/anchor/stinger assy. RIH to 4902'. Ran SS Gyro check. Sting into packer @ 4929. Shear off Whipstock. Mill on shear lug w/start mill. Pump slug & POH. 4757, 30.7, S56.2W, 4431, 1304.43, S654.31, Wl140.89 5040, 33.7, S54.0W, 4670, 1455.09, S740.57, W1264.55 7" @ 4925 5086', (155'), Drlg Wt. 10.8, PV 15, YP 15, PH 9.5, WL 5.8, Sol 14 RIH, mill window thru 7" f/4909'-4925', POH. PU string mill, RIH, rm thru mill rn, POOH. PU drlg assy, TIH, drl f/4925'-4940'. KOP @ 4931'. Tst formation to 12.7 ppg EMW, drl 6-1/8" hole to 5086'. DD & 7" @ 4925 5500', (414'), Drlg Wt. 10.4+, PV 13, YP 13, PH 9.5, WL 5.9, Sol 13 Gyro & surv, drl 6-1/8" hole f/5086'-5245', TOH, PU DD. surv to 5500'. 5023', 29.5°, S54.5W, 4657 TVD, 1454 VS, 736N, 1256W 5387', 22°, S54W, 4984 TVD, 1612 VS, 821N, 1390W 7" @ 4925' 6503', (1003'), Drlg Wt. 11.7, PV 20, YP 16, PH 9.5, WL 6.1, Sol 15 Drl & surv 6-1/8" hole to 6503'. 5642', 21.75°, S52W, 5221TVD, 1708 VS, 878N, 1467W 6058', 23°, S49W, 5605 TVD, 1866 VS, 979N, 1589W Alaska iWell no. 2T-12A 56.24% RECEIVED AUG- 5 1986 Alaska Oil & Gas Cons. Comm,o Anchcraoe The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Joate I Title Drilling Supervisor ADDENDUM WELL: 7/2]./86 2T-12A Arctic Pak w/175 sx AS I, followed by 54 bbls Arctic Pak. RECEIVED AUG- 5 1986 Alaska Oil & Gas Cons. Anchorage ]~-r illing Supervisor ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty, parish or borough North Slope Borough ILease or Unit ADL 25569 ITitle Drill Kuparuk River Auth. or W.O. no, AFE AK0791 State Alaska IWoll no. 2T-12A 2T-12 Abandonment Rowan 34 API 50-103-20066-01 Operator IARCO W n ARCO Alaska, Tnc. Spudded or W.O. begun IDate IHour [Prior status if a W,O. Accepted 7/06/86 1030 hrs. 7/06/86 thru 7/07/86 7/08/86 Complete record for each day reported 7" @ 6300 6154' (0') POH w/bit & junk baskets WT 10.6+, PV 20, YP 7, PH 9.5, WL 5.6, Sol 14 Finish skid rig from 2T-9. Replace beams, rathold hydric. Accept Rig @ 1030 hrs 7/06/86. N/U BOPE. Test same to 3000 psi OK. P/U BHA. RIH SLM. Tagged EZSV @ 4165'. Circ B/U & test csg. to 3000 psi OK. Drill EZSV & push to 4290'. RIH to 6154'. Circ B/U & test csg to 3000 psi OK. Pump slug & POH to P/U csg scrapers. 7/09/86 Date and depth as of 8:00 a.m. 7/10/86 7/11/86 7" @ 6300 4931' PBD L/D start mill & P/U window mill Wt. 10.7, PV 14, YP 12, PH 9.5, WL 5.6, Sol 13 Fin POH. PU csg scrpr, RIH to 6154', C&C, POOH. RU Schl, rn CET log f/ 6080'-3862'. PU gauge ring/junk basket, rn to 5150' w/tight spot @ 3692' when POH. PU Baker DW-1-Perm Packer & set @ 4931', RD SOS. RnoSS Gyro surv. PU Whipstock w/anchor/stinger assy. RIH to 4902'. Ran SS Gyro check. Sting into packer @ 4929. Shear off Whipstock. Mill on shear lug w/start mill. Pump slug & POH. 4757, 30.7, S56.2W, 4431, 1304.43, S654.31, Wl140.89 5040, 33.7, S54.0W, 4670. 1455.09, S740.57, W1264.55 :2T-12 Plugged & Abandoned 7" @ 4925 5086', (155'), Drlg Wt. 10.8, PV 15, YP 15, PH 9.5, WL 5.8, Sol 14 RIH, mill window thru 7" f/4909'-4925', POH. PU string mill, RIH, rm thru mill rn, POOH. PU drlg assy, TIH, drl f/4925'-4940'. KOP @ 4931'. Tst formation to 12.7 ppg EMW, drl 6-1/8" hole to 5086'. 7" @ 4925 5500', (414'), Drlg Wt. 10.4+, PV 13, YP 13, PH 9.5, WL 5.9, Sol 13 Gyro & surv, drl 6-1/8" hole f/5086'-5245', TOH, PU DD. surv to 5500'. 5023', 29.5°, S54.5W, 4657 TVD, 1454 VS, 736N, 1256W 5387', 22°, S54W, 4984 TVD, 1612 VS, 821N, 1390W 7" @ 4925' 6503', (1003'), Drlg Wt. 11.7, PV 20, YP 16, PH 9.5, WL 6.1, Sol 15 Drl & surv 6-1/8" hole to 6503'. 5642', 21.75°, S52W, 5221TVD, 1708 VS, 878N, 1467W 6058', 23°, S49W, 5605 TVD, 1866 VS, 979N, 1589W DD & 56.24% The above is correct AR3B-459-1-D I RECEIVED Drilling Supervisor OCT - 2 1986 rNumber all daily well history forms consecutively for each J as they are prepared well. Naska 0il & 6as Cons. C .L,m..missio,-, Anchorage i Pa~.e no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. 'The "Final Report" form may be used for reporting the entire operation if space is available. District ]County or Parish I Alaska Field ~Lease or Unit Kuparuk River I APL 25569 Auth, or W.O. no. ~Title I AFE AK1771 Rowan 34 Operator l AR.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O, begun Date Accepted 7/06/86 Complete record for each day reported 7/12/86 thru 7/14/86 Date and depth as of 8:00 a.m. 7/15/86 North Slope Borough Accounting cost center code State Alaska Well no. 2T-12A Drill API 50-103-20066-01 I otal number of wells (active or inactive) on this pst center prior to plugging and bandonment of this well our ~ Prior status if a W.O, I 1030 hrs. 7" @ 4925' 6725', (222'), NU tree Wt. 11.8+, PV 16, YP 12, PH 9.0, WL 6.4, Sol 15 Drl & surv 6-1/8" hole to 6725, 20 std short trip, CBU, POOH. RU Schl, log DIL/GR/SP/SFL f/6734'-6100', cunt w/GR to 4909'. Log FDC/CNL f/6734'-6100' & 5300'-4900'. Rn CAL f/6734'-6100', RD Schl. TIH to 6725', lost rtns. Att to lift 12 ppg pill out of hole. Press up formation, bled off. Att'd @ 5579' & 5021'; no rtns. TOH to 4065', circ. Stage in @ 4979', 5550' & 6120', rm f/6100'-6725', TOH; tight @ 6440' & 6373'-6275' Wrk pipe, POOH. RU & rn 57 jts + mkr jt, 5", 18#, S-140 lnr w/FC @ 6691', FS @ 6725', LC @ 6657', mkr jt f/6426'-6393', hgr @ 4704'. Cmt w/225 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46, TOH; well flowing. SI well, bled to 0 psi. Opened well; well dead. ND BOPE. NU tree. 5" f/4704'-6725' 6725' RR , NU short tree. RR @ 1000 hrs, 7/14/86. Old TD ~ New TO PB Depfh 6725' TD 6657' PBTD Released rig Date K nd of r g 1000 hrs. 7/14/86 Rotary Classifications (oil. gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) FloWing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil" on test ~3as per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity AHowable Effective date corrected The above is correct For form preparation and distribution, AR3B-459-3-C Date RECEIVED OCT - 2 1986 JTitle Drilling Supervisor Number all daily well history forms consecutively j Pag; no. as they are prepared for each well. Alaska 0il & Gas Cons. Commission An~,hnr~n~ ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rel~ort" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field County. parish or borough IState Alaska North Slope Borough I Alaska Lease or Unit ADL 25569 I T tie Drill Kuparuk River Auth. or W.O. no, AFE AK0791 2T-12 Abandon~e n Rowan 34 API 50-103-20066-01 Operator IARCO W I ARCO Alaska, Inc. I 56.24% SpuddedorW.O. begun IDate {Hour P ..... tatusi, aW.O. Accepted 7/06/86 1030 hfs. 7/06/86 thru 7/07/86 7/08/86 Date and depth as of 8:00 a.m. 7/09/86 7/10/86 7/tl/86 Complete record for each day reported 7" @ 6300 6154' (0') POH w/bit & junk baskets WT 10.6+, PV 20, YP 7, PH 9.5, WL 5.6, Sol 14 Finish skid rig from 2T-9. Replace beams, rathold hydric. Accept Rig @ 1030 hfs 7/06/86. N/U BOPE. Test same to 3000 psi OK. P/U BHA. RIH SLM. Tagged EZSV @ 4165'. Circ B/U & test csg. to 3000 psi OK. Drill EZSV & push to 4290'. RIH to 6154'. Circ B/U & test csg to 3000 psi OK. Pump slug & POH to P/U csg scrapers. 7" @ 6300 4931' PBD L/D start mill & P/U window mill Wt. 10.7, PV 14, YP 12, PH 9.5, WL 5.6, Sol 13 Fin POH. PU csg scrpr, RIH to 6154', C&C, POOH. RU Schl, rn CET log f/ 6080'-3862'. PU gauge ring/Junk basket, rn to 5150' w/tight spot @ 3692' when POH. PU Baker DW-1-Perm Packer & set @ 4931', RD SOS. Rn-SS Gyro surv. PU Whipstock w/anchor/stinger assy. RIH to 4902'. Ran SS Gyro check. Sting into packer @ 4929. Shear off Whipstock. Mill on shear lug w/start mill. Pump slug & POH. 4757, 30.7, S56.2W, 4431, 1304.43, S654.31, Wl140.89 5040, 33.7, S5~.0~.~7~P~.)~4.[[~0.~, S740.57, W1264.55 7" @ %9~5~ ............................ ; 5086', (155'), Drlg Wt. 10.8, PV 15, YP 15, PH 9.5, WL 5.8, Sol 14 RIH, mill window thru 7" f/4909'-4925', POH. PU string mill, RIH, rm thru mill rn, POOH. PU drlg assy, TIH, drl f/4925'-4940'. KOP @ 4931'. Tat formation to 12.7 ppg EMW, drl 6-1/8" hole to 5086'. 7" @ 4925 5500', (414'), Drlg Wt. 10.4+, PV 13, YP 13, PH 9.5, WL 5.9, Sol 13 Gyro & surv, drl 6-I/8" hole f/5086'-5245', TOH, PU DD. surv to 5500'. 5023', 29.5*, S54.5W, 4657 TVD, 1454 VS, 736N, 1256W 5387', 22*, S54W, 4984 TVD, 1612 VS, 821N, 1390W DD & 7" @ 4925' 6503', (1003'), Drlg Wt. 11.7, PV 20, YP 16, PH 9.5, WL 6.1, Sol 15 Drl & surv 6-1/8" hole to 6503' 5642', 21.75', S52W, 5221 TV]], 1708 VS, 878N, 1467W 6058', 23*, S49W, 5605 TVD, 1866 VS, 979N, 1589W The above is correct Si gna~ For form preparation and distribution, see Procedures Manual. Section 10, Pages 86 and 87. I. RECEIVED Drilling Supervisor OCT - 2 1986 Number all d3ily well history f ........... lively Jas they are prepared for each well, Alaska 0il & Gas Cons. Co~missio,~ Anchoraae ARCO Oil and Gas Company ,~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Ral3ort" on the first Wednesday after allowable has been assigned Or well is Plugged. Abandoned. or Sold. "Final Rel~ort" should be submitted also when operations are suspended for an indefinite or appreciable length of ume. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used Ior ,eportmg the entire operation if space ~S avadal3ie. Spudded or W.O. begun Accepted t Accounting COSt conler code District ICounty or Parish State Alaska I North Slope Borough Alaska Field ~Lease or Unit Well no Kuparuk River I ADL 25569 2T-12A Auth. or W.O. no. ~Tit!e AFE AK1771 I Drill Rowan 34 API 50-103-20066-01 Operator ]AR.Co. W.I. ARCO Alaska, Inc. 56.24% IDate 7/06/86 Complete record tot each day reported 7/12/86 thru 7/14/86 Date and depth as of 8:00 7/15/86 Iotal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well our JPrior status if a W.O. 1030 hrs. 7" @ 4925' 6725', (222'), NU tree Wt. 11.8+, PV 16, YP 12, PH 9.0, WL 6.4, Sol 15 Drl & surv 6-1/8" hole to 6725, 20 std short trip, CBU, POOH. RU Schl, log DIL/GR/SP/SFL f/6734'-6100', cont w/GR to 4909'. Log FDC/CNL f/6734'-6100' & 5300'-4900'. Rn CAL f/6734'-6100', RD Schl. TIH to 6725', lost tins. Att to lift 12 ppg pill out of hole. Press up formation, bled off. Att'd @ 5579' & 5021'; no tins. TOH to 4065', circ. Stage in @ 4979', 5550' & 6120', rm f/6100'-6725' TOH; tight @ 6440' & 6373'-6275'. Wrk pipe, POOH. RU & rn 5~ its + mkr it, 5", 18#, S-140 lnr w/FC @ 6691', FS @ 6725', LC @ 6657', mkr jt f/6426'-6393', hgr @ 4704'. Cml w/225 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46, TOH; well flowing. SI well, bled to 0 psi. Opened well; well dead. ND BOPE. NU tree. 5" f/4704'-6725' 6725', RR NU short tree. RR @ 1000 hrs, 7/14/86. OIdTD IINewTD Ip"oepth 6725' TD 6657' PBTD Released rig ~ Date Kind of rig 1000 hrs. 7/[4/86 Rotary Classifications (oil. gas, etc.) Oil Producing method F lowing Potential test data Type completion (single, dual. etc.) Single Officim reservoir nameis) Kuparuk Sands , Well no, Date Reservoir Producing Interval Oil Or gas iTest time Production 0il on test Gas per clay Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity' A'liowable Effectiv~ date corrected The above is correct For form~reDaration and distribution, AR3B-459-3-C Drilling Supervisor RECEIVED OCT - 2 1986 JNumber all daily well history forms consecutively ] Page no /as they are prepared for each well. Alaska 0il & Gas Cons. C0rnml.!ssj~n 2 A.choraoe o,.,-,o, o, ARCO AlasKa. inc. Post Office Box 100360 Anchorage. AlasKa 99510-0360 Telephone 907 276 1215 DATE 07-30-86 TRANSMITT.~ # 5727 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0 360 Transmitted herewith are the following items. return one signed copy of this transmittal. Open Hole LIS Tapes Plus Listings' Schl' -'~ 2T-8 ' 07-21-86 ~ 2T-9 ~ 07-03-86 --~ 2T-12A/07-12-86 --- 3K-3f 06-27-86 -~- 3K-4/ 07-04-86 ----.3K-5/ 07-12-86 Run #1 Run #3 Run =1 Run #1 Run #1 Run #1 0097.5-7669.0 3300.0-6389.0 4885.5-6756.0 0187.0-8929.0 2992.0-8937.5 2388.5-8168.5 Please acknowledge receipt and One copy of each EDIT EDIT . EDIT EDIT Receipt Acknowledged: state of Alaska ARCO Ala$1La. Inc. ,s · Sulos,O,/r¥ Of AlilntmcRtchfleldCompan'/ Date: '¥~[-Ig s,OD~V uo ~s~ ~08 ~ p~ss~u~ ! 'K~mm~s Ul 'smoqs ~zodoz ~so~ ~08 poqo~w oq~ sv $.m pu~ -m'd 0~:~ ~* uw~oq aso~ ROg oq% · somni!~~ ou ozoa ozoq~ pIo!A xoA!M MnxednM ¥g[-%Z fltDt ODMV :~sa,L ¢I0~ :103c8ns ao~oadsuI mnoIox~aj aaasoA 'C fqqo~ :~OHH S.[.E OF ALASEA 'ALASKA OIL & C~3 CONSERVATION ~.0.P.E. Inspection Report Reserve Pit Mud Svs=~s Visual Audio Trip Tank Pit CauEe Flo~ Monizor (;as De=et:ors . BOPE Stack ~nnu!ar Preventer Pipe P~ms Blind R~-~ Choke Line Valves. H.C.R. V~!ve Kill Line Yalves Check V-~Ive Tes: Pressure ,,'7 ca~l,~ set ~ 'ql/o ~" ~. ~:essu:e *~:e: C2es~:e j~ ~ ~u~p ~c:. c~es. ~:es. 2~ ps~g.~ ~u~ C~:ge ~:essu:e ~::~e~:' Remote ~~ Blinds s~'i:cb cover Ke!lv and Floor Safety Valves Upper Kellx / Test Pressure Lover Kel!X / Test Pressure Ball T)Te / Test Pressure inside BOP / Test Pressure psig · psig Choke ¥~nifoid Nc. Valves Adjusuable Chokes Hvdrauica!!v o~era:ed choke Test Time ~ hrs. '/ /'os_. / and inspector/ Test Resu!us: Pziiu:es D Repair or P~ep!acemen: of faile~ equipment Co~-issiom office notified. Re~arks: -- - D.s.__bu.ion ~ . "'- orig. - AO&GCC cc - Supervisor !nspec:or June 26, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 2T-12A ARCO Alaska, Inc. Permit No. 86-128 Sur. Loc. 102:FSL, 556'FIFL, Sec. !, TllN, RSE, UM. Btmhole Loc. I064'FSrL, ]193'FEL, Sec. 1!, TllN, R8E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indem~nify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ~ V. C~tertbn Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COP~ISSION dif Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lower~/ .... STATE OF ALASKA ALASKA ~._ ,.. AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of work Drill [] Redrill ~1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Cd Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone J~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 117', PAD 82' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25569 ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 102'FSL, 556'FWL, Sec.1, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu ,mber Number 980'FNL, ll05'FEL, Sec.11, T11N, R8E, UM 2T-12A #8088-26-27 At total depth 9. Approximate spud date Amount 1064'FNL, 1193'FEL, Sec.ll, TllN, R8E, UM 07/12/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 6755 'MD 4087 feet 2T-13 25'~ surface feet 2560 f6254'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) ( 5900 ' TVD ) Kickoff depth 1 747 feet Maximum hole angle 34 0 Maximum surface 2 745 psig At total depth (TVD) 3374 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 9b.,, 1¢;" ¢;~ c.~ N-&O w,~!d 80' 35' 35' !!5' 115' _200 cf 8-1/2" 7" 26.0# J-55 BTC 6266' 34' 34' 6300' 5711 ' 6-1/8" 5" 18.0# S140 SFJ 1955' 4800' 4435' 6755' 6254' 200 ~x Class 0 19. To be completed for Redrilt, Re-entry, and Deepen Operations. Present well condition summary Total depth' measured 6800 ' feet Plugs (measured) cmt plug f/6669' -6150' true vertical 61 39 feet Effective depth: measured feet Junk (measured) None true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 75' 16" to surface 1lO'MD 110'TVD Surface 2856' 9-5/8" to surface 2891 'MD 2830'TVD Intermediate 6226' 7" to 2900' 6300'MD 5711 'TVD Liner (See attached Drilling Program for proposed liner.) RECEIVE[ ~ ~effo~r.,a~io~"depth:.- m¢,a'cu~e~ N ~, ,, i¢;,.' ~ ' .. '. ;~ ..... e EZSV set at 4165'MD JUN 1 8 1986 ]~':~- :~ ~:..-.;':;~' , · .:true e~cal 2~. Aft~ch~r~'~nt§'*¢ "~li~hgff~ Property plat [] BOP Sketch ~ Diverter Sketch [] · Drilling p~b~i~rr~j~ t~a~ 60n8, Drilling fluid pro~J~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requir~l~~ 21, I hereby ce[,tify' ~fi/at the foregoing is tr, u~ and correct to the best of my knowledge Signed i / ,/ ).¢ ~/~.¢,/.¢v¢.~ Title Regional Drilling Engineer Date '" ~Z" ~"~'7 / / Commission Use Only ( HRE ) PD/PD286 ,// ,./"~- mb'e ~. / I APInumber ]Approve. date See cover letter Permit Nu ::~ -- i'z.~ 50--/o:~ ~%o,; ~ -,~ i 06/26/86 for other requirements Conditions of approval Samples required [] Yes ~-,No Mud log required [] Yes [~, No Hydrogen sulfide measures [] Yes [] No Directional survey required [~ Yes [] No R equiredwork~~~~ 5M; E~ 10M; [] 15M Other: " by order of Approved by ~ ',,,/~ "/,¢~"~~a4/' Commissioner the commission Date Form 10-401 Rev. 12-1-85 ! Subr~il :riplicate 2T-12A DRILLING PROGRAM I. Move and rig up Rowan #34. NU and test BOPs to 3000 psi. 2. PU 6-1/8" bit, 4-3/4" DCs, 3-1/2" DP. RIH and tag EZSV at 4165'MD. 3. Pressure test 7" casing to 3000 psig. Drill out EZSV. 4. Clean out to TOC at 6100'MD. TOH. 5. PU 6-1/8" bit and casing scraper. Clean out to 6100'MD. 6. RU cased hole 1 oggers. Run gauge ri ng/CET/CCL. 7. PU Baker "DB" permanent packer on 3-1/2" DP. RIH orient 125° left of high side with single shot Gyro. Set packer at approximately 5040'MD. 8. PU permanent whipstock with starting mill. Latch into packer, shear pin, mill approximately 2' of casing. TOH. 9. PU carbide window mill and string mill . Cut approximately 10' casing (total window will be 12'). TOH. 10. PU taper mill and watermel on mil 1 and dress window. TOH. 11. PU 6-1/8" BHA. TIH, drill 15' new hole, test formation to 13.5 ppg EMW. Drill 6-1/8" according to directional plan to total depth. 12. Run open hole logs. 13. Run 5", 18.0#, S-140, SFJ liner with 200' overlap in 7" casingt cement liner wi th caliper hole volume plus volume of liner lap plus 200' fil 1 inside 7" casing. 14. Displace top 2000' of 7" casing with diesel. 15. Downsqueeze Arctic pack and cement in 7" x 9-5/8" annulus. 1 6 . ND BOPE. 17. Instal], 7-1/1~i ..SM x 3" 5M adapter flange and 3" 5M valve. Secure well. 18. RD and move r~ig. 19. Move in workover rig. NU and test BOPE. 20. RIH with 6.125" bit and scraper. Clean out to liner top. Test lap to 3000 psi. TOH. RECEIVED JUN ! 8 Alaska Oil & G~s Oons. aommissio~ Anchorage 2T-12A DRILLING PROGRAM (cont'd) 21. TIH with 4.125" bit and boot basket. Drill out landing collar and clean out to fl oat collar. Test liner to 3000 psi . TOH. 22. Run cased hole logs. 23. Perforate and run completion assembly. Set and test packer. 24. ND blow out preventer and install x-mas tree. Change over to diesel. 25. 26. Flow well to tanks. Shut in. 27. Secure well and release rig. 28. Fracture stimulate. PD/PD286a:tw RECE VED JUN 1 8 1986 Alaska Oil & Gas Cons. Commission Anchorage ARCO i&LASKA, [NC. , PAD 2T. ',dELL NO, 12A F~OPOSED. K__UP.__A_R..U.._K__. F. !_E L D:L NO_RT H_ ...S LOPE_, ..... ~..~s,.'~ ~.~P~s?oc,:i_ ~,c... - -~J[,/ \ V"/ I'll I'ri 2 DEe DeIL.I/ 24' 41' 100 FT 20' 4~ ' TARGET ANGLE MtN- - KOP (T~e ~n Point) _ TVD=4671 THD=5040 DEP=1464 ..4.2.._~1:..N. S 54 ..~..'.e. w EOC TVD-5348 TMD-S797 DEP-17*96 ..... ?000. I I 'l 1000 2000 VERTICAL SECTION TARGET TVD=5900 TMD=6381 DEP=I 982 BASE KUP- SNDS TVD=6065 TMD=6555 DEP=2038 TD (LOGGING PT) TVD=6254 TMD=6755 DEP=2102 3000 ~ ~ 'i ,:.~' ,',,-, :' ~. ~ ~., -, ' ...... ~ R[CEIVED JUN 1 8 1986 Ai~ska Oil & Gas Cons. ~nchorjgo HORIZON~TAL PROJECT ION SCALE I Itl. - 1000 FEET , 2T, WELL_.NO~ 12A PROPOSED KUPARUK FIELD. NORTH SLOPE. ALASKA ~ooo, o ~ ooo o ' ~ ~5i ~' '~ ' ~ ' * ~ ' ~ ' -t" ' . ;,~, . , .... ~ ~ ]~ ,. ~ ~ .~[- .... 2000_, T~ .L~A~[~ ~ ~c. H. T~N..R~ .~i- ~ .:. , ~ ~ PL~ANE . 1 000 b~4N['F'ACE LOOAT ION, i02 F~L. SS& FWL SEC. 1. TIlN. ~ 200 , 300 , i I . i ~00 500 ,6oo ~'oo' JBO0. ' 900 , i1000' :, i t- 1 ~ CO ' '~', ' '- ' t ........ J'"i~" ' ~ ~ ' : ' ' t--' ............ 1 .......... I~ ' ............... = ~ ' ' ! ' ' ' ~ ~ ' ~ ' . ' ~ .... ~ ' ' ' ~ ~ ~ ~ 1455 ' ~ ,* : , · / ~ ,, 3737 I , ~ . ~ ~ ,,, , ~ ~ ~ ~, i ' ' · ' ' ,055 ' ~ .........~ I ' -~' 26T~ ~ .... , - . , . 200 : soo , 400 500 600 700 Boo ' 900 i. ~000 ~ - ~ i "', .................. , , , ~~ T .... J ....... ~, ............... , ~ , 1100 DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing Density 9.6-9.8 PV 15-30 Drill out to Weight Up 8.7-9.2 5-15 Yp 20-40 8-12 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate AP1 20 pH 9-10 % Solids lO± 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Dr, i,,l!ing Fluid Syste,m: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. L~5 / ih After 200' of departure, there are no well bores within 200' of this proposed well. CONFIDENIIA INDI FINli'i LY RECEIVED JUN 1 8 1988 Oil & Gas Cons. C SHALE ~ STiR DEG,~SSER i ,,,! ~ i Tvpjf' ~' i , -../'~-,L MUD SYSTEM SCHEMATIC ECEiVED JUN 1 8 IO~ Oil & Gas Cons. 7 6 DIAGRAM **1 13-5/8" 50(X) P~[ RSRRA BOP ~TACK I. I~" - 2000 PSI TAIt~CO STARTING ~ 3. I1' - ~ ~I X 1~8' - ~ ~I ~A~ ~ 4. 1~8" - ~ ~I PI~ ~ 5. 1~8' - ~ ~I ~ILLI~ ~ W/~ ~ KI~ LI~ G. 1~8" - ~ ~I ~E ~ W/PI~ ~ ~ T~, 7. 1~8' - ~ ~I ~ A,C(llVlJLATOR CAPACITY TgST I. Q-ECl( AI~ FILL A~TCR RESE]~OIR TO ~ LEVEL WITH HYDRN~IC FLUID. 2_. ~ THAT A~TC~ PRE~ IS _3000~_ PSI WITH C~ Tli~o ~ CI.C~ ALL UNITS SllvlLTAI~EOL~I.Y AIL UNITS ARE CLOSED WITH O4AROING ~ CFF. 4. RECI3~ C~ ~ REI:I3~, ~ ACCEPTABLE LCIM~R LIMIT IS 45 SE~ CLOSIN$ TII~[ ~ I~ ~I ~INI~ 5 4 ii 2 13-~t~" BOP STACK Tt~ST i, FILL BaP STACI( At~ CI-K~KE MANIFCI.D WITH ARCTIC DIESEL, 2. (]'[C~ THAT ALL LOCI( D(]~ SCREI~ IN V~E].LI-EAD ARE F1JLLY RETRACTED. ~AT TEST F~UG IN V~ WITH Rt.t~IN~ dl' AI~ ~ IN LCX]<D(3~ ~. 3, CL__C6~_ ~ PREVENTE~ ~ IVaN.IN. KILL ~ CHCKE LIbE VALVES ADJACENT TO ~ STAO(, ALL 4, ~ UIa TO 250~ FCR I0 MIN. IN- C~ PR~ TO ~(:S[31:J}~AI~ HaI.D FCR I0 MIN. BLEED PEES~ TO O"PS~, 5. ~ ~ PR~"VENTER ~ ~ KILL AN3 Q-K~E LIllE: VALVES, CLOSE TaP PIPE: RAN~ ~ I-K:R VALVES 6, TEST TO 2.50 PSI AI~D~ AS IN STEP 4. 7. ~INLJE TESTING AL~VESo LII~.S° AAD C]-tCKES WITH A 250 PSI LCIN ~ 3(:J(X~ PSI HIGH, TEST AS IN STEP 4. Da NOT PR~ASLR~ TEST ~J~Y O-¢XEcN_TNATY[-~ NOT A FLLL CLOSING POSITIYE SEAL Q-iCI(E. F~I~ T~ST CJ-113~ TI~T DO ~ FI.I. LY CLOSE. 8, ~ TCI: PIPE RAMS ~ CLOSE BOTTCM PIPE TEST BOTTCM PIPE ~ TO 2.50 PSI ~ 3OClO PSI. 10, CLOSE IBLII~D ~ ~ TEST TO Z50 PSI AN3 3000 PSI, il, ~ l~..[l~) ~J~IS AI~D. RETRjIEVE-TEST PLUG, MAKE MANIF(3.D ~ LILIES ARE FLI. L CF N~ING FLUID. SET ALL VALVES IN DRILLING PO~ITICN. 12.' TEST STAI~IPE VALVES. KELLY. K~I__LY CCX3<So CRILL PIPt~ SAFETY VALVE. A~ liPIDE tB43P TO 2.50 PSI 3000 PSI. 13. EEO:RD TEST IN:'DRIV~TICN (:N 8LO/IOUT PREVENTER TEST FORa° SIGNo A~D ~ TO DRILLING SL~ISDR. 14.PERI:'(~ CC~ETE BCI~ TEST AFTER NIPPLING LI~ 14EEKLY THEREAFTER F1JNCTI~Y CI~TE B(~ DALLY. v DCONFIDENTIAL 510084001 Oil & Gas Cons. ARCO Alaska, Inc. Post Office BoX 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 2T Pad (Wells 2- 17) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L44 Enclosure If CONFIDENTIAL RECEIVED FEB, 0 5 lt~r, Al~cka Oil r,h~,. ,-~ LOCATED IN PROTRACTED SEC. I, TII N,RSE, U.M. 2 - Y ' 5,970,382.43 LAT. 70°19'49.1287'' X · 498,944.93 LONG.150°00'30.807'' 402' FSL, 556' FWL OG = 77' PAD = 81.5 3 - Y ' 5,970,357.42 LAT. 70°19'48.B82B" X = 498,944.91 LONG.150°00"30.808'' 377' FSL, 556' FWL OG ' 77' PAD = 81.5 4 -'Y = 5,970,332.46 LAT. 70°19'48.6372" X = 498,944.84 LONG.150°00'30-809" 352" FSL, 556' FWL OG ' 77' PAD = 81.6 5 - Y = 5,970,307.52 LAT. 70°19'48.3919" X ' 498,944.91 LONG.i50°00'30.808" 327' FSL, 556' FWL OG ' 77' PAD - 81.6 6 - Y = 5,970,282.50 LAT. 70°19'48.1459.' X = 498,944.95 LONG.150°00'30.806'' 302' FSL, 556' FWL OG = 77' PAD = 81.7 7 - Y = 5,970,257.54 LAT. 70°19'47.9003" X = 498,944.95 LONG-150°00'30-806'' 277' FSL, 556' FWL OG = 77' PAD = 81.6 B - Y = 5,970,232.63 LAT. 70°19'47.6553" X = 498,944.96 LONG.150°00'30-806" 252' FSL, 556' FWL OG = 76.9 PAD = 81.6 9 - Y = 5,970.207.62 LAT. 70°19'47.4093" X = 498,945.01 LONG. 150°00'30.804" 227' FSL, 556' FWL OG = 76.3 PAD = 81.6 NOTES i tt: lO I~: il: 6 7 CD 0 LOCATED IN PROTRACTED SEC. I , TI I N,R8E, U.M. 10 - Y = 5,970,132.65 LAT. 70°19'46.6719" X - 498,945.27 LONG.150°00'30'796" 152'FSL, 556' FWL OG - 76.0 PAD - B1.7 11 = Y = 5,970,107.71 LAT. 70°19'46.4267" X · 498,945.10 LONG.150°OO'30-B01" 127' FSL, 556' FWL OG ' 75.9 PAD - B1.7 12 - Y = 5,970,082.58 LAT. 70°19'46.1794" X = 498,944.98 LONG.150°00'30'804" 102' FSL, 556' FWL OG - 75.7 PAD · 81.7 13 - Y = 5,970,057.59 LAT. 70°19'45.9336' X - 498,945.08 LONG.150°00'30-801' 77' FSL, 556' FWL OG - 75.5 PAD - 81.6 c> 14 - Y = 5,970,032.60 LAT. 70°19'45.6079' L-~ X = 498,944 91 LONG.150°00'30.806' ~ 52' FSL, 556' FWL OG - 75.3 PAD - 81.7 cS , ~S 15 - Y = 5,970,007.69 LAT. 70°19'45.442B" <~ X 498,944.93 LONG.150°00'30'B06" 27' FSL, 556' FWL DG - 75.2 PAD - 81.6 16 - Y = 5,969,982.85 LAT. 70°19'45.1985" X = 498,944.88 LONG.150°00'30'807'' 2' FSL, 556' FWL OG = 75.1 PAD - BX.7 LOCATED IN PROTRACTED SEC.12, TI I N,R8E, U.M. 17 - Y -' 5,969,957.72 LAT. 70°19'44-9514" X = 498,944.94 LONG. 150°00' 30-805" 2 F 1~5 ' 0 .6 CO qfiDENTI AL, IND[FINITi LY I. ALL COORDINATES ARE A.S.P.,ZONEA. 2. SECTION LINE DISTANCES ARE TRUE. 3. HORIZ; POSITIONS BASED ON TEME MON's ZT-EAST, 2T-WEST !~ ?.T-MIDDLE PER LHD& ASSOC. 4. VERT. POSITIONS BASED ON TBM' , s 2T-6 ~k NI9+75 EI1+52 PER F.R,B. & ASSOC. 5.0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED- RIXX-3140 rev, CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYINg iN ThE STATE Of ALASKA ~ND THAT THIS PLAT REPRESENTS A LOC~TION SURVEY M~DE BY ME OR UNDER MY SUPERVISION, AND That ALL DIMENSIONS AND OTHER DETAILS ~ " SURVEYED FOR: ~ ~F RUPARUK PROJECT ' DAT~ I~ JAN ~6 · DRILL SITE 2T CONDUCTOR ~CKED SM ~ ~~, ~,~ ~ ~.~.~..~ AS- BUILT LOCATIONS IlIIlllll ,. lJll Iil~l,lll 5335 Arctic Boulevard, Suite 201, Anchorage, Alaska 99503 DWG. No. NSK 86-6 SCALE N.T.S. JOB NO. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (3) Admin (~'thru 13), 10. :::' : :"-: ::: 11. (10 and 13) 12 13] (4) c sg (14 thru 22) CONFIDENTIAL FINIT[LY (23 thru 28) Company ,:Z~5 Lease & Well No. YES NO the permit fee attached ,~ .... ' Is operator the only affected party ' Can permit be approved before ten-day wait .......................... 11 b fi 1 2. Is we to e located in a de ned poe .............................. 2>---, 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... ~ 5. Is sufficient undedicated acreage available in this pool ............ , , 6. Is well to be deviated and is wellbore plat included .................... 7. 8. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ................. ~ Does the well have a unique name ;~ ~b;r .~ .~ .... ~.~ ~ ....... 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate ~,( Are necessary diagrams and descriptions of-~i~.~i-~_-r__.~n~ BOPE attached. ~ Does BOPE have sufficient pressure rating - Test to ~~, , psig .. ~ ..... Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. __ REMARKS ! t/ (6) OTIIER ,A/,/~, (29 thru 31) For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented (6) Add: ~.~, L-Ig-~ 32. Additional requirements ............................................. .Geology: Engjln_ee~ring: .cs 7/ EW- _, WVA~ MTM~ HJH i '....., ' ...... rev: 04/03/86 6.011 POOL · INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Additional Remarks: 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. AUG" ~ 131~6 CONFIDENTIAl. INDEFINITELY MICRO[ILNED LIS TAPE VERIFICATION LISTING LV? OlO.HO2 VERiFiCATiON LZSTINC- PAGE 1 "-~- R:EL HEADER SERVICE NAME :EDIT DATE :86/07/16 ORIGIN : REEL NAME :149587 CONTINUATION m :01 PREVIOUS REEL : COMMENTS :LIBRARY TAPE -,-~. TAPE HEAD=R. -,-.,. SERVICE NAME :EDIT DATE :85/07/16 ORIGIN :0000 TAPE NAME :1590 CONTINU6TION ~ :01 PREVIOUS TAPE : .COMMENTS :LIBRARY ;~:~ FILE HEADER FiLE NAME :EDIT SERVICE NAME : VERSION ~ : DATE : M~XIMUM LENGTH : FILE TYPE : PREVIOUS FILE INFORMATION TAPE .001 1024 : RE.CORDS.,--,. MNEM CONTENTS CN : ARCO ALASKA, WN : 2T-12A FN : KUPARUK RANG: 8E 'TOWN: liN SECT: 1 COUN: NORTH SLOPE S'TAT: 6LASK~ CTRY: US~ MNE.M CONTENTS INC. PRES: E ...... COMMENTS.,--,- UNIT UNIT TYPE 000 000 000 000 000 000 000 000 000 TYPE 000 C AT'E 000 0 O0 000 000 000 000 000 000 000 CATE 000 SIZE 018 006 O08 O02 0O4 O02 012 006 O03 SIZE 001 CODE 065 065 065 065 065 065 065 065 COOE 0 6.5 LVP OlO.M02 VERIFICATInN,-, LigTiNG PAGE 2 ~- SCHLUMBE RG~R -'- ALASKA COMMUTING CENTER ;',-' WELL : 2T-12A FIELD : KUPARUK COUNTY = NORTH SLOPE ~.OROUGH STATE = ALASKA JOB NUMBER AT ACC: 71590 RUN #1, DATE LOGGED: 12-JUL-86 LOP: RICK KRUWELL CASING : 7.000" @ 4909' - BIT SIZE : 6.125" TO 6725' TYPE FLUID = WT.. POLYMER DENSITY : 1!.7 LE/G RM = 2.55 @ 71 DF VISCOSITY : 47 S RMF : 2.12 @ 71 0~ PH : 9.5 RMC : 2.39 @ 71 DF FLUID LOSS = 6.1 C3 RM AT BHT : 1.251 @ 152 DF MATRIX SANDSTONE ~~ THIS DATA HAS NOT BEEN DEPTH ,SHIFTED - OVERLAYS FIELD PRINTS LVP OiO.HO2 VERIFICATION LISTING PAG~ 3 -,- SCHLUMB=RG=R LOGS TNCLUDED WITH THiS MAGNr-TIC TAP:: .,- DUAL rNDUCTIBN SPHERICALLY FOCUSED LOG (OIL) '~ ~. OAT~ AVAILABLE: 6728 TO 4915 * FORMA'TION DENSITY COMPENSATED LOG (FDN) ~ ~;~ C~MPENSATED .~EUTRDN LSG (:ON) :1= DATA AVAIL~BL.E: 6702' TO 4915' .--'- .~-'- .~ ......... .,.-~ ~. ~. .,., .,. .,. .,. ~. .,. ~. .,..,.~- .... :~,..,.~' ~ ~. .~ .,. DATA FORMAT RECORD ;X:~ EN'TRY BLOCKS TYPE SiZE RF. PR CODE ENTRY Z 1 66 0 4 1 ~ I 8 4 73 60 9 4 65 · 1 IN 16 1 66 1 0 1 56 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT AP1 API APl ~PI FiLE SIZE SPL REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD ND. CCDE (OCTAL) DEPT FT O0 000 O0 0 0 4 i 68 00000000000000 SFLU DZL OHMM O0 220 Ot 0 0 4 i 6~ 00000000000000 ILO OIL DHMM O0 120 ~6 0 0 ~ I 68 00000000000000 LVP OlO.H02 VERIFICATION LISTING iLM DIL OHMM O0 120 44 0 SP OIL MV O0 010 01 0 GR OIL GAPI O0 310 01 0 GR FDN GAPI O0 310 O1 0 CALl FDN IN O0 280 O1 0 RHOB FON G/C3 O0 350 02 0 DRHD FDN G/C3 O0 358 OI 0 NRAT FON O0 420 Ol 0 RNRA FDN O0 000 O0 0 NPflI FDN PU O0 890 O0 0 NCNL FDN CPS O0 330 31 0 FCNL FDN CPS O0 330 30 0 PAGE 4 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 i 58 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 -,-* DATA,,--,- DEPT SP RHOB NPHI 6756.0000 SFLU -38.9883 GR 2.4651 DRHD 37.4512 NCNL Dr:PT~. SP RHOB NPHI 6700.0000 SFLU -13.9980 GR 2.4202 ORHO 36.6211 NCNL DEPT SP RHOB NPHI 6600.0000 SFLU -16.4951 GR 2.4319 DRHO 40.5273 NCNL DEPT SP RHOB NPHI 5500.0000 SFLU -23.4951 GR 2.3401 DRHO 37.4512 NCNL 'OEPT SP RHOB NPHI 6,400.0000 SFLU -26.9951 GR 2.4846 DRHO 33'6426 NCNL DEPT SP NPHi 6300.0000 SFLU -31.4951 GR 2.3381 DRHO 42.2363 NCNL DEP'T SP RHOB NPHI 6200.0000 SELU -36.4883 GR 2.3948 DRHO 45.2148 NCNL OEPT SO RHOB 6100.0000 SFLU -38.9B83 G~ 2.3225 D:RHO 2.9397 ILD 122.0273 GR 0.0737 NRAT 2427.5000 FCNL 2.2170 ILO 117.7148 GR 0.0605 NRAT 2375.5000 FCNL 1.8047 ILD 112.2773 GR 0.0591 NRAT 2257.5000 FCNL 3.9319 ILD 114.1523 GR 0.0483 NRAT 2101.5000 FCNL 2.4924 ILD 122.7148 GR 0.0571 NRAT 2225.5000 FCNL 1.5128 ILO 143.6875 GR 0.0381 NRAT 1911.6875 FCNL 2.2659 132.4375 GR 0.0474 NR4T 1959.6875 FCN~ 4.4070 ILO 248.5625 GR 0.0088 NRAT 2.6624 122.0273 3.0295 769.3125 2.2131 117.7148 2.9631 761.3125 2.0491 112.2773 3.1799 690.3125 3.8674 114.1523 3.0334 690.3125 2.6194 122-7148 2.8147 748.8125 1.6592 143.6875 3.3030 617..31.25 1.9258 132.4375 3'.4553 536.3125 3.1956 248.5625 3.5808 !LM 2.6252 CALl 6.1257 RNR~ 3.1545 ILM 2.2756 CALI 5.7859 RNRA 3.1194 ILM 1.9942 CAL'I 5.8484 RNRA 3.2698 ILM 3.6272 CALI 6.2273 RNR~ 3.0432 ILM 2.5725 CALI 6.0242 RNRA 2.9709 ILM 1.7589 CALI 6.3501 RNRA .3.0959 'ILM 2.0081 CALI 6.1648 RNRA 3.6545 ILM 3. 2834 CALl 6.1179 RNRa 3.6194 LVP OlO.H02 VERIFICATION LISTING PAGE 5 NPHI 47.ZI68 NCNL DEPT 6000.0000 SFLU SP -36.4883 GR RHOB -999.2500 DRHO NPHI -'999.2500 NCNL DEPT 5900.0000 SFLU SP -54.4883 GR RHOE -999.2500 DRHO NPHI -999.2500 NCNL DEPT 5800.0000 SFLU SP -57.4883 GR RHOB -999.2500 DRHO NPHI -999.2500 NCNL DEPT 5700.0000 SFLU SP -58.7383 GR RHO~ -999.2500 DRHO NPHI -999.2500 NCNL DEPT 5600.0000 SFLU SP -20.4951 GR RHOB -999.2500 DRHO NPHI .-999.2500 NCNL DEPT 5500.0000 SFLU SP -20.9951 GR RHOS -999.2500 DRHO NPHI -999.2500 NCNL DEPT 5400.0000 SFLU SP -27.2451 GR RHOB -999.2500 DRHO NPHI -999.2500 NCNL DEPT 5300.0000 SFLU SP -28.2451 GR RHOB 2.3655 ORHO NPHZ 36.8164 NCNL DEPT 5200.0000 SFLU SP -34.7383 GR RHOB 2.3499 DRHO NPHI 31.8359 NCNL DEPT 5100.0000 SFLU SP -51.2383 GR RHOB 2.4143 DRHG NPHI 38.7207 NCNL DEPT 5000.0000 SFLU SP -55.9883 GR i978.6~75 FCNL 2.1389 ILO 230.3125 GR -999.2500 NRAT -999.2500 FCNL 4°7390 ILD 116.6523 GR -999.2500 NRAT -999.2500 FCNL ~.8R53 ILD 126.52'73 GR -999.2500 NRAT -999.2500 FCNL 3.6272 iLO 120.1523 GR -999.2500 NRAT -999.2500 FCNL 3.3323 ILO 122.0898 GR -999.2500 NR6T .-999.2500 FCNL 3.3928 ILO 124.2148 GR -999.2500 NRAT -999.2500 FCNL 2.7639 ILD 141.1875 GR -999.2500 NRAT -999.2500 FCNL 2.8459 ILO 115.7148 GR 0.0000 NRAT 2795.5000 FCNL 4.4773 iLD 101.9648 GR 0.0034 NRAT 2795.5000 ~CNL 3.2.639 ILD 150.8125 GR 0.0347 NRAT 2121.5000 FCNL 1.9922 ILO 146.4375 GR 546.8125 1.3829 ILM -999.2500 CALl -999.2500 RNRA -999.2500 3.5354 ILM -999.2500 C~LI -999.2500 RNR~ -999.2500 3.5452 ILM -999.2500 CALI -999.2500 RNRA -999.2500 3.4807 ILM -999.2500 CAL'i -999.2500 RNRA -999.2500 3.0374 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 2.7500 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 2.7776 ILM -999.2500 CALI -999.2500 RNR4 -999.2500 3.1506 ILM 115.7148 CAL'I 3.0315 RNRA 835.3125 3.4006 ILM 101.9648 CALI 2.7346 RNRA 992.3125 3.2229 ILM 150.8125 CALl 3.2307 RNR~ 640.8125 2.7385 ILM 146.4375 CaLl 1.4708 -999.2500 -999.2500 3.6174 -999.2500 -999.2500 3.6331 -999.2500 -999.2500 3.5120 -999.2500 -999.2500 3.1174 -999.2500 -999.2500 2.8440 -999.2500 -999.2500 2.9866 -999.2500 -999.2500 3.0549 5.7703 3.3.4'59 3.5096 6.6218 2.8167 3.2776 8.1973 3.3088 9.3379 8.7832 LVP 010.H02 VERIFICATION LISTING PAGE 6 RH06 2.3596 ORHO NPHI 42.1387 NCNL DEFT 4900.0000 SFLU SP -56.4883 GR RHO5 -999.2500 DRHG NPHI -999.2500 NCNL DEFT 4885.5000 SFLU SP -55.4883 GR RHOB -999.2500 DRHO NPHi -999.2500 NCNL 0.0356 NRAT 1976.5875 FCNL 2000.6875 iLO 109.9645 GR -999.2500 NRAT -9'99.2500 FCNL 2000.6875 ILD 72.6523 GR -999.2500 NRAT -999.2500 FCNL ~:~: FTLE_ TRAILER FILE NAME :EDIT .001 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME .-o,. 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